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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-15850-029-23761-00-00223-0563"10"7/31/20254.258/7/2025N/A Rig cemented to surface
Originated: Delivered to:19-Jun-25Alaska Oil & Gas Conservation Commiss19Jun25-NR
! "# $$%$ !&$$'($)*%+
($)*%,- .WELL NAME API #SERVICE ORDER #FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED1C-158 50-029237-61-00-00 223-056 Kuparuk River WL TTiX-RST FINAL FIELD 7-Jun-251C-17 50-029228-72-00-00 198-224 Kuparuk River WL IPROF FINAL FIELD 8-Jun-253T-731 50-103209-05-00-00 224-156 Kuparuk River WL TTiX-HSD FINAL FIELD 10-Jun-253S-721 50-103209-11-00-00 225-025 Kuparuk River WL TTiX-SCMT FINAL FIELD 12-Jun-251A-22 50-029221-27-00-00 191-0003 Kuparuk River WL PPROF FINAL FIELD 17-Jun-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 "
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T40618T40619T40620T40621T406221C-15850-029237-61-00-00223-056Kuparuk RiverWLTTiX-RSTFINAL FIELD7-Jun-25Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.06.25 08:36:59 -08'00'
Originated: Delivered to:17-Jan-25Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPEDATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 1A-26 50-029-22115-00 909678321 Kuparuk River Packer Setting Record Field- Final 14-Nov-24 0 12 1A-26 50-029-22115-00 909619342 Kuparuk River Packer Setting Record Field- Final 21-Oct-24 0 13 1A-27 50-029-22124-00 909781603 Kuparuk River Multi Finger Caliper Field & Processed 25-Dec-24 0 14 1B-19 50-029-22475-00 909619036 Kuparuk River Packer Setting Record Field- Final 17-Oct-24 0 15 1B-20 50-029-23164-00 909619415 Kuparuk River Plug Setting Record Field- Final 8-Oct-24 0 16 1B-20 50-029-23164-00 909678322 Kuparuk River Plug Setting Record Field- Final 13-Nov-24 0 17 1C-04A 50-029-20547-01 909677469 Kuparuk River Packer Setting Record Field- Final 23-Nov-24 0 18 1C-158 50-029-23761-00 909810535 Kuparuk River Injection Profile Field & Processed 11-Jan-25 0 19 1D-05 50-029-20417-00 909607635 Kuparuk River Correlation Record Field- Final 9-Oct-24 0 110 1D-14 50-029-22950-00 909677466 Kuparuk River Packer Setting Record Field- Final 26-Nov-24 0 1PLEASE 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 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:T39991T39991T39992T39993T39994T39994T39995T39996T39997T39998190-166190-180194-064203-115217-078223-056179-095199-0891/23/202581C-15850-029-23761-00909810535Kuparuk RiverInjection ProfileField & Processed11-Jan-2501217 078223-056179 095Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.01.23 15:06:40 -09'00'
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Thursday, April 11, 2024
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Kam StJohn
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
ConocoPhillips Alaska, Inc.
1C-158
KUPARUK RIV U WSAK 1C-158
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 04/04/2024
1C-158
50-029-23761-00-00
223-056-0
W
SPT
3977
2230560 1500
1096 1097 1096 1096
123 310 304 292
INITAL P
Kam StJohn
2/6/2024
Initial MITIA for new injector
30 MinPretestInitial15 Min
Well Name
Type Test
Notes:
Interval P/F
Well
Permit Number:
Type Inj TVD
PTD Test psi
API Well Number Inspector Name:KUPARUK RIV U WSAK 1C-158
Inspection Date:
Tubing
OA
Packer Depth
400 2200 2160 2150IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitKPS240206105656
BBL Pumped:2.4 BBL Returned:2.2
Thursday, April 11, 2024 Page 1 of 1
1a. Well Status:SuspendedAbandonedOtherSPLUGOil 1b. Well Class:
20AAC 25.11020AAC 25.105 ExploratoryDevelopment
WDSPLGINJ WINJ No. of Completions: __________________Stratigraphic TestService
14. Permit to Drill Number / Sundry:6. Date Comp., Susp., or2. Operator Name:
Aband.:
15. API Number:7. Date Spudded:3. Address:
16. Well Name and Number:8. Date TD Reached:4a. Location of Well (Governmental Section):
Surface:
9. Ref Elevations: KB: 17. Field / Pool(s):Top of Productive Interval: 1908' FSL, 2356' FEL S7 T11N R11E
GL:58.30 BF:
10. Plug Back Depth MD/TVD: 18. Property Designation:Total Depth:
11. Total Depth MD/TVD: 19. DNR Approval Number:4b. Location of Well (State Base Plane Coordinates, NAD 27):
Zone- 4y-x-Surface:
20. Thickness of Permafrost MD/TVD:12. SSSV Depth MD/TVD:Zone- 4y-x-TPI:
Zone- 4y-x-Total Depth:
5. Directional or Inclination Survey: Yes (attached) No 21. Re-drill/Lateral Top Window MD/TVD:13. Water Depth, if Offshore:
N/A (ft MSL)Submit electronic information per 20 AAC 25.050
23.
BOTTOM
155'H-4020"
1943'L-8010-3/4"
4018'L-807-5/8"
3957'L-804-1/2"
25.NoYes24. Open to production or injection?
26.
NoWas hydraulic fracturing used during completion? Yes
AMOUNT AND KIND OF MATERIAL USEDDEPTH INTERVAL (MD)
27.
Method of Operation (Flowing, gas lift, etc.):Date First Production:
Gas-MCF:Production forHours Tested:
Test Period
Oil Gravity - API (corr):Gas-MCF:CalculatedCasing Press:
Press. 24-Hour Rate
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
CASING, LINER AND CEMENTING RECORD
6.75"
TUBING RECORD
Lead: 353bbls 14ppg Class G
Tail: 53bbls 15.3ppg Class G
9.875"
11738'MD/3977'TVD11777'4-1/2"
BOTTOM
97.30'
P.O.Box 100360, Anchorage, AK 99510-0360
561982
1455' FNL, 976' FWL S12 T11N R10E
4273' FNL, 1698' FWL S6 T11N R11E
10/14/2023
1889'MD/1794'TVD
SETTING DEPTH TVD
5971295
HOLE SIZE AMOUNT
PULLEDTOP
SETTING DEPTH MD
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
568866
567962
CEMENTING RECORD
5966924
13.5"
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
ConocoPhillips Alaska, Inc.
WAG
Gas
223-056/323-55110/21/2023
Lead: 331bbls 10.7ppg Class G
Tail: 56bbls of 15.8ppg Class G
CASING
50-029-23761-00-00
KRU 1C-158
9/4/2023
15826'MD/3954'TVD
42"
5968781
Kaparuk River Field/ West Sak
ADL047449, ADL025649, ADL028242, ADL02
LONS 01-013
39'
12.6#
39'
11738'
2073'
18298'MD/3993'TVD
TOP
10 yards
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size
and Number; Date perf'd or liner run):
Liner Ran 10/18/23: 11738'MD-15650'MD/ 3977'TVD-3957'TVD
Gas-Oil Ratio:Choke Size:
11906'MD/4003'TVD
39'
39'
Per 20 AAC 25.283 (i)(2) attach electronic information
29.7#
15650'
36'
3977'
94#
45.5#
155'
12635'36'
PACKER SET (MD/TVD)DEPTH SET (MD)SIZE
Sr Res EngSr Pet GeoSr Pet Eng
N/A
Water-Bbl:Oil-Bbl:
Water-Bbl:
PRODUCTION TEST
N/A - Injection Well
Oil-Bbl:Date of Test:
Flow Tubing
Due within 30 days of Completion, Suspension, or AbandonmentForm 10-407 Revised 10/2022
22.Logs Obtained: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,
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.
GR, RES, DIR, SONIC
By Grace Christianson at 8:00 am, Nov 21, 2023
Completed
10/21/2023
JSB
RBDMS JSB 112923
G
DSR-12/8/23
Conventional Core(s): Yes No Sidewall Cores:
30.
MD TVD
Surface Surface
1752 1678
1889 1794
2151 2004
2536 2286
Ugnu C 7964 3285
11313 3907
15826 3954
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:
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
reports and Excel or ASCII tables per 20 AAC 25.071.
NAME
Permafrost - Top
T-5
29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS
Top of Productive
Interval:
West Sak D
Permafrost - Base
Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
T-3
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
K-15
Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and
other tests as required including, but not limited to: core analysis, paleontological report, production or well test results.
Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29.
Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool.
If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the
producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,
showing the data pertinent to such interval).
Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit
detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity,
permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology.
Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain).
Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical
laboratory information required by 20 AAC 25.071.
Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion,
suspension, or abandonment; or 90 days after log acquisition, whichever occurs first.
Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov
20
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Page 1/37
1C-158
Report Printed: 11/9/2023
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)
9/2/2023
12:00
9/2/2023
12:30
0.50 MIRU, MOVE SFTY P PJSM with all hands on moving the rig. 0.0 0.0
9/2/2023
12:30
9/2/2023
13:00
0.50 MIRU, MOVE MOB P Set pipshed on suspension and stage at
1C-158.
0.0 0.0
9/2/2023
13:00
9/2/2023
14:00
1.00 MIRU, MOVE MOB P Place power, pump, and pit modules on
suspension, pull off 1C-501 and stage
for tranport to 1C-158.
0.0 0.0
9/2/2023
14:00
9/2/2023
15:30
1.50 MIRU, MOVE MOB P Skid rig floor and raise stompers.
SIMOPS - install sub tow tongue.
0.0 0.0
9/2/2023
15:30
9/2/2023
18:30
3.00 MIRU, MOVE MOB P Pull sub off 1C-501 and spot at 1C-158. 0.0 0.0
9/2/2023
18:30
9/2/2023
19:15
0.75 MIRU, MOVE MOB P Set stoppers and skid floor. SIMOPS -
remove sub tow tongue.
0.0 0.0
9/2/2023
19:15
9/2/2023
19:45
0.50 MIRU, MOVE MOB P Spot pit module. 0.0 0.0
9/2/2023
19:45
9/2/2023
20:15
0.50 MIRU, MOVE MOB P Spot pump module. 0.0 0.0
9/2/2023
20:15
9/2/2023
20:45
0.50 MIRU, MOVE MOB P Spot power module. 0.0 0.0
9/2/2023
20:45
9/2/2023
21:15
0.50 MIRU, MOVE MOB P Spot rockwasher. 0.0 0.0
9/2/2023
21:15
9/2/2023
21:45
0.50 MIRU, MOVE MOB P Spot pipeshed. 0.0 0.0
9/2/2023
21:45
9/2/2023
22:15
0.50 MIRU, MOVE MOB P Spot rockwasher and cuttings box. 0.0 0.0
9/2/2023
22:15
9/3/2023
00:00
1.75 MIRU, MOVE MOB P Complete rig acceptance checklist. 0.0 0.0
9/3/2023
00:00
9/3/2023
04:00
4.00 MIRU, MOVE MOB P Complete rig accepance checklist.
Unable to function skate, spool line onto
skate, function test drag chain, lower
pipeshed loading arms, or the top drive
due to Harmonic filter / Lineator install
being incomplete.
0.0 0.0
9/3/2023
04:00
9/3/2023
12:00
8.00 MIRU, MOVE NUND P Nipple up surface annular and knife
valve to accumulator. Install lower riser
to surface annular. Install wind break in
cellar due to not being able to close
cellar door (diverter too tall). Install
drain lines into cellar box.
SIMOPS - SurePoint continue with
Lineator install. Rig up MagTec.
Organize cellar wellhead equipment.
Inspect flow line hatches for excess
debris. Ready pits for surface drilling.
Flood service lines and check for leaks
w/ air. Calibrate gas alarms. Work on
gas watch system upgrade.
0.0 0.0
9/3/2023
12:00
9/3/2023
19:30
7.50 MIRU, MOVE RURD P Install 40' diverter line section w/ 22°
bend, weighted stand and catch tank.
Mobilize BHA components and handling
subs to the rig floor. Ready containment
for tank farm install. Obtain RKB's.
Bleed down pipe shed loading arms to
load shed with BHA and 5" HWDP.
Continue to ready pits and pumps for
surface drilling. Test gas alarms.
SIMOPS - Continue with Harmonic
Lineator install. Install grating on
walkways and stairs for lineator project.
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 10/21/2023
Page 2/37
1C-158
Report Printed: 11/9/2023
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)
9/3/2023
19:30
9/3/2023
21:00
1.50 MIRU, MOVE RURD T Attempt to power up Lineators with 2ea
3512 cat engines (failed). Attempt to
power up Lineators with high line
(failed). Electricians bypass Lineators.
Swap rig to high line.
0.0 0.0
9/3/2023
21:00
9/3/2023
23:30
2.50 MIRU, MOVE RURD P Install skate cables. Install upper riser.
Load spud mud into the pits. Build jar
std and rack back.
0.0 0.0
9/3/2023
23:30
9/4/2023
00:00
0.50 MIRU, MOVE BOPE P Perform Diverter test. Knife valve
opening time - 10 sec. Annular closing
time - 27 sec. Perform accumulator
test. Starting pressure = 3000 psi, after
function = 1900 psi, 200 psi attained = 9
sec's, full recovery = 42 sec. 6 nitrogen
bottles at 1958 psi. Test PVT gain/loss
and flow out alarms. Test LEL and H2S
alarms. AOGCC rep Guy Cook waived
witness to the test.
0.0 0.0
9/4/2023
00:00
9/4/2023
01:30
1.50 MIRU, MOVE BHAH P PJSM, Make up BHA clean out
assembly to 40' MD.
0.0 40.0
9/4/2023
01:30
9/4/2023
02:15
0.75 MIRU, MOVE SEQP P Fill conductor and checked for leaks.
PT mud lines to 4,000 psi (good).
40.0 40.0
9/4/2023
02:15
9/4/2023
04:00
1.75 MIRU, MOVE REAM P Ream in the hole to base of the
conductor at 155' MD w/ 425 GPM, 20
RPM, 1K TQ, 15% F/O, 350 PSI, 55K
ROT WT.
40.0 155.0
9/4/2023
04:00
9/4/2023
05:30
1.50 SURFAC, DRILL DDRL P Drill 13½" surface hole F/ 155‘ MD- T/
225‘ MD, WOB = 1k, GPM = 425, PSI
on = 411, PSI off = 401, RPM = 40, TQ
on = 2K, Flow out = 15%, P/U WT = 68K
S/O WT = 67K, RT WT = 68K.
Observe losses at 165' MD to 204' MD.
Pump 20 bbl LCM pill. 90 bbls total
losses (120 bph loss rate)
155.0 225.0
9/4/2023
05:30
9/4/2023
06:15
0.75 SURFAC, DRILL BKRM P BROOH F/ 225' MD T/ 40' MD @ GPM
= 425, PSI - 310, RPM = 40, TQ on =
2K, Flow out = 10%.
SIMOPS - Pump 40 bbl LCM pill.
225.0 40.0
9/4/2023
06:15
9/4/2023
08:00
1.75 SURFAC, DRILL BHAH P P/U remaining 13½" surface BHA w/
GWD as per SLB DD/SDI reps T/ 187'
MD. P/U WT = 52K, S/O WT = 52K
40.0 187.0
9/4/2023
08:00
9/4/2023
08:30
0.50 SURFAC, DRILL SRVY P Wash and ream in the hole F/ 187' MD
T/ 225' MD w/ GPM = 425, PSI = 734,
RPM = 40, 1K TQ, F/O = 15%.
Obtain survey @ 207' MD.
187.0 225.0
9/4/2023
08:30
9/4/2023
14:00
5.50 SURFAC, DRILL DDRL P Drill 13½" surface hole F/ 225‘ MD- T/
745‘ MD, WOB = 1-3k, GPM = 425, PSI
on = 980, PSI off = 862, ECD = 10.98,
RPM = 40, TQ on = 2-4K, Flow out =
15%, P/U WT = 87K S/O WT = 82K, RT
WT = 85K. Drop soap stick at each
connection.
While POOH to install jar stand, unable
to break out of std of HWDP. Removed
top drive handler and use rig tongs.
225.0 745.0
9/4/2023
14:00
9/4/2023
14:30
0.50 SURFAC, DRILL SVRG P Service washpipe and inspect top drive
handler grabber dies and saver sub.
745.0 745.0
Rig: DOYON 142
RIG RELEASE DATE 10/21/2023
Page 3/37
1C-158
Report Printed: 11/9/2023
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)
9/4/2023
14:30
9/5/2023
00:00
9.50 SURFAC, DRILL DDRL P Drill 13½" surface hole F/ 745‘ MD- T/
1,708‘ MD, WOB = 15k, GPM = 460,
PSI on = 1508, PSI off = 1292, ECD =
11.22, RPM = 40, TQ on = 5K, Flow out
= 15%, P/U WT = 101K S/O WT = 99K,
RT WT = 99K. Max gas units = 5108.
Drop soap stick on each connection.
Observe hydrates @ 1,170' MD.
Total bbls lost to formation last 24 hrs =
267
745.0 1,708.0
9/5/2023
00:00
9/5/2023
04:00
4.00 SURFAC, DRILL DDRL P Drill 13½" surface hole F/ 1,708‘ MD- T/
2,079‘ MD, WOB = 9k, GPM = 460, PSI
on = 1493, PSI off = 1282, ECD = 10.8
(9.6 MWT), RPM = 40, TQ on = 5K,
Flow out = 15%, P/U WT = 109K S/O
WT = 102K, RT WT = 104K. Max gas
units = 2324. Drop soap stick on each
connection.
1,708.0 2,079.0
9/5/2023
04:00
9/5/2023
04:15
0.25 SURFAC, TRIPCAS SRVY P Shoot final survey and obtain final tq
and drag values. - P/U WT = 109K S/O
WT = 102K, RT WT = 104K.
2,079.0 2,079.0
9/5/2023
04:15
9/5/2023
04:30
0.25 SURFAC, TRIPCAS OWFF P OWFF - static with minimal hydrate
breakouts.
2,079.0 2,079.0
9/5/2023
04:30
9/5/2023
06:00
1.50 SURFAC, TRIPCAS BKRM P BROOH F/ 2,079' MD T/ 1,975' MD.
Pump 30 bbl nut plug drill zone sweep,
circ 2x b/u at full drilling rate racking
back stand per b/u w/ GPM = 500, PSI =
1520, ECD = 10.72 (9.6 MWT), RPM =
40, TQ 2-6K, Flow out = 15%, P/U WT
@ rate = 101K.
2,079.0 1,975.0
9/5/2023
06:00
9/5/2023
12:45
6.75 SURFAC, TRIPCAS BKRM P Continue to BROOH F/ 1,975' MD T/
187' MD w/ GPM = 500, PSI = 1130,
ECD = 10.25 (9.6 MWT), RPM = 40,
TQ 2K, Flow out = 15%, P/U WT @ rate
= 61K.
SIMOPS - Pump nut plug sweep on last
stand of HWDP to scour BHA.
1,975.0 187.0
9/5/2023
12:45
9/5/2023
13:00
0.25 SURFAC, TRIPCAS OWFF P OWFF - static. SIMOPS - L/D std of 5"
HWDP via mousehole.
187.0 187.0
9/5/2023
13:00
9/5/2023
15:30
2.50 SURFAC, TRIPCAS BHAH P L/D 10¾" surface BHA as per SLB DD
and GWD. Monitor disp via TT.
187.0 0.0
9/5/2023
15:30
9/5/2023
16:30
1.00 SURFAC, TRIPCAS BHAH T Unable to breakout and L/D 2ea stds of
5" HWDP. Decision made to rack back
in the derrick and expedite HT100 rig
tongs to the rig after csg is set to assist
in rig down of the stands.
0.0 0.0
9/5/2023
16:30
9/5/2023
17:00
0.50 SURFAC, TRIPCAS BHAH P Clean and clear rig floor. 0.0 0.0
9/5/2023
17:00
9/5/2023
19:00
2.00 SURFAC, CASING RURD P Rig up to run 10¾" 45.5# L-80 Hyd563
surface csg.
0.0 0.0
9/5/2023
19:00
9/5/2023
19:30
0.50 SURFAC, CASING SFTY P PJSM with CPAI Rig Manager, DDI TP,
DDI rig crew, Doyon Csg rep, and MI
Mud Man on running csg.
0.0 0.0
9/5/2023
19:30
9/5/2023
20:30
1.00 SURFAC, CASING PUTB P Run in the hole w/ 10¾" 45.5# L-80
Hyd563 surface csg. M/U shoe track to
167' MD. BakerLoc to pin end of jt #4.
Tq connections to 16,200 ft/lbs. Double
bump connections. Pump through
floats/shoe to ensure clear fluid path
(good).
0.0 167.0
Rig: DOYON 142
RIG RELEASE DATE 10/21/2023
Page 4/37
1C-158
Report Printed: 11/9/2023
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)
9/5/2023
20:30
9/6/2023
00:00
3.50 SURFAC, CASING PUTB P Cont to run in the hole w/ 10¾" 45.5# L-
80 Hyd563 surface csg F/ 167' MD T/
807' MD. Tq connections to 16,200
ft/lbs. Double bump connections. Place
bow spring centralizers at ea
connection.
167.0 807.0
9/6/2023
00:00
9/6/2023
12:00
12.00 SURFAC, CASING PUTB P Cont to run in the hole w/ 10¾" 45.5# L-
80 Hyd563 surface csg F/ 807' MD T/
1,430' MD. Tq connections to 16,200
ft/lbs. Double bump connections. Place
bow spring centralizers at ea
connection.
Fight hole conditions throughout run.
Attempt to rotate string at 5-10 RPM, 10
-14K TQ w/ no success. Decision made
to wash ea jt dn @ 5 BPM w/ 30-100
PSI. UP WT - 108K, S/O WT - 67K.
807.0 1,430.0
9/6/2023
12:00
9/6/2023
18:15
6.25 SURFAC, CASING PUTB P Cont to run in the hole w/ 10¾" 45.5# L-
80 Hyd563 surface csg F/ 1,430' MD T/
2,030' MD. Tq connections to 16,200
ft/lbs. Double bump connections. Place
bow spring centralizers at ea
connection.
Continue to work through hole
conditions by washing ea jt dn @ 5 BPM
w/ 30-100 PSI. UP WT - 129K, S/O WT
- 91K.
1,430.0 2,030.0
9/6/2023
18:15
9/6/2023
19:00
0.75 SURFAC, CASING HOSO P M/U 10¾" surface hanger. P/U and
make up landing jt. Wash dn F/ 2,030'
MD T/ 2,073' MD w/ GPM = 148, PSI =
155, S/O WT - 95K.
