Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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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-15750-029-23754-00-00223-03857"30.289"7/31/20252.28/7/2025
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:
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 21467'feet None feet
true vertical 3924' feet None feet
Effective Depth measured 21467'feet 10255'feet
true vertical 3924' feet 3903' feet
Perforation depth Measured depth
True Vertical depth
Tubing (size, grade, measured and true vertical depth) 4"
4-1/2"
10255' MD
11116' MD
3903' TVD
3976' TVD
Packers and SSSV (type, measured and true vertical depth) 10255' MD
N/A
3903' 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:
N/A
Sr Pet Eng: Sr Pet Geo: Sr Res Eng:
WINJ WAG
100
Water-BblOil-Bbl
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
N/A
Packer: P2P Packer
SSSV: None
Natalie Dye
Natalie.B.Dye@conocophillips.com
(907) 265-1027Senior Production Engineer
None
None
Tubing - Pump Insert
L-80
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)
880
Gas-Mcf
MD
1180
Size
154'
190 811290
450 440330
435
measured
TVD
9-5/8"
9-5/8"
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
223-038
50-029-23754-00-00
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:
ADL0025638, ADL0025649, ADL0028242
Kuparuk River Field/ West Sak Oil Pool
KRU 1C-157
Plugs
Junk measured
Length
ower Intermediate
Production
1918'
9305'
10356'
Casing
1847'
3985'
4-1/2"
1954'
11256'
21427' 3925'
2022'
154'Conductor
Surface
Intermediate
20"
13-3/8"
115'
2062' 1935'
Burst Collapse
Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov
By Grace Christianson at 7:53 am, Apr 29, 2025
Natasha Dye Digitally signed by Natasha Dye
Date: 2025.04.28 13:32:47 -08'00'
DSR-4/29/25
RBDMS JSB 050225
JJL 5/8/25
DTTMSTART JOBTYP SUMMARYOPS
3/24/2025 ACQUIRE DATA RIG UP SLB ELINE AND 3RD PARTY CRANE FOR WELLTEC TRACTOR
CONVEYED ESP INSTALL. RIH WELLTEC TRACTORS, STROKER &
WELLGRAB TOOS, ENGAGE ISO-SLEEVE FN AT 10,246' (10196' CCL DEPTH).
SET ANCHORS AND STROKE UP, ISO-SLEEVE FREE AT 5000 LBS. FLAG
WIRELINE AND POOH W/ ISO-SLEEVE. MAKE UP & TEST TOOLS FOR RU#2,
JOB IN PROGRESS.
3/25/2025 ACQUIRE DATA ***JOB CONTINUED FROM 24-MAR-2025***
PICK UP LUBRICATOR AND RIH W/ TANDEM TRACTOR, STROKER AND B-
SHIFTING TOOL. ENGAGE TRACTOR AT 4166', TRACTOR DOWN AND LATCH
NEXA SLIDING SLEEVE AT 10823.2'. ANCHOR AND STROKE UP, SLEEVE
SHIFTED OPEN AT 3100 LBS. TRACTOR DOWN AND DRIFT THROUGH
SLEEVE TO CONFIRM OPEN. HANG UP WHILE POOH IN B-PROFILE SUB AT
10270'. ABLE TO PASS FREELY AT 300 FPM. LAY DOWN LUBRICATOR AND
PREP TOOLS FOR NEXT RUN.
***JOB IN PROGRESS***
3/26/2025 ACQUIRE DATA ***JOB CONTINUED FROM 25-MAR-2025***
PICK UP LUBRICATOR AND RIH W/ WELLTEC TRACTOR, STROKER AND
ACCESS HIGH EXPANSION SHIFTING TOOL. LOCATE SLEEVE AND SHIFT
OPEN WITH STROKER TOOL AFTER MULTIPLE ATTEMPTS (INCONSISTENT
DATA ON SURFACE IN TERMS OF FORCE APPLIED DURING VARIOUS
PASSES) . TRACTOR PAST SLEEVE WITHOUT LATCHING TO CONFIRM
OPEN POSITION. POOH AND LAY DOWN LUBRICATOR. UPON INSPECTION
OF THE SHIFTING TOOL, 2 OF THE 4 KEYS REMAIN STUCK IN THE
DEPRESSED POSITION (USED A MALLET TO FREE STUCK KEYS), LEADING
TO UNCERTAINTY ON THE OPEN CONDITION OF THE SLIDING SLEEVE.
REDRESS TOOL TO BE RUN AGAIN IN THE MORNING WITH THE ADDITION
OF CENTRALIZERS.
***JOB IN PROGRESS***
3/26/2025 ACQUIRE DATA PREP FOR ELINE DEPLOYMENT JOB
3/27/2025 ACQUIRE DATA
***JOB CONTINUED FROM 26-MAR-2025***
PICK UP LUBRICATOR AND RIH W/ WELLTEC TRACTOR, STROKER,
CENTRALIZER AND HIGH EXPANSION SHIFTING TOOL. START RIH, SIT
DOWN GOING THROUGH TREE, ABLE TO PASS BY HAND SPANGING THE
TOOLSTRING. CONFIR W/ WELLTEC AND COP, DECISION MADE TO POOH
AND INSPECT SHIFTING TOOL. APPLY ELECTRICAL TAPE TO SHIFTING KEYS
AND ADD ADDITIONAL CENTRALIZER ABOVE. PT QTS, SWAB OPEN, RIH SIT
DOWN AGAIN WHILE RUNNING THROUGH TREE. HAND SPANG THROUGH.
CONFIR W/ WELLTEC AND COP, CONTINUE RIH. SIT DOWN IN DEVIATION AT
4106'. ENGAGE TRACTOR AND CONTINUE RIH. CORRELATE TO GAUGE
MANDREL AT 9788.5', AND ENGAGE TRACTOR AND CONTINUE GOING DOWN
AT 40 FPM TO 10,190'. PICK UP TO 10,050 AND TRACTOR DOWN AT 15 FPM
TO 10,190', REPEAT THIS PASS MULTIPLE TIMES AND NEVER SAW THE
SLEEVE, SHOWING CONFIRMATION SLEEVE WAS SHIFTED FROM PREVIOUS
DAY, POOH AND REDRESS TOOLS FOR NEXT RUN.
***JOB IN PROGRESS***
3/27/2025 ACQUIRE DATA
DEPLOYED 50' 3'' X 4.5'' BAKER ESP MOTOR @ 3515' RKB . READY FOR ELINE
3/28/2025 ACQUIRE DATA
STANDBY FOR ELINE
1C-157 Convert GL to ESP
Summary of Operations
3/28/2025 ACQUIRE DATA ***JOB CONTINUED FROM 27-MAR-2025***
RIH WITH WELLTEC TRACTOR/WELLGRAB/STROKER, LATCH ESP MOTOR
AT 4235'. RIH WITH MOTOR TO NO-GO AT 10,283'. PICKUP AND EXPERIENCE
OVER PULL OF 1800 LBS AND DID NOT LOCATE B-PROFILE. PULL UP TO
10,130' AND MAKE MULTIPLE ATTEMPTS TO TRACTOR DOWN TO THE NO-
GO NIPPLE SUCESSFULLY BUT UNABLE TO LOCATE B-PROFILE (13.5' FROM
NO-GO TO B-PROFILE). UNABLE TO SET MOTOR. CONFER WITH CONOCO
REP AND BAKER HUGHES REP. PULL TO 3400' (60 DEG INCLINATION) AND
RELEASE MOTOR FOR SLICKLINE. POOH.
***JOB IN PROGRESS***
3/29/2025 ACQUIRE DATA POOH AND STANDBY FOR ESP MOTOR RETRIEVAL AND REDRESS.
3/29/2025 ACQUIRE DATA
PULLED BAKER ESP MOTOR @ 3860'RKB . MOTOR SENT TO GET
REDRESSED. JOB IN PROGRESS
3/30/2025 ACQUIRE DATA
***JOB CONTINUED FROM 29-MAR-2025***
RIH WITH WELLTEC TRACTOR/WELLGRAB/STROCKER TO LATCH ESP
MOTOR AND PUSH TO NO-GO NIPPLE @10283'. MOVE UP, HAD OVERPULL
AT B-PROFILE, ENGAGE STROKER AND SHEAR @7000LBS.
MOVE UP 17', HAD 2ND OVERPULL, TRACTOR DOWN, TEST CONNECTION,
NO CONNECTION. ENGAGE STROKER, NO CONNECTION, ATTEMPT OVER
PULL AT TOP OF LOCATOR SLOT (REPEATED MULTIPLE TIMES
OVERPULLING AND THEN TRACTORING BACK DOWN TO TEST MOTOR
CONECTION). ON THE LAST OVERPULL ATTEMPT (PULLING UP TO CLOSE
MAX SAFE PULL OF THE CABLE), DISCOVERED WELLGRAB HAD RELEASED
FROM MOTOR (AUTO RELEASED). TRACTOR BACK DOWN TO LATCH BACK
ON TO MOTOR. PULL BACK UP TO TOP OF LOCATOR SLOT AND PULLED UP
TO 5000 LBF (2300 LB OVER PICKUP), TRACTOR DOWN AND CONFIRM
BAKER READING TO ESP FROM SURFACE. STROKE DOWN 2000 LBF.
CONFIRM GOOD READINGS FROM SURFACE. UNLATCH ESP. PULL UPHOLE
TO 10090'. CONFIRM GOOD CONTINUOUS READING. POOH. LAY DOWN
LUBRICATOR. REDRESS TOOLS. SECURE WL UNIT AND WELLHOUSE FOR
INCLEMENT WEATHER.
***JOB IN PROGRESS***
3/30/2025 ACQUIRE DATA DEPLOY BAKER 50'7'' X 4.5'' ESP MOTOR 4110' RKB . READY FOR ELINE
3/31/2025 ACQUIRE DATA PULL BAKER ESP MOTOR @ 4000' RKB . JOB IN PROGRESS
3/31/2025 ACQUIRE DATA
***JOB CONTINUED FROM 30-MAR-2025***
RIH WITH WELLTEC TRACTOR/STROKER/WELLGRAB TO RETRIEVE ESP
MOTOR. LATCH ON TO MOTOR, PULL TO 3700' AND MOTOR RELEASES.
POOH TO 3750' AND RELEASE MOTOR FOR SLICKLINE TO PULL. CONTINUE
POOH. LAY DOWN TO ALLOW SLICKLINE ON THE WELL.
***JOB IN PROGRESS***
4/1/2025 ACQUIRE DATA
***JOB CONTINUED FROM 31-MAR-2025***
STANDBY FOR SL TO DEPLOY ESP MOTOR. UNABLE TO RU DUE TO HIGH
WINDS.
***JOB IN PROGRESS***
4/1/2025 ACQUIRE DATA DEPLOYED 50.9' ESP MOTOR @ 3948' RKB . READY FOR ELINE
4/2/2025 ACQUIRE DATA
***JOB CONTINUED FROM 01-APR-2025***
RU AND RIH WITH WELLTEC TRACTOR-WELLGRAB-STROKER, RIH TO SET
ESP MOTOR. TAG ESP AT 4117'. ENGAGE TRACTOR TO 4166'. CONFIRM
WELLTEC LATCHED WITH GOOD UP WEIGHT. CONTINUE TRACTORING TO
9850'. LOG UP TO CORRELATE TO GAUGE MANDREL AT 9788'. CONTINUE
TRACTORING DOWN. SET ESP MOTOR AT AC PORT,.CONFIRMED GOOD
READING TO SENSORS FROM SURFACE. DISENGAGE MOTOR FROM WELL
GRAB. POOH. UNSTAB AND LAY DOWN. STANDBY FOR HALIBURTON SLK.
WELLTEC REDRESS THEIR TOOLS FOR NEXT RUN. HALIBURTON RIG
DOWN. WELLTEC PERFORM SURFACE CHECKS. STAB ON TO WELL.
PERFORM PT WITH LRS.
***JOB IN PROGRESS***
4/2/2025 ACQUIRE DATA
DEPLOYED 53.22' X 4.5'' SUMMIT ESP PUMP @ 3929'RKB . READY FOR ELINE
4/3/2025 ACQUIRE DATA
*** JOB CONTINUED ***
RIH WITH SUMMIT ESP PUMP, TAG TOP OF ESP MOTOR, SET ANCHORS AND
STROKE DOWN 2500 LBS (NO MOVEMENT), TEST MOTOR AT SURFACE
(GOOD), REALEASE FROM PUMP, POOH, JOB POSTPONED FOR RIG JOB.
4/6/2025 ACQUIRE DATA RIH W/ 4.5" PIIP PACKER (SN: CPP45011) XO TO STANDING VALVE WITH
STINGER SEAL. TAG TOP OF PUMP AT ~10,150' RKB. STROKE DOWN
STAGING UP TO 4K WITH NO ROD MOVEMENT, TO CONFIRM SEALS STUNG
INTO PBR. PUMP 60 BBLS DIESEL DOWN TBG AT 1 BPM. WAIT FOR DPU TO
SET PKR (MID-ELEMENT AT 10,147.6' RKB) AND POOH. CONFIRM SET ONCE
AT SURFACE. RD AND RU LRS TO PERFORM PT.
4/6/2025 ACQUIRE DATA
LOAD TBG 175 BBLS DSL
PT TBG TO 2000 PSI AFTER 10 MINUTES TBG PRESSURE AT 225 PSI.
JOB COMPLETE, READY FOR PLAN FORWARD
4/8/2025 ACQUIRE DATA
SET 4.5'' SLIP STOP CATCHER BELOW ST # 2 4000' RKB, INSTALLED 1'' 2000 #
TUBING SHEAR SOV w/ BK LATCH ST # 2 3917' RKB, INSTALLED 1'' DMY VLV
W/ BK LATCH ST # 1 1833' RKB, PERFORMED 1000 PSI DP HF TEST, GOOD
TEST, PULLED SS CATCHER 4000 ' RKB.. COMPLETE
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Install ESP1C-1574/6/2025bworthi1
Casing Strings
Csg Des OD (in)ID (in)Top (ftKB)
Set Depth
(ftKB)
Set Depth
(TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread
Conductor2019.12 39.3 154.3 154.394.00 L-80 Welded
Surface 13 3/8 12.42 39.3 2,061.7 1,934.6 68.00 L-80 Hyd563
Intermediate - Patch 9 5/8 8.76 36.2 1,954.0 1,846.7 43.50 L80 H563
*Lower* Intermediate 9 5/8 8.84 1,951.0 11,256.2 3,984.7 40.00 L80 HYD563
Production 4 1/2 3.96 11,071.5 21,427.0 3,925.0 12.60 L-80 HYD563
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
34.5
Set Depth…
11,116.0
Set Depth…
3,976.1
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)
34.5 34.5 0.00 Hanger 13.475 Vault MB242 13-1/2 x 4-1/2 tubing
hanger, 4.909" RH MCA top
Vault MB242 3.900
1,833.6 1,748.5 35.16 Mandrel 4.500 4-1/2" x 1" KBMG-1 GLM S/N
24393-12
SLB 4.5" x 1"
KBMG
3.865
3,917.6 3,045.5 70.80 Mandrel 4.500 4-1/2" x 1" KBMG-1 GLM S/N
24393-08
SLB 4.5" x 1"
KBMG
3.865
9,788.5 3,856.9 84.81 Gauge / Pump
Sensor
4.500 HES Opsis Gauge mandrel w/
Downhole gauge, 4-1/2" H563, L80
HES Opsis 3.923
10,181.1 3,895.3 84.27 Sliding Sleeve 5.500 5-1/2" GV Sliding sleeve 4 1/2"
Vamtop Box x 5 1/2", 23#, Vam FJL
Box
***SLEEVE OPENED 3/26/25***
Access
ESP
Sliding
Sleeve
3.910
10,187.4 3,895.9 84.26 Motor Shroud 5.500 Motor Shroud, 5 1/2" 23# Vam FJL
Pin x Pin
Access
ESP
4.548
10,192.2 3,896.4 84.26 Motor
Centralizer
5.500 Motor Cenralizer, 5 1/2" 23# Vam
FJL Box x Box
Access
ESP
3.894
10,194.0 3,896.6 84.26 Motor Shroud 5.500 Motor Shroud, 5 1/2" 23# Vam FJL
Pin x Pin
Access
ESP
4.548
10,198.8 3,897.1 84.27 Motor
Centralizer
5.500 Motor Cenralizer, 5 1/2" 23# Vam
FJL Box x Box
Access
ESP
3.893
10,200.6 3,897.2 84.27 Motor Shroud 5.500 Motor Shroud, 5 1/2" Vam FJL Box x
Pin
Access
ESP
3.894
10,205.4 3,897.7 84.27 Motor
Centralizer
5.500 Motor Cenralizer, 5 1/2" 23# Vam
FJL Box x Box
Access
ESP
4.548
10,207.1 3,897.9 84.27 Motor Shroud 5.500 Motor Shroud, 5 1/2" Vam FJL Box x
Pin
Access
ESP
4.548
10,211.9 3,898.4 84.28 Motor
Centralizer
5.500 Motor Cenralizer, 5 1/2" 23# Vam
FJL Box x Box
Access
ESP
3.894
10,213.6 3,898.5 84.28 Motor Shroud 5.500 Motor Shroud, 5 1/2" 23# Vam FJL
Pin x Pin
Access
ESP
4.548
10,218.4 3,899.0 84.28 Motor
Centralizer
5.500 Motor Cenralizer, 5 1/2" 23# Vam
FJL Box x Box
Access
ESP
3.893
10,220.2 3,899.2 84.29 Motor Shroud 5.500 Motor Shroud, 5 1/2" 23# Vam FJL
Pin x Pin
Access
ESP
4.548
10,225.0 3,899.7 84.29 Motor
Centralizer
5.500 Motor Cenralizer, 5 1/2" 23# Vam
FJL Box x Box
Access
ESP
3.894
10,226.8 3,899.8 84.29 Motor Shroud 5.500 Motor Shroud, 5 1/2" 23# Vam FJL
Pin x Pin
Access
ESP
4.548
10,231.7 3,900.3 84.30 Motor
Centralizer
5.500 Motor Cenralizer, 5 1/2" 23# Vam
FJL Box x B+H56:H85ox
Access
ESP
3.894
10,233.4 3,900.5 84.30 Motor Shroud 5.500 Motor Shroud, 5 1/2" 23# Vam FJL
Pin x Pin
Access
ESP
4.548
10,238.2 3,901.0 84.30 Motor
Centralizer
5.500 Motor Cenralizer, 5 1/2" 23# Vam
FJL Box x Box
Access
ESP
3.894
10,240.1 3,901.2 84.30 Motor Shroud 5.500 Motor Shroud, 5 1/2" 23# Vam FJL
Pin x Pin
Access
ESP
4.548
10,246.4 3,901.8 84.31 Annular
Connection
Port
5.950 Ann Connection Port, 5", 18# Vam
FJL Box x 4 1/2" 12.6# Vamtop Box
Access
ESP
3.860
10,270.03,904.184.33 Profile Sub 4.500 B-Profile sub, 4 1/2", 12.6#, L-80
Vamtop Box x Box
Access
ESP
3.913
10,283.5 3,905.4 84.35 No-go nipple 5.000 No-Go, 4 1/2" 12.6# Vamtop Box x 4
1/2" Hyd 563 Box
3.805
10,823.2 3,953.3 85.68 Sliding Sleeve 4.500 NEXA-2 Sliding sleeve, 3.813" X
Profile, 4-1/2", 12.6#, L80, H563
***SLEEVE OPENED 3/25/25***
SLB NEXA-2 3.813
10,966.5 3,964.2 85.46 Mandrel 4.500 HES Chemical injection mandrel, 4-
1/2" 12.6#, L80, H563
HESChemica
l
Injection
Mandrel,
HES
SAP#
1108136
3.908
11,031.7 3,969.5 85.22 Nipple X 4.500 3.813" XN Nipple, 3.75" no-go - Re-
Run
HES XN 3.75
no go
3.750
11,094.3 3,974.5 85.78 Locator Sub 5.500 Locator 5.5" OD Baker GBH-22 3.880
11,108.9 3,975.6 85.97 Seal Assembly 4.730 Seals Baker 192-47 3.890
11,112.0 3,975.8 86.01 Wireline Guide 4.500 HES Self aligning mule shoe HES 3.890
Top (ftKB)
10,144.0
Set Depth…
10,255.0
Set Depth…
3,902.6
String Max No…
4
Tubing Description
Tubing - Pump Insert
Wt (lb/ft)
877.00
Grade Top Connection ID (in)
HORIZONTAL, 1C-157, 4/21/2025 1:15:33 PM
Vertical schematic (actual)
Production; 11,071.5-21,427.0
*Lower* Intermediate; 1,951.0-
11,256.2
Wireline Guide; 11,112.0
Mandrel; 10,966.5
Sliding Sleeve; 10,823.2
Motor guide; 10,254.6
Plugarm assembly; 10,242.6
ESP Sensor; 10,239.0
ESP Motor; 10,222.0
Seal; 10,213.8
Seal; 10,205.6
Lower-mating Unit; 10,204.4
Upper-mating Unit; 10,204.0
Intake; 10,200.4
Intake; 10,196.8
Pump - ESP; 10,175.0
Sliding Sleeve; 10,181.1
Pump - ESP; 10,153.2
Discharge Head; 10,152.7
Polishbore receptacle; 10,150.6
Stinger Seal; 10,149.7
Standing Valve; 10,148.7
X-over; 10,148.3
4-1/2" P2P Packer; 10,144.0
Intermediate String 1 Cement;
3,422.0 ftKB
Mandrel; 3,917.6
Surface; 39.3-2,061.7
Intermediate - Patch; 36.2-
1,954.0
Mandrel; 1,833.6
Surface String Cement; 39.5
ftKB
Remedial; 39.2 ftKB
Conductor; 39.3-154.3
Hanger; 34.5
KUP PROD
KB-Grd (ft)
39.28
RR Date
8/2/2023
Other Elev…
1C-157
...
TD
Act Btm (ftKB)
21,467.0
Well Attributes
Field Name
WEST SAK
Wellbore API/UWI
500292375400
Wellbore Status
PROD
Max Angle & MD
Incl (°)
92.70
MD (ftKB)
18,974.76
WELLNAME WELLBORE
Annotation End DateH2S (ppm)DateComment
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)
10,144.0 3,891.6 84.30 4-1/2" P2P
Packer
3.760 2.000
10,148.33,892.084.30 X-over 3.2702.000
10,148.7 3,892.1 84.30 Standing Valve 3.720 0.000
10,149.7 3,892.284.30 Stinger Seal 3.730 2.250
10,150.6 3,892.2 84.30 Polishbore
receptacle
3.730
10,152.7 3,892.5 84.29 Discharge
Head
3.720 Summit
ESP
400X.
416 SS
10,153.2 3,892.5 84.29 Pump - ESP 4.000 125 Stages Summit
ESP
SF2250
AR,
NO15,
125S
10,175.0 3,894.7 84.28 Pump - ESP 4.000 76 Stages Summit
ESP
SFGH25
00XRX,
NO15,
76S
10,196.8 3,896.8 84.26 Intake 4.000 Summit
ESP
Gas
Separat
or, 400
HighFlo
w
10,200.4 3,897.2 84.27 Intake 4.000 Summit
ESP
Gas
Separat
or, 400
HighFlo
w
10,204.03,897.684.27 Upper-mating
Unit
3.750 AccessE
SP
08301-1
10,204.4 3,897.6 84.27 Lower-mating
Unit
3.750 AccessE
SP
08374-1
10,205.63,897.7 84.27 Seal 3.380 Summit
ESP
338,
BSBSL
10,213.8 3,898.5 84.28 Seal 3.380 Summit
ESP
338,
BSBSL
10,222.03,899.4 84.29 ESP Motor 3.750 AccessE
SP
A375,
4140,
250HP/2
900V/47
A
10,239.0 3,901.1 84.30 ESP Sensor 3.750 AccessE
SP/Zenit
h
67065-5
10,242.6 3,901.4 84.31 Plugarm
assembly
3.750 AccessE
SP
07851-3
10,254.6 3,902.6 84.32 Motor guide 3.750 AccessE
SP
06505-2
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)
1,833.6 1,748.5 35.16 1 GAS LIFT DV BK 1 4/8/2025SLBOther 0.000
3,917.63,045.5 70.80 2 GAS LIFT SOVBK 1 4/8/2025 2000#SLB Other 0.000
Cement Squeezes
Top (ftKB)Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB)Des Com
Pump Start
Date
39.6 2,062.0 39.5 1,934.8 Surface String
Cement
6/19/2023
3,422.0 11,256.2 2,847.3 3,984.7 Intermediate
String 1
Cement
Perform cement job f/ 9 5/8" int. csg as per
Halliburton program, Flood lines w/ 5 bpm H2O 278
psi, PressureTest lines t/ 4000psi, pump 77 bbls
tuned 10.5 ppg spacer @ 3.75 bpm/ 370 psi 12% f/o,
Drop #2 bottom plug, pump 370 bbls 14 ppg Lead
cmt @ 6 bpm 140psi 14% f/o, pump 138 bbls 15.3
ppg Tail cmt @ 4 bpm 135 psi 10% f/o, Drop top
plug, pump 20 bbls fresh H2O, line up t/ rig pumps t/
displace. w/ 827 bbls @ 6 bpm 207 psi 14% f/o f/
2620 stks. Cont. displacement @ 6 bpm 770 psi F/O
13% f/ 3200 strokes, Slow rate t/5 bpm 855 psi f/700
strokes, Slow rate t/4 bpm 887 psi f/240 strokes,
Slow rate t/3 bpm @ 847 psi, Bump plug @ 7010
strokes pressure up to 1380 psi hold f/ 5 min. Bleed
off/ check floats good. Cement in place at 1340 hrs
7/4/2023
39.21,890.039.21,794.6 Remedial Cement from stage tool to surface 10/26/2024
HORIZONTAL, 1C-157, 4/21/2025 1:15:37 PM
Vertical schematic (actual)
Production; 11,071.5-21,427.0
*Lower* Intermediate; 1,951.0-
11,256.2
Wireline Guide; 11,112.0
Mandrel; 10,966.5
Sliding Sleeve; 10,823.2
Motor guide; 10,254.6
Plugarm assembly; 10,242.6
ESP Sensor; 10,239.0
ESP Motor; 10,222.0
Seal; 10,213.8
Seal; 10,205.6
Lower-mating Unit; 10,204.4
Upper-mating Unit; 10,204.0
Intake; 10,200.4
Intake; 10,196.8
Pump - ESP; 10,175.0
Sliding Sleeve; 10,181.1
Pump - ESP; 10,153.2
Discharge Head; 10,152.7
Polishbore receptacle; 10,150.6
Stinger Seal; 10,149.7
Standing Valve; 10,148.7
X-over; 10,148.3
4-1/2" P2P Packer; 10,144.0
Intermediate String 1 Cement;
3,422.0 ftKB
Mandrel; 3,917.6
Surface; 39.3-2,061.7
Intermediate - Patch; 36.2-
1,954.0
Mandrel; 1,833.6
Surface String Cement; 39.5
ftKB
Remedial; 39.2 ftKB
Conductor; 39.3-154.3
Hanger; 34.5
KUP PROD 1C-157
...
WELLNAME WELLBORE
Originated: Delivered to:27-Mar-25Alaska Oil & Gas Conservation Commiss27Mar25-NR
! "# $$%$ !&$$'($)*%+
($)*%,- .WELL NAME API #SERVICE ORDER #FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPE DATE LOGGEDMT7-15 50-103-20885-00-00 224-037 Greater Mooses Tooth WL TTiX-PPROF FINAL FIELD 5-Feb-251H-106 50-029-23800-00-00 224-117 Kuparuk River WL TTiX-PPROF FINAL FIELD 22-Feb-251C-157 50-029-23754-00-00 223-038 Kuparuk River WL TTiX-FSI FINAL FIELD 27-Feb-25CD3-127 50-103-20634-00-00 211-005 Colville River WL Patch&Packer FINAL FIELD 8-Mar-251C-151 50-029-23497-00-00 213-123 Kuparuk River WL TTiX-FSI FINAL FIELD 12-Mar-253S-624 50-103-20868-00-00 223-104 Kuparuk River WL TTiX-FSI FINAL FIELD 22-Mar-25Transmittal Receipt//////////////////////////////// 0/////////////////////////////////
+
! 1 Please return via courier or sign/scan and email a copy to Schlumberger. " 2"3 +45
%TRANSMITTAL DATETRANSMITTAL #1
67
8 "
! -
+" 8 # !(3 . 8 ) "3
8 # !9
3 :
8" +8 6 8
8 " 8 # !;" " 3
-
3 " 3 ""+
3 +
< +3!%
T40238T40239T40240T40241T40242T402431C-15750-029-23754-00-00223-038Kuparuk RiverWLTTiX-FSIFINAL FIELD27-Feb-25Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.03.28 08:11:16 -08'00'
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
BOPE Test Report for:
Reviewed By:
P.I. Suprv
Comm ________KUPARUK RIV U WSAK 1C-157
JBR 12/12/2024
MISC. INSPECTIONS:
FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK:
ACCUMULATOR SYSTEM:MUD SYSTEM:
P/F P/F
P/FP/FP/F
Visual Alarm
QuantityQuantity
Time/Pressure
SizeQuantity
Number of Failures:0
Tested with 4 1/5 and 9 5/8 test joints, Precharge Bottles = 22 each all at 1000psi each.
Test Results
TEST DATA
Rig Rep:E. Potter / C. BaliOperator:ConocoPhillips Alaska, Inc.
Rig Owner/Rig No.:Doyon 25 PTD#:2230380DATE:10/21/2024
Operator Rep:A. Negusse / L. Shirley
Type Operation:WRKOV Annular:
250/2500Type Test:INIT
Valves:
250/2500
Rams:
250/2500
Test Pressures:Inspection No:bopBDB241022050849
Inspector Brian Bixby
Inspector
Insp Source
Related Insp No:
INSIDE REEL VALVES:
Quantity P/F
(Valid for Coil Rigs Only)
Remarks:
Test Time 5
MASP:
796
Sundry No:
324-510
Control System Response Time (sec)
Time P/F
Housekeeping:P
PTD On Location P
Standing Order Posted P
Well Sign P
Hazard Sec.P
Test Fluid W
Misc NA
Upper Kelly 1 P
Lower Kelly 1 P
Ball Type 2 P
Inside BOP 1 P
FSV Misc 0 NA
15 PNo. Valves
1 PManual Chokes
1 PHydraulic Chokes
0 NACH Misc
Stripper 0 NA
Annular Preventer 1 13 5/8 P
#1 Rams 1 9 5/8 P
#2 Rams 1 Blind/Shear P
#3 Rams 1 2 7/8x5 P
#4 Rams 0 NA
#5 Rams 0 NA
#6 Rams 0 NA
Choke Ln. Valves 1 3 1/8 P
HCR Valves 2 3 1/8 P
Kill Line Valves 2 3 1/8 P
Check Valve 0 NA
BOP Misc 0 NA
System Pressure P3000
Pressure After Closure P1950
200 PSI Attained P13
Full Pressure Attained P65
Blind Switch Covers:PYES
Bottle precharge P
Nitgn Btls# &psi (avg)P6@1995
ACC Misc NA0
P PTrip Tank
P PPit Level Indicators
P PFlow Indicator
P PMeth Gas Detector
P PH2S Gas Detector
0 NAMS Misc
Inside Reel Valves 0 NA
Annular Preventer P10
#1 Rams P6
#2 Rams P5
#3 Rams P5
#4 Rams NA0
#5 Rams NA0
#6 Rams NA0
HCR Choke P2
HCR Kill P2
9
9
9
9
9999
9
9
%23(7HVW'R\RQ
.58& 37'
$2*&&,QVSERS%'%
%23(7HVW'R\RQ
.58& 37'
$2*&&,QVS
ERS%'%
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: Replace Tubing
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 21467'feet None feet
true vertical 3924' feet None feet
Effective Depth measured 21467'feet 11072'feet
true vertical 3924'feet 3973'feet
Perforation depth Measured depth
True Vertical depth
Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 11116' 3976'
Packers and SSSV (type, measured and true vertical depth)11072' 3973'
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure:
13a.
Prior to well operation:
Subsequent to operation:
13b. Pools active after work: 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:
2062' 1935'
Burst Collapse
Intermediate
Liner
11219'
Casing
3985'11256'
21427' 3925'
2023'
154'Conductor
Surface
20"
13-3/8"
115'
measured
TVD
9-5/8"
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
223-038
50-029-23754-00-00
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:
ADL0025649, ADL0028242, ADL025638
Kuparuk River Field/ West Sak Oil Pool
KRU 1C-157
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)
N/A
Gas-Mcf
MDSize
154'
Well Shut-In
324-510
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: SL ZXP
SSSV: None
Brian Glasheen
brian.glasheen@conocophillips.com
(907) 265-6379 RWO Engineer
None
None
10355' 4-1/2"
Fra
O
s
6. A
PG
,
C
g
Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov
By Grace Christianson at 10:33 am, Nov 26, 2024
Digitally signed by Brian Glasheen
DN: OU=RWO's, O=ConocoPhillips, CN=Brian Glasheen, E=brian.glasheen@conocophillips.com
Reason: I am the author of this document
Location:
Date: 2024.11.25 13:53:52-09'00'
Foxit PDF Editor Version: 13.0.0
Brian Glasheen
Page 1/12
1C-157
Report Printed: 11/25/2024
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/5/2024
13:00
10/6/2024
01:00
12.00 MIRU, MOVE DMOB P Continue bridal up to UPR derrick.
Scope down and remove bridal lines.
Pin top drive. Unspool drawwork drill
line on rig floor. Secure energy track.
Raise C-section. Prep and lower upper
cattle chute. Staging rig to move to 1C
Pad.
0.0 0.0
10/6/2024
00:00
10/6/2024
12:00
12.00 MIRU, MOVE MOB P Stomping pipe shed - 50' turn. Put pipe,
power and pump module on
suspension. Strom sub off the well,
stage pipe shed to front of pad. Stomp
50' turn with sub. Hook up truck, turn
power module around at end of pad.
Hook jeep to sub, stage down well row.
Pull motor module ahead, load mats,
turn around pump module. Pull Pit
module off mats, continue loading mats.
Scratch / prep road to Pad 1C for rig
move. Start moving motor and pump
module to Pad 1C. Hook truck / pit jeep
up to pit and pipe shed module, move to
Pad 1C.
0.0 0.0
10/6/2024
12:00
10/7/2024
00:00
12.00 MIRU, MOVE MOB P Take trucks / jeep off pit and pipe shed
module return to 1H pad. Latch on to
sub module, move to 1C Pad. Stage sub
in line with well, level Pad. Lay down
herculite. Set mats for sub and stage
sub on mats. Remove jeep from sub,
stomp and spot sub over well. Move
casing module from 1H to 1C, while
continue setting mats. Spot casing
module on 1C. Stage pipe module in
line to crab over in line with sub.
0.0 0.0
10/7/2024
00:00
10/7/2024
09:00
9.00 MIRU, MOVE SVRG P Continue staging pipe module in line to
crab inline with sub, take pits off
suspension. Continue stomping pipe
module, take pump module off
suspension. Take motor module off
suspension. Pin pipe module and sub,
take casing module off suspension.
Stomp and set pit module, stomp casing
module. Stomp and set casing module.
Stomp pump RM and stab HP hoses to
pits. Stomp / spot power module. Lower
all landing. Lay herculite in courtyard.
Prep handling tools for inspection.
Remove drill line off dead man, remove
4" Vac line from pits.
Ball Mill Maintenance work - Inspect of
HDPE, Fuell genny and check oil, build
backups for HDPE, worked on billing.
0.0 0.0
10/19/2024
18:00
10/19/2024
20:00
2.00 MIRU, WELCTL RURD P RU lines in cellar to circulate SW around
and kill well. Pressure test lines to
1000PSI.
Initial pressures:
OA 130 PSI
IA 100 PSI
TBG 300 PSI
0.0 0.0
Rig: DOYON 25
RIG RELEASE DATE 10/31/2024
Page 2/12
1C-157
Report Printed: 11/25/2024
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/19/2024
20:00
10/20/2024
00:00
4.00 MIRU, WELCTL CIRC P Pump 70 BBLS 8.5ppg SW down IA and
up tbg to tiger tank at 4 BPM. SD and
line up to pump down tbg and up IA to
tiger tank. Displace hole to 8.5ppg SW
(350 bbls) at 4 BPM. Swap over and
pump 8.5 SW down tbg and up OA (45
bbls). Swap lines and circulate to pits
until 8.5ppg in/out..
0.0 0.0
10/20/2024
00:00
10/20/2024
00:30
0.50 MIRU, WELCTL KLWL P Circulate 4 BPM. monitoring gas 1700-
7100 units.
0.0 0.0
10/20/2024
00:30
10/20/2024
01:30
1.00 MIRU, WELCTL KLWL P Shut down observe diesel at shaker.
Bring pumps back on and observed
clean seawater at shaker as soon as we
start pumping.
0.0 0.0
10/20/2024
01:30
10/20/2024
02:00
0.50 MIRU, WELCTL KLWL P Shut down and close well in. Verify no
issues at surface. Bypass manifold and
pump down tbg and take returns up IA.
0.0 0.0
10/20/2024
02:00
10/20/2024
08:30
6.50 MIRU, WELCTL KLWL P Discuss with office plan forward and
decision made to attempt to get diesel
out of OA. Pump 50 BBLS seawater
down tbg and take returns up OA. Shut
down and monitor, Observed diesel at
shakers as soon as we shut down. Max
gas 10000 units. Pump 50bbls of
seawater and repeat. Max gas 8100
units. Pump 25 bbls. Shut down and
monitor flowback and gas. Observed
diesel as soon as we shutdown and max
gas 9100 units. Repeat.
0.0 0.0
10/20/2024
08:30
10/20/2024
09:00
0.50 MIRU, WELCTL OWFF P Shut down and monitor well, zero flow -
wait for good 30 min flow check - well
static.
0.0 0.0
10/20/2024
09:00
10/20/2024
10:30
1.50 MIRU, WELCTL RURD P Install BPV and test from below to 500
psi for 10 minutes - test good. Blow
down RD circulation hoses and
manifold.
0.0 0.0
10/20/2024
10:30
10/20/2024
12:00
1.50 MIRU, WHDBOP RURD P Nipple down well head tree and install
blanking plug.
0.0 0.0
10/20/2024
12:00
10/20/2024
20:30
8.50 MIRU, WHDBOP RURD P Nipple up BOP stack, choke and kill
hose. Stuff and seal Joes Box. Install
riser and flow line.
0.0 0.0
Rig: DOYON 25
RIG RELEASE DATE 10/31/2024
Page 3/12
1C-157
Report Printed: 11/25/2024
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/20/2024
20:30
10/21/2024
00:00
3.50 MIRU, WHDBOP BOPE P Test BOPE:
9 5/8" test joint- Annular 250/2500 PSI
for 5min each. UPRs 9 5/8 casing ram/
4" kill line/HCR Kill and Choke/ Manual
Choke and Kill/ 5" FOSVs #1 and #2 /
Dart valve to 250/2500 PSi for 5 min
each.
Blind/Shear rams- 250/5000 PSI for 5
min each
4 1/2"" test joint- Annular 250/2500 PSI
for 5 min each. LPRs 2 7/8" x 5" VBRs
250/2500 PSI for 5 min each.
Accumulator drawdown- ACC=3000
PSI. Manifold= 1500 PSI. 1900 PSI post
function. Nitrogen 6 bottle
average=1816 PSI. 200 PSI increase =
16 sec. Closing times - Annular= 20
sec.UPRs = 5 sec. LPRs = 5 sec.
Blind/Shears = 5 sec. Choke HCR = 2
sec. Kill HCR = 1.5 sec. Test PVT
Gain/Loss and flow out alarms. Test LEL
and H2S alarms.
Witnessed by AOGCC Brian Bixby.
0.0 0.0
10/21/2024
00:00
10/21/2024
01:00
1.00 MIRU, WHDBOP BOPE P Finish BOPE test:
Test annular and LPRs w/ 4 /2" test joint
- 250 psi low/2500psi high f/ 5 min each.
0.0 0.0
10/21/2024
01:00
10/21/2024
02:00
1.00 MIRU, WHDBOP BOPE P R/D testing equip. B/O landing joint with
blanking plug and L/D, B/D choke
manifold, choke and kill lines
0.0 0.0
10/21/2024
02:00
10/21/2024
04:30
2.50 COMPZN, RPCOMP RURD P Stage equipment to rig floor. PJSM. RU
sheave for ESP and chemical inj line
and secure to drill collar fingers in
derrick. Assemble TEC spooler and RU
double stack tongs.
0.0 0.0
10/21/2024
04:30
10/21/2024
05:30
1.00 COMPZN, RPCOMP RURD P Retrieve BPV from hanger. No pressure
observed.
0.0 0.0
10/21/2024
05:30
10/21/2024
07:00
1.50 COMPZN, RPCOMP RURD P MU landing joint to tbg hanger. MU
XOP,FOSV, pump in sub to landing joint.
0.0 0.0
10/21/2024
07:00
10/21/2024
08:45
1.75 COMPZN, RPCOMP CIRC P Circulate 50 bbls down tubing, up IA @
5 bpm, 350 psi. SD and monitor returns
SIMOPS prep floor and shed for pulling
pipe.
11,075.0 11,075.0
10/21/2024
08:45
10/21/2024
09:30
0.75 COMPZN, RPCOMP PULL P PU hanger off seat 115k PU. RD
circulating equipment. Pull hanger to rig
floor. 131k PU.
11,075.0 11,000.0
10/21/2024
09:30
10/21/2024
11:30
2.00 COMPZN, RPCOMP PULL P Terminate and secure Tec line, ESP line
and chem-inj line from hanger. L/D
hanger and landing joint. Secure ropes
to control lines and snake through
sheaves.
11,000.0 11,000.0
10/21/2024
11:30
10/21/2024
18:30
7.00 COMPZN, RPCOMP PULL P L/D 4.5" tubing F/11000' MD T/ 6945'
MD 125K PUW. Removing clamps and
spooling up ESP,Chemical injection and
TEC lines.
11,000.0 6,945.0
10/21/2024
18:30
10/21/2024
20:00
1.50 COMPZN, RPCOMP RURD P SD and swap out spool on spooling unit.
SimOps- Repair hooch around spooling
units that were ripped by wind.
6,945.0 6,945.0
Rig: DOYON 25
RIG RELEASE DATE 10/31/2024
Page 4/12
1C-157
Report Printed: 11/25/2024
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/21/2024
20:00
10/21/2024
20:30
0.50 COMPZN, RPCOMP PULL P L/D 4.5" tubing F/ 6945' MD T/ 6378' MD
125K PUW. Removing clamps and
spooling up ESP,Chemical injection and
TEC lines.
6,945.0 6,378.0
10/21/2024
20:30
10/21/2024
21:00
0.50 COMPZN, RPCOMP SVRG P Service rig and pipe skate. 6,378.0 6,378.0
10/21/2024
21:00
10/22/2024
00:00
3.00 COMPZN, RPCOMP PULL P L/D 4.5" tubing F/ 6378' MD T/4017' MD
125K PUW. Removing clamps and
spooling up ESP,Chemical injection and
TEC lines.
6,378.0 4,017.0
10/22/2024
00:00
10/22/2024
01:00
1.00 COMPZN, RPCOMP PULL P L/D 4.5" tubing F/ 4017' MD T/3408' MD
84K PUW. Removing clamps and
spooling up ESP,Chemical injection and
TEC lines.
4,017.0 3,408.0
10/22/2024
01:00
10/22/2024
02:00
1.00 COMPZN, RPCOMP WAIT P SD and swap out full spool on unit. 3,408.0 3,408.0
10/22/2024
02:00
10/22/2024
05:30
3.50 COMPZN, RPCOMP PULL P L/D 4.5" tubing F/ 3408' MD T/898' MD
54K PUW. Removing clamps and
spooling up ESP,Chemical injection and
TEC lines.
