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P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
August 9, 2025
Commissioner Jessie Chmielowski
Alaska Oil & Gas Commission
333 West 7th Avenue, Suite 100
Anchorage, AK 99501
Commissioner Jessie Chmielowski:
Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of
these wells were found to have a void in the conductor. These voids were filled with cement if
needed and corrosion inhibitors, engineered to prevent water from entering the annular space.
As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification
that the treatments took place and meets the requirements of form 10-404, Report of Sundry
Operations. The attached spread sheet presents the well name, top of cement depth prior to filling
and volumes used on each conductor.
Please call Brennen Green or Roger Mouser at 907-659-7506, if you have any questions.
Sincerely,
ConocoPhillips Well Integrity Field Supervisor
RBDMS JSB 081425
Digitally signed by Brennen Green
DN: C=US, O=ConocoPhillips, CN=Brennen Green, E=n1927@
conocophillips.com
Reason: I am the author of this document
Location:
Date: 2025.08.11 16:34:01-08'00'
Foxit PDF Editor Version: 13.1.6
Brennen Green
ConocoPhillips Alaska Inc.Well Name API # PTD #Initial top of cementVol. of Portland Type I cement pumpedFinal top of cementCement top off date Corrosion inhibitorCorrosion inhibitor/ sealant datein gal in gal1C-17 50-029-22872-00-00 198-224 N/AN/A post SC Repair8" N/A 0.85 8/7/20251C-150 50-029-23496-00-00 213-120 N/AN/A Rig cemented to surface4" N/A 3 8/7/20251C-152 50-029-23548-00-00 215-114 50" 34.4 9" 7/31/2025 2.13 8/7/20251C-153 50-029-23549-00-00 215-116 N/AN/A Rig cemented to surface9" N/A 1.73 8/7/20251C-154 50-029-23559-00-00 215-166 70" 51.8 10" 7/31/2025 3.4 8/7/20251C-155 50-029-23561-00-00 215-180 64" 35.8 8" 7/31/2025 1.7 8/7/20251C-15650-029-23750-00-00 223-023 25" 12.00 10" 7/31/2025 5.1 8/7/20251C-157 50-029-23754-00-00 223-038 57" 30.28 9" 7/31/2025 2.2 8/7/20251C-15850-029-23761-00-00 223-056 3"N/A Rig cemented to surface10" 7/31/2025 4.25 8/7/20251C-501 50-029-23757-00-00 223-045 139" 11.40 8" 7/31/2025 3.8 8/7/20251H-107 50-029-23795-00-00 224-092 34" 14.80 10" 7/31/2025 5.25 8/7/20251H-11250-029-23787-01-00 224-032 47" 33.19 7" 7/31/2025 4.25 8/7/20251H-12050-029-23794-01-00 224-081 30" 13.70 8" 7/31/2025 4 8/7/20253H-3550-103-20805-00-00 219-064 45" 32.20 7" 8/1/2025 3.6 8/8/20253H-3650-103-20838-00-00 222-014 60" 44.20 8" 8/1/2025 3.4 8/8/20253H-3750-103-20822-00-00 219-194 35" 23.00 8" 8/1/2025 3.4 8/8/2025Date 08/09/251C, 1H, and 3H PadsKuparuk FieldReport of Sundry Operations (10-404)Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off1C-15650-029-23750-00-00223-02325"12.0010"7/31/20255.18/7/2025
Originated: Delivered to:7-Mar-25
Halliburton Alaska Oil and Gas Conservation Comm.
Wireline & Perforating Attn.: Natural Resource Technician
Attn: Fanny Haroun 333 West 7th Avenue, Suite 100
6900 Arctic Blvd. Anchorage, Alaska 99501
Anchorage, Alaska 99518
Office: 907-275-2605
FRS_ANC@halliburton.com
The technical data listed below is being submitted herewith. Please address any problems or
concerns to the attention of the sender above
WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#
1 1A-20 50-029-22112-00 909816971 Kuparuk River Packer Setting Record Field- Final 16-Feb-25 0 1
2 1A-24 50-029-22984-00 909816969 Kuparuk River Multi Finger Caliper Field & Processed 12-Feb-25 0 1
3 1A-24 50-029-22984-00 909816969 Kuparuk River Plug Setting Record Field- Final 15-Feb-25 0 1
4 1C-156 50-029-23750-00 909809782 Kuparuk River Injection Profile Field & Processed 11-Jan-25 0 1
5 1E-11 50-029-20787-00 909890720 Kuparuk River Leak Detect Log Field- Final 1-Mar-25 0 1
6 1E-11 50-029-20787-00 909890665 Kuparuk River Plug Setting Record Field- Final 1-Mar-25 0 1
7 1E-11 50-029-20787-00 909890665 Kuparuk River Plug Setting Record Field- Final 28-Feb-25 0 1
8 1E-22 50-029-20884-00 909890664 Kuparuk River Leak Detect Log Field- Final 27-Feb-25 0 1
9 1Q-04 50-029-21250-00 909678506 Kuparuk River SBHP Record Field- Final 9-Nov-24 0 1
10 2B-11 50-029-21089-00 909890473 Kuparuk River Packer Setting Record Field- Final 21-Feb-25 0 1
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:
Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518
FRS_ANC@halliburton.com
Date:Signed:
Transmittal Date:
T40190
T40191
T40191
T40192
T40193
T40193
T40193
T40194
T40195
T40196
190-162
200-181
223-023
182-051
182-214
184-234
184-035
3/7/2025 Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2025.03.07 10:25:17 -09'00'
223-023
1C-156 50-029-23750-00 909809782 Kuparuk River Injection Profile Field & Processed 11-Jan-25 0 1
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Friday, January 12, 2024
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Bob Noble
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
ConocoPhillips Alaska, Inc.
1C-156
KUPARUK RIV U WSAK 1C-156
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 01/12/2024
1C-156
50-029-23750-00-00
223-023-0
W
SPT
3968
2230230 1500
629 629 629 629
132 190 190 190
INITAL P
Bob Noble
11/15/2023
30 MinPretestInitial15 Min
Well Name
Type Test
Notes:
Interval P/F
Well
Permit Number:
Type Inj TVD
PTD Test psi
API Well Number Inspector Name:KUPARUK RIV U WSAK 1C-156
Inspection Date:
Tubing
OA
Packer Depth
1210 1810 1785 1785IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitRCN231116161957
BBL Pumped:0.6 BBL Returned:0.7
Friday, January 12, 2024 Page 1 of 1
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: Convert to Injector
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 19567'feet None feet
true vertical 3881' feet None feet
Effective Depth measured 19567'feet 9599'feet
true vertical 3881' feet 3968' feet
Perforation depth Measured depth
True Vertical depth
Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 9636' MD 3969' TVD
Packers and SSSV (type, measured and true vertical depth) 9599' MD
N/A
3968' TVD
N/A
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure: N/A
13a.
Prior to well operation:
Subsequent to operation:
13b. Pools active after work: West Sak Oil Pool
15. Well Class after work:
Daily Report of Well Operations Exploratory Development Service Stratigraphic
Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL
Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG
Sundry Number or N/A if C.O. Exempt:
Authorized Name and
Digital Signature with Date: Contact Name:
Contact Email:
Authorized Title: Contact Phone:
323-574
Sr Pet Eng: 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.
N/A
Packer: Baker SLZXP LT Packer
SSSV: None
Will Parker
will.parker@conocophillips.com
(907) 265-6239Senior Production Engineer
Slotted Liner: 9599-19517'
Slotted Liner: xx-3882'
measured
true vertical
Packer
Representative Daily Average Production or Injection Data
Casing Pressure Tubing Pressure
14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283)
~
Gas-Mcf
MD
~
Size
148'
~ ~~
INJECTOR ~~
~
measured
TVD
7-5/8"
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
223-023
50-029-23750-00-00
P.O. Box 100360
Anchorage, AK 99510
3. Address:
ConocoPhillips Alaska, Inc.
N/A
5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work:
ADL025638, ADL025649, ADL028242
Kuparuk River Field/ West Sak Oil Pool
KRU 1C-156
Plugs
Junk measured
Length
Production
Slotted Liner
9737'
9918'
Casing
3971'
4-1/2"
9773'
19517' 3882'
1906'
148'Conductor
Surface
Intermediate
24"
10-3/4"
109'
1945' 1900'
Burst Collapse
Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov
Digitally signed by Will Parker
DN: CN=Will Parker, O=ConocoPhillips, OU=GKA Production
Engineering, E=Will.Parker@ConocoPhillips.com, C=US
Reason: I am the author of this document
Location:
Date: 2023.11.17 06:22:02-09'00'
Foxit PDF Editor Version: 13.0.0
Will Parker
By Grace Christianson at 10:06 am, Nov 17, 2023
DTTMSTART JOBTYP SUMMARYOPS
11/1/2023 REPAIR WELL PULL OV @ 1825' RKB. LOAD IA WITH 55 BBLS OF DIESEL. SET DV @ 1825'
RKB. PERFORM PASSING MITIA TO 2500 PSI, JOB COMPLETE.
1C-156 Convert to Injection
Summary of Operations
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason:Set OV Sta #1 (Sheared Arsenal Disk) 1C-156 8/13/2023 scolem
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 24 20.00 39.1 148.0 148.0 154.34 65 Welded
Surface 10 3/4 9.95 39.0 1,945.4 1,900.2 45.50 L-80 Hyd563
Intermediate 7 5/8 6.88 36.2 9,772.9 3,970.7 29.70 L80 Hyd563
Slotted Liner 4 1/2 3.83 9,598.6 19,517.0 3,881.9 12.60 L-80 HYD563
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
33.8
Set Depth
9,635.5
Set Depth
3,969.4
String Max No
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)
33.8 33.8 0.00 Hanger 5.750 Vault 4-1/2" Tubing Hanger Vault SN#
6506411
3.900
1,721.8 1,698.0 22.86 Nipple - X 4.500 X Nipple, 4-1/2" / 3.813" ID, SN#
0004855432-12
Halliburt
on
SR#
0004855
432-12
3.813
1,825.5 1,792.7 25.09 Mandrel - SOV 5.500 KBMG 4-1/2" w/ 1" SOV @ 2000
PSI, SN# 23685-02
VanOil 1114S20
1
3.865
9,388.6 3,963.7 87.98 Mandrel GAS
LIFT
5.500 KBMG 4-1/2" w/ 1" Dummy, SN#
23061-12
VanOil 1114S20
1
3.865
9,498.5 3,966.6 89.04 Nipple - XN 4.500 XN Nipple, 4-1/2" / 3.813" ID with
3.725" No-Go, SN# 0004685840-1
Halliburt
on
SR#
0004685
840-1
3.730
9,551.4 3,967.4 88.94 Sub - Shear
Out - SOS
4.500 Arsenal Glass Disk Sub (3500 psi
Shear) SN# 12299-01-01
3.958
9,603.7 3,968.6 88.52 Locator 5.170 Baker Mechanical Locator (4.30'
from fully located)
Baker 1080412
72-06
3.900
9,605.6 3,968.6 88.51 Seal Assembly 4.500 Seal Assembly Baker 1080412
72-06
3.900
9,631.5 3,969.3 88.67 Shoe - Mule 4.740 HES Self-Aligning Muleshoe Baker 0004921
822-3
3.870
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)
1,825.5 1,792.7 25.09 1 GAS LIFT OV BK 1 8/13/2023 Camco 0.313
9,388.6 3,963.7 87.98 2 GAS LIFT DMY BK 1 6/13/2023 Dum
my
Valve
Camco Dummy
valve
1.000
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)
9,598.6 3,968.4 88.56 Packer 5.500 Baker SLZXP 4.75" x 7.63" Liner
top packer L-80 5.5" Hyd 563 pin
Baker SLZXP S/N
ZAN465
4.750
14,498.2 3,935.8 90.08 Packer - Swell 6.000 Baker Swell Packer, 4-1/2" x 6-
1/8", SN 003453-001-2
Baker Rapid Swell
920
compound
3.833
14,805.5 3,927.7 92.45 Packer - Swell 6.000 Baker Swell Packer, 4-1/2" x 6-
1/8", SN 003453-001-8
Baker Rapid Swell
920
compound
3.833
16,391.6 3,907.5 90.02 Packer - Swell 6.000 Baker Swell Packer, 4-1/2" x 6-
1/8", SN 003453-001-1
Baker Rapid Swell
920
compound
3.833
16,698.9 3,908.3 89.99 Packer - Swell 6.000 Baker Swell Packer, 4-1/2" x 6-
1/8", SN 003453-001-17
Baker Rapid Swell
920
compound
3.833
HORIZONTAL, 1C-156, 10/12/2023 1:10:30 PM
Vertical schematic (actual)
Slotted Liner; 9,598.6-19,517.0
Intermediate; 36.2-9,772.9
Seal Assembly; 9,605.6
Sub - Shear Out - SOS; 9,551.4
Nipple - XN; 9,498.5
Mandrel GAS LIFT; 9,388.6
Intermediate String 1 Cement;
3,354.0 ftKB
Surface; 39.0-1,945.4
Mandrel - SOV; 1,825.4
Nipple - X; 1,721.8
Surface String Cement; 39.5
ftKB
Conductor; 39.1-148.0
Hanger; 33.8
KUP SVC
KB-Grd (ft)
39.00
RR Date
6/14/2023
Other Elev
1C-156
...
TD
Act Btm (ftKB)
19,567.0
Well Attributes
Field Name
WEST SAK
Wellbore API/UWI
500292375000
Wellbore Status
SVC
Max Angle & MD
Incl (°)
92.62
MD (ftKB)
14,740.03
WELLNAME WELLBORE1C-156
Annotation End DateH2S (ppm) DateComment
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?
Yes No
9. Property Designation (Lease Number): 10. Field:
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:
Contact Email:
Contact Phone:
Authorized Title:
Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number:
Plug Integrity BOP Test Mechanical Integrity Test Location Clearance
Other Conditions of Approval:
Post Initial Injection MIT Req'd? Yes No
APPROVED BY
Approved by: COMMISSIONER THE AOGCC Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
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):Perforation Depth TVD (ft):
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
Length Size
Proposed Pools:
TVD BurstMD
Perforation Depth MD (ft):
approval: Notify AOGCC so that a representative may witness Sundry Number:
BOP Test Mechanical Integrity TestLocation Clearance
ons of Approval:
ection MIT Req'd? Yes No Subsequent Form Required:
Suspension Expiration Date:
AOGCC USE ONLY
Contact Name:
Contact Email:
Contact Phone:
e:
certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval.
me and
ure with Date:
Datefor 15. Well Status after proposed work:
Operations:OIL WINJ WDSPL Suspended
proval:Date:GAS WAG GSTOR SPLUG
esentative: GINJ Op Shutdown Abandoned
nts: Proposal Summary Wellbore schematic13. Well Class after proposed work:
ations Program BOP Sketch Exploratory Stratigraphic Development Service
SSSV Type:Packers and SSSV MD (ft) and TVD (ft):
TubingSize:Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft):pth MD (ft):
quest: Abandon Plug PerforationsFracture Stimulate Reppair Well Operations shutdown
Suspend Perforate Other Stimulate Pulll Tubing Change Approved Program
Plugfor Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: er Casing ___________________
ame:4.Current Well Class:5.Permit to Drill Number:
Exploratory Development
Stratigraphic Service 6.API Number:
g:8. Well Name and Number:
ation or Conservation Order governs well spacing in this pool?
Yes No
esignation (Lease Number):10. Field:
D (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD:Junk (MD):
g Collapse
al
or
e
ate
on
quire a spacing exception due to property boundaries?
Current Pools:
MPSP (psi):Plugs (MD):
PRESENT WELL CONDITION SUMMARY
Length Size
Proposed Pools:
TVD BurstMD
Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
Convert to INJ
ConocoPhillips Alaska, Inc.
1C-156N/A
223-023
50-029-23750-00-00
Kuparuk River Field West Sak
PO Box 100360, Anchorage, AK 99510
ADL025649 / ADL028242 / ADL025638
20"109' 148' 148'
1945' 1900'1906'
9737'
10 3/4"
7 5/8"
None None
9773' 3971'
9918' 4 1/2" 19517' 3882'
9599' - 19517' 3968' - 3882' 4 1/2" L-80 9636'
Baker Liner Top Packer 9599' MD (3968' TVD)
Marina Krysinski
marina.l.krysinski@cop.com
907-263-4018Surveillance Reservoir Engineer
19567' 3881' 19567' 3881'
November 1, 2023
By Grace Christianson at 3:04 pm, Oct 19, 2023
Marina Krysinski Digitally signed by Marina
Krysinski
Date: 2023.10.19 14:54:38 -08'00'
X 10-404
DSR-10/19/23
g pp
Convert to INJ
VTL 11/1/2023
X
SFD 10/20/2023*&:
Brett W. Huber, Sr.Digitally signed by Brett W.
Huber, Sr.
Date: 2023.11.01 13:26:02 -08'00'11/01/23
RBDMS JSB 110223
1
ConocoPhillips Alaska, Inc.
700 G St.
Anchorage, AK 99501-3448
October 19, 2023
AOGCC Commissioner
State of Alaska, Oil & Gas Conservation Commission
333 W. 7th Ave., Ste. 100
Anchorage, AK 99501
Re: KRU 1C-156 (PTD 223-023) Conversion to Injection
Dear Commissioner,
ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk River Unit Well 1C-156
from Production to Water Alternating Gas Service. A 10-404 was recently submitted to
inform of our intention to flow back this injector for more than 30 days, effectively,
converting it to a producer. The required flowback will be complete next week and the
well is planned to be placed water injection service.
Attached you will find the 10-403 Application for Sundry Approval for ConocoPhillips
Alaska, Inc. for conversion of KRU 1C-156 to WAG service.
If you have any questions regarding this matter, please contact me at 907-263-4018 or
by email at marina.l.krysinski@cop.com.
Sincerely,
Marina Krysinski
Surveillance Reservoir Engineer
ConocoPhillips Alaska, Inc.
Attachments:
Sundry application
1C-156
DESCRIPTION SUMMARY OF PROPOSAL
ConocoPhillips Alaska Inc. requests approval to convert Kuparuk River Unit Well 1C-156 from Oil Production
service to Water Alternating Gas Injection service now that the post-drill flowback has been completed.
Area of Review:
KRU Well 1C-156 was originally completed as an injector in the West Sak reservoir in June 2023. The
flowback period required to clean up the completion exceded the 30 day window for flowback and the well was
converted to production.
The top of the West Sak D-sand in 1C-156 is at 8274' MD / 3783' TVDSS.
Area Map with 1/4 mile radius around target injection zone (see attached)
The attached map shows that seven KRU wells are located within the 1/4 mile radius, all of which have surface
casing set and cemented to surface across the West Sak interval. Further detail on each well is provided in the
AOR table.
Mechanical Condition of Well to be Converted:
The mechanical condition of 1C-156 is good. The injection tubing / casing annulus is isolated with a Halliburton
TNT Prod Packer set at 9599' MD / 3968' TVD.
A NON-witnessed MITIA will be performed prior to injection. After injection has stablized a State-witnessed SW
MITIA will be performed.
CBL and interpretation of cement quality
All hydrocarbon zones penetrated by the well are isolated. See attached Area of Review Detail for offset wells.
The 10-3/4" Surface Casing was cemented with 381 bbls of 10.7 ppg lead cement and 58 bbls of 15.8 ppg tail
cement.
The 7-5/8" intermediate string was cemented with 241 bbls of 14 ppg lead cement and 55 bbls of 15.3 ppg tail
cement. Sonic log indicates top of cement at 3359' MD / 2893' TVD.
converted to production.
g
Sonic log indicates top of cement at 3359' MD f
convert Kuparuk River Unit Well 1C-156 from Oil Productionpqpp
service to Water Alternating Gas Injection s
originally completed as an injector in the West Sak reservoir in June 2023.
KRU 1C-156 AREA OF REVIEW
PTD API WELL NAME STATUS
Top of West Sak
D-sand (MD)
Top of West Sak D-
sand (TVDSS)
Top of Cement
(MD)
Top of Cement
(TVDSS)
Top of Cement
Determined By Reservoir Status Zonal Isolation Cement Operations Summary Mechanical Integrity
206-001 500292286101 1C-14A Injector 6,209 3,815 Surface Surface Returns
Active Kuparuk C-sand
Injector
9 5/8" surface casing set below the
West Sak interval and cemented to
surface
Lead: 236 bbls 10.5 ppg
Tail: 130 bbls
2nd stage lead: 442 bbls 10.8
ppg
2nd stage tail: 10 bbls
5/17/22 - passed state-
witnessed MITIA to 1800 psi
198-229 500292293200 1C-15 Injector 5,352 3,808 Surface Surface Returns
Active Kuparuk C-sand
Injector
9 5/8" surface casing set below the
West Sak interval and cemented to
surface
Lead: 662 bbls 10.7 ppg
Tail: 122 bbls 15.8 ppg
5/17/22 - passed state-
witnessed MITIA to 1800 psi
198-246 500292293400 1C-16 Producer 6,203 3,802 Surface Surface Returns
Active Kuparuk C-sand
Producer
9 5/8" surface casing set below the
West Sak interval and cemented to
surface
Lead: 699 bbls 10.7 ppg
Tail: 145 bbls 15.8 ppg
5/7/2019 - passed TIFL
5/27/2013 - IA tested to
2500 psi on rig
203-054 500292314900 1C-19 Producer 5,548 3,780 Surface Surface Returns
Active Kuparuk C-sand
Producer
9 5/8" surface casing set below the
West Sak interval and cemented to
surface
Lead: 655 bbls 10.7 ppg
Tail: 144 bbls 12.0 ppg
5/19/2019 - passed TIFL
9/7/2017 - MITIA passed to
2750 psi
199-031 500292294100 1C-25 Injector 5,453 3,804 Surface Surface Returns
Active Kuparuk C-sand
Injector
9 5/8" surface casing set below the
West Sak interval and cemented to
surface
Lead: 628 bbls 10.7 ppg
Tail: 128 bbls 15.7 ppg
5/15/2022 - passed state-
witnessed MITIA to 1810 psi
199-043 500292294300 1C-27 Injector 5,779 3,837 Surface Surface Returns
Active Kuparuk C-sand
Injector
9 5/8" surface casing set below the
West Sak interval and cemented to
surface
Lead: 651 bbls 10.7 ppg
Tail: 134 bbls 15.7 ppg
Waivered for water injection
only
10/28/2022 - passed MITIA
to 3010 psi
205-104 500292327000 1C-28 Producer 7,415 3,813 Surface Surface Returns
Active Kuparuk C-sand
Producer
10 3/4" surface casing set below the
West Sak interval and cemented to
surface
Lead: 859 bbls of 10.7 ppg
Tail: 229.5 bbls 12.0 ppg
3/1/2018 - passed CMIT to
2500 psi
4/2/2016 - passed TIFL
215-180 1C-155 Prod 6,210 3,782 3,758 2,891 MD Shoe @ 6,413 MD with top cmt @ 3,758' MD isolates t/West Sak and overlying Ugnu sands.