2,030.0 2,073.0
9/6/2023
19:00
9/6/2023
21:30
2.50 SURFAC, CEMENT CIRC P Condition mud. Stage pumps up to 254
GPM, ICP = 141, FCP = 90, F/O% = 18,
UP WT = 130K, S/O WT = 107K. Total
stks pumped = 5671 (571 bbls)
2,073.0 2,073.0
9/6/2023
21:30
9/6/2023
22:00
0.50 SURFAC, CEMENT RURD P Install cement line to Volant CRT.
Establish circ. Stage pumps up to 6
BPM, GPM = 254, PSI = 214, F/O % =
16. Total stks pumped = 2713 (273
bbls)
SIMOPS = PJSM on cement job.
2,073.0 2,073.0
9/6/2023
22:00
9/7/2023
00:00
2.00 SURFAC, CEMENT CMNT P Pump 5 bbls fresh water. Test lines to
3500 psi. Pump 60 bbls of spacer w/
poly flake and red dye @ 6 BPM, PSI =
100. F/O - 15%. Load bottom plug.
(Cmt Wet @ 22:35 hrs) Batch up and
pump 331 BBLS 10.7 PPG cement -
pump rate 5.75 BPM, 100 PSI, 16%
F/O. Pump 56 BBLS of 15.8 tail cement
@ 3.88 BPM, 96 PSI, 16% F/O.
2,073.0 2,073.0
9/7/2023
00:00
9/7/2023
01:00
1.00 SURFAC, CEMENT CMNT P Drop top plug. Chase plug with 20 bbls
of water from HES. Line up rig pumps.
Displace cement at 5 BPM, ICP - 100,
FCP - 375. Reduce rate @ 1600 stks T/
3 BPM, FCP - 411. Bump plug @ 1674
stks (168.5 bbls). CIP @ 00:55 hrs.
Pressure up to 875 psi and hold for 5
min. Bleed off and check floats (good).
Observe 62 bbls of 10.7 cement
returned to surface. 0 losses during
cement job.
2,073.0 2,073.0
Rig: DOYON 142
RIG RELEASE DATE 10/21/2023
Page 5/37
1C-158
Report Printed: 11/9/2023
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)
9/7/2023
01:00
9/7/2023
04:00
3.00 SURFAC, CEMENT RURD P R/D Doyon Csg and L/D Vault landing jt.
Flush surface equipment and valves
with black water pills.
0.0 0.0
9/7/2023
04:00
9/7/2023
09:30
5.50 SURFAC, WHDBOP NUND P N/D 21¼" surface equipment. 0.0 0.0
9/7/2023
09:30
9/7/2023
14:15
4.75 SURFAC, WHDBOP NUND P N/U Vault wellhead equipment. N/U
BOPE. Install dutch riser spool onto
annular. Obtain RKB's.
0.0 0.0
9/7/2023
14:15
9/7/2023
17:15
3.00 SURFAC, WHDBOP OTHR T Observe swamp gas fluid with cement
contaminents exiting hanger flutes.
Monitor the situation, and observe
depleted returns through the flutes.
Mobilize clean up tools and equipment.
Clean cellar area. Mobilize DHD
personnel to sample test fluid at the
conductor hanger flute area. R/U to 4"
conductor outlets and fill w/ ~2 bbls of
9.4 brine. Observe no gas dectiction
readings from rig monitoring system.
0.0 0.0
9/7/2023
17:15
9/7/2023
19:15
2.00 SURFAC, WHDBOP NUND P Continue to N/U BOPE. Install choke
and kill lines. Install riser.
SIMOPS - M/U 2ea 5" FOSV and 1ea 5"
dart valve.
0.0 0.0
9/7/2023
19:15
9/7/2023
19:45
0.50 SURFAC, WHDBOP RURD P Install test plug as per Vault rep. 0.0 0.0
9/7/2023
19:45
9/7/2023
20:45
1.00 SURFAC, WHDBOP BOPE P Flood lines and shell test BOPE to 5000
psi (good).
0.0 0.0
9/7/2023
20:45
9/8/2023
00:00
3.25 SURFAC, WHDBOP BOPE P Initial BOPE test. All tests at 250/5000
psi. Test with 5" and 7 5/8" test joints.
Test annular preventers to 3500 w/ 7
5/8" and 5000 with 5". Upper pipe rams
with 7 5/8". Lower pipe rams with 5"
test joints. Test blind rams. Test choke
valves #1 & #6-14, 1ea 5" dart valve
and 2ea TIW valves, test rig floor,
mezzanine, HCR and manual kill valves,
hydraulic and manual chokes to 2000
psi. and demonstrate bleed off. Test
PVT gain/loss and flow out alarms. Test
witnessed by AOGCC rep Austin
McLeod and Josh Hunt.
0.0 0.0
9/8/2023
00:00
9/8/2023
05:00
5.00 SURFAC, WHDBOP BOPE P With 5" test jt test, HCR and manual
choke valves, upper and lower top drive
IBOP's, lower 3½ x 6" pipe rams, blind
shear rams, choke valves #2-5. Perform
accumulator test. Starting pressure =
3000 psi, after function= 1800 psi, 200
psi attained= 14 sec's, full recovery= 48
sec. 6 nitrogen bottles at 1958 psi. Test
LEL/H2S alarms. F/P on 4 way at the
accumulator on the annular. Replace
and test good. F/P on the rain shield of
the gas sensor in the cellar. Replace
and test good. Test witnessed by
AOGCC rep Austin McLeod and Josh
Hunt.
0.0 0.0
9/8/2023
05:00
9/8/2023
05:45
0.75 SURFAC, WHDBOP RURD P Pull test plug and install 12.25 ID wear
bushing. RILDS (x2).
0.0 0.0
9/8/2023
05:45
9/8/2023
06:45
1.00 SURFAC, WHDBOP RURD P B/D and rig down testing equipment. 0.0 0.0
9/8/2023
06:45
9/8/2023
08:30
1.75 SURFAC, WHDBOP PULD T Break down 2ea stands of HWDP.
Found threads to be galled.
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 10/21/2023
Page 6/37
1C-158
Report Printed: 11/9/2023
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)
9/8/2023
08:30
9/8/2023
10:30
2.00 SURFAC, WHDBOP RURD P Ready all areas for intermediate drill out.
Mobilize tank farm equipment to
complete rig up. Prep rock washer for
operations. Clean and reorganize cellar
area. DHD rig up and collect sample
on surface csg hanger. Remove
diverter pipe.
0.0 0.0
9/8/2023
10:30
9/8/2023
13:00
2.50 SURFAC, DRILLOUT BHAH P P/U 9Ǭ" intermediate BHA as per SLB
DD/MWD to 530' MD. Monitor disp via
Pit #1 - Pill pit #1. UP WT - 86K, S/O
WT - 86K
0.0 530.0
9/8/2023
13:00
9/8/2023
14:45
1.75 SURFAC, DRILLOUT PULD P RIH w/ 9Ǭ" intermediate BHA picking up
drill pipe from the shed T/ 1940' MD (45
jts). Monitor disp via Pit #1 - Pill pit #1.
UP WT - 89K, S/O WT - 89K
530.0 1,940.0
9/8/2023
14:45
9/8/2023
15:45
1.00 SURFAC, DRILLOUT DHEQ P Test MWD tools at GPM = 550, PSI =
925, F/O = 17%. Total stks pumped =
5733 (577 bbls).
1,940.0 1,940.0
9/8/2023
15:45
9/8/2023
17:15
1.50 SURFAC, DRILLOUT PRTS P PT 10¾" surface csg to 3000 psi for 30
charted min (good). 3.8 bbls to
pressure up to 3150 psi. 3 bbls bled
back.
1,940.0 1,940.0
9/8/2023
17:15
9/8/2023
17:30
0.25 SURFAC, DRILLOUT RURD P B/D and rig down testing equipment. 1,940.0 1,940.0
9/8/2023
17:30
9/8/2023
18:00
0.50 SURFAC, DRILLOUT REAM P Wash and Ream F/ 1940' to TOC @
1960' MD. GPM=450. PSI=610,
RPM=40, TQ=3.5
1,940.0 1,960.0
9/8/2023
18:00
9/8/2023
21:30
3.50 SURFAC, DRILLOUT DRLG P Drill out 10¾" cement, plugs, and float
collar as per SLB/DD adjusting
parameters as needed F/ 1960' to 2003'
MD. GPM=450, PSI=610, RPM=40,
TQ=4k WOB = 15K. Work past F/C 3x.
1,960.0 2,003.0
9/8/2023
21:30
9/9/2023
00:00
2.50 SURFAC, DRILLOUT DRLG P Drill out 10¾" cement and tag top of the
shoe as per SLB/DD adjusting
parameters as needed F/ 2003' to 2069'
MD. GPM=450, PSI=616, RPM=40,
TQ=4k, WOB = 2-5K
2,003.0 2,069.0
9/9/2023
00:00
9/9/2023
01:00
1.00 SURFAC, DRILLOUT DRLG P Drill out 10¾" shoe as per SLB/DD F/
2069' to 2079' MD. GPM=450,
PSI=620, RPM=40, TQ=4k, WOB = 5K.
Pass through shoe 3x to ensure clean.
2,069.0 2,079.0
9/9/2023
01:00
9/9/2023
01:30
0.50 SURFAC, DRILLOUT DDRL P Drill 9Ǭ" production hole F/2079' to
2099' MD, WOB=5k, GPM=450,
PSI=605, RPM=60, TQ=5k, F/O 8%.
2,079.0 2,099.0
9/9/2023
01:30
9/9/2023
02:30
1.00 SURFAC, DRILLOUT BKRM P BROOH up into the 10¾" shoe at drilling
rate. Circ 2x B/U. UP WT @ rate - 91K.
Std back std.
Total stlks pumped - 3287 (331bbls).
2,099.0 2,036.0
9/9/2023
02:30
9/9/2023
03:30
1.00 SURFAC, DRILLOUT LOT P LOT. Pump 9.5 ppg spud mud at 5 spm,
21 stks(2.1 bbls) to 510 psi. Shut in and
observe psi drop to 24 psi in 10 min.
Open up wellbore and record 1.2 bbls
bled back to the trip tank. Determine
breakover at 404 psi - 13.5 EMW.
2,036.0 2,036.0
9/9/2023
03:30
9/9/2023
04:00
0.50 INTRM1, DRILL REAM P Wash and ream to btm F/ 2036' MD T/
2099' MD @, GPM=530, PSI=892,
RPM=60, TQ=5k, F/O 8%, S/O WT @
rate=91k.
2,036.0 2,099.0
9/9/2023
04:00
9/9/2023
06:15
2.25 INTRM1, DRILL DDRL P Drill 9Ǭ" production hole F/2099' to
2320' MD, WOB=5k, GPM=530,
PSI=625, RPM=90, TQ=3k, F/O 6%,
ECD=9.76, P/U=98k, S/O=95k, RT=94k.
Displace to 9.0 ppg FWP on the fly.
2,099.0 2,320.0
Rig: DOYON 142
RIG RELEASE DATE 10/21/2023
Page 7/37
1C-158
Report Printed: 11/9/2023
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)
9/9/2023
06:15
9/9/2023
07:15
1.00 INTRM1, DRILL PMPO T It was observed that a survey was
missed. Pump out the hole F/ 2320' MD
T/ 2163' MD w/ GPM=540, PSI=642,
F/O 22%, ECD=9.67, P/U WT @ rate
=95k.
Reshoot survey @ 2,163' MD.
2,320.0 2,163.0
9/9/2023
07:15
9/9/2023
07:45
0.50 INTRM1, DRILL REAM T Wash and ream to btm F/ 2163' MD T/
2320' MD w/ GPM=530, PSI=628, F/O
22%, ECD=9.65, S/O WT @ rate =97k.
2,163.0 2,320.0
9/9/2023
07:45
9/9/2023
12:00
4.25 INTRM1, DRILL DDRL P Drill 9Ǭ" intermediate hole F/2320' to
2791' MD, WOB=5k, GPM=650,
PSI=963, RPM=120, TQ=3k, F/O 6%,
ECD=9.76, P/U=104k, S/O=102k,
RT=102k. Max gas units = 189
2,320.0 2,791.0
9/9/2023
12:00
9/9/2023
18:00
6.00 INTRM1, DRILL DDRL P Drill 9Ǭ" intermediate hole F/2791' to
3636' MD via NOVOS, WOB=9k,
GPM=650, PSI=1089, RPM=120,
TQ=7k, F/O 21%, ECD=10.10,
P/U=117k, S/O=94k, RT=104k. Max
gas units = 325.
Work through challenging directional
plan. Fell behind curve. Increased
ROP to 500 ft/hr to try and keep BHA
engaged to make the turn.
Pump 30 bbl Hi-Vis sweeps @ 3,000'
MD & 3,345' MD - .8 ppb Duo Vis, 7 ppb
Nut plug Med.
Backream entire std while pumping
sweeps.
2,791.0 3,636.0
9/9/2023
18:00
9/10/2023
00:00
6.00 INTRM1, DRILL DDRL P Drill 9Ǭ" intermediate hole F/3636' to
4300' MD via NOVOS, WOB=10k,
GPM=650, PSI=1166, RPM=120,
TQ=6k, F/O 21%, ECD=10.27,
P/U=120k, S/O=98k, RT=104k. Max
gas units = 136.
Pump 30 bbl Hi-Vis sweep @ 3,820' MD
- .8 ppb Duo Vis, 7 ppb Nut plug Med.
Pump 30 bbl bit balling - nut plug sweep
@ 4,300' MD - 12 ppb Nut plug Med, 20
gal Drillzone.
Backream entire std while pumping
sweeps.
3,636.0 4,300.0
9/10/2023
00:00
9/10/2023
06:00
6.00 INTRM1, DRILL DDRL P Drill 9Ǭ" intermediate hole F/4300' to
4962' MD via NOVOS, WOB=11k,
GPM=650, PSI=1194, RPM=120,
TQ=9k, F/O 21%, ECD=10.19,
P/U=117k, S/O=88k, RT=99k. Max gas
units = 95.
4,300.0 4,962.0
9/10/2023
06:00
9/10/2023
12:00
6.00 INTRM1, DRILL DDRL P Drill 9Ǭ" intermediate hole F/4962' to
5624' MD via NOVOS, WOB=8k,
GPM=700, PSI=1548, RPM=120,
TQ=9k, F/O 21%, ECD=10.19,
P/U=113k, S/O=87k, RT=101k. Max
gas units = 65
4,962.0 5,624.0
9/10/2023
12:00
9/10/2023
16:00
4.00 INTRM1, DRILL DDRL P Drill 9Ǭ" intermediate hole F/5624' to
6005' MD via NOVOS, WOB=6k,
GPM=700, PSI=1454, RPM=120,
TQ=9k, F/O 21%, ECD=10.26,
P/U=118k, S/O=82k, RT=99k. Max gas
units = 76
5,624.0 6,005.0
Rig: DOYON 142
RIG RELEASE DATE 10/21/2023
Page 8/37
1C-158
Report Printed: 11/9/2023
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)
9/10/2023
16:00
9/10/2023
16:45
0.75 INTRM1, DRILL CIRC P Observe rising ECD. Pump 2ea 30 bbl
high vis sweeps. Rot and recip pipe F/
6005' MD T/ 5910' MD @ drilling rate,
(I)ECD = 10.4. (F)ECD = 10.35. MWT
= 9.0ppg. Total stks pumped = 6706
(675 bbls).
6,005.0 6,005.0
9/10/2023
16:45
9/10/2023
18:00
1.25 INTRM1, DRILL DDRL P Drill 9Ǭ" intermediate hole F/6005' to
6191' MD via NOVOS, WOB=6k,
GPM=700, PSI=1454, RPM=120,
TQ=9k, F/O 21%, ECD=10.26,
P/U=118k, S/O=82k, RT=99k. Max gas
units = 76
6,005.0 6,191.0
9/10/2023
18:00
9/11/2023
00:00
6.00 INTRM1, DRILL DDRL P Drill 9Ǭ" intermediate hole F/6191' to
6868' MD via NOVOS, WOB=12k,
GPM=700, PSI=1667, RPM=130,
TQ=10k, F/O 21%, ECD=10.46,
P/U=124k, S/O=84k, RT=105k. Max
gas units = 76
6,191.0 6,868.0
9/11/2023
00:00
9/11/2023
06:00
6.00 INTRM1, DRILL DDRL P Drill 9Ǭ" intermediate hole F/6868' to
7560' MD via NOVOS, WOB=8k,
GPM=700, PSI=1753, RPM=110,
TQ=12k, F/O 22%, ECD=10.45,
P/U=132k, S/O=92k, RT=110k. Max
gas units = 96
6,868.0 7,560.0
9/11/2023
06:00
9/11/2023
12:00
6.00 INTRM1, DRILL DDRL P Drill 9Ǭ" intermediate hole F/7560' to
8079' MD via NOVOS, WOB=15k,
GPM=700, PSI=1884, RPM=100,
TQ=12k, F/O 22%, ECD=10.71,
P/U=132k, S/O=92k, RT=110k. Max
gas units = 96
7,560.0 8,079.0
9/11/2023
12:00
9/11/2023
12:30
0.50 INTRM1, DRILL SVRG T Made connection at 8079' MD. NOVOS
kicked on mud pumps and an electrical
signal was triggered that suggested the
IBOP was open. The IBOP however
didn't function open, blowing the popoffs
on both mud pumps. Racked back
stand, manually operated the IBOP and
serviced.
8,079.0 8,079.0
9/11/2023
12:30
9/11/2023
13:00
0.50 INTRM1, DRILL RGRP T Rig crew was able to reset #1 mp PRV.
#2 mp PRV failed to reset and was
replaced.
8,079.0 8,079.0
9/11/2023
13:00
9/11/2023
18:00
5.00 INTRM1, DRILL DDRL P Drill 9Ǭ" intermediate hole F/8079' to
8456' MD via NOVOS, WOB=15k,
GPM=700, PSI=1953, RPM=100,
TQ=12k, F/O 22%, ECD=10.72,
P/U=137k, S/O=90k, RT=111k. Max
gas units = 150
8,079.0 8,456.0
9/11/2023
18:00
9/11/2023
20:45
2.75 INTRM1, DRILL CIRC P Complete wellbore clean up cycle by rot
and recip pipe F/8456 T/8268 GPM=700
-725, (I)PSI=1953, (F)PSI=1990,
RPM=150, TQ=8k, F/O 22%, (I)
ECD=10.72, (F)ECD=10.62, MWT - 9.1,
P/U wt @ rate = 105K. Total stks
pumped = 14,804 (1491 bbls)
SIMOPS - Pump 30 bbls Hi-Vis sweep
with minimal results
Pump 25 bbl Lo-Vis followed by 25 bbl 2
ppg over weightedt sweep with good
results.
8,456.0 8,268.0
Rig: DOYON 142
RIG RELEASE DATE 10/21/2023
Page 9/37
1C-158
Report Printed: 11/9/2023
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)
9/11/2023
20:45
9/12/2023
00:00
3.25 INTRM1, DRILL DDRL P Drill 9Ǭ" intermediate hole F/8456' to
8739' MD via NOVOS, WOB=15k,
GPM=725, PSI=2043, RPM=100,
TQ=9k, F/O 22%, ECD=10.62,
P/U=137k, S/O=90k, RT=111k. Max
gas units = 150
Pump 25 bbl Lo-Vis followed by 25 bbl 2
ppg over weighted sweep @ 8,720' MD
with good results.
8,268.0 8,739.0
9/12/2023
00:00
9/12/2023
06:00
6.00 INTRM1, DRILL DDRL P Drill 9Ǭ" intermediate hole F/ 8739' to
9306' MD via NOVOS, WOB=15k,
GPM=725, PSI=2043, RPM=100,
TQ=9k, F/O 22%, ECD=10.62,
P/U=137k, S/O=90k, RT=111k. Max
gas units = 150. Pump 25 bbl Lo-Vis
followed by 25 bbl 2 ppg over weighted
sweep.
8,739.0 9,306.0
9/12/2023
06:00
9/12/2023
11:30
5.50 INTRM1, DRILL DDRL P Drill 9Ǭ" intermediate hole F/9306' to
9740' MD via NOVOS, WOB=8k,
GPM=725, PSI=2106, RPM=100,
TQ=13k, F/O 22%, ECD=10.72,
P/U=151k, S/O=89k, RT=117k. Max
gas units = 150. Pump 25 bbl Lo-Vis
followed by 25 bbl 2 ppg over weighted
sweep.
9,306.0 9,740.0
9/12/2023
11:30
9/12/2023
12:00
0.50 INTRM1, DRILL CIRC T Pickup off bottom and reduced pump
rate GPM 200, PSI 378 due to shaker
screens blinding off, Change shaker
screens from 170"s to 140's.
9,740.0 9,740.0
9/12/2023
12:00
9/12/2023
12:30
0.50 INTRM1, DRILL DDRL P Drill 9Ǭ" intermediate hole F/ 9740' to
9828' MD via NOVOS, WOB=7.5k,
GPM=725, PSI=2141, RPM=100,
TQ=13k, F/O 22%, ECD=10.70,
P/U=151k, S/O=89k, RT=117k. Max
gas units = 180.
9,740.0 9,828.0
9/12/2023
12:30
9/12/2023
16:30
4.00 INTRM1, DRILL CIRC T Pickup off bottom and reduced pump
rate GPM 200, PSI 378, RPM 60, TQ
9.5, due to shaker screens blinding off
with Ugnu formation. Change shaker
screens from 140's to 100's. Rotate and
reciprocate in different stop points.
Taking on mud from tank farm and
trucks.
9,828.0 9,828.0
9/12/2023
16:30
9/12/2023
18:00
1.50 INTRM1, DRILL DDRL P Drill 9Ǭ" intermediate hole F/ 9828' to
9967' MD via NOVOS, WOB=10k,
GPM=725, PSI=2106, RPM=100,
TQ=14k, F/O 22%, ECD=10.54,
P/U=151k, S/O=89k, RT=117k. Max
gas units = 183. ADT 1.75, Bit hrs 48.64
hrs, total Jars 56.21.
9,828.0 9,967.0
9/12/2023
18:00
9/12/2023
19:15
1.25 INTRM1, DRILL RGRP T Swab failure observer, Pickup off bottom
rack stand back, reduce back to 1 mud
pump, work pipe at reduced pump rate
GPM 380, PSI 370, RPM 60, while
changing out swab on #2 pump.