3,408.0 898.0
10/22/2024
05:30
10/22/2024
08:30
3.00 COMPZN, RPCOMP PULL P LD 4.5" tubing F/898' MD T 840' MD,
51K PUW, disconnect ESP cable,
secure cable to ropes, pull rope through
sheave and secure cable to spool, L/D 5
-1/2" jewelry using mouse hole
898.0 840.0
10/22/2024
08:30
10/22/2024
12:00
3.50 COMPZN, RPCOMP PULL P L/D 4.5" tubing F/840' MD t/ surface,
disconnect chemical-inj line and secure
to spool, R/D casing/tubing equipment
840.0 0.0
10/22/2024
12:00
10/22/2024
14:00
2.00 COMPZN, RPCOMP BOPE P Install test plug. Test Annular and LPR
w/ 5" test joint. 250/2500 psi for 5 min
ea. Retrieve test plug and install 9" ID
wear bushing.
0.0 0.0
10/22/2024
14:00
10/23/2024
00:00
10.00 COMPZN, RPCOMP ELNE P RU Eline. MU USIT tool string and
calibrate. RIH. Perform calibrations. Log
f/ 4019' to surface. LD tools.
SimOps:
Process 9 5/8' casing and 5" DP.
Housekeeping.
0.0 0.0
10/23/2024
00:00
10/23/2024
01:00
1.00 COMPZN, RPCOMP ELNE P LD USIT Log and tools per SLB. 0.0 0.0
10/23/2024
01:00
10/23/2024
02:30
1.50 COMPZN, RPCOMP ELNE P PJSM and MU Gyrodata Gyro tools and
test. Run in the hole to 1,500', Lost
communication to the gyro tools
-Notes: Voltage test tools through gyro
(good), Test continuity (good),
Troubleshoot continuity through eline
head
0.0 1,500.0
10/23/2024
02:30
10/23/2024
05:00
2.50 COMPZN, RPCOMP ELNE T POOH with Gyro tools and troubleshoot
at surface, Double check tools, swap
gyro swivel, test tools (good)
1,500.0 0.0
10/23/2024
05:00
10/23/2024
08:30
3.50 COMPZN, RPCOMP ELNE P RIH with Gyro tools to 3,900', POOH
and R/D wireline equipment. Clean and
clear floor
0.0 0.0
10/23/2024
08:30
10/23/2024
09:00
0.50 COMPZN, RPCOMP RURD P Pump through OA to confirm casing
anomaly at , RU to pump down
backside, Shut blinds, open hcr kill,
pump up to the tiger tank, 24bbls.
Notes: Did not observe diesel at
surface,
SIMOPS: PU Baker RBP, Test Packer
and other equipment
0.0 0.0
Rig: DOYON 25
RIG RELEASE DATE 10/31/2024
Page 5/12
1C-157
Report Printed: 11/25/2024
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/23/2024
09:00
10/23/2024
11:00
2.00 COMPZN, RPCOMP PULD P MU jetting sub and Single in hole with 5
stds 5" DP. MU 9 5/8" test packer and
single in hole to 962'. Test packer depth
506'.
0.0 962.0
10/23/2024
11:00
10/23/2024
12:30
1.50 COMPZN, RPCOMP PRTS P Set test packer and Test below packer
to 2500 PSI for 10 minutes. Good test.
Bleed off pressure 8 BBLs returned.
962.0 962.0
10/23/2024
12:30
10/23/2024
13:00
0.50 COMPZN, RPCOMP TRIP P Release packer and POOH to surface.
LD test packer.
962.0 0.0
10/23/2024
13:00
10/23/2024
15:45
2.75 COMPZN, RPCOMP PULD P MU 9 5/8" RBP and 9 5/8" test packer
RIH from derrick to 962'. Continue
singling in hole w/ 5" DP form pipe shed
to 2190'.
90k PU
93k SO
0.0 2,190.0
10/23/2024
15:45
10/23/2024
16:30
0.75 COMPZN, RPCOMP PACK P Set 9 5/8" RBP at 2185'. 30k OP and set
down 30k on RBP. Release from RBP.
2,190.0 2,190.0
10/23/2024
16:30
10/23/2024
17:00
0.50 COMPZN, RPCOMP CIRC P Circulate 5 BPM at 1 PSI. 100 BBLS. 2,190.0 2,190.0
10/23/2024
17:00
10/23/2024
18:00
1.00 COMPZN, RPCOMP PRTS P PU to 2151'. Set test packer and test
below to 3300 PSI for 10 minutes. Good
test. Bleed off. 2 BBLs returned.
2,190.0 2,190.0
10/23/2024
18:00
10/23/2024
20:00
2.00 COMPZN, RPCOMP TRIP P Release packer and POOH. LD Test
packer.
2,190.0 0.0
10/23/2024
20:00
10/23/2024
21:00
1.00 COMPZN, RPCOMP TRIP P MU mule shoe and RIH to 2103'. 0.0 2,103.0
10/23/2024
21:00
10/24/2024
00:00
3.00 COMPZN, RPCOMP OTHR P RU hopper to dump sand. Dump sand
down DP 10-15 minutes per sack.
2,103.0 2,103.0
10/24/2024
00:00
10/24/2024
08:00
8.00 COMPZN, RPCOMP OTHR P Dumping sand down DP with hopper. 50
sacks total dumped. Wait 30 minutes
and tag sand at 2119'. 66 ft above RBP
at 2185'.
2,103.0 2,119.0
10/24/2024
08:00
10/24/2024
09:00
1.00 COMPZN, RPCOMP CIRC P PU to 2065'. Circulate surface to
surface. 5 BPM/36 PSI. Flow check.
2,119.0 2,065.0
10/24/2024
09:00
10/24/2024
10:00
1.00 COMPZN, RPCOMP TRIP P POOH and LD muleshoe.. 2,065.0 0.0
10/24/2024
10:00
10/24/2024
11:30
1.50 COMPZN, RPCOMP TRIP P MU casing cutter and RIH to 1936'.
Space out and get cutter on depth at
1950'.
0.0 1,950.0
10/24/2024
11:30
10/24/2024
12:00
0.50 COMPZN, RPCOMP CPBO P Bring up pumps and open cutter blades.
Cut 9 5/8" casing at 1950'.
80 RPM
7k TQ
266 GPM
841 PSI
1,950.0 1,950.0
10/24/2024
12:00
10/24/2024
13:45
1.75 COMPZN, RPCOMP CIRC P Close annular and pump 150 bbls down
DP and out OA to tiger tank. 5 BPM/790
PSI.
Flow check and observe fluid breakout
and U-tubing. Close annular. No
pressure. Line up and open up to choke
no pressure.
1,950.0 1,950.0
10/24/2024
13:45
10/24/2024
15:30
1.75 COMPZN, RPCOMP CIRC P Open annular and circulate BU. Flow
check. Good.
1,950.0 1,950.0
10/24/2024
15:30
10/24/2024
17:00
1.50 COMPZN, RPCOMP TRIP P POOH and LD cutter. Blades looked
good.
1,950.0 0.0
10/24/2024
17:00
10/24/2024
18:00
1.00 COMPZN, RPCOMP WWSP P Retrieve wear bushing and 9 5/8"
packoff.
0.0 0.0
Rig: DOYON 25
RIG RELEASE DATE 10/31/2024
Page 6/12
1C-157
Report Printed: 11/25/2024
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/24/2024
18:00
10/24/2024
19:30
1.50 COMPZN, RPCOMP RURD P PU landing jt and MU to hanger. RU bail
extensions,FOSV and circulating line to
landing joint.
0.0 0.0
10/24/2024
19:30
10/24/2024
20:00
0.50 COMPZN, RPCOMP CIRC P PU hanger 3ft. 125k PU. Circulate BU,
6 BPM
90 PSI
0.0 0.0
10/24/2024
20:00
10/24/2024
21:30
1.50 COMPZN, RPCOMP PULL P Pull landing joint to rig floor. Observed
split in pup joint below hanger. LD
landing joint and hanger. Observed wear
in ID of hanger and pup joint. RD bail
extensions.
0.0 0.0
10/24/2024
21:30
10/25/2024
00:00
2.50 COMPZN, RPCOMP PULL P POOH LD 9 5/8" casing from 1910'.
Separate and number 1st 20 joints for
inspection. Did not visually see any
other anomalies.
0.0 0.0
10/25/2024
00:00
10/25/2024
02:00
2.00 COMPZN, RPCOMP PULL P POOH L/D 9-5/8" csg to surface. Total
LD= 47 jts and 1 cut JT-12.51'
0.0 0.0
10/25/2024
02:00
10/25/2024
03:00
1.00 COMPZN, RPCOMP RURD P R/D power tongs C/O elevators, drain
stack, set 12-5/16" ID wear ring
0.0 0.0
10/25/2024
03:00
10/25/2024
04:00
1.00 COMPZN, RPCOMP BHAH P Transfer BHA components to rig
floor.MU dress off BHA and RIH
0.0 100.0
10/25/2024
04:00
10/25/2024
06:00
2.00 COMPZN, RPCOMP TRIP P RIH w/ BHA to 1867'. 100.0 1,867.0
10/25/2024
06:00
10/25/2024
06:30
0.50 COMPZN, RPCOMP PULD P Wash down f/ 1867' to 1950'.
6 BPM
64 PSI
93k SO
1,867.0 1,950.0
10/25/2024
06:30
10/25/2024
08:30
2.00 COMPZN, RPCOMP CPBO P Dress off top of fish at 1949.82' MD, w/
5K WOB, 40 RPM, 55-190 PSI, 42%
F/O. new top of fish after dress off at
1951.35' MD
Dress top of fish f/ 1950' to 1951.35'.
5k WOB
40 RPM
3-7k TQ
254 GPM
55-190 PSI
1,950.0 1,951.4
10/25/2024
08:30
10/25/2024
09:00
0.50 COMPZN, RPCOMP CIRC P Circulate hole clean.
6 BPM
55 PSI
1,951.4 1,951.4
10/25/2024
09:00
10/25/2024
09:30
0.50 COMPZN, RPCOMP SVRG P Service rig. 0.0 0.0
10/25/2024
09:30
10/25/2024
11:00
1.50 COMPZN, RPCOMP PULL P POOH to BHA. 1,951.4 0.0
10/25/2024
11:00
10/25/2024
12:00
1.00 COMPZN, RPCOMP BHAH P LD BHA. 0.0 0.0
10/25/2024
12:00
10/25/2024
13:00
1.00 COMPZN, RPCOMP RURD P Drain stack and retrieve wear bushing. 0.0 0.0
10/25/2024
13:00
10/25/2024
14:30
1.50 COMPZN, RPCOMP RURD P RU casing handling equipment to run 9
5/8" casing.
0.0 0.0
10/25/2024
14:30
10/25/2024
21:30
7.00 COMPZN, RPCOMP PUTB P MU 9 5/8" overshot/patch and HES
cementer. RIH w/ 9 5/8" 43.50# H563
casing to 1940'
0.0 1,940.0
Rig: DOYON 25
RIG RELEASE DATE 10/31/2024
Page 7/12
1C-157
Report Printed: 11/25/2024
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/25/2024
21:30
10/25/2024
22:00
0.50 COMPZN, RPCOMP PUTB P Wash down f/ 1940' at 10 RPM/6k TQ, 1
BPM/35PSI. Engage 9 5/8" stump with
overshot at 1954' Observed pressure
spike as over shot engaged stump. SD
pumps and rotary. Set 75k down. Fully
engaged at 1955'. PU 50k overpull then
to 170k overpull. Slack off and set in
slips with 10k over.
140k PU before engaging stump.
1,940.0 1,954.0
10/25/2024
22:00
10/25/2024
23:30
1.50 COMPZN, RPCOMP RURD P RD Volant and casing handling
equipment. MU cement head and lines.
1,954.0 1,954.0
10/25/2024
23:30
10/26/2024
00:00
0.50 COMPZN, RPCOMP PRTS P Line up and attempt to test casing.
Swage below cement head leaking.
Bleed off and tighten.
1,954.0 1,954.0
10/26/2024
00:00
10/26/2024
01:00
1.00 COMPZN, RPCOMP PRTS P Work air out of system and pressure test
9 5/8" casing/overshot to 2000 PSi f/ 10
minutes. Good test.
1,954.0 1,954.0
10/26/2024
01:00
10/26/2024
01:30
0.50 COMPZN, RPCOMP CIRC P Stage up pumps in 500 PSI increments
and shift ES cementer open at 2660
PSI. Stage up rate to 6 BPM and
circulate 1.25 casing volume.
1,954.0 1,954.0
10/26/2024
01:30
10/26/2024
03:00
1.50 COMPZN, RPCOMP CMNT P PJSM. Load plug in cement head. Flood
lines and pressure test cement lines to
3500 PSI. Good test. Start batching up
cement.
1,954.0 1,954.0
10/26/2024
03:00
10/26/2024
05:00
2.00 COMPZN, RPCOMP CMNT P Pump 5 BBLs FW + 20 BBLs 15.7ppg
Neat AS1 cement + 102 BBLs 15.7ppg
PressureNet w/ 1 lb/bbl Cement + 295
BBLs 15.7 AS1 w/ 1 lb/bbl CemNet + 20
BBLs 15.7 ppg Neat AS1 cement. SD
and drop plug. Pump 10 BBLs FW w/
cement unit and swap over to rig to
displace. Displace at 6 BPM slow to 3
BPM last 20 BBLs. Plug down at 1314
stks 132 BBLs. Pressure up to 1950 PSI
to shift tool closed. Hold for 5 minutes.
Bleed off pressure and check for
flowback. No flow. Full returns
throughout job. 190 BBLs cement back
to surface.
Cement in place at 04:50 hrs 10/26/24.
1,954.0 1,954.0
10/26/2024
05:00
10/26/2024
14:00
9.00 COMPZN, RPCOMP WOC P Flush BOPs, function annular. Jet flow
line,clean Joe's box, possum belly,
cement lines and demco valves. Rig
down cement head. Clear IA valves,
WOC.
SimOps: Service rig top
drive,blocks,roughneck,IBOP,and
washpipe. Continue flushing lines with
black water. Prep to ND BOP.
0.0 0.0
10/26/2024
14:00
10/26/2024
17:00
3.00 COMPZN, RPCOMP NUND P ND wellhead. Raise Stack. Install
emergency slips per Vault. Set w/ 50k
tension. Slack off and cut 9 5/8" casing.
0.0 0.0
10/26/2024
17:00
10/26/2024
20:00
3.00 COMPZN, RPCOMP NUND P Lower stack and NU well head flange.
Install riser. Torque well head flange
bolts. Install 9 5/8" packoff. RILDS. Test
9 5/8" packoff to 3000 PSI for 15
minutes. Good test. Install 8.97" wear
bushing.
SimOps: Stage BHA to rig floor.
0.0 0.0
10/26/2024
20:00
10/26/2024
21:00
1.00 COMPZN, RPCOMP BHAH P PU and RIH w/ drill out BHA. 0.0 250.0
Rig: DOYON 25
RIG RELEASE DATE 10/31/2024
Page 8/12
1C-157
Report Printed: 11/25/2024
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/26/2024
21:00
10/26/2024
21:30
0.50 COMPZN, RPCOMP TRIP P RIH w/ drill out BHA to 1380'. 250.0 1,380.0
10/26/2024
21:30
10/26/2024
22:00
0.50 COMPZN, RPCOMP SVRG P Service rig. 1,380.0 1,380.0
10/26/2024
22:00
10/26/2024
23:00
1.00 COMPZN, RPCOMP TRIP P RIH f/ 1380 to 1855'. Tag cement at
1855'.
1,380.0 1,855.0
10/26/2024
23:00
10/27/2024
00:00
1.00 COMPZN, RPCOMP DRLG P Wash/Ream from 1855' to top of plug at
1890'. Drill out plug and ES cementer.
Wash and ream to 1945'
8 BPM
168 PSI
90 RPM
3k TQ
98k ROT
5-15k WOB
1,855.0 1,945.0
10/27/2024
00:00
10/27/2024
00:30
0.50 COMPZN, RPCOMP WASH P Wash/Ream 1945' to 2120'. SD pumps
Set 5k down on sand at 2121'.
8 BPM
170 PSI
90 RPM
3k TQ
105k ROT
1,945.0 2,121.0
10/27/2024
00:30
10/27/2024
01:30
1.00 COMPZN, RPCOMP DRLG P Dry drill f/ 2121' to 2126'. Drill at 1/2
BPM f/ 2126' to 2132' at 1/2 BPM 5k
WOB.
2,121.0 2,132.0
10/27/2024
01:30
10/27/2024
02:00
0.50 COMPZN, RPCOMP CIRC P Circulate BU.
10 BPM
260 PSI
2,132.0 2,132.0
10/27/2024
02:00
10/27/2024
03:00
1.00 COMPZN, RPCOMP TRIP P POOH to BHA. 2,132.0 350.0
10/27/2024
03:00
10/27/2024
04:00
1.00 COMPZN, RPCOMP BHAH P Rack back HWDP and LD BHA. Clean
magnets and junk baskets. Observe
cemet=nt plug and some metal in junk
baskets.
350.0 0.0
10/27/2024
04:00
10/27/2024
05:00
1.00 COMPZN, RPCOMP BHAH P MU wash over shoe BHA. RIH w/
HWDP and intensifier.
0.0 330.0
10/27/2024
05:00
10/27/2024
06:00
1.00 COMPZN, RPCOMP TRIP P RIH to 1877'. 330.0 1,877.0
10/27/2024
06:00
10/27/2024
06:30
0.50 COMPZN, RPCOMP TRIP P RIH f/ 1877' to 2066'. Dress off EZ
cementer at 1892'.
1,877.0 2,066.0
10/27/2024
06:30
10/27/2024
07:00
0.50 COMPZN, RPCOMP WASH P Wash down f/ 2066' to 2150'
7 BPM
2800 PSI
30 RPM
2.5k TQ
2,066.0 2,150.0
10/27/2024
07:00
10/27/2024
08:00
1.00 COMPZN, RPCOMP CIRC P Circulate 2 x BU.
7 BPM
2800 PSI
10 RPM
3k TQ
2,150.0 2,150.0
10/27/2024
08:00
10/27/2024
09:30
1.50 COMPZN, RPCOMP TRIP P POOH to BHA. 2,150.0 330.0
10/27/2024
09:30
10/27/2024
10:30
1.00 COMPZN, RPCOMP BHAH P Rack back HWDP. Clean and clear
magnets and junk baskets.
330.0 0.0
10/27/2024
10:30
10/27/2024
11:00
0.50 COMPZN, RPCOMP SVRG P Service rig. Change encoder on B drive
motor and reseal Joe's Box.
0.0 0.0
10/27/2024
11:00
10/27/2024
11:30
0.50 COMPZN, RPCOMP BHAH P MU and run back in hole w/ washover
shoe BHA.
0.0 330.0
Rig: DOYON 25
RIG RELEASE DATE 10/31/2024
Page 9/12
1C-157
Report Printed: 11/25/2024
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/27/2024
11:30
10/27/2024
12:30
1.00 COMPZN, RPCOMP TRIP P RIH f/ 330' to 2066' 330.0 2,066.0
10/27/2024
12:30
10/27/2024
13:30
1.00 COMPZN, RPCOMP WASH P Washdown and tag at 2150' w/ 8k.
Attempt to wash down f/ 2150'. No
success
8 BPM
3600 PSI
30 RPM
3k TQ.
2,066.0 2,150.0
10/27/2024
13:30
10/27/2024
14:00
0.50 COMPZN, RPCOMP CIRC P Circulate BU.
8 BPM
3600 PSI.
2,150.0 2,150.0
10/27/2024
14:00
10/27/2024
15:00
1.00 COMPZN, RPCOMP TRIP P POOH to BHA. 2,150.0 330.0
10/27/2024
15:00
10/27/2024
16:00
1.00 COMPZN, RPCOMP BHAH P Rack back HWDP. LD and cleanout junk
baskets and magnets,
330.0 0.0
10/27/2024
16:00
10/27/2024
16:30
0.50 COMPZN, RPCOMP BHAH P PU Junk mill BHA #8 and RIH to 353'. 0.0 353.0
10/27/2024
16:30
10/27/2024
17:30
1.00 COMPZN, RPCOMP TRIP P RIH to 2150'. 353.0 2,150.0
10/27/2024
17:30
10/27/2024
19:00
1.50 COMPZN, RPCOMP DRLG P Attempt to mill down f/ 2150'. No
success.
80 RPM
3k TQ
1-4 BPM
50 PSI.
3-20k WOB
2,150.0 2,150.0
10/27/2024
19:00
10/27/2024
19:30
0.50 COMPZN, RPCOMP CIRC P Circulate BU.
10 BPM
267 PSI
2,150.0 2,150.0
10/27/2024
19:30
10/27/2024
20:30
1.00 COMPZN, RPCOMP TRIP P POOH to BHA 2,150.0 350.0
10/27/2024
20:30
10/27/2024
21:00
0.50 COMPZN, RPCOMP BHAH P Rack back HWDP. Empty junk baskets
and inspect junk mill. Very little debris in
junk baskets. Observed 2" oval spot in
center of junk mill.
350.0 0.0
10/27/2024
21:00
10/27/2024
21:30
0.50 COMPZN, RPCOMP BHAH P MU Washover shoe/cleanout BHA and
RIH to 350'.
0.0 350.0
10/27/2024
21:30
10/27/2024
22:30
1.00 COMPZN, RPCOMP TRIP P RIH w/ BHA to 2150'. 350.0 2,150.0
10/27/2024
22:30
10/27/2024
23:00
0.50 COMPZN, RPCOMP WASH P Wash down to 2154'. PU 5' and repeat x
5.
6 BPM
2800 PSI
2,150.0 2,154.0
10/27/2024
23:00
10/27/2024
23:30
0.50 COMPZN, RPCOMP CIRC P Circulate BU
8 BPM
3620 PSI
2,154.0 2,154.0
10/27/2024
23:30
10/28/2024
00:00
0.50 COMPZN, RPCOMP TRIP P POOH to 1597'. 2,154.0 1,597.0
10/28/2024
00:00
10/28/2024
01:00
1.00 COMPZN, RPCOMP TRIP P POOH from 1597' to BHA. 1,597.0 350.0
10/28/2024
01:00
10/28/2024
02:30
1.50 COMPZN, RPCOMP BHAH P Clean magnets and junk baskets. LD
BHA.
350.0 0.0
10/28/2024
02:30
10/28/2024
04:00
1.50 COMPZN, RPCOMP TRIP P MU RBP retrieval tool and RIH to 2086'
MD.
0.0 2,086.0
Rig: DOYON 25
RIG RELEASE DATE 10/31/2024
Page 10/12
1C-157
Report Printed: 11/25/2024
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/28/2024
04:00
10/28/2024
04:30
0.50 COMPZN, RPCOMP FISH P Wash down from 2086' MD at 4 BPM.
Set 7k down at 2155' MD. PU to 20k
over. SO and set 7k down. Rotate at 10
RPM to release RBP. Let elements
relax. SO to 2160' MD to confirm
engaged and released. PU to 2145' MD.
2,086.0 2,145.0
10/28/2024
04:30
10/28/2024
05:00
0.50 COMPZN, RPCOMP CIRC P Circulate BU. No gas observed at BU.
8 BPM
105 PSI
2,145.0 2,145.0
10/28/2024
05:00
10/28/2024
05:30
0.50 COMPZN, RPCOMP OWFF P Flow check. Static. 2,145.0 2,145.0
10/28/2024
05:30
10/28/2024
07:00
1.50 COMPZN, RPCOMP TRIP P POOH to RBP. 2,145.0 20.0
10/28/2024
07:00
10/28/2024
08:00
1.00 COMPZN, RPCOMP BHAH P LD RBP and retrieval tool. 20.0 0.0
10/28/2024
08:00
10/28/2024
09:00
1.00 COMPZN, RPCOMP PRTS P RU and test casing to 2500 PSI for 30
minutes. Good test.
0.0 0.0
10/28/2024
09:00
10/28/2024
10:30
1.50 COMPZN, RPCOMP TRIP P RIH with mule shoe to 2430' MD. 0.0 2,430.0
10/28/2024
10:30
10/28/2024
11:00
0.50 COMPZN, RPCOMP CIRC P Circulate BU.
5 BPM
60 PSI
2,430.0 2,430.0
10/28/2024
11:00
10/28/2024
11:30
0.50 COMPZN, RPCOMP PULD P POOH LD DP from 2430' to 2125' MD. 2,430.0 2,125.0
10/28/2024
11:30
10/28/2024
12:00
0.50 COMPZN, RPCOMP CIRC P Circulate and pump slug. 2,125.0 2,125.0
10/28/2024
12:00
10/28/2024
15:00
3.00 COMPZN, RPCOMP PULD P POOH LD DP to surface. 2,125.0 0.0
10/28/2024
15:00
10/28/2024
15:30
0.50 COMPZN, RPCOMP CIRC P MU jetting sub and flush stack. Function
rams.
0.0 0.0
10/28/2024
15:30
10/28/2024
16:30
1.00 COMPZN, RPCOMP CIRC P Drain stack. Retrieve wear bushing. Jet
stack and function rams again.
0.0 0.0
10/28/2024
16:30
10/28/2024
17:00
0.50 COMPZN, RPCOMP CLEN P Clean and clear rig floor. 0.0 0.0
10/28/2024
17:00
10/28/2024
20:00
3.00 COMPZN, RPCOMP RURD P RU spools, spooling equipment and
handling equipment to run upper
completion. PJSM with all personnel.
0.0 0.0
10/28/2024
20:00
10/29/2024
00:00
4.00 COMPZN, RPCOMP PUTB P MU and RIH with 4-1/2" 12.50# H563
upper completion. MU TQ 3800 ft/lbs.
Drift with 3.82" drift on skate. Terminate
chemical injection line and pressure line
to 1400 PSI to check function of check
valve. Bleeed off to 500 psi and lock in.
Installing clamps on each joint.
0.0 858.0
10/29/2024
00:00
10/29/2024
01:30
1.50 COMPZN, RPCOMP PUTB P RIH with 4-1/2" 12.5# Hyd 563 upper
completion tubing from 857' to 1023'
MD. 3800 ft-lbs MU TQ. Drift tubing on
skate with 3.82" drift.
858.0 1,023.0
10/29/2024
01:30
10/29/2024
04:30
3.00 COMPZN, RPCOMP OTHR P Splice flat pack to ESP cable and test. 1,023.0 1,023.0
10/29/2024
04:30
10/29/2024
06:00
1.50 COMPZN, RPCOMP PUTB P RIH with 4-1/2" 12.5# Hyd 563 upper
completion tubing from 1023' to 1323'
MD. 3800 ft-lbs MU TQ. Drift tubing on
skate with 3.82" drift.
1,023.0 1,323.0
10/29/2024
06:00
10/29/2024
07:00
1.00 COMPZN, RPCOMP PULL P Pull tubing from 1323' to 1040' MD.
Install clamp across splice.
Run back in hole to 1323' MD.
1,323.0 1,323.0
10/29/2024
07:00
10/29/2024
08:00
1.00 COMPZN, RPCOMP OTHR P Terminate control line to gauge mandrel
and test connection to 10000psi for 10
minutes.
1,323.0 1,323.0
Rig: DOYON 25
RIG RELEASE DATE 10/31/2024
Page 11/12
1C-157
Report Printed: 11/25/2024
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/29/2024
08:00
10/29/2024
08:30
0.50 COMPZN, RPCOMP PUTB P RIH with 4-1/2" 12.5# Hyd 563 upper
completion tubing from 1323' to 1458'
MD. 3800 ft-lbs MU TQ. Drift tubing on
skate with 3.82" drift.
1,323.0 1,458.0
10/29/2024
08:30
10/29/2024
09:00
0.50 COMPZN, RPCOMP SVRG P Service rig. Change out coupler on
casing hydraulic unit.
1,458.0 1,458.0
10/29/2024
09:00
10/29/2024
17:00
8.00 COMPZN, RPCOMP PUTB P RIH with 4-1/2" 12.5# Hyd 563 upper
completion tubing from 1458' to 5940'
MD. 3800 ft-lbs MU TQ. Drift tubing on
skate with 3.82" drift. Checking
continuity on lines evey 1000'.
1,458.0 5,940.0
10/29/2024
17:00
10/29/2024
20:00
3.00 COMPZN, RPCOMP RURD P Swap out chemical injection line and
splice .
5,940.0 5,940.0
10/29/2024
20:00
10/30/2024
00:00
4.00 COMPZN, RPCOMP PUTB P RIH with 4-1/2" 12.5# Hyd 563 upper
completion tubing from 5940' to 8240'
MD. 3800 ft-lbs MU TQ. Drift tubing on
skate with 3.82" drift. Checking
continuity on lines evey 1000'.
5,940.0 8,240.0
10/30/2024
00:00
10/30/2024
00:30
0.50 COMPZN, RPCOMP PUTB P RIH with 4-1/2" 12.5# Hyd 563 upper
completion tubing from 8240' to 8518'
MD. 3800 ft-lbs MU TQ. Drift tubing on
skate with 3.82" drift. Checking
continuity on lines evey 1000'.
8,240.0 8,518.0
10/30/2024
00:30
10/30/2024
02:00
1.50 COMPZN, RPCOMP RURD P Connect new ESP spool to ESP line. 8,518.0 8,518.0
10/30/2024
02:00
10/30/2024
02:30
0.50 COMPZN, RPCOMP PUTB P RIH with 4-1/2" 12.5# Hyd 563 upper
completion tubing from 8518' to 8811'
MD. 3800 ft-lbs MU TQ. Drift tubing on
skate with 3.82" drift. Checking
continuity on lines evey 1000'.
8,518.0 8,811.0
10/30/2024
02:30
10/30/2024
06:00
3.50 COMPZN, RPCOMP RURD P Make permanent splice to ESP cable on
rig floor.
8,811.0 8,811.0
10/30/2024
06:00
10/30/2024
11:00
5.00 COMPZN, RPCOMP PUTB P RIH with 4-1/2" 12.5# Hyd 563 upper
completion tubing from 8811' to 11121'
MD. 3800 ft-lbs MU TQ. Drift tubing on
skate with 3.82" drift. Checking
continuity on lines evey 1000'.
Fully located at 11121'. Set 7k Down.
55k SO
148k PU
8,811.0 11,121.0
10/30/2024
11:00
10/30/2024
11:30
0.50 COMPZN, RPCOMP PUTB P LD joint # 265. MU head pin and
pressure up to 300 PSI to confirm
located.
11,121.0 11,121.0
10/30/2024
11:30
10/30/2024
14:00
2.50 COMPZN, RPCOMP HOSO P LD joints #264/263/262. MU space out
pup joints. 5 pup joints
3.88'/5.85'/7.78'/9.70'/9.73' + joint # 262.
MU hanger and landing joint.
11,121.0 11,121.0
10/30/2024
14:00
10/30/2024
18:00
4.00 COMPZN, RPCOMP CIRC P Pump 200 BBLs SW ahead and displce
hole to 8.5ppg CI Brine.
3-5 BPM
100-207 PSI
SimOps - Terminating lines through
hanger.
11,121.0 11,121.0
10/30/2024
18:00
10/30/2024
19:00
1.00 COMPZN, WHDBOP HOSO P Land hanger. RILDS. Test hanger to
5000 psi for 15 minutes. Good test.
4.92' off fully located.
11,116.0 1,116.0
10/30/2024
19:00
10/30/2024
20:00
1.00 COMPZN, WHDBOP RURD P RU to test tubing and IA. Replace seal
on cement line valve.
0.0 0.0
Rig: DOYON 25
RIG RELEASE DATE 10/31/2024
Page 12/12
1C-157
Report Printed: 11/25/2024
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/30/2024
20:00
10/30/2024
22:30
2.50 COMPZN, WHDBOP PRTS P Test tubing to 2500 psi for 30 minutes.
Good test.
Bleed tubing pressure to 2000 psi.
Test IA to 2500 PSI for 30 minutes.
Good test.
Dump tubing pressure and shear SOV.
Pump 10 bbls down IA and up tubing to
confirm.
0.0 0.0
10/30/2024
22:30
10/30/2024
23:00
0.50 COMPZN, WHDBOP OWFF P Flow check. Static.
SimOps - LD landing joint.
0.0 0.0
10/30/2024
23:00
10/30/2024
23:30
0.50 COMPZN, WHDBOP PRTS P Set HP-BPV and test from below to
1000 psi for 15 minutes. Good test.
0.0 0.0
10/30/2024
23:30
10/31/2024
00:00
0.50 COMPZN, WHDBOP NUND P ND Stack. 0.0 0.0
10/31/2024
00:00
10/31/2024
03:30
3.50 COMPZN, WHDBOP NUND P Pull trip nipple. RD choke/kill, flow line
and Joe's box. ND BOP and risers.
Offload fluid from pits.
SimOps: Peform BWM on BOP.
0.0 0.0
10/31/2024
03:30
10/31/2024
09:00
5.50 COMPZN, WHDBOP NUND P Install test dart. Prep TEC wire, CI line
and ESP cable. NU tubing adapter and
tree. Connect ESP and TEC wire to
termination box.
SimOps: Inspect mud pumps. RD
interconnects in pits. Clean pumps and
pits.
0.0 0.0
10/31/2024
09:00
10/31/2024
14:00
5.00 COMPZN, WHDBOP FRZP P RU to freeze protect. Test tree to
250/5000 psi for 15 min each. Perform
freeze protect with 140 BBLs diesel.
Pump at 1.5 BPM. Allow well to U-tube.
SimOps: Bridle up and scope down
mast. Blow down lines.
0.0 0.0
10/31/2024
14:00
10/31/2024
16:00
2.00 DEMOB, MOVE RURD P Blow down lines and RD. Clean cellar
and tree. Obtain final pressures.
TBG - 550 PSI
IA - 50 PSI
OA - 0 PSI
0.0 0.0
10/31/2024
16:00
10/31/2024
18:00
2.00 DEMOB, MOVE RURD P Blow down steam lines. Lower cattle
chute.
0.0 0.0
Rig: DOYON 25
RIG RELEASE DATE 10/31/2024
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Run GLD 1C-157 11/18/2024 bworthi1
Casing Strings
Csg Des OD (in)ID (in)Top (ftKB)
Set Depth
(ftKB)
Set Depth
(TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread
Conductor 20 19.12 39.3 154.3 154.3 94.00 L-80 Welded
Surface 13 3/8 12.42 39.3 2,061.7 1,934.6 68.00 L-80 Hyd563
Intermediate - Patch 9 5/8 8.76 36.2 1,954.0 1,846.7 43.50 L80 H563
*Lower* Intermediate 9 5/8 8.84 1,951.0 11,256.2 3,984.7 40.00 L80 HYD563
Production 4 1/2 3.96 11,071.5 21,427.0 3,925.0 12.60 L-80 HYD563
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
34.5
Set Depth
11,116.0
String Max No
4 1/2
Set Depth
3,976.1
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)
34.5 34.5 0.00 Hanger 13.475 Vault MB242 13-1/2 x 4-1/2 tubing
hanger, 4.909" RH MCA top
Vault MB242 3.900
1,833.6 1,748.5 35.16 Mandrel 4.500 4-1/2" x 1" KBMG-1 GLM w/ 2000
psi SOV, BEK Latch S/N 24393-12
SLB 4.5" x 1"
KBMG
3.865
3,917.6 3,045.5 70.80 Mandrel 4.500 4-1/2" x 1" KBMG-1 GLM w/ DV& BK
latch S/N 24393-08
SLB 4.5" x 1"
KBMG
3.865
9,788.5 3,856.9 84.81 Gauge / Pump
Sensor
4.500 HES Opsis Gauge mandrel w/
Downhole gauge, 4-1/2" H563, L80
HES Opsis 3.923
10,181.1 3,895.3 84.27 Sliding Sleeve 5.500 5-1/2" GV Sliding sleeve 4 1/2"
Vamtop Box x 5 1/2", 23#, Vam FJL
Box
Access
ESP
Sliding
Sleeve
3.910
10,187.4 3,895.9 84.26 Motor Shroud 5.500 Motor Shroud, 5 1/2" 23# Vam FJL
Pin x Pin
Access
ESP
4.548
10,192.2 3,896.4 84.26 Motor
Centralizer
5.500 Motor Cenralizer, 5 1/2" 23# Vam
FJL Box x Box
Access
ESP
3.894
10,194.0 3,896.6 84.26 Motor Shroud 5.500 Motor Shroud, 5 1/2" 23# Vam FJL
Pin x Pin
Access
ESP
4.548
10,198.8 3,897.1 84.27 Motor
Centralizer
5.500 Motor Cenralizer, 5 1/2" 23# Vam
FJL Box x Box
Access
ESP
3.893
10,200.6 3,897.2 84.27 Motor Shroud 5.500 Motor Shroud, 5 1/2" Vam FJL Box x
Pin
Access
ESP
3.894
10,205.4 3,897.7 84.27 Motor
Centralizer
5.500 Motor Cenralizer, 5 1/2" 23# Vam
FJL Box x Box
Access
ESP
4.548
10,207.1 3,897.9 84.27 Motor Shroud 5.500 Motor Shroud, 5 1/2" Vam FJL Box x
Pin
Access
ESP
4.548
10,211.9 3,898.4 84.28 Motor
Centralizer
5.500 Motor Cenralizer, 5 1/2" 23# Vam
FJL Box x Box
Access
ESP
3.894
10,213.6 3,898.5 84.28 Motor Shroud 5.500 Motor Shroud, 5 1/2" 23# Vam FJL
Pin x Pin
Access
ESP
4.548
10,218.4 3,899.0 84.28 Motor
Centralizer
5.500 Motor Cenralizer, 5 1/2" 23# Vam
FJL Box x Box
Access
ESP
3.893
10,220.2 3,899.2 84.29 Motor Shroud 5.500 Motor Shroud, 5 1/2" 23# Vam FJL
Pin x Pin
Access
ESP
4.548
10,225.0 3,899.7 84.29 Motor
Centralizer
5.500 Motor Cenralizer, 5 1/2" 23# Vam
FJL Box x Box
Access
ESP
3.894
10,226.8 3,899.8 84.29 Motor Shroud 5.500 Motor Shroud, 5 1/2" 23# Vam FJL
Pin x Pin
Access
ESP
4.548
10,231.7 3,900.3 84.30 Motor
Centralizer
5.500 Motor Cenralizer, 5 1/2" 23# Vam
FJL Box x B+H56:H85ox
Access
ESP
3.894
10,233.4 3,900.5 84.30 Motor Shroud 5.500 Motor Shroud, 5 1/2" 23# Vam FJL
Pin x Pin
Access
ESP
4.548
10,238.2 3,901.0 84.30 Motor
Centralizer
5.500 Motor Cenralizer, 5 1/2" 23# Vam
FJL Box x Box
Access
ESP
3.894
10,240.1 3,901.2 84.30 Motor Shroud 5.500 Motor Shroud, 5 1/2" 23# Vam FJL
Pin x Pin
Access
ESP
4.548
10,246.4 3,901.8 84.31 Annular
Connection
Port
5.950 Ann Connection Port, 5", 18# Vam
FJL Box x 4 1/2" 12.6# Vamtop Box
Access
ESP
3.860
10,270.0 3,904.1 84.33 Profile Sub 4.500 B-Profile sub, 4 1/2", 12.6#, L-80
Vamtop Box x Box
Access
ESP
3.913
10,283.5 3,905.4 84.35 No-go nipple 5.000 No-Go, 4 1/2" 12.6# Vamtop Box x 4
1/2" Hyd 563 Box
3.805
10,823.2 3,953.3 85.68 Sliding Sleeve 4.500 NEXA-2 Sliding sleeve, 3.813" X
Profile, 4-1/2", 12.6#, L80, H563
SLB NEXA-2 3.813
10,966.5 3,964.2 85.46 Mandrel 4.500 HES Chemical injection mandrel, 4-
1/2" 12.6#, L80, H563
HES Chemica
l
Injection
Mandrel,
HES
SAP#
1108136
3.908
11,031.7 3,969.5 85.22 Nipple X 4.500 3.813" XN Nipple, 3.75" no-go - Re-
Run
HES XN 3.75
no go
3.750
11,094.3 3,974.5 85.78 Locator Sub 5.500 Locator 5.5" OD Baker GBH-22 3.880
11,108.9 3,975.6 85.97 Seal Assembly 4.730 Seals Baker 192-47 3.890
11,112.0 3,975.8 86.01 Wireline Guide 4.500 HES Self aligning mule shoe HES 3.890
HORIZONTAL, 1C-157, 11/25/2024 9:48:01 AM
Vertical schematic (actual)
Production; 11,071.5-21,427.0
*Lower* Intermediate; 1,951.0-
11,256.2
Wireline Guide; 11,112.0
Mandrel; 10,966.5
Sliding Sleeve; 10,823.2
ISO-SLEEVE; 10,246.4
Sliding Sleeve; 10,181.1
Intermediate String 1 Cement;
3,422.0 ftKB
Mandrel; 3,917.6
Surface; 39.3-2,061.7
Intermediate - Patch; 36.2-
1,954.0
Mandrel; 1,833.6
Surface String Cement; 39.5
ftKB
Remedial; 39.2 ftKB
Conductor; 39.3-154.3
Hanger; 34.5
KUP PROD
KB-Grd (ft)
39.28
RR Date
8/2/2023
Other Elev
1C-157
...
TD
Act Btm (ftKB)
21,467.0
Well Attributes
Field Name
WEST SAK
Wellbore API/UWI
500292375400
Wellbore Status
PROD
Max Angle & MD
Incl (°)
92.70
MD (ftKB)
18,974.76
WELLNAME WELLBORE
Annotation End DateH2S (ppm)DateComment
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top (ftKB)
Top (TVD)
(ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in)
10,246.4 3,901.8 84.31 ISO-SLEEVE 4 1/2" ISOLATION SLEEVE
(11.28' OAL / 2.98" ID)
11/15/2024 2.980
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)
1,833.6 1,748.5 35.16 1 GAS LIFT GLV BK 1 1,300.0 11/18/2024 SLB Other 0.125
3,917.6 3,045.5 70.80 2 GAS LIFT OV BK 1 11/18/2024 SLB Other 0.313
Cement Squeezes
Top (ftKB)Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB)Des Com
Pump Start
Date
39.6 2,062.0 39.5 1,934.8 Surface String
Cement
6/19/2023
3,422.0 11,256.2 2,847.3 3,984.7 Intermediate
String 1
Cement
Perform cement job f/ 9 5/8" int. csg as per
Halliburton program, Flood lines w/ 5 bpm H2O 278
psi, PressureTest lines t/ 4000psi, pump 77 bbls
tuned 10.5 ppg spacer @ 3.75 bpm/ 370 psi 12% f/o,
Drop #2 bottom plug, pump 370 bbls 14 ppg Lead
cmt @ 6 bpm 140psi 14% f/o, pump 138 bbls 15.3
ppg Tail cmt @ 4 bpm 135 psi 10% f/o, Drop top
plug, pump 20 bbls fresh H2O, line up t/ rig pumps t/
displace. w/ 827 bbls @ 6 bpm 207 psi 14% f/o f/
2620 stks. Cont. displacement @ 6 bpm 770 psi F/O
13% f/ 3200 strokes, Slow rate t/5 bpm 855 psi f/700
strokes, Slow rate t/4 bpm 887 psi f/240 strokes,
Slow rate t/3 bpm @ 847 psi, Bump plug @ 7010
strokes pressure up to 1380 psi hold f/ 5 min. Bleed
off/ check floats good. Cement in place at 1340 hrs
7/4/2023
39.2 1,890.0 39.2 1,794.6 Remedial Cement from stage tool to surface 10/26/2024
HORIZONTAL, 1C-157, 11/25/2024 9:48:04 AM
Vertical schematic (actual)
Production; 11,071.5-21,427.0
*Lower* Intermediate; 1,951.0-
11,256.2
Wireline Guide; 11,112.0
Mandrel; 10,966.5
Sliding Sleeve; 10,823.2
ISO-SLEEVE; 10,246.4
Sliding Sleeve; 10,181.1
Intermediate String 1 Cement;
3,422.0 ftKB
Mandrel; 3,917.6
Surface; 39.3-2,061.7
Intermediate - Patch; 36.2-
1,954.0
Mandrel; 1,833.6
Surface String Cement; 39.5
ftKB
Remedial; 39.2 ftKB
Conductor; 39.3-154.3
Hanger; 34.5
KUP PROD 1C-157
...