223-038 1C-157 Prod 10,332 3,814 3,422 2,737 MD Shoe at 11,256 MD with top cmt @ 3,442 MD isolates t/West Sak and overlying Ugnu sands. SFD
3S-625
DESCRIPTION OF WORK COMPLETED
SUMMARY
Date Event Summary
3S-625
DESCRIPTION OF WORK COMPLETED
SUMMARY
2
T12NR11E
T11NR11E
T1
2
N
R
1
1
E
T1
2
N
R
1
0
E
T1
1
N
R
1
1
E
T1
1
N
R
1
0
E
T12NR10E
T11NR10E
ADL025638
ADL025649
ADL028243
ADL025650
ADL028242
ADL047449
3135
1211
2
13
36
7
14
1
18
6
1C
1C-09
L3
-0
21
D
-
1
2
L
3
-
0
3
1
D
-
1
1
2
1
C
-
1
3
3
1
D
-
1
1
0
A
1
D
-
1
0
3
1
D
-
1
1
0
1D-
1
0
5
1
D
-
1
1
1
1
D
-
1
0
1
1C-117
1D
-
0
1
1D
-
1
0
7
1C-04
1D
-
1
4
0
L
1
1C
-
0
2
1C-01
1
D
-
1
4
1C-1
2
3
1C
-
0
5
1D
-
1
4
0
1
D
-
1
0
8
1D
-
1
4
3
L
1
1C
-
1
8
1
C
-
1
3
1
1D
-
1
4
3
L
3
1D
-
1
4
5
1C-119
1D-02
1C-0
8
1C-0
8
L
1
1C-0
8
L
1
-
0
1
1C-1041C-104
L
1
1C-121
1C-
1
2
7
1C-0
1
L
1
1C-17
8
L
1
1C-17
8
1C-
1
1
1
1
C
-
0
1
L
1
-
0
1
1C-03A
1C-03
1C
-
1
3
1C-12
5
1C-24
1C-01
L
1
-
0
2
1C
-
1
0
1C
-
1
0
9
1C
-
1
0
9
L
1
1
C
-
0
4
A
L
1
1
C
-
0
1
L
1
-
0
3
1
C
-
0
4
A
1
C
-
1
7
4
1D
-
1
0
5
A
1C-15
1C
-
0
7
1C-21L1
1
D
-
1
4
3
1D
-
1
4
3
L
2
1C-06
1C-21L2
1
C
-
1
7
1C-24L1
1C-25
1C-
1
9
1
C
-
1
3
5
1C-0
7
A
L
1
1C
-
1
9
0
1C-15
L
1
1C-07A
1C-14
1
C
-
1
1
1C-27
1C
-
1
0
2
1C
-
1
0
2
L
1
1C-23A
1C-23AL11C-23AL21C-23AL2-011C-23AL2-021C-23
1C-06L1
1C-25L1
1
C
-
1
7
0
1C-16
1
C
-
1
8
4
1C-21L3
1C-21
1C-15
L
2
1C-28
1C-28L
1
1C-22
1C-14A
1
C
-
1
5
1
1
C
-
1
5
2
1C
-
1
1
L
2
-
0
1
1C
-
1
1
L
2
1C
-
1
7
2
1C-11L
1
-
0
1
1C-
0
6
L
1
-
0
2
1C-11
L
1
-
0
2
1
C
-
1
5
0
1
C
-
1
5
3
1
C
-
1
5
4
1
C
-
1
1
L
1
1C-26
1C
-
0
6
L
1
-
0
1
1C-
1
2
1C-2
0
1C
-
1
7
2
A
L
2
1
C
-
1
5
5
1C
-
1
7
2
A
1C
-
1
7
2
A
L
1
1C
-
1
9
L
1
1C
-
1
1
L
2
-
0
2
1
C
-
1
5
6
1
C
-
1
5
7
10/18/2023
1C-156
Injection Sundryk
2 Well Pad
Top WSAK Pick
Open Interval
Well Trajectory
P+A Well
Active Well
1C-156 Quarter Mile Radius
Roads and Pads
Kuparuk PA
West Sak PA
Unit Boundary
CPAI Lease
ADNR Township
ADNR Section 00.50.25 Miles
10-3/4" 45.5# L80 H563
1945' (1900' TVD)
7-5/8" 29.7# L80 H563 CSG
9773' (3973' TVD)
Wellhead
Vault 10-3/4" x 7-5/8" x 4-½” 5M MB-222
1C
-
1
5
6
A
s
-
d
r
i
l
l
e
d
s
c
h
e
m
a
t
i
c
.
v
s
d
6/
2
0
/
2
0
2
3
As
-
D
r
i
l
l
e
d
S
c
h
e
m
a
t
i
c
I
n
j
e
c
t
o
r
4-½” 12.6# L80 H563 Completion Tubing
6-3/4” OH
19567' (3881' TVD)
SLZXP Liner Top Packer & Liner Hanger 9599'
1825' Gas Lift Mandrel, Camco KBMG 4-1/2" x 1"
9498' 4-½” XN Nipple 3.813" w/3.725" No-Go
1722' 4-½” X Nipple, 3.813"
1C-156 Slotted Liner Injector
As-Drilled Schematic
9389' Gas Lift Mandrel, Camco KBMG 4-1/2" x 1"
9551' Arsenal Glass Disk Sub
9604' Locator & Seal Assembly
20" Conductor 148'
4-½” 12.6# L80 H563 Slotted Liner
Float Shoe
19517' (3882' TVD)
Baker Water Swell Packer 16699'
16392'14805'14498'
Fault 16567'Fault 14680'
Baker 20' Sealbore Extension 9621'
TOC 3359' (2893' TVD)
Top Ugnu C 4052' (3203' TVD)
9635' Bottom of Muleshoe
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: Pre-produce > 30 days
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 19567'feet None feet
true vertical 3881' feet None feet
Effective Depth measured 19567'feet 9599'feet
true vertical 3881' feet 3968' feet
Perforation depth Measured depth
True Vertical depth
Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 9636' MD 3969' TVD
Packers and SSSV (type, measured and true vertical depth) 9599' MD
N/A
3968' TVD
N/A
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure: N/A
13a.
Prior to well operation:
Subsequent to operation:
13b. Pools active after work: West Sak Oil Pool
15. Well Class after work:
Daily Report of Well Operations Exploratory Development Service Stratigraphic
Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL
Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG
Sundry Number or N/A if C.O. Exempt:
Authorized Name and
Digital Signature with Date: Contact Name:
Contact Email:
Authorized Title: Contact Phone:
1945' 1900'
Burst Collapse
Production
Slotted Liner
9737'
9918'
Casing
3971'
4-1/2"
9773'
19517' 3882'
1906'
148'Conductor
Surface
Intermediate
24"
10-3/4"
109'
measured
TVD
7-5/8"
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
223-023
50-029-23750-00-00
P.O. Box 100360
Anchorage, AK 99510
3. Address:
ConocoPhillips Alaska, Inc.
N/A
5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work:
ADL025638, ADL025649, ADL028242
Kuparuk River Field/ West Sak Oil Pool
KRU 1C-156
Plugs
Junk measured
Length
measured
true vertical
Packer
Representative Daily Average Production or Injection Data
Casing Pressure Tubing Pressure
14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283)
110
Gas-Mcf
MD
0
Size
148'
110 65020
0 00
275
N/A
Sr Pet Eng: Sr Pet Geo: Sr Res Eng:
WINJ WAG
0
Water-BblOil-Bbl
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
N/A
Packer: Baker SLZXP LT Packer
SSSV: None
Marina Krysinski
Marina.L.Krysinski@conocophillips.com
(907) 263-4018Surveillance Reservoir Engineer
Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov
Slotted Liner: 9599-19517'
Slotted Liner: 3968-3882'
By Grace Christianson at 7:40 am, Oct 13, 2023
Marina Krysinski
Surveillance Reservoir Engineer
ConocoPhillips Alaska, Inc.
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
October 12, 2023
Commissioner
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, AK 99501
Commissioner,
Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for KRU 1C-156 (PTD 223-
023), Pre-producing the well over 30 days.
1C-156 was drilled as an injector which was expected to pre-produce for approximately two
weeks to clean up filter cake from drilling operations. Due to the deviation of the well, a shallow
gas lift point was used. This resulted in lower-than-expected production rates, so we do not think
we have adequately cleaned up the wellbore. The well is being converted to production to allow
us time to perform well intervention to lift the well deeper and better clean up the lateral prior to
putting the well on injection.
Please contact me, Marina Krysinski at (907) 263-4018,if you have any questions.
Sincerely,
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason:Set OV Sta #1 (Sheared Arsenal Disk) 1C-156 8/13/2023 scolem
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 24 20.00 39.1 148.0 148.0 154.34 65 Welded
Surface 10 3/4 9.95 39.0 1,945.4 1,900.2 45.50 L-80 Hyd563
Intermediate 7 5/8 6.88 36.2 9,772.9 3,970.7 29.70 L80 Hyd563
Slotted Liner 4 1/2 3.83 9,598.6 19,517.0 3,881.9 12.60 L-80 HYD563
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
33.8
Set Depth
9,635.5
Set Depth
3,969.4
String Max No
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)
33.8 33.8 0.00 Hanger 5.750 Vault 4-1/2" Tubing Hanger Vault SN#
6506411
3.900
1,721.8 1,698.0 22.86 Nipple - X 4.500 X Nipple, 4-1/2" / 3.813" ID, SN#
0004855432-12
Halliburt
on
SR#
0004855
432-12
3.813
1,825.5 1,792.7 25.09 Mandrel - SOV 5.500 KBMG 4-1/2" w/ 1" SOV @ 2000
PSI, SN# 23685-02
VanOil 1114S20
1
3.865
9,388.6 3,963.7 87.98 Mandrel GAS
LIFT
5.500 KBMG 4-1/2" w/ 1" Dummy, SN#
23061-12
VanOil 1114S20
1
3.865
9,498.5 3,966.6 89.04 Nipple - XN 4.500 XN Nipple, 4-1/2" / 3.813" ID with
3.725" No-Go, SN# 0004685840-1
Halliburt
on
SR#
0004685
840-1
3.730
9,551.4 3,967.4 88.94 Sub - Shear
Out - SOS
4.500 Arsenal Glass Disk Sub (3500 psi
Shear) SN# 12299-01-01
3.958
9,603.7 3,968.6 88.52 Locator 5.170 Baker Mechanical Locator (4.30'
from fully located)
Baker 1080412
72-06
3.900
9,605.6 3,968.6 88.51 Seal Assembly 4.500 Seal Assembly Baker 1080412
72-06
3.900
9,631.5 3,969.3 88.67 Shoe - Mule 4.740 HES Self-Aligning Muleshoe Baker 0004921
822-3
3.870
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)
1,825.5 1,792.7 25.09 1 GAS LIFT OV BK 1 8/13/2023 Camco 0.313
9,388.6 3,963.7 87.98 2 GAS LIFT DMY BK 1 6/13/2023 Dum
my
Valve
Camco Dummy
valve
1.000
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)
9,598.6 3,968.4 88.56 Packer 5.500 Baker SLZXP 4.75" x 7.63" Liner
top packer L-80 5.5" Hyd 563 pin
Baker SLZXP S/N
ZAN465
4.750
14,498.2 3,935.8 90.08 Packer - Swell 6.000 Baker Swell Packer, 4-1/2" x 6-
1/8", SN 003453-001-2
Baker Rapid Swell
920
compound
3.833
14,805.5 3,927.7 92.45 Packer - Swell 6.000 Baker Swell Packer, 4-1/2" x 6-
1/8", SN 003453-001-8
Baker Rapid Swell
920
compound
3.833
16,391.6 3,907.5 90.02 Packer - Swell 6.000 Baker Swell Packer, 4-1/2" x 6-
1/8", SN 003453-001-1
Baker Rapid Swell
920
compound
3.833
16,698.9 3,908.3 89.99 Packer - Swell 6.000 Baker Swell Packer, 4-1/2" x 6-
1/8", SN 003453-001-17
Baker Rapid Swell
920
compound
3.833
HORIZONTAL, 1C-156, 10/12/2023 1:10:30 PM
Vertical schematic (actual)
Slotted Liner; 9,598.6-19,517.0
Intermediate; 36.2-9,772.9
Seal Assembly; 9,605.6
Sub - Shear Out - SOS; 9,551.4
Nipple - XN; 9,498.5
Mandrel GAS LIFT; 9,388.6
Intermediate String 1 Cement;
3,354.0 ftKB
Surface; 39.0-1,945.4
Mandrel - SOV; 1,825.4
Nipple - X; 1,721.8
Surface String Cement; 39.5
ftKB
Conductor; 39.1-148.0
Hanger; 33.8
KUP SVC
KB-Grd (ft)
39.00
RR Date
6/14/2023
Other Elev
1C-156
...
TD
Act Btm (ftKB)
19,567.0
Well Attributes
Field Name
WEST SAK
Wellbore API/UWI
500292375000
Wellbore Status
SVC
Max Angle & MD
Incl (°)
92.62
MD (ftKB)
14,740.03
WELLNAME WELLBORE1C-156
Annotation End DateH2S (ppm) DateComment
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: 1441' FSL, 5113' FWL S12 T11N R10E 9. Ref Elevations: KB:
GL: 58.3 BF:
Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation:
4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number:
Surface: x- y- Zone- 4
TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD:
Total Depth: x- y- Zone- 4
5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD:
Submit electronic information per 20 AAC 25.050 N/A (ft MSL)
22. Logs Obtained:
23.
BOTTOM
20" 65 148'10yards
10-3/4" L-80 1900'
7 5/8" L-80 3971'
4 1/2" L-80 3882'
24. Open to production or injection? Yes No 25.
26.
Was hydraulic fracturing used during completion? Yes No
DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED
27.
Date First Production: Method of Operation (Flowing, gas lift, etc.):
Hours Tested: Production for Gas-MCF:
Test Period
Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr):
Press. 24-Hour Rate
Sr Res EngSr Pet GeoSr Pet Eng
N/A
Oil-Bbl: Water-Bbl:
Water-Bbl:
PRODUCTION TEST
N/A
Date of Test: Oil-Bbl:
Flow Tubing
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size
and Number; Date perf'd or liner run):
Liner: 9599'MD/3968' TVD - 19517'MD/3882'TVD
Gas-Oil Ratio:Choke Size:
suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud
log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing
collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary.
N/A
GR, RES, DEN, DIR, AZI, PWD, NEU, POR, SONIC,
39'
39'
Per 20 AAC 25.283 (i)(2) attach electronic information
29.7 36'
154.4
45.5
148
36' 9773'
SIZE DEPTH SET (MD) PACKER SET (MD/TVD)
9599'
42"
12.6
5968748
ADL025649, ADL028242, ADL025638
LONS 01-013
39'
39'
1945
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date perf'd or liner run):
WT. PER
FT.GRADE
566140
563884
CEMENTING RECORD
5966433
1832'MD/1799'TVD
SETTING DEPTH TVD
5977111
TOP HOLE SIZE AMOUNT
PULLEDTOP
SETTING DEPTH MD
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
ConocoPhillips Alaska, Inc.
WAG
Gas
6/13/2023 223-023
50-029-23750-00-00
KRU 1C-156
5/12/2023
19567'MD/3881'TVD
N/A
97.3
P.O.Box 100360, Anchorage, AK 99510-0360
562033
3791' FSL, 1026' FWL S12 T11N R10E
1579' FSL, 2951' FWL S36 T12N R10E
6/7/2023
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
CASING, LINER AND CEMENTING RECORD
List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion,
TUBING RECORD
19517'
Lead: 241 bbl 14ppg Class G
Tail: 55 bbl 15.3ppg Class G
3968
9.875'
6.5'
9636'4.5 9599'MD/3968' TVD
BOTTOM
13.5' Lead: 381bbl 10.7ppg Class G
Tail: 58bbl 15.8ppg Class G
CASING
Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment
17. Field / Pool(s):
Kuparuk River Field/ West Sak Oil pool
By Grace Christianson at 10:17 am, Jul 12, 2023
Complete
6/13/2023
JSB
RBDMS JSB 071223
G
ArcticCem SFD
SFD 10/20/2023 DSR-8/7/23
Conventional Core(s): Yes No Sidewall Cores:
30.
MD TVD
Surface Surface
1832 1799
8270 3880
19753 3881
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: Abby Warren
Digital Signature with Date:
Contact Phone:907-240-9293
General:
Item 1a:
Item 1b:
Item 4b:
Item 9:
Item 15:
Item 19:
Item 20:
Item 22:
Item 23:
Item 24:
Item 27:
Item 28:
Item 30:
Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and
other tests as required including, but not limited to: core analysis, paleontological report, production or well test results.
Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29.
Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool.
If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the
producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,
showing the data pertinent to such interval).
Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit
detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity,
permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology.
Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain).
Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical
laboratory information required by 20 AAC 25.071.
Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion,
suspension, or abandonment; or 90 days after log acquisition, whichever occurs first.
Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
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: abby.warren@conocophillips.com
Authorized Title: Drilling Engineer
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:
West Sak D
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
NAME
Permafrost - Top
Permafrost - Base
29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS
Top of Productive Interval:
West Sak D
Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov
10
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Page 1/28
1C-156
Report Printed: 6/29/2023
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)
5/10/2023
00:00
5/10/2023
12:00
12.00 MIRU, MOVE MOB P Rig down and prep for move to 1C-156 0.0 0.0
5/10/2023
12:00
5/10/2023
18:00
6.00 MIRU, MOVE MOB P Move rig to 1C-156 all modules are on
location @ 1800 hrs
0.0 0.0
5/10/2023
18:00
5/11/2023
00:00
6.00 MIRU, MOVE MOB P Prep location and spot modules and R/U
rig
0.0 0.0
5/11/2023
00:00
5/11/2023
00:15
0.25 MIRU, MOVE MOB P Nes SOW truck mechanical issue, Swap
trucks.
0.0 0.0
5/11/2023
00:15
5/11/2023
00:45
0.50 MIRU, MOVE RURD P Cont. t/ spot pump modules, t/pits
modules, R/D NES set and secure
0.0 0.0
5/11/2023
00:45
5/11/2023
01:15
0.50 MIRU, MOVE RURD P Spot motors modules t/pump modules,
R/D NES set and secure modules
0.0 0.0
5/11/2023
01:15
5/11/2023
01:45
0.50 MIRU, MOVE RURD P R/U NES t/pipeshed and ready t/spot
t/sub, Cont. t/matting board layout f/
setting shed
0.0 0.0
5/11/2023
01:45
5/11/2023
02:15
0.50 MIRU, MOVE RURD P Pipe Shed power loss, troubleshoot, low
voltage output Simops-Ready modules
interconnects f/Rig Accept Checklist.
0.0 0.0
5/11/2023
02:15
5/11/2023
03:00
0.75 MIRU, MOVE RURD P Spot Pipe Shed into sub Via Nes, Stage
modules Via Nes Until Power Restored
t/ move system
from setting and secure
0.0 0.0
5/11/2023
03:00
5/11/2023
03:45
0.75 MIRU, MOVE RURD P Spot Rrockwasher Via NES, Set and
secure, Lay Herculite and Berms for
cutting containment
and Magtec cuttings system
0.0 0.0
5/11/2023
03:45
5/11/2023
06:30
2.75 MIRU, MOVE RURD P Work on rig acceptance checklist, Plug
in Rig power to all modules, Cont. to
ready interconnects
service lines, R/U Rig floor Hydraulic
lines, Ready cellar area and Wind walls,
Stage lower surface riser
and annular Via bridge cranes, finish
spotting pipe shed modules to sub and
secure
0.0 0.0
5/11/2023
06:30
5/11/2023
09:30
3.00 MIRU, MOVE RURD P Cont. t/work on rig acceptance checklist,
R/U interconnects f/ motors,
pits,rock,sub, pipe modules.
Install Hp mud lines Cmt lines, Landings
and Landing handrails, Drain lines,
Berms,Spot cutting tanks,
R/U steam, air and H20 to rig
0.0 0.0
5/11/2023
09:30
5/11/2023
11:00
1.50 MIRU, MOVE RURD P Install Skate and Spool on cables 0.0 0.0
5/11/2023
11:00
5/11/2023
12:00
1.00 MIRU, MOVE RURD P Install Beaver Slide 0.0 0.0
5/11/2023
12:00
5/11/2023
18:00
6.00 MIRU, MOVE RURD P Make up 4" conductor ball valves. Make
up 2" side entry port w/ low torque
valve, Remove annular lines from BOPE
and install on surface annular. Make up
hydraulic jumper hoses to knife valve.
RKB'S- LDS=39.85, GL= 39.00, LS=
39.05. Middle of annular = 28.62. N/U
surface annular to csg head adapter,
N/U riser to top surface annular.
SIMOPS install mouse hole and cut
surface riser
install charging pump #1 Load 20 JTS.
5" HWDP/ 9 JTS. 5" DP in pipe shed .
RIG
Rig accepted @ 18:00
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 6/14/2023
Page 2/28
1C-156
Report Printed: 6/29/2023
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)
5/11/2023
18:00
5/11/2023
19:30
1.50 MIRU, MOVE RURD P Cont. working on rig acceptance
checklist, cont. t/torque lower surface
riser to annular and annular
to set head adapter, clean settling
chamber on #1 mud pump
0.0 0.0
5/11/2023
19:30
5/11/2023
21:00
1.50 MIRU, MOVE RURD P Install upper riser t/ lower riser section,
secure and ready for drilling
Install diverter extension t/ diverter
system
0.0 0.0
5/11/2023
21:00
5/12/2023
00:00
3.00 MIRU, MOVE RURD P Change out saver sub f/ xt-39 to NC 50
and remove upper and lower IBOP assy.
Take on spud mud to pits, clean suction
screens on mud pumps, check system
fluids
Ready Top Drive to Drill, Berm cellar w/
Herculite f/ proper containment. Work on
koomy
Nitro bladder system/check bottle bank
press.
0.0 0.0
5/12/2023
00:00
5/12/2023
06:00
6.00 MIRU, MOVE RURD P Install upper topdrive IBOP assy, as per
procedure.torque to 44k, Wire tie fetter
ring, install new NC 50 saver sub, Install
5" bell guides, change Top Drive
grabber dies, repair service loop wire
extrusion, continue to work on koomey
Nitrogen Bladder system. Check bottle
Bank pressure. Load and Strap 5"
HWDP in pipe shed. Change out
Roughneck dies and service
unit,Grease IBOP assy. Ready pie shed
for 10 3/4" casing, Ready rock washer
for drilling fluid. Dress shakers with
screens and function test all shakers.
Stocked pits with drilling product.
Function test alarm system
0.0 0.0
5/12/2023
06:00
5/12/2023
11:30
5.50 MIRU, MOVE RURD P Swap Dies in from 4" to 5" on back
saver slips, Bring on koomey to full
system pressure, Adjust Annular
pressure to 1100 psi, P/U subs from
beaver slide, Load BHA in pipe shed as
per MWD hand, Derrick inspection
inspect and grease all sheaves, Test
gas alarm system, P/U and install
master bushings, M/U 1 stand 5" HWDP,
Test diverter Annular close time 15 sec
Knife valve close time 9 sec. Koomey
draw down test witness by CPAI
AOGCC waved witness by Cam St.
John
Trouble shoot Totco screen in driller cab.
0.0 0.0
5/12/2023
11:30
5/12/2023
12:00
0.50 MIRU, MOVE PULD P P/U 5" HWDP F/shed and Rack in
Derrick
0.0 0.0
5/12/2023
12:00
5/12/2023
13:15
1.25 MIRU, MOVE PULD P Cont. t/ P/U 5" HWDP from shed and
rack back in derrick.
Off rig power, On high-line power
13:00hrs
0.0 0.0
5/12/2023
13:15
5/12/2023
14:15
1.00 SURFAC, DRILL SFTY P Pre-Spud Safety meeting, PJSM for
picking up surface BHA with day crew
0.0 0.0
5/12/2023
14:15
5/12/2023
15:30
1.25 SURFAC, DRILL RURD P M/U stand 5" HWDP from Derrick T/Top
drive, RIH with 5" HWDP to 72' Fill
conductor with 29bbls spud mud. Test
surface lines to 4000 psi good test.
POOH rack stand back in derrick, Blow
down top-Drive, Ready rig floor to pick
up BHA
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 6/14/2023
Page 3/28
1C-156
Report Printed: 6/29/2023
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)
5/12/2023
15:30
5/12/2023
19:30
4.00 SURFAC, DRILL BHAH P P/U surface BHA as per SLB DD, UP
and Down weight 62K
0.0 0.0
5/12/2023
19:30
5/12/2023
22:30
3.00 SURFAC, DRILL RURD P Load 5" drill pipe on short side pipe
shed strap and Talley, Load first row 10
3/4" casing #8 thru # 50in shed
0.0 0.0
5/12/2023
22:30
5/12/2023
23:00
0.50 SURFAC, DRILL SFTY P Pre Spud Meeting with Night Crew and
all hands involved
0.0 0.0
5/12/2023
23:00
5/13/2023
00:00
1.00 SURFAC, DRILL DRLG P Wash out conductor as per SLB DD and
CPAI Rep, from 0' to 148' 230 GPM, 200
PSI, 20 RPM with 1K TQ, 31% F/O 1K
WOB, RT/WT 66K
0.0 148.0
5/13/2023
00:00
5/13/2023
06:00
6.00 SURFAC, DRILL DDRL P Drill 13 ½” Surface Hole F/ 148‘ MD - T/
352‘ MD , WOB = 1, GPM = 450, PSI
ON = 660, PSI
RPM = 40, TQ ON = 2K, TQ OFF = 1K,
FLOW OUT = 40%, P/U WT = 73K, S/O
WT = 66K, RT WT =
69K,
@185' Note Losses drilling outside
conductor 60 BBLS
148.0 352.0
5/13/2023
06:00
5/13/2023
12:00
6.00 SURFAC, DRILL DDRL P Drill 13 1/2” Surface Hole F/ 352‘ MD -
T/ 734‘ MD 734‘ TVD, WOB = 2K, GPM
= 465, PSI
ON = 928, PSI OFF = 901, RPM = 40,
TQ ON = 2K, FLOW OUT = 40%, ECD
= 10.01 PPG, P/U WT
= 85K, S/O WT = 82K, RT WT = 84K,
AST= 0.89, ART = 6.11, ADT = 7.00,
Total Bit Hours = 38.35,
352.0 734.0
5/13/2023
12:00
5/13/2023
12:30
0.50 SURFAC, DRILL DDRL P Drill 13 1/2” Surface Hole F/ 734‘ MD -
T/ ‘ MD 775‘ TVD, WOB = 2K, GPM =
470, PSI ON =
997, PSI OFF = 962, RPM = 40, TQ ON
= 2K, FLOW OUT = 40%, ECD = 10.01
PPG, P/U WT = 86K,
S/O WT = 82K, RT WT = 84K,
734.0 775.0
5/13/2023
12:30
5/13/2023
13:30
1.00 SURFAC, DRILL TRIP P @775' POOH T/ 650' W/ 1 STD
5"HWDP, Rack in Derrick and Pull 1
single 5"HWDP F/ M/U JAR
STD, U/D WT.- 86K, OWFF(Static), M/U
Jar stand IN 90' M/H, M/U t/ string and
run in hole with jars stand M/U 5"HWDP
F/ Derrick and cont. drilling ahead.