10,155.0 10,067.0
9/12/2023
19:15
9/12/2023
23:30
4.25 INTRM1, DRILL DDRL P Drill 9Ǭ" intermediate hole F/ 9967' to
10250' MD via NOVOS, WOB=17k,
GPM=725, PSI=2053, RPM=100,
TQ=16k, F/O 22%, ECD=10.60,
P/U=161k, S/O=86k, RT=118k. Max
gas units = 183. ADT 2.80, Bit hrs 51.46
hrs, Total Jars hrs. 59.01.
9,967.0 10,250.0
9/12/2023
23:30
9/13/2023
00:00
0.50 INTRM1, DRILL WASH T Wash and ream back to Bottom with
both mud pumps, GPM 400, PSI 763,
RPM 60, P/U=161k, S/O=86k, RT=118k.
10,155.0 10,250.0
Rig: DOYON 142
RIG RELEASE DATE 10/21/2023
Page 10/37
1C-158
Report Printed: 11/9/2023
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)
9/13/2023
00:00
9/13/2023
06:00
6.00 INTRM1, DRILL DDRL P Drill 9Ǭ" intermediate hole F/10250' to
10724' MD via NOVOS, WOB=18k,
GPM=725, PSI=2115, RPM=100,
TQ=13k, F/O 22%, ECD=10.76,
P/U=161k, S/O=86k, RT=118k. Max
gas units = 84, ADT 4.72, Bit hrs 56.18
hrs, Total Jars hrs. 63.73.
10,250.0 10,724.0
9/13/2023
06:00
9/13/2023
08:30
2.50 INTRM1, DRILL DDRL P Drill 9Ǭ" intermediate hole F/10724' to
10819' MD via NOVOS, WOB=10k,
GPM=725, PSI=2198, RPM=120,
TQ=12k, F/O 21%, ECD=10.84,
P/U=167k, S/O=86k, RT=120k. Max
gas units = 97. ADT 1.85, Bit hrs 58.03
hrs, Total Jars hrs. 65.58.
10,724.0 10,819.0
9/13/2023
08:30
9/13/2023
09:00
0.50 INTRM1, DRILL SVRG P Rig service Lubricate top-drive, iron
roughneck. IBOP
10,819.0 10,819.0
9/13/2023
09:00
9/13/2023
13:00
4.00 INTRM1, DRILL RGRP T Unable to break out from top-drive at
kelly down, Open up torque tube, Break
top-drive connection, rack stand 109#
back in derrick and inspected top-drive,
found IBOP actuator key way was
sheared. Unable to change key it was
wedged unable to remove. Decision was
made to continue drilling and inspecting
actuator at each connection. Changed
out top single on stand 109# due to over
torque connection.
10,819.0 10,819.0
9/13/2023
13:00
9/13/2023
15:00
2.00 INTRM1, DRILL DDRL P Drill 9Ǭ" intermediate hole F/10819' to
11030' MD via NOVOS, WOB=13k,
GPM=725, PSI=2253, RPM=120,
TQ=13k, F/O 21%, ECD=10.88,
P/U=167k, S/O=86k, RT=120k. Max
gas units = 92.
10,819.0 11,030.0
9/13/2023
15:00
9/13/2023
16:30
1.50 INTRM1, DRILL CIRC T Circulate and rotate and reciproiacate
GPM 360, PSI 796, While trouble
shooting #1 mud pumps Loss
communication reset modbus.
11,030.0 11,030.0
9/13/2023
16:30
9/13/2023
18:00
1.50 INTRM1, DRILL DDRL P Drill 9Ǭ" intermediate hole F/11030' to
11135' MD via NOVOS, WOB=10k,
GPM=725, PSI=2292, RPM=120,
TQ=12k, F/O 21%, ECD=10.93,
P/U=169k, S/O=84k, RT=120k. Max
gas units = 97. ADT 2.99, Bit hrs 61.02
hrs, Total Jars hrs. 68.57.
11,030.0 11,135.0
9/13/2023
18:00
9/13/2023
21:00
3.00 INTRM1, DRILL DDRL P Drill 9Ǭ" intermediate hole F/11135' to
11291' MD via NOVOS, WOB=17k,
GPM=725, PSI=2291, RPM=120,
TQ=13k, F/O 21%, ECD=10.91,
P/U=155k, S/O=94k, RT=118k. Max
gas units = 93.
11,135.0 11,291.0
9/13/2023
21:00
9/13/2023
21:30
0.50 INTRM1, DRILL SVRG P Service top-drive, inspected actuator
key on top-drive IBOP
11,291.0 11,291.0
9/13/2023
21:30
9/14/2023
00:00
2.50 INTRM1, DRILL DDRL P Drill 9Ǭ" intermediate hole F/11291' to
11543' MD via NOVOS, WOB=10k,
GPM=725, PSI=2397, RPM=120,
TQ=15k, F/O 21%, ECD=10.98,
P/U=155k, S/O=84k, RT=118k. Max
gas units = 97. ADT 4.16, Bit hrs 65.18
hrs, Total Jars hrs. 72.73.
11,291.0 11,543.0
9/14/2023
00:00
9/14/2023
06:00
6.00 INTRM1, DRILL DDRL P Drill 9Ǭ" intermediate hole F/11,543' to
11,858' MD via NOVOS, WOB=17k,
GPM=725, PSI=2401, RPM=100,
TQ=15k, F/O 23%, ECD=11.11,
P/U=158k, S/O=94k, RT=112k. Max
gas units = 112. ADT 4.93, Bit hrs 70.11
hrs, Total Jars hrs. 77.66.
11,543.0 11,858.0
Rig: DOYON 142
RIG RELEASE DATE 10/21/2023
Page 11/37
1C-158
Report Printed: 11/9/2023
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)
9/14/2023
06:00
9/14/2023
09:15
3.25 INTRM1, DRILL DDRL P Drill 9Ǭ" intermediate hole F/11,858' to
12,080' MD via NOVOS, WOB=18k,
GPM=725, PSI=2401, RPM=120,
TQ=13k, F/O 23%, ECD=11.23,
P/U=158k, S/O=96k, RT=112k. Max
gas units = 112. ADT 2.60, Bit hrs 72.71
hrs, Total Jars hrs. 80.26. @ 11950' MD
pumped fluid caliper 8544 strokes, 9-
23/32 avg. sizes hole, 0' to11950' MD
2424 cubic ft.
11,858.0 12,080.0
9/14/2023
09:15
9/14/2023
12:00
2.75 INTRM1, DRILL CIRC P Circulate, rotate & reciprocate from
12,048‘ MD to 11,950‘ MD, GPM 725,
PSI 2444, F/O 22%, RPM 80, TQ 9k,
ECD 11.27ppg, P/U 158k, S/O 96k, RT
112k. Rack back stand #123. Survey
shoot @ 12,078'. Circulate while waiting
on orders from town.
11,950.0 12,048.0
9/14/2023
12:00
9/14/2023
12:30
0.50 INTRM1, DRILL WASH P Wash and ream from 12,048' to 12,080',
GPM 735, PSI 2381, F/O 22%, ECD
11.27ppg, RPM 120, TQ 9.5k, RT 118k.
12,048.0 12,080.0
9/14/2023
12:30
9/14/2023
16:30
4.00 INTRM1, DRILL DDRL P Drill 9Ǭ" intermediate hole F/12,080' to
12,514' MD via NOVOS, WOB=10k,
GPM=725, PSI=2428, RPM=120,
TQ=12k, F/O 23%, ECD=11.38,
P/U=158k, S/O=96k, RT=112k. Max
gas units = 112.
12,080.0 12,514.0
9/14/2023
16:30
9/14/2023
17:15
0.75 INTRM1, DRILL CIRC P Circulate, rotate & reciprocate from
12,514‘ to 12,420‘ MD, GPM 725, PSI
2516, F/O 22%, RPM 120, TQ 10.5k,
ECD 11.34ppg, P/U 158k, S/O 96k,
RT=112k. Circ while waiting on orders
from town.
12,514.0 12,514.0
9/14/2023
17:15
9/14/2023
18:00
0.75 INTRM1, DRILL DDRL P Drill 9Ǭ" intermediate hole F/12,514' to
12,543' MD via NOVOS, WOB=17k,
GPM=725, PSI=2401, RPM=100,
TQ=15k, F/O 23%, ECD=11.11,
P/U=162k, S/O=93k, RT=113k. Max
gas units = 282. ADT 2.60, Bit hrs 72.71
hrs, Total Jars hrs. 80.26.
12,514.0 12,543.0
9/14/2023
18:00
9/14/2023
19:30
1.50 INTRM1, DRILL DDRL P Drill 9Ǭ" intermediate hole F/12,543' to
12,642' MD via NOVOS, WOB=11k,
GPM=725, PSI=2508, RPM=120,
TQ=13k, F/O 21%, ECD=11.37,
P/U=166k, S/O=92k, RT=123k. Max
gas units = 282. ADT .61, Bit hrs 76.61
hrs, Total Jars hrs.84.16.
12,543.0 12,642.0
9/14/2023
19:30
9/14/2023
20:00
0.50 INTRM1, TRIPCAS SRVY P Obtain final survey, torque, and drag,
SPR’s, and send downlinks to put tools
in neutral.
12,642.0 12,642.0
9/14/2023
20:00
9/14/2023
21:30
1.50 INTRM1, TRIPCAS CIRC P Circulate, rotate & reciprocate from
12,640‘MD to 12,551‘MD, GPM 725,
PSI 2405, F/O 22%, RPM 100, TQ 10k,
ECD 11.35 ppg, P/U 112k, S/O 117k,
while pumping LCM sweep. 12,893 total
strokes pumped.
12,640.0 12,551.0
9/14/2023
21:30
9/14/2023
22:45
1.25 INTRM1, TRIPCAS CIRC P Drop caliper oats per Ellison Rep, pump
fluid caliper oats while circulate, rotate &
reciprocate from 12,640‘MD to
12,551‘MD, GPM 725, PSI 2405, F/O
22%, RPM 100, TQ 10k, ECD 11.35
ppg, P/U 112k, S/O 117k 9039 strokes 9
21/32” avg. hole size. 0’ to 12642’MD
2560 cubic ft.
12,640.0 12,551.0
Rig: DOYON 142
RIG RELEASE DATE 10/21/2023
Page 12/37
1C-158
Report Printed: 11/9/2023
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)
9/14/2023
22:45
9/15/2023
00:00
1.25 INTRM1, TRIPCAS BKRM P BROOH from 12,640‘MD to 12,340‘MD,
GPM 725, PSI 2365, RPM 80, TQ 10k.
F/O 21%, ECD 11.20 ppg, P/U 115k
while laying down 5" drill pipe via 90 ft.
mouse hole.
12,640.0 12,340.0
9/15/2023
00:00
9/15/2023
06:00
6.00 INTRM1, TRIPCAS BKRM P BROOH from 12,340‘MD to 11113'MD,
GPM 725, PSI 2187, RPM 80, TQ 10k.
F/O 21%, ECD 11.26 ppg, P/U 115k
while laying down 5" drill pipe via 90 ft.
mouse hole.
12,340.0 11,113.0
9/15/2023
06:00
9/15/2023
12:00
6.00 INTRM1, TRIPCAS BKRM P BROOH from 11,113‘MD to 9,775‘MD,
GPM 725, PSI 2035, RPM 120, TQ
10k. F/O 21%, ECD 11.40 ppg, P/U
104k while laying down 5" drill pipe via
90 ft. mouse hole.
11,113.0 9,775.0
9/15/2023
12:00
9/15/2023
18:00
6.00 INTRM1, TRIPCAS BKRM P BROOH from 9,775‘MD to 8,540‘MD,
GPM 725, PSI 2004, RPM 120, TQ
7.5k. F/O 21%, ECD 11.35 ppg, P/U 98k
while laying down 5" drill pipe via 90 ft.
mouse hole. Pumped 30 bbl nut plug
sweep no increase in cuttings observed
at shaker.
9,775.0 8,540.0
9/15/2023
18:00
9/16/2023
00:00
6.00 INTRM1, TRIPCAS BKRM P BROOH from 8540‘MD to 7470‘MD,
GPM 725, PSI 1800, RPM 120, TQ
6.7k. F/O 21%, ECD 11.35 ppg, P/U 97k
while laying down 5" drill pipe via 90 ft.
mouse hole.
8,540.0 7,470.0
9/16/2023
00:00
9/16/2023
06:00
6.00 INTRM1, TRIPCAS BKRM P BROOH from 7470‘MD to 6580‘MD,
GPM 725, PSI 1700, RPM 120, TQ
6.7k. F/O 21%, ECD 11.35 ppg, P/U
95k. While laying down 5" drill pipe via
90 ft. mouse hole.
7,470.0 6,580.0
9/16/2023
06:00
9/16/2023
12:00
6.00 INTRM1, TRIPCAS BKRM P BROOH from 6580‘MD to 5060‘MD,
GPM 725, PSI 1560, RPM 120, TQ
4.7k. F/O 21%, ECD 11.87 ppg, P/U
94k. While laying down 5" drill pipe via
90 ft. mouse hole. Observed increase in
TQ to 9K @ 6075' MD work through
tight spot.
6,580.0 5,060.0
9/16/2023
12:00
9/16/2023
18:00
6.00 INTRM1, TRIPCAS BKRM P BROOH from 5060‘MD to 3803‘MD,
GPM 725, PSI 1460, RPM 120, TQ
4.3k. F/O 21%, ECD 10.87 ppg, P/U
94k. While laying down 5" drill pipe via
90 ft. mouse hole. Observed increase in
torque at 4585' MD and 4258' MD.
Wash and ream tight spots, Pump 30bbl
weighted nut plug sweep @ 4215' MD.
Observe slight increase in cuttings at
shakers.
5,060.0 3,803.0
9/16/2023
18:00
9/17/2023
00:00
6.00 INTRM1, TRIPCAS BKRM P BROOH from 3803‘MD to 2760‘MD,
GPM 725, PSI 1190, RPM 120, TQ
3.4k. F/O 21%, ECD 11.02 ppg, P/U
94k. While laying down 5" drill pipe via
90 ft. mouse hole.
3,803.0 2,760.0
9/17/2023
00:00
9/17/2023
04:15
4.25 INTRM1, TRIPCAS BKRM P BROOH from 2760‘MD to 2090‘MD,
GPM 725, PSI 1070, RPM 120, TQ
3.4k. F/O 21%, ECD 10.74 ppg, P/U
91k, while laying down 5" drill pipe via
90 ft. mouse hole.
2,760.0 2,090.0
9/17/2023
04:15
9/17/2023
04:45
0.50 INTRM1, TRIPCAS CIRC P Shut down rotary and pump out across
the shoe from 2,090' MD to 2,038' MD,
725 GPM, 1,070 PSI, 20% F/O, P/U
95K.
2,090.0 2,090.0
Rig: DOYON 142
RIG RELEASE DATE 10/21/2023
Page 13/37
1C-158
Report Printed: 11/9/2023
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)
9/17/2023
04:45
9/17/2023
09:00
4.25 INTRM1, TRIPCAS CIRC P At 2,038' MD pump 30 bbls of 11.5 ppg
weighted nut plug sweep and circulate
until shakers clean while rotate and
reciprocate pipe from 2,038'MD to
1,944' MD, 60 RPM, 1K TQ, 725 GPM,
1,045 PSI, 20 % FO, at 9,966 strokes.
Decision made to pump 2x bit balling
sweeps upon assessment of returns, 30
bbl 1st, 20 bbl 2nd total stokes during
circulation - 41,186.
2,090.0 2,090.0
9/17/2023
09:00
9/17/2023
09:15
0.25 INTRM1, TRIPCAS OWFF P OWFF - well static. 2,090.0 2,090.0
9/17/2023
09:15
9/17/2023
11:15
2.00 INTRM1, TRIPCAS TRIP P Pull 1 stand on elevators, blow down top
drive, TOOH L/D drill pipe 1x1 from
2090‘MD to 596‘MD, with 5” drill pipe,
P/U 94k, Monitor displacement via trip
tank.
2,090.0 596.0
9/17/2023
11:15
9/17/2023
11:30
0.25 INTRM1, TRIPCAS OWFF P Observe well for flow (static) prior to
pulling HWDP.
595.0 596.0
9/17/2023
11:30
9/17/2023
12:00
0.50 INTRM1, TRIPCAS CIRC P @ Last stand of HWDP, pump 27 bbl bit
ball sweep, @ 720 GPM, 790 PSI.
Minimal increase of cuttings observed
@ shakers.
596.0 596.0
9/17/2023
12:00
9/17/2023
15:00
3.00 INTRM1, TRIPCAS TRIP P Continue L/D HWDP. PJSM L/D BHA.
L/D BHA. as per SLB Rep.
596.0 0.0
9/17/2023
15:00
9/17/2023
15:30
0.50 INTRM1, TRIPCAS WWWH P M/U XT-39 stack washer and crossover,
flush stack 3x working upwards through
stack.
0.0 0.0
9/17/2023
15:30
9/17/2023
16:00
0.50 INTRM1, TRIPCAS WWSP P P/U 2 singles from shed, drain stack,
M/U wear bushing puller as per Vault
Rep. Pull wear bushing (ID - 12.312'').
0.0 0.0
9/17/2023
16:00
9/17/2023
18:00
2.00 INTRM1, CASING RURD P Rig up Volant torqued to 30k, verified
per Doyon Casing Rep. Continue prep
for 7 5/8'' casing run, mobilize handling
equip, casing hanger. Prep for dummy
run.
0.0 0.0
9/17/2023
18:00
9/17/2023
19:00
1.00 INTRM1, CASING WWSP P Make up landing joint and 7 5/8" hanger
and conduct dummy run as per Vault
Rep.
0.0 0.0
9/17/2023
19:00
9/17/2023
19:30
0.50 INTRM1, CASING RURD P Install 350 ton elevators and secure,
ready rig floor for 7 5/8"casing run.
0.0 0.0
9/17/2023
19:30
9/17/2023
20:00
0.50 INTRM1, CASING PUTB P Pick up shoe track and Baker-lok all
connections to the 4th joint (166' MD),
check floats (good) verified by CPAI
Rep.
0.0 166.0
9/17/2023
20:00
9/18/2023
00:00
4.00 INTRM1, CASING PUTB P Continue to run in the hole with 7 5/8"
29.7 lbs/ft Hydril 563 as per tally from
166' MD, to 1,226 ' MD (30 joints),
installing centralizers every joint, filling
every joint and topping off every ten,
torqued to 10.3k, S/O 76k.
166.0 1,226.0
9/18/2023
00:00
9/18/2023
01:30
1.50 INTRM1, CASING PUTB P Continue to run in the hole with 7 5/8"
29.7 lbs/ft Hydril 563 as per tally from
1,226' to 2043' MD (50 joints), installing
centralizers every joint, filling every joint
and topping off every ten, torqued to
10.3k, S/O 92k.
1,226.0 2,043.0
9/18/2023
01:30
9/18/2023
02:00
0.50 INTRM1, CASING CIRC P Circulate bottoms up at 2043', while
staging pump up in 1/2 bbl increments,
1 BPM 69 PSI, 6 BPM 114 PSI, 1009
strokes pump total.
2,043.0 2,043.0
Rig: DOYON 142
RIG RELEASE DATE 10/21/2023
Page 14/37
1C-158
Report Printed: 11/9/2023
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)
9/18/2023
02:00
9/18/2023
06:00
4.00 INTRM1, CASING PUTB P Continue RIH with 7-5/8" 29.7# Hydril
563 as per csg tally from 2,043’ MD to
3,672' MD (90 joints), install centralizers
every jt as per running order, fill every
joint & top of every 10 joints, torque to
10,300 ft/lbs with Volant, S/O 109k
2,043.0 3,672.0
9/18/2023
06:00
9/18/2023
09:00
3.00 INTRM1, CASING PUTB P Continue RIH with 7-5/8" 29.7# Hydril
563 as per csg tally from 3,672' MD, to
4,440 ' MD (109 joints), install
centralizers every jt as per running
order, fill every joint, torqued to 10,300
ft/lbs, S/O 107k break circulation/ pump
200 strokes @ 2 BPM every 10 joints
RIH
3,672.0 4,440.0
9/18/2023
09:00
9/18/2023
09:45
0.75 INTRM1, CASING CIRC P Circulate and condition mud while RIH
on joint #110 4440' MD, staging up
pumps in ½ BBL increments, ICP @ 2
BPM 163 PSI, FCP @ 6 BPM 229 PSI,
S/O 105k @ rate Mud weight 9.6 ppg
with 56 vis @ bottoms up
4,440.0 4,440.0
9/18/2023
09:45
9/18/2023
12:00
2.25 INTRM1, CASING PUTB P Continue RIH with 7 5/8" 29.7# Hydril
563 as per detail from 4440’ MD to
5170' MD (127 joints), installing
centralizers every jt as per running
order, torqued to10,300 ft/lbs, w/ volant
S/O 101k break circulation/ pump 200
strokes @ 2 BPM every 10 joints RIH
4,440.0 5,170.0
9/18/2023
12:00
9/18/2023
18:00
6.00 INTRM1, CASING PUTB P Continue RIH with 7 5/8" 29.7# Hydril
563 as per detail from 5170’ MD to
6941' MD (170 joints), installing
centralizers every joint, torqued to
10,300 ft/lbs, S/O 90k break circulation/
pump 200 strokes @ 2 BPM every 10
joints RIH
5,170.0 6,941.0
9/18/2023
18:00
9/18/2023
22:30
4.50 INTRM1, CASING PUTB P Continue RIH with 7 5/8" 29.7# Hydril
563 as per detail from 6,941’ MD to
8,169' MD (200 joints), installing
centralizers every joint, torqued to
10,300 ft/lbs, S/O 86k break circulation/
pump 200 strokes @ 2 BPM every 10
joints RIH
6,941.0 8,169.0
9/18/2023
22:30
9/18/2023
23:30
1.00 INTRM1, CASING CIRC P Circulate bottoms up strokes while
reciprocating pipe from 8,169' MD to
8,128' MD, staging pumps up 1/2 bbl at
a time, ICP at 2 bpm, 298 psi 6% F/O,
FCP at 6 BPM, 330 PSI, with 10 % F/O,
total strokes pumped 3,212, P/U 136k,
S/O 86k Mud weight 9.6PPG with 55 vis
at bottoms up.