WELLNAME WELLBORE
2 %%8 8 68
0'0&-)+8*,"8
'(" )% 8*,"8
-
0(-#)(8+', ((0&+ 8!+,8 )(-8 0(-#)(8%"( ,8 0(-#)(8)( 8+'8-2# 8
& -8*+,,0+ 8,-#%"3 8( 8+ )+ 8$80*8("-+) (8)--% ,8
0'0%-)+8*,"8
(#-+) (8)--& ,8
).% 8
8
)/% 88
).% 8
)/% 8
).% 88
)/& 88
1 8 )+88)--& ,88
47+(8)(8 &
8*0'* 8, 8 )+8 8*,"88
-0+(8)(8"+8*0'*,8
5' 8 )+8 0%%8!+ 8
*,"8
%23(7HVW'R\RQ
.58& 37'
$2*&&,QVSERS%'%
1C-157 10/21/2024
Tested to 250PSI/5 Min, 25OOPSI/5 Min
9 5/8” Test Jt
CHART #1
1. Annular Preventer, Valves: 1, 13, 14, 15, 3” Kill Line Valve (RIG FLOOR)
UIBOP
2. Upper Pipe Rams (9 5/8”), Valves: 2, 10, 12, HCR KILL, LIBOP
3. Valves: 6, 9, 11, MAN Kill, 5” DART
4. Valves: 5, 7, 8, 5” FOSV #1
5. Valve: 3 & 5” FOSV #2
6. HCR CHOKE
7. MAN CHOKE
8. BLINDS & Valve 4
9. (9A) Super choke (9B) Manual choke
4.5” Test Jt
10. Annular Preventer
CHART #2
11. Lower Pipe Rams (2 7/8”x 5”)
%23(7HVW'R\RQ
.58& 37'
$2*&&,QVSERS%'%
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: Replace Tubing
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?N/A
Yes No
9. Property Designation (Lease Number): 10. Field:
West Sak Oil Pool West Sak Oil Pool
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD):
21467' 3924' 11180' 3980' 796 11180' None
Casing Collapse
Conductor
Surface
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: 907-265-6379
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
Kuparuk River Field
Brian Glasheen
brian.glasheen@conocophillips.com
RWO Engineer
Subsequent Form Required:
Suspension Expiration Date:
L-80
TVD
Will perfs require a spacing exception due to property boundaries?
Current Pools:
MPSP (psi): Plugs (MD):
17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval.
Authorized Name and
Digital Signature with Date:
Tubing Size:
PRESENT WELL CONDITION SUMMARY
Length Size
AOGCC USE ONLY
Tubing Grade: Tubing MD (ft):
11072'MD/3973'TVD
Perforation Depth TVD (ft):
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL0025649, ADL028242, ADL025638
223-038
P.O. Box 100360, Anchorage, AK 99510 50-029-23754-00-00
ConocoPhillips Alaska, Inc
Proposed Pools:
Burst
11115'
MD
154'
1935'
154'
2062'
3985'9-5/8"
20"
13-3/8"
115'
Baker ZXP
SSSV: None
2023'
11256'
Perforation Depth MD (ft):
KRU 1C-157
None
11219'
4-1/2"
None
9/20/2024
21427'10355'
4-1/2"
3925'
Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
By Grace Christianson at 11:16 am, Sep 09, 2024
Digitally signed by Brian Glasheen
DN: OU=RWO's, O=ConocoPhillips, CN=Brian
Glasheen, E=brian.glasheen@conocophillips.com
Reason: I am the author of this document
Location:
Date: 2024.09.09 08:37:15-08'00'
Foxit PDF Editor Version: 13.0.0
Brian
Glasheen
324-510
X 10-404
DSR-9/11/24VTL 9/19/2024
X
BOP test to 2500 psig
Annular preventer test to 2500 psig
A.Dewhurst 11SEP24*&:
Jessie L.
Chmielowski
Digitally signed by Jessie L.
Chmielowski
Date: 2024.09.23 08:39:50 -08'00'09/23/24
RBDMS JSB 092424
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
September 3, 2024
Commissioner
State of Alaska
Alaska Oil & Gas Conservation Commission
333 West 7th Avenue Suite 100
Anchorage, Alaska 99501
Dear Commissioner:
Brian Glasheen
RWO Engineer
ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over WEST SAK Producer 1C-
157 (PTD# 223-038-0).
Well 1C-157 was originally spud in 6/16/23 and rig released 8/2/23.The well has primarily been a WEST Sak
Producer.The well has developed AnnComm issues that moved it to being a RWO candidate due to a casing leak in the 9-
5/8'' at ~305'.
If you have any questions or require any further information, please contact me at +1-907-545-1144
The tubing will be pulled. The 9-5/8" casing will be cut below the leak and removed. Then new 9-5/8" casing with
sealing overshot and cement will be installed and pressure tested. Identical 4.5" completion will be installed and stung
back in to the sealbore to recomplete the well.
1C-157 RWO Procedure
West Sak Producer
P&R Tubing w/Casing repair Subsidence like
PTD #223-038
Page 1 of 3
Pre-Rig Work
1. T-PPPOT, T-POT
2. Shift Sliding sleeve open for circulation
3. Prepare well within 48-96 hrs of rig arrival. Confirm no gas in OA, IA, or tubing.
Rig Work
MIRU
1. MIRU Nabors 7ES on 1C-157.
2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete
30-minute NFT. Verify well is dead. Circulate KWF as needed.
3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/2,500 psi. Test annular 250/2500
psi.
Retrieve 4-1/2” Tubing
4. Pull BPV, MU landing joint and BOLDS.
5. Pull 4-1/2” tubing down to seal assembly at 11,107’
9-5/8” Casing Subsidence-Style Repair
6. RU E-line: Run USIT with Caliper or Microguide Gyro and log 9-5/8” casing for OA cement
7. RIH with test packer and set at 500’ and pressure test to 2500 psi below the test packer to confirm 9-5/8’’ casing
integrity below know leak at 305’.
8. Set storm packer or plug in 9-5/8” casing
9. Pull 9-5/8’’ Packoff
10. Cut 9-5/8” casing 2-3 joints above the surface casing shoe or 2-3 joints above the OA cement observed from
USIT, TOOH and stand back DP
11. PU casing and circulate out the OA until clean.
12. POOH and lay down the 9-5/8” casing.
13. RIH and dress off 9-5/8” casing stump.
14. RIH with new 9-5/8” casing and overshot with seals
15. Land 9-5/8” on slips and confirm casing overshot passed pressure test to 2500psi PT
16. Cement OA to surface
17. Break multi-bowl between upper and lower flange and secure Tubing head/BOPs with secondary restraints
18. Install new 9-5/8 emergency packoff.
19. NU wellhead flange where broken and Test break
20. Run in and wash debris from top of plug
21. Pull casing plug
Install 4-½” Tubing
22. MU 4-1/2” completion and RIH to sealbore sting into seal bore and mark for space out.
23. PUH and circulate CI brine, space out as needed, land hanger, RILDS.
24. Pressure test tubing to 2,500 psig for 30 minutes and chart.
25. Pressure test inner annulus to 2,500 psig for 30 minutes and chart.
ND BOP, NU Tree
26. Confirm pressure tests, then shear out SOV with pressure differential.
27. Install BPV.
28. ND BOPE. NU tree.
29. Pull BPV and freeze protect well
1C-157 RWO Procedure
West Sak Producer
P&R Tubing w/Casing repair Subsidence like
PTD #223-038
Page 2 of 3
30. RDMO.
Post-Rig Work
31. Run GLD.
32. Pull plug.
33. Turn over to operations.
1C-157 RWO Procedure
West Sak Producer
P&R Tubing w/Casing repair Subsidence like
PTD #223-038
Page 3 of 3
General Well info:
Wellhead type/pressure rating: 13-3/8" X 9-5/8" X 4-1/2" 5M MB-222/MB-242 MULTIBOWL ASSY
Production Engineer: Will Parker
Reservoir Development Engineer: Carolyn Kirchner
Estimated Start Date: 9/20/2024
Workover Engineer: Brian Glasheen (907-545-1144 / Brian.Glasheen@conocophillips.com)
Current Operations: This well is currently shut in and secured.
Well Type: Producer
Scope of Work: Pull the existing 4-1/2” completion, perform subsidence like repair on 9-5/8” production casing, and
install a new 4-1/2” completion.
BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram
Following subject to change/be updated with pre-rig work:
MIT results:
MIT-T: Passed ( 2500 psi 4/30/2024)
CMIT-TxIA: Failed (4/19/2024)
MIT-OA: Failed 9/1/24 (Known open shoe)
IC POT & PPPOT – TBD
TBG POT & PPPOT – TBD
MPSP: 796 psi using 0.1 psi/ft gradient
Static BHP: 1184 psi / 3885’ TVD measured on 4/27/24 (5.86 ppg EMW)
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Annotate Casing Leak 1C-157 5/26/2024 bworthi1
Casing Strings
Csg Des OD (in)ID (in)Top (ftKB)
Set Depth
(ftKB)
Set Depth
(TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread
Conductor2019.12 39.3 154.3 154.394.00 L-80 Welded
Surface 13 3/8 12.42 39.3 2,061.7 1,934.6 68.00 L-80 Hyd563
Intermediate 9 5/8 8.84 36.9 11,256.2 3,984.7 40.00 L80 HYD563
Production 4 1/2 3.96 11,071.5 21,427.0 3,925.0 12.60 L-80 HYD563
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
0.0
Set Depth …
11,114.9
Set Depth …
3,976.0
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)
0.00.00.00 HANGER 13.375 Vault 13-3/8" x 4-1/2" tubing hanger Vault MB 2423.958
2,124.4 1,985.5 35.85 GAS LIFT 4.500 4-1/2" x 1" Vanoil KBMG GLM w/
SOV (pinned to 2000psi
SLB SN -
28685-
06
3.958
3,920.5 3,046.5 70.87 Mandrel - SOV 4.500 4-1/2" x 1" Vanoil KBMG GLM w/
Dummy
SLB SN -
23685-
08
3.958
10,081.2 3,885.4 84.28 Mandrel –
PROD
4.500 HES Opsis Guage Mandrel w DHG
Ser# MXM18767-0-6
HES SN -
MXM187
67-0-6
3.920
10,217.3 3,898.9 84.28 SLEEVE 5.500 CMD Gas Venting Sliding Sleeve, 4-
1/2" VAM Top box x 5-1/2" VAM FJL
pin (CLOSED 4/19/24)
AccessE
SP
3.910
10,222.33,899.4 84.29 MOTOR5.500Motor Shroud #8, 5-1/2" VAM FJL
pin X pin
AccessE
SP
4.548
10,227.13,899.984.29 Centralizer 5.500 Motor Centralizer, 5-1/2" VAM FJL
box X box
AccessE
SP
3.893
10,228.93,900.084.29 MOTOR5.500Motor Shroud #7, 5-1/2" VAM FJL
pin X pin
AccessE
SP
4.548
10,233.7 3,900.5 84.30 Centralizer 5.500 Motor Centralizer, 5-1/2" VAM FJL
box X box
AccessE
SP
3.893
10,235.4 3,900.7 84.30 MOTOR5.500Motor Shroud #6, 5-1/2" VAM FJL
pin X pin
AccessE
SP
4.548
10,240.23,901.284.30 Centralizer 5.500 Motor Centralizer, 5-1/2" VAM FJL
box X box
AccessE
SP
3.893
10,242.03,901.384.31 MOTOR5.500Motor Shroud #5, 5-1/2" VAM FJL
pin X pin
AccessE
SP
4.548
10,246.83,901.884.31 Centralizer 5.500 Motor Centralizer, 5-1/2" VAM FJL
box X box
AccessE
SP
3.893
10,248.5 3,902.084.31 MOTOR5.500Motor Shroud #4, 5-1/2" VAM FJL
pin X pin
AccessE
SP
4.548
10,253.33,902.5 84.32 Centralizer 5.500 Motor Centralizer, 5-1/2" VAM FJL
box X box
AccessE
SP
3.893
10,255.13,902.684.32 MOTOR5.500Motor Shroud #3, 5-1/2" VAM FJL
pin X pin
AccessE
SP
4.548
10,259.93,903.184.32 Centralizer 5.500 Motor Centralizer, 5-1/2" VAM FJL
box X box
AccessE
SP
3.893
10,261.63,903.384.32 MOTOR5.500Motor Shroud #2, 5-1/2" VAM FJL
pin X pin
AccessE
SP
4.548
10,266.4 3,903.884.33 Centralizer 5.500 Motor Centralizer, 5-1/2" VAM FJL
box X box
AccessE
SP
3.893
10,268.23,903.984.33 MOTOR5.500Motor Shroud #1, 5-1/2" VAM FJL
pin X pin
AccessE
SP
3.893
10,274.5 3,904.684.34 Annular
Connection
Port (ACP)
5.950 ACP 5" VAM FJL box X 4-1/2" VAM
Top box
AccessE
SP
3.860
10,298.03,906.984.29 Nipple - Profile 4.500 B Profile, 4-1/2" VAM Top box X box AccessE
SP
3.913
10,311.5 3,908.284.20 Nipple - No Go4.500NoGo Nipple, 4-1/2" VAM Top box X
4-1/2" Hyd 563 box
AccessE
SP
3.813
10,858.7 3,956.085.75 SLEEVE 4.500 CMU Sliding Sleeve w/ 3.813" X
profile (CLOSED 4/19/2024)
SLB SN -
4791673
114-01-
02
3.813
10,965.5 3,964.1 85.47 Mandrel – INJ 4.500 HES Chemical Injection Mandrel HES SAP -
1108136
4.310
11,030.8 3,969.4 85.22 Nipple - XN 4.500 HES 3.813" XN Nipple (3.725" no-
go)
HESSN -
0004685
840-2
3.725
11,093.2 3,974.5 85.77 LOCATOR 4.500 Baker Mechanical locator (5.52'
f/Fully Located)
BakerH45301
0111
4.650
11,107.7 3,975.5 85.95 SEAL
ASSEMBLY
4.500 Baker Bonded Seal Assembly Baker H02186
1300
3.870
11,110.9 3,975.7 86.00 SHOE MULE 4.750 Baker Self-Aligning Muleshoe Baker 1028304
16
3.880
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top (ftKB)
Top (TVD)
(ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in)
300.0300.01.27 LEAK -
CASING
CSG LEAK AT ~300' TO 305'
RKB IDENFITIED BY EL LDL
5/26/2024 8.840
10,274.5 3,904.684.34ISO-SLEEVE 4 1/2" ISOLATION SLEEVE
(11.28' OAL / 2.98" ID)
4/30/2024 2.980
HORIZONTAL, 1C-157, 5/30/2024 8:59:09 AM
Vertical schematic (actual)
Production; 11,071.5-21,427.0
SHOE FLOAT; 21,424.3-
21,427.0
SEAL PACKOFF; 21,404.5-
21,405.7
PACKER SWELL; 18,911.0-
18,931.1
PACKER SWELL; 18,586.5-
18,606.6
PACKER SWELL; 14,147.5-
14,167.6
PACKER SWELL; 13,985.8-
14,005.5
PACKER SWELL; 12,306.7-
12,326.8
Intermediate; 36.9-11,256.2
Shoe - Float; 11,252.3-11,256.2
PLUG; 11,180.0
Collar - Float; 11,170.2-11,173.1
XO REDUCING; 11,145.3-
11,147.1
XO ENLARGING; 11,136.9-
11,138.6
SBE; 11,107.5-11,127.2
SHOE MULE; 11,110.9
SEAL ASSEMBLY; 11,107.7
XO REDUCING; 11,105.9-
11,107.5
TUBING; 11,095.0
HANGER; 11,096.5-11,105.9
NIPPLE; 11,093.7-11,096.5
PACKER; 11,071.5-11,093.7
Nipple - XN; 11,030.8
Mandrel – INJ; 10,965.5
SLEEVE; 10,858.7
Nipple - No Go; 10,311.5
Nipple - Profile; 10,298.0
ISO-SLEEVE; 10,274.5
Annular Connection Port (ACP);
10,274.5
MOTOR; 10,268.2
Centralizer; 10,266.4
MOTOR; 10,261.6
Centralizer; 10,259.9
MOTOR; 10,255.1
Centralizer; 10,253.3
MOTOR; 10,248.5
Centralizer; 10,246.8
MOTOR; 10,242.0
Centralizer; 10,240.2
MOTOR; 10,235.4
Centralizer; 10,233.7
MOTOR; 10,228.9
Centralizer; 10,227.1
MOTOR; 10,222.3
SLEEVE; 10,217.3
Mandrel – PROD; 10,081.2
Collar - Floatation; 8,254.8-
8,256.4
Intermediate String 1 Cement;
3,422.0 ftKB
Mandrel - SOV; 3,920.5
GAS LIFT; 2,124.4
Surface; 39.3-2,061.7
Shoe - Float; 2,058.0-2,061.7
Annular Fluid - Diesel; 36.9-
2,125.0; 8/2/2023
Annular Fluid - Diesel; 35.0-
2,125.0; 8/2/2023
Surface String Cement; 39.5
ftKB
Annular Fluid - Diesel; 39.4-
2,062.0; 8/2/2023
LEAK - CASING; 300.0
Conductor; 39.3-154.3
Casing Hanger; 39.3-39.5
Casing Hanger; 36.9-37.6
HANGER; 0.0
KUP PROD
KB-Grd (ft)
39.28
RR Date
8/2/2023
Other Elev…
1C-157
...
TD
Act Btm (ftKB)
21,467.0
Well Attributes
Field Name
WEST SAK
Wellbore API/UWI
500292375400
Wellbore Status
PROD
Max Angle & MD
Incl (°)
92.70
MD (ftKB)
18,974.76
WELLNAME WELLBORE
Annotation End DateH2S (ppm)DateComment
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top (ftKB)
Top (TVD)
(ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in)
11,180.0 3,980.2 86.46 PLUG 4 1/2" RBP (CENTER
ELEMENT @ 11,183')
OAL=8.12
CPSC
HP45
007/C
PEQ4
5013
4/29/2024 0.000
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)
2,124.4 1,985.5 35.85 1 GAS LIFT DMY BEK 8/5/2023
3,920.5 3,046.5 70.87 2 GAS LIFT DMY BK 0.03/28/2024 Schlumb
erger
BK 0.000
Cement Squeezes
Top (ftKB)Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB)Des Com
Pump Start
Date
39.6 2,062.0 39.5 1,934.8 Surface String
Cement
6/19/2023
3,422.0 11,256.2 2,847.3 3,984.7 Intermediate
String 1
Cement
Perform cement job f/ 9 5/8" int. csg as per
Halliburton program, Flood lines w/ 5 bpm H2O 278
psi, PressureTest lines t/ 4000psi, pump 77 bbls
tuned 10.5 ppg spacer @ 3.75 bpm/ 370 psi 12% f/o,
Drop #2 bottom plug, pump 370 bbls 14 ppg Lead
cmt @ 6 bpm 140psi 14% f/o, pump 138 bbls 15.3
ppg Tail cmt @ 4 bpm 135 psi 10% f/o, Drop top
plug, pump 20 bbls fresh H2O, line up t/ rig pumps t/
displace. w/ 827 bbls @ 6 bpm 207 psi 14% f/o f/
2620 stks. Cont. displacement @ 6 bpm 770 psi F/O
13% f/ 3200 strokes, Slow rate t/5 bpm 855 psi f/700
strokes, Slow rate t/4 bpm 887 psi f/240 strokes,
Slow rate t/3 bpm @ 847 psi, Bump plug @ 7010
strokes pressure up to 1380 psi hold f/ 5 min. Bleed
off/ check floats good. Cement in place at 1340 hrs
7/4/2023
HORIZONTAL, 1C-157, 5/30/2024 8:59:10 AM
Vertical schematic (actual)
Production; 11,071.5-21,427.0
SHOE FLOAT; 21,424.3-
21,427.0
SEAL PACKOFF; 21,404.5-
21,405.7
PACKER SWELL; 18,911.0-
18,931.1
PACKER SWELL; 18,586.5-
18,606.6
PACKER SWELL; 14,147.5-
14,167.6
PACKER SWELL; 13,985.8-
14,005.5
PACKER SWELL; 12,306.7-
12,326.8
Intermediate; 36.9-11,256.2
Shoe - Float; 11,252.3-11,256.2
PLUG; 11,180.0
Collar - Float; 11,170.2-11,173.1
XO REDUCING; 11,145.3-
11,147.1
XO ENLARGING; 11,136.9-
11,138.6
SBE; 11,107.5-11,127.2
SHOE MULE; 11,110.9
SEAL ASSEMBLY; 11,107.7
XO REDUCING; 11,105.9-
11,107.5
TUBING; 11,095.0
HANGER; 11,096.5-11,105.9
NIPPLE; 11,093.7-11,096.5
PACKER; 11,071.5-11,093.7
Nipple - XN; 11,030.8
Mandrel – INJ; 10,965.5
SLEEVE; 10,858.7
Nipple - No Go; 10,311.5
Nipple - Profile; 10,298.0
ISO-SLEEVE; 10,274.5
Annular Connection Port (ACP);
10,274.5
MOTOR; 10,268.2
Centralizer; 10,266.4
MOTOR; 10,261.6
Centralizer; 10,259.9
MOTOR; 10,255.1
Centralizer; 10,253.3
MOTOR; 10,248.5
Centralizer; 10,246.8
MOTOR; 10,242.0
Centralizer; 10,240.2
MOTOR; 10,235.4
Centralizer; 10,233.7
MOTOR; 10,228.9
Centralizer; 10,227.1
MOTOR; 10,222.3
SLEEVE; 10,217.3
Mandrel – PROD; 10,081.2
Collar - Floatation; 8,254.8-
8,256.4
Intermediate String 1 Cement;
3,422.0 ftKB
Mandrel - SOV; 3,920.5
GAS LIFT; 2,124.4
Surface; 39.3-2,061.7
Shoe - Float; 2,058.0-2,061.7
Annular Fluid - Diesel; 36.9-
2,125.0; 8/2/2023
Annular Fluid - Diesel; 35.0-
2,125.0; 8/2/2023
Surface String Cement; 39.5
ftKB
Annular Fluid - Diesel; 39.4-
2,062.0; 8/2/2023
LEAK - CASING; 300.0
Conductor; 39.3-154.3
Casing Hanger; 39.3-39.5
Casing Hanger; 36.9-37.6
HANGER; 0.0
KUP PROD 1C-157
...
WELLNAME WELLBORE
1C-157 Proposed RWO Completion
COMPLETION
INFO
MD
(ft RKB)
TVD
(ft RKB)
OD
(in)
Nom. ID
(in)
Weight
(lb/ft)Grade Thread
(top)
Thread
(btm)
Conductor 154 154 20 19.12 94 L-80 Welded Welded
Surface 2062 1935 13-3/8 12.42 68 L-80 Hyd563 Hyd563
Intermediate 11,256 3985 9-5/8 8.84 40 L-80 Hyd563 Hyd563
Liner 21,427 3925 4.5 3.96 12.6 L-80 Hyd563 Hyd563
Tubing 11,071 3976 4.5 3.96 12.6 L-80 Hyd563 Hyd563
Proposed Completion
Production Casing:
9-5/8" 40# L-80 TXP to surface
9-5/8" ES Cementer @ ~1940' RKB
9-5/8" Sealing overshot @ ~1980 RKB
Production Tubing:
4-1/2" 12.6# L-80 Hyd563 to surface
4-1/2" x 1" KBMG gas lift mandrels @ 2124' & 3921' RKB
4-1/2" Gauge Mandrel @ 10,081' RKB
4-1/2" CMD sliding sleeve @ 10,217' RKB
Access ESP Motor shroud/centralizer assembly @ 10,222' RKB
Access ESP ACP @ 10,274' RKB
B- Nipple Profile (3.913" ID) @ 10,298' RKB
No-Go Nipple (3.813" ID) @ 10,311' RKB
4-1/2" CMU sliding sleeve (3.813" X profile) @ 10,858' RKB
4-1/2" Chemical Injection Mandrel @ 10,965' RKB
4-1/2" XN Nipple (3.813" ID, 3.725" no-go) @ 11,030' RKB
Locator & Seal assembly (190-47) @ 11,093' RKB
13-3/8" 68# L-80
shoe @ 2062' MD
9-5/8" 40# L-80 shoe
@ 11,256' MD
4-1/2" 12.6# L-80 shoe @ 21,427'
MD
4-1/2" OHSAS
20" 94# L-80
shoe @ 154' MD
Originated: Delivered to:9-Jul-24
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-11 50-029-20685-00 909447215 Kuparuk River Radial Bond Record Field & Processed 3-Jul-24 0 1
2 1B-04 50-029-20595-00 909359143 Kuparuk River Plug Setting Record Field- Final 5-Jun-24 0 1
3 1C-24 50-029-23063-00 n/a Kuparuk River Plug Setting Record Field- Final 6-May-24 0 1
4 1C-157 50-029-23754-00 909345851 Kuparuk River Water Flow Record Field & Processed 25-May-24 0 1
5 1D-135 50-029-22816-00 n/a Kuparuk River Plug Setting Record Field- Final 25-May-24 0 1
6 1D-145 50-029-23526-00 909335380 Kuparuk River Jewelry Record Field- Final 14-May-24 0 1
7 1E-08A 50-029-20496-01 909539034 Kuparuk River Plug Setting Record Field- Final 1-Jun-24 0 1
8 1F-03A 50-029-20853-01 909382731 Kuparuk River Leak Detect Log Field- Final 18-Jun-24 0 1
9 1F-03A 50-029-20853-01 909424095 Kuparuk River Multi Finger Caliper Field & Processed 2-Jul-24 0 1
10 1G-04 50-029-20835-00 909359162 Kuparuk River Patch Setting Record Field- Final 11-Jun-24 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:
T39146
T39147
T39148
T39149
T39150
T38151
T39152
T39153
T39153
T39154
181-173
181-065
201-248
223-038
197-184
214-138
210-181
196-096
182-161
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2024.07.10 13:03:51
-08'00'
1C-157 50-029-23754-00 909345851 Kuparuk River Water Flow Record Field & Processed 25-May-24 0 1 T39149
223-038
WELL NAME API #
SERVICE ORDER
# FIELD NAME
SERVICE
DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED
COLOR
PRINTS CDs
1C-157 50-029-23754-00-00 223-038 KUPARUK RIVER MWD/LWD/DD VISION SERVICES FINAL FIELD 20-Jul-23 1
Transmittal Receipt
________________________________X____________________________________________
Print Name Signature Date
Please return via courier or sign/scan and email a copy to Schlumberger.
VTuong@slb.com SLB Auditor -
A Transmittal Receipt signature confirms that a package (box,
envelope, etc.) has been received and the contents of the package
have been verified to match the media noted above. The specific
content of the CDs and/or hardcopy prints may or may not have been
verified for correctness or quality level at this point.
# Schlumberger-Private
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: 3806' FNL, 3335' FEL S7 T11N R11E 9. Ref Elevations: KB:
GL:58.30 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" L-80 154'9 cubic yards 10 yards
13 3/8" L-80 1935'
9-5/8" L-80 3985'
4-1/2" L-80 3925'
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
GR, RES, DEN, DIR, AZI, PWD, NEU, POR, SONIC, CALIPER
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
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
39'
39'
Per 20 AAC 25.283 (i)(2) attach electronic information
40
21427'
37'
3973'
94#
68#
154'
37' 11256'
SIZE DEPTH SET (MD) PACKER SET (MD/TVD)
42"
5968770
ADL025649, ADL028242, ADL025638
LONS 01-013
39'
12.6
39'
11072'
2062'
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
567893
564895
CEMENTING RECORD
5966482
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
ConocoPhillips Alaska, Inc.
WAG
Gas
8/2/2023 223-038
16" Lead: 364bbl 10.7ppg Class G
Tail: 69bbl 15.8ppg Class G
CASING
50-029-23754-00-00
KRU 1C-157
6/16/2023
21467'MD/3924'TVD
N/A
97.58'
P.O.Box 100360, Anchorage, AK 99510-0360
561999
1466' FNL, 4287' FEL S12 T11N R10E
3660' FNL, 1317' FEL S36 T12N R10E
7/14/2023
1888'MD/1793'TVD
SETTING DEPTH TVD
5977160
TOP HOLE SIZE AMOUNT
PULLEDTOP
SETTING DEPTH MD
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,
8-3/8"
TUBING RECORD
Lead: 370bbl 14ppg Class G
Tail: 140bbl 15.3ppg Class G
12-1/4"
11115'4-1/2" 11072'MD/3973'TVD
BOTTOM
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
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size
and Number; Date perf'd or liner run):
Open Hole Stand Alone Screen:
Liner Ran 7/22/23: 11072'MD-21427'TVD
By Grace Christianson at 9:14 am, Aug 23, 2023
Completed
8/2/2023
JSB
RBDMS JSB 083123
DSR-9/12/23 G
Conventional Core(s): Yes No Sidewall Cores:
30.
MD TVD
Surface Surface
1888' 1793'
10332' 3909'
21467' 3924'
31. List of Attachments:
Directional Survey, Well Schematic, Cement Operations, Operations Summary
32. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Contact Name: Matt Smith
Digital Signature with Date:
Contact Phone:907-263-4324
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: matt.smith@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
Matthew
Smith
Digitally signed by
Matthew Smith
Date: 2023.08.23 07:38:41
-08'00'
Page 1/37
1C-157
Report Printed: 8/17/2023
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)
6/14/2023
00:00
6/14/2023
00:30
0.50 MIRU, MOVE MOB P Secure stompers and cellar windwalls. 0.0 0.0
6/14/2023
00:30
6/14/2023
01:45
1.25 MIRU, MOVE MOB P Pull sub off well 1C-156 and spot for
crane pic.
0.0 0.0
6/14/2023
01:45
6/14/2023
05:30
3.75 MIRU, MOVE MOB P C/O drill line spools, install smoke stack
caps on boiler exhaust, position hyd
motor into sub hyd room all via crane.
SIMOPS - correct height of stomper
mats. Shuffle surface riser, DSA, and
spacer spools into cellar of 1C-157.
0.0 0.0
6/14/2023
05:30
6/14/2023
06:00
0.50 MIRU, MOVE MOB P Begin to spot sub over well 1C-157.
Observe steering slip guide damaged.
0.0 0.0
6/14/2023
06:00
6/14/2023
12:00
6.00 MIRU, MOVE MOB T Remove and repair steering slip guide.
SIMOPS - Mobilize wellhead equip into
cellar of 1C-157. Process 35 jts 13 3/8"
surface csg in the pipe shed. Install
conductor valves, stage 9 5/8" rams in
the BOP deck, PM on dust collector
system in the pits, install surface
annular hyd fittings, prep rig mats over
1C-157, change out hyd pump #2 and
repair, troubleshoot and repair HVAC
MCC cooling system.
0.0 0.0
6/14/2023
12:00
6/14/2023
19:30
7.50 MIRU, MOVE MOB T Prep sub structural areas for weld
repair. Decision to remove structural
slip post cross member and repair as
per QC repair procedure. SIMOPS -
complete BWM, service drag chain,
change out BOPE top rams to 9 5/8"
solid rams. TOTCO repairs on sensors
in pits. Release NES. Build cellar floor
for even working surfaces, Weld boiler
exhaust caps in place, work on rig audit
compliance checklist, inspect and clean
centrifuge. Work all 13 3/8" csg on
location.
0.0 0.0
6/14/2023
19:30
6/14/2023
21:00
1.50 MIRU, MOVE MOB T Complete welding and allow steering
guide components to cool. Stage tools
at sub for install of steering guide
components.
0.0 0.0
6/14/2023
21:00
6/15/2023
00:00
3.00 MIRU, MOVE MOB T Install steering guide components. 0.0 0.0
6/15/2023
00:00
6/15/2023
02:00
2.00 MIRU, MOVE MOB P Spot sub over 1C-157. 0.0 0.0
6/15/2023
02:00
6/15/2023
03:30
1.50 MIRU, MOVE MOB P Lower stompers. Observe tight
clearance for ODS stomper location w/
adjacent well plumbing. Notify Pad ops.
SIMOPS - Unpin stomper to slide
towards DS to gain extra clearance.
Remove sub tow tongue.
0.0 0.0
6/15/2023
03:30
6/15/2023
04:15
0.75 MIRU, MOVE MOB P Skid rig floor into drill position. SIMOPS
- shuffle rig mats.
0.0 0.0
6/15/2023
04:15
6/15/2023
05:00
0.75 MIRU, MOVE MOB P Spot pit module. 0.0 0.0
6/15/2023
05:00
6/15/2023
06:00
1.00 MIRU, MOVE MOB P Spot pump module. 0.0 0.0
6/15/2023
06:00
6/15/2023
07:00
1.00 MIRU, MOVE MOB P Spot pipeshed module. 0.0 0.0
6/15/2023
07:00
6/15/2023
07:30
0.50 MIRU, MOVE MOB P Spot motor module. 0.0 0.0
6/15/2023
07:30
6/15/2023
08:00
0.50 MIRU, MOVE MOB P Spot rock washer. - SIMOPS - Begin
connection of interconnects.
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 8/2/2023
Page 2/37
1C-157
Report Printed: 8/17/2023
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)
6/15/2023
08:00
6/15/2023
11:00
3.00 MIRU, MOVE RURD P Work on rig acceptance checklist,
connect pumps to pits interconnect,
secure cellar windfalls. M/U kill line,
choke line, cement line @ flow line
hallway and gen cold start room. Obtain
RKB's.
0.0 0.0
6/15/2023
11:00
6/15/2023
12:00
1.00 MIRU, MOVE RURD P Install skate guide rail. SIMOPS - Work
on BOPE deck kill line blank flange.
Install BOPE deck hyd lines. Secure
mezz landing corridor/walkway.
Continue to work interconnects.
0.0 0.0
6/15/2023
12:00
6/15/2023
14:30
2.50 MIRU, MOVE RURD P Berm cellar and rock washer cuttings
tank areas. Ready pits centrifuge for
surface drilling. Install pipe skate winch
cables. Cont to prep pits for surface.
Double check all valves and lines for
plugs and caps.
0.0 0.0
6/15/2023
14:30
6/15/2023
16:00
1.50 MIRU, MOVE NUND P Install 3" outlet to starting head f/ black
water use. Install koomey lines to
surface annular and knife valve.
SIMOPS - install geranimo line.
Replace seals on blind/shear rams.
Accept rig at 16:00 hrs.
0.0 0.0
6/15/2023
16:00
6/15/2023
19:00
3.00 MIRU, MOVE NUND P N/U surface riser to 21¼ annular. Install
upper riser to bell niple. SIMOPS - load
pipe shed w/ BHA.
0.0 0.0
6/15/2023
19:00
6/15/2023
21:00
2.00 MIRU, MOVE RURD P L/D 4" handling equipment off the rig
floor. P/U 5" handling equipment to the
rig floor. SIMOPS - load pipe shed w/ 5"
DP. Take on 8.7 ppg spud mud into the
pits.
0.0 0.0
6/15/2023
21:00
6/15/2023
21:30
0.50 MIRU, MOVE BOPE P Perform Diverter test. Knife valve
opening time - 6 sec. Annular closing
time - 21 sec. Perform accumulator
test. Starting pressure = 3000 psi, after
function = 1900 psi, 200 psi attained = 4
sec's, full recovery = 41 sec. 6 nitrogen
bottles at 1992 psi. Test PVT gain/loss
and flow out alarms. Test LEL and H2S
alarms. AOGCC rep Sean Sullivan
waived witness to the test.
0.0 0.0
6/15/2023
21:30
6/15/2023
22:00
0.50 MIRU, MOVE RURD P Continue loading 8.7 ppg spud mud into
the pits. C/O iron roughneck dies to 5".
Stap 5" HWDP in the derrick.
0.0 0.0
6/15/2023
22:00
6/15/2023
22:30
0.50 MIRU, MOVE SFTY P Perform pre-spud derrick inspection. 0.0 0.0
6/15/2023
22:30
6/15/2023
22:45
0.25 MIRU, MOVE RURD P Install mousehole. 0.0 0.0
6/15/2023
22:45
6/15/2023
23:30
0.75 MIRU, MOVE SEQP P PT surface lines to 3500 psi (good). 0.0 0.0
6/15/2023
23:30
6/16/2023
00:00
0.50 MIRU, MOVE SFTY P Pre-Spud meeting with all hands. 0.0 0.0
6/16/2023
00:00
6/16/2023
00:30
0.50 MIRU, MOVE SVRG P Service iron roughneck, top drive,
drawworks, and air slips.
0.0 0.0
6/16/2023
00:30
6/16/2023
03:00
2.50 MIRU, MOVE RGRP T Trouble shoot pipe skate electical issue. 0.0 0.0
6/16/2023
03:00
6/16/2023
04:45
1.75 MIRU, MOVE BHAH P M/U 16" surface BHA #1 as per SLMB
DD. Tag fill at 67' MD.
0.0 67.0
6/16/2023
04:45
6/16/2023
05:00
0.25 MIRU, MOVE REAM P Clean out conductor F/ 67' MD T/ 75'
MD @ WOB = 1k, GPM = 400, PSI =
375, RPM = 20, TQ on = 1K, Flow out =
25%, P/U WT = 58K S/O WT = 58K, RT
WT = 58K. Encounter electrical faults
on the mud pumps.
67.0 75.0
Rig: DOYON 142
RIG RELEASE DATE 8/2/2023
Page 3/37
1C-157
Report Printed: 8/17/2023
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)
6/16/2023
05:00
6/16/2023
11:45
6.75 MIRU, MOVE RGRP T Trouble shoot mud pump electrical
issue. Find MODBUS com's to MCC
connection failure (fiber optic cable).
SIMOPS - Take on remaining spud mud,
prep shaker screens, mobilize tools and
equipment for drill line splice, mobilize
surface csg running equipment to the rig
floor (centralizers, plugs, swedge).
General housekeeping in all areas of the
rig. Weld splice on 1 3/8" drill line to
new spool per DDI weld procedure.
75.0 75.0
6/16/2023
11:45
6/16/2023
12:45
1.00 MIRU, MOVE SVRG P Continue to weld splice on 1 3/8" drill
line to new spool per DDI weld
procedure.
75.0 75.0
6/16/2023
12:45
6/16/2023
13:45
1.00 MIRU, MOVE REAM P Clean out conductor F/ 75' MD to 154'
MD @ WOB = 1k, GPM = 400, PSI =
330, RPM = 20, TQ on = 1-2K, Flow out
= 33%, P/U WT = 64K S/O WT = 64K,
RT WT = 64K.
75.0 154.0
6/16/2023
13:45
6/16/2023
14:45
1.00 SURFAC, DRILL DDRL P Drill 16" surface hole F/ 154‘MD- T/
227‘MD 227‘ TVD, WOB = 1-3k, GPM =
500, PSI = 450, RPM =160, TQ on = 3K,
Flow out = 33%, P/U WT = 65K S/O WT
= 65K, RT WT = 65K.
Observe 35 bbl loss out of the
conductor, with a constant 30-50 bph
losses.Observe water levels increaing in
offset cellars. Notify pad operators.
Start to dewater from a single spot and
observe water levels in several cellars
decrease.
154.0 227.0
6/16/2023
14:45
6/16/2023
15:30
0.75 SURFAC, DRILL BKRM P BROOH f/ 227' MD to 30' MD W/ GPM =
250, PSI = 250, RPM = 20, TQ on = 5K,
Flow out = 30%.
SIMOPS - Laid in 40 BBL 35 PPB LCM
pill in open hole to help with losses.
227.0 30.0
6/16/2023
15:30
6/16/2023
19:00
3.50 SURFAC, DRILL BHAH P M/U remaining directional BHA as per
slb DD to 180' MD.
30.0 180.0
6/16/2023
19:00
6/16/2023
19:30
0.50 SURFAC, DRILL REAM P Ream down F/ 180' MD T/ 204' MD @
550 GPM, 20 RPM, 1K TQ, 34% F/O,
610 PSI, 77K ROT WT. Shoot GYRO
survey. Cont to ream to btm w/ same
rate.
180.0 227.0
6/16/2023
19:30
6/17/2023
00:00
4.50 SURFAC, DRILL DDRL P Drill 16" surface hole F/ 227‘MD- T/
551‘MD 551‘ TVD, WOB = 1k, GPM =
550, PSI on = 765, PSI off = 743, RPM
= 40, TQ on = 2K, Flow out = 34%, P/U
WT = 98K S/O WT = 96K, RT WT =
93K. Pump 40 BBL 35 PPB LCM
sweeps at each connection. Drop soap
sticks at each connection.
Observe losses improve to less than 10
bph @ 457' MD. Total losses to
formation last 24 hrs - 147 bbls.
Dewatered cellars out at 15:00 hrs.
Dewatered cellars out at 20:30, recover
4 bbls of water. As of report time (5:00
on 6/17), no noticeable changes in
offset cellars.
227.0 551.0
Rig: DOYON 142
RIG RELEASE DATE 8/2/2023
Page 4/37
1C-157
Report Printed: 8/17/2023
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)
6/17/2023
00:00
6/17/2023
06:00
6.00 SURFAC, DRILL DDRL P Drill 16" surface hole F/ 551‘MD- T/
852‘MD 850‘ TVD, WOB = 1K, GPM =
550, PSI on = 928, PSI off = 921, RPM
= 40, TQ on = 3K, Flow out = 35%,
MWT = 9.1ppg, P/U WT = 98K S/O WT
= 96K, RT WT = 93K. Pump 20 BBL 35
PPB LCM sweeps at each connection.
Drop soap sticks at each connection.
551.0 852.0
6/17/2023
06:00
6/17/2023
12:00
6.00 SURFAC, DRILL DDRL P Drill 16" surface hole F/ 852‘MD- T/
1393‘MD 1366‘ TVD, WOB = 12K, GPM
= 550, PSI on = 1160, PSI off = 1020,
RPM = 40, TQ on = 7K, Flow out =
35%,, MWT = 9.2 ppg, P/U WT = 105K
S/O WT = 102K, RT WT = 106K. Drop
soap sticks at each connection.
852.0 1,393.0
6/17/2023
12:00
6/17/2023
18:00
6.00 SURFAC, DRILL DDRL P Drill 16" surface hole F/ 1393‘MD- T/
1875‘ MD 1778‘ TVD, WOB = 12k, GPM
= 550, PSI on = 1160, PSI off = 1020,
RPM = 40, TQ on = 7K, Flow out =
35%,, MWT = 9.6 ppg, P/U WT = 105K
S/O WT = 102K, RT WT = 106K. Drop
soap sticks at each connection.
(Encountered hydrates at 1,160' MD /
157 units max gas)
1,393.0 1,875.0
6/17/2023
18:00
6/17/2023
19:30
1.50 SURFAC, DRILL DDRL P Drill 16" surface hole F/ 1875‘MD- T/
2066‘ MD 1938‘ TVD, WOB = 12k, GPM
= 650, PSI on = 1768, PSI off = 1603,
RPM = 40, TQ on = 8K, Flow out = 35%,
, MWT = 9.7 ppg, P/U WT = 1110K S/O
WT = 108K, RT WT = 109K. Drop soap
sticks at each connection.
1,875.0 2,066.0
6/17/2023
19:30
6/17/2023
19:45
0.25 SURFAC, TRIPCAS SRVY P Take final survey. Std back std #13.
SIMOPS - std back std #14
2,066.0 2,066.0
6/17/2023
19:45
6/18/2023
00:00
4.25 SURFAC, TRIPCAS BKRM P BROOH F/ 2066' T/ 1305' MD, GPM =
650, ICP = 1679, FCP = 1406, RPM =
40, TQ = 3-5K, Flow out = 35%,RT WT
= 104K. SIMOPS - Pump 35 bbl 10 ppb
nut plug w/ 1% drill zone @ 2,063' MD.