775.0 650.0
5/13/2023
13:30
5/13/2023
18:00
4.50 SURFAC, DRILL DDRL P Drill 13 1/2” Surface Hole F/ 775‘ MD -
T/ 1052‘ MD 1052‘ TVD, WOB = 2K,
GPM = 465, PSI
ON = 1035, PSI OFF = 1003, RPM =
40, TQ ON = 3K, FLOW OUT = 40%,
ECD = 10.17 PPG, P/U
WT = 97K, S/O WT = 89K, RT WT =
92K,
775.0 1,052.0
5/13/2023
18:00
5/14/2023
00:00
6.00 SURFAC, DRILL DDRL P Drill 13 1/2” Surface Hole F/ 1052‘ MD -
T/1536‘ MD 1524‘ TVD, WOB = 6K,
GPM = 470, PSI
ON = 1260, PSI OFF = 1200, RPM =
40, TQ ON = 4K, FLOW OUT = 47%,
ECD = 10.42 PPG, P/U
WT = 94K, S/O WT = 99K, RT WT =
96K, AST= 2.21HRS, ART = 4.96HRS,
ADT = 7.17HRS, Total Bit Hours= 45.08,
Total Jar Hours= 45.08HRS
1,052.0 1,536.0
Rig: DOYON 142
RIG RELEASE DATE 6/14/2023
Page 4/28
1C-156
Report Printed: 6/29/2023
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)
5/14/2023
00:00
5/14/2023
06:00
6.00 SURFAC, DRILL DDRL P Drill 13 1/2” Surface Hole F/ 1536‘ MD
- T/1960‘ MD 1913‘ TVD, WOB = 4K,
GPM = 470, PSI
ON = 1250, PSI OFF = 1200, RPM =
40, TQ ON = 3K, FLOW OUT =45%,
ECD = 10.40 PPG, P/U
WT = 98K, S/O WT = 103K, RT WT
=101K TQ OFF=2K.
AST=1.02HRS, ART=2.67HRS,
ADT=3.69HRS, JARS=10.42HR,
BIT=49.21HRS
TD = 1960' @ 0600
1,536.0 1,960.0
5/14/2023
06:00
5/14/2023
06:30
0.50 SURFAC, TRIPCAS OWFF P OWFF, Obtain final survey as per SLB.,
Final torque and drag - U/D WT.- 105K,
ROT.- 106K
W/ 2K TQ@20RPM
1,960.0 1,960.0
5/14/2023
06:30
5/14/2023
07:30
1.00 SURFAC, TRIPCAS CIRC P F/ 1960' T/ 1770' Brooh, Circulate 2X
Btms up@ 470 GPM, 1109 PSI, ROT.-
101K W/ 3K TQ @ 40
RPM 3K TQ, Pump 2X NP Lcm sweeps
@ 40 BBLS Each w/ Brooh
1,960.0 1,770.0
5/14/2023
07:30
5/14/2023
12:00
4.50 SURFAC, TRIPCAS BKRM P BROOH f/ 1770‘ MD - T/ 795‘ MD, W/
GPM = 470, PSI = 1011, RPM = 40, TQ
= 2-6K. F/O = 46%,
ECD = 10.45 PPG, P/U WT = 85K, S/O
WT = 81K, RT WT = 83K Max Gas =
331
1,770.0 795.0
5/14/2023
12:00
5/14/2023
14:15
2.25 SURFAC, TRIPCAS BKRM P BROOH F/ 795‘ MD - T/ 180'‘ MD, W/
GPM = 470, PSI = 900, RPM = 40, TQ =
2-6K. F/O = 46%,
ECD = 10.6 PPG, P/U WT = 70K, S/O
WT = 72K, RT WT = 69K (Rack back
Hwdp and jars)
Pump 30 bbl nut plug drill zone BHA
balling sweep on last stand of Hwdp.
Max gas 204 units
795.0 180.0
5/14/2023
14:15
5/14/2023
14:30
0.25 SURFAC, TRIPCAS OWFF P OWFF 15 MIN, (Static) 180.0 180.0
5/14/2023
14:30
5/14/2023
17:30
3.00 SURFAC, TRIPCAS BHAH P PJSM L/D Bha f/ 180' to Surface, Box
thread on ARC tool were galled and had
trouble
breaking out. L/D ARC tool with lift sub
attached. All stabilizers in gauge. Bit
Grade 1-1-BU-A-E-IN-WT-TD
180.0 0.0
5/14/2023
17:30
5/14/2023
19:30
2.00 SURFAC, TRIPCAS CLEN P Clean and clear rig floor of BHA tools 0.0 0.0
5/14/2023
19:30
5/14/2023
20:00
0.50 SURFAC, TRIPCAS SVRG P Service and lube Top drive, ST 100,
Pipe skate and Draw Works
0.0 0.0
5/14/2023
20:00
5/14/2023
21:45
1.75 SURFAC, CASING RURD P R/U casing running equipment as per
Doyon casing Rep, Volant CRT, 350T
spiders, Elevators,
TIW install on Pump in Swedge prior to
running casing.
0.0 0.0
5/14/2023
21:45
5/14/2023
23:00
1.25 SURFAC, CASING HOSO P M/U 10 3/4" casing hanger to landing jt.
Dummy run hanger as per Vault Rep.
Drain riser and verify hanger is landed
through landing port.
0.0 0.0
5/14/2023
23:00
5/14/2023
23:30
0.50 SURFAC, CASING SFTY P PJSM Running 10 3/4" casing with al
hands involved
0.0 0.0
5/14/2023
23:30
5/15/2023
00:00
0.50 SURFAC, CASING PUTB P RIH to 167' MD M/U 10 3/4" shoe track,
Bakerlok pin ends, Fill casing check
floats(Good)
0.0 167.0
Rig: DOYON 142
RIG RELEASE DATE 6/14/2023
Page 5/28
1C-156
Report Printed: 6/29/2023
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)
5/15/2023
00:00
5/15/2023
06:30
6.50 SURFAC, CASING PUTB P Run 10 ¾ ,45.5#, l-80, hyd563 surface
casing as per tally. M/U TQ 16,200 ft/lbs.
fill every joint top off every ten,
monitoring displacement on pit # 1,
pp#1. F/167' MD, t/ 1912 ' MD.
SOW=110k. Calculated displacement,
31.68bbls. Actual displacement, 27bbls
167.0 1,912.0
5/15/2023
06:30
5/15/2023
10:15
3.75 SURFAC, CASING PUTB T @1912' R/D spider elev., P/U and M/U
hanger assy. and landing jt. t/ 10 3/4"
casing as per Vault Rep, washdown w/
0.5bpm/95psi, u/d wt.- 122k/105k,
@1937' s/o
wt. with excess wt. 30k, attempt t/ work
thru w/ staging rates f/ 0.5-7bpm
95-180psi, decide t/ check landing jt.
guide clearance/remove, check stack
alignment, drain stack and visually
inspect hanger w/ s/o, determined taking
wt. downhole, attempt t/ s/o w/ circ.
again, no progress, decide t/ r/d hanger
and landing jt., m/u jt. casing f/ working
single
1,912.0 1,912.0
5/15/2023
10:15
5/15/2023
12:00
1.75 SURFAC, CASING PUTB T L/D hanger and landing jt., p/u 10 3/4" jt
casing@40.31', m/u t/ casing string,
wash down@6bpm/187psi, u/d wt.
118/104k and tag tight spot@1930', p/u
and work
casing down increased w/ p/u and s/o,
rot. 1/4 turns t/ right periodically 3-10k
tq,
stage rate t/ 7.5bpm/210psi, s/o t/ 1934',
remain on depth @s/o loss point and
attempt t/ wash shoe bottom t/ clear
debris (hook load showed progress)
1,930.0 1,930.0
5/15/2023
12:00
5/15/2023
17:30
5.50 SURFAC, CASING PUTB T F/ 1934' t/1949' cont. t/ work casing
string u/d w/ rot. 1/4 turns t/ right
periodically 3-12k tq, pump rate@7.5
bpm/210 psi, u/d wt.- 118/103k, slowly
making incremental progress 0.3-0.8'
ea. 3-7 strokes, work casing single
down and p/u 14.64' 10 3/4" pup jt, m/u
w/ Volant CRT and cont. t/ work casing
down t/ 1960' MD
1,934.0 1,949.0
5/15/2023
17:30
5/15/2023
19:30
2.00 SURFAC, CASING PUTB T @1949' pump out casing w/ 4bpm/128
psi, l/d 14.64' pup jt., 40.31' 10 3/4"
casing working single, aluminum casing
jt. t/ pipeshed, m/u 14.64', 9.62', 5.01'
pup jts. and m/u t/surface hanger, m/u
landing jt. t/ hanger and RIH t/ set depth,
u/d 124/104k .set depth @ 1,945' MD.
1,949.0 1,945.0
5/15/2023
19:30
5/15/2023
21:45
2.25 SURFAC, CEMENT CIRC P Circulate and condition mud f/ cement
job. reciprocate pipe 5'. land hanger
periodically. 270 gpm, 100 psi, 30% f/o,
p/u= 112k, sow= 101k.
1,945.0 1,945.0
5/15/2023
21:45
5/15/2023
22:00
0.25 SURFAC, CEMENT SFTY P PJSM on cement job w/ all hands
involved.
1,945.0 1,945.0
5/15/2023
22:00
5/15/2023
23:00
1.00 SURFAC, CEMENT CMNT P R/U cementers/ cement hose t/ Volant
CRT. Blow air t/ cementers, B/D top
drive. Break circ stag back up t/
170gpm, 100psi.
1,945.0 1,945.0
5/15/2023
23:00
5/16/2023
00:00
1.00 SURFAC, CEMENT CMNT P Cement 10-3/4'' surface csg as per
Halliburton pump schedule, flood lines
5bbls h20@ 2.8bpm/109psi, pt lines
t/3500psi, pump 60bbl, 10.2ppg tuned
prime space w/ 4lb red dye w/ 3.5 bpm,
140psi, shutdown and drop bottom plug.
1,945.0 1,945.0
Rig: DOYON 142
RIG RELEASE DATE 6/14/2023
Page 6/28
1C-156
Report Printed: 6/29/2023
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)
5/16/2023
00:00
5/16/2023
02:45
2.75 SURFAC, CEMENT CMNT P Pump 381 BBLS 10.7 ppg Arcticcem
Lead cement @ 4.5 bpm 250 psi. Pump
58/ bbls 15.8 ppg Tail cement @ 3.4
bpm @270 psi. Shutdown drop top plug.
Flush lines with 20 bbls H20. Displace
with rig pumps @ 6 bpm 450 psi for
1450 strokes. Slow to 3 bpm 450 psi.
Bump plug with calculated strokes -
1567 total strokes. Initial pressure - 450
psi
final pressure - 1000 psi. Hold for 5
mins. Check floats (good). Cement in
Place @ 02:37 Hrs.
1,945.0 1,945.0
5/16/2023
02:45
5/16/2023
06:00
3.25 SURFAC, CEMENT RURD P Flush lines, clean and clear rig floor.
Drain stack. R/D Volant casing running
tool. L/D landing jt. Blow down cement
lines and mud lines.
0.0 0.0
5/16/2023
06:00
5/16/2023
12:00
6.00 SURFAC, WHDBOP NUND P Clean out under Rotary Bushings.
Remove upper riser and lower sections.
Clean and L/D beaver slide. Remove
black water line from riser and starting
head. Disconnect koomey lines from
surface annular. N/D plug ports and
install boots saver riser. N/D lower risers
form annular connection. Remove knife
valves and diverter adapter. Ready
starting head for removal, Remove
starting head as per Vault Rep. SIMOPS
clean pits, rockwasher and all services
lines at rig and to Magtec. ( Welder
repair beaver slide access door).
0.0 0.0
5/16/2023
12:00
5/16/2023
18:00
6.00 SURFAC, WHDBOP NUND P Install Wellhead seal assy. into adapter
flange. M/U threaded wellhead adapter
flange to wellhead. Orient wellhead as
per DSO verified. Test seals t/ 2000 psi
for 10 mins through housing port flange
(good test). Support diverter for
removal. Remove diverter, install wind
walls covers for cellar and rear doors.
N/U spacer spool. L/D DSA spool and
adapter flange. N/U BOPE and tighten
connections. SIMOPS cont. to clean
pits, rockwasher and make ready to drill
INTRM section, Grease choke manifold.
0.0 0.0
5/16/2023
18:00
5/17/2023
00:00
6.00 SURFAC, WHDBOP NUND P Install 13-5/8" double flange - spacer
spool needed for correct height. Tighten
all connections. Make up choke and kill
lines and install 16" bell nipple to
annular. (Welder has to make
modification to extend 16" bell nipple).
Remove Kill HCR valve - valve was
bypassing fluid internal. SIMOPS
process 5" drill pipe in pipe shed.
0.0 0.0
5/17/2023
00:00
5/17/2023
00:30
0.50 SURFAC, WHDBOP SVRG T Service Rig. Cont. to change out HCR
kill Valve. Grease Mud Cross.
0.0 0.0
5/17/2023
00:30
5/17/2023
01:30
1.00 SURFAC, WHDBOP RGRP T Cont. Change out HCR Kill valve. Cont.
to take on mud to pits. Prep pipe shed to
start picking up 5" drilll pipe.
0.0 0.0
5/17/2023
01:30
5/17/2023
04:00
2.50 SURFAC, WHDBOP PULD T Pickup and rack back 15 stands 5" drill
pipe in derrick.
0.0 0.0
5/17/2023
04:00
5/17/2023
05:30
1.50 SURFAC, WHDBOP RGRP T Install HCR kill valve and line. Install
riser.
0.0 0.0
5/17/2023
05:30
5/17/2023
08:00
2.50 SURFAC, WHDBOP BOPE P Set Test plug, R/U Testing Equipment,
Flood Lines, Shell test BOPE'S. Purge
air from system.
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 6/14/2023
Page 7/28
1C-156
Report Printed: 6/29/2023
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)
5/17/2023
08:00
5/17/2023
12:00
4.00 SURFAC, WHDBOP BOPE P BOPE test t/ 250 low 5,000 high for 5
charted min. w/ exception of manual
ooperated & super choke tested t/ 250
low & 2,000 psi for 5 charted min, w/ 7
5/8" test jt, test annular 250 low 5000
high, 7 5/8" solid body upper rams, test
choke valves 1-14, manual operated &
super choke, choke & kill manuals &
hcr's, 4" valves on kill line, 5" FOSV 5"
dart valve; (choke OTEC conn. on test
#1 and mud cross conn. on test #3
leaked @ initial 3500/5000psi high tests,
0.0 0.0
5/17/2023
12:00
5/17/2023
15:30
3.50 SURFAC, WHDBOP BOPE P Cont. Bope test t/ 250 low 5,000 high for
5 charted min. w/ exception of manual
operated & super choke tested t/ 250
low & 2,000 psi for 5 charted min, w/ 7
5/8" test jt, test annular 250 low 5000
high, 7 5/8" solid body upper rams, test
choke valves 1-14, manual operated &
super choke, choke & kill manuals &
hcr's, 4" valves on kill line, 5" fosv, 5"
dart valve, upper & lower ibop;
blind/shear rams;
Perform koomey drawdown, acc = 2975
psi. mani. = 1500 psi. acc = psi after all
functions on bottles, 10 sec for 200 psi.
build w/ 2 elec. pumps, 62 sec t/ build
full sys. pressure w/ 2 elec. & 2 air
pumps, closing times annular = 24 sec.
upper = 18 sec. blind / shears = 16 sec.
lpr = 16 sec. choke hcr = 2 sec. kill hcr =
2 sec;
Nitrogen 6 bottle avg= 1918 psi, test pvt
gain/loss and flow out alarms, test lel
and h2s alarms;
AOGCC REP BRIAN BIXBY WAIVED
WITNESS @ 15:49 HRS on 05/15/2023
0.0 0.0
5/17/2023
15:30
5/17/2023
17:00
1.50 SURFAC, WHDBOP PULD P Pull test plug, drain stack and set wear
ring as per Vault Rep. ID= 12 3/8",
Length 33". L/D 5" test joint and R/D
testing equip. B/D choke manifold and
kill line. Position f/ ready t/ drill. Clean
and clear rig floor excess tools/equip.
and ready t/ P/U interm. BHA
0.0 0.0
5/17/2023
17:00
5/17/2023
19:30
2.50 SURFAC, DRILLOUT BHAH P PJSM. P/U and M/U Interim Hole
section BHA as per SLB. SOW =67k.
0.0 0.0
5/17/2023
19:30
5/17/2023
21:00
1.50 SURFAC, DRILLOUT TRIP P RIH w/ Interm hole section BHA on 5"
drill pipe f/ derrick f/530' to 1850'.
Monitor displacement on pill pit #2.
0.0 0.0
5/17/2023
21:00
5/17/2023
21:45
0.75 SURFAC, DRILLOUT CIRC P Perform shallow hole test as per SLB.
600 GPM, 1450 psi, 45% F/O. SIMOPS
PJSM for Slip and cut drill line.
0.0 0.0
5/17/2023
21:45
5/17/2023
23:45
2.00 SURFAC, DRILLOUT SLPC P Slip and Cut drill line. Check and re-set
all limits. Circulating @ 2 bpm 30 psi, for
casing test.
0.0 0.0
5/17/2023
23:45
5/18/2023
00:00
0.25 SURFAC, DRILLOUT RURD P Rig up casing test equipment. Flood
lines. Test 10-3/4" surface casing to
3000 psi on chart.
0.0 0.0
5/18/2023
00:00
5/18/2023
01:15
1.25 SURFAC, DRILLOUT PRTS P R/U casing test equipment. Flood lines.
Test 10-3/4'' surface casing t/3000psi,
f/30 mins (charted). Stokes/bbls t/
pressure up =35 strokes/3.5 bbls. Bleed
back = 3.3 bbls.
1,850.0 1,850.0
Rig: DOYON 142
RIG RELEASE DATE 6/14/2023
Page 8/28
1C-156
Report Printed: 6/29/2023
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)
5/18/2023
01:15
5/18/2023
09:15
8.00 SURFAC, DRILLOUT COCF P Wash f/1850' t/1852'. Take weight @
1852' w/12k WOB. Drill off w/40 RPM.
Tag @ 1856'. Drill out shoetrack
adjusting parameters: GPM: 350 - 500,
PSI: 590 - 960, RPM: 40 - 60, WOB:
15k, TQ: 2 - 5k, PUW: 97k, SOW: 96k,
ROTW: 97k.
Tag shoe @ 1942'. Drill out shoe with
GPM: 500 - 700, PSI: 875 - 1619, RPM:
80 -100, WOB: 2 - 7k, ROTW: 99k, TQ:
3 - 9k, F/O: 53%
Work thru shoe 3x and cont. t/ drill rat
hole t/ 1960' with GPM: 650, PSI: 1368,
RPM: 100, TQ: 3 - 4k.
1,850.0 1,856.0
5/18/2023
09:15
5/18/2023
09:45
0.50 SURFAC, DRILLOUT DRLG P Drill 9-7/8” Intermediate hole f/ 1960‘
MD t/ 1980‘ MD, 1976‘ TVD with WOB:
3 - 6k, GPM: 650, PSI ON:1380, PSI
OFF:1330, RPM:100, TQ ON: 4k, F/O:
52%, ECD: 9.96 ppg, PUW: = 99k,
SOW: 97k, ROTW: 98k, ADT: 0.38 hrs,
TBH: 0.38 hrs, TJH: 0.80 hrs.
1,960.0 1,980.0
5/18/2023
09:45
5/18/2023
11:00
1.25 SURFAC, DRILLOUT FIT P F/1980' t/1940' circ./cond. mud sys. for
LOT test w/ rot./recipe w/650 GPM/1380
psi, ROTW: 99k w/ 80rpm 2-3k tq, F/O:
52%, ECD: 9.96ppg, Initial MW: 9.4+
ppg,Ffinal MW: 9.5+ ppg in/out. Rack
std in derrick, B/D top drive and ready t/
R/U f/ FIT test.
1,980.0 1,940.0
5/18/2023
11:00
5/18/2023
11:15
0.25 SURFAC, DRILLOUT OWFF P OWFF (static). 1,940.0 1,940.0
5/18/2023
11:15
5/18/2023
12:00
0.75 SURFAC, DRILLOUT FIT P @1940'. Perform LOT test as CPAI test
procedure, close annular andpressure
up thru drill pipe/kill line, pump 5 stks t/
210 psi, observe leak off at 180 psi,
shutdown and attempt t/ monitor o/a psi
(bled t/ o psi), decide t/ psi up via
annular t/ 210psi (same result) pumped
1 bbl for both test.
1,940.0 1,940.0
5/18/2023
12:00
5/18/2023
14:00
2.00 SURFAC, DRILLOUT FIT P @1940' Cont. Perform LOT test as CPAI
test procedure. Decide t/ spaceout f/
3.5"x6" lower rams, close rams and kill
line, Pump thru drill pipe only f/ 7stks t/
300 psi, shut-in and monitor psi loss (o/a
bled t/ 0 psi), tot. vol. pumped= .7bbls
wait-on-orders based on lop test results
t/ confirm plan forward EMW = 12.4ppg
@ 260 psi Leak off pressure.
1,940.0 1,940.0
5/18/2023
14:00
5/18/2023
14:45
0.75 SURFAC, DRILLOUT FIT P R/D Fit test tools and equipment, Blow
down test lines used, M/U std 5"drill
pipe f/ derrick t/ Top drive, pump up
Mwd survey data as per Slb Mwd w/
750gpm 1810psi, ready t/ drill ahead
and displace well t/ 9ppg FWP drilling
mud system
1,940.0 1,940.0
5/18/2023
14:45
5/18/2023
18:00
3.25 INTRM1, DRILL DDRL P Drill 9 7/8” Intermediate hole f/ 1980‘ md
- t/ 2223‘ md 2137‘ tvd, wob = 5k, gpm =
700, psi on = 1112, psi off =1102, rpm
=100, tq on = 2.8k, flow out = 43%, ecd
= 9.76ppg, p/u wt = 99k, s/o wt = 97k, rt
wt = 98k, Displace well t/ 9ppg FWP f/
9.5+ spud mud w/ drilling ahead
1,980.0 2,223.0
Rig: DOYON 142
RIG RELEASE DATE 6/14/2023
Page 9/28
1C-156
Report Printed: 6/29/2023
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)
5/18/2023
18:00
5/19/2023
00:00
6.00 INTRM1, DRILL DDRL P Drill 9 7/8” Intermediate hole f/2223 ‘ md
- t/2887‘ md, 2617‘ Tvd, Wob =8 gpm
=745 , psi on =1287, psi off =1280, rpm
=120, tq on = 3k, flow out = 53%, Ecd
=10.24 ppg, p/u wt =108k, s/o wt =
104k, rt wt = 103k, adt =6.63hrs,
bit=7.01hrs, jars=17.43hrs
2,223.0 2,887.0
5/19/2023
00:00
5/19/2023
06:00
6.00 INTRM1, DRILL DDRL P Drill 9-7/8” Intermediate hole F/ 2887‘
MD - T/ 3680‘ MD, 3060‘ TVD, WOB =
5K, GPM = 750, PSI = 1640, RPM =
160, TQ on = 5K, Flow out = 55%, ECD
= 10.83 PPG, P/U WT = 116K, S/O WT
= 106K, RT WT = 106K.