8,169.0 8,128.0
9/18/2023
23:30
9/19/2023
00:00
0.50 INTRM1, CASING PUTB P Continue RIH with 7 5/8" 29.7# Hydril
563 as per detail from 8,169'' MD, to
8,252' MD (202 joints), installing
centralizers every joint, torqued to
10,300 ft/lbs, S/O 86k break circulation/
pump 200 strokes @ 2 BPM every 10
joints RIH
8,169.0 8,252.0
9/19/2023
00:00
9/19/2023
06:00
6.00 INTRM1, CASING PUTB P Continue RIH with 7 5/8" 29.7# Hydril
563 as per detail from 8252' MD, to
10156' MD (247joints), installing
centralizers every joint, torqued to
10,300 ft/lbs, S/O 90k break circulation/
pump 200 strokes @ 2 BPM every 10
joints RIH
8,252.0 10,156.0
Rig: DOYON 142
RIG RELEASE DATE 10/21/2023
Page 15/37
1C-158
Report Printed: 11/9/2023
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)
9/19/2023
06:00
9/19/2023
12:00
6.00 INTRM1, CASING PUTB P Continue RIH with 7 5/8" 29.7# Hydril
563 as per detail from 10156' MD, to
11850' MD (291 joints), installing
centralizers every joint, torqued to
10,300 ft/lbs, S/O 95k break circulation/
pump 200 strokes @ 2 BPM every 10
joints RIH
10,156.0 11,850.0
9/19/2023
12:00
9/19/2023
14:00
2.00 INTRM1, CASING PUTB P Continue RIH with 7 5/8" 29.7# Hydril
563 as per detail from 11850' MD, to
12538' MD (306 joints), installing
centralizers every joint, torqued to
10,300 ft/lbs, S/O 78k break circulation/
pump 200 strokes @ 2 BPM every 10
joints RIH
11,850.0 12,538.0
9/19/2023
14:00
9/19/2023
15:00
1.00 INTRM1, CASING PUTB P Continue RIH with 7 5/8'' 27.9# Hydril
563 as per detail, torque to 10,300 ft/lbs
washing down @2bpm ( joints frrom
12538' MD to 12600' MD (307/308) S/O
77k
12,538.0 12,600.0
9/19/2023
15:00
9/19/2023
15:30
0.50 INTRM1, CASING HOSO P M/U hanger/ landing joint as per Vault
Rep. wash down hanger @2 bpm. drain
stack/ verify landing with 34k on load
shoulder @ 35.93' (RKB to load
shoulder) to 12635'MD
12,600.0 12,635.0
9/19/2023
15:30
9/19/2023
18:30
3.00 INTRM1, CEMENT CIRC P Circulate and condition mud on pits 2-5.
Staging up in 1/2 bpm increments
starting @ 2 BPM PSI= 450, @ 2.5 BPM
PSI= 470, @ 3 BPM PSI = 488, @ 3.5
BPM PSI= 520, @ 4BPM PSI=530
Remain @ 4BPM until 5,812 Stokes
12,635.0 12,635.0
9/19/2023
18:30
9/19/2023
19:00
0.50 INTRM1, CEMENT CIRC P Shut down pumps, blow down top drive,
rig up cement line top Volant, brake out
Volant, dump fluid caliper oats as per
Ellison Rep.at 8460 strokes , 0' to
12627' MD 2705 cubic ft, Avg hole size
9-55/64"
12,635.0 12,635.0
9/19/2023
19:00
9/19/2023
23:00
4.00 INTRM1, CEMENT CIRC P Continue circulate out fluid caliper oats
out and rig up HES cementers, staging
pumps up to 8 BPM ICP= 650 PSI,
FCP= 630, FO=15%, total strokes
pumped = 24,340
12,635.0 12,635.0
9/19/2023
23:00
9/20/2023
00:00
1.00 INTRM1, CEMENT CMNT T PJSM with all involved, HES cementers
pump 5 bbls of water to flood lines and
attempt to pressure test lines, HES
trouble shoot leak at their unit by pulling
apart the frac valve. Found cement
under valve.
12,635.0 12,635.0
Rig: DOYON 142
RIG RELEASE DATE 10/21/2023
Page 16/37
1C-158
Report Printed: 11/9/2023
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)
9/20/2023
00:00
9/20/2023
05:45
5.75 INTRM1, CEMENT CMNT P Pump 5bbls fresh water. Test lines to
4000 psi. Load 1st bottom plug. Pump
58.9 bbls of spacer 4 bpm, 200 psi. 14%
Flow out. Load 2nd bottom plug. (Cmt
Wet @ 0121 hrs) Batch up and pump
353 bbls 14.09 ppg Class G lead
cement - pump rate 4.5 bpm, 420 psi,
17% Flow out.Switch over and pump 52
bbls 15.3 pgg class G cement. Shut
down Load top plug. Halliburton pump
20 bbls water. Swap to rig and displace
with 9.5 ppg. LSND. @ 6 bpm 240 psi.
30% F/O. Decreased rate to Strokes to
slow pump to 5 BPM = 3538 STK
Strokes to slow pump to 4 BPM = 4034
STK Strokes to slow pump to 3 BPM =
4531 STK Strokes to slow pump to 2
BPM = 5027 STK Strokes when
bumped plug = 5548 STK
Final circ. psi. 1030 Pressure up to
1690 psi & hold for 5 minutes. Bleed off
pressure, Check floats good. CIP 0545
hrs 01/20/23. 0 bbl. loss during cement
job.
12,635.0 12,635.0
9/20/2023
05:45
9/20/2023
07:15
1.50 INTRM1, CEMENT PRTS P Rig up pressure test 7 5/8" casing @ 1
BPM to 3500psi, 8.5 bbls pumped to
pressure up. Hold pressure for 30
minutes on chart. Bleed pressure of bled
back 8.5 bbls
12,635.0 12,635.0
9/20/2023
07:15
9/20/2023
09:00
1.75 INTRM1, CEMENT RURD P Blow down lines, Pull landing joint, R/D
casing handling equipment.
12,635.0 12,635.0
9/20/2023
09:00
9/20/2023
10:30
1.50 INTRM1, WHDBOP WWSP P M/U packoff running assy. RIH with
packoff and install. Test packoff to 5000
psi for 10 minutes,( witness by CPAI
Rep) R/D packoff running assy.
12,635.0 12,635.0
9/20/2023
10:30
9/20/2023
15:00
4.50 INTRM1, WHDBOP SVRG P Change out cam rollers on upper, IBOP
on Top-drive, change out upper pipe
rams from 7 5/8" solid rams to 3 1/2" x
6" VBR's Change out NC-50 saver sub
and install XT-39 saver sub on top drive.
12,635.0 12,635.0
9/20/2023
15:00
9/20/2023
21:30
6.50 INTRM1, WHDBOP RURD P Lay down 5" drill pipe that was over
torque from derrick. Highest torque
observed 72K, Observer pin and box
threads that showed galling. Not able to
break 2 stands down with rig tongs and
ST-100
12,635.0 12,635.0
9/20/2023
21:30
9/20/2023
22:00
0.50 INTRM1, WHDBOP RURD P Clean and Clean rig floor of 5" handling
tools and equipment.
12,635.0 12,635.0
9/20/2023
22:00
9/20/2023
23:30
1.50 INTRM1, WHDBOP RURD P Set test plug per Vault Rep and rig up to
test BOPE, fluid pack lines and work air
out of system.
12,635.0 12,635.0
9/20/2023
23:30
9/21/2023
00:00
0.50 INTRM1, WHDBOP BOPE P Test BOPE's, all tests to 250 low 3,500
high for 5 charted minutes with
exception of manual operated & super
choke tested to 250 low & 2,000 psi for
5 charted minutes, with 4" test jt test
annular, choke valves 1,12,13,14, 4" kill
valve, 4" xt-39 dart valve test PVT
gain/loss and flow out alarms, test LEL
and H2S alarms: AOGCC Rep Brian
Bixby waived witness @ 11:17am hrs on
09/17/2023
12,635.0 12,635.0
Rig: DOYON 142
RIG RELEASE DATE 10/21/2023
Page 17/37
1C-158
Report Printed: 11/9/2023
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)
9/21/2023
00:00
9/21/2023
05:00
5.00 INTRM1, WHDBOP BOPE P Test Bope’s, all tests to 250 low 3,500
high for 5 charted minutes with
exception of manual operated & super
choke tested to 250 low & 2,000 psi for
5 charted minutes, with 4" test joints, 3
1/2" x 6" upper, 3 1/2" x 6" lower pipe
ram, with 4 1/2" test jt test 3 1/2" x 6"
upper & 3 1/2" x 6" lower pipe ram, test
choke valves 1-15, manual operated &
Super choke, choke & kill manuals &
Hcr's, 4" valves on Kill line, 4" FOSV, 4"
dart valve, upper & lower IBOP; blind/
shear rams; perform Koomey
drawdown, ACC = 3000 psi.Manifold=
1500 psi. ACC = 1800 psi after all
functions on bottles, 8 sec for 200 psi.
build with 2 elec. pumps, 55 seconds to
build full system pressure with 2 electric
& 2 air pumps, closing times annular =
14 seconds upper = 8 seconds, blind /
shears = 10 seconds low pipe ram = 10
seconds. Choke HCR = 2 seconds, Kill
HCR = 2 seconds, Nitrogen 6 bottle Avg.
= 1883 psi; Test PVT gain/loss and flow
out alarms, test LEL and H2S alarms;
AOGCC Rep Brian Bixby waived
witness @ 11:17am hrs on 09/17/2023
12,635.0 12,635.0
9/21/2023
05:00
9/21/2023
05:45
0.75 INTRM1, WHDBOP RURD P Pull test plug and rig down bope testing
equipment, blowdown all associated test
lines and equipment, line up choke and
Bope’s for drilling operations
12,635.0 12,635.0
9/21/2023
05:45
9/21/2023
06:00
0.25 INTRM1, WHDBOP RURD P Install wear ring as per Vault Rep ID=
9.062" OD. = 13.46" length= 14.75”
12,635.0 12,635.0
9/21/2023
06:00
9/21/2023
07:00
1.00 INTRM1, DRILLOUT CLEN P Clean and clear rig floor of bop testing
tools and equipment.
12,635.0 12,635.0
9/21/2023
07:00
9/21/2023
07:30
0.50 INTRM1, DRILLOUT RURD P Breakdown 2 remaining over torqued 5"
drill pipe stands from derrick and lay
down.
12,635.0 12,635.0
9/21/2023
07:30
9/21/2023
08:30
1.00 INTRM1, DRILLOUT BHAH P Bring BHA tools and equipment to rig
floor.
12,635.0 12,635.0
9/21/2023
08:30
9/21/2023
10:00
1.50 INTRM1, DRILLOUT BHAH P Make up 6 3/4" Production BHA to 168'
MD as per SLB Reps
0.0 168.0
9/21/2023
10:00
9/21/2023
12:00
2.00 INTRM1, DRILLOUT TRIP P Run in hole picking up 4" drill pipe from
pipe shed from 168'MD to1587'MD,
PU=57k, SO= 62k
168.0 1,587.0
9/21/2023
12:00
9/21/2023
13:00
1.00 INTRM1, DRILLOUT TRIP P Run in the hole picking up 4" drill pipe
from pipe shed from 1,587'MD to 2,154
MD, P/U =59k, S/O= 64k
1,587.0 2,154.0
9/21/2023
13:00
9/21/2023
13:45
0.75 INTRM1, DRILLOUT SRVY P At 2,154'MD, fill pipe, shallow hole test
MWD tools at 275 GPM, 1,489 PSI,
10% F/O, Send down link to tools for
logging operations.
2,154.0 2,154.0
9/21/2023
13:45
9/21/2023
18:00
4.25 INTRM1, DRILLOUT DLOG P Run in the hole from the derrick from
2,154'MD, to 3,571'MD, while sonic
logging for cement, 245 GPM, 1,300
PSI, 10% F/O, 450/900 ft/hr, P/U= 79k,
S/O= 77k
2,154.0 3,571.0
9/21/2023
18:00
9/21/2023
20:15
2.25 INTRM1, DRILLOUT DLOG P Run in the hole from the derrick from
3,571'MD, to 4320'MD, while Sonic
logging for top of cement, 245 GPM,
1,300 PSI, 10% F/O, 450/900 ft/hr, P/U=
79k S/O 77k
3,571.0 4,320.0
9/21/2023
20:15
9/22/2023
00:00
3.75 INTRM1, DRILLOUT DLOG P RIH on elevators from 4,320'MD to
7892'MD @ 5400'/hr while logging
record mode for cement P/U= 97k, S/O=
79k.
4,320.0 7,892.0
Rig: DOYON 142
RIG RELEASE DATE 10/21/2023
Page 18/37
1C-158
Report Printed: 11/9/2023
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)
9/22/2023
00:00
9/22/2023
05:15
5.25 INTRM1, DRILLOUT TRIP P Single in the hole from the pipe shed
with 5" Drill pipe while logging cement in
record mode from 7892’MD to
12473'MD, P/U = 116k, S/O= 72k
7,892.0 12,473.0
9/22/2023
05:15
9/22/2023
05:45
0.50 INTRM1, DRILLOUT WASH P From 12473' MD to 12512' MD wash
down with 245 GPM, 2058 PSI, 12%
F/O, P/U 118k S/O 72K, tag cement @
12512'MD, P/U to 12,500'MD.
12,473.0 12,512.0
9/22/2023
05:45
9/22/2023
06:00
0.25 INTRM1, DRILLOUT RURD P Rig up injection line to OA from mud
pump #1 for injection rate.
12,512.0 12,512.0
9/22/2023
06:00
9/22/2023
07:30
1.50 INTRM1, DRILLOUT FRZP P Perform injection test on the OA at 1/2
bpm with 9.4 ppg mud, pressuring up to
452 psi, shut in and monitor, send
injection test to town for review, blow
down and rig down injection line (all
charted)
12,512.0 12,512.0
9/22/2023
07:30
9/22/2023
08:00
0.50 INTRM1, DRILLOUT SRVY P Bring up pumps to 275 GPM, 2,200 PSI,
send down link to MWD tools, slow rate
to 245 GPM, 2,000 PSI, 11% F/O, ream
in hole from 12,500'MD, 60 RPM, 4-6k
TQ, tag up on float collar at 12,549'MD.
12,500.0 12,549.0
9/22/2023
08:00
9/22/2023
12:00
4.00 INTRM1, DRILLOUT DRLG P Drill out float collar and shoe track, from
12,549'MD to 12,366' MD, 70 RPM, 4-6k
TQ, 245 GPM, 2,020 PSI, 11% F/O, 3-
6k WOB, ROT 91k, working string every
10-15 minutes.
12,549.0 12,366.0
9/22/2023
12:00
9/22/2023
14:30
2.50 INTRM1, DRILLOUT DRLG P Continue drill out shoe track and
cement, from 12,366'MD to 12,642' MD,
75 RPM, 8-11k TQ, 245 GPM, 2,020
PSI, 11% F/O, 5-7k WOB, ROT 91k,
working string every 10-15 minutes,
work through shoe several times to
ensure free travel path.
12,366.0 12,642.0
9/22/2023
14:30
9/22/2023
15:00
0.50 INTRM1, DRILLOUT DRLG P Drill 20' new 6.75” production hole from
12,642‘MD to 12,662‘MD, 4039' TVD,
WOB 3k, 275 GPM, 2,366 PSI, 70 RPM,
8.5k TQ.,11% F/O, P/U 98k, S/O 90k,
RT 92k, ADT= 0.25, Total bit hrs= 0.25
12,642.0 12,662.0
9/22/2023
15:00
9/22/2023
16:30
1.50 INTRM1, DRILLOUT CIRC P Rotate and reciprocate while circulating
bottoms up, from 12,662’MD to
12,568'MD, 275 GPM, 2,355 PSI, 60
RPM, 7-9k TQ, 12% F/O, Total strokes
3,931, lay down single to stay in shoe
12,630'MD.
12,662.0 12,568.0
9/22/2023
16:30
9/22/2023
17:30
1.00 INTRM1, DRILLOUT LOT P Rig up, flood kill and cement lines,
perform LOT, pump at 1/2 bpm for 3.4
bbls up to 860 psi, with 1.35 bbls bled
back, LOT EWM 13.5 ppg @ 860psi,
12,568.0 12,568.0
9/22/2023
17:30
9/23/2023
00:00
6.50 PROD1, DRILL DDRL P Drill 6.75” production hole from
12,662‘MD to 12,770‘MD 4038’ TVD, 5k
WOB, 275 GPM, 2185, 80 RPM, 8k
TQ,13% F/O, P/U 118k S/O 73k, RT
95k, ADT 5.73, Total bit hrs= 5.98,
Displace on the fly from 9.4 ppg drill out
mud to 9.0 ppg Flo-Pro from 12,662'MD
to 12,711'MD while drilling ahead
displacement finished @ 1900 hrs. @
12726' MD encountered hard formation
which deflected bit 1 degrees in 40'
12,662.0 12,770.0
9/23/2023
00:00
9/23/2023
06:00
6.00 PROD1, DRILL DDRL P Drill 6.75” production hole from
12770‘MD to12884‘MD 4035’ TVD, 10k
WOB, 275 GPM, 2174 PSI, 80 RPM,
8kTQ,13% F/O,10.47 ECD, P/U 118k
S/O 70k, RT 95k
12,770.0 12,884.0
Rig: DOYON 142
RIG RELEASE DATE 10/21/2023
Page 19/37
1C-158
Report Printed: 11/9/2023
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)
9/23/2023
06:00
9/23/2023
12:00
6.00 PROD1, DRILL DDRL P Drill 6.75” production hole from
12,884‘MD to 12,995‘MD 4030’ TVD,
14k WOB, 275 GPM, 2327 PSI, 80
RPM, 8k TQ,13% F/O,10.59 ECD, P/U
118k S/O 73k, RT 95k, ADT 10.57, Total
bit hrs= 16.55,
12,884.0 12,995.0
9/23/2023
12:00
9/23/2023
18:00
6.00 PROD1, DRILL DDRL P Drill 6.75” production hole from
12,995‘MD to 13060‘MD 4025’ TVD, 10k
WOB, 275 GPM, 2174, 100 RPM,
8kTQ,13% F/O,10.49 ECD, P/U 118k
S/O 70k, RT 90k,
12,995.0 13,060.0
9/23/2023
18:00
9/24/2023
00:00
6.00 PROD1, DRILL DDRL P Drill 6.75” production hole from
13060'MD to 13225‘MD 4021’ TVD, 15k
WOB, 275 GPM, 2465 PSI, 120 RPM,
8k TQ,13% F/O, 10.79 ECD, P/U 118k
S/O 73k, RT 95k, ADT 10.97 hrs, Total
bit hrs= 27.52,
13,060.0 13,225.0
9/24/2023
00:00
9/24/2023
06:00
6.00 PROD1, DRILL DDRL P Drill 6.75” production hole geo-steering
from 13225'MD to 13450‘MD 4009’
TVD, 6k WOB, 275 GPM, 2505 PSI, 120
RPM, 9k TQ,13% F/O, 10.79 ECD, P/U
118k S/O 65k, RT 93k, ADT 3.79 hrs,
Total bit hrs 31.31,
13,225.0 13,450.0
9/24/2023
06:00
9/24/2023
12:00
6.00 PROD1, DRILL DDRL P Drill 6.75” production hole geo-steering
from 13450'MD to 13740‘MD 3996’
TVD, 2k WOB, 285 GPM, 2536 PSI, 120
RPM, 9k TQ,13% F/O, 10.86 ECD, P/U
120k S/O 60k, RT 91k, ADT 4.26 hrs,
Total bit hrs= 35.57,
13,450.0 13,740.0
9/24/2023
12:00
9/24/2023
18:00
6.00 PROD1, DRILL DDRL P Drill 6.75” production hole geo-steering
from 13740'MD to 14031‘MD 3986’
TVD, 2k WOB, 285 GPM, 2545 PSI, 120
RPM, 8k TQ,13% F/O, 10.89 ECD, P/U
120k S/O 60k, RT 91k, ADT 5.15 hrs,
Total bit hrs 40.72,
13,740.0 14,031.0
9/24/2023
18:00
9/25/2023
00:00
6.00 PROD1, DRILL DDRL P Drill 6.75” production hole geo-steering
from 14031'MD to 14446‘MD 3975’
TVD, 2k WOB, 285 GPM, 2660 PSI, 120
RPM, 9k TQ,13% F/O, 11.09 ECD, P/U
118k S/O 59k, RT 92k, ADT 3.02 hrs,
Total bit hrs= 43.74,
14,031.0 14,446.0
9/25/2023
00:00
9/25/2023
06:00
6.00 PROD1, DRILL DDRL P Drill 6.75” production hole geo-steering
from 14446'MD to 14890‘MD 3967’
TVD, .5k WOB, 285 GPM, 2685 PSI,
120 RPM, 10k TQ,13% F/O, 11.03 ECD,
P/U 112k S/O na, RT 90k, ADT 4.51 hrs,
Total bit hrs= 48.25,
14,446.0 14,890.0
9/25/2023
06:00
9/25/2023
12:00
6.00 PROD1, DRILL DDRL P Drill 6.75” production hole geo-steering
from 14890'MD to 15361‘MD 3964’
TVD, 3k WOB, 285 GPM, 2688 PSI, 120
RPM, 10k TQ,13% F/O, 11.05 ECD, P/U
127k S/O na, RT 92k, ADT 4.75 hrs,
Total bit hrs=53.00,
14,890.0 15,361.0
9/25/2023
12:00
9/25/2023
18:00
6.00 PROD1, DRILL DDRL P Drill 6.75” production hole geo-steering
from 15361'MD to 15718‘MD 3959’TVD,
1k WOB, 285 GPM, 2752 PSI, 120
RPM, 9k TQ,13% F/O, 11.11 ECD, P/U
125k S/O na, RT 92k, ADT 3.61 hrs,
Total bit hrs= 56.51,
15,361.0 15,718.0
9/25/2023
18:00
9/25/2023
23:00
5.00 PROD1, DRILL DDRL P Drill 6.75” production hole geo-steering
from 15718' MD to 16111‘MD 3960’
TVD, 3k WOB, 285 GPM, 2811 PSI, 100
RPM, 9k TQ,12% F/O, 11.21 ECD, P/U
125k S/O na, RT 93k, ADT 2.60 hrs,
Total bit hrs=59.85,
15,718.0 16,111.0
Rig: DOYON 142
RIG RELEASE DATE 10/21/2023
Page 20/37
1C-158
Report Printed: 11/9/2023
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)
9/25/2023
23:00
9/26/2023
00:00
1.00 PROD1, DRILL SEQP T Pickup string to 16070' Noticed pressure
loss from 2753 psi to 2132 psi for 621
psi pressure difference and MWD
turbine decrease indicating a washout,
tested all surface equipment and
associated circulating equipment(good),
checked mud system for integrated air
entrained mud(good), pressure tested
surface lines to 875 psi with IBOP
(good), PJSM, POOH to check string for
washout.