2,066.0 1,305.0
6/18/2023
00:00
6/18/2023
04:30
4.50 SURFAC, TRIPCAS BKRM P BROOH F/ 1305' T/ 274' MD, GPM =
650, ICP = 1406, FCP = 1000, RPM =
40, TQ = 3-8K, Flow out = 35%,RT WT
= 74K.
1,305.0 274.0
6/18/2023
04:30
6/18/2023
04:45
0.25 SURFAC, TRIPCAS OWFF P OWFF (static). 274.0 274.0
6/18/2023
04:45
6/18/2023
05:30
0.75 SURFAC, TRIPCAS BKRM P Cont to BROOH F/ 274' MD T/ 180' MD
w/ GPM = 650, PSI = 1000, RPM = 20,
TQ = 1K, Flow out = 35%,RT WT = 64K.
SIMOPS - Pump 30 bbls of 10 ppg / 1%
drillzone sweep.
274.0 180.0
6/18/2023
05:30
6/18/2023
08:15
2.75 SURFAC, TRIPCAS BHAH P L/D surface BHA as per SLB DD/MWD. 180.0 0.0
6/18/2023
08:15
6/18/2023
09:15
1.00 SURFAC, TRIPCAS BHAH P Clear and clean rig floor. 0.0 0.0
6/18/2023
09:15
6/18/2023
10:45
1.50 SURFAC, CASING RURD P R/U Doyon csg running equipment. 0.0 0.0
6/18/2023
10:45
6/18/2023
11:45
1.00 SURFAC, CASING PUTB P Dummy run surface csg hanger. 0.0 0.0
6/18/2023
11:45
6/18/2023
12:00
0.25 SURFAC, CASING SFTY P PJSM on running 13 3/8" surface csg. 0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 8/2/2023
Page 5/37
1C-157
Report Printed: 8/17/2023
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)
6/18/2023
12:00
6/18/2023
20:00
8.00 SURFAC, CASING PUTB P RIH w/ 13 3/8" 68# Hyd563 L-80 surface
csg T/ 2,022' MD S/O wt - 119K. Tq
connections to 25K ft/lbs. Install bow
spring centralizer at ea connection.
Bakerlok shoe track. Monitor disp on pit
#5. Filling on the fly and topping off
every 10 jts.
0.0 2,022.0
6/18/2023
20:00
6/18/2023
20:45
0.75 SURFAC, CASING HOSO P M/U hanger and landing jt. 2,022.0 2,022.0
6/18/2023
20:45
6/18/2023
21:00
0.25 SURFAC, CASING WASH P Wash dn @ ½ BPM, 90 PSI, 1% F/O.
120K S/O WT.
2,022.0 2,061.0
6/18/2023
21:00
6/18/2023
23:45
2.75 SURFAC, CEMENT CIRC P Circ and condition mud. Stage pumps
up to 7 BPM, ICP = 95 w/ 17% F/O,
FCP = 90 w/ 24% F/O. Recip pipe 20'
alternation stop points and landing out
every 3rd stroke. Observe losses at 8
bpm. Decision made to stay at 7 bpm.
Total stks = 7160(721 bbls). 3924 stks
were at 7 bpm(395 bbls)
2,061.0 2,061.0
6/18/2023
23:45
6/19/2023
00:00
0.25 SURFAC, CEMENT RURD P Shut down pumps and R/U cement line. 2,061.0 2,061.0
6/19/2023
00:00
6/19/2023
00:30
0.50 SURFAC, CEMENT SFTY P PJSM on cementing surface csg.
Simops - Break circ through cement line
staging pumps up to 7 BPM.
2,061.0 2,061.0
6/19/2023
00:30
6/19/2023
04:30
4.00 SURFAC, CEMENT CMNT P Pump 5bbls fresh water. Test lines to
1000 psi low & 3500 psi high (good).
Pump 60 bbls of spacer 4 bpm, ICP -
75, FCP - 50. 13% Flow out. Load btm
plug. (Cmt Wet @ 01:33 hrs) Batch up
and pump 364 bbls 10.7 ppg Class G
cement - pump rate 5 bpm, ICP - 90,
FCP - 115, 17% Flow out. Chase with 70
bbls of 15.8 tail cement 4 bpm, 110 psi,
14% Flow out. Load top plug.
Halliburton pump 20 bbls water. Swap to
rig and displace with 9.6 ppg pre treated
spud mud @ 7 bpm ICP - 191 psi. 30%
F/O. Decreased rate to 6bpm @ 105
bbl’s pumped, 165 psi. 33% F/O.
Decreased rate to 3 bpm 265 bbl
pumped - 373 psi. 11 % F/O. Plug
bumped @ 2734 stks (275.31 bbl)
pumped. Final circ. psi. 390 Pressure
up to 920 psi & hold for 5 minutes.
Bleed off pressure, Check floats good.
CIP 04:16 hrs 06/18/23. 80 bbls of
interface seen at surface and 107 bbls
of 10.7 ppg cement. Stroke pipe 20'
then reduce to 10' due to hanger
hanging up on riser. Set on ring every
3rd stroke. Set on ring at each fluid
rounding the corner. Final up wt - 200k,
s/o - 124k. Final stroke at 170 bbls into
displacement (observe 10.6+ cement at
surface)
2,061.0 2,061.0
6/19/2023
04:30
6/19/2023
05:15
0.75 SURFAC, CEMENT RURD P R/D & B/D cement lines. Clean cement
manifold valves. Jet flow line w/ black
water. Drain stack to cellar box. Flush
stack and annular with black water.
0.0 0.0
6/19/2023
05:15
6/19/2023
06:45
1.50 SURFAC, WHDBOP RURD P Remove landing jt per Vault rep. R/U
stap tongs to back out landing jt.
0.0 0.0
6/19/2023
06:45
6/19/2023
08:15
1.50 SURFAC, WHDBOP RURD P R/D Doyon Csg running equipment. 0.0 0.0
6/19/2023
08:15
6/19/2023
12:00
3.75 SURFAC, WHDBOP NUND P Nipple down diverter system. SIMOPS -
load shed with intermediate BHA. Clean
mud pits.
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 8/2/2023
Page 6/37
1C-157
Report Printed: 8/17/2023
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)
6/19/2023
12:00
6/19/2023
18:00
6.00 SURFAC, WHDBOP NUND P Nipple up wellhead and BOPE.
SIMOPS - install mousehole, obtain
RKB's. Load 49 jts of 9 5/8" csg into the
shed.
0.0 0.0
6/19/2023
18:00
6/19/2023
20:00
2.00 SURFAC, WHDBOP RURD P Install test plug as per Vault rep. M/U
2ea NC50 floor valves and 1ea NC50
dart.
0.0 0.0
6/19/2023
20:00
6/20/2023
00:00
4.00 SURFAC, WHDBOP BOPE P Test BOPE to 250 low, 5,000 high for
5/5 charted min. w/ the exception of the
manual operated & super choke tested
to 2,500 psi, and the annular to 250 low,
3500 high for 5/5 charted min. With the
9 5/8" test jt, test annular, 9 5/8" upr,
choke valves 1-14, manual operated
and super choke, choke & kill manuals
and HCR's, 4" kill line, 5" FOSV (x2), 5"
dart valve. Test PVT gain/loss and flow
out alarms. Test LEL and H2S alarms.
AOGCC rep Adam Earl witness the test.
0.0 0.0
6/20/2023
00:00
6/20/2023
02:30
2.50 SURFAC, WHDBOP BOPE P Perform accumulator test. Starting
pressure=2950 psi, after function= 1850
psi, 200 psi attained=7 sec's, full
recovery=94 sec. 6 nitrogen bottles at
2000 psi.Test blind shear rams 250 psi
low and 500 psi high, Test annular with
5" and 3 1/2" x 6" VBR's 250 low and
5000 psi high. Test gas alarms, PVT and
flow show. 1 F/P on 4" dart valve.
Functioned and re-test was good.
Witness by AOGCC Adam Earl.
0.0 0.0
6/20/2023
02:30
6/20/2023
02:45
0.25 SURFAC, WHDBOP RURD P Pull test plug and set wear ring as per
Vault Rep (ID =12.37" OD= 13.44"
Length =33").
0.0 0.0
6/20/2023
02:45
6/20/2023
04:00
1.25 SURFAC, WHDBOP RURD P Rig Down/Blow down all testing
equipment. R/U on annulus valves for
testing casing. P/U BHA components via
beaver slide.
0.0 0.0
6/20/2023
04:00
6/20/2023
04:30
0.50 SURFAC, DRILLOUT PRTS P Test surface casing to 3000 psi 30 min
on chart @ 0.5 spm. Pumped 4.6 bbls.
Bled back 3.8 bbls.
0.0 0.0
6/20/2023
04:30
6/20/2023
05:00
0.50 SURFAC, DRILLOUT SFTY P PJSM for picking interm BHA as per
SLB.
0.0 0.0
6/20/2023
05:00
6/20/2023
08:00
3.00 SURFAC, DRILLOUT BHAH P P/U 12-1/4" BHA as per SLB. 0.0 630.0
6/20/2023
08:00
6/20/2023
08:30
0.50 SURFAC, DRILLOUT BHAH P Move 3 stands of heavy weight drill pipe
in derrick.
630.0 630.0
6/20/2023
08:30
6/20/2023
09:45
1.25 SURFAC, DRILLOUT TRIP P RIH W/ 12-1/4" Interm BHA F/ 630' to
1948' MD. S/O= 93K.
630.0 1,948.0
6/20/2023
09:45
6/20/2023
10:00
0.25 SURFAC, DRILLOUT SRVY P Shallow hole test MWD tools. Wash and
Ream F/ 1948' to TOC @ 1958' MD.
GPM=550. PSI=780.
1,948.0 1,958.0
6/20/2023
10:00
6/20/2023
12:00
2.00 SURFAC, DRILLOUT DRLG P Drill out 13-3/8" cement and shoe track
as per SLB/DD adjusting parameters as
needed F/ 1958' to 1960' MD.
GPM=560, PSI=780, RPM=40, TQ=4k.
1,958.0 1,960.0
6/20/2023
12:00
6/20/2023
18:00
6.00 SURFAC, DRILLOUT DRLG P Drill out 13-3/8" shoe track as per
SLB/DD adjusting parameters as
needed F/ 1960' to 2057' MD. Float
collar @ 1965' MD, GPM=560-600,
PSI=780-890, RPM=60-80, TQ=4-10k.
1,960.0 2,057.0
6/20/2023
18:00
6/20/2023
20:45
2.75 SURFAC, DRILLOUT DRLG P Drill out 13-3/8" shoe track as per
SLB/DD adjusting parameters as
needed F/ 2057' to 2066' MD. GPM=560
-600, PSI=780-890, RPM=60-80, TQ=4-
10k. Dress off shoe 3x as per DD.
2,057.0 2,066.0
Rig: DOYON 142
RIG RELEASE DATE 8/2/2023
Page 7/37
1C-157
Report Printed: 8/17/2023
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)
6/20/2023
20:45
6/20/2023
22:00
1.25 SURFAC, DRILLOUT DDRL P Drill new hole from 2066' to 2086' MD.
GPM=550, RPM=80, PSI=700, TQ=6k,
F/O 31%, ECD=9.71 PPG, WOB=3K.
BROOH to 2040' MD. P/U=100k
RT=100k.
2,066.0 2,086.0
6/20/2023
22:00
6/20/2023
23:00
1.00 SURFAC, DRILLOUT LOT P R/U for LOT. Flood lines and perform
LOT. @ 5 spm, 1 bbl pumped, 0.25 bbl
bled back. Observed break over @ 333
psi = EMW 12.8 ppg. R/D blow down
lines.
2,040.0 2,040.0
6/20/2023
23:00
6/20/2023
23:30
0.50 INTRM1, DRILL SVRG P Rig service. Grease top drive and crown
inspection.
2,040.0 2,040.0
6/20/2023
23:30
6/21/2023
00:00
0.50 INTRM1, DRILL SRVY P Kelly up and shoot data survey as per
SLB.
2,040.0 2,040.0
6/21/2023
00:00
6/21/2023
00:30
0.50 INTRM1, DRILL WASH P Wash and Ream F/2040 to 2086' MD.
GPM=700, RPM=80, PSI=1094, F/O-
34%, TQ=2-8k, while displacing well
with 9.0 PPG FWP. P/U=103k,
S/O=103k.
2,040.0 2,086.0
6/21/2023
00:30
6/21/2023
06:00
5.50 INTRM1, DRILL DDRL P Drill 12-1/4" intermediate hole F/2086' to
2544' MD 2313' TVD, WOB=6k,
GPM=800, PSI=919, RPM=120, TQ=4k,
F/O 38%, ECD=9.66, P/U=113k,
S/O=108k, RT=108k, Mud/wt 9.0 ppg
2,086.0 2,544.0
6/21/2023
06:00
6/21/2023
12:00
6.00 INTRM1, DRILL DDRL P Drill 12-1/4" intermediate hole F/2544' to
3079' MD 2664' TVD, WOB=6k,
GPM=800, PSI=1017, RPM=120,
TQ=4k, F/O 38%, ECD=9.85, P/U=119k,
S/O=110k, RT=110k, Mud/wt 9.0 ppg.
Pump Hi-Vis sweep every 500'.
ADT=8.06, BIT=8.31, Jars=17.31.
2,544.0 3,079.0
6/21/2023
12:00
6/21/2023
18:00
6.00 INTRM1, DRILL DDRL P Drill 12-1/4" intermediate hole F/ 3079'
to 3739' MD 2980' TVD, WOB=6k,
GPM=800, PSI=1396, RPM=120,
TQ=4k, F/O 38%, ECD=9.93,
P/U=126k, S/O=109k, RT=112k, Mud/wt
9.0 ppg. Pump Hi-Vis sweep every 500'.
3,079.0 3,739.0
6/21/2023
18:00
6/22/2023
00:00
6.00 INTRM1, DRILL DDRL P Drill 12-1/4" intermediate hole F/ 3739'
to 4497' MD 3156' TVD, WOB=12k,
GPM=800, PSI=1483, RPM=120,
TQ=6k, F/O 38%, ECD=10.04,
P/U=123k, S/O=102k, RT=110k, Mud/wt
9.0 ppg. Pump Hi-Vis sweep every 500'.
ADT=7.70, BIT=16.01, Jars=25.01.
3,739.0 4,497.0
6/22/2023
00:00
6/22/2023
06:00
6.00 INTRM1, DRILL DDRL P Drill 12-1/4" intermediate hole F/ 4497'
to 5254' MD 3229' TVD, WOB=11k,
GPM=880, PSI=1650, RPM=120,
TQ=7k, F/O 40%, ECD=10.29+,
P/U=122k, S/O=100k, RT=108k, Mud/wt
9.0 ppg. Pump Hi-Vis sweep every 500'.
ADT=4.28, BIT=20.29, Jars=38.29.
4,497.0 5,254.0
6/22/2023
06:00
6/22/2023
12:00
6.00 INTRM1, DRILL DDRL P Drill 12-1/4" intermediate hole F/ 5254 to
6066' MD 3308' TVD, WOB=10k,
GPM=880, PSI=11755, RPM=120,
TQ=8k, F/O 40%, ECD=10.49,
P/U=129k, S/O=101k, RT=11k, Mud/wt
9.1 ppg. Pump Hi-Vis sweep every 500'.
ADT=4.13, BIT=24.42, Jars=42.42.
5,254.0 6,066.0
Rig: DOYON 142
RIG RELEASE DATE 8/2/2023
Page 8/37
1C-157
Report Printed: 8/17/2023
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)
6/22/2023
12:00
6/22/2023
19:30
7.50 INTRM1, DRILL DDRL P Drill 12-1/4" intermediate hole F/ 6066 to
6859' MD 3392' TVD, WOB=8k,
GPM=880, PSI=1887, RPM=120,
TQ=11k, F/O 40%, ECD=10.28,
P/U=133k, S/O=96k, RT=113k, Mud/wt
9.1 ppg. Pump Hi-Vis sweep every 500'.
ADT=4.52, BIT=28.94, Jars=46.94.
TD called due to DTF with ARC and
resistivity sensors failed and log quality
not good enough to land intermediate
hole section.
6,066.0 6,859.0
6/22/2023
19:30
6/22/2023
20:30
1.00 INTRM1, DRILL CIRC T Take final survey. DD sent downlink
prior to BROOH. Perform well bore
clean up. Pump 30 bbls LCM sweep and
circulate out while BROOH F/ 6859' to
6764' MD. GPM=880, PSI=1874,
RPM=80, TQ=6k, F/O 40%,
ECD=10.23, P/U=106k, S/O=106k,
RT=106k, Mud/wt 9.1 ppg.
6,859.0 6,764.0
6/22/2023
20:30
6/23/2023
00:00
3.50 INTRM1, DRILL BKRM T BROOH F/ 6764' MD to 6012' MD,
GPM=800, PSI=1483, RPM=80, TQ=6k,
F/O 37%, ECD=10.19, P/U=105k,
S/O=105k, RT=105k, Mud/wt 9.1 ppg.
6,764.0 6,012.0
6/23/2023
00:00
6/23/2023
06:00
6.00 INTRM1, DRILL BKRM T BROOH F/ 6012' MD to 4030' MD,
GPM=800, PSI=1300, RPM=80, TQ=5k,
F/O 37%, ECD=10.51, P/U=107k,
S/O=107k, RT=107k, Mud/wt 9.1 ppg.
Monitor Displacement Via pits 1-5.
6,012.0 4,030.0
6/23/2023
06:00
6/23/2023
12:00
6.00 INTRM1, DRILL BKRM T BROOH F/ 4030' MD to 2400' MD,
GPM=800, PSI=1070, RPM=80, TQ=4k,
F/O 37%, ECD=10.19, P/U=102k,
S/O=102k, RT=102k, Mud/wt 9.1 ppg.
Monitor Displacement Via pits 1-5.
Encounter significant cuttings unloading
while back reaming through the K-15.
1B WIF not able to unload ACB's fast
enough and process cuttings. The WIF
ended up breaking down. Had to slow
back reaming speed to aid in process
cuttings on surface and filling up ACB's.
Had to dispose of cuttings in back up
class 2 pit.
4,030.0 2,400.0
6/23/2023
12:00
6/23/2023
13:30
1.50 INTRM1, DRILL BKRM T BROOH F/ 2400' MD to 2038' MD,
GPM=800, PSI=935, RPM=80, TQ=3k,
F/O 37%, ECD=9.64, P/U=100k,
S/O=100k, RT=100k, Mud/wt 9.1 ppg.
Monitor Displacement Via Pits 1-5.
2,400.0 2,038.0
6/23/2023
13:30
6/23/2023
15:00
1.50 INTRM1, DRILL CIRC T Circulate, Rotate, and Recip F/ 2038'
MD to 1944' MD GPM=800, PSI=935,
RPM=80, TQ=3k, F/O 37%, ECD=9.64,
P/U=100k, S/O=100k, RT=100k, Mud/wt
9.1 ppg. While pumping LCM/Bit Balling
sweep to clean BHA and casing.
Saw significant cuttings unloading while
performing wellbore casing clean up.
2,038.0 1,944.0
6/23/2023
15:00
6/23/2023
15:15
0.25 INTRM1, DRILL OWFF T OWFF - Well Static. 1,944.0 1,944.0
6/23/2023
15:15
6/23/2023
16:45
1.50 INTRM1, DRILL TRIP T POOH F/ 1944' MD to 267' MD W/ 5"
drill pipe racking back in derrick. P/U
74K. Monitor Displacement Via Trip
Tank.
1,944.0 267.0
6/23/2023
16:45
6/23/2023
17:15
0.50 INTRM1, DRILL CIRC T Pump 30 bbl LCM sweep to clean up
BHA at GPM=750, PSI=550. RPM-40.
267.0 267.0
Rig: DOYON 142
RIG RELEASE DATE 8/2/2023
Page 9/37
1C-157
Report Printed: 8/17/2023
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)
6/23/2023
17:15
6/23/2023
20:45
3.50 INTRM1, DRILL BHAH T POOH lay down directional BHA as per
SLB Rep.
267.0 0.0
6/23/2023
20:45
6/23/2023
21:15
0.50 INTRM1, DRILL SVRG T Change out Wash Pipe on Top Drive. 0.0 0.0
6/23/2023
21:15
6/24/2023
00:00
2.75 INTRM1, DRILL BHAH T M/U 12 1/4" Interm BHA #3 as per SLB
DD. P/U 5 stands heavy weight drill pipe
in derrick to 342' MD. SIMOPS - change
liners in mud pumps 1 and 2.
0.0 342.0
6/24/2023
00:00
6/24/2023
01:00
1.00 INTRM1, DRILL TRIP T RIH on elevators w/12-1/4" interm BHA
#3 f/ 624' to 1950' MD S/O=95k
Monitoring displacement Via Trip Tank
624.0 1,950.0
6/24/2023
01:00
6/24/2023
03:00
2.00 INTRM1, DRILL TRIP T C/O mud pump liners f/ 6" to 6.5" 1,950.0 1,950.0
6/24/2023
03:00
6/24/2023
09:00
6.00 INTRM1, DRILL TRIP T RIH on elevators w/12-1/4" interm BHA
#3 f/1950' to 6763' MD S/O=98k
Monitoring displacement Via pits 1-5,
Filling pipe every 20 stands
624.0 6,763.0
6/24/2023
09:00
6/24/2023
09:45
0.75 INTRM1, DRILL WASH T Wash and Ream F/6763' to 6859' MD @
GPM=900, PSI=1772, RPM=40, F/O=41
TQ-6.5, P/U=11, S/O=111, RT=111
While DD sending downlinks.
6,763.0 6,859.0
6/24/2023
09:45
6/24/2023
12:00
2.25 INTRM1, DRILL DDRL P Drill 12-1/4" intermediate hole F/ 6859'
to 7044' MD 3415' TVD, WOB=11k,
GPM=900, PSI=1776, RPM=120,
TQ=11k, F/O 41%, ECD=9.56,
P/U=133k, S/O=96k, RT=113k, Mud/wt
9.1 ppg. Pump Hi-Vis sweep every 500'.
ADT=1.99, BIT=1.99, Jars=46.92
6,859.0 7,044.0
6/24/2023
12:00
6/24/2023
16:30
4.50 INTRM1, DRILL DDRL P Drill 12-1/4" intermediate hole F/ 7044'
to 7421' MD 3461' TVD, WOB=11k,
GPM=900, PSI=1776, RPM=120,
TQ=11k, F/O 41%, ECD=9.56,
P/U=133k, S/O=96k, RT=113k, Mud/wt
9.1 ppg. Pump Hi-Vis sweep every 500'.
ADT=2.80, BIT=4.79, Jars= 49.72.
(Not able to maintain directional control
and assembly not turning/azim and
drifting from plan)
7,044.0 7,421.0
6/24/2023
16:30
6/24/2023
17:15
0.75 INTRM1, DRILL SRVY P Shoot survey and send downlinks as per
MWD. Discuss plan forward options with
drilling team and town team. Decision
made to POOH and C/O BHA.
7,421.0 7,421.0
6/24/2023
17:15
6/24/2023
19:15
2.00 INTRM1, DRILL CIRC T Perform well bore clean up. Circulate,
Rotate and Recip, F/ 7418' to 7235' MD.
GPM=900, PSI=1793, F/O=41%,
RPM=30, TQ=6k, ECD=9.65, P/U=107,
S/O=107. Total strokes pumped 15200,
B/U 2x.
7,418.0 7,235.0
6/24/2023
19:15
6/24/2023
19:30
0.25 INTRM1, DRILL OWFF T OWFF well - Static. 7,235.0 7,235.0
6/24/2023
19:30
6/25/2023
00:00
4.50 INTRM1, DRILL TRIP T POOH F/ 7235' to 4850' MD with 5" drill
pipe rack in derrick. P/U 115k Monitor
displacement on trip tank.
7,235.0 4,850.0
6/25/2023
00:00
6/25/2023
05:30
5.50 INTRM1, DRILL TRIP T POOH F/ 4850' to 2038' MD with 5" drill
pipe rack in derrick. P/U 102k. Monitor
displacement on trip tank.
4,850.0 2,038.0
6/25/2023
05:30
6/25/2023
06:00
0.50 INTRM1, DRILL CIRC T Circulate, Rot and Recip, f/ 2038' to
1945' MD, GPM=850, PSi=980, F/O=40,
RPM=20, TQ=2, ECD=9.47, RT=95k
2,038.0 1,945.0
6/25/2023
06:00
6/25/2023
07:00
1.00 INTRM1, DRILL TRIP T POOH F/ 1945' to 260' MD with 5" drill
pipe rack in derrick. P/U 70k. Monitor
displacement on trip tank.
1,945.0 260.0
Rig: DOYON 142
RIG RELEASE DATE 8/2/2023
Page 10/37
1C-157
Report Printed: 8/17/2023
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)
6/25/2023
07:00
6/25/2023
09:30
2.50 INTRM1, DRILL SLPC T PJSM. Slip and cut 44' drill line.
Deadman TQ witnessed by Driller and
Tool Pusher. Working on MP2's and
housekeeping, while waiting orders from
town on next BHA.
260.0 260.0
6/25/2023
09:30
6/25/2023
11:30
2.00 INTRM1, DRILL BHAH T L/D BHA #3 as per DD, F/ 260' to
surface.
260.0 0.0
6/25/2023
11:30
6/25/2023
12:00
0.50 INTRM1, DRILL CLEN T Clean and clear rig floor for next BHA
#4.
0.0 0.0
6/25/2023
12:00
6/25/2023
15:45
3.75 INTRM1, DRILL CLEN T Continue Housekeeping around rig,
Working on MP2's. Electrician
troubleshoot and repair ST-100, Change
suction screens on both mud pumps,
clean up debris around pad, while MWD
makes smart tools ready for BHA #4.
0.0 0.0
6/25/2023
15:45
6/25/2023
17:45
2.00 INTRM1, DRILL BHAH T PJSM on BHA #4. P/U BHA #4 as per
SLB DD, F/ surface to 163' MD. S/O
weight below jars 68k.
0.0 163.0
6/25/2023
17:45
6/25/2023
18:45
1.00 INTRM1, DRILL BHAH T TIH f/ 163' to 2050' MD, W/ 5" drill pipe
out of derrick, S/O=102k. Monitor
displacement on active pits 1-5 Filling
pipe every 20 stands.
163.0 2,050.0
6/25/2023
18:45
6/25/2023
19:00
0.25 INTRM1, DRILL SRVY T Shallow hole test MWD, Good test.
GPM=700, PSI=700, F/O=36%.
2,050.0 2,050.0
6/25/2023
19:00
6/25/2023
23:00
4.00 INTRM1, DRILL TRIP T TIH f/2050' to 7244' MD, W/ 5" drill pipe
out of derrick, S/O=88k. Monitor
displacement on active pits 1-5 Filling
pipe every 20 stands, Calc
Displacement 69.25 bbls, Actual
Displacement 57.bbls.
2,050.0 7,244.0
6/25/2023
23:00
6/26/2023
00:00
1.00 INTRM1, DRILL WASH T Wash and Ream F/ 7244' to 7375' MD.
GPM=650, PSI=1130, F/O=34%,
RPM=40, TQ=8k,RT=111k.
7,244.0 7,375.0
6/26/2023
00:00
6/26/2023
00:30
0.50 INTRM1, DRILL WASH T Wash and Ream F/7375' to 7420' MD.
GPM=650, PSI=1130, F/O=34%,
RPM=40, TQ=8k, RT=111k.
7,375.0 7,420.0
6/26/2023
00:30
6/26/2023
06:00
5.50 INTRM1, DRILL DDRL P Drill 12-1/4" intermediate hole F/ 7420'
to 8374' MD 3636' TVD, WOB=10k,
GPM=1050, PSI=2410, RPM=120,
TQ=13.5k, F/O 43%, ECD=9.97,
P/U=114k, S/O=101k, RT=122k, Mud/wt
9.2 ppg. ADT=2.45, BIT=2.45,
Jars=52.63.
7,420.0 8,374.0
6/26/2023
06:00
6/26/2023
12:00
6.00 INTRM1, DRILL DDRL P Drill 12-1/4" intermediate hole F/ 8374'
to 8940' MD 3786' TVD, WOB=12k,
GPM=900, PSI=2154, RPM=120,
TQ=13k, F/O 39%, ECD=9.95,
P/U=144k, S/O=101k, RT=122k, Mud/wt
9.0 ppg. ADT=3.16, BIT=5.61,
Jars=55.33.
8,374.0 8,940.0
6/26/2023
12:00
6/26/2023
18:00
6.00 INTRM1, DRILL DDRL P Drill 12-1/4" intermediate hole F/ 8940'
to 9695' MD 3847' TVD, WOB=16k,
GPM=900, PSI=2168, RPM=120,
TQ=13k, F/O 40%, ECD=10.76,
P/U=140k, S/O=105k, RT=124k, Mud/wt
9.2 ppg. ADT=3.11, BIT=8.72,
Jars=58.44.
8,940.0 9,695.0
6/26/2023
18:00
6/26/2023
20:15
2.25 INTRM1, DRILL DDRL P Drill 12-1/4" intermediate hole F/9695' to
9884' MD 33861 TVD, WOB=18k,
GPM=900, PSI=2326, RPM=120,
TQ=15k, F/O 40%, ECD=10.96,
P/U=140k, S/O=105k, RT=124k, Mud/wt
9.2 ppg. ADT=.69, BIT=9.41,
Jars=59.13.
9,695.0 9,884.0
Rig: DOYON 142
RIG RELEASE DATE 8/2/2023
Page 11/37
1C-157
Report Printed: 8/17/2023
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)
6/26/2023
20:15
6/26/2023
20:30
0.25 INTRM1, DRILL OWFF P OWFF - Well static. 9,884.0 9,884.0
6/26/2023
20:30
6/27/2023
00:00
3.50 INTRM1, DRILL BKRM P BROOH F/ 9884' to 9409' MD
GPM=750, PSI=1811, RPM=80, TQ=80,
F/O=36%, ECD=10.63, P/U=137k,
S/O=101k, RT=122k
9,884.0 9,409.0
6/27/2023
00:00
6/27/2023
06:00
6.00 INTRM1, DRILL BKRM P BROOH F/ 9409' to 8600' MD
GPM=800, PSI=1944, RPM=100,
TQ=10, F/O=36%, ECD=11.12,
RT=110k
9,409.0 8,600.0
6/27/2023
06:00
6/27/2023
12:00
6.00 INTRM1, DRILL BKRM P BROOH F/ 8600' to 7616' MD,
GPM=1000, PSI=2093, RPM=100,
TQ=6, F/O=42%, ECD=10.72
RT=110kPumping LCM sweeps, Bit
Balling and PHPA sweeps.
8,600.0 7,616.0
6/27/2023
12:00
6/27/2023
18:00
6.00 INTRM1, DRILL BKRM P BROOH F/ 7616' to 6324' MD,
GPM=850, PSI=1557, RPM=100, TQ=5,
F/O=39%, ECD=10.21, RT=106k
Pumping LCM sweeps, Bit Balling and
PHPA sweeps.
7,616.0 6,324.0
6/27/2023
18:00
6/28/2023
00:00
6.00 INTRM1, DRILL BKRM P BROOH F/6324' to 5543' MD,
GPM=800, PSI=1257, RPM=100,
TQ=10, F/O=37%, ECD=9.74,
RT=105k Pumping LCM sweeps, Bit
Balling and PHPA sweeps f/ hole
cleaning. ( Major increase in cutting to
shaker 6358' Sweep and 5565' sweep.)
6,324.0 5,543.0
6/28/2023
00:00
6/28/2023
06:00
6.00 INTRM1, DRILL BKRM P BROOH F/ 5543' to 4364' MD,
GPM=800, PSI=1257, RPM=100,
TQ=10, F/O=37%, ECD=9.95,
RT=105k Pumping LCM sweeps, Bit
Balling and PHPA sweeps f/ hole
cleaning. every 500'
5,543.0 4,364.0
6/28/2023
06:00
6/28/2023
12:00
6.00 INTRM1, DRILL BKRM P BROOH F/4364' to 3272' MD,
GPM=800, PSI=1257, RPM=100,
TQ=10, F/O=37%, ECD=9.77, RT=96k
Pumping LCM sweeps, Bit Balling and
PHPA sweeps f/ hole cleaning. every
500'
4,364.0 3,272.0
6/28/2023
12:00
6/28/2023
17:30
5.50 INTRM1, DRILL BKRM P BROOH F/3272 to 2042' MD,
GPM=800, PSI=1257, RPM=100,
TQ=10, F/O=37%, ECD=9.80, RT=97k
Pumping LCM sweeps, Bit Balling and
PHPA sweeps f/ hole cleaning,
3,272.0 2,042.0
6/28/2023
17:30
6/28/2023
20:30
3.00 INTRM1, DRILL CIRC P Circulate Rot,Recip, F/ 2042 to 1950'
MD, GPM=800, PSI=1257, RPM=100,
TQ=10, F/O=37%, ECD=9.80, RT=97k
Pumping LCM sweeps, Bit Balling and
PHPA sweeps f/ hole cleaning, Pump 2x
30 bbls weighted sweep to surface. 1st
sweep hole unloaded 20% extra, 2nd
hole unloaded 10% extra and circulate
clean.
2,042.0 1,950.0
6/28/2023
20:30
6/29/2023
00:00
3.50 INTRM1, DRILL TRIP P TIH f/ 1950' to 5875' W/ 5" dril pipe filling
pipe every 20 stands
1,950.0 5,875.0
6/29/2023
00:00
6/29/2023
00:15
0.25 INTRM1, DRILL TRIP P TIH f/ 5875' to 6125' W/ 5" drill pipe
filling pipe every 20 stands
5,875.0 6,125.0
6/29/2023
00:15
6/29/2023
00:30
0.25 INTRM1, DRILL OWFF P OWFF well static 6,125.0 6,125.0
6/29/2023
00:30
6/29/2023
01:00
0.50 INTRM1, DRILL SVRG P Rig Service, Iron Roughneck grease
and clean dies.
6,125.0 6,125.0
6/29/2023
01:00
6/29/2023
01:30
0.50 INTRM1, DRILL SVRG P Riser air boot leaking, PJSM change out
boots on riser.
6,125.0 6,125.0
6/29/2023
01:30
6/29/2023
05:00
3.50 INTRM1, DRILL TRIP P TIH f/6125' to 9698' MD W/ 5" drill pipe
filling pipe every 20 stands
5,875.0 9,698.0
Rig: DOYON 142
RIG RELEASE DATE 8/2/2023
Page 12/37
1C-157
Report Printed: 8/17/2023
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)
6/29/2023
05:00
6/29/2023
06:00
1.00 INTRM1, DRILL TRIP P Wash down f/ 9698 to 9884' MD
GPM=750 PSI=1580 P/U-133, S/O=96
9,698.0 9,884.0
6/29/2023
06:00
6/29/2023
12:00
6.00 INTRM1, DRILL DDRL P Drill 12-1/4" intermediate hole F 9884' to
10301 MD 3907 TVD, WOB=10k,
GPM=900, PSI=2174, RPM=120,
TQ=12k, F/O 40%, ECD=10.02,
P/U=141k, S/O=103k, RT=119k, Mud/wt
9.4 ppg. ADT=.3.28, BIT=12.69,
Jars=62.41.
9,844.0 10,301.0
6/29/2023
12:00
6/29/2023
18:00
6.00 INTRM1, DRILL DDRL P Drill 12-1/4" intermediate hole F/10301
to 10721' MD 3921 TVD, WOB=11k,
GPM=900, PSI=2273, RPM=120,
TQ=14k, F/O 40%, ECD=10.05,
P/U=145k, S/O=98k, RT=123k, Mud/wt
9.4 ppg. ADT=.3.64, BIT=16.33,
Jars=62.35.
10,301.0 10,721.0
6/29/2023
18:00
6/29/2023
23:30
5.50 INTRM1, DRILL DDRL P Drill 12-1/4" intermediate hole F/10721'
to 11263' MD 3981'TVD, WOB=13k,
GPM=900, PSI=2420, RPM=120,
TQ=13k, F/O 40%, ECD=10.42,
P/U=148k, S/O=101k, RT=121k, Mud/wt
9.4 ppg. ADT=.2.90, BIT=19.23,
Jars=68.35.Obtain final survey,
Downlink RSS to neutral position, Send
real time data log command.
10,721.0 11,263.0
6/29/2023
23:30
6/29/2023
23:45
0.25 INTRM1, DRILL OWFF P OWFF Well Static 11,263.0 11,263.0
6/29/2023
23:45
6/30/2023
00:00
0.25 INTRM1, TRIPCAS CIRC P @ 11263' Circualte,Rotate,Recip Pump
30 BBLS 11.0 PPG weighted sweep,
Circualte to surface, Pump 3x B/U GPM-
900, PSI=2430, RPM=120, TQ=8k ECD-
10.50, P/U 139, S/O=103, RT=121
11,263.0 11,263.0
6/30/2023
00:00
6/30/2023
06:00
6.00 INTRM1, TRIPCAS BKRM P BROOH F/ 11263' to 10702' MD,
Circualte,Rotate,Recip Pump 30 BBLS
11.0 PPG weighted sweep, Circualte to
surface, Pump 3x B/U rack stand back
in derrick after each B/U, GPM-900,
PSI=2430, RPM=120, TQ=8k ECD-
10.50, P/U 139, S/O=103, RT=121
11,263.0 10,702.0
6/30/2023
06:00
6/30/2023
12:00
6.00 INTRM1, TRIPCAS BKRM P BROOH F/ 10702' to 9412' MD,
GPM=900, PSI=2200, RPM=120,
TQ=18, F/O=41%, ECD=10.21,
RT=113k
10,702.0 9,412.0
6/30/2023
12:00
6/30/2023
18:00
6.00 INTRM1, TRIPCAS BKRM P BROOH F/ 9412' to 7327' MD,
GPM=900, PSI=1090, RPM=120,
TQ=7k, F/O=41%, ECD=10.08,
RT=105k
9,412.0 7,327.0
6/30/2023
18:00
7/1/2023
00:00
6.00 INTRM1, TRIPCAS BKRM P BROOH F/ 3727 to 4883' MD,
GPM=900, PSI=1544, RPM=120,
TQ=5k, F/O=41%, ECD=9.95, RT=100k
7,327.0 4,883.0
7/1/2023
00:00
7/1/2023
06:00
6.00 INTRM1, TRIPCAS BKRM P BROOH F/4883' to 2888' MD,
GPM=900, PSI=1248, RPM=120,
TQ=5k, F/O=41%, ECD=9.77, RT=100k
4,883.0 2,888.0
7/1/2023
06:00
7/1/2023
12:00
6.00 INTRM1, TRIPCAS BKRM P BROOH F/ 2888' to 1907' MD,
GPM=900, PSI=1104, RPM=120,
TQ=2k, F/O=41%, ECD=9.76, RT=93k
2,888.0 1,907.0
Rig: DOYON 142
RIG RELEASE DATE 8/2/2023
Page 13/37
1C-157
Report Printed: 8/17/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
7/1/2023
12:00
7/1/2023
14:45
2.75 INTRM1, TRIPCAS BKRM P BROOH F/ 2888' to 1195' MD,
GPM=900, PSI=1102, RPM=80, TQ=2k,
F/O=41%, ECD=9.75, RT=93k.
Pumped 30 bbl 11 ppg weighted sweep
@ 2215' 50% increase in cuttings at
shakers. Followed w/ 3X Hi Vis sweeps
@ 1648', 1525', 1275', Notable increase
in cutting at shakers 15% to 25% on
@x sweeps and 3rd sweep was
minimal. When pulled in to shoe at
2062' no increase in pull or torque.
1,907.0 1,195.0
7/1/2023
14:45
7/1/2023
15:15
0.50 INTRM1, TRIPCAS OWFF P OWFF well static 1,195.0 1,195.0
7/1/2023
15:15
7/1/2023
17:00
1.75 INTRM1, TRIPCAS TRIP P TOOH from 1195' to 289' MD racking
pipe back in derrick. L/D HWT drill pipe
to shed, jars, to shed. P/U=58k,
S/O=58k
1,195.0 289.0
7/1/2023
17:00
7/1/2023
20:30
3.50 INTRM1, TRIPCAS BHAH P L/D BHA as per SLB DD, f/ 289' to
surface. P/U=48k S/O=48k
289.0 0.0
7/1/2023
20:30
7/1/2023
21:45
1.25 INTRM1, TRIPCAS WWWH P Pull wear ring as per Vault Rep, M/U
stack washer tool wash stack 6x times
@ GPM=900, PSI=780 RPM-40
0.0 0.0
7/1/2023
21:45
7/1/2023
22:30
0.75 INTRM1, CASING CLEN P Clean and Clear rig floor of BHA tools
and equipment. Ready rig floor for
casing tools
0.0 0.0
7/1/2023
22:30
7/2/2023
00:00
1.50 INTRM1, CASING RURD P P/U and M/U 9-5/8" casing running tools
as per Doyon casing Rep
0.0 0.0
7/2/2023
00:00
7/2/2023
00:45
0.75 INTRM1, CASING RURD P M/U 9-5/8" hanger and landing jt,
Dummy run hanger as per Vault Rep.
Good run.
0.0 0.0
7/2/2023
00:45
7/2/2023
01:30
0.75 INTRM1, CASING RURD P Cont. R/U casing equipment ready rig
floor to P/U and Run 9-5/8" casing
0.0 0.0
7/2/2023
01:30
7/2/2023
02:15
0.75 INTRM1, CASING PUTB P PJSM P/U shoe track, Baker lock each
connection, Verify shoe was pinned, RIH
to 206' MD Check floats, Floats good.
P/U=47K
S/O=47
0.0 206.0
7/2/2023
02:15
7/2/2023
06:00
3.75 INTRM1, CASING PUTB P RIH w/ 9-5/8" 40# L-80 HYD 563 as per
program to 1460' MD P/U=52 S/O=52
206.0 1,460.0
7/2/2023
06:00
7/2/2023
12:00
6.00 INTRM1, CASING PUTB P RIH w/ 9-5/8" 40# L-80 HYD 563 as per
program F/ 1460' to 3446' MD @ shoe
P/U=57 S/O=51, M/U floatation collar on
top of joint #47 P/U=60 S/O=50, Begin
filling pipe using fill up hose S/O=57
1,460.0 3,446.0
7/2/2023
12:00
7/2/2023
18:00
6.00 INTRM1, CASING PUTB P RIH w/ 9-5/8" 40# L-80 HYD 563 as per
program F/ 3446' to 5674' MD Cont.
filling pipe on the fly and topping off fill
every 10 joints. SIMOPS pre-treating
mud for cementing operations at pits
S/O=105
3,446.0 5,674.0
7/2/2023
18:00
7/3/2023
00:00
6.00 INTRM1, CASING PUTB P RIH w/ 9-5/8" 40# L-80 HYD 563 as per
program F/5674' to 7694' MD Cont.
filling pipe on the fly and topping off fill
every 10 joints. SIMOPS pre- treating
mud for cementing operations at pits
S/O=122
5,674.0 7,694.0
7/3/2023
00:00
7/3/2023
06:00
6.00 INTRM1, CASING PUTB P RIH w/ 9-5/8" 40# L-80 HYD 563 as per
program F/7694' to 9078 MD Cont.
filling pipe on the fly and topping off fill
every 10 joints. SIMOPS pre- treating
mud for cementing operations at pits
S/O=117
7,694.0 9,078.0
Rig: DOYON 142
RIG RELEASE DATE 8/2/2023
Page 14/37
1C-157
Report Printed: 8/17/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
7/3/2023
06:00
7/3/2023
12:00
6.00 INTRM1, CASING PUTB P RIH w/ 9-5/8" 40# L-80 HYD 563 as per
program F/9078' to 10169' MD Cont.
filling pipe on the fly and topping off fill
every 10 joints. SIMOPS pre- treating
mud for cementing operations at pits
S/O=115
9,078.0 10,169.0
7/3/2023
12:00
7/3/2023
18:00
6.00 INTRM1, CASING PUTB P RIH w/ 9-5/8" 40# L-80 HYD 563 as per
program F/10169' to 11125' MD Cont.
filling pipe on the fly and topping off fill
every 10 joints. SIMOPS pre- treating
mud for cementing operations at pits
S/O=112
10,169.0 11,125.0
7/3/2023
18:00
7/3/2023
18:30
0.50 INTRM1, CASING PUTB P RIH w/ 9-5/8" 40# L-80 HYD 563 as per
program F/11125' to 11214' MD Cont.
filling pipe on the fly and topping off fill
every 10 joints. SIMOPS pre- treating
mud for cementing operations at pits
S/O=115
11,125.0 11,214.0
7/3/2023
18:30
7/3/2023
19:15
0.75 INTRM1, CASING HOSO P M/U 9-5/8" hanger assy. W/ landing joint
as per Vault Rep RIH f/ 11214' to 11256'
MD shoe depth, land out hanger.