Pumped weight sweep at 3262' saw no
increase in return cuttings.
Managing directional control with Rop
up 500 fph with intervals with 0 weight
on bit.
2,887.0 3,680.0
5/19/2023
06:00
5/19/2023
09:00
3.00 INTRM1, DRILL DDRL P Drill 9-7/8” Intermediate hole F/ 3680‘
MD - T/ 4021‘ MD, 3253‘ TVD, WOB =
5K, GPM = 750, PSI = 1640, RPM =
160, TQ on = 5K, Flow out = 55%, ECD
= 10.83 PPG, P/U WT = 116K, S/O WT
= 106K, RT WT = 106K.
Pumped high Vis sweep every 5 stands
seen 30% increase in return cuttings.
Observe intermittent 2" to 4" clay
paddies over shakers through out
interval.
3,680.0 4,021.0
5/19/2023
09:00
5/19/2023
09:30
0.50 INTRM1, DRILL SVRG P Rig Service - add oil to hydraulic,
Grease wash pipe, Grease rotating link
assy.
4,021.0 4,021.0
5/19/2023
09:30
5/19/2023
09:45
0.25 INTRM1, DRILL SVRG P Inspect top-drive leak (Hardline for
hydraulics leaking). Replace hose line
with HP hose.
4,021.0 4,021.0
5/19/2023
09:45
5/19/2023
12:00
2.25 INTRM1, DRILL DDRL P Drill 9-7/8” Intermediate hole F/ 4021‘
MD - T/ 4207‘ MD, 3253‘ TVD, WOB =
9K, GPM = 750, PSI = 1651, RPM =
160, TQ on = 4K, Flow out = 56%, ECD
= 10.49 PPG, P/U WT = 114K, S/O WT
= 105K, RT WT = 106K.
Pumped high Vis sweep every 5 stands
- seen 20% increase in return cuttings.
Total tour losses - 120 bbls.
4,021.0 4,207.0
5/19/2023
12:00
5/19/2023
18:00
6.00 INTRM1, DRILL DDRL P Drill 9-7/8” Intermediate hole F/ 4207‘
MD - T/ 4776‘ MD, 3381‘ TVD, WOB =
11K, GPM = 750, PSI = 1797, RPM =
160, TQ on = 5K, Flow out = 47%, ECD
= 10.79 PPG, P/U WT = 119K, S/O WT
= 104K, RT WT = 108K.
Pumped high Vis sweep every 5 stands
- seen 30% increase in return cuttings.
4,207.0 4,776.0
Rig: DOYON 142
RIG RELEASE DATE 6/14/2023
Page 10/28
1C-156
Report Printed: 6/29/2023
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)
5/19/2023
18:00
5/20/2023
00:00
6.00 INTRM1, DRILL DDRL P Drill 9 -7/8” Intermediate hole F/ 4776‘
MD - T/ 5429‘ MD 3452‘ TVD, WOB =
12K, GPM = 750, PSI = 1818, RPM
=160, TQ on = 6K, Flow out = 47%,
ECD = 10.791PPG, P/U WT = 122K
S/O WT = 102K, RT WT = 108k, ADT =
15.85, Total Bit hrs =22.86, Jars Hrs =
33.28.
@ 4497' Pump 30 bbl hi-vis sweep with
2 ppb Nut Plug, 20% increase in
cuttings with baseball size clay balls
coming across shakers, 30 bbls early
@ 5060' Pump 30 bbl hi-vis sweep with
2 ppb Nut Plug, 10% increase in
cuttings with large softball sized
cavings, 40-50 bbls early
4,776.0 5,429.0
5/20/2023
00:00
5/20/2023
06:00
6.00 INTRM1, DRILL DDRL P Drill 9-7/8” Intermediate hole F/ 5429‘
MD - T/ 5955‘ MD, 3499‘ TVD, WOB =
12K, GPM = 750, PSI = 1920, RPM =
150, TQ on = 6K, Flow out = 47%, ECD
= 10.81 PPG, P/U WT = 124K, S/O WT
= 104K, RT WT = 110k, ADT = 15.85,
Total Bit hrs =22.86, Jars Hrs = 33.28.
@ 5637' Pump 30 bbl hi-vis sweep with
2 ppb Nut Plug, 20% increase in
cuttings with large softball sized
cavings, 40-50 bbls early.
5,429.0 5,955.0
5/20/2023
06:00
5/20/2023
12:00
6.00 INTRM1, DRILL DDRL P Drill 9-7/8” Intermediate hole F/ 5955‘
MD - T/ 6522‘ MD, 3609‘ TVD, WOB =
12K, GPM = 750, PSI = 2000, RPM =
150, TQ on = 7K, Flow out = 47%, ECD
= 10.90 PPG, P/U WT = 129K, S/O WT
= 108K, RT WT = 117k, ADT = 8.84,
Total Bit hrs =31.7, Jars Hrs = 42.12.
@ 6115' Pump 30 bbl hi-vis sweep with
2 ppb Nut Plug, 20% increase in
cuttings with large softball sized
caving's, 50 bbls early
@ 6265' Pump 30 bbl hi-vis sweep with
2 ppb Nut Plug, 10% increase in
cuttings, 60 bbls early.
5,955.0 6,522.0
5/20/2023
12:00
5/20/2023
18:00
6.00 INTRM1, DRILL DDRL P Drill 9-7/8” Intermediate hole F/ 6522‘
MD - T/ 7220‘ MD, 3677‘ TVD, WOB =
11.7K, GPM = 725, PSI = 1950, RPM =
150, TQ on = 7K, Flow out = 47%, ECD
= 10.79 PPG, P/U WT = 134K, S/O WT
= 105K, RT WT = 1114k,
@ 6759' Pump 30 bbl 11 ppg wt'd
sweep, 10-15% increase in small cutting
to med cuttings with some clay balls, 50-
60 bbls early.
6,522.0 7,220.0
Rig: DOYON 142
RIG RELEASE DATE 6/14/2023
Page 11/28
1C-156
Report Printed: 6/29/2023
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)
5/20/2023
18:00
5/21/2023
00:00
6.00 INTRM1, DRILL DDRL P Drill 9-7/8” Intermediate hole F/ 7220‘
MD - T/ 7647‘ MD, 3784‘ TVD, WOB =
13K, GPM = 725, PSI = 1950, RPM =
150, TQ on = 7K, Flow out = 47%, ECD
= 11.04 PPG, P/U WT = 136K, S/O WT
= 108K, RT WT = 116k, ADT = 8.77,
Total Bit hrs =40.47, Jars Hrs = 50.59.
@ 7359' Pump 30 bbl 11.0 ppg
weighted sweep. Did not see an
increase in cuttings.
7,220.0 7,647.0
5/21/2023
00:00
5/21/2023
06:00
6.00 INTRM1, DRILL DDRL P Drill 9-7/8” Intermediate hole F/ 7647‘
MD - T/ 8088‘ MD, 3857‘ TVD, WOB =
17.1K, GPM = 725, PSI = 2121, RPM =
150, TQ on = 8.9K, Flow out = 46%,
ECD = 11.10 PPG, P/U WT = 136K,
S/O WT = 108K, RT WT = 116k, ADT =
4.85, Total Bit hrs =45.32, Jars Hrs =
55.74.
7,647.0 8,088.0
5/21/2023
06:00
5/21/2023
12:00
6.00 INTRM1, DRILL DDRL P Drill 9-7/8” Intermediate hole F/ 8088‘
MD - T/ 8549‘ MD, 3910‘ TVD, WOB =
10K, GPM = 725, PSI = 1950, RPM =
150, TQ on = 7K, Flow out = 47%, ECD
= 11.0 PPG, P/U WT = 137K, S/O WT =
105K, RT WT = 118k, ADT = 4.85, Total
Bit hrs =49.31, Jars Hrs = 59.73.
8,088.0 8,549.0
5/21/2023
12:00
5/21/2023
18:00
6.00 INTRM1, DRILL DDRL P Drill 9-7/8” Intermediate hole F/ 8549‘
MD - T/ 8784‘ MD, 3930‘ TVD, WOB =
5K, GPM = 650, PSI = 1815, RPM = 80,
TQ on = 9K, Flow out = 47%, ECD =
10.69 PPG, P/U WT = 137K, S/O WT =
105K, RT WT = 118k, ADT = 3.83, Total
Bit hrs =52.69, Jars Hrs = 63.11.
8,549.0 8,784.0
Rig: DOYON 142
RIG RELEASE DATE 6/14/2023
Page 12/28
1C-156
Report Printed: 6/29/2023
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)
5/21/2023
18:00
5/22/2023
00:00
6.00 INTRM1, DRILL DDRL P Drill 9-7/8” Intermediate hole F/ 8784‘
MD - T/ 8829‘ MD, 3934‘ TVD, WOB =
5K, GPM = 650, PSI = 1786, RPM = 80,
TQ on = 9K, Flow out = 43%, ECD =
10.69 PPG, P/U WT = 137K, S/O WT =
105K, RT WT = 118k, ADT = 5.84, Total
Bit hrs =58.53, Jars Hrs = 68.95.
@ 8180' Pump 30 bbl 11.0 ppg
weighted sweep, 10% increase in small
to med cuttings with some clay
balls/patties 65 bbls early
8,784.0 8,829.0
5/22/2023
00:00
5/22/2023
04:00
4.00 INTRM1, DRILL DDRL P Drill 9-7/8” Intermediate hole F/ 8829‘
MD - T/ 8885‘ MD, 3930‘ TVD, WOB =
15K, GPM = 750, PSI = 2260, RPM =
140, TQ on = 9K, Flow out = 46%, ECD
= 11.05 PPG, P/U WT = 137K, S/O WT
= 105K, RT WT = 118k.
8,829.0 8,885.0
5/22/2023
04:00
5/22/2023
05:00
1.00 INTRM1, DRILL CIRC P Circulate, Rotate and Recipicate F/8885'
MD to 8833' MD, GPM = 750, PSI =
2260, RPM = 140, TQ on = 9K, Flow out
= 46%, ECD = 11.05 PPG, P/U WT =
137K, S/O WT = 105K, RT WT = 118k.
8,885.0 8,883.0
5/22/2023
05:00
5/22/2023
06:00
1.00 INTRM1, DRILL DDRL P Drill 9-7/8” Intermediate hole F/ 8883‘
MD - T/ 8889‘ MD, 3930‘ TVD, WOB =
15K, GPM = 750, PSI = 2260, RPM =
140, TQ on = 9K, Flow out = 46%, ECD
= 11.05 PPG, P/U WT = 137K, S/O WT
= 105K, RT WT = 118k, ADT = 3.01,
Total Bit Hrs = 61.54, Total Jar Hrs
=71.96.
8,883.0 8,889.0
5/22/2023
06:00
5/22/2023
12:00
6.00 INTRM1, DRILL DDRL P Drill 9-7/8” Intermediate hole F/ 8889‘
MD - T/ 8894‘ MD, 3930‘ TVD, WOB =
15K, GPM = 750, PSI = 2260, RPM =
140, TQ on = 9K, Flow out = 46%, ECD
= 11.05 PPG, P/U WT = 137K, S/O WT
= 105K, RT WT = 118k, ADT = 3.01,
Total Bit Hrs = 61.54, Total Jar Hrs
=71.96.
8,889.0 8,894.0
5/22/2023
12:00
5/22/2023
18:00
6.00 INTRM1, DRILL DDRL P Drill 9-7/8” Intermediate hole F/ 8894‘
MD - T/ 8900‘ MD, 3930‘ TVD, WOB =
5K, GPM = 750, PSI = 2280, RPM =
140, TQ on = 8K, Flow out = 47%, ECD
= 10.92 PPG, P/U WT = 137K, S/O WT
= 105K, RT WT = 118k, ADT = 5.86,
Total Bit Hrs = 71.59, Total Jar Hrs =
82.01.
8,894.0 8,900.0
5/22/2023
18:00
5/22/2023
18:30
0.50 INTRM1, DRILL OWFF T @ 8897' MD 3930' TVD. Obtain SPR's.
Obtain Final survey. (OWFF well static).
Prep to BROOH.
Note: BROOH due to Directional BHA
not about to obtain drop rates or turn
rates.
8,897.0 8,897.0
Rig: DOYON 142
RIG RELEASE DATE 6/14/2023
Page 13/28
1C-156
Report Printed: 6/29/2023
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)
5/22/2023
18:30
5/23/2023
00:00
5.50 INTRM1, DRILL BKRM T BROOH F/ 8897' MD to 7608' MD,
GPM = 750, PSI = 2280, RPM = 140,
TQ on = 8K, Flow out = 47%, ECD =
11.2 PPG, P/U WT = 107K, S/O WT =
111K, RT WT = 111k.
Note: BROOH due to Directional BHA
not about to obtain drop rates or turn
rates.
8,897.0 7,608.0
5/23/2023
00:00
5/23/2023
06:00
6.00 INTRM1, DRILL BKRM T BROOH F/ 7608' MD to 6264' MD,
GPM = 700, PSI = 1776, RPM = 140,
TQ on = 5K, Flow out = 46%, ECD =
10.93 PPG, P/U WT = 104K, S/O WT =
108K.
7,608.0 6,264.0
5/23/2023
06:00
5/23/2023
12:00
6.00 INTRM1, DRILL BKRM T BROOH F/ 6264' MD to 4020' MD,
GPM = 700, PSI = 1530, RPM = 140,
TQ on = 3.5K, Flow out = 46%, ECD =
10.75 PPG, P/U WT = 100K.
6,264.0 4,020.0
5/23/2023
12:00
5/23/2023
18:00
6.00 INTRM1, DRILL BKRM T BROOH F/ 4020' MD to 2700' MD,
GPM = 700, PSI = 1340, RPM = 140,
TQ on = 3.5K, Flow out = 46%, ECD =
9.96 PPG, P/U WT = 96K.
4,020.0 2,700.0
5/23/2023
18:00
5/24/2023
00:00
6.00 INTRM1, DRILL BKRM T BROOH F/ 2700 MD to 2268' MD,
GPM = 700, PSI = 970, RPM = 140, TQ
on = 8K, Flow out = 44%, ECD = 9.96
PPG, P/U WT = 96K, @ 2397' MD.
Hole packed off and ECD increased to
11.0 ppg. Decreased speed and pump
pressure. S/O to 2420' MD. Pump 30
bbls LCM sweep. When sweep reached
pack off, hole started to unload cuttings
of all different sizes and volumes.
Started increasing GPM, staging to 700
GPM, hole was still unloading. Pump
2nd 30 bbls LCM sweep and continue
BROOH at slow rate to allow hole to
clean up.
2,700.0 2,268.0
5/24/2023
00:00
5/24/2023
03:00
3.00 INTRM1, DRILL BKRM T BROOH F/ 2268' MD to 1939' MD,
GPM = 700, PSI = 970, RPM = 140, TQ
on = 8K, Flow out = 44%, ECD = 9.96
PPG, P/U WT = 93K.
2,268.0 1,939.0
5/24/2023
03:00
5/24/2023
03:45
0.75 INTRM1, DRILL CIRC T @ 1939' MD pump high vis sweep GPM
= 700, PSI = 970, RPM = 140, TQ on =
8K, Flow out = 44%, ECD = 9.96 PPG,
P/U WT = 93K. Pump additional 2x B/U
to ensure hole is clean.
1,939.0 1,939.0
5/24/2023
03:45
5/24/2023
05:15
1.50 INTRM1, DRILL TRIP T TOOH on elevators F/1939' MD to 530'
MD, W/ 5" Drill Pipe, Racking drill pipe
back in derrick. P/U WT= 72K. Monitor
displacement at trip tanks.
1,939.0 530.0
5/24/2023
05:15
5/24/2023
05:30
0.25 INTRM1, DRILL OWFF T OWFF prior to L/D BHA. 530.0 530.0
5/24/2023
05:30
5/24/2023
07:30
2.00 INTRM1, DRILL BHAH T TOOH F/ 530' MD to surface
w/directional BHA, L/D BHA as per DD.
Monitoring Displacement at trip tanks.
530.0 0.0
5/24/2023
07:30
5/24/2023
08:45
1.25 INTRM1, DRILL CLEN T Clean and Clear rig floor. Mobilize new
directional tools to rig floor.
0.0 0.0
5/24/2023
08:45
5/24/2023
09:15
0.50 INTRM1, DRILL SVRG T Rig service, Service Top-drive, Draw
Works and pipe skate.
0.0 0.0
5/24/2023
09:15
5/24/2023
11:15
2.00 INTRM1, DRILL BHAH T M/U 9-7/8" BHA # 3 as per SLB DD. 0.0 519.0
5/24/2023
11:15
5/24/2023
12:00
0.75 INTRM1, DRILL TRIP T RIH T/ 1940' MD W/ 5" drill pipe out of
derrick. Monitoring displacement on 1-5
pits. Fill pipe/obtain survey every 15
stands. S/O = 92K.
519.0 1,940.0
Rig: DOYON 142
RIG RELEASE DATE 6/14/2023
Page 14/28
1C-156
Report Printed: 6/29/2023
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)
5/24/2023
12:00
5/24/2023
12:30
0.50 INTRM1, DRILL SRVY T Shallow hole test directional tools @
GPM = 500, PSI = 750, F/O = 44%.
1,940.0 1,940.0
5/24/2023
12:30
5/24/2023
18:30
6.00 INTRM1, DRILL TRIP T RIH F/ 1940' MD T/ 8164' MD W/ 5" Drill
pipe out derrick. Monitoring
Displacement on pits 1-5. Fill pipe and
obtain survey every 15 stands. S/O =
103K.
1,940.0 8,164.0
5/24/2023
18:30
5/24/2023
20:30
2.00 INTRM1, DRILL SRVY T @ 8164' MD. Kelly up, Send downlink
per DD or orient directional tools, MAD
pass F/ 8164' MD to 8351' MD, GPM =
700, RPM = 120, PSI = 1760, F/O =
47%, ECD = 10.23, TQ = 8K S/O, RT
WT = 119K.
8,164.0 8,351.0
5/24/2023
20:30
5/24/2023
21:00
0.50 INTRM1, DRILL TRIP T TIH F/ 8351' MD T/ 8828' MD W/ 5" Drill
pipe out derrick. S/O = 100K. Monitor
displacement pits 1-5.
8,351.0 8,828.0
5/24/2023
21:00
5/24/2023
21:30
0.50 INTRM1, DRILL REAM T @ 8828' MD Kelly up and Wash/Ream
T/ 8900' @ GPM = 700, RPM = 120,
PSI = 1760, F/O = 47%, ECD = 10.23,
TQ = 8K S/O, RT WT = 119K.
8,828.0 8,900.0
5/24/2023
21:30
5/25/2023
00:00
2.50 INTRM1, DRILL DDRL P Drill 9-7/8” Intermediate hole F/ 8900‘
MD - T/ 8968‘ MD, 3930‘ TVD, WOB =
7K, GPM = 700, PSI = 1813, RPM =
140, TQ on = 10K, Flow out = 45%,
ECD = 10.24 PPG, P/U WT = 128K,
S/O WT = 105K, RT WT = 111k, ADT =
2.26, Total Bit Hrs = 2.26, Total Jar Hrs =
84.27.
8,900.0 8,968.0
5/25/2023
00:00
5/25/2023
06:00
6.00 INTRM1, DRILL DDRL P Drill 9-7/8” Intermediate hole F/ 8968‘
MD - T/ 9479‘ MD, 3968‘ TVD, WOB =
10K, GPM = 700, PSI = 1928, RPM =
140, TQ on = 9K, Flow out = 45%, ECD
= 10.45 PPG, P/U WT = 142K, S/O WT
= 106K, RT WT = 120k, ADT = 4.74,
Total Bit Hrs = 7, Total Jar Hrs = 89.01.
8,968.0 9,479.0
5/25/2023
06:00
5/25/2023
12:00
6.00 INTRM1, DRILL DDRL P Drill 9-7/8” Intermediate hole F/9479 ‘
MD - T/ 9666‘ MD, 3969‘ TVD, WOB =
14K, GPM = 675, PSI = 1920, RPM =
100, TQ on = 10K, Flow out = 44%,
ECD = 10.57 PPG, P/U WT = 142K,
S/O WT = 106K, RT WT = 116k, ADT =
3.05, Total Bit Hrs = 10.05, Total Jar Hrs
= 92.06.
9,479.0 9,666.0
5/25/2023
12:00
5/25/2023
14:45
2.75 INTRM1, DRILL DDRL P Drill 9-7/8” Intermediate hole F/ 9666‘
MD - T/ 9777‘ MD, 3969‘ TVD, WOB =
7K, GPM = 675, PSI = 1920, RPM =
100, TQ on = 9K, Flow out = 44%, ECD
= 10.68 PPG, P/U WT = 140K, S/O WT
= 106K, RT WT = 116k, ADT = 2.45,
Total Bit Hrs = 12.5, Total Jar Hrs =
94.51.
9,666.0 9,777.0
5/25/2023
14:45
5/25/2023
15:30
0.75 INTRM1, TRIPCAS CIRC P @ TD 9777' MD. Take final survey. T&D.
Downlink directional tools to neutral
position. Take SPR's.
9,777.0 9,777.0
5/25/2023
15:30
5/25/2023
16:45
1.25 INTRM1, TRIPCAS BKRM P BROOH, Circulating 2x B/U racking
stand back on each B/U, F/ 9777' MD T/
9580' MD. GPM = 700, PSI = 1670,
ECD = 10.70 PPG, RPM = 100, TQ =
8K.
9,777.0 9,580.0
5/25/2023
16:45
5/25/2023
18:00
1.25 INTRM1, TRIPCAS BKRM P BROOH F/9580' MD T/ 9200' MD
Laying down 5" drill via mouse hole and
Monitoring Displacement at Pits 1-5.
GPM = 700, PSI = 1670, ECD = 10.63
PPG, RPM = 100, TQ = 8K.
9,580.0 9,200.0
Rig: DOYON 142
RIG RELEASE DATE 6/14/2023
Page 15/28
1C-156
Report Printed: 6/29/2023
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)
5/25/2023
18:00
5/26/2023
00:00
6.00 INTRM1, TRIPCAS BKRM P BROOH F/9200' MD T/ 7581' MD
Laying down 5" drill via mouse hole and
Monitoring Displacement at Pits 1-5.
GPM = 700, PSI = 1670, ECD = 10.32
PPG, RPM = 100, TQ = 6K.
9,200.0 7,581.0
5/26/2023
00:00
5/26/2023
06:00
6.00 INTRM1, TRIPCAS BKRM P BROOH F/7581' MD T/ 5994' MD
Laying down 5" drill via mouse hole and
Monitoring Displacement at Pits 1-5.
GPM = 675, PSI = 1491, ECD = 10.70
PPG, RPM = 100, TQ = 5K. WT = 106K.
7,581.0 5,994.0
5/26/2023
06:00
5/26/2023
12:00
6.00 INTRM1, TRIPCAS BKRM P BROOH F/5994' MD T/ 4200' MD
Laying down 5" drill via mouse hole and
Monitoring Displacement at Pits 1-5.
GPM = 675, PSI = 1310, ECD = 10.02
PPG, RPM = 100, TQ = 6K. WT = 107K.
5,994.0 4,200.0
5/26/2023
12:00
5/26/2023
19:15
7.25 INTRM1, TRIPCAS BKRM P BROOH F/4200' MD T/ 2022' MD
Laying down 5" drill via mouse hole and
Monitoring Displacement at Pits 1-5.
GPM = 675, PSI = 1020, ECD = 11.0
PPG, RPM = 100, TQ = 6K. WT = 93K.
4,200.0 2,022.0
5/26/2023
19:15
5/26/2023
19:30
0.25 INTRM1, TRIPCAS PMPO P Pump out hole F/2022' MD T/ 1934' MD.
GPM = 675, PSI = 1020, ECD = 11.0
PPG, RPM = 100, TQ = 6K. WT = 93K.
While pulling into shoe no over pull was
observed.