16,111.0 16,111.0
9/26/2023
00:00
9/26/2023
00:30
0.50 PROD1, DRILL OWFF P Flow check well static 16,060.0 16,060.0
9/26/2023
00:30
9/26/2023
01:45
1.25 PROD1, DRILL TRIP P From 16060' to 15311' POOH on
elevators with 4" drill pipe checking
string for washout. P/U 135k Found
washout at 15341' on bottom single of
stand #161. L/D washed joint, P/U new
joint install in string.
16,060.0 15,311.0
9/26/2023
01:45
9/26/2023
03:30
1.75 PROD1, DRILL CIRC P @ 15311 Circulate and reciprocate while
circulating bottoms up to verify pressure
and turbine RPM, 285 GPM, 2808 PSI,
80 RPM, RT 80K 12% F/O, Pressure
stabilized and turbine RPM 3840. All
parameters checked out.
15,311.0 15,311.0
9/26/2023
03:30
9/26/2023
05:15
1.75 PROD1, DRILL TRIP P From 15311' to 16111' TIH with 4" pipe
wash and ream @ 100 GPM, 920 PSI,
S/O 60k, RT 92k, 40 RPM, 7k TQ
15,311.0 16,111.0
9/26/2023
05:15
9/26/2023
08:30
3.25 PROD1, DRILL DDRL P Drill 6.75” production hole geo-steering
from 16111' MD to 16349 ‘MD 3960’
TVD, 4k WOB, 285 GPM, 2844 PSI, 100
RPM, 9k TQ,12% F/O, 11.27 ECD, P/U
125k S/O Na, RT 93k, ADT 1.69 hrs,
Total bit hrs=61.54, Found broken
strands on drill line, Decision made to
come to shoe and slip and cut drill line.
16,111.0 16,349.0
9/26/2023
08:30
9/26/2023
09:00
0.50 PROD1, DRILL SRVY T At 16349' MD obtain on bottom survey,
send downlink to put directional tools in
neutral.
16,349.0 16,349.0
9/26/2023
09:00
9/26/2023
12:30
3.50 PROD1, DRILL BKRM T BROOH from 16349' to 16164' MD,
While circulating bottoms up X2 racking
2 stand back. 285 GPM, 2833 PSI, 12%
F/O, 100 RPM, 8.5k TQ, 11.22 ppg
ECD, Total strokes 9872. Shut down
Monitor well, OWFF 10 minutes (well
Static)
16,349.0 16,164.0
9/26/2023
12:30
9/26/2023
17:00
4.50 PROD1, DRILL TRIP T POOH on elevators from 16164'MD to
12568'MD Monitoring displacement on
trip tank. P/U 138k
16,164.0 12,568.0
9/26/2023
17:00
9/26/2023
18:00
1.00 PROD1, DRILL CIRC T Circulate bottoms up while reaming into
the shoe from 12568' MD to 12560'MD
280 GPM, 2430 PSI, 13% F/O, 60 RPM,
6k TQ, 88k RT, Total strokes 3911.
12,568.0 12,560.0
9/26/2023
18:00
9/26/2023
23:00
5.00 PROD1, DRILL SLPC T Make up TIW valve, hang blocks,
remove wraps from dead man, perform
slip and cut while circulating at 245
GPM, 1911 PSI, 11% F/O, cut & slip 68
wraps 998', M/U dog knot, ensure
Deadman is properly torqued (Driller &
Toolpusher verified), service top drive
and blocks, check and adjust stops and
brakes, calibrate block height,
12,560.0 12,560.0
9/26/2023
23:00
9/27/2023
00:00
1.00 PROD1, DRILL TRIP T TIH F/12,560 T/ 12,754', RT=90K S/O=
62K GPM=100 WITH 740PSI, wash and
ream as required when S/O loss
encountered
12,560.0 12,754.0
Rig: DOYON 142
RIG RELEASE DATE 10/21/2023
Page 21/37
1C-158
Report Printed: 11/9/2023
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)
9/27/2023
00:00
9/27/2023
00:30
0.50 PROD1, DRILL SVRG P Rig service, Grease top-drive 12,754.0 12,754.0
9/27/2023
00:30
9/27/2023
06:00
5.50 PROD1, DRILL TRIP T Continue TIH from 12754' MD to 16349'
MD RT 90k, S/O 62k, GPM 100, PSI
740, wash and ream as required when
loss of S/O weight, SLB DD, send
downlink to Power Drive and MWD to
activate for drilling @ 16256' MD Wash
and ream down at full drilling rate GPM
283, PSI 2712, to 16349' MD,
12,754.0 16,349.0
9/27/2023
06:00
9/27/2023
12:00
6.00 PROD1, DRILL DDRL P Drill 6.75” production hole geo-steering
from 16349' MD to 16893 ‘MD 3953’
TVD, 4k WOB, 285 GPM, 2773 PSI, 100
RPM, 9k TQ,13% F/O, 11.12 ECD, P/U
132k S/O Na, RT 92k, ADT 3.87 hrs,
Total bit hrs=65.41.
16,349.0 16,893.0
9/27/2023
12:00
9/27/2023
18:00
6.00 PROD1, DRILL DDRL P Drill 6.75” production hole geo-steering
from 16893' MD to 17460‘MD 3965’
TVD, 2k WOB, 285 GPM, 2495 PSI, 100
RPM, 9k TQ,13% F/O, 11.37 ECD, P/U
142k S/O Na, RT 96k, ADT 4.30 hrs,
Total bit hrs=69.71.
16,893.0 17,460.0
9/27/2023
18:00
9/28/2023
00:00
6.00 PROD1, DRILL DDRL P Drill 6.75” production hole geo-steering
from 17460' MD to 17843‘MD 3977’
TVD,10k WOB, 285 GPM, 2989 PSI,
100 RPM, 13 TQ,13% F/O, 11.37 ECD,
P/U 151k S/O Na, RT 98k, ADT 4.45
hrs, Total bit hrs=74.16.
17,460.0 17,832.0
9/28/2023
00:00
9/28/2023
06:00
6.00 PROD1, DRILL DDRL P Drill 6.75” production hole geo-steering
from 17832' MD to 17903‘MD 3977’
TVD,15k WOB, 285 GPM, 2989 PSI,
100 RPM, 14 TQ,13% F/O, 11.37 ECD,
P/U 151k S/O Na, RT 98k, ADT 5.24
hrs, Total bit hrs=79.40.
17,832.0 17,903.0
9/28/2023
06:00
9/28/2023
12:00
6.00 PROD1, DRILL DDRL P Drill 6.75” production hole geo-steering
from 17903' MD to 17965‘MD 3982’
TVD,16k WOB, 285 GPM, 2998 PSI, 80
RPM, 15 TQ,13% F/O, 10.98 ECD, P/U
151k S/O Na, RT 98k, ADT 5.90 hrs,
Total bit hrs=85.30. Pumped 30 bbl 20#
1200 carb. bit balling sweep @
17940'MD
17,903.0 17,965.0
9/28/2023
12:00
9/28/2023
18:00
6.00 PROD1, DRILL DDRL P Drill 6.75” production hole geo-steering
from 17965' MD to 18018‘MD 3984’
TVD,16k WOB, 285 GPM, 3030PSI, 60
RPM, 16 TQ,12% F/O, 11.14 ECD, P/U
148k S/O Na, RT 100k, ADT 5.40 hrs,
Total bit hrs=90.70.
17,965.0 18,018.0
9/28/2023
18:00
9/29/2023
00:00
6.00 PROD1, DRILL DDRL P Drill 6.75” production hole geo-steering
from 18018' MD to 18081‘MD 3986’
TVD,16k WOB, 285 GPM, 3044PSI, 60
RPM, 14 TQ,12% F/O, 11.11 ECD, P/U
148k S/O Na, RT 100k, ADT 5.90 hrs,
Total bit hrs=99.60.
18,018.0 18,081.0
9/29/2023
00:00
9/29/2023
06:00
6.00 PROD1, DRILL DDRL P Drill 6.75” production hole geo-steering
from 18081' MD to 18125‘MD 3988’
TVD,16k WOB, 285 GPM, 3064PSI, 60
RPM, 12 TQ,12% F/O, 11.09 ECD, P/U
146k S/O Na, RT 103k, ADT 5.28 hrs,
Total bit hrs=102.0.
18,081.0 18,125.0
9/29/2023
06:00
9/29/2023
12:00
6.00 PROD1, DRILL DDRL P Drill 6.75” production hole geo-steering
from 18125' MD to 18185‘MD 3990’
TVD,20k WOB, 285 GPM, 3144 PSI,
150 RPM, 16 TQ,12% F/O, 11.30 ECD,
P/U 147k S/O Na, RT 105k, ADT 5.92
hrs, Total bit hrs=107.92.
18,125.0 18,185.0
Rig: DOYON 142
RIG RELEASE DATE 10/21/2023
Page 22/37
1C-158
Report Printed: 11/9/2023
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)
9/29/2023
12:00
9/29/2023
18:00
6.00 PROD1, DRILL DDRL P Drill 6.75” production hole geo-steering
from 18185' MD to 18292‘MD 3995’
TVD,20k WOB, 285 GPM, 3215 PSI,
150 RPM, 20 TQ,12% F/O, 11.31 ECD,
P/U 147k S/O Na, RT 105k, ADT 5.38
hrs, Total bit hrs=113.30.
18,185.0 18,292.0
9/29/2023
18:00
9/29/2023
18:30
0.50 PROD1, DRILL DDRL P Drill 6.75” production hole geo-steering
from 18292' MD to 18298‘MD 3995’
TVD,20k WOB, 285 GPM, 3215PSI, 60
RPM, 20TQ,12% F/O, 11.31 ECD, P/U
147k S/O Na, RT 105k, ADT .2 hrs, Total
bit hrs=113.02.
18,292.0 18,298.0
9/29/2023
18:30
9/29/2023
19:00
0.50 PROD1, DRILL SEQP T Observe pressure loss while drilling
after connection, Pressure decreased
from 3171psi to 2923 psi rapid loss.
Shut down pumps pressure test surface
equipment to 800 psi from mud pumps
to IBOP(Good Test) inital P/U 133K
PJSM Prep to POOH. OWFF 15 min
well static
18,298.0 18,298.0
9/29/2023
19:00
9/30/2023
00:00
5.00 PROD1, DRILL TRIP T POOH from 18298'MD to 14124'MD
with 4" drill pipe inspecting drill pipe for
washout. Monitoring displacements at
pit #5
18,298.0 14,124.0
9/30/2023
00:00
9/30/2023
01:45
1.75 PROD1, DRILL TRIP T POOH from 14,124‘MD to 12,557‘MD,
with 4” drill pipe, P/U 93k; Monitor hole
fill on pit 5. Inspect drill pipe for
washout. No overpull observed when
pulling BHA into the shoe
14,124.0 12,557.0
9/30/2023
01:45
9/30/2023
02:00
0.25 PROD1, DRILL OWFF T OWFF (static) 12,557.0 12,557.0
9/30/2023
02:00
9/30/2023
06:00
4.00 PROD1, DRILL TRIP T POOH from 12557‘MD to 7615‘MD, with
4” drill pipe, P/U 68k; Monitor hole fill on
pit 5. Inspect drill pipe for washout.
12,557.0 7,615.0
9/30/2023
06:00
9/30/2023
07:45
1.75 PROD1, DRILL TRIP T POOH 7615‘MD to 5428.57‘MD, w/ 4”
drill pipe P/U 47k; Monitor hole fill on pit
5. Inspect drill pipe for washout. Locate
twist off at middle jt of stand #56, stub
length 4.45', ID 3.75", Max OD flare
4.25". Calculated top of fish 12,870'MD,
Pipe left in hole:
Twist off jt = 27.12'
1 single 31.69'
55 stands 4" drill pipe 5201.31'
169.19' Production BHA
7,615.0 0.0
9/30/2023
07:45
9/30/2023
12:00
4.25 PROD1, DRILL CLEN T Clean/clear rig floor, prep. shed for BHA
and modify pipe tally for fishing run.
Verify xo's on hand, observe well for
flow via trip tank. Service top drive,
inspect handling equipment and work on
Mp2's.
0.0 0.0
9/30/2023
12:00
9/30/2023
15:00
3.00 PROD1, DRILL OWFF T Continue monitoring well via trip tank,
Inventory shaker screens, Prep
pipeshed for fishing BHA, check moving
system tire pressures, mobilize fishing
BHA components to rig floor.
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 10/21/2023
Page 23/37
1C-158
Report Printed: 11/9/2023
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)
9/30/2023
15:00
9/30/2023
16:45
1.75 PROD1, DRILL BHAH T Hold PJSM. M/U fishing BHA assembly
to 234' as per yellow jacket.
6 5/8" ROD Shoe
XO Bushing
5 3/4" S150 Bowl
5 3/4" Upper Extension
S150 Top Sub
Circulate Control Jt
4 3/4" Bumper sub
4 3/4" Oil Jar
6- 4 3/4" Drill Collars
4 3/4" Accelerator jars
Xo Sub = 233.90'
0.0 234.0
9/30/2023
16:45
9/30/2023
22:30
5.75 PROD1, DRILL T RIH with fishing assembly from 234' to
12600'MD with 4'' drill pipe from derrick.
Monitoring displacement via trip tank,
S/O 72k @12600'MD obtain fishing
parameters P/U 138 S/O 84k ROT 103k
with 6k TQ,
234.0 12,600.0
9/30/2023
22:30
10/1/2023
00:00
1.50 PROD1, DRILL T @12600' circulate bottoms up with ICP
85-200 GPM 536-923 psi, FCP 907psi
@ 200 GPM, 492psi @ 85 GPM,
@12600'MD, obtain fishing parameters
as per Yellow Jacket Rep- P/U 138k S/O
84k ROT 103k with 6k TQ.
12,600.0 12,600.0
10/1/2023
00:00
10/1/2023
04:30
4.50 PROD1, DRILL FISH T Wash down from 12600'MD to 12889'
MD with fishing assy. Install single
working joint,31.64' and 15' pup
between #133 and #14 stands, Engage
and dress top of fish to 12907' MD. As
per Yellow Jacket Rep. with 20 RPM, 6-
8 TQ, 84 GPM, 524 PSI, Monitoring
pressure and attempt to engage top of
fish @ 12889' MD. to 12896' P/U 144k,
S/O 46K attempted to engage several
times with no success.
12,600.0 12,889.0
10/1/2023
04:30
10/1/2023
05:30
1.00 PROD1, DRILL CIRC T Circulate bottoms up with 85 GPM, 515
PSI, slowly working pipe up and down
with fishing assy. P/U 143, S/O 74K
12,889.0 12,870.0
10/1/2023
05:30
10/1/2023
06:30
1.00 PROD1, DRILL TRIP T POOH from 12870'MD to 12600'MD.
Lay down working single and 15' pup
P/U 134K
12,870.0 12,600.0
10/1/2023
06:30
10/1/2023
08:30
2.00 PROD1, DRILL CIRC T Circulate bottoms up stage pumps up to
4 BPM, 725 PSi, 5 BPM 922 PSI, 6
BPM 1190 PSI, 6.5 BPM 1315 PSI, 7
BPM 1475 PSI, OWFF( Well Static)
12,600.0 12,600.0
10/1/2023
08:30
10/1/2023
09:00
0.50 PROD1, DRILL TRIP T POOH f/ 12600'MD to 12147'MD P/U
138k
12,600.0 12,147.0
10/1/2023
09:00
10/1/2023
09:15
0.25 PROD1, DRILL CIRC T Pump 13 BBL dry job @ 12147' MD 12,147.0 12,147.0
10/1/2023
09:15
10/1/2023
15:00
5.75 PROD1, DRILL TRIP T POOH from 12147'MD to 328'MD 12,147.0 328.0
10/1/2023
15:00
10/1/2023
15:30
0.50 PROD1, DRILL OWFF T OWFF (Well Static ) 328.0 328.0
10/1/2023
15:30
10/1/2023
17:00
1.50 PROD1, DRILL BHAH T Rack back last stand, L/D crossover,
PJSM, L/D 6 3/4" drill collars, fishing
jars. Break down over shot inspect
packoff and grapple. No indication that
packoff or grapple had engaged fish.
Slight wear to tip of overshot shoe.
328.0 0.0
10/1/2023
17:00
10/1/2023
18:00
1.00 PROD1, DRILL CLEN T Clean and clear rig floor, Move new
fishing tool assy to rig floor.
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 10/21/2023
Page 24/37
1C-158
Report Printed: 11/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/1/2023
18:00
10/1/2023
18:45
0.75 PROD1, DRILL BHAH T M/U Yellow Jacket fishing tool assy to
101'MD P/U 47k
5 3/4 WALLHOOK GUIDE 3.00
5 3/4 S150 BOWL 1.55
5 3/4 UPPER EXTENSION 2.75
S150 TOP SUB 1.33
XO SUB, XT 39 BX 3 1/2 IF P 1.60
2 JOINTS XT 39 DP 63.30
XO SUB, 3 1/2 IF B X XT39 P 2.96
4 3/4 BUMPER SUB 7.90
4 3/4 OIL JAR 13.21
XO SUB 2.04 =101.29'
0.0 101.0
10/1/2023
18:45
10/2/2023
00:00
5.25 PROD1, DRILL TRIP T TIH from 101'MD to 10612'MD P/U 74K
S/O 74K
101.0 10,612.0
10/2/2023
00:00
10/2/2023
01:45
1.75 PROD1, DRILL TRIP T RIH from 10612' MD to 12600' MD with
fishing assy. Monitor well displacement
via trip tank.
10,612.0 12,600.0
10/2/2023
01:45
10/2/2023
03:00
1.25 PROD1, DRILL CIRC T Circulate bottoms up at 12600' MD with
314 GPM, 894 PSI, 9% F/O, P/U 135K,
S/O 82K, RT 105K, Pumped 3731
strokes.
12,600.0 12,600.0
10/2/2023
03:00
10/2/2023
09:00
6.00 PROD1, DRILL FISH T Wash down to attempt to engage fish
from 12600' MD to 12882' MD @ 84
GPM, 480 PSI, 6% F/O, P/U 138k, S/O
82K, Pickup to 12862'. Indexing
wallhook tool 1/4 to1/2 turn attempting
to locate fish. Rotate with10 RPM, 84
GPM, 480 PSI, 6% F/O, P/U 138k, S/O
82K, RT 105k. 6k freeTQ, Indexing from
12862'MD to12882'MD, 12882'MD
to12895'MD, 12845'MD to12884'MD.
With no pump, slack off from12840'MD
to 12884'MD. No success locating fish.
12,600.0 12,880.0
10/2/2023
09:00
10/2/2023
09:45
0.75 PROD1, DRILL PMPO T Pump out hole from 12870'MD to
12565'MD @ 2.5 BPM 500 PSI P/U
130k.
12,870.0 12,565.0
10/2/2023
09:45
10/2/2023
10:00
0.25 PROD1, DRILL OWFF T OWFF ( well static). 12,565.0 12,565.0
10/2/2023
10:00
10/2/2023
10:45
0.75 PROD1, DRILL TRIP T POOH from 12565'MD to 12195' (No
swabbing). Hole took proper fill. Line up
and pump dry job.
12,565.0 12,195.0
10/2/2023
10:45
10/2/2023
17:00
6.25 PROD1, DRILL TRIP T POOH from 12195' MD to 101' MD with
Fishing BHA.
12,195.0 101.0
10/2/2023
17:00
10/2/2023
18:30
1.50 PROD1, DRILL BHAH T POOH with fishing BHA. Inspect
wallhood assy. L/D fishing BHA. Clear
and clean floor. Mobilize new fishing
assy to rig floor. Service Iron roughneck
and slips.
101.0 0.0
10/2/2023
18:30
10/2/2023
19:15
0.75 PROD1, DRILL BHAH T M/U Fishing BHA to 191', P/U 54k
5 1/16" CONCAVE JUNK MILL 1.65'
BIT SUB 3 1/2 IFX REG 1.98'
CIRC CONTROL JNT 1.60'
XO SUB, XT 39 BX 3 1/2 IF P 1.65'
5 JOINTS XT 39 DP 158.27'
XO SUB, 3 1/2 IF B X XT39 P 2.96'
4 3/4 BUMPER SUB 7.90'
4 3/4 OIL JAR 13.21'
XO SUB 2.04 = 191.26'
0.0 191.0
10/2/2023
19:15
10/3/2023
00:00
4.75 PROD1, DRILL TRIP T TIH from 191'MD to 9288'MD, P/U
112k, S/O 74k.
191.0 9,288.0
10/3/2023
00:00
10/3/2023
01:15
1.25 PROD1, DRILL TRIP T TIH from 9,288' MD to 11,094' MD, P/U
112k, S/O 74k. Monitor disp via tt.
9,288.0 11,094.0
10/3/2023
01:15
10/3/2023
01:45
0.50 PROD1, DRILL SVRG T Service rig. Adjust draw works encoder. 11,094.0 11,094.0
Rig: DOYON 142
RIG RELEASE DATE 10/21/2023
Page 25/37
1C-158
Report Printed: 11/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/3/2023
01:45
10/3/2023
02:45
1.00 PROD1, DRILL TRIP T TIH from 11,094' MD to 12,600' MD, S/O
84k. Monitor disp via tt.
11,094.0 12,600.0
10/3/2023
02:45
10/3/2023
04:15
1.50 PROD1, DRILL CIRC T Circ and condition mud system above 7-
5/8" csg shoe staging pumps up to 214
gpm, ICP - 468, FCP - 893, F/O - 7%,
max gas - 210 units. Total stks pumped
- 4315 (435 bbls).
11,094.0 12,600.0
10/3/2023
04:15
10/3/2023
06:00
1.75 PROD1, DRILL FISH T Obtain parameters as per YellowJacket
rep. GPM - 84, PSI - 480, F/O - 5%,
RPM - 20, TQ - 6K. P/U WT - 134K. S/O
WT - 83K, Rot WT - 108K. Wash and
ream down from 12,600' MD to 12,813'
MD. Observe 7K WOB @ 12,813' MD.
12,600.0 12,813.0
10/3/2023
06:00
10/3/2023
07:00
1.00 PROD1, DRILL FISH T Successfully work past 12,813' and cont
in the hole w/ GPM - 84, PSI - 480, F/O
- 5%, RPM - 10, TQ - 6K. P/U WT -
134K. S/O WT - 83K, Rot WT - 108K.
Observe tight hole @ 12,828' MD.
Successfully work past 12,828' MD to
12,829' MD (kelly down) and confirm no
fish.