S/O=114k
11,214.0 11,256.0
7/3/2023
19:15
7/4/2023
00:00
4.75 INTRM1, CEMENT CIRC P Line up returns thru choke system to
open choke and top drive / volant CRT
to pit 1-6 for shearing out floatation sub,
close annular on 9-5/8" landing joint,
pressure up to 1348 psi 5.6 bbls
pumped observe shear, standpipe
pressure decrease back to 4 psi,
circulate thru choke at 8 BPM until
pressure increase at 1638 stroke
pumped,with returns to pits. when
pressure leveled off reduced pump rate
to 7 BPM PSi=408 psi Circulated
surface to surface 12500 strokes, Shut
down open annular circulate
conventional surface to surface 12500
strokes while treating mud at mud pits.
11,256.0 11,256.0
7/4/2023
00:00
7/4/2023
02:45
2.75 INTRM1, CEMENT CIRC P Cont. t/ circulate through 9-5/8" casing
with Volant tools, Surface to Surface @
7 bpm 385 psi.
11,256.0 11,256.0
7/4/2023
02:45
7/4/2023
06:00
3.25 INTRM1, CEMENT CIRC P Load indicator plug into landing jt. Pump
down w/ 8-3bpm/360-185psi f/
5262stks, Shear anchor sleeve(no
indication), Cont. t/ pump 5-3bpm/272-
200psi t/ Float collar f/ 7220stks,
Pressure up t/ 896 psi and rupture
indicator disc in plug, Pressure
decreased indicator disc burst. Cont
circulate and condition mud @
6bpm/321psi
11,256.0 11,256.0
7/4/2023
06:00
7/4/2023
08:00
2.00 INTRM1, CEMENT RURD P Load #1 Bottom plug. R/D Volant tool,
R/U Halliburton cement head and
equipment. Load #2 bottom plug and
Top plug in cement head. COP
witnessed. Prepare pits for cement Job.
PJSM
11,256.0 11,256.0
Rig: DOYON 142
RIG RELEASE DATE 8/2/2023
Page 15/37
1C-157
Report Printed: 8/17/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
7/4/2023
08:00
7/4/2023
13:45
5.75 INTRM1, CEMENT CMNT P Perform cement job f/ 9 5/8" int. csg as
per Halliburton program, Flood lines w/
5 bpm H2O 278 psi, PressureTest lines
t/ 4000psi, pump 77 bbls tuned 10.5 ppg
spacer @ 3.75 bpm/ 370 psi 12% f/o,
Drop #2 bottom plug, pump 370 bbls 14
ppg Lead cmt @ 6 bpm 140psi 14% f/o,
pump 138 bbls 15.3 ppg Tail cmt @ 4
bpm 135 psi 10% f/o, Drop top plug,
pump 20 bbls fresh H2O, line up t/ rig
pumps t/ displace. w/ 827 bbls @ 6 bpm
207 psi 14% f/o f/ 2620 stks. Cont.
displacement @ 6 bpm 770 psi F/O 13%
f/ 3200 strokes, Slow rate t/5 bpm 855
psi f/700 strokes, Slow rate t/4 bpm 887
psi f/240 strokes, Slow rate t/3 bpm @
847 psi, Bump plug @ 7010 strokes
pressure up to 1380 psi hold f/ 5 min.
Bleed off/ check floats good. Cement in
place at 1340 hrs
11,256.0 11,256.0
7/4/2023
13:45
7/4/2023
15:45
2.00 INTRM1, CEMENT RURD P R/D cement head, B/D cement lines,
clean valves, L/D landing joint, R/D
casing equipment and remove from rig
floor, Flush stack with fresh water.
11,256.0 11,256.0
7/4/2023
15:45
7/4/2023
18:00
2.25 INTRM1, WHDBOP WWSP P R/U set pack-off, Run in lock downs,
Test pack-off to 5000 psi f/ 10 min As
per Vault Rep and Cop Rep.
11,256.0 11,256.0
7/4/2023
18:00
7/4/2023
18:45
0.75 INTRM1, WHDBOP RURD P R/D pack-off running equipment, L/D 5"
HWDP, PJSM ready tools to change out
lower and upper rams.
11,256.0 11,256.0
7/4/2023
18:45
7/5/2023
00:00
5.25 INTRM1, WHDBOP SVRG P Change rams, t/ 2-7/8' x 5" Lowers and
3-1/2" x 6" uppers, change #1 and #2
pump liners t/ 6" Liners and swabs.
Clean mud pits, Change out saver sub t/
new NC50
11,256.0 11,256.0
7/5/2023
00:00
7/5/2023
01:00
1.00 INTRM1, WHDBOP SVRG P PJSM, P/U stack riser assy, Install
backup air boots on riser f/ contingency,
Grease HCR valves Choke and Kill and
manual valves on BOP mud cross.
0.0 0.0
7/5/2023
01:00
7/5/2023
01:30
0.50 INTRM1, WHDBOP PRTS P Install test plug W 5" drill pipe as per
Vault Rep.
0.0 0.0
7/5/2023
01:30
7/5/2023
02:30
1.00 INTRM1, WHDBOP PRTS P Flood BOPE/ Choke manifold w/ H2O
and purge air from lines and BOPE
system, line up for initial BOPE shell
test.
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 8/2/2023
Page 16/37
1C-157
Report Printed: 8/17/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
7/5/2023
02:30
7/5/2023
12:00
9.50 INTRM1, WHDBOP BOPE P Test BOPE's: All test T 250 psi low 3500
psi high for 5 charted min. w/ exception
of manual choke and super choke
tested 250 low and 2000 psi high for 5
charted min. W/ 5" pipe, Test annular, 3
1/2" x 6" upper rams, 2 7/8" x 5" lower
rams, W/ 4 1/2" pipe test, 3 1/2" x 6"
upper rams, 2 7/8" x 5" lower rams, W/ 2
7/8" pipe test annular, 2 7/8" x 5 lower
pipe rams, choke valves 1-14, manual
operated and super choke, choke and
kill and manual hcr's, 4" valve on kill line
#2 FOSV's 1-5" dart valve, upper and
lower IBOP, blind/shear rams. Perform
koomey drawdown ACC=2990 psi
Manifold = 1450 psi, ACC= 1825 after all
functions on bottles, 8 seconds for 200
psi, Build w/ 2 electric pumps, 54
seconds t/ build full system pressure/ 2
electric pumps and 2 air pumps. Closing
times Annular= 23 seconds, Upper pipe
rams = 18 seconds, Blind/shears=16
seconds, Lower pipe rams=16 seconds,
Choke hcr's=2 seconds, Kill hcr's=2
seconds. Test PVT gain/loss and flow
out alarms, Test LEL and H2S alarms
AOGCC rep Sean Sullivan waived
witness @ 0643 hrs 7-4-23
0.0 0.0
7/5/2023
12:00
7/5/2023
13:30
1.50 INTRM1, WHDBOP BOPE P Cont Test Bop's 4 unsuccessful test on
annular w/ 2 7/8" pipe, Pulled test joint
found test joint causing problems,
moved test joint by adding pup joint.
Tested good test.
0.0 0.0
7/5/2023
13:30
7/5/2023
14:30
1.00 INTRM1, WHDBOP WWWH P R/D Test plug, Run wear bushing as per
Vault Rep. ID=9" OD=13.375, Length
=14.75" L/D test joint and test
equipment
0.0 0.0
7/5/2023
14:30
7/5/2023
16:15
1.75 INTRM1, DRILLOUT CLEN P Clean and Clear rig floor, Ready all tools
and equipment to P/U production BHA
Via beaver slide. PJSM
0.0 0.0
7/5/2023
16:15
7/5/2023
18:30
2.25 INTRM1, DRILLOUT BHAH P M/U 8 3/8" production BHA to 163' MD
as per SLB DD and MWD, P/U 54k
S/O=54k
0.0 163.0
7/5/2023
18:30
7/5/2023
20:00
1.50 INTRM1, DRILLOUT TRIP P TIH f/ 163' to 2045' MD P/U=54k S/O
54k
163.0 2,045.0
7/5/2023
20:00
7/5/2023
20:45
0.75 INTRM1, DRILLOUT CIRC P Shallow test directional tools as per
SLB, W/ GPM=450 PSI=571, P/U=80
S/O=80
2,045.0 2,045.0
7/5/2023
20:45
7/5/2023
21:45
1.00 INTRM1, DRILLOUT FRZP P Perform O/A injection test w/ 9.4 ppg
mud weight, Pump 60 strokes @ .04
BPM to 374 psi Observed pressure
stabilize @ .04 bpm rate to 68 strokes
Total pumped, Shut down and monitored
pressure, pressure bled back to 278 psi
in 5 min. Bleed off to pits=.25 bbls
2,045.0 2,045.0
7/5/2023
21:45
7/5/2023
23:00
1.25 INTRM1, DRILLOUT DLOG P Perform downlink t sonic tools f/ free
ring cement logs w/ GPM=475, PSI=631
as per SLB. DD and MWD
2,045.0 2,045.0
7/5/2023
23:00
7/6/2023
00:00
1.00 INTRM1, DRILLOUT DLOG P RIH logging with directional tools f/
2045' to 2430' MD Free Ring Pipe,
GPM=900 PSI=598, P/U=90k S/O =90K
2,045.0 2,430.0
7/6/2023
00:00
7/6/2023
05:00
5.00 INTRM1, DRILLOUT DLOG P RIH logging with directional tools f/
2430' to 3748' MD Free Ring Pipe,
GPM=900 PSI=598, P/U=90k S/O =90K
2,430.0 3,748.0
Rig: DOYON 142
RIG RELEASE DATE 8/2/2023
Page 17/37
1C-157
Report Printed: 8/17/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
7/6/2023
05:00
7/6/2023
11:45
6.75 INTRM1, DRILLOUT DLOG P RIH on elevator w/ pipe from derrick,
logging with directional tools f/ 3748' to
10851' MD Free Ring Pipe, P/U=90k
S/O =90K
3,748.0 10,851.0
7/6/2023
11:45
7/6/2023
12:00
0.25 INTRM1, DRILLOUT DLOG P RIH w/ singles from pipe shed, Logging
@ 3600' FPH P/U=89k S/O=89K
10,851.0 11,019.0
7/6/2023
12:00
7/6/2023
15:30
3.50 INTRM1, DRILLOUT CIRC P Circulate and Condition mud @
GPM=300, PSI=584, F/O=18% SIMOP
slip and cutt drilling, 5 wraps 73' Verify
proper torque on dog nut, and deadman
Inspect brass, calibrate blocks
11,019.0 11,019.0
7/6/2023
15:30
7/6/2023
18:00
2.50 INTRM1, DRILLOUT PRTS P R/U T/ Test 9-5/8" Interm. casing,
Pressure up @ 5 SPM to 3500 psi and
hold for 30 minutes on chart 108 strokes
pumped, Bled back 10.8 bbls
11,019.0 11,019.0
7/6/2023
18:00
7/6/2023
18:30
0.50 INTRM1, DRILLOUT WASH P Wash down f/ 11019' to 11170' MD
GPM=450, PSI=1214, P/U=135k
S/O=95k, Tag plugs @ 11170' MD
11,019.0 11,170.0
7/6/2023
18:30
7/7/2023
00:00
5.50 INTRM1, DRILLOUT DRLG P Drill out shoe track F/ 11170' to 11174'
MD GPM=450, PSI=1256, RPM=40,
ROT=114k, TQ=9k, P/U=130k,
S/O=95K
11,170.0 11,174.0
7/7/2023
00:00
7/7/2023
05:15
5.25 INTRM1, DRILLOUT DRLG P Drill out shoe track F/ 11170' to 11174'
MD GPM=450, PSI=1256, RPM=40,
ROT=114k, TQ=9k, P/U=130k,
S/O=95K, @ 11174' top drive stalled
once thru float collar, Attempted to
release torque several times, P/U max
55k over pickup, 30k down, Obtain free
travel, Back ream 2 stands, pump 30
Lube sweep.
11,174.0 11,263.0
7/7/2023
05:15
7/7/2023
05:45
0.50 INTRM1, DRILLOUT DRLG P Drill 20' new formation f/ 11263' to
11283' MD WOB=5k, GPM=550,
PSi=1520, RPM=80, TQ=15k, F/O 19,
ECD=10.6, P/U=130, S/O=95k,
RT=117k, ADT=.3,
11,263.0 11,283.0
7/7/2023
05:45
7/7/2023
07:00
1.25 INTRM1, DRILLOUT CIRC P @ 11283' Rotate and Recip. while
circulate and condition mud for FIT/LOT
MUD weight in and out 9.3 ppg POOH
to 11256
11,283.0 11,256.0
7/7/2023
07:00
7/7/2023
08:30
1.50 INTRM1, DRILLOUT LOT P @ 11256' R/U perform LOT test, Pump
45 strokes @ 0.5 BPM to 1000 PSI,
achieve 14.1 PPG EMW 4.5 bbls bled
back to pits, R/D test equipment.
11,256.0 11,256.0
7/7/2023
08:30
7/7/2023
11:00
2.50 PROD1, DRILL CIRC P Rotate and Recip. f/ 11256' to 11210'
MD, While displacing well with 9.2 ppg
Flow pro from 9.3 ppg LSND, Pump 2x
Hi-Vis spacer sweeps with 9.2 Flow pro
@ 7-8 BPM ICP=828, F/O=12%, TQ=8,
P/U=116k, S/O=122K, FCP=924, Total
Strokes pumped 9261.
11,256.0 11,210.0
7/7/2023
11:00
7/7/2023
13:15
2.25 PROD1, DRILL CIRC P Rotate and Recip. T /11256' MD obtain
SPR's GPM=550, PSI=1680, RPM=80
TQ=8k, ECD= 10.2, P/U=148k,
S/O=99k, RT=118k, Note: change out
shaker screens to manage fluid loss
over shakers until fluid shears out
completely.
11,210.0 11,256.0
7/7/2023
13:15
7/7/2023
13:30
0.25 PROD1, DRILL WASH P Wash and Ream f/ 11256' to 11283' MD,
GPM=550, PSI=1680, RPM=80 TQ=8k,
ECD= 10.2, P/U=148k, S/O=99k,
RT=118k
11,256.0 11,283.0
Rig: DOYON 142
RIG RELEASE DATE 8/2/2023
Page 18/37
1C-157
Report Printed: 8/17/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
7/7/2023
13:30
7/7/2023
18:00
4.50 PROD1, DRILL DDRL P Drill 8 3/8” Production hole f/ 11283‘ MD
- t/ 11313‘ MD 3987‘ TVD, WOB= 10-
18k, GPM= 550, PSI on= 1800, PSI,
RPM= 80-100, TQ = 9-10k, Flow out=
20%, ECD= 10.92 PPG, P/U wt= 153k,
S/O wt= 101k, RT= 119k, ADT= 2.76,
Total bit hrs= 3.06, @11303' noted psi
incr., Hook load decrease, decide t/
ream stand into shoe w/
GPM=550/PSI=1709, Rt=108k w/
RPM=80, TQ=8k t/ Clear any excess
debris @11308' pump 28bbl hi-vis
sweep t/ clean any obstruction/excess
debris
11,283.0 11,313.0
7/7/2023
18:00
7/8/2023
00:00
6.00 PROD1, DRILL DDRL P Drill 8 3/8” Production hole f/ 11313‘ md
- t/ 11373‘ MD TVD=3990‘ , WOB= 9-
14k, GPM= 567, PSI= 1790, RPM= 120,
TQ=12-14k, Flow out= 20%, ECD=
11.07 PPG, P/U= 153k, S/O= 101k,
RT=119k, ADT= 5.43, Total bit hrs= 8.49
@11343' Pump 26bbl hi-vis sweet t/
clean hole
11,313.0 11,373.0
7/8/2023
00:00
7/8/2023
06:00
6.00 PROD1, DRILL DDRL P Drill 8 3/8” Production hole F/ 11373‘
MD - T/ 11677‘ MD TVD=4004‘ , WOB=
10k, GPM= 567, PSI= 1920, RPM= 120,
TQ=12k, Flow out= 20%, ECD= 11.24
PPG, P/U= 146k, S/O= 90k, RT=116k,
ADT= 4.89, Total bit hrs= 13.38
11,373.0 11,677.0
7/8/2023
06:00
7/8/2023
12:00
6.00 PROD1, DRILL DDRL P Drill 8 3/8” Production hole F/ 11677‘
MD - T/ 12126‘ MD TVD=3990‘ , WOB=
4k, GPM= 567, PSI= 1950, RPM= 120,
TQ=12-14k, Flow out= 20%, ECD=
11.36, PPG, P/U= 153k, S/O= 101k,
RT=119k, ADT= 4.69
11,677.0 12,126.0
7/8/2023
12:00
7/8/2023
18:00
6.00 PROD1, DRILL DDRL P Drill 8 3/8” Production hole F/ 12126‘
MD - T/ 12490‘ MD TVD=3990‘ , WOB=
1k, GPM= 567, PSI= 1938, RPM= 120,
TQ=12k, Flow out= 20%, ECD=11.4
PPG, P/U= 151k, S/O= 89k, RT=122k,
ADT= 4.68,
12,126.0 12,490.0
7/8/2023
18:00
7/9/2023
00:00
6.00 PROD1, DRILL DDRL P Drill 8 3/8” Production hole F/ 12490‘
MD - T/ 12724‘ MD TVD=3977‘ ,
WOB=4k, GPM= 567, PSI= 1935,
RPM= 120, TQ=12k, Flow out= 20%,
ECD= 11.28 PPG, P/U= 152k, S/O=88k,
RT=119k, ADT= 5.30, Total bit hrs=
28.05
12,490.0 12,724.0
7/9/2023
00:00
7/9/2023
06:00
6.00 PROD1, DRILL DDRL P Drill 8 3/8” Production hole F/ 12724‘
MD - T/ 13122‘ MD TVD=3978‘ ,
WOB=2k, GPM= 563, PSI= 1970,
RPM= 120, TQ=12k, Flow out= 20%,
ECD= 11.34 PPG, P/U= 151k, S/O=90k,
RT=120k, ADT= 2.75, Total bit hrs=
30.58
12,724.0 13,122.0
7/9/2023
06:00
7/9/2023
12:00
6.00 PROD1, DRILL DDRL P Drill 8 3/8” Production hole F/ 13122‘
MD - T/ 13571‘ MD TVD=3977‘ ,
WOB=3k, GPM= 563, PSI= 1989,
RPM= 120, TQ=12k, Flow out= 24%,
ECD= 11.35 PPG, P/U= 161k, S/O=85k,
RT=125k, ADT= 5.72, Total bit hrs=
37.52
13,122.0 13,571.0
Rig: DOYON 142
RIG RELEASE DATE 8/2/2023
Page 19/37
1C-157
Report Printed: 8/17/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
7/9/2023
12:00
7/9/2023
18:00
6.00 PROD1, DRILL DDRL P Drill 8 3/8” Production hole F/ 13571‘
MD - T/ 13987‘ MD TVD=3974‘ ,
WOB=5k, GPM= 563, PSI= 1970,
RPM= 120, TQ=13k, Flow out= 24%,
ECD= 11.40 PPG, P/U= 158k, S/O=82k,
RT=124k, ADT= 4.40, Total bit hrs=
46.87
13,571.0 13,987.0
7/9/2023
18:00
7/10/2023
00:00
6.00 PROD1, DRILL DDRL P Drill 8 3/8” Production hole F/ 13987‘
MD - T/ 14412‘ MD TVD=3965‘ ,
WOB=5k, GPM= 563, PSI= 2073,
RPM= 120, TQ=14k, Flow out= 24%,
ECD= 11.53 PPG, P/U= 160k, S/O=80k,
RT=120k, ADT= 4.94, Total bit hrs=
46.87
13,987.0 14,412.0
7/10/2023
00:00
7/10/2023
06:00
6.00 PROD1, DRILL DDRL P Drill 8 3/4" production hole section
geosteering with NOVOS while
maintaining AIS specs F/ 14412‘ MD - T/
14722‘ MD TVD=3957‘, WOB= 4k,
GPM= 563, PSI= 2066, RPM= 120, TQ=
14k, Flow out= 24%, ECD= 11.49 PPG,
P/U= 161k, S/O= 78k, RT= 120k, ADT=
4.46, Total bit hrs= 51.33.
14,412.0 14,722.0
7/10/2023
06:00
7/10/2023
12:00
6.00 PROD1, DRILL DDRL P Drill 8 3/4" production hole section
geosteering with NOVOS while
maintaining AIS specs F/ 14722‘ MD - T/
15178‘ MD TVD=3951', WOB= 3k,
GPM= 558, PSI= 2076, RPM= 120, TQ=
13k, Flow out= 24%, ECD= 11.44 PPG,
P/U= 162k, S/O= 80k, RT= 122k, ADT=
5.07 Total bit hrs= 56.40.
14,722.0 15,178.0
7/10/2023
12:00
7/10/2023
18:00
6.00 PROD1, DRILL DDRL P Drill 8 3/4" production hole section
geosteering with NOVOS while
maintaining AIS specs F/ 15178‘ MD - T/
15618‘ MD TVD=3955‘, WOB= 2k,
GPM= 558, PSI= 2121, RPM= 120, TQ=
13k, Flow out= 24%, ECD= 11.57 PPG,
P/U= 165k, S/O= 68k, RT= 120k, ADT=
4.30, Total bit hrs= 60.70.
15,178.0 15,618.0
7/10/2023
18:00
7/11/2023
00:00
6.00 PROD1, DRILL DDRL P Drill 8 3/4" production hole section
geosteering with NOVOS while
maintaining AIS specs F/ 15618‘ MD - T/
16136‘ MD TVD=3955‘, WOB= 3k,
GPM= 563, PSI= 2190, RPM= 120, TQ=
13k, Flow out= 24%, ECD= 11.64 PPG,
P/U= 169k, S/O= 67k, RT= 124k, ADT=
4.41, Total bit hrs= 65.11.
15,618.0 16,136.0
7/11/2023
00:00
7/11/2023
06:00
6.00 PROD1, DRILL DDRL P Drill 8Ǫ" production hole section
geosteering with NOVOS while
maintaining AIS specs F/ 16,136‘ MD -
T/ 16,637‘ MD TVD= 3,966‘ MD, WOB=
5k, GPM= 563, PSI= 2303, RPM= 120,
TQ= 15k, Flow out= 20%, MWT= 9.2,
ECD= 11.69 PPG, P/U= 180k, S/O= NA,
RT= 128k, ADT= 4.5, Total bit hrs=
69.61.
16,136.0 16,637.0
7/11/2023
06:00
7/11/2023
12:00
6.00 PROD1, DRILL DDRL P Drill 8Ǫ" production hole section
geosteering with NOVOS while
maintaining AIS specs F/ 16,637‘ MD -
T/ 17,123‘ MD TVD= 3,958‘ MD, WOB=
4k, GPM= 563, PSI= 2458, RPM= 120,
TQ= 15k, Flow out= 20%, MWT= 9.2,
ECD= 11.81 PPG, P/U= 184k, S/O=
82k, RT= 139k, ADT= 4.64, Total bit
hrs= 74.25.
16,637.0 17,123.0
Rig: DOYON 142
RIG RELEASE DATE 8/2/2023
Page 20/37
1C-157
Report Printed: 8/17/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
7/11/2023
12:00
7/11/2023
18:00
6.00 PROD1, DRILL DDRL P Drill 8Ǫ" production hole section
geosteering with NOVOS while
maintaining AIS specs F/ 17,123‘ MD -
T/ 17,478‘ MD TVD= 3,958‘ MD, WOB=
6k, GPM= 563, PSI= 2516, RPM= 120,
TQ= 16k, Flow out= 20%, MWT= 9.2,
ECD= 11.86 PPG, P/U= 192k, S/O= NA,
RT= 135k, ADT= 4.59, Total bit hrs=
78.84.
17,123.0 17,478.0
7/11/2023
18:00
7/12/2023
00:00
6.00 PROD1, DRILL DDRL P Drill 8Ǫ" production hole section
geosteering with NOVOS while
maintaining AIS specs F/ 17,478‘ MD -
T/ 17,614‘ MD TVD= 3,960‘ MD, WOB=
4k, GPM= 563, PSI= 2490, RPM= 120,
TQ= 16k, Flow out= 20%, MWT= 9.2,
ECD= 11.65 PPG, P/U= 207k, S/O= NA,
RT= 144k, ADT= 5.54, Total bit hrs=
84.38.
SIMOPS - Fluid pack the OA w/ 3.3 bbls
of 9.2 mud via #1 charge pump and
observe 48 psi.
17,478.0 17,614.0
7/12/2023
00:00
7/12/2023
06:00
6.00 PROD1, DRILL DDRL P Drill 8Ǫ" production hole section
geosteering with NOVOS while
maintaining AIS specs F/ 17,478‘ MD -
T/ 18,095‘ MD TVD= 3,976‘ MD, WOB=
3k, GPM= 563, PSI= 2602, RPM= 120,
TQ= 15k, Flow out= 18%, MWT= 9.2,
ECD= 11.93 PPG, P/U= 199k, S/O= NA,
RT= 144k, ADT= 4.13, Total bit hrs=
99.51.
17,614.0 18,095.0
7/12/2023
06:00
7/12/2023
12:00
6.00 PROD1, DRILL DDRL P Drill 8Ǫ" production hole section
geosteering with NOVOS while
maintaining AIS specs F/ 18,095‘ MD -
T/ 18,543‘ MD TVD= 3,978‘ MD, WOB=
6k, GPM= 563, PSI= 2706, RPM= 120,
TQ= 16k, Flow out= 18%, MWT= 9.2,
ECD= 12.06 PPG, P/U= 193k, S/O= NA,
RT= 144k, ADT= 4.65, Total bit hrs=
93.16.
18,095.0 18,543.0
7/12/2023
12:00
7/12/2023
18:00
6.00 PROD1, DRILL DDRL P Drill 8Ǫ" production hole section
geosteering with NOVOS while
maintaining AIS specs F/ 18,543‘ MD -
T/ 18,875‘ MD TVD= 3,975‘ MD, WOB=
2k, GPM= 563, PSI= 2687, RPM= 120,
TQ= 15k, Flow out= 17%, MWT= 9.2,
ECD= 11.85 PPG, P/U= 206k, S/O= NA,
RT= 143k, ADT= 4.84, Total bit hrs= 98.
Cross fault at 18,685' MD w/ 20' up
throw. Cross fault @ 18,825' MD w/ 20'
up throw and observe minimal losses.
18,543.0 18,875.0
7/12/2023
18:00
7/13/2023
00:00
6.00 PROD1, DRILL DDRL P Drill 8Ǫ" production hole section
geosteering with NOVOS while
maintaining AIS specs F/ 18,875‘ MD -
T/ 19,035‘ MD TVD= 3,967‘ MD, WOB=
6k, GPM= 563, PSI= 2745, RPM= 120,
TQ= 15k, Flow out= 17%, MWT= 9.2,
ECD= 11.95 PPG, P/U= 201k, S/O= NA,
RT= 143k, ADT= 5.13, Total bit hrs=
103.13.
18,875.0 19,035.0
Rig: DOYON 142
RIG RELEASE DATE 8/2/2023
Page 21/37
1C-157
Report Printed: 8/17/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
7/13/2023
00:00
7/13/2023
06:00
6.00 PROD1, DRILL DDRL P Drill 8Ǫ" production hole section
geosteering with NOVOS while
maintaining AIS specs F/ 19,035‘ MD -
T/ 19,390‘ MD TVD= 3,961‘ MD, WOB=
7k, GPM= 475, PSI= 2205, RPM= 120,
TQ= 16k, Flow out= 13%, MWT= 9.2,
ECD= 11.57 PPG, P/U= 199k, S/O= NA,
RT= 145k, ADT= 4.96, Total bit hrs=
108.09
Cross fault at 19,290' MD and observe
150 bph loss rate. Decrease rate to 475
and mix 35 bbl 40 ppb Safecarb LCM
pill.
19,035.0 19,390.0
7/13/2023
06:00
7/13/2023
12:00
6.00 PROD1, DRILL DDRL P Drill 8Ǫ" production hole section
geosteering with NOVOS while
maintaining AIS specs F/ 19,390‘ MD -
T/ 19,689‘ MD TVD= 3,955‘ MD, WOB=
7k, GPM= 525, PSI= 2825, RPM= 120,
TQ= 16k, Flow out= 13%, MWT= 9.2,
ECD= 11.90 PPG, P/U= 212k, S/O= NA,
RT= 151k, ADT= 4.09, Total bit hrs=
112.18
Continue to pump 35 bbl 40 ppb
Safecarb LCM pills (5ppb Safe Carb 40,
5 ppb Baracarb 1200, 20 ppb Safe Carb
500, 10 ppb Safe Carb 750) at each
connection. Observe loss rate of 50
bph.
19,390.0 19,689.0
7/13/2023
12:00
7/13/2023
18:00
6.00 PROD1, DRILL DDRL P Drill 8Ǫ" production hole section
geosteering with NOVOS while
maintaining AIS specs F/ 19,689‘ MD -
T/ 20,063‘ MD TVD= 3,955‘ MD, WOB=
7k, GPM= 500-563, PSI= 2422-2820,
RPM= 120, TQ= 16k, Flow out= 13%,
MWT= 9.2, ECD= 11.60 PPG, P/U=
212k, S/O= NA, RT= 151k, ADT= 4.43,
Total bit hrs= 116.61
Continue to pump 35 bbl 40 ppb
Safecarb LCM pills at each connection.
Observe loss rate of 50 bph.
19,689.0 20,063.0
7/13/2023
18:00
7/14/2023
00:00
6.00 PROD1, DRILL DDRL P Drill 8Ǫ" production hole section
geosteering with NOVOS while
maintaining AIS specs F/ 20,063 MD -
T/ 20,270‘ MD TVD= 3,938‘ MD, WOB=
2-10k, GPM= 500, PSI= 2545, RPM=
120, TQ= 16k, Flow out= 14%, MWT=
9.2, ECD= 11.62 PPG, P/U= 222k, S/O=
NA, RT= 157k, ADT= 5.23, Total bit hrs=
121.84
Continue to pump 35 bbl 40 ppb
Safecarb LCM pills (5ppb Safe Carb 40,
5ppb Baracarb 1200, 10 ppb Safe Carb
500, 15 ppb Safe Carb 750, 5ppb
BaraFlak) at each connection. Observe
loss rate of 50 bph. Total bbls loss to
formation last 24 hrs = 1,679.
20,063.0 20,270.0
Rig: DOYON 142
RIG RELEASE DATE 8/2/2023
Page 22/37
1C-157
Report Printed: 8/17/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
7/14/2023
00:00
7/14/2023
06:00
6.00 PROD1, DRILL DDRL P Drill 8Ǫ" production hole section
geosteering with NOVOS while
maintaining AIS specs F/ 20,270 MD -
T/ 20,521‘ MD TVD= 3,941‘ MD, WOB=
8k, GPM= 500, PSI= 2575, RPM= 120,
TQ= 16k, Flow out= 14%, MWT= 9.2,
ECD= 11.75 PPG, P/U= 224k, S/O= NA,
RT= 157k, ADT= 4.82, Total bit hrs=
126.66
Continue to pump 35 bbl 40 ppb
Safecarb LCM pills (5ppb Safe Carb 40,
5ppb Baracarb 1200, 10 ppb Safe Carb
500, 15 ppb Safe Carb 750, 5ppb
BaraFlak) at each connection. Observe
loss rate of 50 bph.
20,270.0 20,521.0
7/14/2023
06:00
7/14/2023
12:00
6.00 PROD1, DRILL DDRL P Drill 8Ǫ" production hole section
geosteering with NOVOS while
maintaining AIS specs F/ 20,521 MD -
T/ 20,875‘ MD TVD= 3,941‘ MD, WOB=
9k, GPM= 500, PSI= 2653, RPM= 120,
TQ= 16k, Flow out= 12%, MWT= 9.2,
ECD= 11.60 PPG, P/U= 222k, S/O= NA,
RT= 153k, ADT= 5.08, Total bit hrs=
131.74
Continue to pump 35 bbl 40 ppb
Safecarb LCM pills (5ppb Safe Carb 40,
5ppb Baracarb 1200, 10 ppb Safe Carb
500, 15 ppb Safe Carb 750, 5ppb
BaraFlak) at each connection. Observe
loss rate of 50 bph.
20,521.0 20,875.0
7/14/2023
12:00
7/14/2023
18:00
6.00 PROD1, DRILL DDRL P Drill 8Ǫ" production hole section
geosteering with NOVOS while
maintaining AIS specs F/ 20,875 MD -
T/ 21,280‘ MD TVD= 3,928‘ MD, WOB=
13k, GPM= 500, PSI= 2847, RPM= 120,
TQ= 16k, Flow out= 13%, MWT= 9.2,
ECD= 12.01 PPG, P/U= 249k, S/O= NA,
RT= 156k, ADT= 4.55, Total bit hrs=
136.29
Continue to pump 35 bbl 40 ppb
Safecarb LCM pills (5ppb Safe Carb 40,
5ppb Baracarb 1200, 10 ppb Safe Carb
500, 15 ppb Safe Carb 750, 5ppb
BaraFlak) at each connection. Observe
loss rate of 50 bph.
20,875.0 21,280.0
7/14/2023
18:00
7/14/2023
20:45
2.75 PROD1, DRILL DDRL P Drill 8Ǫ" production hole section
geosteering with NOVOS while
maintaining AIS specs F/ 21,280 MD -
T/ 21,467‘ MD TVD= 3,925‘ MD, WOB=
14k, GPM= 500, PSI= 2912, RPM= 120,
TQ= 15k, Flow out= 15%, MWT= 9.2,
ECD= 12.05 PPG, P/U= 230k, S/O= NA,
RT= 168k, ADT= 2.38, Total bit hrs=
138.67
Continue to pump 35 bbl 40 ppb
Safecarb LCM pills (5ppb Safe Carb 40,
5ppb Baracarb 1200, 10 ppb Safe Carb
500, 15 ppb Safe Carb 750, 5ppb
BaraFlak) at each connection. Observe
loss rate of 50 bph.
21,280.0 21,467.0
7/14/2023
20:45
7/14/2023
21:00
0.25 PROD1, TRIPCAS SRVY P Obtain final T&D, survey data. 21,467.0 21,467.0
Rig: DOYON 142
RIG RELEASE DATE 8/2/2023
Page 23/37
1C-157
Report Printed: 8/17/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
7/14/2023
21:00
7/14/2023
21:30
0.50 PROD1, TRIPCAS OWFF P OWFF. Rot string @ 5 rpm, 18k tq,
161K rot wt. Observe wellbore
breathing. Confirm with diminishing flow
out - Initial F/O - 10%, Final F/O - less
than 1%. 77 bbls total bled back. (No
observations of gas at surface on BU
after flow check).
21,467.0 21,467.0
7/14/2023
21:30
7/15/2023
00:00
2.50 PROD1, TRIPCAS BKRM P BROOH via NOVOS F/ 21,467' MD T/
21,373' MD. Circ BU per stand w/
GPM= 500, PSI= 2905, RPM= 120, TQ=
14k, Flow out= 11%, MWT= 9.2, ECD=
12.03 PPG, UP WT @ rate = 160K.
SIMOPS - set powerdrive into neutral.
Continue to pump 35 bbl 40 ppb
Safecarb LCM pills (5ppb Safe Carb 40,
5ppb Baracarb 1200, 10 ppb Safe Carb
500, 15 ppb Safe Carb 750, 5ppb
BaraFlak) at each connection. Observe
loss rate of 50 bph. Total bbls loss to
formation last 24 hrs = 1551
21,467.0 21,373.0
7/15/2023
00:00
7/15/2023
06:00
6.00 PROD1, TRIPCAS BKRM P BROOH via NOVOS F/ 21,373' MD T/
20,426' MD, GPM= 500, PSI= 2566,
RPM= 120, TQ= 13k, Flow out= 8%,
MWT= 9.2, ECD= 11.37 PPG, UP WT
@ rate = 151K.
Continue to pump 35 bbl 40 ppb
Safecarb LCM pills (5 ppb Safe Carb 40,
5 ppb Baracarb 1200, 10 ppb Safe Carb
500, 15 ppb Safe Carb 750, 5 ppb
BaraFlak) at every 3rd connection.
21,373.0 20,426.0
7/15/2023
06:00
7/15/2023
12:00
6.00 PROD1, TRIPCAS BKRM P BROOH via NOVOS F/ 20,426' MD T/
18,540' MD, GPM= 500, PSI= 2300,
RPM= 100, TQ= 11.5k, Flow out= 8%,
MWT= 9.2, ECD= 11.32 PPG, UP WT
@ rate = 138K.
Continue to pump 35 bbl 40 ppb
Safecarb LCM pills (5 ppb Safe Carb 40,
5 ppb Baracarb 1200, 10 ppb Safe Carb
500, 15 ppb Safe Carb 750, 5 ppb
BaraFlak) at every 3rd connection up to
above the loss zone of 19,290' MD.
Observe tight hole @ 18,530. Wash
and ream to clear obstruction.
20,426.0 18,540.0
7/15/2023
12:00
7/15/2023
18:00
6.00 PROD1, TRIPCAS BKRM P BROOH via NOVOS F/ 18,540' MD T/
16,710' MD, GPM= 500, PSI= 1960,
RPM= 120, TQ= 10k, Flow out= 8%,
MWT= 9.2, ECD= 11.20 PPG, UP WT
@ rate = 125K.
Continue to monitor fluids via AIS
testing.
18,540.0 16,710.0
7/15/2023
18:00
7/16/2023
00:00
6.00 PROD1, TRIPCAS BKRM P BROOH via NOVOS F/ 16,710' MD T/
14,213' MD, GPM= 500, PSI= 1668,
RPM= 110, TQ= 9k, Flow out= 15%,
MWT= 9.2, ECD= 10.84 PPG, UP WT
@ rate = 111K.
Continue to monitor fluids via AIS
testing.
Total bbls loss to formation last 24 hrs =
455
16,710.0 14,213.0
Rig: DOYON 142
RIG RELEASE DATE 8/2/2023
Page 24/37
1C-157
Report Printed: 8/17/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
7/16/2023
00:00
7/16/2023
10:00
10.00 PROD1, TRIPCAS BKRM P BROOH via NOVOS F/ 14,213' MD T/
11,210' MD, GPM= 500, PSI= 1400,
RPM= 110 - 80, TQ=8 k, Flow out=
16%, MWT= 9.2, ECD= 10.49 PPG, UP
WT @ rate = 110K.
Continue to monitor fluids via AIS
testing.
Observe tight hole @ 13,345', 13,307'
w/ 100 psi pressure spikes and tq
swings F/ 9k to 15k. Work through
spots 2X.
SIMOPS - clean tank farm tanks for SF
FloPro.
14,213.0 11,210.0
7/16/2023
10:00
7/16/2023
10:30
0.50 PROD1, TRIPCAS OWFF P OWFF. Observe slight flow due to
wellbore breathing.
11,210.0 11,210.0
7/16/2023
10:30
7/16/2023
11:15
0.75 PROD1, TRIPCAS OTHR P Drop 2.115 OD ball to open well
commander. Pump at 120 GPM, 275
PSI. Reduce rate to 80 GPM, 225 PSI.
Ball on seat at 990 stks. Pressure up to
850 PSI. Held for 30 sec. Stage up in
500 PSI increments. Observe tool shift
open at 1660 PSI. Confirm open w/ ICP
- 500 GPM w/ 1406 PSI, FCP - 500
GPM w/ 950 PSI.
11,210.0 11,210.0
7/16/2023
11:15
7/16/2023
13:15
2.00 PROD1, TRIPCAS CIRC P Rot and recip pipe T/ 11,210' MD T/
11,120' MD and circ csg clean staging
pumps up to GPM - 750, ICP - 1545,
FCP -1720 RPM - 125, 8K TQ. Total
Stks pumped - 19,849(2000 bbls)
11,210.0 11,210.0
7/16/2023
13:15
7/16/2023
14:00
0.75 PROD1, TRIPCAS OTHR P Drop 2.115 OD ball to close well
commander. Pump at 125 GPM, 250
PSI. Reduce rate to 80 GPM, 197 PSI.
Ball on seat at 970 stks. Pressure up to
680 PSI. Held for 30 sec. Stage up in
500 PSI increments. Observe tool shift
close at 2030 PSI.
11,210.0 11,210.0
7/16/2023
14:00
7/16/2023
20:15
6.25 PROD1, TRIPCAS TRIP P RIH w/ 5" DP from the derrick F/ 11,210'
MD T/ 15,258' MD. Fill pipe every 20
stds. Monitor disp via pit #1 and pill pit
#2. Inspecting and c/o defective super
sliders. Lose slackoff wt @ 14,558' MD.
Wash and ream in the hole F/ 14,558'
MD T/ 14,653 GPM - 150, PSI - 470,
RPM - 40, TQ - 12K, 110K S/O WT.
Cont to RIH on elevators T/ 15,258' MD.
SIMOPS - Continue to clean tank farm
tanks & rig pits for SF FloPro.
11,210.0 15,258.0
7/16/2023
20:15
7/16/2023
23:30
3.25 PROD1, TRIPCAS REAM P Wash and ream in the hole F/ 15,258'
MD T/ 16,684' MD W/ GPM - 150, PSI -
500, RPM - 40, TQ - 12K, 120K S/O WT.
Monitor disp via pit #1 and pill pit #2.
Inspecting and c/o defective super
sliders
SIMOPS - Continue clean rig pits for SF
FloPro.
15,258.0 16,684.0
Rig: DOYON 142
RIG RELEASE DATE 8/2/2023
Page 25/37
1C-157
Report Printed: 8/17/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
7/16/2023
23:30
7/17/2023
00:00
0.50 PROD1, TRIPCAS TRIP P RIH on elevators F/ 16,684' MD T/
16,964' MD w/ 5" HWDP. Monitor disp
via pit #1 and pill pit #2. S/O WT - 80K.
SIMOPS - Continue to clean rig pits for
SF FloPro.
Total fluid loss to formation last 24 hrs -
108 bbls.
16,684.0 16,964.0
7/17/2023
00:00
7/17/2023
02:30
2.50 PROD1, TRIPCAS TRIP P RIH on elevators F/ 16,964' MD T/
19,458' MD w/ 5" HWDP. Monitor disp
via pit #1 and pill pit #2. S/O WT - 80-
50K.
SIMOPS - Continue to clean rig pits for
SF FloPro.
16,964.0 19,485.0
7/17/2023
02:30
7/17/2023
08:45
6.25 PROD1, TRIPCAS REAM P Lost slackoff weight @ 19,485' MD.
Decision made to ream in the hole.
Wash/ream F/ 19,485' MD T/ 21,462'
MD w/ 150 GPM, ICP - 762, FCP - 820,
20 RPM, 16K Tq, 2% F/O. S/O ROT
WT - 176K.