2,022.0 1,934.0
5/26/2023
19:30
5/26/2023
22:15
2.75 INTRM1, TRIPCAS CIRC P Pump 30 BBLS of 9.4 PPG LCM
weighted sweep, Working pipe and
rotating slow in casing. GPM = 675, PSI
= 1020, ECD = 11.0 PPG, RPM = 100,
TQ = 6K. P/U= 93K, S/O=99K, 30%
increase in small cuttings with sweeps
at surface.
1,934.0 1,934.0
5/26/2023
22:15
5/26/2023
23:00
0.75 INTRM1, TRIPCAS OWFF P Break out Top-Drive, Blow down Top-
Drive. OWFF Monitor well (Well Static).
1,934.0 1,934.0
5/26/2023
23:00
5/27/2023
00:00
1.00 INTRM1, TRIPCAS TRIP P POOH on elevators From 1934' MD to
1300' P/U = 95K Monitoring
displacement at pits 1-5.
1,934.0 1,300.0
5/27/2023
00:00
5/27/2023
01:00
1.00 INTRM1, TRIPCAS TRIP P Cont. POOH on Elevators F/1300' MD
T/5198' MD Laying down 5" drill pipe to
pipe shed, P/U = 75K.
1,300.0 519.0
5/27/2023
01:00
5/27/2023
01:15
0.25 INTRM1, TRIPCAS OWFF P PJSM. L/D BHA OWFF/15 min well
static.
519.0 519.0
5/27/2023
01:15
5/27/2023
04:30
3.25 INTRM1, TRIPCAS BHAH P Rack back one stand HWDP L/D jars
replace with HWDP single rack in
derrick. L/D remaining directional tools
as per SLB DD, Attempted several times
to break out periscope and exceed tool
connection - not able to due to galled
threads. L/D tools as one piece W/ bit
attached.
519.0 0.0
5/27/2023
04:30
5/27/2023
05:30
1.00 INTRM1, TRIPCAS CLEN P Clean and Clear rig floor of BHA tools
and handling equipment.
0.0 0.0
5/27/2023
05:30
5/27/2023
06:00
0.50 INTRM1, CASING WWSP P Drain stack, Rig up and Pull Wear
bushing as per Vault Rep.
0.0 0.0
5/27/2023
06:00
5/27/2023
08:45
2.75 INTRM1, CASING RURD P P/U and R/U Volant and 7-5/8" casing
handling equipment as per Doyon
casing Rep.
0.0 0.0
5/27/2023
08:45
5/27/2023
09:00
0.25 INTRM1, CASING WWSP P Perform 7-5/8" hanger dummy run as
per Vault Rep. (Good Run).
0.0 0.0
5/27/2023
09:00
5/27/2023
09:30
0.50 INTRM1, CASING SFTY P Hold PJSM on running 7-5/8" 29.7# Hyd
563 casing.
0.0 0.0
5/27/2023
09:30
5/27/2023
11:00
1.50 INTRM1, CASING PUTB P M/U Shoe and Float assy as per Doyon
casing Rep. Baker Lok Joints 1-4.
Check floats. Witness By CPAI Rep.
0.0 170.0
Rig: DOYON 142
RIG RELEASE DATE 6/14/2023
Page 16/28
1C-156
Report Printed: 6/29/2023
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)
5/27/2023
11:00
5/27/2023
12:00
1.00 INTRM1, CASING PUTB P RIH F/170' MD T/ 456' MD W/ 7-5/8"
29.7# 563 Hyd casing. S/O = 60K.
Monitoring displacement at Pit1. Filling
Pipe Via Volant tool.
170.0 456.0
5/27/2023
12:00
5/27/2023
15:45
3.75 INTRM1, CASING PUTB P RIH F/456' MD T/ 1921' MD W/ 7-5/8"
29.7# 563 Hyd casing. S/O = 94K.
Monitoring displacement at Pit1. Filling
Pipe Via Volant tool.
456.0 1,921.0
5/27/2023
15:45
5/27/2023
16:30
0.75 INTRM1, CASING CIRC P Circulate 1 BU at surfce shoe staging up
pumps T/ BPM = 6, PSI = 138, F/O =
38, P/U = 95K, S/O = 94K.
1,921.0 1,921.0
5/27/2023
16:30
5/27/2023
18:00
1.50 INTRM1, CASING PUTB P RIH F/1921' MD T/ 2721' MD W/ 7-5/8"
29.7# 563 Hyd casing. S/O = 105K.
Monitoring displacement at Pit1. Filling
Pipe Via Volant tool.
1,921.0 2,721.0
5/27/2023
18:00
5/28/2023
00:00
6.00 INTRM1, CASING PUTB P RIH F/2721' MD T/ 5655' MD W/ 7-5/8"
29.7# 563 Hyd casing. S/O = 105K.
Monitoring displacement at Pit1. Filling
Pipe Via Volant tool.
2,721.0 5,655.0
5/28/2023
00:00
5/28/2023
06:00
6.00 INTRM1, CASING PUTB P RIH F/5655' MD T/ 8628' MD W/ 7-5/8"
29.7# 563 Hyd casing. S/O = 95K.
Monitoring displacement at Pit1. Filling
Pipe Via Volant tool. Breaking
Circulation each time we fill up pipe @
6988' MD and 8219' MD.
5,655.0 8,628.0
5/28/2023
06:00
5/28/2023
08:15
2.25 INTRM1, CASING PUTB P RIH F/8628' MD T/ 9650' MD W/ 7-5/8"
29.7# 563 Hyd casing. S/O = 93K.
Monitoring displacement at Pit1. Filling
Pipe Via Volant tool. Breaking
Circulation each time we fill up pipe @
9650' MD.
8,628.0 9,650.0
5/28/2023
08:15
5/28/2023
09:15
1.00 INTRM1, CASING WASH P Wash down F/ 9650' MD to 9728' MD,
Staging pumps up on the fly. BPM=1
PSI=364, BPM=1.5, PSI=400, BPM=2
PSI=433, F/O=20%, S/O=93K .
9,650.0 9,728.0
5/28/2023
09:15
5/28/2023
09:30
0.25 INTRM1, CASING PULD P Make up 7-5/8" hanger, Pick up land
joint as Vault Rep.
9,728.0 9,728.0
5/28/2023
09:30
5/28/2023
10:00
0.50 INTRM1, CASING WASH P Wash Down 7-5/8" hanger F/ 9827' MD
T/ 9772' MD. BPM=2, PSI=413,
F/O=19%, P/U=162K, S/O=88K.
9,728.0 9,772.0
5/28/2023
10:00
5/28/2023
12:00
2.00 INTRM1, CEMENT CIRC P Circulate and Recip F/ 9772' MD T/
9756' MD, Staging up rate, BPM=2.5
PSI=419, BPM=3 PSI=424, BPM=3.5
PSI=441, BPM=3.5 PSI=447, BPM=4
PSI=441, BPM=4.5 PSI=421, BPM=5
PSI=435, BPM=5.5 PSI=435, F/O 23%,
P/U=160, S/O 100K.
9,772.0 9,756.0
5/28/2023
12:00
5/28/2023
12:30
0.50 INTRM1, CEMENT RURD P Land 7-5/8" hanger @ 9772'. Shut
down. Blow down top-drive, R/U
cementer to Volant tool.
9,756.0 9,772.0
5/28/2023
12:30
5/28/2023
13:00
0.50 INTRM1, CEMENT CIRC P Circulate and Recip F/ 9770' MD T/
9756' MD BPM =7, PSI=576, F/O=27%,
P/U=152K, S/O=100K. Total Pumped
8754 stks. Hold PJSM for Cement job.
9,770.0 9,756.0
Rig: DOYON 142
RIG RELEASE DATE 6/14/2023
Page 17/28
1C-156
Report Printed: 6/29/2023
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)
5/28/2023
13:00
5/28/2023
17:15
4.25 INTRM1, CEMENT CMNT P Perform Cement job F/ 7-5/8" INT
casing as per Halliburton. Flood Lines
W/ 5 bbls H20 290 PSI, Pressure test
lines 3500 PSI, Drop 1st plug, Pump 60
bbls 10.5 ppg Primed tunned spaces @
4 bpm 404 psi. Drop 2nd plug Pump 241
bbls 14 ppg Lead cement W/ BMII @ 4
bpm 400 psi, Mix and Pump 55 bbls
15.3 ppg tail cement without BMII @ 4
bpm 115 psi, Drop top plug, Pump 10
bbls H20, Line up rig pumps to displace
with 399 bbls 9.4 ppg mud @ 7 bpm 940
psi @ 1300 strokes, Slow rate to 5 bpm
970 psi @ 400 strokes, Slow rate to 3
bpm 940 psi, Bump plug @ 4337
strokes, Int. pressure 970psi, Bump with
1500 psi. Hold floats for 5 min. Bleed off
- floats held. CIP @ 17:35 hrs.
9,772.0 9,772.0
5/28/2023
17:15
5/28/2023
18:45
1.50 INTRM1, WHDBOP RURD P Rig down cementer's and Doyon casing
equipment remove from rig floor.
9,772.0 9,772.0
5/28/2023
18:45
5/28/2023
19:45
1.00 INTRM1, WHDBOP WWSP P Rig up and set packoff as per Vault
Rep.Test packoff 5000 psi for 10 min
witness by CPAI Rep.
9,772.0 9,772.0
5/28/2023
19:45
5/29/2023
00:00
4.25 INTRM1, WHDBOP RURD P Change out saver sub F/ NC-50 to XT-
39, Change out iron rough neck dies to
4" pipe, Change out upper Rams from
solid 7-5/8" casing rams to 3-1/2" x 6"
VBR's. Load 4.5" tubing in shed and
process.
9,772.0 9,772.0
5/29/2023
00:00
5/29/2023
01:00
1.00 INTRM1, WHDBOP RURD P Install 5" elevators, Rig up, Bring
Exceed tool to rig floor and break bit and
remove bit, L/D exceed tool
0.0 0.0
5/29/2023
01:00
5/29/2023
02:00
1.00 INTRM1, WHDBOP RURD P R/U all test BOP equipment 0.0 0.0
5/29/2023
02:00
5/29/2023
03:00
1.00 INTRM1, WHDBOP BOPE P Purge all air from lines, Flood lines and
equipment, Shell test BOP
0.0 0.0
5/29/2023
03:00
5/29/2023
08:00
5.00 INTRM1, WHDBOP BOPE P Bope test t/ 250 low 3500 high for 5
charted min. w/ exception of manual
operated & super choke tested t/ 250
low & 2,000 psi for 5 charted min, w/ 4"
and 4.5" test jts, test annular 250 low
3500 high, 3.5" x 6" VBR's upper rams,
test choke valves 1-15, manual
operated & super choke, choke & kill
manuals & hcr's, 4" valves on kill line, 2x
4" fosv, 4" dart valve, upper & lower
ibop; blind/shear rams;
Perform koomey drawdown, Acc = 3000
psi. Manifold. = 1560 psi. Acc = psi after
all functions on bottles, 8 sec for 200
psi. build w/ 2 electric. pumps, 65 sec t/
build full sys. pressure w/ 2 electric. & 2
air pumps, closing times annular = 11
sec. upper = 6 sec. blind / shears = 6
sec. lpr = 6 sec. choke hcr = 2 sec. kill
hcr = 2 sec;
Nitrogen 6 bottle avg= 1975 psi, test pvt
gain/loss and flow out alarms, test lel
and h2s alarms;
AOGCC REP Adam Earl waived
witness @ 19.12 HRS on 05/28/2023
0.0 0.0
5/29/2023
08:00
5/29/2023
08:30
0.50 INTRM1, WHDBOP RURD P Pull test plug, Run wear bushing as per
Vault Rep. (ID 9" OD 13- 3/8" Length 14
-3/4" ) R/D and Blow down Bop test
equipment
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 6/14/2023
Page 18/28
1C-156
Report Printed: 6/29/2023
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)
5/29/2023
08:30
5/29/2023
10:45
2.25 INTRM1, WHDBOP RURD P Finish loading, strapping and tallying 4"
drill pipe, Install 4" handling equip, P/U
short BHA tools via beaver slide.
0.0 0.0
5/29/2023
10:45
5/29/2023
11:00
0.25 INTRM1, WHDBOP SFTY P Hold PJSM picking up Directional BHA 0.0 0.0
5/29/2023
11:00
5/29/2023
13:30
2.50 INTRM1, DRILLOUT BHAH P P/U and M/U 6-3/4" Production BHA #1
as per SLB DD/MWD to 353' MD S/O
below jars 53k
0.0 353.0
5/29/2023
13:30
5/29/2023
16:00
2.50 INTRM1, DRILLOUT TRIP P RIH picking up singles of 4" drill pipe F/
353' MD to 1963' MD S/O 63k
Monitoring displacement on 1-2 pits
353.0 1,963.0
5/29/2023
16:00
5/29/2023
16:30
0.50 INTRM1, DRILLOUT SRVY P @ 1963' MD Kelly up perform shallow
hole test as per MWD/DD sent downlink
1,963.0 1,963.0
5/29/2023
16:30
5/30/2023
00:00
7.50 INTRM1, DRILLOUT DLOG P Wash down logging for TOC f/ 1963"
MD T/ 3354' MD TOC, Keep logging to
3657' MD GPM= , PSI= , F/O= 22%,
ROP=600 FPH, S/O=74K as per SLB
1,963.0 3,657.0
5/30/2023
00:00
5/30/2023
08:45
8.75 INTRM1, DRILLOUT DLOG P Continue to p/u 4" DP 1x1 logging
cement via sonic tool f/ 3,657' MD to
9,434' MD. Filling pipe every 15 stds.
Monitor disp via pit 1 and pill pit 1, s/o wt
- 74k
3,657.0 9,434.0
5/30/2023
08:45
5/30/2023
09:30
0.75 INTRM1, DRILLOUT WASH P Kelly up. Send downlink to change
memory settings on sonic tool. Wash dn
f/ 9,434' MD to 9,526' MD w/ 260 gpm,
1,982 psi, 28% f/o. Up wt - 115k, s/o wt
- 78k
9,434.0 9,526.0
5/30/2023
09:30
5/30/2023
11:00
1.50 INTRM1, DRILLOUT PRTS P R/U and test 7.625 int csg to 3,750 psi f/
30 charted min. (good). 60 stks to
pressure up. 6 bbls bled back.
9,526.0 9,526.0
5/30/2023
11:00
5/30/2023
12:00
1.00 INTRM1, DRILLOUT WASH P Wash dn f/ 9,526' MD to top of float
collar at 9,684' MD w/ 260 gpm, 1,994
psi, 23% f/o, s/o wt - 75k.
9,526.0 9,684.0
5/30/2023
12:00
5/30/2023
12:30
0.50 INTRM1, DRILLOUT DRLG P Drill float collar f/ 9,684' MD to 9,687'
MD w/ 260 gpm, 2,150 psi, 24% f/o, 60
rpm, 9k tq, 5k wob.
9,684.0 9,687.0
5/30/2023
12:30
5/30/2023
13:30
1.00 INTRM1, DRILLOUT DRLG P Drill cement f/ 9,687' MD to 9,714' MD
w/ 260 gpm, 2,172 psi, 26% f/o, 80 rpm,
8k tq, 7k wob.
9,687.0 9,714.0
5/30/2023
13:30
5/30/2023
14:00
0.50 INTRM1, DRILLOUT FIT P FIT OA to 12.5 ppg. Pressure up to 253
psi. Shut in for 10 min and observe psi
drop to 101 psi. Bleed psi off. Observe
no injection into OA.
9,714.0 9,714.0
5/30/2023
14:00
5/30/2023
15:15
1.25 INTRM1, DRILLOUT DRLG P Cont to drill cement f/ 9,714' MD to top
of shoe @ 9,769' MD w/ 260 gpm, 2,126
psi, 26% f/o, 80 rpm, 7k tq, 6k wob.
9,714.0 9,769.0
5/30/2023
15:15
5/30/2023
17:00
1.75 INTRM1, DRILLOUT DRLG P Drill shoe and rat hole f/ 9,769' MD to
9,777' MD w/ 260 gpm, 2,095 psi, 23%
f/o, 60 rpm, 9k tq, 6k wob.
9,769.0 9,777.0
5/30/2023
17:00
5/30/2023
17:30
0.50 INTRM1, DRILLOUT DDRL P Drill 6¾" production hole f/ 9,777' MD to
9,797' MD w/ 260 gpm, 2,032 psi, 28%
f/o, 120 rpm, 9k tq, 10k wob, ecd - 9.48
9,777.0 9,797.0
5/30/2023
17:30
5/30/2023
19:00
1.50 INTRM1, DRILLOUT CIRC P Rot and recip pipe f/ 9,797' MD to 9,753'
MD. Circ and condition mud w/ 260
gpm, 2,014 psi, 26% f/o, 60 rpm, 9k tq.
Up wt - 89k. s/o wt - 93k at rate. Total
stks pumped - 3742 (376 bbls).
SIMOPS - work through shoe w/ no
rotation 3x (good)
9,797.0 9,797.0
5/30/2023
19:00
5/30/2023
20:00
1.00 INTRM1, DRILLOUT FIT P POOH f/ 9,797' MD to 9,716' MD and rig
up to FIT. Pump 2.5 bbls at ½ bpm, to
1,163 psi. Achieve 15 ppg EMW. Bleed
back 2.5 bbls. B/D surface lines and
RIH t/ 9,797' MD.
9,797.0 9,797.0
Rig: DOYON 142
RIG RELEASE DATE 6/14/2023
Page 19/28
1C-156
Report Printed: 6/29/2023
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)
5/30/2023
20:00
5/30/2023
21:30
1.50 PROD1, DRILL DISP P Displace wellbore to 9.0 Flo-Pro NT.
Rot and recip pipe f/ 9,797' MD to 9,716'
MD. Pump 35 bbl 9.0 ppg hi-vis spacer.
Chase w/ 9.0 ppg Flo-Pro @ 5 bpm, 211
gpm, icp - 1725, fcp - 1,300, 20% f/o, 20
rpm, 8.5k tq, up wt - 88k, s/o wt - 93k.
Total stks pumped - 4526 (455 bbls)
9,797.0 9,797.0
5/30/2023
21:30
5/30/2023
22:00
0.50 PROD1, DRILL OWFF P OWFF (static). SIMOPS - clean under
shaker beds
9,797.0 9,797.0
5/30/2023
22:00
5/30/2023
22:15
0.25 PROD1, DRILL CLEN P Continue to clean under shakers 9,797.0 9,797.0
5/30/2023
22:15
5/30/2023
22:30
0.25 PROD1, DRILL CIRC P Obtain SPR's. 9,797.0 9,797.0
5/30/2023
22:30
5/31/2023
00:00
1.50 PROD1, DRILL DDRL P Drill 6¾" production hole f/ 9,797' MD to
9,907' MD w/ 260 gpm, 1,875 psi, 29%
f/o, 100 rpm, 7k tq, 2k wob, ecd - 10.17.
Up wt - 116k, s/o wt - 72k, rot wt - 92k
9,797.0 9,907.0
5/31/2023
00:00
5/31/2023
02:00
2.00 PROD1, DRILL DDRL P Drill 6¾" production hole f/ 9,907' MD to
10,000' MD 3,966' TVD, w/ 280 gpm,
2,139 psi, 29% f/o, 120 rpm, 7k tq, 2k
wob, ecd - 10.18. Up wt - 116k, s/o wt -
72k, rot wt - 92k. Observe issue with
PowerDrive. Pump lo/hi vis sweep to
mitigate issue. (unsuccessful).
9,907.0 10,000.0
5/31/2023
02:00
5/31/2023
03:30
1.50 PROD1, DRILL DDRL T Observe no real time drilling data from
PowerDrive. Complete anti-jamming
procedure per slmb. Lower flow rate to
100 gpm, 530 psi, 14% f/o for 5 min.
increase flow 25 gal every 5 min staging
up to 280 gpm, 2120 psi, 28% f/o, while
recip pipe f/ 10,000' MD to 9,913' MD
with 60 rpm, 6k tq, 92k rot wt.
10,000.0 10,000.0
5/31/2023
03:30
5/31/2023
04:00
0.50 PROD1, DRILL DDRL P Drill 6¾" production hole f/ 10,000' MD
to 10,059' MD 3,966' TVD, w/ 280 gpm,
2,140 psi, 29% f/o, 120 rpm, 7k tq, 2k
wob, ecd - 10.22. Up wt - 116k, s/o wt -
72k, rot wt - 91k
10,000.0 10,059.0
5/31/2023
04:00
5/31/2023
05:00
1.00 PROD1, DRILL DDRL T Observe PowerDrive communication
issues. Recip pipe f/ 10,059' MD to
10,035' MD w/ 260 gpm, 1900 psi, 28%
f/o, 60 rpm, 6k tq. Attempt to send
directional command to PowerDrive
(failed). Decision made to POOH and
c/o BHA. Send command to place
PowerDrive in neutral.
10,059.0 10,035.0
5/31/2023
05:00
5/31/2023
05:30
0.50 PROD1, DRILL OWFF T OWFF(static). B/D TD. Line up mud
pits on TT.
10,035.0 10,035.0
5/31/2023
05:30
5/31/2023
06:30
1.00 PROD1, DRILL TRIP T POOH on elevators f/ 10,035' MD to
9,064' MD. Up wt - 122k, s/o wt - 91K.
Monitor disp via TT.
10,035.0 9,064.0
5/31/2023
06:30
5/31/2023
06:45
0.25 PROD1, DRILL CIRC T Pump 20 bbl slug @ 4 bpm, 730 psi,
18% f/o. B/D TD.
9,064.0 9,064.0
5/31/2023
06:45
5/31/2023
11:45
5.00 PROD1, DRILL TRIP T POOH on elevators f/ 9,064' MD to 451'
MD. Monitor disp via TT. Up wt - 52K.
9,064.0 451.0
5/31/2023
11:45
5/31/2023
12:00
0.25 PROD1, DRILL OWFF T OWFF (static). SIMPOS - PJSM on L/D
BHA.
451.0 451.0
5/31/2023
12:00
5/31/2023
12:15
0.25 PROD1, DRILL TRIP T R/B 4" HWDP and jar stand. 451.0 138.0
5/31/2023
12:15
5/31/2023
13:45
1.50 PROD1, DRILL BHAH T L/D BHA as per SLMB DD. 138.0 0.0
5/31/2023
13:45
5/31/2023
14:30
0.75 PROD1, DRILL BHAH T Clean and clear rig floor. SIMOPS - rig
up on OA to perform injectivity test.
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 6/14/2023
Page 20/28
1C-156
Report Printed: 6/29/2023
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)
5/31/2023
14:30
5/31/2023
15:30
1.00 PROD1, DRILL LOT P Pump down OA at .5 bpm. Observe
formation break down at 443 psi (14.4
ppg EMW). Pump 3 total bbls FCP -
387. Shut down and shut in OA.
Observe psi bleed down to 179 (264 psi)
in 15 min. Exceeded surface csg shoe
LOT (12.5 ppg EMW) as per risk
assessment.
0.0 0.0
5/31/2023
15:30
5/31/2023
16:45
1.25 PROD1, DRILL BHAH T P/U 6¾" production BHA as per SLMB
DD to 323' MD. Monitor disp via TT.
SIMOPS - Freeze protect 10.75" x
7.625" OA via LRS. PT lines to 2500
PSI. Pump 80 bbls of diesel, ICP - 380
@ .5 bpm. FCP - 477 @ 2 bpm. Max
psi seen during pumping - 730. Initial
SIP - 477. 15 sec SIP - 453. 30 sec
SIP - 446. Monitored for total of 20 min.
FSIP - 410 (67 psi bleed off).
0.0 323.0
5/31/2023
16:45
5/31/2023
17:30
0.75 PROD1, DRILL TRIP T RIH w/ 6¾" production BHA f/ 323' MD
to 1,741' MD on 4" DP from the derrick.
Monitor disp via pit #1, s/o wt - 68k.
323.0 1,741.0
5/31/2023
17:30
5/31/2023
18:00
0.50 PROD1, DRILL SRVY T Shallow hole test directional tools (good)
w/ 220 gpm, 861 psi, 24% f/o.
1,741.0 1,741.0
5/31/2023
18:00
5/31/2023
23:30
5.50 PROD1, DRILL TRIP T RIH w/ 6¾" production BHA f/ 1741' MD
to 9,878' MD on 4" DP from the derrick.