12,813.0 12,829.0
10/3/2023
07:00
10/3/2023
07:30
0.50 PROD1, DRILL FISH T Increase flow rate to 5BPM, GPM - 211,
PSI - 900, F/O - 7% and work stand
from 12,829' MD to 12,733' MD.
12,829.0 12,829.0
10/3/2023
07:30
10/3/2023
12:00
4.50 PROD1, DRILL FISH T Cont in the hole w/ GPM - 84, PSI - 480,
F/O - 5%, P/U WT - 134K. S/O WT -
83K. Observe 9.5K WOB @ 12,905'
MD. Engage rot to 30 RPM, 7K TQ.
Increase flow to 211 GPM, 909 PSI, F/O
- 8%. Observe 15K WOB @ 12,910'
MD. Successfully work by 12,910' MD
down to 12,945' MD.
12,829.0 12,945.0
10/3/2023
12:00
10/3/2023
13:15
1.25 PROD1, DRILL FISH T Decrease rate and cont in the hole to
13,000' MD w/ GPM - 84, PSI - 480, F/O
- 6%, RPM - 30, TQ - 7K, P/U WT -
134K. S/O WT - 83K, ROT WT - 107K
12,945.0 13,000.0
10/3/2023
13:15
10/3/2023
14:00
0.75 PROD1, DRILL PMPO T Pump out of the hole laying dn working
singles (x6) and rack back std in the
derrick from 13,000' MD to inside the
csg shoe at 12,555' MD w/ GPM - 211,
PSI - 900, F/O - 8%.
13,000.0 12,555.0
10/3/2023
14:00
10/3/2023
15:45
1.75 PROD1, DRILL CIRC T Circ btm up @ GPM - 211, PSI - 900,
F/O - 8%. Total stks pumped - 3937
(397 bbls)
13,000.0 12,555.0
10/3/2023
15:45
10/3/2023
16:00
0.25 PROD1, DRILL OWFF T OWFF 13,000.0 12,555.0
10/3/2023
16:00
10/3/2023
16:30
0.50 PROD1, DRILL TRIP T POOH on elevators from 12,555' MD to
12,102' MD. Monitor disp via tt.
12,555.0 12,102.0
10/3/2023
16:30
10/3/2023
16:45
0.25 PROD1, DRILL CIRC T Pump 10 bbl 11.1 ppg slug. B/D TD and
install stripping rubber.
12,102.0 12,102.0
10/3/2023
16:45
10/3/2023
22:30
5.75 PROD1, DRILL TRIP T POOH on elevators f/ 12,102' MD to 96'
MD. Monitor disp via tt.
12,102.0 96.0
10/3/2023
22:30
10/3/2023
23:30
1.00 PROD1, DRILL BHAH T L/D fishing BHA as per YellowJacket rep
f/ 96' MD.
96.0 0.0
10/3/2023
23:30
10/4/2023
00:00
0.50 PROD1, DRILL BHAH T Clean and clear floor of YellowJacket
BHA.
0.0 0.0
10/4/2023
00:00
10/4/2023
01:15
1.25 PROD1, DRILL BHAH T Continue to clean and clear rig floor.
Expedite Baker scraper and bit sub to
the rig floor. SIMOPS - service iron
roughneck.
0.0 0.0
10/4/2023
01:15
10/4/2023
01:45
0.50 PROD1, DRILL BHAH T M/U Baker scraper, bit sub, bit, and xo. 0.0 8.0
Rig: DOYON 142
RIG RELEASE DATE 10/21/2023
Page 26/37
1C-158
Report Printed: 11/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/4/2023
01:45
10/4/2023
08:45
7.00 PROD1, DRILL TRIP T RIH w/ scraper assembly on 4" DP from
the derrick to 11,920' MD. P/U WT -
117K, S/O WT - 77K. Fill pipe every 20
stds. Monitor disp via pit #5.
8.0 11,920.0
10/4/2023
08:45
10/4/2023
12:00
3.25 PROD1, DRILL CIRC T Circ and condition mud for upcoming
milling ops staging pumps up to 4 BPM,
GPM - 169, ICP - 590, FCP - 1345, F/O
- 9%. Work string from 11,920' MD to
12,014' MD.
Total stks pumped - 6404 (645 bbls).
11,920.0 12,014.0
10/4/2023
12:00
10/4/2023
12:15
0.25 PROD1, DRILL OWFF T Stand back stnd of 4" HWDP and
OWFF. Observe slight flow back.
Decision made to pump out of the hole.
11,920.0 11,920.0
10/4/2023
12:15
10/4/2023
16:45
4.50 PROD1, DRILL PMPO T Pump OOH from 11,920' MD to 10,423'
MD @ 3 BPM, GPM - 127, PSI - 1080,
UP WT - 109K.
SIMOPS - L/D 4" DP via mousehole.
11,920.0 10,423.0
10/4/2023
16:45
10/4/2023
17:15
0.50 PROD1, DRILL OWFF T OWFF - static 10,423.0 10,423.0
10/4/2023
17:15
10/4/2023
17:30
0.25 PROD1, DRILL TRIP T POOH on elevators racking back two
stands observing fluid dropping.
10,423.0 10,138.0
10/4/2023
17:30
10/4/2023
18:00
0.50 PROD1, DRILL CIRC T Pump 8 bbl 11.1 slug. 10,138.0 10,138.0
10/4/2023
18:00
10/5/2023
00:00
6.00 PROD1, DRILL PULD T POOH from 10,138' MD to 5,636' MD
L/D 4" DP. Monitor disp via TT.
10,138.0 5,636.0
10/5/2023
00:00
10/5/2023
06:00
6.00 PROD1, DRILL PULD T POOH from 5,636' MD to 500' MD L/D
4" DP. Monitor disp via TT.
5,636.0 500.0
10/5/2023
06:00
10/5/2023
08:00
2.00 PROD1, DRILL FRZP T Establish injection rate into 10-3/4" X 7-
5/8" OA . Fill OA w/ 9 bbls of 9.1ppg
FWP. Inject @ .5 BPM. Observe
breakover at 795 (17.4 EMW) FCP -
535. Total bbls injected - 4.5. ISIP -
535. FSIP - 361 after 20 min. Swap to
LRS and inject 85 bbls of 6.8 ppg diesel
@ 2 bpm, injection psi - 786. ISIP - 786.
FSIP - 702 after 20 min.
SIMOPS - POOH L/D 4" DP from 500'
MD.
500.0 8.0
10/5/2023
08:00
10/5/2023
08:30
0.50 PROD1, DRILL BHAH T L/D Baker csg scraper BHA. 8.0 0.0
10/5/2023
08:30
10/5/2023
10:15
1.75 PROD1, DRILL OTHR T Load and process 4" DP in the
pipeshed.
0.0 0.0
10/5/2023
10:15
10/5/2023
10:45
0.50 PROD1, WELLPR BHAH T M/U Baker CIBP as per rep. 0.0 0.0
10/5/2023
10:45
10/5/2023
13:00
2.25 PROD1, WELLPR PULD T Single in the hole from pipeshed w/
bridge plug assembly on 4" DP to 1,335'
MD. Monitor disp via TT.
0.0 1,335.0
10/5/2023
13:00
10/5/2023
13:30
0.50 PROD1, WELLPR SVRG T Service drawworks, top drive, pipeskate,
and iron roughneck.
1,335.0 1,335.0
10/5/2023
13:30
10/5/2023
15:00
1.50 PROD1, WELLPR OTHR T Load and process 4" DP in the
pipeshed.
1,335.0 1,335.0
10/5/2023
15:00
10/5/2023
19:30
4.50 PROD1, WELLPR PULD T Single in the hole from pipeshed w/
bridge plug assembly on 4" DP from
1,335' MD to 4,242' MD. Monitor disp
via TT. S/O WT - 81K
1,335.0 4,242.0
10/5/2023
19:30
10/5/2023
20:15
0.75 PROD1, WELLPR OTHR T Load and process 4" DP in the
pipeshed.
0.0 0.0
10/5/2023
20:15
10/6/2023
00:00
3.75 PROD1, WELLPR PULD T Single in the hole from pipeshed w/
bridge plug assembly on 4" DP from
4,242' MD to 6,638' MD. Monitor disp
via TT. S/O WT - 76K
4,242.0 6,638.0
Rig: DOYON 142
RIG RELEASE DATE 10/21/2023
Page 27/37
1C-158
Report Printed: 11/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/6/2023
00:00
10/6/2023
08:00
8.00 PROD1, WELLPR PULD T Single in the hole from pipeshed w/
bridge plug assembly on 4" DP from
6,638' MD to 11,918' MD. Monitor disp
via TT. S/O WT - 105K
6,638.0 11,918.0
10/6/2023
08:00
10/6/2023
09:00
1.00 PROD1, WELLPR MPSP T Obtain parameters. UP WT - 105K, S/O
WT - 105K. Apply 20 RH turns w/ 12
RPM, 7.3K TQ. Work string from
11,919' MD to 11,929' MD while rot w/
16 RPM. Stop rot and work string again
from 11,919' MD to 11,929' MD. Initiate
mud pump @ 6 BPM, 253 GPM, 985
PSI, P/U to 11,920' MD and observe
plug not set. S/O to 11,929' MD and
apply 30 RH turns w/ 6.2 TQ. Work
string up/dn from 11,929' MD to 11,918'
MD (3x) and observe tq decrease to 5K,
indicating plug set. Apply 7 additional
turns to the RT w/ 6.1K TQ. Pick up to
11,918' MD and set dn to 64K at 11,924'
MD 3x confirming plug set.
11,918.0 11,924.0
10/6/2023
09:00
10/6/2023
09:30
0.50 PROD1, WELLPR PMPO T Pump OOH from 11,924' MD to 11,886'
MD w/ 3 BPM, 980 psi, UP WT at Rate -
152K. Std back std.
11,924.0 11,886.0
10/6/2023
09:30
10/6/2023
10:00
0.50 PROD1, WELLPR PRTS T PT CIBP to 1000 psi (good). 11,886.0 11,886.0
10/6/2023
10:00
10/6/2023
12:00
2.00 PROD1, WELLPR CIRC T Circ while recip pipe increasing lubes to
3% @ 5 BPM, 211 GPM, 1360 PSI, P/U
WT - 140K, S/O WT - 101K. Total stks
pumped - 5200 (523 bbls). Pump 10 bbl
11.1 ppg slug.
11,886.0 11,886.0
10/6/2023
12:00
10/6/2023
13:30
1.50 PROD1, WELLPR TRIP T POOH from 11,886' MD to 10,694' MD.
UP WT - 144K. Monitor disp via TT.
11,886.0 10,694.0
10/6/2023
13:30
10/6/2023
14:00
0.50 PROD1, WELLPR SVRG T Service Drawworks, iron roughneck, and
top drive.
10,694.0 10,694.0
10/6/2023
14:00
10/6/2023
20:00
6.00 PROD1, WELLPR TRIP T POOH on elevators from 10,694' MD.
L/D Baker running tool.
10,694.0 0.0
10/6/2023
20:00
10/6/2023
21:00
1.00 PROD1, WELLPR RURD T B/D hole fill. Drain stack and pull wear
bushing per Vault rep.
0.0 0.0
10/6/2023
21:00
10/6/2023
22:00
1.00 PROD1, WELLPR WWWH T M/U flushing tool and flush stack w/ 850
GPM. Make 4 passes. B/D top drive
and rig down flushing tool.
0.0 0.0
10/6/2023
22:00
10/7/2023
00:00
2.00 PROD1, WELLPR BOPE T P/U 4" test jt. Set test plug per Vault
rep. M/U test equipment, flood lines,
and shell test BOPE.
0.0 0.0
10/7/2023
00:00
10/7/2023
05:30
5.50 PROD1, WHDBOP BOPE T BOPE test. All tests at 250/3500 psi.
Test with 4” and 4½" test joints. Test
annular preventer with 4" & 4½". Upper
and lower pipe rams with 4” and 4½"
test joints. Test blind rams. Test choke
valves #1 to #14, upper and lower top
drive IBOP's, test 4” dart valve and 2ea
TIW valves, test rig floor, mezzanine,
HCR and manual kill valves, test HCR
and manual choke valves, hydraulic and
manual chokes to 1500 psi. and
demonstrate bleed off. Perform
accumulator test. Starting
pressure=3000 psi, after function= 1800
psi, 200 psi attained=19 sec's, full
recovery=103 sec. 6 nitrogen bottles at
1950 psi. Test gas alarms, PVT and flow
show. 1 F/P on 4" dart valve. Changed
out, re-test was good. Witness was
waived by AOGCC Rep Kam StJohn.
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 10/21/2023
Page 28/37
1C-158
Report Printed: 11/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/7/2023
05:30
10/7/2023
07:00
1.50 PROD1, WHDBOP RURD T Pull test plug and install 9.062" ID wear
bushing. B/D and rig down testing
equipment.
0.0 0.0
10/7/2023
07:00
10/7/2023
10:30
3.50 PROD1, WHPST SLPC T Slip and cut 107' drill line. 0.0 0.0
10/7/2023
10:30
10/7/2023
11:00
0.50 PROD1, WHPST SVRG T Service topdrive, drawworks, and ST-
100.
0.0 0.0
10/7/2023
11:00
10/7/2023
14:30
3.50 PROD1, WHPST BHAH T PJSM, Pick up Baker whipstock
assembly to 337' MD. Scribe MWD per
DD/MWD and Baker Rep.
0.0 337.0
10/7/2023
14:30
10/7/2023
16:30
2.00 PROD1, WHPST TRIP T RIH w/ whipstock assembly to 2,269'
MD. Monitor disp via pit 1. S/O WT -
75K.
337.0 2,269.0
10/7/2023
16:30
10/7/2023
17:15
0.75 PROD1, WHPST DHEQ T Shallow pulse test SonicScope w/ GPM
- 250, PSI - 860, 10% F/O (good). B/D
TD.
2,269.0 2,269.0
10/7/2023
17:15
10/7/2023
17:30
0.25 PROD1, WHPST TRIP T RIH w/ whipstock assembly from 2,269'
MD to 2,740' MD. Monitor disp via pit
1. S/O WT - 80K.
2,269.0 2,740.0
10/7/2023
17:30
10/7/2023
18:00
0.50 PROD1, WHPST DHEQ T Shallow pulse test SonicScope to re-
confirm tool was activated w/ GPM -
250, PSI - 860, 10% F/O (good). B/D
TD.
2,740.0 2,740.0
10/7/2023
18:00
10/7/2023
19:00
1.00 PROD1, WHPST SFTY T Conduct safety stand up with rig crews.
Emphasizing the importance of asking
questions, acquiring help when needed,
and speaking up if unsure of any task
that's asked of you.
2,740.0 2,740.0
10/7/2023
19:00
10/8/2023
00:00
5.00 PROD1, WHPST TRIP T RIH w/ whipstock assembly from 2,740'
MD to 8,392' MD. Monitor disp via pit
1. S/O WT - 82K.
2,740.0 8,392.0
10/8/2023
00:00
10/8/2023
03:30
3.50 PROD1, WHPST TRIP T RIH w/ whipstock assembly from 8,392'
MD to 11,789' MD. Monitor disp via pit
1. S/O WT - 101K. Fill pipe every 20
stds.
8,392.0 11,789.0
10/8/2023
03:30
10/8/2023
05:30
2.00 PROD1, WHPST WPST T Kelly up and wash dn and orient
whipstock to 43° R w/ 245 GPM, 2004
PSI, 12% F/O. UP WT - 139K, S/O WT
- 98K. Set anchor w/ 10K dn wt. Pick
up 10K over to confirm anchor set.
Attempt to shear 35K brass bolt. Slack
off to block weight and gradually pick up
to 40K over (worked string 7x).
Continue to work string and pump Hi-Vis
drill bead pill to assist. On 9th up stroke
to 184K observe shear out, prior to
beads leaving the mill assembly.
SIMOPS - obtain spr's @ 11,888' MD.
11,798.0 11,924.0
10/8/2023
05:30
10/8/2023
13:30
8.00 PROD1, WHPST MILL T Mill window from 11,906' MD to 11,920'
MD w/ GPM - 250, PSI - 2105, RPM -
70-90, TQ - 6-14K, F/O - 10%. WOB - 2
-5K. UP WT - 139K, S/O WT - 98K,
ROT WT - 124K. Pump super sweep
pills every 5'.
11,906.0 11,920.0
10/8/2023
13:30
10/8/2023
16:15
2.75 PROD1, WHPST DDRL T Drill new formation from 11,920' MD to
11,945' MD w/ GPM - 250, PSI - 2105,
RPM - 70-90, TQ - 6-14K, F/O - 10%.
WOB - 2-5K. UP WT - 139K, S/O WT -
98K, ROT WT - 124K.
11,920.0 11,945.0
10/8/2023
16:15
10/8/2023
17:00
0.75 PROD1, WHPST BKRM T BROOH @ GPM - 250, PSI - 2445,
RPM - 110, TQ - 7K, F/O - 11%. Work
through window x2 observe no issues.
Kill pump and rot and pass through
window observing slight overpull.
11,945.0 11,945.0
Rig: DOYON 142
RIG RELEASE DATE 10/21/2023
Page 29/37
1C-158
Report Printed: 11/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/8/2023
17:00
10/8/2023
18:00
1.00 PROD1, WHPST MILL T Engage rot and pumps @ GPM - 250,
PSI - 2500, RPM - 70, TQ - 5.7K, F/O -
11%. Dress window from 11,906' MD to
11,930' MD. Kill rot and pump out to
11,899' MD working string back dn to
11,945' MD. Pump out again to 11,905'
MD. Kill pump and slack off to 11,945'
MD. POOH to 11,861' MD. Total
passes after dressing (5), observing no
obstructions.
11,945.0 11,861.0
10/8/2023
18:00
10/8/2023
19:45
1.75 PROD1, WHPST FIT T FIT to 15.1 EMW. Pressure up to 1230
psi @ ½ bpm w/ 9.2 ppg. Shut in and
observe psi bleed dn to 925 in 10 min.
3 bbs to pressure up and 2.6 bbls bled
back. R/D and blow down test
equipment.
SIMOPS - obtain SPR's while rigging up
at 11,861' MD.
11,861.0 11,861.0
10/8/2023
19:45
10/9/2023
00:00
4.25 PROD1, WHPST TRIP T POOH on elevators from 11,861' MD to
6,499' MD. Monitor disp via TT.
SIMOPS - inject 3 bbls of 6.8 ppg diesel
into the 10-3/4" x 7-5/8" OA. Observe
776 psi (14.4 EMW) break over. Final
psi 710 psi. Observe psi drop to 446 in
20 min.
11,861.0 6,499.0
10/9/2023
00:00
10/9/2023
03:45
3.75 PROD1, WHPST TRIP T POOH on elevators from 6499' MD to
453' MD. Monitor disp via TT.
6,499.0 453.0
10/9/2023
03:45
10/9/2023
04:00
0.25 PROD1, WHPST OWFF T OWFF (static). SIMOPS - PJSM on L/D
BHA.
453.0 453.0
10/9/2023
04:00
10/9/2023
05:30
1.50 PROD1, WHPST BHAH T L/D milling BHA as per Baker reps. 453.0 0.0
10/9/2023
05:30
10/9/2023
07:30
2.00 PROD1, WHPST BHAH T Clear and clean rig floor from BHA
components and metal swarf.
0.0 0.0
10/9/2023
07:30
10/9/2023
08:30
1.00 PROD1, WHPST WWWH T M/U stack flushing tool and flush
stack/wellhead w/ 850 gpm, 140 PSI, 5
RPM. B/D choke and kill lines. Repeat
flushing sequence.
SIMOPS - Weekly function of the
Annular, Upper & Lower pipe rams,
Blind Shear rams, HCR choke and Kill.
0.0 0.0
10/9/2023
08:30
10/9/2023
11:30
3.00 PROD1, WHPST BHAH T M/U 6¾" motor BHA as per SLMB
DD/MWD to 659' MD. Monitor disp via
TT.
0.0 659.0
10/9/2023
11:30
10/9/2023
13:15
1.75 PROD1, WHPST TRIP T RIH w/ 4" DP from the derrick to 3,024'
MD. Monior disp via TT. S/O WT - 74K
659.0 3,024.0
10/9/2023
13:15
10/9/2023
13:30
0.25 PROD1, WHPST DHEQ T Shallow pulse test MWD (good) w/ 250
GPM, 1290 PSI, 9% F/O, P/U WT - 80K,
S/O WT - 74K. B/D TD.
3,024.0 3,024.0
10/9/2023
13:30
10/9/2023
20:00
6.50 PROD1, WHPST TRIP T Cont to RIH. Fill pipe every 25 stds.
B/D TD after every fill. Monitor disp via
TT.
3,024.0 11,891.0
10/9/2023
20:00
10/9/2023
20:45
0.75 PROD1, WHPST CIRC T Orient mud motor to 37° R w/ 250 GPM,
2432 PSI, 9% F/O.
11,891.0 11,891.0
10/9/2023
20:45
10/9/2023
21:00
0.25 PROD1, DRILL TRIP T RIH from 11,891' MD to 11,945' MD.
Observe no drag going across window.
Observed slight 3-5K drag once bit hit
under gauged hole @ 11,932' MD. Tag
bottom w/ 8K.
11,891.0 11,945.0
Rig: DOYON 142
RIG RELEASE DATE 10/21/2023
Page 30/37
1C-158
Report Printed: 11/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/9/2023
21:00
10/10/2023
00:00
3.00 PROD1, DRILL DDRL T Drill 6¾" production hole from 11945'
MD to 12,072 MD 4,018’ TVD,10K
WOB, 250 GPM, 2662 PSI, 0-40 RPM,
7 TQ, 8% F/O, P/U WT 139K, S/O WT -
96K, RT - 115K.
11,945.0 12,072.0
10/10/2023
00:00
10/10/2023
00:30
0.50 PROD1, DRILL SRVY T Shoot survey. Confirming separation
from 1C-158PB.
SIMOPS - PJSM on displacement.
12,072.0 12,072.0
10/10/2023
00:30
10/10/2023
02:30
2.00 PROD1, DRILL DISP T Rot and recip pipe displacing wellbore to
9.0 ppg FLOPRO NT. Displace w/ GPM
- 250, PSI - 2502, F/O - 7%, RPM - 30,
TQ - 6K, ROT WT - 116K. Total stks
pumped - 5700 (574 bbls).
12,072.0 11,979.0
10/10/2023
02:30
10/10/2023
02:45
0.25 PROD1, DRILL CIRC T Orient motor to 37° R. Obtain SPR's,
P/U WT - 157K, S/O WT - 103K.