19,485.0 21,462.0
7/17/2023
08:45
7/17/2023
14:30
5.75 PROD1, TRIPCAS CIRC P Rot & Recip pipe F/ 21,462' MD T/
21,371' MD alternating stop points w/
250 GPM, 1350 PSI, 11% F/O, 120
RPM, 16K TQ. UP WT @ rate - 184K,
S/O WT @ rate - 174K.
SIMOPS - PJSM on fluid displacement.
21,462.0 21,462.0
7/17/2023
14:30
7/17/2023
19:30
5.00 PROD1, TRIPCAS DISP P Displace wellbore to 9.2 ppg SF FloPro
while rot & recip pipe F/ 21,462' MD T/
21,371' MD alternating stop points w/
250 GPM, ICP - 1095, FCP - 896 11%
F/O, 50 RPM, 15K TQ. UP WT @ rate -
184K, S/O WT @ rate - 174K. Total stks
pumped - 16,000 (1,611 bbls).
21,462.0 21,462.0
7/17/2023
19:30
7/17/2023
20:00
0.50 PROD1, TRIPCAS CLEN P Clean under shakers. Obtain PST per
mud engineer. (failed)
21,462.0 21,462.0
7/17/2023
20:00
7/18/2023
00:00
4.00 PROD1, TRIPCAS CIRC P Continue to circ 9.2 ppg SF FloPro while
rot & recip pipe F/ 21,462' MD T/ 21,371'
MD alternating stop points w/ 250 GPM,
900 PSI, 12% F/O, 50 RPM, 15K TQ.
UP WT @ rate - 186K, S/O WT @ rate -
177K. Obtain PST per mud engineer.
Total stks pumped - 13,893 (1400 bbls)
Total bbls lost to formation last 24 hrs -
66 bbls
21,462.0 21,462.0
7/18/2023
00:00
7/18/2023
00:15
0.25 PROD1, TRIPCAS CIRC P Obtain initial parameters prior to Well
Commander ball. Obtain SPR's.
21,462.0 21,462.0
7/18/2023
00:15
7/18/2023
00:30
0.25 PROD1, TRIPCAS OWFF P OWFF - observe mild flow back due to
wellbore breathing.
21,462.0 21,462.0
7/18/2023
00:30
7/18/2023
02:15
1.75 PROD1, TRIPCAS OTHR P Drop 2.115 OD Well Commander
activation ball. Pump down @ 126
GPM, 495 PSI, while rot & recip pipe F/
21,462' MD T/ 21,371' MD alternating
stop points. Ball on seat @ 2594 stks.
Pressure up to 1500. Held for 5 min.
Bleed psi off. Wait for 10 min. Pressure
pack up gradually and observe ball
shear out at 1971 psi. Confirm tool did
not shift open by pumping @ 126 gpm
and observe 500 psi.
21,462.0 21,462.0
Rig: DOYON 142
RIG RELEASE DATE 8/2/2023
Page 26/37
1C-157
Report Printed: 8/17/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
7/18/2023
02:15
7/18/2023
14:30
12.25 PROD1, TRIPCAS TRIP P POOH on elevators F/ 21,462' MD T/
11,020' MD. UP WT - 277K. S/O WT -
NA. Monitor disp via TT. Insect hard
bands and SuperSliders. Observe 15k
overfull (UP WT - 142K) when 1st
stabilizer entered the shoe.
21,462.0 11,020.0
7/18/2023
14:30
7/18/2023
14:45
0.25 PROD1, TRIPCAS OWFF P OWFF - static 11,020.0 11,020.0
7/18/2023
14:45
7/18/2023
15:00
0.25 PROD1, TRIPCAS CIRC P Obtain baseline parameters prior to
dropping Well Commander ball. 80
GPM - 175 PSI, 120 GPM - 212 PSI,
500 GPM - 1050 PSI, 20 RPM 7K TQ,
ROT WT - 114K.
11,020.0 11,020.0
7/18/2023
15:00
7/18/2023
15:45
0.75 PROD1, TRIPCAS OTHR P Drop 2.115 OD Well Commander
activation ball. Pump down @ 120
GPM, 225 PSI, reduce rate to 80 GPM -
184 PSI, ball on seat @ 880 stks.
Pressure up to 1140. Held for 30 sec.
Increase pressure @ 500 psi increments
holding for 30 sec. Observe tool shift
open @ 2005 psi. Confirm tool shift
open by pumping @ 500 gpm and 670
psi.
11,020.0 11,020.0
7/18/2023
15:45
7/18/2023
17:15
1.50 PROD1, TRIPCAS CIRC P Circ through Well Commander w/ 600
GPM - 845 PSI, 28% F/O, 20 RPM 7K
TQ while rot and recip pipe F/ 11,020'
MD T/ 10,930' MD. ROT WT UP - 110K,
ROT WT DN - 114K. Total stks pumped
- 11,783 (1187 bbls)
11,020.0 11,020.0
7/18/2023
17:15
7/18/2023
18:15
1.00 PROD1, TRIPCAS CIRC P Decision made to pump citric pill. Circ
w/ 500 GPM - 654 PSI, 26% F/O, 15
RPM 7K TQ, while rot and recip pipe F/
11,020' MD T/ 10,930' MD. ROT WT UP
- 110K, ROT WT DN - 114K. Observe
losses over shakers. Shut down and
screen down to 170 mesh.
11,020.0 11,020.0
7/18/2023
18:15
7/18/2023
19:45
1.50 PROD1, TRIPCAS CIRC P Continue to circ w/ 600 GPM - 804 PSI,
28% F/O, 20 RPM 7K TQ while rot and
recip pipe F/ 11,020' MD T/ 10,930' MD.
Total stks pumped - 11,700 (1178 bbls).
ROT WT UP - 110K, ROT WT DN -
115K. Total stks pumped - 12,732 (1282
bbls) Obtain PST per mud engineer
(failed)
11,020.0 11,020.0
7/18/2023
19:45
7/18/2023
20:30
0.75 PROD1, TRIPCAS OTHR P Decision made to close Well
Commander. Drop 2.115 Well
Commander activation ball. Pump down
@ 127 GPM, 177 PSI, reduce rate to 85
GPM - 150 PSI, ball on seat @ 914
stks. Pressure up to 630. Held for 30
sec. Increase pressure @ 500 psi
increments holding for 30 sec up to
1000 psi and held for 2 min. Gradually
increase pressure and observe tool shift
closed @ 2368 psi. Confirm tool shift
closed by pumping @ 500 gpm and
1038 psi.
SIMOPS - Service TD.
11,020.0 11,020.0
Rig: DOYON 142
RIG RELEASE DATE 8/2/2023
Page 27/37
1C-157
Report Printed: 8/17/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
7/18/2023
20:30
7/19/2023
00:00
3.50 PROD1, TRIPCAS CIRC T Continue to circ w/ Well Commander
closed @ 600 GPM - 1331 PSI, 27%
F/O, 20 RPM 7K TQ while rot and recip
pipe F/ 11,020' MD T/ 10,930' MD. ROT
WT UP - 110K, ROT WT DN - 115K.
Obtain PST per mud engineer.
SIMOPS - pump citric pill(#2) and
achieve passing PST after pill returned
to surface. Screen back up to 270 mesh
@ 10,000 stks (1007 bbls). Total stks
pumped = 31,372(3159 bbls).
Total bbls pumped @ 600 gpm while at
the shoe = 5628 bbls (55,887 stks)
11,020.0 11,020.0
7/19/2023
00:00
7/19/2023
00:15
0.25 PROD1, TRIPCAS OWFF P OWFF - static. SIMOPS - PJSM on L/D
BHA.
163.0 163.0
7/19/2023
00:15
7/19/2023
03:30
3.25 PROD1, TRIPCAS CIRC T Continue to circ w/ Well Commander
closed @ 600 GPM - 1350 PSI, 28%
F/O, 20 RPM 7K TQ while rot and recip
pipe F/ 11,020' MD T/ 10,930' MD. ROT
WT UP - 110K, ROT WT DN - 114K.
Total stks pumped - 26,786 (2697 bbls)
SIMOPS - Pump 3rd citric pill and obtain
passing PST per mud engineer.
11,020.0 11,020.0
7/19/2023
03:30
7/19/2023
04:00
0.50 PROD1, TRIPCAS OWFF T OWFF - observe slight flow back due to
wellbore breathing.
SIMOPS - Transfer active system to pit
5 to treat for low PH levels w/ caustic.
11,020.0 11,020.0
7/19/2023
04:00
7/19/2023
10:15
6.25 PROD1, TRIPCAS CIRC T Continue to circ w/ Well Commander
closed treating active system w/ caustic
due to low PH w/ ICP @ 600 GPM =
1367 PSI, FCP @ 550 GPM = 1120 PSI,
24% F/O, 20 RPM 7K TQ while rot and
recip pipe F/ 11,020' MD T/ 10,930' MD.
ROT WT UP - 110K, ROT WT DN -
114K. Total stks pumped - 43,307
SIMOPS - Obtain 2ea passing PST
tests.
11,020.0 11,020.0
7/19/2023
10:15
7/19/2023
11:00
0.75 PROD1, TRIPCAS OWFF P OWFF - observe slight flow back.
Confirm wellbore breathing by
diminishing returns.
11,020.0 11,020.0
7/19/2023
11:00
7/19/2023
22:15
11.25 PROD1, TRIPCAS TRIP P POOH L/D 5" DP F/ 11,020' MD T/
2,581' MD. UP WT - 145K. Monitor
disp via TT.
11,020.0 2,581.0
7/19/2023
22:15
7/19/2023
22:45
0.50 PROD1, TRIPCAS SVRG P Change out dies in ST-100 2,581.0 2,581.0
7/19/2023
22:45
7/20/2023
00:00
1.25 PROD1, TRIPCAS TRIP P POOH L/D 5" DP F/ 2,581' MD T/ 163'
MD. UP WT - 145K. Monitor disp via
TT.
2,581.0 163.0
7/20/2023
00:00
7/20/2023
02:00
2.00 PROD1, TRIPCAS BHAH P L/D production BHA as per SLB DD F/
163' MD.
163.0 0.0
7/20/2023
02:00
7/20/2023
03:00
1.00 PROD1, TRIPCAS BHAH P Clear and clean rig floor of BHA
components.
0.0 0.0
7/20/2023
03:00
7/20/2023
03:45
0.75 COMPZN, WHDBOP WWWH P M/U stack jetting tool and wash BOPE
@ 400-800 gpm.
0.0 0.0
7/20/2023
03:45
7/20/2023
04:00
0.25 COMPZN, WHDBOP RURD P Pull wear bushing and set test plug as
per Vault rep.
0.0 0.0
7/20/2023
04:00
7/20/2023
07:00
3.00 COMPZN, WHDBOP RURD P R/U to test BOPE. Clear all air from
system and make up 2ea 5" FOSV and
1ea 5" dart.
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 8/2/2023
Page 28/37
1C-157
Report Printed: 8/17/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
7/20/2023
07:00
7/20/2023
13:00
6.00 COMPZN, WHDBOP BOPE P Test BOPE to 250 low, 3,500 high for
5/5 charted min. w/ the exception of the
manual operated & super choke tested
to 2,500 psi. Test annular with 5” and
2Ǭ” test jts. With the 4½" test jt test,
3½" x 6" upr, choke valves 1-14, manual
operated and super choke, choke & kill
manuals and HCR's, 4" kill line, 5"
FOSV (x2), 5" dart valve. With 5” test jt
test upr and 2Ǭ” x 5” lwr pipe rams.
With the 2Ǭ” test jt, test lpr. Perform
koomey drawdown - acc - 2950 psi,
manifold - 1500 psi, acc - 1800 after all
functions, 10 sec for 200 psi build w/ 2
elec pumps, 52 sec to build full system
psi w/ 2 elec pumps and 2 air pumps.
Closing times for annular - 16 sec, upr -
7 sec, blind / shears - 8 sec, upr - 7 sec,
choke HCR - 2 sec, kill HCR - 2 sec. 6
bottle nitrogen backup ave. - 1992 psi.
Test PVT gain/loss and flow out alarms.
Test LEL and H2S alarms. AOGCC rep
Brian Bixby waived witness to the test
@ 18:53 on 7/16/2023.
0.0 0.0
7/20/2023
13:00
7/20/2023
14:15
1.25 COMPZN, WHDBOP RURD P Pull test plug and install 9" ID wear
bushing as per Vault rep. R/D and B/D
testing equipment.
0.0 0.0
7/20/2023
14:15
7/20/2023
15:30
1.25 COMPZN, CASING RURD P R/U to run 4½ 12.6# L-80 Hyd563
OHSAS lower completion.
0.0 0.0
7/20/2023
15:30
7/20/2023
15:45
0.25 COMPZN, CASING SFTY P PJSM with Conoco rig supervisor, rig
crews, DDI TP, DDI csg, & Baker reps.
0.0 0.0
7/20/2023
15:45
7/21/2023
00:00
8.25 COMPZN, CASING PUTB P RIH w/ 4½" 12.6# L-80 Hyd563
Excluder Screens as per tally to 3,450'
MD. M/U TQ = 3,800 FT/LBS. S/O WT
- 84K. Monitor disp via TT.
0.0 3,250.0
7/21/2023
00:00
7/21/2023
10:00
10.00 COMPZN, CASING PUTB P RIH w/ 4½" 12.6# L-80 Hyd563
Excluder Screens as per tally to 10,264'
MD. M/U TQ = 3,800 FT/LBS. S/O WT
- 80K. Monitor disp via TT.
3,250.0 10,264.0
7/21/2023
10:00
7/21/2023
11:00
1.00 COMPZN, CASING RURD P R/D 4½" csg running equipment. Clean
and clean rig floor.
10,264.0 10,264.0
7/21/2023
11:00
7/21/2023
12:00
1.00 COMPZN, CASING RURD P R/U 2Ǭ" csg running equipment. 10,264.0 0.0
7/21/2023
12:00
7/22/2023
00:00
12.00 COMPZN, CASING PULD P RIH w/ 2Ǭ 6.5# L-80 HYD511 wash pipe
T/ 6,442' MD. Monitor disp via pit #1.
M/U TQ - 800 FT/LBS. S/O WT - 64K.
0.0 6,442.0
7/22/2023
00:00
7/22/2023
05:15
5.25 COMPZN, CASING PULD P RIH w/ 2Ǭ 6.5# L-80 HYD511 wash pipe
T/ 10,263' MD. Monitor disp via pit #1.
M/U TQ - 800 FT/LBS. S/O WT - 57K.
6,442.0 10,263.0
7/22/2023
05:15
7/22/2023
05:45
0.50 COMPZN, CASING PULD P Tag up on nogo @ 10,263' MD. Set dn
10K (3x). Lay dn jts 339 and 340.
10,263.0 10,263.0
7/22/2023
05:45
7/22/2023
09:30
3.75 COMPZN, CASING OTHR P M/U triple connect running tool to FLCV
in the pipe shed w/ jt 339. M/U FLCV to
inner string / screen assembly.
Remove & L/D handling sub. P/U SBE
and set in the mousehole. C/O handling
equipment to 2Ǭ. P/U & M/U jt 340 to
inner string wash pipe. C/O handling
equipment to 5". M/U 7" SLZXP to SBE.
Remove false bowl and M/U
SLXZP/SBE to inner string / screen
assembly. Batch up and fill tieback with
Xanplex and RIH T/ 10,355' MD.
10,263.0 10,355.0
7/22/2023
09:30
7/22/2023
11:00
1.50 COMPZN, CASING RURD P Clean and clear rig floor of 3ea DDI
power tongs, 2Ǭ", & 4½" handling
equipment.
10,355.0 10,355.0
Rig: DOYON 142
RIG RELEASE DATE 8/2/2023
Page 29/37
1C-157
Report Printed: 8/17/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
7/22/2023
11:00
7/22/2023
12:00
1.00 COMPZN, CASING RUNL P M/U XO's and Rubicon swivel. Verify
free travel to the right and locking to the
left. M/U Well Commander and RIH.
M/U to std #3, RIH and circ at 170 gpm,
500 psi, & obtain T&D w/ 20 and 30 rpm
- .6k tq, T/ 10,670' MD. ROT WT - 116K.
10,355.0 10,670.0
7/22/2023
12:00
7/22/2023
19:30
7.50 COMPZN, CASING RUNL P RIH w/ 4½" OHSAS lower completion on
5" DP F/ 10,670' MD T/ 18,690' MD. Fill
pipe and obtain T&D every 10 stds. P/U
WT - 175K, S/O WT - 100K. Monitor
disp via pit #1. Lost slackoff wt @
18,690' MD w/ 20K S/O WT.
10,670.0 18,690.0
7/22/2023
19:30
7/22/2023
20:00
0.50 COMPZN, CASING RUNL P P/U and initiate pump & rotation @ 2
BPM, 500 psi, 20 RPM, 6-8K and
successfully regain slackoff working
down to 18,757' MD.
18,690.0 18,757.0
7/22/2023
20:00
7/22/2023
22:00
2.00 COMPZN, CASING RUNL P RIH w/ 4½" OHSAS lower completion on
5" HWDP F/ 18,757' MD T/ 20,436' MD.
Fill pipe and obtain T&D every 10 stds.
P/U WT - 245K, S/O WT - 100K.
Monitor disp via pit #1. Lost slackoff wt
@ 20,436' MD
18,757.0 20,436.0
7/22/2023
22:00
7/22/2023
22:30
0.50 COMPZN, CASING RUNL P P/U and initiate pump & rotation @ 2
BPM, 550 PSI, 20 RPM, 9-11K TQ, and
successfully successfully regain
slackoff down to 20,529' MD.
20,436.0 20,529.0
7/22/2023
22:30
7/23/2023
00:00
1.50 COMPZN, CASING RUNL P RIH w/ 4½" OHSAS lower completion on
5" HWDP F/ 20,529' MD T/ 21,431' MD.
Fill pipe and obtain T&D every 10 stds.
P/U WT - 283K, S/O WT - 83K. Monitor
disp via pit #1.
20,529.0 21,431.0
7/23/2023
00:00
7/23/2023
00:30
0.50 COMPZN, CASING RUNL P P/U and position SLZXP liner hanger on
depth @ shoe depth of 21,427' MD.
TOL-11,071' MD. Final S/O WT - 84K,
UP WT - 283k
21,431.0 21,427.0
7/23/2023
00:30
7/23/2023
01:15
0.75 COMPZN, CASING CIRC P Circ string volume @ 169 GPM, 1,142
PSI, 12% F/O, total stks pumped - 2234
(225 bbls).
21,427.0 21,427.0
7/23/2023
01:15
7/23/2023
02:30
1.25 COMPZN, CASING PACK P Drop 1.125 OD ball liner setting ball.
Pump down at 169 GPM, 1,130 PSI,
11% F/O, @ 1,600 stks slow pumps to
85 GPM, 575 PSI, 10% F/O, observe
ball on seat @ 1,983 stks. Slowly
pressure up to 2,700 PSI to set liner
hanger. Slack off to block wt to ensure
set (good). Pressure up to 3,570 PSI to
release running tool from liner. Pick up
to verify and observe 160K UP WT
confirming release. Pressure up to
4,450 psi and hold for blowing out the
ball seat. Observe ball seat blow out at
4,425 PSI.
21,427.0 21,427.0
7/23/2023
02:30
7/23/2023
03:00
0.50 COMPZN, WELLPR SFTY P PJSM with CPAI rig supervisor, DDI TP,
DDI rig crews, M-I mud engineer on fluid
displacment.
SIMOPS - circulate @ 169 GPM, 1,053
PSI, 11% F/O.
21,427.0 21,427.0
7/23/2023
03:00
7/23/2023
08:15
5.25 COMPZN, WELLPR DISP P Displace wellbore to 9.2 filtered brine.
Pump 70 bbls hi-vis spacer @ 4 BPM,
840 PSI, 11% F/O. Chase w/ 9.2 filtered
brine @ 253 GPM, ICP - 2,335, FCP -
2743 @ 230 GPM, 16% F/O. Total stks
pumped - 16,310 (1,642 bbls).
21,427.0 21,427.0
Rig: DOYON 142
RIG RELEASE DATE 8/2/2023
Page 30/37
1C-157
Report Printed: 8/17/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
7/23/2023
08:15
7/23/2023
09:30
1.25 COMPZN, WELLPR CLEN P Shut down pumps. Clean under
shakers and trough. Screen up shaker
screens to 325 mesh. Continue to
offload FloPro SF & clean pits. MT
rockwasher. Prep for wellbore clean up.
21,427.0 21,427.0
7/23/2023
09:30
7/23/2023
13:45
4.25 COMPZN, WELLPR CIRC P Complete 1st circ w/ clean 9.2 filtered
brine. Pump @ 230 GPM, 2800 PSI,
18% F/O. Taking returns out to tank
farm and M-I filtration team filter returns.
Total stks pumped - 13,758 (1385 bbls)
21,427.0 21,427.0
7/23/2023
13:45
7/23/2023
21:00
7.25 COMPZN, WELLPR CLEN T M-I filtration unit packed off after ~400
bbls of processing. Shut down and
clean filters at the press.
SIMOPS - MT tanks of fluid returns and
fill with clean 9.2 ppg filtered brine.
21,427.0 21,427.0
7/23/2023
21:00
7/23/2023
21:30
0.50 COMPZN, WELLPR CIRC P PJSM w/ CPAI rig supervisor, DDI TP,
DDI rig crew, M-I mud engineer on 2nd
circ w/ clean 9.2 filtered brine.
21,427.0 21,427.0
7/23/2023
21:30
7/24/2023
00:00
2.50 COMPZN, WELLPR CIRC P Conduct 2nd circ w/ clean 9.2 filtered
brine. Pump @ 230 GPM, ICP - 2800
PSI, 18% F/O. FCP - 1960 PSI @ 212
GPM. Reduce rate due to shaker
overloading. Taking returns out to tank
farm for M-I filtration team to filter. Total
stks pumped - 6870
M-I filtration unit processed ~400 bbls
successfully.
21,427.0 21,427.0
7/24/2023
00:00
7/24/2023
02:00
2.00 COMPZN, WELLPR CIRC P Continue with 2nd circ w/ clean 9.2
filtered brine. Pump @ 230 GPM, ICP -
2,586 PSI, 16% F/O. FCP - 2,732.
Taking returns out to tank farm for M-I
filtration team to filter. Total stks
pumped - 6635 (668 bbls) M-I filtration
unit processed ~250 bbls successfully.
21,427.0 21,427.0
7/24/2023
02:00
7/24/2023
10:15
8.25 COMPZN, WELLPR CLEN T After full s/s circ, shut down. Clean
packed off filtering unit. Transfer mud
from pits to upright tanks. SIMOPS - rig
crews work on rig PM's, paint projects,
and general housekeeping throughout
the rig.
21,427.0 21,427.0
7/24/2023
10:15
7/24/2023
14:00
3.75 COMPZN, WELLPR CIRC P Conduct 3rd circ w/ clean 9.2 filtered
brine. Pump @ 230 GPM, 2,766 PSI,
16% F/O. Taking returns out to tank
farm for M-I filtration team to filter. Total
stks pumped - 11,619 (1170 bbls)
21,427.0 21,427.0
7/24/2023
14:00
7/24/2023
18:00
4.00 COMPZN, WELLPR RURD P L/D top single in string, R/U bail
extensions, TIW, head pin, & cement
line for upcoming acid job. Continue to
work rig PM's, paint projects, steam
projects, c/o air actuator valves on
shakers.
21,427.0 21,427.0
7/24/2023
18:00
7/25/2023
00:00
6.00 COMPZN, WELLPR COND P Prep tank farm for upcoming acid job.
Process fluid returns. Fill MT tanks with
clean 9.2 filtered brine, clean filter press.
Rig crew continue with rig PM's, misc
paint projects, clean derrick wind walls,
inventory CPAI xo subs on location.
Monitor wellbore via hole fill.
21,427.0 21,427.0
Rig: DOYON 142
RIG RELEASE DATE 8/2/2023
Page 31/37
1C-157
Report Printed: 8/17/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
7/25/2023
00:00
7/25/2023
00:45
0.75 COMPZN, WELLPR COND P Prep tank farm for upcoming acid job.
Process fluid returns. Fill MT tanks with
clean 9.2 filtered brine, clean filter press.
Rig crew continue with rig PM's, misc
paint projects, clean derrick wind walls,
inventory CPAI xo subs on location.
Monitor wellbore via hole fill.
21,427.0 21,427.0
7/25/2023
00:45
7/25/2023
01:15
0.50 COMPZN, WELLPR SFTY P PJSM with CPAI rig supervisor, DDI TP,
DDI rig crew, mud engineer, & SLB acid
team on spotting 9% formic acid.
21,427.0 21,427.0
7/25/2023
01:15
7/25/2023
04:45
3.50 COMPZN, WELLPR DISP P SLB prime and test lines to 500 psi low,
3900 psi high (good). Pump 580 bbls of
9.3 ppg 9% formic acid. Pump @ 233
GPM, ICP - 2,350, FCP - 2,307, 15%
F/O. Followed by 10 bbls of fresh water.
Swap to rig pumps and chase w/ 9.2
ppg filtered brine @ 233 GPM, ICP -
2,564, FCP - 2,365, 15% F/O. Total stks
pumped - 1,994 (200 bbls).
21,427.0 21,427.0
7/25/2023
04:45
7/25/2023
12:15
7.50 COMPZN, WELLPR OWFF P Monitor loss rate via pits 5-7, with
constant hole fill, recording volumes
every 15 min. Observe initial loss rate
of 16 BPH and final loss rate of 4 BPH.
Total bbls loss during observation - 100
bbls
21,427.0 21,427.0
7/25/2023
12:15
7/25/2023
12:45
0.50 COMPZN, WELLPR SFTY P PJSM with CPAI rig supervisor, DDI TP,
DDI rig crew, mud engineer, & SLB acid
team on displacing 9% formic acid.
21,427.0 21,427.0
7/25/2023
12:45
7/25/2023
16:00
3.25 COMPZN, WELLPR DISP P Displace 9% formic acid. Pump @ 233
GPM, 2,371 PSI, 15% F/O. Shut down
@ 5,964 stks (600 bbls) and divert to
open top tanks. Total bbls lost during
circ - 180 bbls
21,427.0 21,427.0
7/25/2023
16:00
7/25/2023
20:30
4.50 COMPZN, WELLPR DISP P Continue to displace acid @ 233 GPM,
2647 PSI. Observe increased losses
and decrease rate to 169 GPM, 1400
PSI. Total stks pumped diverting out to
open top tanks - 15,417 (15,525 bbls).
Total lost wile diverting out to open top
tanks - 480 bbls.
21,427.0 21,427.0
7/25/2023
20:30
7/26/2023
00:00
3.50 COMPZN, WELLPR DISP P Shut down. Open annular. Close IA.
Resume pumping @ 169 GPM, 1267
PSI, 12% F/O, monitoring PH levels.
Observe 6.7 PH after 8335 stks (840
bbls). SIMOPS - PJSM with CPAI rig
supervisor, DDI TP, DDI rig crew, mud
engineer, & SLB acid team on spotting
9% formic acid.
BBLS lost to formation last 24 hrs - 884
21,427.0 21,427.0
7/26/2023
00:00
7/26/2023
04:00
4.00 COMPZN, WELLPR DISP P SLB prime and test lines to 1000 psi
low, 3600 psi high (good). Pump 581
bbls of 9.3 ppg 9% formic acid. Pump
@ 169 GPM, ICP - 1,305, FCP - 1,220,
12% F/O. Followed by 10 bbls of fresh
water. Swap to rig pumps and chase w/
9.2 ppg filtered brine @ 169 GPM, ICP -
1,384, FCP - 1,283, 15% F/O. Total stks
pumped - 1,976 (199 bbls). Acid in
place @ 0400 hrs.
Total bbls loss during spotting pill - 152
bbls
21,427.0 21,427.0
Rig: DOYON 142
RIG RELEASE DATE 8/2/2023
Page 32/37
1C-157
Report Printed: 8/17/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
7/26/2023
04:00
7/26/2023
11:00
7.00 COMPZN, WELLPR OWFF P Allow acid to soak and monitor loss rate
via pits 5-7, with constant hole fill,
recording volumes every 15 min.
Observe ave loss rate of 16 BPH.
SIMOPS - Fluid management @ tank
farm and open top tanks, mitigating low
PH readings. Clean out packed off
filtration unit.
21,427.0 21,427.0
7/26/2023
11:00
7/26/2023
20:00
9.00 COMPZN, WELLPR OWFF T Continue to monitor hole losses allowing
acid to soak. Trucks were unable to
offload at 1B due to low PH levels.
Found issues relating to caustic and the
formic acid. Built soda ash pills in the
pits to offload to vac trucks to raise PH
levels, so trucks can offload at 1B.
Total bbls loss during observation - 256
bbls
21,427.0 21,427.0
7/26/2023
20:00
7/26/2023
22:30
2.50 COMPZN, WELLPR DISP P Displace 9% formic acid. Pump @ 163
GPM, 1,237 PSI, 11% F/O. Shut down
@ 6082 stks (612 bbls) and divert to
open top tanks observing 5.0 PH levels.
Total bbls lost during circ - 27 bbls
21,427.0 21,427.0
7/26/2023
22:30
7/27/2023
00:00
1.50 COMPZN, WELLPR DISP P Open up to open top tanks and close
annular. Continue to displace acid @
169 GPM, 1,341 PSI. Total stks
pumped diverting out to open top tanks -
9,066 (913 bbls).
BBLS lost to formation last 24 hrs - 518
21,427.0 21,427.0
7/27/2023
00:00
7/27/2023
03:00
3.00 COMPZN, WELLPR DISP P Open up to open top tanks and close
annular. Continue to displace acid @
169 GPM, 1,341 PSI. Total stks
pumped diverting out to open top tanks -
16,163 (1627 bbls).
Bbls lost while circ to open top tank - 36.
21,427.0 21,427.0
7/27/2023
03:00
7/27/2023
04:15
1.25 COMPZN, WELLPR DISP P Observe 6.7 PH. Open annular and
take returns back to the pits. Continue
to circ @ 169 GPM, 1286 PSI, 12% F/O.
Total stk back to the pits - 2658 (268
bbls). Total circulation for displacing
acid - 18,821 (1895 bbls).
Bbls lost whilc circ to pits - 78.
21,427.0 21,427.0
7/27/2023
04:15
7/27/2023
05:00
0.75 COMPZN, WELLPR CLEN P Prep mud pits for CI brine displacement.
Monitor wellbore losses via TT.
21,427.0 21,427.0
7/27/2023
05:00
7/27/2023
09:30
4.50 COMPZN, WELLPR DISP P Displace open hole to 9.2 ppg CI brine.
Stage pumps up to 169 GPM, 1,298
PSI, 12% F/O. Total stks pumped -
10,052 (1012 bbls).
Bbls lost while displacing - 189.
21,427.0 21,427.0
7/27/2023
09:30
7/27/2023
10:00
0.50 COMPZN, WELLPR RURD P R/D cement line. P/U DP single,
Acquire P/U WT - 250K, S/O WT - 129K
21,427.0 21,427.0
7/27/2023
10:00
7/27/2023
10:15
0.25 COMPZN, WELLPR PACK P Set SLZXP as per Baker reps. 21,427.0 21,427.0
7/27/2023
10:15
7/27/2023
10:30
0.25 COMPZN, WELLPR PRTS P Test SLZXP packer to 2000 PSI (Failed) 21,427.0 21,427.0
Rig: DOYON 142
RIG RELEASE DATE 8/2/2023
Page 33/37
1C-157
Report Printed: 8/17/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
7/27/2023
10:30
7/27/2023
13:15
2.75 COMPZN, WELLPR PACK T Attempt to release f/ liner using
emergency release procedure. Apply
left hand turns in neutral weight and
attempt to release (failed). Apply left
hand turns and work string up and down
transferring the tq to the tool and have
positive indication of release f/ liner.
Attempt to set pkr and re-test as per
Baker rep (failed). Decision made to
POOH.
21,427.0 21,427.0
7/27/2023
13:15
7/27/2023
21:15
8.00 COMPZN, WELLPR TRIP P POOH on elevators racking back 5"
HWDP/DP F/ 21,417' MD T/ 10,554'
MD. Monitor disp via pit #5. UP WT -
248K.
21,417.0 10,554.0
7/27/2023
21:15
7/27/2023
23:15
2.00 COMPZN, WELLPR PULD P L/D well commander and swivel T/
10,424' MD. UP WT - 72K. Monitor
disp via pit #5.
Bbls lost while POOH - 36
10,554.0 10,424.0
7/27/2023
23:15
7/28/2023
00:00
0.75 COMPZN, WELLPR PULD P L/D SLZXP running tool as per Baker
reps T/ 10,364' MD. UP WT - 70K.
Monitor disp via pit #5
Total bbls lost to formation last 24 hrs -
339.
10,424.0 10,364.0
7/28/2023
00:00
7/28/2023
12:30
12.50 COMPZN, WELLPR PULD P POOH L/D 2Ǭ" inner string F/ 10,364'
MD. UP WT - 60K. Monitor disp via TT.
10,364.0 0.0
7/28/2023
12:30
7/28/2023
13:45
1.25 COMPZN, WELLPR RURD P R/D Doyon Csg handling equipment. 0.0 0.0
7/28/2023
13:45
7/28/2023
14:00
0.25 COMPZN, WELLPR PRTS P PT wellbore to 1000 psi (good). Pump
2.5 bbls. Bled back 2.5 bbls.
0.0 0.0
7/28/2023
14:00
7/28/2023
20:15
6.25 COMPZN, WELLPR TRIP P M/U Baker dog sub - pack off assembly
to std of DP. RIH w/ 5" DP/HWDP T/
11,002' MD
0.0 11,002.0
7/28/2023
20:15
7/28/2023
20:45
0.50 COMPZN, WELLPR PACK P Kelly up, obtain P/U WT - 236K, S/O WT
- 142K. ROT WT - 192 @ 20 RPM, 15K
TQ. Execute Baker packer setting
procedure as per Baker rep. RIH to top
of pkr @ 11,078' MD (dog sub depth)
and set 60K (120K Hookload) down wt
and rot for 5 min @ 20 RPM - 22K TQ.
P/U to neutral wt @ 200K.
11,002.0 11,078.0
7/28/2023
20:45
7/28/2023
22:45
2.00 COMPZN, WELLPR PRTS P R/U and test packer to 2,000 PSI for 30
charted min (good). 4.2 bbls to
pressure up. 4.2 bbls bled back to TT.
11,078.0 11,078.0
7/28/2023
22:45
7/29/2023
00:00
1.25 COMPZN, WELLPR DISP P P/U 10' to expose packoff. Displace
well to 9.2 ppg CI brine. Stage pumps
up to GPM - 296, ICP - 410, FCP - 795,
20% F/O. Total stks pumped - 2317
(233 bbls).
11,078.0 11,062.0
7/29/2023
00:00
7/29/2023
01:30
1.50 COMPZN, WELLPR DISP P Displace well to 9.2 ppg CI brine @
GPM - 296, PSI - 795, 20% F/O. Total
stks pumped - 5746 - Total displacement
bbls pumped - 812.
11,062.0 11,062.0
7/29/2023
01:30
7/29/2023
02:00
0.50 COMPZN, WELLPR OWFF P OWFF - static 11,602.0 11,602.0
7/29/2023
02:00
7/29/2023
11:30
9.50 COMPZN, WELLPR PULD P POOH L/D 5" HWDP T/ 5874' MD (54
stds). Monitor disp via TT. PU WT -
206K, S/O WT - 149K.
11,602.0 5,874.0
7/29/2023
11:30
7/29/2023
18:00
6.50 COMPZN, WELLPR PULD P POOH L/D 5" DP (62 stds). Monitor
disp via TT. PU WT - 112K, S/O WT -
102K.
5,874.0 0.0
7/29/2023
18:00
7/29/2023
18:30
0.50 COMPZN, WELLPR RURD P Pull wear bushing per Vault rep. 0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 8/2/2023
Page 34/37
1C-157
Report Printed: 8/17/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
7/29/2023
18:30
7/29/2023
20:00
1.50 COMPZN, WELLPR RURD P Clear and clean rig floor. Prep rig floor
to stage upper completion equipment.
Stage cannon clamps and tubing hanger
on the rig floor.
0.0 0.0
7/29/2023
20:00
7/29/2023
21:45
1.75 COMPZN, WELLPR SLPC P Cut and slip 73' 1Ǫ" drill line. 0.0 0.0
7/29/2023
21:45
7/29/2023
22:15
0.50 COMPZN, WELLPR SVRG P Service TD. 0.0 0.0
7/29/2023
22:15
7/30/2023
00:00
1.75 COMPZN, RPCOMP RURD P R/U to run 4½" HYD 563 L-80 upper
completion.
0.0 0.0
7/30/2023
00:00
7/30/2023
08:00
8.00 COMPZN, RPCOMP RURD P R/U to run 4½" HYD 563 L-80 upper
completion.
0.0 0.0
7/30/2023
08:00
7/30/2023
10:00
2.00 COMPZN, RPCOMP PUTB P Run 4½" HYD 563 L-80 upper
completion T/ 802' MD. S/O WT - 51K.
Monitor disp via TT.
0.0 802.0
7/30/2023
10:00
7/30/2023
16:30
6.50 COMPZN, RPCOMP PUTB T While M/U ESP assembly #1, power
tongs came into contact with collar.
Decision made to change it out.
SIMOPS - General housekeeping
around the rig. Re-position slick line
unit. Rig PM's. Prep pad for upcoming
rig move.
802.0 802.0
7/30/2023
16:30
7/30/2023
19:30
3.00 COMPZN, RPCOMP PUTB P M/U ESP assembly per Summit and
Access reps T/ 918' MD
802.0 918.0
7/30/2023
19:30
7/30/2023
22:30
3.00 COMPZN, RPCOMP PUTB P Splice ESP motor assembly cable to
ESP spool cable as per Summit reps.
918.0 918.0
7/30/2023
22:30
7/30/2023
23:00
0.50 COMPZN, RPCOMP PUTB P Run 4½" HYD 563 L-80 upper
completion T/ 1,025' MD. S/O WT -
52K. Monitor disp via TT. Tq
connections to 3,800 ft/lbs. Install
cannon clamps every connection.
918.0 1,025.0
7/30/2023
23:00
7/31/2023
00:00
1.00 COMPZN, RPCOMP PUTB P M/U HES OPSIS gauge mandrel w/
DHG. Install TEC wire and test
continuity and pressure test to 10,000
PSI (good).
1,025.0 1,025.0
7/31/2023
00:00
7/31/2023
15:00
15.00 COMPZN, RPCOMP PUTB P Run 4½" HYD 563 L-80 upper
completion F/ 1,025' MD T/ 8,380' MD.
S/O WT - 73K. Monitor disp via TT. Tq
connections to 3,800 ft/lbs. Install
cannon clamps every connection. Test
electrical continuity every 1000' MD and
drift via HES slick line every 2000' MD
w/ 3.830 drift.
1,025.0 8,380.0
7/31/2023
15:00
7/31/2023
18:00
3.00 COMPZN, RPCOMP OTHR P Change out spools and splice ESP
cable as per Summit reps. Test
connection (good).
SIMOPS - R/D tank farm and pump
house. Prep pad for rig move.
Complete rig PM's and general
housekeeping.
8,380.0 8,380.0
7/31/2023
18:00
7/31/2023
19:00
1.00 COMPZN, RPCOMP PUTB P Run 4½" HYD 563 L-80 upper
completion F/ 8,380' MD T/ 9,000' MD.
S/O WT - 73K. Monitor disp via TT. Tq
connections to 3,800 ft/lbs. Install
cannon clamps every connection. Test
electrical continuity every 1000' MD and
drift via HES slick line every 2000' MD
w/ 3.830 drift.
8,380.0 9,000.0
Rig: DOYON 142
RIG RELEASE DATE 8/2/2023
Page 35/37
1C-157
Report Printed: 8/17/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
7/31/2023
19:00
7/31/2023
20:00
1.00 COMPZN, RPCOMP OTHR P Change out spools and splice chemical
injection line as per Summit reps. Test
connection (good).
SIMOPS - Drift string via HES slick line
w/ 3.830 drift.
9,000.0 9,000.0
7/31/2023
20:00
7/31/2023
23:15
3.25 COMPZN, RPCOMP PUTB P Run 4½" HYD 563 L-80 upper
completion F/ 9,000' MD T/ 11,000' MD.
S/O WT - 73K. Monitor disp via TT. Tq
connections to 3,800 ft/lbs. Install
cannon clamps every connection. Test
electrical continuity every 1000' MD and
drift via HES slick line every 2000' MD
w/ 3.830 drift.
9,000.0 11,000.0
7/31/2023
23:15
8/1/2023
00:00
0.75 COMPZN, RPCOMP PUTB P P/U jts. 262, 263, & 264. Tag no-go @
11,120.42 mule shoe depth. Confirm
with 10k down wt. Initiate pump and
pressure up to 300 psi to confirm seals
are located in SBE.
11,000.0 11,120.0
8/1/2023
00:00
8/1/2023
02:45
2.75 COMPZN, RPCOMP PUTB P Cont. t/ space out- L/D jts 264-261, P/U
space out pups a- 38.52, b- 38.61, c-
40.00, m/u t/ hanger assy., ready t/
terminate tec-wire and ESP wire thru
hanger assy., U/D WT.= 114/70k, test
tec-wire/ESP wire as per Summit and
Access ESP, @11075' drift t/ 3.813" via
HES slickline t/ 3765',
11,000.0 11,120.0
8/1/2023
02:45
8/1/2023
06:00
3.25 COMPZN, RPCOMP THGR P M/U hanger assy. t/ landing jt. and
terminate tec-wire/ESP cable thru
hanger as per HES/summit and access
ESP reps, drift hanger assy. t/ 3.813" via
HES slickline thru pup jt., SIMOPS- R/D
HES slickline drift assy., wireline
sheaves, tec-lines sheaves, Ect f/
Derrick, L/D beaverslide, clean and
clear rig floor excess tools/equip.
11,000.0 11,120.0
8/1/2023
06:00
8/1/2023
11:30
5.50 COMPZN, RPCOMP THGR P Summit Reps cont. splice ESP cable for
hanger penetration, connect chemical
injection line to hanger, Halliburton reps
connect tec line to hanger / SIMOPS
ready rig for rig move, rig up on OA for
injecting, prep for testing tubing and IA.
line up on OA. for injection rates, pump
at 1/2 bpm, observe formation
breakdown at 353 psi (12.9 EMW), then
cont. to pressure up and break down
again at 533 (14.7 EMW) psi, inject 3
bbls at 1/2 bpm w/ 445-475 psi, 9.5 bbls
pumped total, shut in OA. and monitor
psi
11,120.0 11,120.0
8/1/2023
11:30
8/1/2023
12:00
0.50 COMPZN, RPCOMP THGR P Upon landing tubing, the hanger hung
up in a ram cavity in the bops. While
picking the string back up the ESP cable
was pinched. Pulled hanger to rig floor
for evaluation. Decision made to re-
splice ESP cable into hanger.