Monitor disp via pit #1, Fill pipe every
15 stds. up wt - k, s/o wt - xxk.
1,741.0 9,878.0
5/31/2023
23:30
6/1/2023
00:00
0.50 PROD1, DRILL WASH T RIH w/ 6¾" production BHA and wash
in the hole f/ 9,878' MD to 9,944' MD w/
258 gpm, 1765 psi, 27% f/o, 67k s/o.
9,878.0 9,944.0
6/1/2023
00:00
6/1/2023
00:30
0.50 PROD1, DRILL REAM T Wash and ream in the hole f/ 9,944' MD
to 10,059' MD w/ 260 gpm, 1748 psi,
25% f/o, 80 rpm, 5k tq, rot wt - 93k.
Simops - send downlink for mwd tools.
9,944.0 10,059.0
6/1/2023
00:30
6/1/2023
02:15
1.75 PROD1, DRILL DDRL P Drill 6¾" production hole f/ 10,059' MD
to 10,100' MD 3,968 TVD w/ 260 gpm,
1804 psi, 28% f/o, 120 rpm, 8k tq, 5k
wob, 10.14 ecd, up wt - 118k, s/o wt -
68k, rot wt - 93k.
10,059.0 10,100.0
6/1/2023
02:15
6/1/2023
06:00
3.75 PROD1, DRILL REAM T Observe higher than anticipated drill
string interference with survey
corrections not aligning with originally
observed corrections. Re-shoot survey
at 10,100 (poor survey). Conduct rolling
surveys all at 260 gpm 1780 psi, 27%
f/o w/o success. Ream out to 9,996' MD
with 60 rpm, 5k tq, same rate. Re-shoot
surveys w/o success. Recip pipe f/
9,996' MD to 9,972' MD while waiting on
town decision. Continue to ream out to
9,902' MD at same rate and conduct
rolling surveys w/o success. Work pipe
f/ 9,902' MD to 9,972' MD while awaiting
decision from town. Ream up to 9,855'
MD and shoot survey with same results
(poor).
10,100.0 9,855.0
6/1/2023
06:00
6/1/2023
07:00
1.00 PROD1, DRILL TRIP T Decision made to rih and continue
drilling. Trip to btm f/ 9,855' MD to
10,100' MD. Shoot survey on btm w/
260 gpm, 1740 psi, 25% f/o, 120 rpm,
6k tq, s/o wt - 72k, rot wt - 91k.
9,855.0 10,100.0
Rig: DOYON 142
RIG RELEASE DATE 6/14/2023
Page 21/28
1C-156
Report Printed: 6/29/2023
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)
6/1/2023
07:00
6/1/2023
12:00
5.00 PROD1, DRILL DDRL P Drill 6¾" production hole f/ 10,100' MD
to 10,269' MD 3,960' TVD w/ 260 gpm,
1805 psi, 28% f/o, 150 rpm, 8k tq, 8k
wob, 10.21 ecd, up wt - 118k, s/o wt -
68k, rot wt - 93k.
10,100.0 10,269.0
6/1/2023
12:00
6/1/2023
18:00
6.00 PROD1, DRILL DDRL P Drill 6¾" production hole via NOVOS f/
10,269' MD to 10,595' MD 3,952' TVD
w/ 270 gpm, 2029 psi, 28% f/o, 150
rpm, 8k tq, 9k wob, 10.36 ecd, up wt -
115k, s/o wt - 72k, rot wt - 93k.
10,269.0 10,595.0
6/1/2023
18:00
6/2/2023
00:00
6.00 PROD1, DRILL DDRL P Drill 6¾" production hole via NOVOS f/
10,595' MD to 10,838' MD 3,944' TVD
w/ 270 gpm, 2079 psi, 28% f/o, 150
rpm, 9k tq, 16k wob, 10.34 ecd, up wt -
116k, s/o wt - 70k, rot wt - 91k.
Encounter slow rop (10 ft/hr) at top of
the WSAK D formation 10,820' MD to
10,838' MD.
10,595.0 10,838.0
6/2/2023
00:00
6/2/2023
06:00
6.00 PROD1, DRILL DDRL P Drill 6¾" production hole via NOVOS F/
10,838‘ MD- T/ 10,890' MD 3,941‘ TVD,
WOB = 10-16K, GPM = 270, PSI =
2027, RPM = 120, TQ on = 8K, Flow out
= 27%, ECD= 10.22 ppg, P/U WT =
116K S/O WT = 70K, RT WT = 94K.
Slow ROP of 8 FT/HR.
10,838.0 10,890.0
6/2/2023
06:00
6/2/2023
12:00
6.00 PROD1, DRILL DDRL P Drill 6¾" production hole via NOVOS F/
10,890‘ MD- T/ 10,940' MD 3,940‘ TVD,
WOB = 13K, GPM = 270, PSI = 2038,
RPM = 120, TQ on = 8K, Flow out =
26%, ECD= 10.18 ppg, P/U WT = 117K
S/O WT = 77K, RT WT = 94K. Slow
ROP of 8 FT/HR.
10,890.0 10,940.0
6/2/2023
12:00
6/2/2023
18:00
6.00 PROD1, DRILL DDRL P Drill 6¾" production hole via NOVOS F/
10,940‘ MD- T/ 10,994' MD 3,938‘ TVD,
WOB = 14K, GPM = 270, PSI = 2080,
RPM = 120, TQ on = 7.5K Flow out =
27%, ECD= 10.20 ppg, P/U WT = 117K
S/O WT = 77K, RT WT = 94K. Slow
ROP of 9 FT/HR.
10,940.0 10,994.0
6/2/2023
18:00
6/3/2023
00:00
6.00 PROD1, DRILL DDRL P Drill 6¾" production hole via NOVOS F/
10,994‘ MD- T/ 11,052' MD 3,938‘ TVD,
WOB = 14K, GPM = 270, PSI = 2079,
RPM = 120, TQ on = 7K, Flow out =
28%, ECD= 10.33 ppg, P/U WT = 115K
S/O WT = 72K, RT WT = 86K. Observe
increase in ROP at 11,037' MD.
10,994.0 11,052.0
6/3/2023
00:00
6/3/2023
06:00
6.00 PROD1, DRILL DDRL P Drill 6¾" production hole via NOVOS F/
11,052‘ MD- T/ 11,318' MD 3,934‘ TVD,
WOB = 9.5K, GPM = 270, PSI = 2170,
RPM = 120, TQ on = 7K, Flow out =
26%, MW in/out = 9.0 ppg, ECD= 10.42
ppg, P/U WT = 112K S/O WT = 65K, RT
WT = 86K. Max gas = 230 units.
11,052.0 11,318.0
6/3/2023
06:00
6/3/2023
12:00
6.00 PROD1, DRILL DDRL P Drill 6¾" production hole via NOVOS F/
11,318‘ MD- T/ 11,581' MD 3,937‘ TVD,
WOB = 1-2K, GPM = 270, PSI = 2062,
RPM = 120, TQ on = 6K, Flow out =
27%, MW in/out = 9.0 ppg, ECD= 10.50
ppg, P/U WT = 117K S/O WT = 66K, RT
WT = 92K. Max gas = 1020 units.
11,318.0 11,581.0
6/3/2023
12:00
6/3/2023
18:00
6.00 PROD1, DRILL DDRL P Drill 6¾" production hole via NOVOS F/
11,581‘ MD- T/ 12,152' MD 3,934‘ TVD,
WOB = 1-2K, GPM = 270, PSI = 2072,
RPM = 120, TQ on = 6K, Flow out =
27%, MW in/out = 9.0 ppg, ECD= 10.50
ppg, P/U WT = 117K S/O WT = 69K, RT
WT = 91K. Max gas = 1368 units.
11,581.0 12,152.0
Rig: DOYON 142
RIG RELEASE DATE 6/14/2023
Page 22/28
1C-156
Report Printed: 6/29/2023
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)
6/3/2023
18:00
6/4/2023
00:00
6.00 PROD1, DRILL DDRL P Drill 6¾" production hole via NOVOS F/
12,152‘ MD- T/ 12,718' MD 3,933‘ TVD,
WOB = 4K, GPM = 270, PSI = 2145,
RPM = 120, TQ on = 7K, Flow out =
26%, MW in/out = 9.0 ppg, ECD= 10.65
ppg, P/U WT = 123K S/O WT = 60K,
RT WT = 95K. Max gas = 1446 units.
12,152.0 12,718.0
6/4/2023
00:00
6/4/2023
06:00
6.00 PROD1, DRILL DDRL P Drill 6¾" production hole via NOVOS F/
12,718‘ MD- T/ 13,146' MD 3,930‘ TVD,
WOB = 4K, GPM = 270, PSI = 2256,
RPM = 120, TQ on = 7K, Flow out =
27%, MW in/out = 9.0 ppg, ECD= 10.71
ppg, P/U WT = 126K S/O WT = 55K,
RT WT = 93K. Max gas = 642 units.
12,718.0 13,146.0
6/4/2023
06:00
6/4/2023
12:00
6.00 PROD1, DRILL DDRL P Drill 6¾" production hole via NOVOS F/
13,146‘ MD- T/ 13,405' MD 3,924‘ TVD,
WOB = 2K, GPM = 270, PSI = 2251,
RPM = 120, TQ on = 7K, Flow out =
27%, MW in/out = 9.0 ppg, ECD= 10.71
ppg, P/U WT = 126K S/O WT = 56K,
RT WT = 93K. Max gas = 173 units.
13,146.0 13,405.0
6/4/2023
12:00
6/4/2023
18:00
6.00 PROD1, DRILL DDRL P Drill 6¾" production hole via NOVOS F/
13,405‘ MD- T/ 13,854' MD 3,918‘ TVD,
WOB = 3K, GPM = 270, PSI = 2191,
RPM = 120, TQ on = 7K, Flow out =
27%, MW in/out = 9.0 ppg, ECD= 10.65
ppg, P/U WT = 126K S/O WT = 52K,
RT WT = 93K. Max gas = 384 units.
13,405.0 13,854.0
6/4/2023
18:00
6/5/2023
00:00
6.00 PROD1, DRILL DDRL P Drill 6¾" production hole via NOVOS F/
13,854‘ MD- T/ 14,300' MD 3,934‘ TVD,
WOB = 3K, GPM = 270, PSI = 2371,
RPM = 120, TQ on = 7K, Flow out =
27%, MW in/out = 9.0 ppg, ECD= 10.85
ppg, P/U WT = 127K S/O WT = NA, RT
WT = 95K. Max gas = 202 units.
13,854.0 14,300.0
6/5/2023
00:00
6/5/2023
06:00
6.00 PROD1, DRILL DDRL P Drill 6¾" production hole via NOVOS F/
14,300‘ MD- T/ 14,753' MD 3,933‘ TVD,
WOB = 6K, GPM = 270, PSI = 2354,
RPM = 120, TQ on = 7K, Flow out =
27%, MW in/out = 9.0 ppg, ECD= 10.72
ppg, P/U WT = 130K S/O WT = NA, RT
WT = 93K. Max gas = 662 units.
Crossed a fault/rubble zone at 14,689'
MD. Started to see losses at ~20 bbl/hr
but then dimeninished as we drilled
further away from fault.
14,300.0 14,753.0
6/5/2023
06:00
6/5/2023
12:00
6.00 PROD1, DRILL DDRL P Drill 6¾" production hole via NOVOS F/
14,753‘ MD- T/ 14,952' MD 3,922‘ TVD,
WOB = 2-6K, GPM = 270, PSI = 2385,
RPM = 120, TQ on = 7K, Flow out =
27%, MW in/out = 9.0 ppg, ECD= 10.72
ppg, P/U WT = 130K S/O WT = NA, RT
WT = 93K. Max gas = 540 units.
14,753.0 14,952.0
6/5/2023
12:00
6/5/2023
18:00
6.00 PROD1, DRILL DDRL P Drill 6¾" production hole via NOVOS F/
14,952‘ MD- T/ 15,294' MD 3,918‘ TVD,
WOB = 6-8K, GPM = 270, PSI = 2455,
RPM = 120, TQ on = 8K, Flow out =
27%, MW in/out = 9.0 ppg, ECD= 10.95
ppg, P/U WT = 131K S/O WT = NA, RT
WT = 94K. Max gas = 680 units.
14,952.0 15,294.0
Rig: DOYON 142
RIG RELEASE DATE 6/14/2023
Page 23/28
1C-156
Report Printed: 6/29/2023
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)
6/5/2023
18:00
6/6/2023
00:00
6.00 PROD1, DRILL DDRL P Drill 6¾" production hole via NOVOS F/
15,294‘ MD- T/ 15,855' MD 3,909‘ TVD,
WOB = 2K, GPM = 270, PSI = 2570,
RPM = 120, TQ on = 8K, Flow out =
27%, MW in/out = 9.0 ppg, ECD= 11.12
ppg, P/U WT = 136K S/O WT = NA, RT
WT = 99K. Max gas = 740 units.
15,294.0 15,855.0
6/6/2023
00:00
6/6/2023
06:00
6.00 PROD1, DRILL DDRL P Drill 6¾" production hole via NOVOS F/
15,855‘ MD- T/ 16,461' MD 3,907‘ TVD,
WOB = 3K, GPM = 270, PSI = 2729,
RPM = 120, TQ on = 8K, Flow out =
27%, MW in/out = 9.0 ppg, ECD= 11.26
ppg, P/U WT = 142K S/O WT = NA, RT
WT = 103K. Max gas = 600 units.
Steady ROP of 140 ft/hr.
15,855.0 16,461.0
6/6/2023
06:00
6/6/2023
12:00
6.00 PROD1, DRILL DDRL P Drill 6¾" production hole via NOVOS F/
16,461‘ MD- T/ 17,052' MD 3,906‘ TVD,
WOB = 3K, GPM = 270, PSI = 2807,
RPM = 120, TQ on = 9K, Flow out =
25%, MW in/out = 9.0 ppg, ECD= 11.32
ppg, P/U WT = 155K S/O WT = NA, RT
WT = 109K. Max gas = 796 units.
Increase ROP to150 ft/hr @ 16,950'
MD.
16,461.0 17,052.0
6/6/2023
12:00
6/6/2023
18:00
6.00 PROD1, DRILL DDRL P Drill 6¾" production hole via NOVOS F/
17,052‘ MD- T/ 17,618' MD 3,891‘ TVD,
WOB = 3K, GPM = 270, PSI = 2894,
RPM = 120, TQ on = 10K, Flow out =
24%, MW in/out = 9.0 ppg, ECD= 11.39
ppg, P/U WT = 162K S/O WT = NA, RT
WT = 116K. Max gas = 1011 units.
Increase ROP to 160 ft/hr @ 17,230'
MD.
17,052.0 17,618.0
6/6/2023
18:00
6/7/2023
00:00
6.00 PROD1, DRILL DDRL P Drill 6¾" production hole via NOVOS F/
17,618‘ MD- T/ 18,261' MD 3,882‘ TVD,
WOB = 4K, GPM = 270, PSI = 3014,
RPM = 120, TQ on = 10K, Flow out =
24%, MW in/out = 9.0 ppg, ECD= 11.48
ppg, P/U WT = 170K S/O WT = NA, RT
WT = 122K. Max gas = 1297 units.
Increase ROP to 160 ft/hr @ 17,230'
MD. Increase ROP to 170 ft/hr @
17,667'' MD
17,618.0 18,261.0
6/7/2023
00:00
6/7/2023
06:00
6.00 PROD1, DRILL DDRL P Drill 6¾" production hole via NOVOS F/
18,261‘ MD - T/ 18,806' MD 3,882‘ TVD,
WOB = 1K, GPM = 240, PSI = 2542,
RPM = 120, TQ on = 10K, Flow out =
22%, MW in/out = 9.0 ppg, ECD= 11.29
ppg, P/U WT = 173K S/O WT = NA, RT
WT = 124K. Max gas = 1063 units.
At 18,445' MD observe F/O%, ECD, &
Gain/Loss decrease - 120 bph intial loss
rate. Pump 35 bbl 35 ppb LCM sweeps.
Observe loss rate improve to 60 bph.
Start to observe wellbore breathing on
connections (no observations on BU
after connections).
18,261.0 18,806.0
Rig: DOYON 142
RIG RELEASE DATE 6/14/2023
Page 24/28
1C-156
Report Printed: 6/29/2023
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)
6/7/2023
06:00
6/7/2023
12:00
6.00 PROD1, DRILL DDRL P Drill 6¾" production hole via NOVOS F/
18,806‘ MD - T/ 19,243' MD 3,886‘ TVD,
WOB = 4K, GPM = 240, PSI = 2618,
RPM = 120, TQ on = 11K, Flow out =
20%, MW in/out = 9.0 ppg, ECD= 11.34
ppg, P/U WT = 199K S/O WT = NA, RT
WT = 125K. Max gas = 1112 units.
Continue to pump 35 bbl 35 ppb LCM
sweeps@ each connection. Observe
loss rate of 40-60 bph.
18,806.0 19,243.0
6/7/2023
12:00
6/7/2023
16:00
4.00 PROD1, DRILL DDRL P Drill 6¾" production hole via NOVOS F/
19,243‘ MD - T/ TD of 19,567' MD 3,881‘
TVD, WOB = 3K, GPM = 240, PSI =
2655, RPM = 120, TQ on = 11K, Flow
out = 21%, MW in/out = 9.0 ppg, ECD=
11.20 ppg, P/U WT = 199K S/O WT =
NA, RT WT = 127K. Max gas = 1289
units.
Continue to pump 35 bbl 35 ppb LCM
sweeps@ each connection. Observe
loss rate of 20-40 bph.
19,243.0 19,567.0
6/7/2023
16:00
6/7/2023
16:15
0.25 PROD1, TRIPCAS SRVY P Send downlink to put power drive into
neutral. Acquire final survey & torque
and drag values.
19,567.0 19,567.0
6/7/2023
16:15
6/7/2023
16:45
0.50 PROD1, TRIPCAS OWFF P OWFF. Observe wellbore breathing.
Confirm with diminishing flow out. (No
observations with BU after flow check)
19,567.0 19,567.0
6/7/2023
16:45
6/8/2023
00:00
7.25 PROD1, TRIPCAS BKRM P BROOH F/ 19,567' MD to 19,129' MD @
60' HR completing B/U per stand w/
GPM = 240, IPSI = 2690, FCP = 2364,
RPM = 120, TQ = 9K, Flow out = 21%,
MW in/out = 9.0 ppg, ECD= 11.20 ppg,
P/U WT = 199K Max gas = 1016 units.
Continue to pump 35 bbl 35 ppb LCM
(safe-carb) sweeps@ each connection.
Observe loss rate improve to 20 bph @
19,475' MD.
Total formation losses in the last 24
hours = 517 bbls.
19,567.0 19,129.0
6/8/2023
00:00
6/8/2023
12:00
12.00 PROD1, TRIPCAS BKRM P BROOH F/ 19,129' MD to 15,730' MD
racking back 4" HWDP w/ GPM = 240,
ICP = 2364, FCP = 2040, RPM = 120,
TQ = 7K, Flow out = 20%, MW in/out =
9.0 ppg, ECD= 10.64 ppg, P/U WT =
137K, S/O WT = NA, ROT WT = 95K.
Max gas = 215 units.
Pump final 35 bbl 35 ppb LCM(safe-
carb) pill @ 18,227' MD. Observe loss
rate of 10-20 BPH.
19,129.0 15,730.0
6/8/2023
12:00
6/8/2023
13:45
1.75 PROD1, TRIPCAS BKRM P BROOH F/ 15,730' MD to 15,181' MD
racking back 4" HWDP w/ GPM = 250,
ICP = 2040, FCP = 2004, RPM = 120,
TQ = 6K, Flow out = 22%, MW in/out =
9.0 ppg, ECD= 10.49 ppg, P/U WT =
122K, S/O WT = 67K, ROT WT = 94K.
Max gas = 254 units.
15,730.0 15,181.0
Rig: DOYON 142
RIG RELEASE DATE 6/14/2023
Page 25/28
1C-156
Report Printed: 6/29/2023
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)
6/8/2023
13:45
6/9/2023
00:00
10.25 PROD1, TRIPCAS BKRM P BROOH F/ 15,181' MD to 11,619 MD
L/D 4" DP via mousehole w/ GPM =
250, ICP = 2004, FCP = 1850, RPM =
120, TQ = 6K, Flow out = 22%, MW
in/out = 9.0 ppg, ECD= 10.28 ppg, P/U
WT = 118K, S/O WT = 76K, ROT WT =
94K. Max gas = 222 units.
Total formation losses in the last 24
hours = 125 bbls.
15,181.0 11,619.0
6/9/2023
00:00
6/9/2023
06:45
6.75 PROD1, TRIPCAS BKRM P BROOH F/ 11,619' MD to 9,750 MD L/D
4" DP via mousehole w/ GPM = 250,
ICP = 1850, FCP = 1820, RPM = 120,
TQ = 4K, Flow out = 22%, MW in/out =
9.0 ppg, ECD= 10.52 ppg, P/U WT =
118K, S/O WT = 76K, ROT WT = 94K.
Max gas = 389 units.
11,619.0 9,750.0
6/9/2023
06:45
6/9/2023
10:00
3.25 PROD1, TRIPCAS DHEQ P Drop 1.75" Well Commander ball @
9,750' MD to simulate shifting open the
tool. Pump @ 250 GPM, 1675 PSI,
22% FO, F/ 12 MIN, Slow pumps to 84
GPM, 423 PSI, 14% FO in anticipation
of landing ball on seat. Observe no PSI
change. ROT / RECIP F/ 9750' MD T/
9682' MD W/ 5-10 RPM, 4 K TQ, ROT -
95K, Slowly stage pumps up in 1 BBL
increments T/ 48 STKS (195 GPM)
1005 PSI, 19% FO, without observing
ball on seat. Shut down and refer to the
Well Commander trouble shooting
guide. Decision to drop 2nd 1.75" OD
activation ball at same rate. After 1200
STKS without ball on seat, bring pumps
back up to 250 GPM, 1675 PSI, 22 %
FO, Observe no pressure change.
Total stks pumped = 5494 (553 bbls)
9,750.0 9,750.0
6/9/2023
10:00
6/9/2023
10:30
0.50 PROD1, TRIPCAS CIRC P Pump 10 BBLS of 11 PPG slug to
sweep drill string. Observe no change
in pressure.
9,750.0 9,750.0
6/9/2023
10:30
6/9/2023
12:30
2.00 PROD1, TRIPCAS CIRC P Stage up to circ rate and RPM's to circ
csg clean. Rot and recip F/ 9750 ' MD,
T/ 9682' MD, 250-285 GPM, 1675-2154
PSI, 22% FO, 20-80 RPM, 4-5K TQ,
TOTAL STKS = 8,954 (901 bbls).
Observe no change in pressure
signaling ball on seat.
9,750.0 9,750.0
6/9/2023
12:30
6/9/2023
13:00
0.50 PROD1, TRIPCAS OWFF P OWFF - static. 9,750.0 9,750.0
6/9/2023
13:00
6/9/2023
13:45
0.75 PROD1, TRIPCAS TRIP P POOH on elevators f/ 9,750' MD to
9,214' MD. Monitor disp via TT. P/U
WT - 115K, S/O WT - 88K.
9,750.0 9,214.0
6/9/2023
13:45
6/9/2023
14:15
0.50 PROD1, TRIPCAS CIRC P Pump 20 bbl weighted slug. B/D TD.
Drop 1.75" OD hollow drift.
9,214.0 9,214.0
6/9/2023
14:15
6/9/2023
20:15
6.00 PROD1, TRIPCAS TRIP P POOH on elevators f/ 9,214 MD to 418'
MD. Monitor disp via TT. P/U WT -
115K, S/O WT - 88K.
9,214.0 418.0
6/9/2023
20:15
6/9/2023
20:45
0.50 PROD1, TRIPCAS OWFF P OWFF - Static. SIMOPS - PJSM on L/D
BHA. Weekly function test BOPE.
Annular closing time - 18 sec, UPR - 10
sec, LPR - 10 sec, Blinds - 10 sec
418.0 418.0
6/9/2023
20:45
6/9/2023
22:15
1.50 PROD1, TRIPCAS TRIP P Cont POOH F/ 418' MD T/ 104' MD std
back, 1ea std 4" DP and 2 stds 4"
HWDP and L/D 6¾" Jars. Recover
1.75" hollow drift at jars. Monitor disp via
TT.