11,979.0 11,979.0
10/10/2023
02:45
10/10/2023
03:00
0.25 PROD1, DRILL TRIP T POOH through the window observing no
obstructions.
SIMOPS - OWFF (static)
11,979.0 11,882.0
10/10/2023
03:00
10/10/2023
11:00
8.00 PROD1, DRILL TRIP T POOH racking back 4" HWDP/DP from
11,882' MD to 659' MD. Monitor disp via
TT.
11,882.0 659.0
10/10/2023
11:00
10/10/2023
11:15
0.25 PROD1, DRILL OWFF T OWFF (static) - SIMOPS - PJSM on
L/D BHA.
659.0 659.0
10/10/2023
11:15
10/10/2023
14:15
3.00 PROD1, DRILL BHAH T L/D 6¾" motor assembly BHA as per
SLMB DD/MWD. Monitor disp via TT.
659.0 0.0
10/10/2023
14:15
10/10/2023
15:30
1.25 PROD1, DRILL BHAH T Clear and clean rig floor. SIMOPS -
Service DW, TD, ST-100.
0.0 0.0
10/10/2023
15:30
10/10/2023
17:00
1.50 PROD1, DRILL BHAH T M/U 6¾" RSS (BHA #9) as per SLMB
DD/MWD to 167' MD.
0.0 167.0
10/10/2023
17:00
10/10/2023
19:00
2.00 PROD1, DRILL TRIP T RIH from the derrick to 2,532' MD. S/O
WT - 71K. Monitor disp via TT.
167.0 2,532.0
10/10/2023
19:00
10/10/2023
19:15
0.25 PROD1, DRILL DHEQ T Shallow hole test MWD w/ 250 GPM,
1230 PSI, 9% F/O.
2,532.0 2,532.0
10/10/2023
19:15
10/10/2023
22:15
3.00 PROD1, DRILL TRIP T Continue to RIH from the derrick to
7,730' MD. S/O WT - 73K. Monitor disp
via TT.
2,532.0 7,730.0
10/10/2023
22:15
10/11/2023
01:15
3.00 PROD1, DRILL PULD T Continue to RIH picking up 4" drill pipe
1x1 to 9,144 MD. S/O WT - 68K.
Monitor disp via TT.
7,730.0 9,144.0
10/11/2023
00:00
10/11/2023
04:00
4.00 PROD1, DRILL PULD T Continue to RIH picking up 4" drill pipe
1x1 from 9,144' MD to 11,891' MD. S/O
WT - 68K. Monitor disp via TT.
9,144.0 11,891.0
10/11/2023
04:00
10/11/2023
04:30
0.50 PROD1, DRILL CIRC T Obtain SPR's and UP WT - 125K. S/O
WT - 74K.
SIMOPS - build stand in the mousehole.
11,891.0 11,891.0
10/11/2023
04:30
10/11/2023
05:00
0.50 PROD1, DRILL TRIP T Cont to RIH sliding across window.
Observe 7-8K drag going across the
window. At first stab observe 12K drag
@ 12,028' MD. Stop and pick up to
12,016 to clear stab from window.
Engage mud pump to 2 bpm, 420 psi
and observe 2-3K drag across window.
Continue to btm and tag btm w/ 8K.
11,891.0 12,072.0
10/11/2023
05:00
10/11/2023
05:30
0.50 PROD1, DRILL SRVY T Obtain survey per DDX w/ 250 GPM,
1850 PSI.
12,072.0 12,072.0
10/11/2023
05:30
10/11/2023
12:00
6.50 PROD1, DRILL DDRL T Drill 6¾” production hole from 12,072‘
MD to 12,345‘ MD 4018’ TVD, 15K
WOB, 250 GPM, 2058 PSI, 100 RPM,
8KTQ, 9% F/O, 10.44 ECD, P/U 126K,
S/O 75K, RT 97K.
12,072.0 12,345.0
Rig: DOYON 142
RIG RELEASE DATE 10/21/2023
Page 31/37
1C-158
Report Printed: 11/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/11/2023
12:00
10/11/2023
18:00
6.00 PROD1, DRILL DDRL T Drill 6¾” production hole from 12,345‘
MD to 12,760‘ MD 4,018’ TVD, 15K
WOB, 265 GPM, 2345 PSI, 120 RPM,
8K TQ, 10% F/O, 10.60 ECD, P/U 121K,
S/O 70K, RT 90K.
12,345.0 12,760.0
10/11/2023
18:00
10/12/2023
00:00
6.00 PROD1, DRILL DDRL T Drill 6¾” production hole from 12,760‘
MD to 13,307‘ MD 4,000’ TVD, 3K
WOB, 265 GPM, 2218 PSI, 120 RPM,
8K TQ, 10% F/O, 10.83 ECD, P/U 123K,
S/O 69K, RT 92K.
Aquire ½ vis cup of metal shavings from
the ez magnets in the trough.
12,760.0 13,307.0
10/12/2023
00:00
10/12/2023
06:00
6.00 PROD1, DRILL DDRL T Drill 6¾” production hole from 13,307‘
MD to 13,650‘ MD 3,992’ TVD, 1K
WOB, 265 GPM, 2245 PSI, 120 RPM,
8K TQ, 10% F/O, 10.78 ECD, P/U 125K,
S/O 69K, RT 92K.
13,307.0 13,650.0
10/12/2023
06:00
10/12/2023
09:45
3.75 PROD1, DRILL DDRL T Drill 6¾” production hole from 13,650‘
MD to 13,961‘ MD 3,983’ TVD, 2K
WOB, 265 GPM, 2303 PSI, 120 RPM,
8K TQ, 10% F/O, 11.00 ECD, P/U 125K,
S/O 68K, RT 92K.
At 13,870' MD begin to experience
magnetic interference with surveys due
to fish left in the hole.
13,650.0 13,961.0
10/12/2023
09:45
10/12/2023
10:45
1.00 PROD1, DRILL BKRM T BROOH to 13,775' MD to reshoot
surveys due to magnetic interference w/
265 GPM, 2284 PSI, 40 RPM, 6K TQ,
9% F/O, 10.77 ECD, UP WT @ RT -
88K.
13,961.0 13,775.0
10/12/2023
10:45
10/12/2023
11:15
0.50 PROD1, DRILL SRVY T RIH from 13,775' MD to 13,961' MD
taking 45' surveys.
13,775.0 13,961.0
10/12/2023
11:15
10/12/2023
12:00
0.75 PROD1, DRILL DDRL T Drill 6¾” production hole from 13,961‘
MD to 13,968‘ MD 3,982’ TVD, 2K
WOB, 265 GPM, 2305 PSI, 120 RPM,
8K TQ, 9% F/O, 10.95 ECD, P/U 119K,
S/O 65K, RT 90K. Max gas - 365 units.
Continue to experience poor surveys
due to magnetic interference from fish
left in the hole.
13,961.0 13,968.0
10/12/2023
12:00
10/12/2023
18:00
6.00 PROD1, DRILL DDRL T Drill 6¾” production hole from 13,968‘
MD to 14,295‘ MD 3,974’ TVD, 1K
WOB, 265 GPM, 2285 PSI, 120 RPM,
7K TQ, 8% F/O, 11.01 ECD, P/U 1217K,
S/O 61K, RT 89K. Max gas - 268
Continue to experience poor surveys
due to magnetic interference from fish
left in the hole. Obtain clean survey at
14,142' MD.
13,968.0 14,295.0
10/12/2023
18:00
10/12/2023
23:15
5.25 PROD1, DRILL DDRL T Drill 6¾” production hole from 14,295‘
MD to 14,440‘ MD 3,973’ TVD, 1K
WOB, 265 GPM, 2285 PSI, 120 RPM,
7K TQ, 8% F/O, 11.01 ECD, P/U 117K,
S/O 61K, RT 89K. Max gas - 37
14,295.0 14,440.0
Rig: DOYON 142
RIG RELEASE DATE 10/21/2023
Page 32/37
1C-158
Report Printed: 11/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/12/2023
23:15
10/13/2023
00:00
0.75 PROD1, DRILL BKRM T BROOH to 14,250' MD to re shoot
surveys to confirm DLS° w/ 265 GPM,
2317 PSI, 120 RPM, 7K TQ, 10% F/O,
10.95 ECD, UP WT @ RT - 86K.
Re Shoot surveys at 14,250' and
14,350' MD.
Acquire 3/4 vis cup of metal shavings
from the ez magnets in the trough past
24 hrs.
13,961.0 13,775.0
10/13/2023
00:00
10/13/2023
00:45
0.75 PROD1, DRILL REAM T Wash and ream dn to 14,440' MD w/
100 GPM, 745 PSI, 60 RPM, .5K TQ,
5% F/O, S/O WT @ RT - 91K.
14,250.0 14,440.0
10/13/2023
00:45
10/13/2023
06:00
5.25 PROD1, DRILL DDRL T Drill 6¾” production hole from 14,440‘
MD to 14,885‘ MD 3,970’ TVD, 1.5K
WOB, 265 GPM, 2457 PSI, 120 RPM,
7.5K TQ, 10% F/O, 11.21 ECD, P/U
122K, S/O 59K, RT 89K. Max gas -
405.
14,440.0 14,885.0
10/13/2023
06:00
10/13/2023
12:00
6.00 PROD1, DRILL DDRL T Drill 6¾” production hole from 14,885‘
MD to 14,921‘ MD 3,969’ TVD, 1.5K
WOB, 280 GPM, 2650 PSI, 120 RPM,
7.5K TQ, 9% F/O, 11.23 ECD, P/U
122K, S/O 59K, RT 89K. Max gas - 20
14,885.0 14,921.0
10/13/2023
12:00
10/13/2023
18:00
6.00 PROD1, DRILL DDRL T Drill 6¾” production hole from 14,921‘
MD to 15,278‘ MD 3,964’ TVD, 3K
WOB, 280 GPM, 2640 PSI, 120 RPM,
7.5K TQ, 9% F/O, 11.29 ECD, P/U
121K, S/O NA, RT 89K. Max gas - 482
14,921.0 15,278.0
10/13/2023
18:00
10/14/2023
00:00
6.00 PROD1, DRILL DDRL T Drill 6¾” production hole from 15,278‘
MD to 15,557‘ MD 3,959’ TVD, 1K
WOB, 280 GPM, 2668 PSI, 110 RPM,
7K TQ, 9% F/O, 11.29 ECD, P/U 121K,
S/O NA, RT 88K. Max gas - 57
Acquire 1/2 vis cup of metal shavings
from the ez magnets in the trough past
24 hrs.
15,278.0 15,557.0
10/14/2023
00:00
10/14/2023
07:00
7.00 PROD1, DRILL DDRL T Drill 6¾” production hole from 15,557‘
MD to 15,821‘ MD 3,954’ TVD, 1K
WOB, 280 GPM, 2725 PSI, 140 RPM,
7K TQ, 9% F/O, 11.36 ECD, P/U 120K,
S/O NA, RT 94K. Max gas - 212
Observe excessive tq and
poor/inconsistant Azimuth surveys.
Decision made to POOH and recheck
surveys.
15,557.0 15,821.0
10/14/2023
07:00
10/14/2023
09:00
2.00 PROD1, DRILL BKRM T BROOH to 15,479' MD w/ 280 GPM,
2669 PSI, 120 RPM, 6K TQ, 8% F/O,
11.18 ECD, P/U @ RT - 85K,
15,821.0 15,479.0
10/14/2023
09:00
10/14/2023
10:30
1.50 PROD1, DRILL REAM T Ream in the hole to 15,821' MD taking
45' survey check shots w/ 280 GPM,
2674 PSI, 120 RPM, 6K TQ, 8% F/O,
11.18 ECD, S/O @ RT - 90K
15,479.0 15,821.0
10/14/2023
10:30
10/14/2023
13:00
2.50 PROD1, DRILL CIRC T While drilling ahead to 15,826' MD
observe excessive tq and failed survey.
Stop drilling. Rot and recip pipe from
15,821' MD to 15,773' MD w/ 280 GPM,
2686 PSI, 110 RPM, 6K TQ, 10% F/O,
11.19 ECD.
SIMOPS - Pump low/hi vis sweep s/s.
Decision made to POOH due to
downhole anomolies.
15,821.0 15,773.0
Rig: DOYON 142
RIG RELEASE DATE 10/21/2023
Page 33/37
1C-158
Report Printed: 11/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/14/2023
13:00
10/14/2023
13:30
0.50 PROD1, DRILL OWFF T OWFF (static) 15,733.0 15,733.0
10/14/2023
13:30
10/15/2023
00:00
10.50 PROD1, DRILL BKRM T BROOH with NOVOS from 15,733' MD
to 12,800' MD w/ 280 GPM, ICP 2636,
FCP - 2372, 100 RPM, 6K TQ, 10%
F/O, (I)ECD 11.00, (F)ECD - 10.78, P/U
WT @ RT - 88K
Acquire 1 vis cup of metal shavings from
the ez magnets in the trough past 24
hrs.
Total metal shavings from well = 2 vis
cups
15,733.0 12,800.0
10/15/2023
00:00
10/15/2023
04:00
4.00 PROD1, DRILL BKRM T BROOH with NOVOS from 12,800' MD
to 12,080' MD w/ 280 GPM, 2375 PSI,
100 RPM, 5.5K TQ, 10% F/O, ECD -
10.78, UP WT - 114K. P/U WT @ RT -
88K
12,800.0 12,080.0
10/15/2023
04:00
10/15/2023
05:30
1.50 PROD1, DRILL PMPO T Attempt to pull up inside the window w/
280 GPM, 2237 PSI, 10% F/O and
observe 25K overpull @ 12,063' MD.
Work overpull up to 35K w/o success.
Downlink powerdrive to neutral and
attempt to pull through obstruction
(failed). Attempt to pull w/o pumps
(failed). Attempt to rotate string 1/4
turns (failed). Verify pipe count and
BHA placement at the window. Attempt
to BROOH past obstruction w/ 30 RPM
and 280 GPM (failed). Decision made
to RIH and complete wellbore clean up
cycle.
12,080.0 12,063.0
10/15/2023
05:30
10/15/2023
06:00
0.50 PROD1, DRILL REAM T Wash and ream in the hole to 12,170'
MD w/ 280 GPM, 2415 PSI, 120 RPM,
5K TQ, 10% F/O, ECD - 10.85, S/O WT
@ RT - 77K.
12,080.0 12,170.0
10/15/2023
06:00
10/15/2023
08:00
2.00 PROD1, DRILL CIRC T Rot and recip pipe from 12,170' MD to
12,076' MD w/ 280 GPM, 2409 PSI,
120 RPM, 5K TQ, 10% F/O, ECD -
10.86, P/U WT @ RT - 86K, S/O WT @
RT - 91K
Pump 25 bbl Hi-Vis BHA scouring
sweep followed by 35 bbls Lo-Vis
erosion sweep s/s.
12,170.0 12,076.0
10/15/2023
08:00
10/15/2023
09:15
1.25 PROD1, DRILL TRIP T Attempt to pull up into the 7-5/8" csg.
UP WT - 114K. Observe 25K overpull
at 12,062' MD. Attempt 3x failed. Put
1/4 turn in string and attempt to pull past
12,062 and successfully pull past
obstruction. Observe 30K overpull at
11,999' MD. Put 1/4 turn into string and
attempt to pull past w/ no success. Put
additional 1/4 turn in string and pull 45K
over and successfully pull past
obstruction up to 11,885' MD.
12,076.0 11,885.0
10/15/2023
09:15
10/15/2023
11:15
2.00 PROD1, DRILL CIRC T Rot and recip pipe from 11,885' MD to
11,789' MD w/ 280 GPM, 2285 PSI, 100
RPM, 5K TQ, 8% F/O, ECD - 10.69,
P/U WT A RT - 95K, S/O WT @ RT -
91K. Total stks pumped - 5300 (533
bbls)
Pump 35 bbl Hi-Vis BHA scouring
sweep.
11,885.0 11,789.0
10/15/2023
11:15
10/15/2023
11:30
0.25 PROD1, DRILL OWFF T OWFF (static) 11,789.0 11,789.0
Rig: DOYON 142
RIG RELEASE DATE 10/21/2023
Page 34/37
1C-158
Report Printed: 11/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/15/2023
11:30
10/15/2023
19:15
7.75 PROD1, DRILL TRIP T POOH to BHA at 170' MD. Monitor disp
via TT.
11,789.0 170.0
10/15/2023
19:15
10/15/2023
21:15
2.00 PROD1, DRILL BHAH T L/D production #2 BHA as per SLMB
DDX from 170' MD. Monitor disp via TT.
170.0 0.0
10/15/2023
21:15
10/16/2023
00:00
2.75 PROD1, DRILL BHAH T Clean and clear rig floor. Expedite
Baker clean out BHA to the rig floor.
Strap and tally 4" HWDP, Baker
magnets, and Baker jewelry for clean
out run.
Acquire ½ vis cup of metal shavings
from the ez magnets in the trough past
24 hrs.
Total metal shavings from well = 2 vis
cups
0.0 0.0
10/16/2023
00:00
10/16/2023
01:45
1.75 PROD1, DRILL BHAH T PJSM, Pick up milling/clean out
assembly as per Baker to 121' MD.
Monitor disp via pit #5.
0.0 121.0
10/16/2023
01:45
10/16/2023
09:30
7.75 PROD1, DRILL TRIP T RIH to 11,878' MD. S/O WT - 101K.
Monitor disp via pit #5. Fill pipe every
20 stds. B/D after ea fill.
121.0 11,878.0
10/16/2023
09:30
10/16/2023
10:30
1.00 PROD1, DRILL REAM T Obtain perameters w/ GPM - 130, PSI -
760, GPM - 250 - 1880, RPM - 50, 6K
TQ, P/U WT - 149K, S/OWT - 103K,
ROT WT - 121K. Attempt to s/o through
window w/o pumps and observe 25K
drag @ 11,957' MD. Wash and ream
through 11,957' MD. Successfully work
past 11,957 w/o pumps and rot.
Continue to RIH and observe excessive
s/o at 12,063' MD.
11,878.0 12,063.0
10/16/2023
10:30
10/16/2023
12:00
1.50 PROD1, DRILL REAM T Wash and ream from 12,063' MD to
12,400' MD w/ GPM - 130, PSI - 730,
RPM - 50, 5K TQ, 5% F/O, ROT WT @
RT - 123K.
12,063.0 12,400.0
10/16/2023
12:00
10/16/2023
12:30
0.50 PROD1, DRILL TRIP T RIH on elevators and confirm no
obstructions down to 12,674' MD. S/O
WT - 103K.
12,400.0 12,674.0
10/16/2023
12:30
10/16/2023
15:15
2.75 PROD1, DRILL BKRM T BROOH from 12,674' MD to 11,846' MD
GPM - 250, PSI - 1800, RPM - 50, 5K
TQ, 8% F/O, ROT WT @ RT - 119K.
SIMOPS - Pump hi-vis sweep.
12,674.0 11,846.0
10/16/2023
15:15
10/16/2023
18:45
3.50 PROD1, DRILL CIRC T Circ csg clean. Rot and recip pipe from
11,846' MD to 11,749' MD w/ GPM -
250, PSI - 1885, RPM - 100, 5K TQ, 8%
F/O, ROT WT @ RT - 114K Up, 117K
Dn. Total stks pumped - 15,650 (1576
bbls). SIMOPS - pump 2ea hi-vis
sweeps.
SIMOPS - L/D 15 stds 4" DP via 90'
mousehole.
11,846.0 11,749.0
10/16/2023
18:45
10/16/2023
19:30
0.75 PROD1, DRILL OWFF T OWFF (static) 11,846.0 11,846.0
10/16/2023
19:30
10/16/2023
19:45
0.25 PROD1, DRILL CIRC T Pump slug and drop 1.76 OD hollow
rabbit w/ 97' tail into string after pumping
slug.
11,846.0 11,846.0
10/16/2023
19:45
10/17/2023
00:00
4.25 PROD1, DRILL TRIP T POOH to 3,800' MD. Monitor disp via
TT. P/U WT - 85K.
Acquire ǩ vis cup of metal shavings
from the ez magnets in the trough past
24 hrs.
Total metal shavings from well = 2ǩ vis
cups
11,846.0 3,800.0
Rig: DOYON 142
RIG RELEASE DATE 10/21/2023
Page 35/37
1C-158
Report Printed: 11/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/17/2023
00:00
10/17/2023
02:45
2.75 PROD1, DRILL TRIP T Continue to POOH from 3,800' MD to
180' MD. Monitor disp via TT. P/U WT -
48K
3,800.0 180.0
10/17/2023
02:45
10/17/2023
04:15
1.50 PROD1, DRILL TRIP T L/D cleanout BHA from 180' MD.
Monitor disp via TT. Clean and clear rig
floor.
180.0 0.0
10/17/2023
04:15
10/17/2023
06:00
1.75 COMPZN, CASING RURD P R/U to run 4½" 12.6# L-80 Hyd563
Liner.
0.0 0.0
10/17/2023
06:00
10/17/2023
06:45
0.75 COMPZN, CASING SFTY P PJSM on running liner. Confirm pipe
count in pipeshed.
0.0 0.0
10/17/2023
06:45
10/17/2023
12:00
5.25 COMPZN, CASING PUTB P Run 4½" 12.6# L-80 Hyd563 Liner as
per detail to 3,862' MD. M/U tq to 7000
ft/lbs. Use BOL 2000 pipe dope.
Install .26 centralizers P/N 80590-02 on
ea jt (92 total) Monitor disp via TT. S/O
WT - 72K.
0.0 3,862.0
10/17/2023
12:00
10/17/2023
12:30
0.50 COMPZN, CASING OTHR P P/U SBE & SLZXP as per Baker reps.
Fill tieback sleeve with Zanplex D. RIH
to 3,926' MD.
3,862.0 3,926.0
10/17/2023
12:30
10/17/2023
12:45
0.25 COMPZN, CASING RUNL P RIH 1 std and obtain parameters @
4,020' MD. P/U WT - 78K, S/O WT -
75K, ROT WT - 77K, 20 RPM - 2K, 30
RPM - 2K.
3,926.0 4,020.0
10/17/2023
12:45
10/17/2023
13:45
1.00 COMPZN, CASING RURD P R/D Doyon Csg, Clean and clear rig
floor of thread protectors, and excess
Baker equipement.
4,020.0 4,020.0
10/17/2023
13:45
10/17/2023
15:15
1.50 COMPZN, CASING RGRP T Repair Iron Roughneck. C/O cables for
make up/break out solenoid.