11,120.0 11,120.0
Rig: DOYON 142
RIG RELEASE DATE 8/2/2023
Page 36/37
1C-157
Report Printed: 8/17/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/1/2023
12:00
8/1/2023
18:45
6.75 COMPZN, RPCOMP THGR T Summit Reps prep and re-splice ESP
cable / SIMOPS Vault Rep change out
O-ring on hanger, clear rig floor of
casing and tec line tools and equipment
as per Halliburton and DDI casing reps,
remove unused summit tools and
equipment from floor, clean surface
equipment and run deep clean through
all pumps and lines in mud pits, rig
down steam line interconnects between
modules, cont. prepping pad for rig
move, bring 7 5/8" solid rams to bop
deck, prep pipe shed for rig move,
disconnect rig from high line and put on
cat power
11,120.0 11,120.0
8/1/2023
18:45
8/1/2023
20:15
1.50 COMPZN, RPCOMP THGR P RIH w/ hanger assy. t/ seat@34.44
upper lock downs, run in lock downs
and test hanger seals thru test port t/
5000psi f/ 10min as per vault rep(good)
11,120.0 11,120.0
8/1/2023
20:15
8/1/2023
20:45
0.50 COMPZN, RPCOMP RURD P R/U t/ landing jt. w/ head pin t/ CMT line,
R/U t/ IA w/ Inj. lines f/ completion
testing,
11,120.0 11,120.0
8/1/2023
20:45
8/1/2023
22:45
2.00 COMPZN, RPCOMP PRTS P End well completion testing- line up and
pressure test through IA via Inj. line t/
1000psi t/ confirm seals in SBE(good)
line up and pressure test tubing t/
1500psi f/ 30min. charted(good), hold
1500psi and line up t/ IA, line up and
pressure test IA t/ 2000psi f/ 30min.
charted(good), bleed psi t/ 0(no shear),
pressure up IA and shear SOV @
(2250psi)
11,120.0 11,120.0
8/1/2023
22:45
8/1/2023
23:15
0.50 COMPZN, RPCOMP OWFF P OWFF(Static) 11,120.0 11,120.0
8/1/2023
23:15
8/2/2023
00:00
0.75 COMPZN, WHDBOP PRTS P L/D landing jt. and install HP-BPV in
tubing hanger as per Vault Rep,
pressure test thru IA/ 1500 psi f/ 10min.
charted(good), bleed off pressure, R/D
completion testing tools and equip.,
11,120.0 11,120.0
8/2/2023
00:00
8/2/2023
04:00
4.00 COMPZN, WHDBOP NUND P Nipple down BOPE, L/D mousehole,
R/D riser assy., Install boot protector on
riser, R/D Dutch riser adapter, r/d choke
and kill lines, R/D BOPE f/ Dsa/spacer
spool assy., Rack back BOPE t/
pedestal and secure, R/D Dsa/spacer
spool, ready wellhead assy. f/ nipple up
0.0 0.0
8/2/2023
04:00
8/2/2023
10:00
6.00 COMPZN, WHDBOP THGR P Prep wellhead t/ install tubing head
adapter, terminate tec-wire and ESP
thru tubing head adapter and set onto
wellhead, Tq t/ spec as per Vault,
Summit, Access Reps, Install tree test
dart into hp-bpv per Vault Rep, N/U and
orient 4 1/16" 5k tree as per CPF-1 Ops
Rep, ready t/ R/U LRS f/ tree test and
freeze protect.
0.0 0.0
8/2/2023
10:00
8/2/2023
11:00
1.00 COMPZN, WHDBOP PRTS P Rig up little red services, test tree 250
psi low, 5,000 psi high charted, pull BPV
as per vault rep
0.0 0.0
8/2/2023
11:00
8/2/2023
12:00
1.00 COMPZN, WHDBOP FRZP P Rig up on OA with LRS and freeze
protect with 70 bbls diesel at 2 bpm,
ICP= 565 psi
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 8/2/2023
Page 37/37
1C-157
Report Printed: 8/17/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/2/2023
12:00
8/2/2023
12:30
0.50 COMPZN, WHDBOP FRZP P LRS Cont. freeze protect OA with 128
total bbls diesel at 2 bpm, ICP= 565 psi,
FCP= 747 psi.
Not able to capture shut-in pressures.
Pump additional 4 bbls to re-establish
injection: circ pressure = 710 psi. Shut
down and monitor pressures: ISIP =
668 psi & FCP = 578 psi (~12.4 ppg
EMW at surf shoe w/ 6.7 ppg diesel).
SIMOPS: remove skate rail, disconnect
interconnects
0.0 0.0
8/2/2023
12:30
8/2/2023
15:00
2.50 COMPZN, WHDBOP FRZP P Rig up LRS on IA and freeze protect IA
taking returns up the tubing to open top
tank, 1.25 Bpm, ICP= 500 psi, FCP=
700 psi, total 154 bbls pumped, install
BPV and companion flanges on IA and
OA as per Vault Reps / SIMOPS:
disconnect rig power cables, stage rig
mats
0.0 0.0
8/2/2023
15:00
8/2/2023
16:00
1.00 DEMOB, MOVE CLEN P Clean and clear cellar of all tools and
equipment, clean out cellar box remove
all fluid from pits
0.0 0.0
8/2/2023
16:00
8/2/2023
17:30
1.50 DEMOB, MOVE DMOB P Prepare to Jack up motors and pump
module, put on suspension, and stage
on other side of pad
0.0 0.0
8/2/2023
17:30
8/2/2023
18:00
0.50 DEMOB, MOVE RURD P Pull cuttings box, hook up to rock
washer and prep to tail roll. Release Rig
at 18:00 hrs
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 8/2/2023
!"
" #
"$"%&
Digitally signed by Vincent Osara
DN: C=US, OU=Schlumberger, O=Schlumberger,
CN=Vincent Osara, E=vosara@slb.com
Reason: I am the author of this document
Location: your signing location here
Date: 2023.07.22 22:30:06-08'00'
Foxit PhantomPDF Version: 10.1.4
Vincent
Osara
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Page 1/1
1C-157
Report Printed: 8/17/2023
Cement
Cement Details
Description
Surface String Cement
Cementing Start Date
6/19/2023 00:30
Cementing End Date
6/19/2023 04:15
Wellbore Name
1C-157
Comment
Cement Stages
Stage # 1
Description
Surface String Cement
Objective
cement surface csg
Top Depth (ftKB)
39.6
Bottom Depth (ftKB)
2,062.0
Full Return?
Yes
Vol Cement …
107.0
Top Plug?
Yes
Btm Plug?
Yes
Q Pump Init (bbl/m…
5
Q Pump Final (bbl/…
3
Q Pump Avg (bbl/…
4
P Pump Final (psi)
390.0
P Plug Bump (psi)
390.0
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 Fluids & Additives
Fluid
Fluid Type
Lead Cement
Fluid Description Estimated Top (ftKB)
39.6
Est Btm (ftKB)
1,562.0
Amount (sacks)
717
Class
G
Volume Pumped (bbl)
364.0
Yield (ft³/sack)
2.86
Mix H20 Ratio (gal/sack)
14.61
Free Water (%) Density (lb/gal)
10.70
Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Fluid
Fluid Type
Tail Cement
Fluid Description Estimated Top (ftKB)
1,562.0
Est Btm (ftKB)
2,062.0
Amount (sacks)
338
Class
G
Volume Pumped (bbl)
69.0
Yield (ft³/sack)
1.16
Mix H20 Ratio (gal/sack)
5.03
Free Water (%) Density (lb/gal)
15.80
Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Surface String Cement
Page 1/1
1C-157
Report Printed: 8/17/2023
Cement
Cement Details
Description
Intermediate String 1 Cement
Cementing Start Date
7/4/2023 08:00
Cementing End Date
7/4/2023 13:40
Wellbore Name
1C-157
Comment
Perform cement job f/ 9 5/8" int. csg as per Halliburton program, Flood lines w/ 5 bpm H2O 278 psi, PressureTest lines t/ 4000psi, pump 77 bbls tuned 10.5 ppg
spacer @ 3.75 bpm/ 370 psi 12% f/o, Drop #2 bottom plug, pump 370 bbls 14 ppg Lead cmt @ 6 bpm 140psi 14% f/o, pump 138 bbls 15.3 ppg Tail cmt @ 4 bpm
135 psi 10% f/o, Drop top plug, pump 20 bbls fresh H2O, line up t/ rig pumps t/ displace. w/ 827 bbls @ 6 bpm 207 psi 14% f/o f/ 2620 stks. Cont. displacement
@ 6 bpm 770 psi F/O 13% f/ 3200 strokes, Slow rate t/5 bpm 855 psi f/700 strokes, Slow rate t/4 bpm 887 psi f/240 strokes, Slow rate t/3 bpm @ 847 psi, Bump
plug @ 7010 strokes pressure up to 1380 psi hold f/ 5 min. Bleed off/ check floats good. Cement in place at 1340 hrs
Cement Stages
Stage # 1
Description
Intermediate String 1
Cement
Objective Top Depth (ftKB)
3,422.0
Bottom Depth (ftKB)
11,256.2
Full Return?
Yes
Vol Cement …
0.0
Top Plug?
Yes
Btm Plug?
Yes
Q Pump Init (bbl/m…
3
Q Pump Final (bbl/…
3
Q Pump Avg (bbl/…
5
P Pump Final (psi)
847.0
P Plug Bump (psi)
1,380.0
Recip?
No
Stroke (ft) Rotated?
No
Pipe RPM (rpm)
Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in)
Comment
Perform cement job f/ 9 5/8" int. csg as per Halliburton program, Flood lines w/ 5 bpm H2O 278 psi, PressureTest lines t/ 4000psi, pump 77 bbls tuned 10.5 ppg
spacer @ 3.75 bpm/ 370 psi 12% f/o, Drop #2 bottom plug, pump 370 bbls 14 ppg Lead cmt @ 6 bpm 140psi 14% f/o, pump 138 bbls 15.3 ppg Tail cmt @ 4 bpm
135 psi 10% f/o, Drop top plug, pump 20 bbls fresh H2O, line up t/ rig pumps t/ displace. w/ 827 bbls @ 6 bpm 207 psi 14% f/o f/ 2620 stks. Cont. displacement
@ 6 bpm 770 psi F/O 13% f/ 3200 strokes, Slow rate t/5 bpm 855 psi f/700 strokes, Slow rate t/4 bpm 887 psi f/240 strokes, Slow rate t/3 bpm @ 847 psi, Bump
plug @ 7010 strokes pressure up to 1380 psi hold f/ 5 min. Bleed off/ check floats good. Cement in place at 1340 hrs
Cement Fluids & Additives
Fluid
Fluid Type
Lead Cement
Fluid Description Estimated Top (ftKB)
3,023.0
Est Btm (ftKB)
9,033.0
Amount (sacks)
1,362
Class
G
Volume Pumped (bbl)
370.0
Yield (ft³/sack)
1.55
Mix H20 Ratio (gal/sack)
7.82
Free Water (%) Density (lb/gal)
14.00
Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Fluid
Fluid Type
Tail Cement
Fluid Description Estimated Top (ftKB)
9,033.0
Est Btm (ftKB)
11,256.2
Amount (sacks)
648
Class
G
Volume Pumped (bbl)
140.0
Yield (ft³/sack)
1.24
Mix H20 Ratio (gal/sack)
5.57
Free Water (%) Density (lb/gal)
15.30
Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Intermediate String 1 Cement
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
BOPE Test Report for:
Reviewed By:
P.I. Suprv
Comm ________KUPARUK RIV U WSAK 1C-157
JBR 07/27/2023
MISC. INSPECTIONS:
FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK:
ACCUMULATOR SYSTEM:MUD SYSTEM:
P/F P/F
P/FP/FP/F
Visual Alarm
QuantityQuantity
Time/Pressure
SizeQuantity
Number of Failures:0
5Kpsi test. No failures.
Test Results
TEST DATA
Rig Rep:Matt Sam/Kelly HaugOperator:ConocoPhillips Alaska, Inc.Operator Rep:Adam Dorr/Byron Marmon
Rig Owner/Rig No.:Doyon 142 PTD#:2230380 DATE:6/20/2023
Type Operation:DRILL Annular:
250/3500Type Test:INIT
Valves:
250/5000
Rams:
250/5000
Test Pressures:Inspection No:bopAGE230620140213
Inspector Adam Earl
Inspector
Insp Source
Related Insp No:
INSIDE REEL VALVES:
Quantity P/F
(Valid for Coil Rigs Only)
Remarks:
Test Time 6
MASP:
1378
Sundry No:
Control System Response Time (sec)
Time P/F
Housekeeping:P
PTD On Location P
Standing Order Posted P
Well Sign P
Hazard Sec.P
Test Fluid W
Misc NA
Upper Kelly 1 P
Lower Kelly 1 P
Ball Type 2 P
Inside BOP 1 P
FSV Misc 0 NA
14 PNo. Valves
1 PManual Chokes
1 PHydraulic Chokes
0 NACH Misc
Stripper 0 NA
Annular Preventer 1 13 5/8"P
#1 Rams 1 9 5/8"P
#2 Rams 1 Blind/shear P
#3 Rams 1 3 1/2 X 6"P
#4 Rams 0 NA
#5 Rams 0 NA
#6 Rams 0 NA
Choke Ln. Valves 1 3 1/8"P
HCR Valves 1 3 1/8"P
Kill Line Valves 1 3 1/8"P
Check Valve 0 NA
BOP Misc 0 NA
System Pressure P2950
Pressure After Closure P1850
200 PSI Attained P8
Full Pressure Attained P47
Blind Switch Covers:PAll Stations
Bottle precharge P
Nitgn Btls# &psi (avg)P6@ 2000
ACC Misc NA0
P PTrip Tank
P PPit Level Indicators
P PFlow Indicator
P PMeth Gas Detector
P PH2S Gas Detector
0 NAMS Misc
Inside Reel Valves 0 NA
Annular Preventer P6
#1 Rams P7
#2 Rams P7
#3 Rams P7
#4 Rams NA0
#5 Rams NA0
#6 Rams NA0
HCR Choke P2
HCR Kill P2
Alaska Oil and Gas
Conservation Commission
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
Chris Brillon
Wells Engineering Manager
Conoco Phillips Alaska, Inc.
700 G Street
Anchorage, AK, 99501
Re: Kuparuk River Field, West Sak Oil, 1C-157
Conoco Phillips Alaska, Inc.
Permit to Drill Number: 223-038
Surface Location: 1467' FNL, 993' FWL, SWNW S12 T11N R10E
Bottomhole Location: 1650' FSL, 1263' FEL, NESE 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 June, 2023. 6
Brett W. Huber,
Sr.
Digitally signed by Brett W.
Huber, Sr.
Date: 2023.06.06 07:10:57
-08'00'
1a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for:
Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates
Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas
2. Operator Name: 5. Bond: Blanket Single Well 11. Well Name and Number:
Bond No.
3. Address: 6.Proposed Depth: 12. Field/Pool(s):
MD: 21214 TVD:3937
4a. Location of Well (Governmental Section): 7. Property Designation:
Surface:
Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date:
6/3/2023
Total Depth: 9. Acres in Property: 14. Distance to Nearest Property:
1260' to ADL047449
4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 97.3 15. Distance to Nearest Well Open
Surface: x-561999 y- 5968770 Zone- 4 58.3 to Same Pool: 2020' to 1C-155
16. Deviated wells: Kickoff depth: 300 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035)
Maximum Hole Angle: 89.4 degrees Downhole: Surface:
Hole Casing Weight Grade Coupling Length MD TVD MD TVD
42" 16" 94 H-40 Welded 81 39 39 120 120
16" 13.375" 68 L-80 Hyd563 1988 39 39 2027 1907
12.25" 9.625" 40 L80 Hyd563 10935 39 39 10974 3987
8.375" 4.5" 12.6 L-80 Hyd563 10390 10824 4107 21214 3937
19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations)
Junk (measured):
TVD
Hydraulic Fracture planned? Yes No
20. Attachments: Property Plat BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis
Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements
Contact Name: Matt Smith
Chris Brillon Contact Email:matt.smith2@cop.com
Wells Engineering Manager Contact Phone:907-263-4324
Date:
Permit to Drill API Number: Permit Approval
Number:Date:
Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales:
No Mud log req'd: Yes No
No Directional svy req'd: Yes No
No Inclination-only svy req'd: Yes No
Post initial injection MIT req'd: Yes No
APPROVED BY
Approved by: COMMISSIONER THE COMMISSION Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
10 yds
P.O. Box 100360 Anchorage, Alaska, 99510-0360 Kuparuk River Field
West Sak
1467' FNL, 993' FWL, SWNW S12 T11N R10E ADL025649 / ADL028242 / ADL025638
(including stage data)
2359' FSL,1497' FWL,NESW S7 T11N R11E LONS 01-013
1650' FSL, 1263' FEL, NESE S36 T12N R10E 2560 / 2469 / 2560
GL / BF Elevation above MSL (ft):
1772 1378
18. Casing Program:
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
20 AAC 25.005
ConocoPhillips 59-52-180 1C-157
850sks 10.7ppg, 330sks 15.8ppg
2160sks 15.3ppg
Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks
OHSAS
Casing Length Size Cement Volume MD
Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft):
Surface
Conductor/Structural
Liner
Production
Intermediate
Perforation Depth MD (ft): Perforation Depth TVD (ft):
21. I hereby certify that the foregoing is true and the procedure approved herein will not be
deviated from without prior written approval.
Authorized Name:
Authorized Title:
Authorized Signature:
Commission Use Only
See cover letter for other
requirements.
Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g)
By Kayla Junke at 4:10 pm, Apr 18, 2023
DSR-4/18/23
Initial BOP test to 5000 psig
Annular test to 2500 psig
Subsequent BOP test to 3500 psig
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
VTL 06/05/2023 SFD 6/2/2023
223-038 API: 50-029-23754-00-00
GCW 06/05/2023
JLC 6/5/2023
Diverter requirement variance denied
06/06/23
06/06/23
Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr.
Date: 2023.06.06 07:11:33 -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'
<ZhϭͲϭϱϳ
Conditions of Approval:
Approval is granted to run the LWD-Sonic on upcoming well with the following provisions:
1. CPAI will provide a written log evaluation/interpretation to the AOGCC along with the log as
soon as they become available. The evaluation is to include/highlight the intervals of competent
cement that CPAI is using to meet the objective requirements for annular isolation, reservoir
isolation, or confining zone isolation etc. Providing the log without an evaluation/interpretation
is not acceptable.
2. LWD sonic logs must show free pipe and Top of Cement, just as the e-line log does. CPAI must
start the log at a depth to ensure the free pipe above the TOC is captured as well as the TOC.
Starting the log below the actual TOC based on calculations predicting a different TOC will not
be acceptable.
3. CPAI will provide a cement job summary report and evaluation along with the cement log and
evaluation to the AOGCC when they become available
4. CPAI will provide the results of the FIT when available.
5. Depending on the cement job results indicated by the cement job report, the logs and the FIT,
remedial measures or additional logging may be required.
ConocoPhillips Alaska, Inc.
Post Office Box 100360
Anchorage, Alaska 99510-0360
Telephone 907-276-1215
April 10, 2023
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
Re: Application for Permit to Drill 1C-157
Dear Sir or Madam:
ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore West Sak D Producer well from the 1C drilling
pad. The intended spud date for this well is 6/3/2023. It is intended that Doyon 142 be used to drill the well.
1C-157 will utilize a 16” surface hole drilled to TD and 13.375” casing will be set and cemented to surface. As noted in
section 4 of the attached proposed drilling program, the low maximum anticipated surface pressure of the well allows use of a
three preventer BOPE per 20 AAC 25.035 (e) (1) (A) (i-iii). The fourth preventer will contain solid body pipe rams that will
be sized for the intermediate casing string. The 12.25” intermediate hole will be drilled and landed in the West Sak D reservoir.
A 9.625” casing string will be set and cemented from TD to secure the shoe and cover 500’MD or 250’TVD above any
hydrocarbon-bearing zones (Ugnu C).
The production interval will be comprised of a 8.375” horizontal hole that will be geo-steered in the West Sak D formation.
The well will be completed as a Producer with 4.5” liner with OHSAS and swell packers as necessary. The upper completion
will include an ESP, dowhole gauge and GLM’s and tied back to surface.
This upper completion mirrors the 3S/Nuna completions design which was approved with the below conditions on
July 30, 2019. It is asked that these stipulations apply to 1C-157 also.
1) The completion proposed is acceptable providing the well is not in a location where a SSSV is required
2) A no flow test is not required
3) COP to provide the control process flow or P&ID for the SVS system. Specifically for the closing of the
actuated valve on the IA prior to the recombination of the gas with produced fluids.
It is requested that a variance of the diverter requirement under 20AAC 25.035(h)(2) is granted for well 1C-157. There are 9
wells within 500’ of the planend 1C-157 surface shoe location (1C-01, 28, 21, 26, 20, 02, 133, 24, 03). One well, 1C-20,
observed hydrates at 1200’, with max 410 units at 2,032’ TVD and 9.4ppg
Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information
attached to this application includes the following:
1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a)
2. A proposed drilling program
3. A proposed completion diagram
4. A drilling fluids program summary
5. Pressure information as required by 20 ACC 25.035 (d)(2)
6. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b)
Information pertinent to the application that is presently on file at the AOGCC:
1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC
25.035 (a) and (b).
2. A description of the drilling fluids handling system.
3. Diagram of riser set up.
If you have any questions or require further information, please contact Matt Smith at 263-4324
(matt.smith2@conocophillips.com) or Chris Brillon at 265-6120.
Sincerely, cc:
1C-157 Well File / Jenna Taylor ATO 1560
David Lee ATO 1552
Matt Smith Chris Brillon ATO 1548
Drilling Engineer John Bertalott ATO 0642
Sincerely,,,,,,,,,,
MSih
Due to gas hydrates in 1C-20, 28, 150, 151 and shallow gas observed in
1C-28, I cannot support this requested variance. SFD 6/2/2023
requested that a variance of the diverter requirement u
Application for Permit to Drill, 1C-157
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1C-157 PTD
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1C-157
Application for Permit to Drill Document
Table of Contents
1. Well Name (Requirements of 20 AAC 25.005 (f)) ............................................................ 2
2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) ............................................ 2
3. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) .......................... 3
4. Blowout Prevention Equipment (Requirements of 20 AAC 25.005(c)(3)) ............... 4
5. Diverter System (Requirements of 20 AAC 25.005(c)(7)) ......................................... 4
6. MASP Calculations (Requirements of 20 AAC 25.005(c)(4)) ................................... 4
7. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC
25.005(c)(5)) .............................................................................................................. 6
8. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) ............. 6
9. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) .................................... 6
10. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9))
................................................................................................................................... 7
11. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) .......................................... 7
12. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) ......................... 7
13. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) ................................... 7
14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 8
(Requirements of 20 AAC 25.005 (c)(14)) ............................................................................. 8
15. Drilling Hazards Summary ....................................................................................... 8
16. Proposed Completion Schematic ......................................................................... 10
Application for Permit to Drill, 1C-157
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1C-157 PTD
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1. Well Name (Requirements of 20 AAC 25.005 (f))
The well for which this application is submitted will be designated as 1C-157
2. Location Summary (Requirements of 20 AAC 25.005(c)(2))
Location at Surface 1467' FNL, 993' FWL, SWNW S12 T11N R10E, UM
NAD 1927
Northings: 561999
Eastings: 5968770
RKB Elevation 97.3’ AMSL
Pad Elevation 58.3’ AMSL
Top of Productive Horizon
(Heel) 2359' FSL, 1497' FWL , NESW S7 T11N R11E, UM
NAD 1927
Northings: 567796
Eastings: 5967365
Measured Depth, RKB:10974’
Total Vertical Depth, RKB:3987’
Total Vertical Depth, SS:3890’
Total Depth (Toe) 1650' FSL, 1263' FEL,NESE S36 T12N R10E, UM
NAD 1927
Northings: 564949
Eastings: 5977191
Measured Depth, RKB:21214’
Total Vertical Depth, RKB:3937’
Total Vertical Depth, SS:3840’
Pad Layout
Application for Permit to Drill, 1C-157
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3. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13))
The proposed drilling program is listed below. Please refer to Attachment 3: Completion Schematic.
1. MIRU Doyon 142 onto 1C-157
2. Rig up and test riser, dewater cellar as needed.
3. Drill 16” hole to the surface casing point as per the directional plan (LWD Program: GR/Res/GWD).
4. Run and cement 13.375” surface casing to surface.
5. Install BOPE.
6. Test BOPE to 250 psi low / 3,500 psi high (24-48 hr regulatory notice).
7. Pick up and run in hole with 12.25” drilling BHA to drill the intermediate hole section.
8. Chart casing pressure test to 3000 psi for 30 minutes.
9. Drill out 20’ of new hole and perform LOT. Maximum LOT to 18 ppg. Minimum LOT required to drill ahead is
10 ppg EMW.
10. Drill 12.25” hole to section TD, within the West Sak D Reservoir. (LWD Program: GR/RES/PWD).
11. Run 9.625” casing and cement to a minimum of 500’ MD or 250’ TVD above any hydrocarbon bearing zones
(cementing schematic attached).
12. Test BOPE to 250 psi low / 3,500 psi high (24-48 Regulatory notice).
13. Pick up and run in hole with 8.375” drilling BHA. Log top of cement with sonic tool in recorded mode.
14. Chart casing pressure test to 3,500 psi for 30 minutes.
15. Drill out shoe track and 20 feet of new formation. Perform LOT to a maximum of 14.5 ppg. Minimum required
leak-off value is 10.0 ppg EMW.
16. Drill 8.375” hole to section TD (LWD Program: GR/RES/PWD).
17. Pull out of hole with drilling BHA. Review cement job details and sonic log TOC.
18. Run 4.5” liner with OHSAS and liner hanger to TD, utilizing 2-7/8” inner string
19. Set liner hanger. Pump (and spot) wellbore cleanup treatments (9% formic acid). Let treatments soak and
monitor wellbore. Circulate out.
20. Set liner top packer. OWFF. TOOH and LD running tools.
21. Run 4.5” upper completion with seal assembly, chemical injection valve, sliding sleeve, rigless ESP, gas lift
mandrel(s), and downhole gauge. RIH to depth, stab seal assembly into liner hanger and land tubing hanger.
22. Pressure test hanger seals to 5,000 psi.
23. Test tubing to 1,500 psi.
24. Pressure test IA to 2,000 psi, chart test.
25. Install HP-BPV and test to 1,500 psi.
26. Nipple down BOP.
27. Install tubing head adapter assembly. N/U tree and test to 5000 psi/10 minutes.
28. Freeze protect well.
29. Secure well. Rig down and move out.
Application for Permit to Drill, 1C-157
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4. Blowout Prevention Equipment (Requirements of 20 AAC 25.005(c)(3))
Please reference BOP schematics on file for Doyon 142.
Doyon 142 will use a BOPE stack equipped with an annular preventer, fixed 9.625” solid body rams,
blind/shear rams and variable rams while drilling and running casing in the intermediate section of 1C-157.
1C-157 has a MASP of 1297 psi in the intermediate hole section using the methodology in section 6 MASP
calculations. With a MASP less than 3000 psi ConocoPhillips classifies the operation as a Class 2.
Per 20AAC 25.035.e.a.A:
For an operation with a maximum potential surface pressure of 3,000 psi or less, BOPE must have at
least three preventers, including:
i. One equipped with pipe rams that fit the size of drill pipe, tubing or casing begin used, except
that pipe rams need not be sixed to bottom-hole assemblies and drill collars.
ii. One with blind rams
iii. One annular type
Intermediate Drilling/Casing Production
9-5/8” fixed rams during drilling Intermediate 3-1/2”x6” VBR in Upper Cavity
3-1/2” x 6” VBR in Lower Cavity 2-7/8”x5-1/2” VBR in Lower Cavity
5. Diverter System (Requirements of 20 AAC 25.005(c)(7))
It is requested that a variance of the diverter requirement under 20 AAC 25.035(h)(2) is granted for well 1C-157.
There are 9 wells within 500’ of surface hole location (1C-01, 28, 21, 26, 20, 02, 133, 24, 03). One well, 1C-20,
observed hydrates at 1200’, with max 410 units at 2,032’ TVD and 9.4ppg.
6. MASP Calculations (Requirements of 20 AAC 25.005(c)(4))
The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well:
Casing Size Csg Setting Depth Fracture Pore pressure ASP Drilling
Application for Permit to Drill, 1C-157
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1C-157 PTD
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(in) MD/TVD(ft) Gradient (ppg) (psi) (psi)
20 120 / 120 10.9 51 54
13.375 2027/ 1907 15.0 853 1297
9.625 10974/ 3987 12.2 1,783 1367
4.5 21214/ 3937 12.2 1,761 n/a
PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP)
ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient
to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows:
1) ASP = [(FG x 0.052) - 0.1]*D
Where: ASP = Anticipated Surface pressure in psi
FG = Fracture gradient at the casing seat in lb/gal
0.052 = Conversion from lb./gal to psi/ft
0.1 = Gas gradient in psi/ft
D = true Vertical depth of casing seat in ft RKB
OR
2) ASP = FPP – (0.1 x D)
Where: FPP = Formation Pore Pressure at the next casing point
FPP = 0.4525 x TVD
1. ASP CALCULATIONS
1. Drilling below 20” conductor
ASP = [(FG x 0.052) – 0.1] D
= [(10.9 x 0.052) – 0.1] x 115 = 54 psi
OR
ASP = FPP – (0.1 x D)
= 853 – (0.1 x 1907) = 662 psi
2. Drilling below 13.375” surface casing
ASP = [(FG x 0.052) – 0.1] D
= [(15 x 0.052) – 0.1] x 1907= 1297 psi
OR
ASP = FPP – (0.1 x D)
= 1783 – (0.1 x 3987) = 1384 psi
3. Drilling below 9.625” intermediate casing
ASP = [(FG x 0.052) – 0.1] D
= [(12.2 x 0.052) – 0.1] x 3987= 2131 psi
OR
ASP = FPP – (0.1 x D)
= 1761– (0.1 x 3937 )= 1367 psi
(B) data on potential gas zones;
The well bore is not expected to penetrate any shallow gas zones.
(C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation
zones, and zones that have a propensity for differential sticking;
Application for Permit to Drill, 1C-157
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Please see Drilling Hazards Summary
7. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005(c)(5))
Drill out the casing shoe and perform LOT/FIT as per the procedure that ConocoPhillips Alaska has on file
with the Commission.
8. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6))
Casing and Cementing Program
Csg/Tbg
OD (in)
Hole Size
(in)
Weight
(lb/ft) Grade Conn. Cement Program
20 42 94 H-40 Welded Cemented to surface with 10 yds slurry
13.375 16 68 L-80 Hyd563 Cement to Surface
9.625 12.25 40.0 L80 Hyd563 250’TVD or 500’MD, whichever is greater, above upper
most producing zone (Ugnu C)
4.5 8.375 12.6 L-80 Hyd563 N/A - OHSAS
Cementing Calculations
13.375” Surface Casing run to 2027’ MD / 1907’ TVD
Cement from 2027’ MD to 1527' (500’ of tail) with Class G + Add's @ 15.8 PPG, and from 1527' to surface with
10.7 ppg Arctic Lite Crete. Assume 250% excess annular volume for lead and 50% excess for tail, zero excess in
20” conductor.
Lead slurry from 1527’ MD to surface with Arctic Lite Crete @ 10.7 ppg
Total Volume = 2479 ft3 => 850 sx of 10.7ppg Class G + Add's @ 2.92 ft3 /sk
Tail slurry from 2027’ MD to 1527’ MD with 15.8 ppg Class G + Add's
Total Volume = 383 ft3 => 330.0 sx of 15.8 ppg Class G + Add's @ 1.16 ft3/sk
9.625” Intermediate Casing run to 10974’ MD / 3987’ TVD
Top of slurry is designed to be at 3881’ MD, which is 500’MD or 250’ TVD above the prognosis shallowest
hydrocarbon bearing zone, Ugnu C. Assume 20% excess annular volume.
Tail slurry from 10974’ MD to 3881’ MD with 15.3 ppg Class G + Add's
Total Volume = 2700ft3 => 2160 sx of 15.3 ppg Class G + Add's@ 1.25 ft3/sk
9. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8))
Surface Intermediate Production
Hole Size in. 16 12.25 8.375
r 250’ TVD above the prognosis shallowest pyg
hydrocarbon bearing zone, Ugnu C. A
Application for Permit to Drill, 1C-157
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1C-157 PTD
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Casing Size in. 13.375 9.625 4.5
Density PPG 9.0 – 10.5 9.0 – 9.5 9.0 – 9.5
PV cP 20-50 8-15 ALAP
YP lb./100 ft2 30 - 80 20 - 30 15 - 20
Funnel Viscosity s/qt.
250 – 300 to
base perm
200-300 to TD
40-60 35-50
Initial Gels lb./100 ft2 30 - 50 8 - 15 5- 10
10 Minute Gels lb./100 ft2 50 - 70 <20 7 - 15
API Fluid Loss cc/30 min. N.C. – 15.0 < 10.0 < 6.0
HPHT Fluid Loss cc/30 min. N/A N/A < 10.0
pH 9.0 – 10.0 9.0 – 10.0 9.5 – 10.0
Surface Hole:
A water based spud mud will be used for the surface interval. Mud engineer to perform regular mud checks to
maintain proper specifications The mud weight will be maintained at M10.5 ppg by use of solids control system and
dilutions where necessary.
Intermediate:
Fresh water polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid
annular velocity. Maintain mud weight at or below 9.5 ppg for formation stability and be prepared to add loss
circulation material if necessary. Good filter cake quality, hole cleaning and maintenance of low drill solids (by
diluting as required) will all be important.
Production Hole:
The horizontal production interval will be drilled with a water-based mud drill-in fluid (FloPro NT) weighted to 8.7
– 9.5 ppg.
Diagram of Doyon 142 Mud System on file.
Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033.
10. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9))
N/A - Application is not for an exploratory or stratigraphic test well.
11. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10))
N/A - Application is not for an exploratory or stratigraphic test well.
12. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11))
N/A - Application is not for an offshore well.
13. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12))
Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission.
Application for Permit to Drill, 1C-157
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14. Discussion of Mud and Cuttings Disposal and Annular Disposal
(Requirements of 20 AAC 25.005 (c)(14))
Waste fluids and cuttings generated during the drilling process will be disposed of by hauling the fluids to a KRU Class
II disposal well at the 1B Facility. If needed, excess cuttings generated will be hauled to Milne Point or Prudhoe Bay
Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well,
or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk
area in accordance with a permit from the State of Alaska.
15. Drilling Hazards Summary
16" Hole / 13.375” Casing Interval
Event Risk Level Mitigation Strategy
Conductor Broach Low Monitor cellar continuously during interval.
Well Collision Low Follow real time surveys very closely, gyro survey as
needed to ensure survey accuracy.
Gas Hydrates Low If observed – control drill, reduce pump rates and
circulating time, reduce mud temperatures
Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets),
pumping out
Washouts/Hole Sloughing Low Cool mud temperatures, minimize circulating times
when possible
Running sands and gravels Low Maintain planned mud properties, increase mud
weight, use weighted sweeps
12.25” Hole /9.625” Liner - Casing Interval
Event Risk Level Mitigation Strategy
Sloughing shale / Tight
hole / Stuck Pipe
Low Good hole cleaning, pre-treatment with LCM,
stabilized BHA, maintain planned mud weights and
adjust as needed, real time equivalent circulating
density (ECD) monitoring
Lost circulation Moderate Reduce pump rates, reduce trip speeds, real time
ECD monitoring, mud rheology, add lost circulation
material
Hole swabbing on trips Moderate Reduce trip speeds, condition mud properties,
proper hole filling, pump out of hole, real time ECD
monitoring, Liner will be in place at TD
Running Casing to Bottom Moderate Properly clean hole on the trip out with BHA,
perform clean out run if necessary, monitor T&D
real time
8.375” Hole / 4.5” Liner - Horizontal Production Hole
Event Risk Level Mitigation Strategy
Lost circulation Moderate Reduce pump rates, real time ECD monitoring,
maintain mud rheology, add lost circulation
material
Hole swabbing on trips Moderate Reduce trip speeds, condition mud properties,
proper hole filling, pump out of hole, real time ECD
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monitoring
Abnormal Reservoir
Pressure
Low Well control drills, check for flow during
connections, increased mud weight
Differential Sticking Moderate Uniform reservoir pressure along lateral, keep pipe
moving, control mud weight
Running Liner to Bottom Moderate Properly clean hole on the trip out with BHA,
perform clean out run if necessary, utilize super
sliders for weight transfer if needed, monitor T&D
real time
Well Proximity Risks:
1C is a multi-well pad, containing an original 56 wells. Directional drilling / collision avoidance information as
required by AOGCC 20 ACC 25.050 (b) is provided in the following attachments.
Drilling Area Risks:
Reservoir Pressure: Offset injection has the potential to increase reservoir pressure over predicted. Although this is
unlikely, the rig will be prepared to weight up if required.
Weak sand stringers could be present in the overburden. LCM material will be available to seal in losses in the
intermediate section.
Fault Crossings - Lost Circulation: Standard LCM material and well bore strengthening pills are expected to be
effective in dealing with lost circulation if needed.
Good drilling practices will be stressed to minimize the potential of taking swabbed kicks.
H2S on 1C pad – There have been elevated H2S levels noted on the 1C pad post drilling. Below table is readings for
wells with the highest concentrations. We will have H2S sensors on the rig which will be tested, escape packs staged
around the rig, and personal monitors will be worn by the core crew members. A detailed emergency operating
procedure will be communicated to all personnel, in the event H2S is encountered.
Well Name H2S Date Reading (ppm)
1C-109 04/05/2020 550
1C-135 07/30/2015 / 08/12/2016 300 / 240
1C-178 03/13/2022 240
1C-123 08/04/2002 232
1C-102 04/05/2020 220
1C-02 09/25/2011 / 07/30/2015 200 / 200
1C-151 04/04/2020 200
1C-170 04/04/2020 200
Application for Permit to Drill, 1C-157 Saved: 13-Apr-23 1C-157 PTD Page 10 of 9 Printed: 13-Apr-2316. Proposed Completion Schematic
39 500
500 800
800 1100
1100 1400
1400 1700
1700 2000
2000 2500
2500 3000
3000 3500
3500 4000
4000 8500
8500 9000
9000 10300
10300 10400
10400 21215
1C-157 wp13 Plan Summary
0
4
Dogleg Severity0 3500 7000 10500 14000 17500 21000
Measured Depth
10-3/4" Surface Casing 7-5/8" Intermediate Casing
4-1/2" Protective Liner
30.0
30.0
60.0
60.0
0
90
180
270
30
210
60
240 120
300
150
330
Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [60 usft/in]
1233
1323
1C-03 1233
1323
709
810
910
1007
1102
1C-04
709
810
910
1007
1102
709
810
910
1007
1102
103203303403
502
600
698
1C-05
1104
1184
1C-178
1104
1184
1104
1184
1104
1184
96
196296
396497
596
696
794
892
987
1C-18
39100200300401502
602
702
802
901
999
1096
1191
1C-156 wp13 - permit
39100200300400499599698
79789699610951194129313921491
1589
1688
1786
1C-158 wp07
0
2250
True Vertical Depth-6250 -5000 -3750 -2500 -1250 0 1250
Vertical Section at 300.00°
10-3/4" Surface Casing
7-5/8" Intermediate Casing 4-1/2" Protective Liner
15
30
Centre to Centre Separation0 425 850 1275 1700 2125 2550 2975
Measured Depth
Equivalent Magnetic Distance
DDI
7.473
SURVEY PROGRAM
Date: 2014-11-10T00:00:00 Validated: Yes Version:
Depth From Depth To Survey/Plan Tool
39.10 1600.00 1C-157 wp13 (1C-157) SDI_URSA1_I4
1600.00 2020.00 1C-157 wp13 (1C-157)MWD OWSG
1600.00 2020.00 1C-157 wp13 (1C-157) MWD+IFR2+SAG+MS
2020.00 3020.00 1C-157 wp13 (1C-157) MWD OWSG
2020.00 10970.00 1C-157 wp13 (1C-157) MWD+IFR2+SAG+MS
10970.00 11970.00 1C-157 wp13 (1C-157) MWD OWSG
10970.00 21214.75 1C-157 wp13 (1C-157) MWD+IFR2+SAG+MS
*round / 58.33
CASING DETAILS
TVD MD Name
1907.40 2027.74 10-3/4" Surface Casing
3987.44 10980.00 7-5/8" Intermediate Casing
3937.40 21214.74 4-1/2" Protective Liner
Mag Model & Date: BGGM2022 01-Jul-23
Magnetic North is 14.55° East of True North (Magnetic Declinatio
Mag Dip & Field Strength: 80.64° 57203.06nT
SECTION DETAILS
Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation
1 39.10 0.00 0.00 39.10 0.00 0.00 0.00 0.00 0.00
2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 Start Build 1.50
3 500.00 3.00 160.00 499.91 -4.92 1.79 1.50 160.00 -4.01 Start Build 2.00
4 700.00 7.00 160.00 699.11 -21.30 7.75 2.00 0.00 -17.36 Start DLS 2.50 TFO -10.00
5 1815.48 34.46 143.61 1732.40 -352.87 213.53 2.50 -10.00 -361.36 Start 121.29 hold at 1815.48 MD
6 1936.77 34.46 143.61 1832.40 -408.13 254.25 0.00 0.00 -424.25 Start 90.97 hold at 1936.77 MD
7 2027.74 34.46 143.61 1907.40 -449.57 284.79 0.00 0.00 -471.41 Start 20.00 hold at 2027.74 MD
8 2047.74 34.46 143.61 1923.89 -458.68 291.50 0.00 0.00 -481.79 Start DLS 2.00 TFO -11.39
9 4580.45 84.62 134.78 3168.83 -2027.23 1704.76 2.00 -11.39 -2489.98 Start 1838.47 hold at 4580.45 MD
10 6418.92 84.62 134.78 3341.14 -3316.63 3003.89 0.00 0.00 -4259.76 Start DLS 3.50 TFO -99.78
11 9900.71 84.60 12.00 3894.30 -2514.24 5694.46 3.50 -99.78 -6188.67 Start 220.00 hold at 9900.71 MD
1210120.71 84.60 12.00 3915.00 -2300.00 5740.00 0.00 0.00 -6120.99 Start DLS 3.50 TFO -85.42
1310360.29 85.32 3.62 3936.08 -2063.78 5772.38 3.50 -85.42 -6030.92 Start 331.62 hold at 10360.29 MD
1410691.91 85.32 3.62 3963.11 -1733.92 5793.22 0.00 0.00 -5884.03 Start DLS 3.50 TFO -92.20
1510994.21 85.00 353.00 3988.68 -1433.26 5784.34 3.50 -92.20 -5726.02 Start Build 2.50
1611194.21 90.00 353.00 3997.40 -1235.00 5760.00 2.50 0.00 -5605.81 Start 20.00 hold at 11194.21 MD
1711214.21 90.00 353.00 3997.40 -1215.15 5757.56 0.00 0.00 -5593.77 Start DLS 2.00 TFO -83.04
1811473.55 90.63 347.85 3995.98 -959.52 5714.44 2.00 -83.04 -5428.61 Start 681.99 hold at 11473.55 MD
1912155.54 90.63 347.85 3988.51 -292.84 5570.92 0.00 0.00 -4970.98 Start DLS 2.00 TFO -86.52
2012248.27 90.74 346.00 3987.40 -202.53 5549.94 2.00 -86.52 -4907.66 1C-157 Tgt 02 102822 Start DLS 2.00 TFO -85.91
21 12417.79 90.98 342.62 3984.85 -39.37 5504.11 2.00 -85.91 -4786.38 Start 2127.46 hold at 12417.79 MD
2214545.25 90.98 342.62 3948.45 1990.64 4868.63 0.00 0.00 -3221.04 Start DLS 1.00 TFO 143.24
2314667.63 90.00 343.35 3947.40 2107.66 4832.82 1.00 143.24 -3131.51 1C-157 Tgt 03 102822 Start DLS 1.00 TFO 141.43
2414706.57 89.70 343.59 3947.50 2144.99 4821.74 1.00 141.43 -3103.26 Start 2783.81 hold at 14706.57 MD
2517490.38 89.70 343.59 3962.29 4815.40 4035.43 0.00 0.00 -1087.09 Start DLS 1.00 TFO 40.20
2617530.23 90.00 343.85 3962.40 4853.65 4024.26 1.00 40.20 -1058.28 1C-157 Tgt 04 102822 Start DLS 1.00 TFO 39.50
2717580.96 90.39 344.17 3962.23 4902.42 4010.29 1.00 39.50 -1021.80 Start 3633.79 hold at 17580.96 MD
28 21214.75 90.39 344.17 3937.40 8398.36 3019.23 0.00 0.00 1584.45 1C-157 Tgt 06 102822 TD at 21214.75
FORMATION TOP DETAILS
TVDPath Formation
1677.42 T-5
1782.42 Base Perm
2009.42 T-3
2274.42 K-15
3270.42 Ugnu C
3483.42 Ugnu B
3608.42 Ugnu A
3702.42 N
3911.42 WSAK D
By signing this I acknowledge that I have been informed of all risks, checked that the data is correct, ensured it's completeness, and all surroundingwells are assigned to the proper position, and I approve the scan and collision avoidance plan as set out in the audit pack.I approve it as the basiis
for the final well plan and wellsite drawings. I also acknowledge that unless notified otherwise all targets have a 100 feet lateral tolerance.