418.0 104.0
Rig: DOYON 142
RIG RELEASE DATE 6/14/2023
Page 26/28
1C-156
Report Printed: 6/29/2023
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)
6/9/2023
22:15
6/9/2023
23:30
1.25 PROD1, TRIPCAS BHAH P L/D 6¾" production BHA as per SLMB
DDX F/ 104' MD. Monitor disp viaTT.
Observe activation balls in well
commander ball catcher.
104.0 0.0
6/9/2023
23:30
6/10/2023
00:00
0.50 PROD1, TRIPCAS WWWH P Flush BOP stack w/ 275 gpm, 20 psi.
B/D the top drive.
0.0 0.0
6/10/2023
00:00
6/10/2023
01:30
1.50 COMPZN, CASING RURD P Rig up to run 4½ 12.6# L-80 slotted
liner.
0.0 0.0
6/10/2023
01:30
6/10/2023
01:45
0.25 COMPZN, CASING SFTY P PJSM on running liner. 0.0 0.0
6/10/2023
01:45
6/10/2023
13:30
11.75 COMPZN, CASING PUTB P Run 4½ 12.6# L-80 slotted liner as per
detail to 9,882' MD. Install 4½ x 6ǩ
centralizers on each jt. S/O WT - 72K.
Tq all connections to 5600 FT/LBS.
Monitor disp via TT.
0.0 9,882.0
6/10/2023
13:30
6/10/2023
14:15
0.75 COMPZN, CASING OTHR P M/U SLZXP liner hanger assembly and
seal bore extension. Tq 5½ HYD563
connection to 7000 FT/LBS. Fill liner tie
back with Zanplex D. RIH to 9,941' MD.
9,882.0 9,941.0
6/10/2023
14:15
6/10/2023
14:45
0.50 COMPZN, CASING RUNL P M/U XO to 4" DP and RIH to 10,035'
MD. Obtain perimeters w/ 20 RPM -
4.5K TQ, 30 RPM - 4K TQ, UP WT -
96K, S/O WT - 69K, ROT WT - 78K.
Pump 2 BPM, 60 PSI. Observe good
returns confirming clear fluid path.
9,941.0 10,035.0
6/10/2023
14:45
6/10/2023
20:30
5.75 COMPZN, CASING RUNL P Run liner in the hole on 4" DP F/ 10,035'
MD T/ 14,578' MD. Monitor disp via TT.
S/O WT - 60K. Take T&D every 5th jt w/
20/30 rpm.
10,035.0 14,578.0
6/10/2023
20:30
6/10/2023
21:15
0.75 COMPZN, CASING RUNL P Cont. to run liner in the hole on 4"
HWDP F/ 14,578' MD T/ 15,311' MD.
Drift stands out of the derrick. Monitor
disp via TT. Lost free S/O WT @
14,940' MD.
14,578.0 15,311.0
6/10/2023
21:15
6/11/2023
00:00
2.75 COMPZN, CASING RUNL P ROT liner in the hole on 4" HWDP F/
15,311' MD T/ 16,590' MD @ 20 RPM,
Initial TQ - 7K and S/O WT - 80K, Final
TQ - 8.2K and S/O WT - 90K. Drift
stands out of the derrick. Monitor disp
via TT.
15,311.0 16,590.0
6/11/2023
00:00
6/11/2023
08:30
8.50 COMPZN, CASING RUNL P ROT liner in the hole on 4" HWDP F/
16,590' MD T/ 19,434' MD @ 20 RPM,
Initial TQ - 8.2K and S/O WT - 90K.
Increase RPM to 30 @ 18,220' MD.
Final TQ - 10.5K and S/O WT - 115K.
Drift stands out of the derrick. Monitor
disp via TT.
16,590.0 19,434.0
6/11/2023
08:30
6/11/2023
09:00
0.50 COMPZN, CASING RUNL P Pick up 9.49' 4" DP pup and 1 std of 4"
DP. Space out to setting depth of
19,517' MD. Obtain perimeters - UP WT
- 206k, S/O WT - NA, ROT WT - 126K
W/ 30 RPM - 10.4K TQ.
19,434.0 19,517.0
6/11/2023
09:00
6/11/2023
09:45
0.75 COMPZN, CASING CIRC P Pump 17.5 bbls high vis sweep followed
by pipe volume @ 3 BPM, 693 PSI, to
clear ball seat of debris. Total stks
pumped - 989 (100 bbls)
19,517.0 19,517.0
Rig: DOYON 142
RIG RELEASE DATE 6/14/2023
Page 27/28
1C-156
Report Printed: 6/29/2023
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)
6/11/2023
09:45
6/11/2023
10:45
1.00 COMPZN, CASING PACK P Drop 1.125" OD ball. Chase bal with
14.5 bbl high vis sweep at 3 BPM, 769
PSI @ 600 slow rate to 1 BPM, 363
PSI. Observe ball on seat at 643 stks.
Pressure up to 2440 and hold for 5 min.
Stage pressure up to 3540 and hold for
5 min. Pressure up to 3750 to shear
ball seat. Bleed psi to 0. S/O to 42K to
confirm set(good). P/U to 143K w/ 1' of
travel to confirm released.
19,517.0 19,517.0
6/11/2023
10:45
6/11/2023
11:30
0.75 COMPZN, CASING PRTS P Test SLZXP liner top pkr to 3500 PSI
(good). R/D test equipment.
9,598.0 9,598.0
6/11/2023
11:30
6/11/2023
12:00
0.50 COMPZN, WELLPR TRIP P POOH F/ TOL @ 9,598' MD T/ 9,494'
MD racking back 1 std 4" DP and L/D
9.47 4" DP pup. P/U WT - 148K
9,598.0 9,494.0
6/11/2023
12:00
6/11/2023
13:15
1.25 COMPZN, WELLPR DISP P Displace well to 9.2 PPG CI Brine.
Pump 37 BBL Hi-vis sweep. Chase w/
9.2 CI Brine @ ICP = 8.5 BPM, 360
GPM, 3380 PSI, FCP = 6 BPM, 250
GPM, 1690 PSI. Total stks pumped -
5201 (523 bbls)
9,494.0 9,494.0
6/11/2023
13:15
6/11/2023
13:45
0.50 COMPZN, WELLPR OWFF P OWFF - SIMOPS - B/D TD. 9,494.0 9,494.0
6/11/2023
13:45
6/11/2023
14:30
0.75 COMPZN, WELLPR PULD P POOH L/D HWDP DP 1x1 F/ 9,494' MD
T/ 9,032' MD. UP WT - 145K. Monitor
disp via TT.
9,494.0 9,032.0
6/11/2023
14:30
6/11/2023
15:00
0.50 COMPZN, WELLPR SVRG P Grease wash pipe, TD, and Iron
Roughneck.
9,032.0 9,032.0
6/11/2023
15:00
6/11/2023
19:45
4.75 COMPZN, WELLPR PULD P POOH L/D HWDP 1x1 F/ 9,032' MD T/
4,636' MD. UP WT - 111K. Monitor disp
via TT.
9,032.0 4,636.0
6/11/2023
19:45
6/12/2023
00:00
4.25 COMPZN, WELLPR PULD P POOH L/D DP 1x1 F/ 4,636' MD T/ 39'
MD. UP WT - 111K. Monitor disp via
TT.
4,636.0 39.0
6/12/2023
00:00
6/12/2023
00:45
0.75 COMPZN, WELLPR BHAH P L/D Baker running tool. Monitor disp via
TT.
39.0 0.0
6/12/2023
00:45
6/12/2023
06:00
5.25 COMPZN, WELLPR PULD P L/D 40 stds of 4" DP F/ derrick via 90'
Mousehole.
0.0 0.0
6/12/2023
06:00
6/12/2023
06:30
0.50 COMPZN, WELLPR SVRG P Grease iron roughneck and top drive. 0.0 0.0
6/12/2023
06:30
6/12/2023
08:30
2.00 COMPZN, WELLPR PULD P L/D 13 stds of 4" DP F/ derrick via 90'
Mousehole.
0.0 0.0
6/12/2023
08:30
6/12/2023
08:45
0.25 COMPZN, WELLPR RURD P Pull wear bushing per Vault rep. 0.0 0.0
6/12/2023
08:45
6/12/2023
09:00
0.25 COMPZN, WELLPR OTHR P Organize 5" HWDP in derrick for rig
move.
0.0 0.0
6/12/2023
09:00
6/12/2023
10:15
1.25 COMPZN, WELLPR WWWH P Jet the BOPE @ 8 BPM, 340 GPM, 37
PSI (X4). R/D jetting tool and B/D TD.
0.0 0.0
6/12/2023
10:15
6/12/2023
10:45
0.50 COMPZN, WELLPR RURD P Clean and clear rig floor. 0.0 0.0
6/12/2023
10:45
6/12/2023
12:00
1.25 COMPZN, RPCOMP RURD P R/U Doyon Csg 4½ running equipment.
R/U fill up hose. Expedite tubing hanger
to the rig floor. Double check pipe count
and running order in the shed.
0.0 0.0
6/12/2023
12:00
6/12/2023
21:00
9.00 COMPZN, RPCOMP PUTB P PJSM, RIH w/ 4½" 12.6# L-80 HYD563
upper completion as per detail to 9597'
MD. P/U WT - 103K. S/O WT - 62K
Tq connections to 3800 FT/LBS.
Monitor disp via TT.
0.0 9,597.0
6/12/2023
21:00
6/12/2023
21:30
0.50 COMPZN, RPCOMP PUTB P Cont to RIH and fully locate no go at
9,610' MD. Mule shoe depth of 9,639'
MD.
9,597.0 9,639.0
Rig: DOYON 142
RIG RELEASE DATE 6/14/2023
Page 28/28
1C-156
Report Printed: 6/29/2023
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)
6/12/2023
21:30
6/12/2023
21:45
0.25 COMPZN, RPCOMP HOSO P POOH L/D jts 232 and 231. OWFF
(static).
9,639.0 9,597.0
6/12/2023
21:45
6/12/2023
23:00
1.25 COMPZN, RPCOMP THGR P M/U hanger and landing jt. RIH to shoe
depth of 9,635' MD (4' off no-go).
9,597.0 9,635.0
6/12/2023
23:00
6/12/2023
23:15
0.25 COMPZN, RPCOMP PRTS P PT hanger seals to 5,000 psi for 10 min
(good). Witnessed by CPAI rep.
9,635.0 9,635.0
6/12/2023
23:15
6/13/2023
00:00
0.75 COMPZN, RPCOMP PRTS P PT IA to 1000 psi to confirm SBE seals
are stabbed (good).
9,635.0 9,635.0
6/13/2023
00:00
6/13/2023
01:30
1.50 COMPZN, RPCOMP PRTS P Pressure test 4½ tbg to 3000 psi for 30
charted min (good). Bleed tbg psi to
2000. Pressure test IA to 3000 psi for
30 charted min (good). Bleed off tbg
rapidly and observe SOV shear and IA
psi bleed to 0.
9,635.0 9,635.0
6/13/2023
01:30
6/13/2023
02:30
1.00 COMPZN, RPCOMP RURD P R/D Doyon Csg / test equipment. L/D
landing jt.
0.0 0.0
6/13/2023
02:30
6/13/2023
02:45
0.25 COMPZN, RPCOMP MPSP P Install HP-BPV as per Vault. 0.0 0.0
6/13/2023
02:45
6/13/2023
03:00
0.25 COMPZN, RPCOMP PRTS P Test HP-BPV to 1500 psi for 10 charted
min (good).
0.0 0.0
6/13/2023
03:00
6/13/2023
09:00
6.00 COMPZN, WHDBOP NUND P Nipple down BOPE. SIMOPS - cut and
slip drill line. Change out saver sub to
NC-50. B/D steam system. Prep areas
for rig move.
0.0 0.0
6/13/2023
09:00
6/13/2023
12:00
3.00 COMPZN, WHDBOP NUND P Clean void for tree adapter. Install ring
seal per Vault rep. Nipple up 5K tree
and orient as per CPF-1 OPS. SIMOPS
- clean rig floor drip pan via super
sucker. Pull rotary table cover plate and
clean floor drain system. Continue to
prep areas for rig move.
0.0 0.0
6/13/2023
12:00
6/13/2023
13:00
1.00 COMPZN, WHDBOP NUND T Observed incorrect orientation of the
SSV. Re-orient the valve. SIMOPS -
continue to clean rig floor drip pan,
rotary table, rig floor drain system, and
prep areas for rig move.
0.0 0.0
6/13/2023
13:00
6/13/2023
15:30
2.50 COMPZN, WHDBOP PRTS P Test tree via LRS to 250 low, 5000
high.0
0.0 0.0
6/13/2023
15:30
6/13/2023
15:45
0.25 COMPZN, WHDBOP MPSP P Pull test dart and HP-BPV per Vault rep. 0.0 0.0
6/13/2023
15:45
6/13/2023
17:30
1.75 COMPZN, WHDBOP FRZP P PJSM, R/U LRS to freeze protect the
well. PT lines to 3500 psi. Freeze
protect the well to 1825' MD w/ 77 bbls
of diesel @ 1-1½ BPM, 500-750 psi,
taking returns to cuttings tank.
0.0 0.0
6/13/2023
17:30
6/13/2023
18:30
1.00 COMPZN, WHDBOP FRZP P B/D and R/D circ lines. 0.0 0.0
6/13/2023
18:30
6/13/2023
23:00
4.50 COMPZN, WHDBOP DMOB P Secure cellar. OA - 94 psi, IA - 0 psi,
TBG - 0 psi. SIMOPS - Move power,
pits, pump, rockwasher, and pipeshed
mods and stage for 1C-157
0.0 0.0
6/13/2023
23:00
6/14/2023
00:00
1.00 DEMOB, MOVE DMOB P Install tow tongue. Skid rig floor. Raise
stompers. SIMOPS - stage mats for
sub. Release rig at 00:00 HRS on
6/14/2023.
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 6/14/2023
Page 1/1
1C-156
Report Printed: 6/29/2023
Cement Detail Report
Cement Details
Description
Surface String Cement
Cementing Start Date
5/15/2023 23:00
Cementing End Date
5/16/2023 02:45
Wellbore Name
1C-156
Comment
CEMENT 10-3/4'' SUFACE CSG AS PER HALLIBURTON PUMP SCH., FLOOD LINES 5BBLS
H20@ 2.8BPM/109PSI, PT LINES T/3500PSI, PUMP 60BBL, 10.2PPG TUNED PRIME SPACE W/
4LB RED DYE W/ 3.5 BPM, 140PSI, SHUTDOWN AND DROP BOTTOM PLUG.
Cement Stages
Stage # 1
Description
Surface String Cement
Objective Top Depth (ftKB)
39.5
Bottom Depth (ftKB)
1,945.4
Full Return?
Yes
Vol Cement …
236.0
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)
450.0
P Plug Bump (psi)
1,000.0
Recip?
Yes
Stroke (ft)
10.00
Rotated?
No
Pipe RPM (rpm)
Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in)
Comment
CEMENT 10-3/4'' SUFACE CSG AS PER HALLIBURTON PUMP SCH., FLOOD LINES 5BBLS
H20@ 2.8BPM/109PSI, PT LINES T/3500PSI, PUMP 60BBL, 10.2PPG TUNED PRIME SPACE W/
4LB RED DYE W/ 3.5 BPM, 140PSI, SHUTDOWN AND DROP BOTTOM PLUG.
Cement Fluids & Additives
Fluid
Fluid Type
Lead Cement
Fluid Description Estimated Top (ftKB)
39.5
Est Btm (ftKB)
1,434.0
Amount (sacks)
749
Class Volume Pumped (bbl)
381.0
Yield (ft³/sack)
2.86
Mix H20 Ratio (gal/sa…
14.61
Free Water (%) Density (lb/gal)
10.70
Plastic Viscosity (cP)
42.3
Thickening Time (hr)
11.00
CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Fluid
Fluid Type
Tail Cement
Fluid Description Estimated Top (ftKB)
1,434.0
Est Btm (ftKB)
1,945.4
Amount (sacks)
280
Class Volume Pumped (bbl)
58.0
Yield (ft³/sack)
1.16
Mix H20 Ratio (gal/sa…
5.03
Free Water (%) Density (lb/gal)
15.80
Plastic Viscosity (cP)
7.0
Thickening Time (hr)
11.00
CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
String: Surface String Cement
Job: DRILLING ORIGINAL-<jobsubtyp> 5/10/2…
Page 1/1
1C-156
Report Printed: 6/29/2023
Cement Detail Report
Cement Details
Description
Intermediate String 1 Cement
Cementing Start Date
5/28/2023 14:00
Cementing End Date
5/28/2023 17:35
Wellbore Name
1C-156
Comment
Perform Cement job F/ 7-5/8" int... casing as per Halliburton. Flood Lines W/ 5 bbls H20 290 PSI, Pressure test lines 3500 PSI, Drop 1st plug, Pump 60 bbls
10.5 ppg Primed tunned spaces @ 4 bpm 404 psi. Drop 2nd plug Pump 241 bbls 14 ppg Lead cement W/ BMII @ 4 bpm 400 psi, Mix and Pump 55 bbls 15.3
ppg tail cement without BMII @ 4 bpm 115 psi, Drop top plug pump 10 bbls H20, Line up rig pumps to displace with 399 bbls 9.4 ppg mud @ 7 bpm 940 psi @
1300 strokes slow rate to 5 bpm 970 psi @ 400 strokes slow rate to 3 bpm 940 psi, Bump plug @ 4337 strokes nit. pressure 970psi bump with 1500 psi. Hold
floats for 5 min Bleed off float held/ CIP 17:35 hrs
Cement Stages
Stage # 1
Description
Intermediate String 1
Cement
Objective Top Depth (ftKB)
3,354.0
Bottom Depth (ftKB)
9,772.9
Full Return?
No
Vol Cement …
0.0
Top Plug?
No
Btm Plug?
Yes
Q Pump Init (bbl/m…
4
Q Pump Final (bbl/…
4
Q Pump Avg (bbl/…
4
P Pump Final (psi)
970.0
P Plug Bump (psi)
1,500.0
Recip?
Yes
Stroke (ft)
10.00
Rotated?
No
Pipe RPM (rpm)
Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in)
Comment
Perform Cement job F/ 7-5/8" int... casing as per Halliburton. Flood Lines W/ 5 bbls H20 290 PSI, Pressure test lines 3500 PSI, Drop 1st plug, Pump 60 bbls
10.5 ppg Primed tunned spaces @ 4 bpm 404 psi. Drop 2nd plug Pump 241 bbls 14 ppg Lead cement W/ BMII @ 4 bpm 400 psi, Mix and Pump 55 bbls 15.3
ppg tail cement without BMII @ 4 bpm 115 psi, Drop top plug pump 10 bbls H20, Line up rig pumps to displace with 399 bbls 9.4 ppg mud @ 7 bpm 940 psi @
1300 strokes slow rate to 5 bpm 970 psi @ 400 strokes slow rate to 3 bpm 940 psi, Bump plug @ 4337 strokes nit. pressure 970psi bump with 1500 psi. Hold
floats for 5 min Bleed off float held/ CIP 17:35 hrs
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/sa…Free Water (%) Density (lb/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
String: Intermediate String 1 Cement
Job: DRILLING ORIGINAL-<jobsubtyp> 5/10/2…
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2(+ & ( 7'&' '&77 '2 (7& ' +27' &+7 +2( &'('2*&+' 2$ 2$'(&$ *2++&( & ( '2+(%& /?=@+?;? )+,
2+(&'7 7&+ +&(7 '2 +&* +27%&$* +2 +&%*'2*+*& 2$ 27$*&+* *2+(7&%7 +&%' '2'((&'( /?=@+?;? )+,
2+'&7% 7(&$% (7&'* '2 ' &7 +2$('&7 +2+'$&*'2*'7& 2$ 27 '&( *2+$ &%( '&$ '2'$&'( /?=@+?;? )+,
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2 $+&$( 7&7 7$&($ '2 $%&% +2$ & ( +2 ( &7%'2*$$&7% 2$ 27(7&* *2 '& $ *&7 '2%'7&' /?=@+?;? )+,
2 7&$ 7&7 7 &'+ '2 ($&% +2$ 7&( +2 $*&7'2 +&* 2$ 27+& % *2% (&7 '& '27+&+' /?=@+?;? )+,
2%% &$ 7&7$ 7'&%$ '2 +'&'' +2$*$&7' +2%77& '2 + &(' 2$ 27+& + *27* &+ +& + '277$&$+ /?=@+?;? )+,
27% &( 7+&( 7&( '2 '%&+ +2$' &7 +277 &$'2 '$&$ 2$ 27' &*( *2$*+&'$ +&%7 '2$ %&%( /?=@+?;? )+,
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%2+ (&(* %%&7 % &%( '2 $$&% +27 & % '2+*%& '2 (+&* 2$ 2$(7& % 2'('& +& * *2+* &7' /?=@+?;? )+,
%2'* &% %7&( %+&7% '2%$&$% +27*&% '2''7&7 '2 ++& % 2$ 2$'*&++ 2'$*&*$ '&77 *2'+&* /?=@+?;? )+,
%2**(&%% %%&%% $&( '2%'$&% +27&7 '2*+ &%$'2 *+&* 2$ 2$ *&$( 2*7& '&$' *2'%+&%+ /?=@+?;? )+,
%2 '*&7' %%& $ & + '2% $&%$ +2%%%&7 '2 (&$('2 +&*$ 2$ 2(((&++ 2 &$7 +& 7 *2*+$&+ /?=@+?;? )+,
%2 '(&'' %7&'' *&( '2%%$&% +2%'7&% '2 $ &% '2 7+&* 2$ 2('$&$' 2 (& ( +&%7 *2*7'&( /?=@+?;? )+,
%2%+*&+( %7&$$ $&$ '2%$7&% +2 $*&$* '2 % &$7'2%((&7% 2$ 2(7'&7+ 2%'&' *&'( *2 '&7' /?=@+?;? )+,
%277&*' %$&*$ &7* '27 &%% +2 * &% '2% &'7'2%7&*% 2$ 2''& 27($&'* *&'+ *2 % &' /?=@+?;? )+,
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72'7 &* 7*&( '$&' '27$+&$7 +2+ $& ' *2 (&% '2%$ & 7 2$ 2 +'&(7 2+&* (&7' *2%''&' /?=@+?;? )+,
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72 %'& 7*&+ '7&+( '2$& +2*&%* *2+%7&('27*&+ 2$ 2 7&$ 2'+%& ( & *2% +&' /?=@+?;? )+,
72 7&*7 7*&77 ' &%+ '2$+(& +2('$&%( *2'' & $'27+'&+ 2$ 2%**&*+ 2'7*&*% & $ *2%%*& 7 /?=@+?;? )+,
72% +&' 77&'* ' &$ '2$+ &( 2$ *&+* *2'$&( '27+7&% 2$ 27+(&'' 2*'$&'( '&%$ *2%7*&77 /?=@+?;? )+,
727 &7( 77& ' & 7 '2$+7& ( 2777&$ *2** &'7'27'&+( 2$ 27$ & 2*$'&$$ (&7$ *2%$ &' /?=@+?;? )+,
72$ (& 7 &* '*&(' '2$''&* 27&% *2 (& '27' & 2$ 2$%'&% 2 *7&' *&*+ *27('&$% /?=@+?;? )',
$2(**&$ 7*&( +7&7 '2$*+&(% 2%'&' *2 *$& %'27**&%% 2$ %2( *& 2 $ &$% &'* *27( &%$ /?=@+?;? )',
$2'$&7* 7 & +(&*+ '2$ (&% 2 * &+ *2 77& ''27 +&7% 2$ %2*(&$ 2 '*&+ 7&** *2%$ &'$ /?=@+?;? )',
$2+''& 7 &** +&* '2$ &+' 2 & 7 *2 *&$*'27 7&$' 2$ %2+'(&%7 2 $&%7 7& * *2%%*&* /?=@+?;? )',
$2'+7&+( 7%&* %&( '2$ &+7 2* +&* *2 '(&$'27 '&$7 2$ %2'+*&(+ 2 %*&$7 &%* *2%*&%+ /?=@+?;? )',
$2*+&% 77&+% '&%$ '2$ *&%% 2' $&*( *2 '$&% '27 %&*% 2$ %2*%& 2 7'&( '& ( *2%(+&7* /?=@+?;? )',
$2 &' 7$&++ & '2$ &7* 2+% &% *2 **&$'27 $& * 2$ %2 &* 2 7 &% +& + *2 $& % /?=@+?;? )',
$2 ($&$% 77&*% (& '2$ 7&%' 27&' *2 * &$''27%&*' 2$ %2 ( &+ 2 7%& % &*+ *2 *&% /?=@+?;? )',
$2%( &$' 7$&'$ (&7( '2$%(& * 2(7*&*' *2 *%&(*'27%'&+* 2$ %2%(+&* 2 7%&$7 (&$$ *2 & % /?=@+?;? )',
$2%$ &(( $(&%* (& '2$%(&** $$ &'% *2 *7&($'27%'&* 2$ %2%$&+( 2 77&+$ & * *2 +'&(* / =15A)*,
$27*+&$ $&+ (&' '2$ $& + $*7&*+ *2 *7&**'27%+&'+ 2$ %27'7&* 2 77&+ &++ *2*$$&77 /?=@+?;? ) ,
$2$' &'% $(&$+ ' %&% '2$ %&7* 7 &(* *2 * &7%'27%(& * 2$ %2$'& ( 2 7 &$ +&% *2* &7+ /?=@+?;? ) ,
(2(' &+$ $(&$ ' & '2$ &+ % &'* *2 *(& $'27 7&$ 2$ 72('&* 2 %7&$ +& *2'$ & + /?=@+?;? ) ,
(2($%& ' $&+ ' '& '2$ &( $*&'( *2 '*& 7'27 %&7( 2$ 72($+&+ 2 %+&*( +& ' *2' (&$( /?=@+?;? ) ,
(2$+& ' $&7* ' & ' '2$ +& ((&+' *2 ++& ('27 &' 2$ 727 &(7 2 $&** +&++ *2'('&' /?=@+?;? ) ,
(2+77& $(&77 '*$&+' '2$ (&'7 ( &$ *2 ( & ('27 '&(7 2$ 72+7(&+( 2 *+&%% +&%( *2+*+&*+ /?=@+?;? ) ,
(2'7+& % $&(+ '* &'' '2$ 7&7+ *'&% *2 7 & ''27 & + 2$ 72'%+&+% 2 ++&(' '&(% *2%7&$$ /?=@+?;? ) ,
(2*% &$7 $+&+ '*'&7 '2$ &+' '++& + *2 +&' '27 7&$' 2$ 72* '&+ 2 $%&(( +&7% *2+&'% /?=@+?;? ) ,
(2 %& $& ( '*&*' '2$ '& +'+&+ *2 '*&'27 &7 2$ 72 '&'+ 2 7&(+ +& *2(*+&% /?=@+?;? ) ,
(2 &' $&7 ''7&+' '2$ (&'* *'&'% *2 (&*7'27 '&(* 2$ 72 *&77 2 '*& '&'7 '2$%(&(7 /?=@+?;? ) ,
(2% &+ $+& '' & '2$*%&( & *2* *&+%'27*$&% 2$ 72%+7&%7 2*$ &%' +&7' '27$*&+* /?=@+?;? ) ,
(27 &'7 $+&' '' &$ '2$*'&'+ '(& + *2*+ &+*'27* &(+ 2$ 727 &+ 2* &$$ (&*% '27%& /?=@+?;? ) ,
(2$ &* $(&$7 '''&$+ '2$*(& & *2'7 &('27*'&+ 2$ 72$((&7+ 2* &( +& $ '2%'$&+ /?=@+?;? ) ,
2(* & $(&7% ''+&77 '2$'$&( +(&%+ *2'*+&'%'27*&% 2$ 72$7 & 2'%+&% &( '2 $&%* /?=@+?;? ) ,
2*(&+ $&$ ''*&7' '2$'%&'' +7 & ( *2'(&$'27*(&(' 2$ $2( $&* 2''(&7 +& '2 7+&* /?=@+?;? ) ,
2+' &'7 $&++ ''7&+ '2$' &'+ '%+&$ *2+ '&+7'27'7&(+ 2$ $2 & 2+$+&+' '& $ '2 ( & ' /?=@+?;? ) ,
2''(&'' $(&(+ ''$&$ '2$'*&'( * &*+ *2++7&7''27'%&(( 2$ $2+**&'* 2+ %&(* & '2*'& /?=@+?;? ) ,
2*+ &(7 77&$$ '*+&%( '2$' & (&$ *2$%&$('27'%&7 2$ $2'''& 2++ &'7 '&7 '2' (&( /?=@+?;? ) ,
2 $&*% 7%&$( '**&'( '2$'%& 7 *&*' *2%&('27*(&'7 2$ $2*+'&7* 2$%&7* +&( '2+$& % /?=@+?;? ) ,
2 '&+' 7$& '**& '2$*(&(7 %'&%' *2* &$7'27*+&%7 2$ $2 '&$+ 2%&$7 &'7 '2++*& /?=@+?;? ) ,
2%(7&$7 $(&7* '* &$ '2$*(&(7 7+*&% *2+&(*'27*+&%7 2$ $2 ( &* 2* &+% &7 '2 &7* /?=@+?;? ) ,
27(*&(( $(&$7 '* &*$ '2$'7& % $ &+$ *2($%&7('27*&+% 2$ $2 $7&( 2++&+% &'7 '2($(& /?=@+?;? ) ,
2$((&(+ $(&$ '* &7* '2$' &$$ 2(($&%( *2(% & '27'$& $ 2$ $2%$&+7 2($$&' (&'% '2(+*&%% /?=@+?;? ) ,
2$$'&* $(&% '*%& ' '2$' & % 2((&7 *2( &('27'7&'% 2$ $277+&+ 2(%%&$% (&7% +2$ &'* /?=@+?;? ) ,
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+2(7'&$ $(& ( '*%&*% '2$'*&% 27$&$ *2(' & ('27'%&* 2$ $2$%(&* 2( %&%' (&+$ +2$((&+ /?=@+?;? ) ,
+27+&($ $(&*$ '* &%' '2$''&7 2+7*&7* *2('& ('27' & 2$%(2( &7% 2(' &(' (&% +27''&* /?=@+?;? ) ,
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+2'%&% $(&+$ '*7&%$ '2$'+&* 2* $&$* '2$%+&'+'27' & 2$%(2+ (& ( 2$$+&+* &%$ +2%( & /?=@+?;? ) ,
+2* & $(&(+ '*$&( '2$'+&+( 2 +&( '2$ *&+$'27'*&$( 2$%(2'*+& 2$%'&** (&*( +2 *'&*$ /?=@+?;? ) ,
+2 $&%$ 7$& * ' (&(* '2$'+& % 2 *& '2$'%&+('27' &+% 2$%(2*' &( 2$ & $ &% +2 7+&'7 /?=@+?;? ) ,
+2 *&7' 7$& ' (&*7 '2$''&+% 2%*7&'' '2$+&+'27' &$% 2$%(2 +7& ' 2$'7&%* (&*% +2 +& + /?=@+?;? ) ,
+2%*$& $ 7$&$+ '*$&$+ '2$''& 27*&% '2$(*&$$'27' &' 2$%(2 +&% 2$+&7* (& 7 +2* (&$% /?=@+?;? ) ,
+27*'& ( $(& * ' +&$( '2$''&+( 2$'*& '27$(&$ '27' &$( 2$%(2%*& 7 2$(%&(' '&+ +2*(+&'* /?=@+?;? ) ,
+2$*(&'7 $(&7* ' *&( '2$'&$ +2('(&%$ '27%$&$ '27'*& 2$%(27(& + 27$ &+ &++ +2'**&% /?=@+?;? ) ,
'2('*&$% $(&*% ' +&(% '2$'(&7% +2+*& 7 '27 7& *'27''& % 2$%(2$(*&*( 277'&( +&* +2+7%&$+ /?=@+?;? ) ,
'2'(&( $&+$ '*$&(* '2$+$&* +2+7&* '27 +&$*'27'+& 2$%(2$$7&(* 27 & 7 '&'( +2++%& + /?=@+?;? ) ,
'2++*&$( $(& % ' (& + '2$+%&%$ +2'&%$ '27' &+('27'(&*$ 2$%2($&++ 27*$&% &%$ +2 &' /?=@+?;? ) ,
'2'$&*$ $&'+ '*$&(% '2$+ &* +2*(*&77 '27$& +'27+7&7* 2$%27*& 27'&%' &%7 +2( &' /?=@+?;? ) ,
'2*+&%% $&* '*%&* '2$+'&77 +2*$ &7 '27((& '27+ & 7 2$%2+% &+$ 27+&( &%' +2(*'&+$ /?=@+?;? ) ,
'2 ( &$ $(&$ '* & '2$+&$' +2 7%&7 '2%%$&(%'27+*& ' 2$%2' &%7 2%7$&%% & ( 2$%7&7 /?=@+?;? ) ,
'2 (+&( $(&$ '*'&+% '2$+(&'$ +2 %$& % '2% *&('27+'&($ 2$%2* 7&+% 2% '&$ '&(* 2$&+7 /?=@+?;? ) ,
'2 $ & ( $(& ' '*'&+$ '2$$&% +2%%(&(+ '2%+ &7*'27+&7% 2$%2 *7&*7 2%' &(* (&* 27*+& ' /?=@+?;? ) ,
'2%$&'+ 7$& '* &'$ '2$$&*+ +27 &' '2%(&+ '27++&+ 2$%2 '$& 2%($& $ +& * 2%%*&%+ /?=@+?;? ) ,
'277*&7 77&+* '**&%$ '2$+& +2$ & 7 '2 %%&$'27+*&+ 2$%2%+$&% 2 7*&7$ &% 2%(7&%( /?=@+?;? ) ,
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*2 $&'$ 77& ''$&%( '2$'& '2++'&$ '2 $'&'27''&7 2$%+2(((&*$ 2 $7& 7 +&( 2 ((&' /?=@+?;? ) ,
*2+ '& 7 7$&(+ ''7& ' '2$''&* '2'&% '2 $& *'27' &7* 2$%+2(77&$ 2 *&+$ &' 2*+%&(% /?=@+?;? ) ,
*2' $&%$ 7$&($ ''7& ( '2$'*&%+ '2*((& 7 '2 +*&''27'%&*+ 2$%+2%%&'$ 2 +7&'+ (&(7 2' &7( /?=@+?;? ) ,
*2* &( 7$& 7 ''7&'( '2$' &% '2*7$&+ '2*7$&+*'27'7&* 2$%+2+ & % 2*$+& ' (& 2+%%&* /?=@+?;? ) ,
*2 (&$ $(& % ''7& '2$' & * '2 %%& ( '2* '&$ '27'7&+* 2$%+2' '&% 2* & + (&$ 2+(+&*+ /?=@+?;? ) ,
*2 * & ( $&'$ ''7&( '2$''&$ '2 &(+ '2*7&*+'27' & 2$%+2**&7' 2*+(&+ (&7% 2+%&*' /?=@+?;? ) ,
*2%*(&(' $+& + ''$& '2$'(& ( '2% *&' '2'7*&'*'27''&'( 2$%+2 +$& * 2'7 &* +&' 2( '&7 /?=@+?;? ) ,
*27'*& % $+&'7 ''7&'* '2$+ &*% '27*+&'$ '2' (&* '27+$&% 2$%+2 %& 2' (&7' &* $7(&'7 /?=@+?;? ) ,
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27&'+ $(&7* ''%&7' '2$+(& *2( &7( '2+*7&(''27+'&+ 2$%+277&* 2+* &+* +& 7 % $&*7 /?=@+?;? ) ,
2+($&%% $(& % '*&(% '2$$&*' *2$+&*+ '2+ &$*'27++&' 2$%+2$ &*7 2+'&** '& 77&7% /?=@+?;? ) ,
2+$$&$' $&*$ '*(& '2$%&7 *2+%%&** '27 &$7'27+(& 2$%'2( &+* 27+&%$ &*% +(&*+ /?=@+?;? ) ,
2'$(&'$ $&$( '*+&% '2$ &* *2' '&(( '2 &% '27%&7* 2$%'2' & 2 +&7 +&'+ +&'' /?=@+?;? ) ,
2*7'&* $(&7( '*& * '2$+&$ *2* &* '2+%&$ '27 & 2$%'2++*&*' 2+'&'' &'+ *7'&'+ /?=@+?;? ) ,
2 % &' $(&( '*&'$ '2$+&+% *2 '7& '2($7&%''27*&$% 2$%'2'& $ 2($'&'$ (&7 **&' /?=@+?;? ) ,
2 &+ $(&'$ '*&( '2$&$+ *2 +'&%( '2( $&%*'27*& + 2$%'2'$ &*$ 2( '&% (& % '* & ' /?=@+?;? ) ,
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2+'&*7 $(&(+ ''$&+* '2$(%& + 2'$&+ +277'&'7'27(&'+ 2$%'2$(&'$ *27%'&( (&'' %+& ' /?=@+?;? ) ,
2'( &( $(&( ''$&% '2$(%& 2++*&$ +27 &+%'27(&+ 2$%'2$$ &7% *27*(&+$ (& *'&+ /?=@+?;? ) ,
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t >>ED W/η^ Zs/ KZ Zη&/ >ED ^ Zs/ ^Z/Wd/KE >/s Z> ^Z/Wd/KE ddzW d >K'' K>KZWZ/Ed^ Ɛ1C-156 50-029-23750-00-00 223-023 KUPARUK RIVER MWD/LWD/DD VISION SERVICES FINAL FIELD 1dƌĂŶƐŵŝƚƚĂůZĞĐĞŝƉƚͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺ yͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺͺWƌŝŶƚEĂŵĞ ^ŝŐŶĂƚƵƌĞ ĂƚĞWůĞĂƐĞƌĞƚƵƌŶǀŝĂĐŽƵƌŝĞƌŽƌƐŝŐŶͬƐĐĂŶĂŶĚĞŵĂŝůĂĐŽƉLJƚŽ^ĐŚůƵŵďĞƌŐĞƌ͘sdƵŽŶŐΛƐůď͘ĐŽŵ^>ƵĚŝƚŽƌͲdƌĂŶƐŵŝƚƚĂůZĞĐĞŝƉƚƐŝŐŶĂƚƵƌĞĐŽŶĨŝƌŵƐƚŚĂƚĂƉĂĐŬĂŐĞ;ďŽdž͕ĞŶǀĞůŽƉĞ͕ĞƚĐ͘ͿŚĂƐďĞĞŶƌĞĐĞŝǀĞĚĂŶĚƚŚĞĐŽŶƚĞŶƚƐŽĨƚŚĞƉĂĐŬĂŐĞŚĂǀĞďĞĞŶǀĞƌŝĨŝĞĚƚŽŵĂƚĐŚƚŚĞŵĞĚŝĂŶŽƚĞĚĂďŽǀĞ͘dŚĞƐƉĞĐŝĨŝĐĐŽŶƚĞŶƚŽĨƚŚĞƐĂŶĚͬŽƌŚĂƌĚĐŽƉLJƉƌŝŶƚƐŵĂLJŽƌŵĂLJŶŽƚŚĂǀĞďĞĞŶǀĞƌŝĨŝĞĚĨŽƌĐŽƌƌĞĐƚŶĞƐƐŽƌƋƵĂůŝƚLJůĞǀĞůĂƚƚŚŝƐƉŽŝŶƚ͘η^ĐŚůƵŵďĞƌŐĞƌͲWƌŝǀĂƚĞPTD: 223-023 T37853Kayla JunkeDigitally signed by Kayla Junke Date: 2023.07.18 09:11:58 -08'00'
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From:Warren, Abby
To:Guhl, Meredith D (OGC)
Cc:Hobbs, Greg S
Subject:1C-156 PTD(#223-023)
Date:Monday, May 1, 2023 1:41:50 PM
Hi Meredith
As discussed. The correct legal description for the top of the horizon and TD are listed below
Top of Productive Horizon 2715' FSL, 4610‘ FEL , S7 T11N R11E, UM
NAD 1927
Northings: 566601
Eastings: 5967712
Measured Depth, RKB:9670’
Total Vertical Depth, RKB:3972’
Total Vertical Depth, SS:3875’
Total Depth (Toe)1859' FSL, 2384' FEL, S36 T12N R10E, UM
NAD 1927
Northings: 563829
Eastings: 5977391
Measured Depth, RKB:19761’
Total Vertical Depth, RKB:3910’
Total Vertical Depth, SS:3813’
Apologies!
Thanks,
Abby Warren
Staff Drilling Engineer
C: 907-240-9293
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: Kuparuk River, West Sak, 1C-156
ConocoPhillips
Permit to Drill Number: 223-023
Surface Location: 1489’ FNL, 1026’ FWL, S12 T11N R10E
Bottomhole Location: 233’ FSL, 4025’ FEL, S36 T12N R10E
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 April, 2023. 26
Brett W.
Huber, Sr.
Digitally signed by Brett W.
Huber, Sr.
Date: 2023.04.26 11:51:25
-08'00'
Initial BOP test to 5000 psig
Annular test to 2500 psig
Subsequent BOP test to 3500 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 attached
Intermediate I cement evaluation ma use SonicScope under the attached Conditions of Approval
Surface casing LOT and annular LOT to the AOGCC as soon as available.
X
MDG 4/21/2023VTL 4/24/2023JLC 4/26/2023
4/26/2023Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr.
Date: 2023.04.26 11:51:50 -08'00'
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'
<ZhϭͲϭϱϲ
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.
From:Warren, Abby
To:Guhl, Meredith D (OGC)
Cc:Davies, Stephen F (OGC); Hobbs, Greg S
Subject:RE: [EXTERNAL]KRU 1C-156 (PTD #223-023) Questions
Date:Tuesday, April 11, 2023 8:13:54 AM
Attachments:image001.png
1C-156 Area of Review rev1.pdf
Hi Meredith,
I had our directional company rerun their scan and they found that they had missed a few wells. I apologize for that, thank you for pointing it out. I have updated the AOR with
wells 1C-14, 25, 27, and 28. 1C-28 was right on the border with its penetration into the West Sak so I included for your reference. 1C-12 is outside of the quarter mile radius.
Please let me know if you have any questions.
Thanks
Abby
From: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>
Sent: Friday, April 7, 2023 12:13 PM
To: Warren, Abby <Abby.Warren@conocophillips.com>
Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>
Subject: RE: [EXTERNAL]KRU 1C-156 (PTD #223-023) Questions
Hello Abby,
Based on a review of well traces and West Sak formation tops, it appears there may be additional wells in the Area of Review not included in the original document. Could you
review the following wells, and if the wells should be included in the AOR, update and resubmit the AOR confirming cement over significant hydrocarbon zones, please?
Well Name PTD API
KRU 1C-12
196-
177 50-029-22719-00-00
KRU 1C-14
198-
017 50-029-22861-00-00
KRU 1C-25
199-
031 50-029-22941-00-00
KRU 1C-27
199-
043 50-029-22943-00-00
KRU 1C-28
205-
104 50-029-23270-00-00
Thank you,
Meredith
From: Warren, Abby <Abby.Warren@conocophillips.com>
Sent: Friday, March 31, 2023 9:54 AM
To: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>
Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>
Subject: RE: [EXTERNAL]KRU 1C-156 (PTD #223-023) Questions
Hi Meredith
Those numbers were pulled from wellhead data and producing wells. While they indicate the highest levels, when looking at drilling history we have not seen H2S while drilling
the West Sak on 1C.
In terms of monitoring, we have our H2S sensors on the rig which will be tested and the rig has a detailed emergency operating procedures if H2S is encountered while drilling
including escape packs staged around the rig. Personal monitors will be worn by core crew members.
Well specific items are communicated through drilling procedures and section plans.
Thanks
Abby
From: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>
Sent: Friday, March 31, 2023 7:41 AM
To: Warren, Abby <Abby.Warren@conocophillips.com>
Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>
Subject: RE: [EXTERNAL]KRU 1C-156 (PTD #223-023) Questions
Hi Abby,
Thank you for the information provided. In light of the elevated H2S levels recorded on this pad, what monitoring and mitigation measures will be implemented, and how will
those measures be communicated to rig personnel?
Thanks,
Meredith
From: Warren, Abby <Abby.Warren@conocophillips.com>
Sent: Thursday, March 30, 2023 1:32 PM
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.
To: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>
Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>
Subject: RE: [EXTERNAL]KRU 1C-156 (PTD #223-023) Questions
Hi Meredith
1. H2S is present in the producing wells on the pad. Below is a screenshot of h2S readings
2. The well will be preproduced for less than 30 days
3. Area of review is attached to this email. There were three wells within the ¼ mile review each of the wells have surface casing through the West Sak D and are cemented
to surface.
Please let me know if you have any other questions
Thanks
Abby
From: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>
Sent: Wednesday, March 29, 2023 9:33 AM
To: Warren, Abby <Abby.Warren@conocophillips.com>
Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>
Subject: [EXTERNAL]KRU 1C-156 (PTD #223-023) Questions
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 Abby,
I have a couple of questions that were not covered in the PTD package:
1. Is H2S expected on 1C pad? What levels of H2S have been recorded from wells on that pad?
2. Will KRU 1C-156 be pre-produced? How long do you anticipate pre-production lasting?
3. An Area of Review was not provided in the PTD package. Please provide the AOR discussion for any well that lies within ¼ mile of the planned KRU 1C-156 injector. The
discussion should include demonstration of cement-isolation for all significant hydrocarbon zones for any well within ¼ mile.
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.
WELL PERMIT CHECKLISTCompanyConocoPhillips Alaska, Inc.Well Name:KUPARUK RIV U WSAK 1C-156Initial Class/TypeSER / 1WINJGeoArea890Unit11160On/Off ShoreOnProgramSERField & PoolWell bore segAnnular DisposalPTD#:2230230KUPARUK RIVER, WEST SAK OIL - 490150NA1Permit fee attachedYesSurf Loc & Prod Int (Portion of) lie in ADL025649; TPI lies in ADL028242; TD lies in ADL025638.2Lease number appropriateYes3Unique well name and numberYesKUPARUK RIVER, WEST SAK OIL - governed by CO 406C4Well located in a defined poolYes5Well located proper distance from drilling unit boundaryYes6Well located proper distance from other wellsYes7Sufficient acreage available in drilling unitYes8If deviated, is wellbore plat includedYes9Operator only affected partyYes10Operator has appropriate bond in forceYes11Permit can be issued without conservation orderYes12Permit can be issued without administrative approvalYes13Can permit be approved before 15-day waitYesAIO 2C.08714Well located within area and strata authorized by Injection Order # (put IO# in comments) (ForYesKRU 1C-14, KRU 1C-15, KRU 1C-16, KRU 1C-19, KRU 1C-25, KRU 1C-27, KRU 1C-28,15All wells within 1/4 mile area of review identified (For service well only)YesPre-produced for less than 30 days, see email response page 76.16Pre-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)Yes81" conductor provided18Conductor string providedYesSC set at 1958 'MD19Surface casing protects all known USDWsYes245% excess20CMT vol adequate to circulate on conductor & surf csgNo21CMT vol adequate to tie-in long string to surf csgNoProductive interval completed with uncemented slotted liner with swell packers22CMT will cover all known productive horizonsYes23Casing designs adequate for C, T, B & permafrostYesRig has steel pits; all waste to approved disposal sites24Adequate tankage or reserve pitNA25If a re-drill, has a 10-403 for abandonment been approvedYesAnti-collision analysis complete; no major risk failures26Adequate wellbore separation proposedYes27If diverter required, does it meet regulationsYesMax reservoir pressure is 1728 psig(8.4 ppg EMW); will drill w/ 8.7-10.5 ppg EMW28Drilling fluid program schematic & equip list adequateYes29BOPEs, do they meet regulationYesMPSP is 1337 psig; will test BOPs to 3500 psig30BOPE press rating appropriate; test to (put psig in comments)Yes31Choke manifold complies w/API RP-53 (May 84)Yes32Work will occur without operation shutdownYesH2S measures required33Is presence of H2S gas probableYes34Mechanical condition of wells within AOR verified (For service well only)NoH2S present in reservoir, H2S measures required. See page 76.35Permit can be issued w/o hydrogen sulfide measuresYesLow risk of abnormal pressure in production leg. Moderate hole swabbing and Lost Circulation risks, LCM36Data presented on potential overpressure zonesNAmaterials on site. See pages 10 &11.37Seismic analysis of shallow gas zonesNA38Seabed condition survey (if off-shore)NA39Contact name/phone for weekly progress reports [exploratory only]ApprMDGDate4/13/2023ApprVTLDate4/26/2023ApprMDGDate4/13/2023AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDateJLC 4/26/2023