Prepared by Checked by Accepted by Approved by
Plan@D142: 39.1+58.3 @ 97.40usft
0150030004500True Vertical Depth-6000 -4500 -3000 -1500 0 1500 3000Vertical Section at 300.00°10-3/4" Surface Casing7-5/8" Intermediate Casing4-1/2" Production Liner1000200030004 0 0 0
50 0 0
6 0 0 0
7 0 0 0
8 0 0 0
9000100001100012 00 0
1 300 0
140 0015000 160001700018000
1900 0
20000
21000
21215
0°30°34°6 0 °8 5 °85°85°90°9 1 °
9 1°90°9 0°
1C-157 wp13
T-5Base PermT-3K-15Ugnu CUgnu BUgnu ANWSAK D1C-157 wp1310:21, April 11 2023Section View
-25000250050007500South(-)/North(+)-5000 -2500 0 2500 5000 7500 10000West(-)/East(+)10-3/4" Surface Casing7-5/8" Intermediate Casing4-1/2" Production Liner1C-157 wp13While drilling production section, stay within 100 feet laterally of plan, unless notified otherwise.10:23, April 11 2023
0
35
Centre to Centre Separation0 500 1000 1500 2000 2500
Partial Measured Depth1C-031C-03A1C-041C-04A1C-04AL11C-051C-1781C-178L11C-178L1PB11C-178L1PB21C-181C-156 wp13 - permit1C-158 wp07Equivalent Magnetic Distance
1C-157 wp13 Ladder View
0
150
300
Centre to Centre Separation0 3500 7000 10500 14000 17500 21000
Measured Depth1C-011C-01L11C-01L1-011C-01L1-021C-01L1-031C-021C-031C-03A1C-041C-04A1C-04AL11C-051C-061C-06L11C-06L1-011C-06L1-021C-1171C-1191C-121C-1211C-1231C-1251C-1271C-131C-1311C-1331C-1351C-135PB11C-141C-14A1C-151C-15L11C-15L21C-15L2PB11C-1501C-1511C-1521C-1531C-1541C-1551C-161C-1701C-170PB11C-1721C-172A1C-172AL11C-172AL21C-172AL2PB11C-172AL2PB21C-1741C-1781C-178L11C-178L1PB11C-178L1PB21C-181C-1841C-201C-20PB11C-211C-21L11C-21L21C-21L31C-231C-23A1C-23AL11C-23AL21C-23AL2-011C-23AL2-021C-23PB11C-241C-24L11C-261C-281C-28L11C-28PB11C-156 wp13 - permit1C-158 wp071C-501 wp12 - permitEquivalent Magnetic Distance
SURVEY PROGRAM
Depth From Depth To Survey/Plan Tool
39.10 1600.00 1C-157 wp13 (1C-157) SDI_URSA1_I4
1600.00 2020.00 1C-157 wp13 (1C-157) MWD OWSG
1600.00 2020.00 1C-157 wp13 (1C-157) MWD+IFR2+SAG+MS
2020.00 3020.00 1C-157 wp13 (1C-157) MWD OWSG
2020.0010970.00 1C-157 wp13 (1C-157) MWD+IFR2+SAG+MS
10970.0011970.00 1C-157 wp13 (1C-157) MWD OWSG
10970.00 21214.75 1C-157 wp13 (1C-157) MWD+IFR2+SAG+MS
10:31, April 11 2023
CASING DETAILS
TVD MD Name
1907.40 2027.74 10-3/4" Surface Casing
3987.44 10980.00 7-5/8" Intermediate Casing
3937.40 21214.74 4-1/2" Production Line
39 500
500 800
800 1100
1100 1400
1400 1700
1700 2000
2000 2500
2500 3000
3000 3500
3500 4000
4000 8500
8500 9000
9000 10300
10300 10400
10400 21215
1C-157 wp13 TC View
30
30
60
60
90
90
120
120
150
150
0
90
180
270
30
210
60
240 120
300
150
330
Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [60 usft/in]
1470
1517
1564
1611
1657
1702
1747
1791
1836
18811C-02
8839359871038108811381186123312781323136714101452149315331C-03
8839359871038108811381186123312781323136714101452149315331C-03A
53103153203
253303354405456507558608659709
760
810
860
910
959
1007
1055
1102
1148
1193
1237
1280
1321
1361
1C-04
53103153203
253303354405456507558608659709
760
810
860
910
959
1007
1055
1102
1148
1193
1237
1280
1321
1361
1C-04A
53103153203
253303354405456507558608659709
760
810
860
910
959
1007
1055
1102
1148
1193
1237
1280
1321
1361
1C-04AL1
53103153203253303353403452502551600649
698
746
794
841
889
935
982
1028
1074
1119
11631C-05
531031532032533033524004484965441C-06
531031532032533033524004484965441C-06L1
531031532032533033524004484965441C-06L1-01
531031532032533033524004484965441C-06L1-02
4696145195245
295344393442490538586634681
728
775
8211C-13
4050100
1502001C-154
4696146196246296345394443491
539
586
633
679
725
769
813
1C-16
3960110160210260310
360410459509558607
656
705
753
801
848
894
940
985
1C-170
3960110160210260310
360410459509558607
656
705
753
801
848
894
940
985
1C-170PB1
39
60110160210260310360410460510
559
609
657
706
754
801
847
1C-172
394797147197247297347397447497546
596
644
693
741
789
835
1C-172A
394797147197247297347397447497546
596
644
693
741
789
835
1C-172AL1
394797147197247297347397447497546
596
644
693
741
789
835
1C-172AL2
394797147197247297347397447497546
596
644
693
741
789
835
1C-172AL2PB1
394797147197247297347397447497546
596
644
693
741
789
835
1C-172AL2PB2
3960110160210260310361411461510
559
608
656
703
748
793
837
880
921
961
1C-174
720771821871920968101510611104
1145
1184
1221
1256
1289
1C-178
720771821871920968101510611104
1145
1184
1221
1256
1289
1C-178L1
720771821871920968101510611104
1145
1184
1221
1256
1289
1C-178L1PB1
720771821871920968101510611104
1145
1184
1221
1256
1289
1C-178L1PB2
4696146196246
296346396446497547596646696
745
794
843
892
940
987
1034
1081
1127
1172
1217
1261
13051C-18
1141
1192
1243
1293
1342
1392
1441
1490
1539
1587
1635
1682
1C-21
1141
1192
1243
1293
1342
1392
1441
1490
1539
1587
1635
1682
1C-21L1
1141
1192
1243
1293
1342
1392
1441
1490
1539
1587
1635
1682
1C-21L2
1141
1192
1243
1293
1342
1392
1441
1490
1539
1587
1635
1682
1C-21L3
1668171717651812185619001944198820322076211921611C-24
1668171717651812185619001944198820322076211921611C-24L1 4796146196246296348400
451503555607659711764
816
869
921
973
1025
10357
10345
10333
10322
103111C-28
4796146196246296348400
451503555607659711764
816
869
921
973
1025
10357
10345
10333
10322
103111C-28L1
4796146196246296348400
451503555607659711764
816
869
921
973
1025
10357
10345
10333
10322
103111C-28PB1
3950100150200250300350401451502552602652702752802
852
901
950
999
1047
1096
1144
1191123912861333137914251471151615611606
1C-156 wp13 - permit
3950100150200250300350400449499549599648698748
79784789694699610451095114411941244129313431392144114911540158916391688173717861835188419341984203320822131218022292279232823772426247625252575262426732723277228222871
29212970301930693118316732173266 3315 3364 3413 3462 3511 3560 3609 3657 37061C-158 wp07
SURVEY PROGRAM
Date: 2014-11-10T00:00:00 Validated: Yes Version:
From To Tool
39.10 1600.00 SDI_URSA1_I4
1600.00 2020.00 MWD OWSG
1600.00 2020.00 MWD+IFR2+SAG+MS
2020.00 3020.00 MWD OWSG
2020.00 10970.00 MWD+IFR2+SAG+MS
10970.00 11970.00 MWD OWSG
10970.00 21214.75 MWD+IFR2+SAG+MS
CASING DETAILS
TVD MD Name
1907.40 2027.74 10-3/4" Surface Casing
3987.44 10980.00 7-5/8" Intermediate Casing
3937.40 21214.74 4-1/2" Production Liner
SECTION DETAILS
Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation
1 39.10 0.00 0.00 39.10 0.00 0.00 0.00 0.00 0.00
2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 Start Build 1.50
3 500.00 3.00 160.00 499.91 -4.92 1.79 1.50 160.00 -4.01 Start Build 2.00
4 700.00 7.00 160.00 699.11 -21.30 7.75 2.00 0.00 -17.36 Start DLS 2.50 TFO -10.00
5 1815.48 34.46 143.61 1732.40 -352.87 213.53 2.50 -10.00 -361.36 Start 121.29 hold at 1815.48 MD
6 1936.77 34.46 143.61 1832.40 -408.13 254.25 0.00 0.00 -424.25 Start 90.97 hold at 1936.77 MD
7 2027.74 34.46 143.61 1907.40 -449.57 284.79 0.00 0.00 -471.41 Start 20.00 hold at 2027.74 MD
8 2047.74 34.46 143.61 1923.89 -458.68 291.50 0.00 0.00 -481.79 Start DLS 2.00 TFO -11.39
9 4580.45 84.62 134.78 3168.83 -2027.23 1704.76 2.00 -11.39 -2489.98 Start 1838.47 hold at 4580.45 MD
10 6418.92 84.62 134.78 3341.14 -3316.63 3003.89 0.00 0.00 -4259.76 Start DLS 3.50 TFO -99.78
11 9900.71 84.60 12.00 3894.30 -2514.24 5694.46 3.50 -99.78 -6188.67 Start 220.00 hold at 9900.71 MD
1210120.71 84.60 12.00 3915.00 -2300.00 5740.00 0.00 0.00 -6120.99 Start DLS 3.50 TFO -85.42
1310360.29 85.32 3.62 3936.08 -2063.78 5772.38 3.50 -85.42 -6030.92 Start 331.62 hold at 10360.29 MD
1410691.91 85.32 3.62 3963.11 -1733.92 5793.22 0.00 0.00 -5884.03 Start DLS 3.50 TFO -92.20
1510994.21 85.00 353.00 3988.68 -1433.26 5784.34 3.50 -92.20 -5726.02 Start Build 2.50
1611194.21 90.00 353.00 3997.40 -1235.00 5760.00 2.50 0.00 -5605.81 Start 20.00 hold at 11194.21 MD
1711214.21 90.00 353.00 3997.40 -1215.15 5757.56 0.00 0.00 -5593.77 Start DLS 2.00 TFO -83.04
1811473.55 90.63 347.85 3995.98 -959.52 5714.44 2.00 -83.04 -5428.61 Start 681.99 hold at 11473.55 MD
1912155.54 90.63 347.85 3988.51 -292.84 5570.92 0.00 0.00 -4970.98 Start DLS 2.00 TFO -86.52
2012248.27 90.74 346.00 3987.40 -202.53 5549.94 2.00 -86.52 -4907.66 1C-157 Tgt 02 102822 Start DLS 2.00 TFO -85.91
21 12417.79 90.98 342.62 3984.85 -39.37 5504.11 2.00 -85.91 -4786.38 Start 2127.46 hold at 12417.79 MD
2214545.25 90.98 342.62 3948.45 1990.64 4868.63 0.00 0.00 -3221.04 Start DLS 1.00 TFO 143.24
2314667.63 90.00 343.35 3947.40 2107.66 4832.82 1.00 143.24 -3131.51 1C-157 Tgt 03 102822 Start DLS 1.00 TFO 141.43
2414706.57 89.70 343.59 3947.50 2144.99 4821.74 1.00 141.43 -3103.26 Start 2783.81 hold at 14706.57 MD
2517490.38 89.70 343.59 3962.29 4815.40 4035.43 0.00 0.00 -1087.09 Start DLS 1.00 TFO 40.20
2617530.23 90.00 343.85 3962.40 4853.65 4024.26 1.00 40.20 -1058.28 1C-157 Tgt 04 102822 Start DLS 1.00 TFO 39.50
2717580.96 90.39 344.17 3962.23 4902.42 4010.29 1.00 39.50 -1021.80 Start 3633.79 hold at 17580.96 MD
28 21214.75 90.39 344.17 3937.40 8398.36 3019.23 0.00 0.00 1584.45 1C-157 Tgt 06 102822 TD at 21214.75
1C-157 wp13AC FlipbookSURVEY PROGRAMDepth From Depth To Tool39.10 1600.00 SDI_URSA1_I41600.00 2020.00 MWD OWSG1600.00 2020.00 MWD+IFR2+SAG+MS2020.00 3020.00 MWD OWSG2020.00 10970.00 MWD+IFR2+SAG+MS10970.00 11970.00 MWD OWSG10970.00 21214.75 MWD+IFR2+SAG+MSCASING DETAILSTVDMDName1907.40 2027.7410-3/4" Surface Casing3987.44 10980.007-5/8" Intermediate Casing3937.40 21214.744-1/2" Production Liner1010202030304040505060600901802703021060240120300150330Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [20 usft/in]12331278132313671C-0312331278132313671C-03A65970976081086091095910071055110211481C-0465970976081086091095910071055110211481C-04A65970976081086091095910071055110211481C-04AL1531031532032533033534034525025516006496987461C-0510611104114511841C-17810611104114511841C-178L110611104114511841C-178L1PB110611104114511841C-178L1PB246961461962462963463964464975475966466967457948438929409871C-18395010015020025030035040145150255260265270275280285290195099910471096114411911C-156 wp13 - permit395010015020025030035040044949954959964869874879784789694699610451095114411941244129313431392144114911540158916391688173717861C-158 wp0739 500500 800800 11001100 14001400 17001700 20002000 25002500 30003000 35003500 40004000 85008500 90009000 1030010300 1040010400 21215From Colour To MD39.10 To 2000.00MD Azi TFace39.10 0.00 0.00300.00 0.00 0.00500.00 160.00 160.00700.00 160.00 0.001815.48 143.61 -10.001936.77 143.61 0.002027.74 143.61 0.002047.74 143.61 0.004580.45 134.78 -11.396418.92 134.78 0.009900.71 12.00 -99.7810120.71 12.00 0.0010360.29 3.62 -85.4210691.91 3.62 0.0010994.21 353.00 -92.2011194.21 353.00 0.0011214.21 353.00 0.0011473.55 347.85 -83.0412155.54 347.85 0.0012248.27 346.00 -86.5212417.79 342.62 -85.9114545.25 342.62 0.0014667.63 343.35 143.2414706.57 343.59 141.4317490.38 343.59 0.0017530.23 343.85 40.2017580.96 344.17 39.5021214.75 344.17 0.00
1C-157 wp13AC FlipbookSURVEY PROGRAMDepth From Depth To Tool39.10 1600.00 SDI_URSA1_I41600.00 2020.00 MWD OWSG1600.00 2020.00 MWD+IFR2+SAG+MS2020.00 3020.00 MWD OWSG2020.00 10970.00 MWD+IFR2+SAG+MS10970.00 11970.00 MWD OWSG10970.00 21214.75 MWD+IFR2+SAG+MSCASING DETAILSTVDMDName1907.40 2027.7410-3/4" Surface Casing3987.44 10980.007-5/8" Intermediate Casing3937.40 21214.744-1/2" Production Liner3030606090901201201501501801800901802703021060240120300150330Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [60 usft/in]1926197220191C-02190019441988203220762119216122031C-24190019441988203220762119216122031C-24L11964201320632114216522162268231923702421247225231C-26103691035710345103331032210311103001C-28103691035710345103331032210311103001C-28L1103691035710345103331032210311103001C-28PB11934198420332082213121802229227923282377242624762525257526242673272327722822287129212970301930693118316732173266331533643413346235113560360936573706375538031C-158 wp07866486858704872387411C-501 wp12 - permit39 500500 800800 11001100 14001400 17001700 20002000 25002500 30003000 35003500 40004000 85008500 90009000 1030010300 1040010400 21215From Colour To MD1900.00 To 11000.00MD Azi TFace39.10 0.00 0.00300.00 0.00 0.00500.00 160.00 160.00700.00 160.00 0.001815.48 143.61 -10.001936.77 143.61 0.002027.74 143.61 0.002047.74 143.61 0.004580.45 134.78 -11.396418.92 134.78 0.009900.71 12.00 -99.7810120.71 12.00 0.0010360.29 3.62 -85.4210691.91 3.62 0.0010994.21 353.00 -92.2011194.21 353.00 0.0011214.21 353.00 0.0011473.55 347.85 -83.0412155.54 347.85 0.0012248.27 346.00 -86.5212417.79 342.62 -85.9114545.25 342.62 0.0014667.63 343.35 143.2414706.57 343.59 141.4317490.38 343.59 0.0017530.23 343.85 40.2017580.96 344.17 39.5021214.75 344.17 0.00
1C-157 wp13AC FlipbookSURVEY PROGRAMDepth From Depth To Tool39.10 1600.00 SDI_URSA1_I41600.00 2020.00 MWD OWSG1600.00 2020.00 MWD+IFR2+SAG+MS2020.00 3020.00 MWD OWSG2020.00 10970.00 MWD+IFR2+SAG+MS10970.00 11970.00 MWD OWSG10970.00 21214.75 MWD+IFR2+SAG+MSCASING DETAILSTVDMDName1907.40 2027.7410-3/4" Surface Casing3987.44 10980.007-5/8" Intermediate Casing3937.40 21214.744-1/2" Production Liner50501001001501502002002502503003000901802703021060240120300150330Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [100 usft/in]143311433414336143401C-14143311433414336143401C-14A1293612927129181290912901128931288512878128711C-231293612927129181290912901128931288512878128711C-23A1293612927129181290912901128931288512878128711C-23AL11293612927129181290912901128931288512878128711C-23AL21293612927129181290912901128931288512878128711C-23AL2-011293612927129181290912901128931288512878128711C-23AL2-02129441293512926129181290912900128921C-23PB1104051039410382103691035710345103331032210311103001029010281102731C-28104051039410382103691035710345103331032210311103001029010281102731C-28L1104051039410382103691035710345103331032210311103001029010281102731C-28PB139 500500 800800 11001100 14001400 17001700 20002000 25002500 30003000 35003500 40004000 85008500 90009000 1030010300 1040010400 21215From Colour To MD10000.00 To 213215.00MD Azi TFace39.10 0.00 0.00300.00 0.00 0.00500.00 160.00 160.00700.00 160.00 0.001815.48 143.61 -10.001936.77 143.61 0.002027.74 143.61 0.002047.74 143.61 0.004580.45 134.78 -11.396418.92 134.78 0.009900.71 12.00 -99.7810120.71 12.00 0.0010360.29 3.62 -85.4210691.91 3.62 0.0010994.21 353.00 -92.2011194.21 353.00 0.0011214.21 353.00 0.0011473.55 347.85 -83.0412155.54 347.85 0.0012248.27 346.00 -86.5212417.79 342.62 -85.9114545.25 342.62 0.0014667.63 343.35 143.2414706.57 343.59 141.4317490.38 343.59 0.0017530.23 343.85 40.2017580.96 344.17 39.5021214.75 344.17 0.00
1C-157 wp13Spider Plot11:20, April 11 202310000.00 To 213215.00Northing (4000 usft/in)Easting (4000 usft/in)3 5404550556065701C-013 5404550556065 1C-01L13 5404550556065 1C-01L1-013 5404550556065 1C-01L1-023 5404550556065 1C-01L1-03354045505560651C-023 5
4 0
4 5
5 0
5 5
6 0
6 5
1C-033 5
4 0
4 5
5 0
5 5
6 0651C-03A3 54045505560651C-043 5404550556065
1C-04A3 5404550556065
1C-04AL135404550556065701C-05354045505 56065701C-06354045505 56065
1C-06L1354045505 560651C-06L1-01354045505 560651C-06L1-0235404550556065701C-07354045505560651C-07A354045505560651C-07AL1354045505560651C-07AL1PB1354045505560651C-07APB135404550556065701C-08354045505560651C-08L1354045505560651C-08L1-01354045505560651C-08L1PB1354 04550556065701C-0935404550556065701C-10351C-102351C-102L13 5 1C-1043 5 1C-104L13 5 1C-104PB1351C-109351C-109L135404550556065701C-11354045505560651C-11L1354045505560651C-11L1-01354045505560651C-11L1-02354045505560651C-11L2354045505560651C-11L2-01354045505560651C-11L2-0235401C-11135401C-11735401C-119354045505560651C-1235401C-12135401C-12335401C-12535401C-127354045505560651C-1335401C-13135401C-133351C-135351C-135PB13 5
4 0
4 5
5 0
5 5
6 0651C-143 5
4 0
4 5
5 0
5 5
6 0651C-14A3 54045505560651C-153 54045505560651C-15L13 54045505560651C-15L23 54045505560651C-15L2PB1351C-150351C-151351C-152351C-153351C-154351C-155354045505560651C-16354045505560651C-17351C-170351C-170PB1351C-172351C-172A351C-172AL1351C-172AL2351C-172AL2PB1351C-172AL2PB2351C-174351C-178351C-178L1351C-178L1PB1351C-178L1PB2354045505560651C-18351C-184354045505560651C-19354045505560651C-19L1351C-190354045505560651C-20354045505560651C-20PB1354045505560651C-21354045505560651C-21L1354045505560651C-21L2354045505560651C-21L33 5
4 0
4 5
5 0
5 5
6 0
6 51C-2235
4 0
4 5
5 0
5 5
6 0
6 51C-2335
4 0
4 5
5 0
5 5
6 0
6 5
1C-23A35
4 0
4 5
5 0
5 5
6 0
6 5
1C-23AL135
4 0
4 5
5 0
5 5
6 0
6 51C-23AL235
4 0
4 5
5 0
5 5
6 0
6 51C-23AL2-0135
4 0
4 5
5 0
5 5
6 0
6 5 1C-23AL2-023 51C-23PB13540455055606 51C-243540455055601C-24L135
40
4 5
505560651C-2535
40
4 5
505560
6 51C-25L1354045505560651C-26354045505560 1C-27354045505560651C-28354045505560651C-28L1354045505560651C-28PB1351C-156 wp133 540
1C-158 wp07351C-501 wp12 - permit351C-157 wp13
1C-157 wp13Spider Plot11:55, April 11 202310000.00 To 213215.00Northing (950 usft/in)Easting (950 usft/in)2 0
2 5
3 0
3 5
4 0
4 5
5 0
556065 701C-012 0
2 5
3 0
3 5
4 0
4 5
5 0
556065
1C-01L12 0
2 5
3 0
3 5
4 0
4 5
5 0
556065 1C-01L1-012 0
2 5
3 0
3 5
4 0
4 5
5 0
556065
1C-01L1-022 0
2 5
3 0
3 5
4 0
4 5
5 0
556065 1C-01L1-03202530354045505560651C-0220
2 5
3 01C-0320
2 5
3 01C-03A2 0
2 5
3 0
3 51C-042 0
2 5
3 0
3 5
1C-04A2 0
2 5
3 0
3 51C-04AL120253035401C-05201C-06201C-06L1201C-06L1-01201C-06L1-0220251C-0720251C-07A20251C-07AL120251C-07AL1PB120251C-07APB12025301C-082025301C-08L12025301C-08L1-012025301C-08L1PB12 0253035404550556065701C-092025303540455055601C-10201C-102201C-102L11C-1041C-104L11C-104PB1202530351C-109202530351C-109L1201C-11201C-11L1201C-11L1-01201C-11L1-02201C-11L2201C-11L2-01201C-11L2-021C-111201C-1171C-1192025303540451C-121C-121201C-1231C-12520251C-12720251C-1320253035401C-13120253035401C-1332025301C-1352025301C-135PB12 0
2 5
3 01C-142 0
2 5
3 01C-14A2 0
2 5
3 0
3 5
4 0
4 51C-152 0
2 5
3 0
3 5
4 0
4 51C-15L12 0
2 5
3 0
3 5
4 0
4 51C-15L22 0
2 5
3 0
3 5
4 0
4 51C-15L2PB1202530351C-150202530351C-1512025301C-152202 5301C-1532 0
2 5
3 01C-154202530351C-155201C-16201C-1720251C-17020251C-170PB1201C-172201C-172A201C-172AL1201C-172AL2201C-172AL2PB1201C-172AL2PB2201C-174201C-178201C-178L1201C-178L1PB1201C-178L1PB22025303540451C-18202530351C-18420251C-1920251C-19L1202530351C-190202530351C-20202530351C-20PB1202530354045505560651C-21202530354045505560651C-21L1202530354045505560651C-21L2202530354045505560651C-21L32 0
2 51C-222 0
2 5
3 0
35
4 0
4 51C-232 0
2 5
3 0
35
4 0
4 51C-23A2 0
2 5
3 0
35
4 0
4 51C-23AL12 0
2 5
3 0
35
4 0
4 51C-23AL22 0
2 5
3 0
35
4 0
4 51C-23AL2-012 0
2 5
3 0
35
4 0
4 51C-23AL2-022 0
2 5
3 0
3 51C-23PB12025303540455055601C-242025303540455055601C-24L12 0
25
30
35
4 0
4 5
5 05560651C-252 0
25
30
35
4 0
4 5
5 05560
6 51C-25L12025303540455055601C-2620
25
303540455055601C-272025303540451C-282025303540451C-28L12025303540451C-28PB1202530351C-156 wp132025303 5401C-158 wp07202530351C-501 wp12202530351C-157 wp13
1C-157 wp13Spider Plot11:57, April 11 202310000.00 To 213215.00Northing (250 usft/in)Easting (250 usft/in)681012141 6
1 8
2 0
2 2
2 4
2 6
2 8
3 0
3 2
3 4
3 6
3 81C-01681012141 6
1 8
2 0
2 2
2 4
2 6
2 8
3 0
3 2
3 4
3 6
3 81C-01L1681012141 6
1 8
2 0
2 2
2 4
2 6
2 8
3 0
3 2
3 4
3 6
3 81C-01L1-01681012141 6
1 8
2 0
2 2
2 4
2 6
2 8
3 0
3 2
3 4
3 6
3 81C-01L1-02681012141 6
1 8
2 0
2 2
2 4
2 6
2 8
3 0
3 2
3 4
3 6
3 81C-01L1-0368101214161820222426283032341C-026810121416182 0
22
1C-036810121416182 0
22
1C-03A68101 2
1 4
1 6
1 8
2 0
2 2
24
1C-0468101 2
1 4
1 6
1 8
2 0
2 2
24
1C-04A68101 2
1 4
1 6
1 8
2 0
2 2
24
1C-04AL168101214161820222426281C-0568101214161C-0668101214161C-06L168101214161C-06L1-0168101214161C-06L1-0268101214161C-0768101214161C-07A68101214161C-07AL168101214161C-07AL1PB168101214161C-07APB168101214161820221C-0868101214161820221C-08L168101214161820221C-08L1-0168101214161820221C-08L1PB16810121 4161820222426283032343638404244464850525456586062646668701C-0968101214161820221C-106
810121C-1026
810121C-102L16810121C-1046810121C-104L16810121C-104PB16810121416181C-1096810121416181C-109L16810121C-116810121C-11L16810121C-11L1-016810121C-11L1-026810121C-11L26810121C-11L2-016810121C-11L2-026
8
1 0
121C-1116 8
1 0
1 2
14161C-11768
1 0
12141C-119681 0
1 2
1 41618 20222426281C-1268
1 0
1 2
1 4
1C-12168
101214161C-1236
8
1012141C-1256810121416181C-12768101214161820221C-136810121416181C-1316 81012141618202224261C-1336810121416181C-1356810121416181C-135PB16
8
1 0
1 2
1 4
1 6
1 81C-146
8
1 0
1 2
1 4
1 6
1 81C-14A6
8
1 0
1 2
1 4
1 6
1 8
2 0
2 2
2 41C-156
8
1 0
1 2
1 4
1 6
1 8
2 0
2 2
2 41C-15L16
8
1 0
1 2
1 4
1 6
1 8
2 0
2 2
2 41C-15L26
8
1 0
1 2
1 4
1 6
1 8
2 0
2 2
2 41C-15L2PB168101214161820222426281C-150681012141618202224261C-15168101214161C-1526810121416181C-15368101 2
1 4
1 6
1 8
2 0
2 2
2 41C-15468
1 0
1 2
1 4
1 6
1 8
2 0222426 2 81C-15568101214161C-1668101C-17681012141618201C-170681012141618201C-170PB168101214161C-17268101214161C-172A68101214161C-172AL168101214161C-172AL268101214161C-172AL2PB168101214161C-172AL2PB268101214161C-1746
8
1 0
1 2
14161C-1786
8
1 0
1 2
14161C-178L16
8
1 0
1 2
14161C-178L1PB16
8
1 0
1 2
14161C-178L1PB2681012141 61820222426
28303234361C-18681012
1 4161820222426 281C-18468101214161820221C-1968101214161820221C-19L16810121416182022242628301C-19068101214161C-2068101214161C-20PB16 8101214161820222426283032341C-216 8101214161820222426283032341C-21L16 8101214161820222426283032341C-21L26 8101214161820222426283032341C-21L36
8
1 0
1 2
1 4
1 6
1 81C-226
8
1 0
1 2
1 4
1 6
1 8
2 01C-236
8
1 0
1 2
1 4
1 6
1 8
2 01C-23A6
8
1 0
1 2
1 4
1 6
1 8
2 01C-23AL16
8
1 0
1 2
1 4
1 6
1 8
2 01C-23AL26
8
1 0
1 2
1 4
1 6
1 8
2 01C-23AL2-016
8
1 0
1 2
1 4
1 6
1 8
2 01C-23AL2-026
8
1 0
1 2
1 4
1 6
1 81C-23PB16810121416182022242628301C-246810121416182022242628301C-24L16
8
1 0
1 2
1 4
1 6
1 8
2 0
2 2
241C-256
8
1 0
1 2
1 4
1 6
1 8
2 0
2 2
241C-25L168101214161820222426281C-2668
1 0
1 21416
1 8
20
2 2
241C-276810121416182022241C-286810121416182022241C-28L16810121416182022241C-28PB1681012141618202224261C-156 wp13681012141618202224261C-158 wp076810121416182022241C-501 wp12681012141618202224261C-157 wp13
1C-157 wp13Spider Plot11:59, April 11 202310000.00 To 213215.00Northing (55 usft/in)Easting (55 usft/in)13579111C-0313579111C-03A135791 1
1 3
1 4
1 6
1 8
1C-04135791 1
1 3
1 4
1 6
1 8
1C-04A135791 1
1 3
1 4
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1 8
1C-04AL113579111314
1618201C-05135791C-06135791C-06L1135791C-06L1-01135791C-06L1-0213571C-0713571C-07A13571C-07AL113571C-07AL1PB113571C-07APB11357
9
1 1
1C-1171357
9
1C-11913579
1C-121135791C-1231351C-12513 51C-12713579111314
161C-1313
5
71C-1413
5
71C-14A131C-15131C-15L1131C-15L2131C-15L2PB113579
111314161C-1501351C-151135791C-154135791C-161357911131C-1701357911131C-170PB113579111C-17213579111C-172A13579111C-172AL113579111C-172AL213579111C-172AL2PB113579111C-172AL2PB21357911131C-174135
7
9
1 1
1 3
141C-178135
7
9
1 1
1 3
141C-178L1135
7
9
1 1
1 3
141C-178L1PB1135
7
9
1 1
1 3
141C-178L1PB21357911131416182022
242628301C-181351C-201351C-20PB1135791113141C-21135791113141C-21L1135791113141C-21L2135791113141C-21L313579111C-2813579111C-28L113579111C-28PB1135791113141C-156 wp131357911131C-158 wp071357911131C-157 wp13
1C-157 wp131C-011C-01L11C-01L1-011C-01L1-021C-01L1-031C-021C-03A1C-041C-051C-061C-06L11C-07A1C-07AP1C-091C-101C-1021C-102L11C-11C-11C-1091C-109L11C-1171C-11C-1231C-1251C-1271C-131C-1311C-1331C-141C-14A1C-151C-15L11C-15L21C-15L2PB11C-1551C-161C-1721C-172A1C-172AL11C-172AL21C-172AL2PB11C-172AL2PB21C-181C-191C-21L11C-21L21C-21L31C-23A1C-23AL11C-23PB11C-241C-24L11C-251C-25L11C-156 wp13 - permit1C-158 wp071C-501 wp12 - permit3-D View1C-157 wp1311:26, April 11 2023
1C-157 wp131C-011C-01L11C-01L1-011C-01L1-021C-01L1-031C-041C-04A1C-04AL11C-051C-061C-06L11C-06L1-011C-06L1-021C-071C-07A1C-07AL11C-07AL1PB11C-07APB11C-081C-08L11C-08L1-011C-08L1PB11C-091C-111C-11L11C-11L1-011C-11L1-021C-11L21C-11L2-011C-11L2-021C-1111C-1171C-131C-1331C-141C-14A1C-151C-15L11C-15L2PB11C-1531C-1541C-1551C-161C-171C-170PB11C-178L1PB11C-181C-191C-19L11C-23PB11C-24L11C-25L11C-156 wp13 - permit1C-158 wp071C-501 wp12 - permit3-D View1C-157 wp1311:27, April 11 2023
-2500025005000750010000South(-)/North(+) (2500 usft/in)-5000 -2500 0 2500 5000 7500 10000 12500 15000West(-)/East(+) (2500 usft/in)3 939394040401C-013 93939404040 1 C -0 1 L 1
3 93939404040 1C-01L1-013 93939404040 1C-01L1-023 93939404040 1C-01L1-033939394040401C -023 93939404040
1 C -0 3
3 93939404040
1C-03A393939404040
1C-04393939404040
1C-04A393939404040
1C-04AL13939394040401C-053939394040401C -0 6
3939394040401C-06L13939394040401C-06L1-013939394040401C-06L1-023939394040401C-073939394040401C-07A3939394040401C-07AL13939394040401C-07AL1PB13939394040401C-07APB13939394040401C-083939394040401C-08L13939394040401C-08L1-013939394040401C-08L1PB13 939394040401C-093939394040401C-101C-1021C-102L11C-1041C-104L11C-104PB11C-1091C-109L13939394040401C-113939394040401C-11L13939394040401C-11L1-013939394040401C-11L1-023939394040401C-11L23939394040401C-11L2-013939394040401C-11L2-023939394040401C-1113939394040401C-1173939394040401C-1193939394040401C-123939394040401C-1213939394040401C -1231C-1251C-1273939394040401C-131C-1313939394040401C-1331C-1351C-135PB13 93939404040
1 C -1 4
3 939394040401C-14A3 93939404040
1 C -1 5
3 939394040401C-15L13 93939404040
1 C -1 5 L 2
3 93939404040
1 C -1 5 L 2 P B 1
1C-1501C-1511C-1521C-1531C-154391C-1553939394040401C -163939394040401C-171C-1701C-170PB1393939401C-1723939391C-172A391C-172AL11C-172AL21C-172AL2PB11C-172AL2PB21C-1741C-1781C-178L11C-178L1PB11C-178L1PB23939394040401C-181C-1843939394040401C-193939394040401C-19L11C-1901C-201 C -2 0 P B 1
3939394040401C-213939394040401C-21L13939394040401C-21L23939394040401C-21L33 93939404040
1C -2 2
3 93939404040
1 C -2 3
3 939394040401C-23A3 939394040401C-23AL13 939394040401C-23AL23 939394040401C-23AL2-013 93939404040 1C-23AL2-021C -23 P B 1
3939394040401 C -2 43939394040401C-2 4 L 1
3939394040401C-25393939404040
1C -25L 1
3939394040401C-263939394040401C-273939394040401C-283939394040401C-28L13939394040401C-28PB1393939401C-156 wp133939394040401C-158 wp071C-501 wp1239393940401C-157 wp131C-157 wp13Quarter Mile View11:31, April 11 2023WELLBORE TARGET DETAILS (MAP CO-ORDINATES)Name TVD Shape1C-157 Tgt 02 102822 3987.40 Circle (Radius: 100.00)1C-157 Tgt 03 102822 3947.40 Circle (Radius: 100.00)1C-157 Tgt 04 102822 3962.40 Circle (Radius: 100.00)1C-157 Tgt 06 102822 3937.40 Circle (Radius: 100.00)1C-157 Srf Csg Pt 3937.40 Circle (Radius: 500.00)1C-157 Tgt 01 120822 3997.40 Circle (Radius: 100.00)1C-157 Tgt 01 QM 3997.40 Circle (Radius: 1320.00)1C-157 Tgt 03 QM 3947.40 Circle (Radius: 1320.00)1C-157 Tgt 04 QM 3962.40 Circle (Radius: 1320.00)1C-157 Tgt 05 102822 3932.40 Circle (Radius: 100.00)1C-157 Tgt 06 QM 3937.40 Circle (Radius: 1320.00)
-2500025005000750010000South(-)/North(+) (2500 usft/in)-5000 -2500 0 2500 5000 7500 10000 12500 15000West(-)/East(+) (2500 usft/in)393940401C-123 9394040
1 C -1 4
3 93940401C-14A39391C-155393940401C -163 9394040
1C -2 2
3 9394040
1 C -2 3
3 93940401C-23A3 93940401C-23AL13 93940401C-23AL23 93940401C-23AL2-013 9394040 1C-23AL2-021C -2 3 P B 1
393940401C-27393940401C-28393940401C-28L1393940401C-28PB13939401C-156 wp13393940401C-158 wp071C-501 wp123939401C-157 wp131C-157 wp13Quarter Mile View11:46, April 11 2023WELLBORE TARGET DETAILS (MAP CO-ORDINATES)Name TVD Shape1C-157 Tgt 02 102822 3987.40 Circle (Radius: 100.00)1C-157 Tgt 03 102822 3947.40 Circle (Radius: 100.00)1C-157 Tgt 04 102822 3962.40 Circle (Radius: 100.00)1C-157 Tgt 06 102822 3937.40 Circle (Radius: 100.00)1C-157 Srf Csg Pt 3937.40 Circle (Radius: 500.00)1C-157 Tgt 01 120822 3997.40 Circle (Radius: 100.00)1C-157 Tgt 01 QM 3997.40 Circle (Radius: 1320.00)1C-157 Tgt 03 QM 3947.40 Circle (Radius: 1320.00)1C-157 Tgt 04 QM 3962.40 Circle (Radius: 1320.00)1C-157 Tgt 05 102822 3932.40 Circle (Radius: 100.00)1C-157 Tgt 06 QM 3937.40 Circle (Radius: 1320.00)
1C-157wp13 Surface Location
1C-157wp13 Surface Location
#SchlumbergerͲConfidential
1C-157wp13 Surface Casing
1C-157wp13 Surface Casing
#SchlumbergerͲConfidential
1C-157wp13 West Sak D
1C-157wp13 West Sak D
#SchlumbergerͲConfidential
1C-157wp13 Intermediate Csg
1C-157wp13 Intermediate Csg
#SchlumbergerͲConfidential
1C-157wp13 TD
1C-157wp13 TD
#SchlumbergerͲConfidential
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Revised 7/2022
TRANSMITTAL LETTER CHECKLIST
WELL NAME:______________________________________
PTD:_____________________________________________
___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional
FIELD:__________________________POOL:____________________________________
Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter
CHECK OPTIONS TEXT FOR APPROVAL LETTER
MULTI
LATERAL
(If last two digits
in API number are
between 60-69)
The permit is for a new wellbore segment of existing well Permit
Number _____________, API Number 50-______________________.
Production from or injection into this wellbore must be reported under
the original API Number stated above.
Spacing
Exception
The permit is approved subject to full compliance with 20 AAC 25.055.
Approval to produce or inject is contingent upon issuance of a
conservation order approving a spacing exception. The Operator
assumes the liability of any protest to the spacing exception that may
occur.
Dry Ditch Sample
All dry ditch sample sets submitted to the AOGCC must be in nogreater
than 30-foot sample intervals from below the permafrost or from where
samples are first caught and 10-foot sample intervals through target
zones.
Non-
Conventional
Well
Please note the following special condition of this permit: Production or
production testing of coal bed methane is not allowed for this well until
after the Operator has designed and implemented a water-well testing
program to provide baseline data on water quality and quantity. The
Operator must contact the AOGCC to obtain advance approval of such
a water-well testing program.
Well Logging
Requirements
Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types
of well logs to be run. In addition to the well logging program proposed
by the Operator in the attached application, the following well logs are
also required for this well:
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071,
composite curves for all well logs run must be submitted to the AOGCC
within 90 days after completion, suspension, or abandonment of this
well, or within 90 days of acquisition of the data, whichever occurs first.
223-038
KRU 1C-157
WEST SAK OILKUPARUK RIVER
WELL PERMIT CHECKLISTCompanyConocoPhillips Alaska, Inc.Well Name:KUPARUK RIV U WSAK 1C-157Initial Class/TypeDEV / PENDGeoArea890Unit11160On/Off ShoreOnProgramDEVField & PoolWell bore segAnnular DisposalPTD#:2230380KUPARUK RIVER, WEST SAK OIL - 490150NA1Permit fee attachedYesSurf Loc & Prod Int (Portion of) lie in ADL0025649; Top Productive Interval lies in ADL0028242;2Lease number appropriateYesTD lies in ADL0025638.3Unique well name and numberYesKUPARUK RIVER, WEST SAK OIL - 4901504Well 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 waitNA14Well located within area and strata authorized by Injection Order # (put IO# in comments) (For servNA15All wells within 1/4 mile area of review identified (For service well only)NA16Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)Yes81'18Conductor string providedYesSurface casing set at 2027' MD19Surface casing protects all known USDWsYes236% excess20CMT vol adequate to circulate on conductor & surf csgNo21CMT vol adequate to tie-in long string to surf csgNo22CMT will cover all known productive horizonsYes23Casing designs adequate for C, T, B & permafrostYesRig has steel tanks; all waste to approved disposal wells24Adequate tankage or reserve pitNA25If a re-drill, has a 10-403 for abandonment been approvedYesAnti-collision analysis complete; no major risk failures26Adequate wellbore separation proposedYesdiverter waiver not granted27If diverter required, does it meet regulationsYesMax reservoir pressure is 1772 psig(8.7 ppg EMW); will drill w/ 8.7-9.5 ppg EMW28Drilling fluid program schematic & equip list adequateYes29BOPEs, do they meet regulationYesMPSP is 1378 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 probableNA34Mechanical condition of wells within AOR verified (For service well only)NoH2S measures are required; rig has sensors and alarms35Permit can be issued w/o hydrogen sulfide measuresYesExpected Pressure Range is 0.447 to 0.447 psi/ft (8.2 to 8.6 ppg EMW). Operator's planned mud program36Data presented on potential overpressure zonesNAappears sufficient to control anticipated pressures and maintain wellbore stability.37Seismic analysis of shallow gas zonesNALost Circulation: moderate risk; LCM and wellbore pills will be available if needed; see p. 13.38Seabed condition survey (if off-shore)NA39Contact name/phone for weekly progress reports [exploratory only]ApprSFDDate5/23/2023ApprVTLDate6/5/2023ApprSFDDate5/23/2023AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDateAbnormal Pressure: some risk due to nearby injection; supplies available to weight up the mud if needed; see p. 14. SFDGCW 06/05/2023JLC 6/5/2023