4,020.0 4,020.0
10/17/2023
15:15
10/17/2023
20:30
5.25 COMPZN, CASING RUNL P RIH w/ 4½" 12.6# L-80 Hyd563 Liner on
4" DP to 11,771' MD. S/O WT - 91K.
Monitor disp via pit #1.
4,020.0 11,771.0
10/17/2023
20:30
10/18/2023
00:00
3.50 COMPZN, CASING RUNL P RIH w/ 4½" 12.6# L-80 Hyd563 Liner on
4" HWDP to 15,283' MD. S/O WT 92K.
Monitor disp via pit #1. Obtain T&D
every 5th std w/ 20-30 rpm w/ 5-5.5K
TQ.
11,771.0 15,283.0
10/18/2023
00:00
10/18/2023
00:30
0.50 COMPZN, CASING RUNL P RIH w/ 4½" 12.6# L-80 Hyd563 Liner on
4" HWDP from 15,283' MD to 15,662.
S/O WT 91K. Monitor disp via pit #1.
Obtain T&D every 5th std w/ 20-30 rpm
w/ 5-5.5K TQ.
15,283.0 15,662.0
10/18/2023
00:30
10/18/2023
01:30
1.00 COMPZN, CASING CIRC P Space out per Baker to shoe depth of
15,650' MD. S/O WT - 91K, UP WT -
161K. Pump 10 bbl h-vis sweep,
followed by string volume @ 3.5 bpm,
150 gpm, 1000 psi, 5% F/O. Total stks
pumped - 1295 (130 bbls).
15,662.0 15,650.0
10/18/2023
01:30
10/18/2023
02:45
1.25 COMPZN, CASING OTHR P Drop 1.125 OD ball. Chase ball w/ 10
bbl hi-vis sweep. Pump dn @ 3 bpm,
127 gpm, 820 psi. Reduce rate to 2
bpm @ 850 stks, 605 psi. Ball on seat
@ 915 stks. Pressure up to 2500 psi.
Hold for 2 min. Slack off to 50K to
confirm pkr set. Pressure up to 3906 to
blow ball seat. P/U to verify released
from liner. Confirm with 149K up wt.
15,650.0 15,650.0
10/18/2023
02:45
10/18/2023
03:45
1.00 COMPZN, CASING PRTS P PT SLZXP to 3500 psi for 30 charted
min (good).
15,650.0 15,650.0
10/18/2023
03:45
10/18/2023
05:45
2.00 COMPZN, WELLPR DISP P Pickup to 11,806' MD and displace
wellbore to 9.2 CI brine @ 250 gpm,
1740 psi, 7% f/o. Total stks pumped -
5440 (548 bbls).
11,806.0 11,806.0
10/18/2023
05:45
10/18/2023
06:00
0.25 COMPZN, WELLPR OWFF P OWFF (static) 11,806.0 11,806.0
Rig: DOYON 142
RIG RELEASE DATE 10/21/2023
Page 36/37
1C-158
Report Printed: 11/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/18/2023
06:00
10/18/2023
20:00
14.00 COMPZN, WELLPR PULD P POOH L/D 4" HWDP/DP. Monitor disp
via TT. P/U WT - 96K.
11,806.0 0.0
10/18/2023
20:00
10/18/2023
20:15
0.25 COMPZN, WELLPR BHAH P L/D Baker running tool. 0.0 0.0
10/18/2023
20:15
10/18/2023
20:45
0.50 COMPZN, WELLPR BHAH P Clean and clear rig floor. Prep for L/D
dp via mousehole.
0.0 0.0
10/18/2023
20:45
10/18/2023
21:15
0.50 COMPZN, WELLPR SVRG P Service iron roughneck and pipeshed
skate
0.0 0.0
10/18/2023
21:15
10/19/2023
00:00
2.75 COMPZN, WELLPR PULD P PJSM, L/D 10 stds 4" DP via
mousehole. L/D 10 stds 4" HWDP.
Monitor wellbore via TT.
0.0 0.0
10/19/2023
00:00
10/19/2023
07:00
7.00 COMPZN, WELLPR PULD P L/D 55 stds 4" DP via mousehole.
Monitor wellbore via TT.
0.0 0.0
10/19/2023
07:00
10/19/2023
08:15
1.25 COMPZN, WELLPR WWWH P M/U stack flushing tool. Flush stack w/
630 gpm, 60 psi, 30 rpm.
SIMOPS - Function test BOPE.
0.0 0.0
10/19/2023
08:15
10/19/2023
08:30
0.25 COMPZN, WELLPR RURD P Pull wear bushing as per Vault rep. 0.0 0.0
10/19/2023
08:30
10/19/2023
10:00
1.50 COMPZN, RPCOMP RURD P R/U Doyon csg to run 4½" 12.6# L-80
Hyd563 upper completion.
0.0 0.0
10/19/2023
10:00
10/19/2023
14:30
4.50 COMPZN, RPCOMP PUTB P RIH w/ 4½" 12.6# L-80 Hyd563 upper
completion as per detail to 1,753' MD.
Tq connections to 3800 ft/lbs. Fill on the
fly and top off every 20 jts. Monitor disp
via pit #1.
0.0 1,753.0
10/19/2023
14:30
10/19/2023
16:00
1.50 COMPZN, RPCOMP RGRP T Trouble shoot pipe skate controls.
Electrician contacted NOV. Problem
corrected itself.
1,753.0 1,753.0
10/19/2023
16:00
10/20/2023
00:00
8.00 COMPZN, RPCOMP PUTB P RIH w/ 4½" 12.6# L-80 Hyd563 upper
completion as per detail from 1,753' MD
to 11,017' MD. S/O WT - 72K. Tq
connections to 3800 ft/lbs. Fill on the fly
and top off every 10 jts. Monitor disp via
pit #1.
1,753.0 11,017.0
10/20/2023
00:00
10/20/2023
01:00
1.00 COMPZN, RPCOMP PUTB P RIH w/ 4½" 12.6# L-80 Hyd563 upper
completion as per detail from 11,017'
MD to 11,716' MD. P/U WT - 110K, S/O
WT - 71K. Tq connections to 3800
ft/lbs. Fill on the fly and top off every 10
jts. Monitor disp via pit #1.
11,017.0 11,716.0
10/20/2023
01:00
10/20/2023
02:45
1.75 COMPZN, RPCOMP HOSO P RIH w/ jts 288 and 289. Tag no-go 24'
dn on jt 289. Flood lines and close
annulare. Pressure test IA to 200 psi
confirming seals are stabbed. POOH
and L/D jts 289, 288, & 287. P/U
spaceout pups 9.77, 1.93, & 9.73 and
RIH. P/U jt 287 and RIH to 11,738.08'
MD.
SIMOPS - Blow down choke and kill
lines. B/D hole fill line. Drain stack.
11,716.0 11,738.0
10/20/2023
02:45
10/20/2023
03:15
0.50 COMPZN, RPCOMP THGR P P/U landing jt M/U to tubing hanger.
M/U hanger to stump. RIH and land
hanger. RILDS. Shoe depth at
11,776.72' MD. NO-GO @ 11,747.01
(4.09 from fully located).
11,738.0 11,776.0
10/20/2023
03:15
10/20/2023
04:00
0.75 COMPZN, RPCOMP RURD P R/U to test TBG and IA.
SIMOPS - PT hanger seals to 5000 psi
for 15 min. CPAI rig supervisor
witnessed test.
11,776.0 11,776.0
10/20/2023
04:00
10/20/2023
04:15
0.25 COMPZN, RPCOMP PRTS P PT IA to 1000 confriming seals are
stabbed.
11,776.0 11,776.0
Rig: DOYON 142
RIG RELEASE DATE 10/21/2023
Page 37/37
1C-158
Report Printed: 11/9/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/20/2023
04:15
10/20/2023
06:45
2.50 COMPZN, RPCOMP PRTS P PT TBG to 3000 psi (good). Bleed dn
TBG to 2000. PT IA to 3000 psi (good).
Rapidly dump TBG psi and observe
SOV shear(3.1 bbls returned to the pits).
Confirm w/ pumping dn IA at 63 GPM
and observe returns to the pits.
11,776.0 11,776.0
10/20/2023
06:45
10/20/2023
07:15
0.50 COMPZN, RPCOMP OWFF P OWFF (static). SIMOPS - R/D testing
equipment and L/D landing jt.
11,776.0 11,776.0
10/20/2023
07:15
10/20/2023
07:30
0.25 COMPZN, RPCOMP RURD P Install "HP" BPV as per Vault rep. 11,776.0 11,776.0
10/20/2023
07:30
10/20/2023
08:00
0.50 COMPZN, WHDBOP PRTS P PT BPV to 1500 psi from below (good), 11,776.0 11,776.0
10/20/2023
08:00
10/20/2023
16:00
8.00 COMPZN, WHDBOP NUND P Nipple down BOPE.
SIMOPS - Transport shop and parts
trailers to 3S.
0.0 0.0
10/20/2023
16:00
10/20/2023
19:00
3.00 COMPZN, WHDBOP NUND P Nipple up tree adapter and tree. 0.0 0.0
10/20/2023
19:00
10/20/2023
20:00
1.00 COMPZN, WHDBOP PRTS P Test tree with diesel to 250 low for 5
min, 5000 high for 15 min (good),
0.0 0.0
10/20/2023
20:00
10/20/2023
21:00
1.00 COMPZN, WHDBOP RURD P Rig up to freeze protect TBG and IA. 0.0 0.0
10/20/2023
21:00
10/21/2023
00:00
3.00 COMPZN, WHDBOP FRZP P PT lines to 3500. Freeze protect IA and
TBG dn to 2069' MD via LRS. Pump at
1.25 bpm, ICP - 200, FCP - 500. Total
bbls pumped - 90.
0.0 0.0
10/21/2023
00:00
10/21/2023
01:30
1.50 COMPZN, WHDBOP MPSP P Observe 50 psi on IA and TBG. R/U
lubricator and install "H" BPV and
secure well. Final pressures tubing = 50
psi, IA = 50 psi, OA = 0 psi
0.0 0.0
10/21/2023
01:30
10/21/2023
06:00
4.50 DEMOB, MOVE DMOB P R/D and prep for rig move. De-energize
steam lines and blow down same.
Disconnect electical interconnects on
modules. Fire up cold starts, Remove
beaverslide.
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 10/21/2023
Page 1/1
1C-158
Report Printed: 11/9/2023
Cement
Cement Details
Description
Surface String Cement
Cementing Start Date
9/6/2023 22:00
Cementing End Date
9/7/2023 01:00
Wellbore Name
1C-158
Comment
PT lines to 3500. 60 bbls of 10.2 mud push w/ poly flake and red dye. 331 bbls of 10.7 lead. 56 bbls 15.8 tail. Bump plug w/ 1674 stks (168.5 bbls). CIP @
00:55.
Cement Stages
Stage # 1
Description
Surface String Cement
Objective Top Depth (ftKB)
39.1
Bottom Depth (ftKB)
2,072.8
Full Return?
Yes
Vol Cement …
62.0
Top Plug?
Yes
Btm Plug?
Yes
Q Pump Init (bbl/m…
6
Q Pump Final (bbl/…
3
Q Pump Avg (bbl/…
6
P Pump Final (psi)
375.0
P Plug Bump (psi)
411.0
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
PT lines to 3500. 60 bbls of 10.2 mud push w/ poly flake and red dye. 331 bbls of 10.7 lead. 56 bbls 15.8 tail. Bump plug w/ 1674 stks (168.5 bbls). CIP @
00:55.
Cement Fluids & Additives
Fluid
Fluid Type
Lead Cement
Fluid Description Estimated Top (ftKB)
39.1
Est Btm (ftKB)
1,537.0
Amount (sacks)
652
Class
G
Volume Pumped (bbl)
331.0
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)
1,537.0
Est Btm (ftKB)
2,072.8
Amount (sacks)
275
Class
G
Volume Pumped (bbl)
56.0
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-158
Report Printed: 11/9/2023
Cement
Cement Details
Description
Intermediate String 1 Cement
Cementing Start Date
9/19/2023 23:00
Cementing End Date
9/20/2023 05:45
Wellbore Name
1C-158
Comment
Pump 5bbls fresh water. Test lines to 4000 psi. Load 1st bottom plug. Pump 58.9 bbls of spacer 4 bpm, 200 psi. 14% Flow out. Load 2nd bottom plug. (Cmt Wet
@ 0121 hrs) Batch up and pump 353 bbls 14.09 ppg Class G lead cement - pump rate 4.5 bpm, 420 psi, 17% Flow out.Switch over and pump 52 bbls 15.3 pgg
class G cement. Shut down Load top plug. Halliburton pump 20 bbls water. Swap to rig and displace with 9.5 ppg. LSND. @ 6 bpm 240 psi. 30% F/O. Decreased
rate to Strokes to slow pump to 5 BPM = 3538 STK
Strokes to slow pump to 4 BPM = 4034 STK Strokes to slow pump to 3 BPM = 4531 STK Strokes to slow pump to 2 BPM = 5027 STK Strokes to bump plug =
5548 STK
Final circ. psi. 1030 Pressure up to 1690 psi & hold for 5 minutes. Bleed off pressure, Check floats good. CIP 0545 hrs 01/20/23. 0 bbl. loss during cement job.
Cement Stages
Stage # 1
Description
Intermediate String 1
Cement
Objective Top Depth (ftKB)
2,491.0
Bottom Depth (ftKB)
12,635.3
Full Return?
Yes
Vol Cement …
0.0
Top Plug?
Yes
Btm Plug?
Yes
Q Pump Init (bbl/m…
1,070
Q Pump Final (bbl/…
1,690
Q Pump Avg (bbl/…
5
P Pump Final (psi)
2.0
P Plug Bump (psi)
1,690.0
Recip?
No
Stroke (ft) Rotated?
No
Pipe RPM (rpm)
Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in)
Comment
Pump 5bbls fresh water. Test lines to 4000 psi. Load 1st bottom plug. Pump 58.9 bbls of spacer 4 bpm, 200 psi. 14% Flow out. Load 2nd bottom plug. (Cmt Wet
@ 0121 hrs) Batch up and pump 353 bbls 14.09 ppg Class G lead cement - pump rate 4.5 bpm, 420 psi, 17% Flow out.Switch over and pump 52 bbls 15.3 pgg
class G cement. Shut down Load top plug. Halliburton pump 20 bbls water. Swap to rig and displace with 9.5 ppg. LSND. @ 6 bpm 240 psi. 30% F/O. Decreased
rate to Strokes to slow pump to 5 BPM = 3538 STK
Strokes to slow pump to 4 BPM = 4034 STK Strokes to slow pump to 3 BPM = 4531 STK Strokes to slow pump to 2 BPM = 5027 STK Strokes to bump plug =
5548 STK
Final circ. psi. 1030 Pressure up to 1690 psi & hold for 5 minutes. Bleed off pressure, Check floats good. CIP 0545 hrs 01/20/23. 0 bbl. loss during cement job.
Cement Fluids & Additives
Fluid
Fluid Type
Lead Cement
Fluid Description Estimated Top (ftKB)
3,905.0
Est Btm (ftKB)
11,328.3
Amount (sacks)
1,282
Class
G
Volume Pumped (bbl)
353.0
Yield (ft³/sack)
1.55
Mix H20 Ratio (gal/sack)
7.82
Free Water (%) Density (lb/gal)
14.00
Plastic Viscosity (cP)
16.0
Thickening Time (hr)
6.10
CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Fluid
Fluid Type
Tail Cement
Fluid Description Estimated Top (ftKB)
11,328.3
Est Btm (ftKB)
12,635.3
Amount (sacks)
238
Class
G
Volume Pumped (bbl)
53.0
Yield (ft³/sack)
1.24
Mix H20 Ratio (gal/sack)
5.57
Free Water (%) Density (lb/gal)
15.30
Plastic Viscosity (cP)
16.0
Thickening Time (hr)
4.50
CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Intermediate String 1 Cement
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Date: 2023.10.24 10:13:12-08'00'Foxit PhantomPDF Version: 10.1.4
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PTD: 223-056
1C-158: T38129
1C-158 PB1: T38130
Kayla Junke
11/15/2023
Kayla
Junke
Digitally signed by
Kayla Junke
Date: 2023.11.15
15:27:41 -09'00'
1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown
Suspend Perforate Other Stimulate Pull Tubing Change Approved Program
Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________
2. Operator Name:4. Current Well Class:5. Permit to Drill Number:
Exploratory Development
3. Address:Stratigraphic Service 6. API Number:
7. If perforating:8. Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool?
Yes No
9. Property Designation (Lease Number):10. Field:
Kuparuk River Field West Sak West Sak
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD:Junk (MD):
18298 3993 3993 1419 12870
Casing Collapse
Structural
Conductor
Surface 2470
Intermediate 4790
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: 10/5/2023 OIL WINJ WDSPL Suspended
16. Verbal Approval:Date:GAS WAG GSTOR SPLUG
AOGCC Representative: GINJ Op Shutdown Abandoned
Contact Name:Abby Warren
Contact Email:
Contact Phone: 907-240-9293
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
abby.warren@conocophillips.com
Staff Drilling Engineer
NA
Perforation Depth MD (ft):
12635
5702 6.75"
10-3/4"
155
7-5/8"12596
2033 2069
4039
2072
399318298
TVD BurstMD
6890
5210
ConocoPhillips
Length Size
Proposed Pools:
Perforation Depth TVD (ft):
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL025638 / ADL028242 / ADL047449 / ADL025649
223-056
P.O. Box 100360 Anchorage, Alaska, 99510-0360 50-029-23761-00-00
Tubing Size:
PRESENT WELL CONDITION SUMMARY
AOGCC USE ONLY
Tubing Grade:Tubing MD (ft):
1C-158
18298
Subsequent Form Required:
Suspension Expiration Date:
Will perfs require a spacing exception due to property boundaries?
Current Pools:
MPSP (psi):Plugs (MD):
17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval.
Authorized Name and Digital
Signature with Date:
Perforate
Repair Wepair Well
Exploratory Stratigraphic Development Service
BOP TestMechanical Integrity Test
No
Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
By Grace Christianson at 10:03 am, Oct 05, 2023
323-551
X
X
10/5/2023
VTL 10/16/2023 SFD 10/5/2023
file with PTD 10-407
DSR-10/5/23
SFD
X
Initial BOP test to 5000 psig
Subsequent BOP test to 3500 psig
Annular BOP test to 2500 psig
All conditions of approval on original approved PTD apply.
($8JLC 10/17/2023
Brett W.
Huber, Sr.
Digitally signed by Brett W.
Huber, Sr.
Date: 2023.10.17 21:09:32
-06'00'10/17/23
RBDMS JSB 101923
1C-158 AOGCC 10-401 APD 1 | 4
1C-158
PTD# 223-056
Application for Sundry Approval
Table of Contents
1.Overview ............................................................................................................................................... 2
2.Planned Operations ............................................................................................................................... 2
3.Present Well Schematic .......................................................................................................................... 3
4.Proposed Completion Schematic ............................................................................................................ 4
5.Area of Review....................................................................................................................................... 4
1C-158 AOGCC 10-401 APD 2 | 4
1. Overview
Doyon 142 was drilling the production later of well 1C-158 when a twist off of the drill pipe occurred. The BHA
was on bottom at 18,298’. The top of fish which is a combination of the drilling BHA and drill pipe is calculated
at ~12,870’. 3 attempts were made to retrieve the fish without success.
Planned operation will be to set a whipstock in the 7-5/8” casing and mill a window into the N mudstones.
From there the rig will redrill the production hole paralleling the existing wellbore and subsequently the fish
left in hole.
2. Planned Operations
1. Set CIBP at ~11,937’ MD in the existing 7-5/8” 29.7 # casing
2. RIH with the mechanical set whipstock, set whipstock at 11,920’, mill window and 20’ of new
formation. Perform LOT to a minimum of 10 ppg EMW and maximum of 15 ppg EMW.
3. POOH and pick up motor. Drill ahead to confirm departure from wellbore, once departure is
confirmed, POOH
4. Drill 6.75” hole to section TD (LWD Program: GR/RES/PWD).
5. Pull out of hole with drilling BHA.
6. Run 4.5” slotted liner with swell packers and liner hanger to TD.
7. Set liner top packer. OWFF. TOOH and LD running tools.
8. Run 4.5” upper completion, landing nipple, and gas lift mandrel(s). Displace production casing to
corrosion inhibited fluid, space out and land tubing hanger with tubing stung into seals.
9. Pressure test hanger seals to 5,000 psi.
10. Test tubing to 3,000 psi.
11. Bleed tubing pressure to 2000 psi and test IA to 3,000 psi, chart test. Shear shearout valve
12. Install HP-BPV and test to 2,000 psi.
13. Nipple down BOP.
14. Install tubing head adapter assembly. N/U tree and test to 5000 psi/10 minutes.
15. Freeze protect well.
16. Secure well. Rig down and move out.
Planned revised bottom-hole location is about 110' from the originally
permitted bottom-hole location. SFD
1C-158 AOGCC 10-401 APD 3 | 4
3. Present Well Schematic
1C-158 AOGCC 10-401 APD 4 | 4
4. Proposed Completion Schematic
5. Area of Review
Does not change from PTD 223-056
11888 11900
11900 12200
12200 12400
12400 12600
12600 13000
13000 13800
13800 13900
13900 15550
15550 15650
15650 21982
1C-158 (ST) wp16 Plan Summary
0
3
Do
g
l
e
g
S
e
v
e
r
i
t
y
12000 13500 15000 16500 18000 19500 21000
Measured Depth
Top Whipstock
4-1/2" Production Liner
30.0
30.0
60.0
60.0
0
90
180
270
30
210
60
240 120
300
150
330
Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [60 usft/in]
11900119501200012050121001214912199122491229812348123981244812497125471259712646
13741137911384113891139411399114041
14091141431419414245147501480014850149001495014999150491509915149151991524915299156481599716047
160971614716197162471629716347163971644716497165471659716647
16697167471679716846168961694617602176521770217752178021785217902179521800218052181021815218201182331C-158
3000
4500
Tr
u
e
V
e
r
t
i
c
a
l
D
e
p
t
h
-3000 -1500 0 1500 3000 4500 6000
Vertical Section at 345.00°
1C-1 587-5/8" Intermediate Casing
4-1/2" Production Liner
1C-1 58 (S T) w p 1 6
0
18
35
Ce
n
t
r
e
t
o
C
e
n
t
r
e
S
e
p
a
r
a
t
i
o
n
11900 12000 12100 12200 12300 12400 12500 12600
Measured Depth
DDI
7.567
SURVEY PROGRAM
Date: 2014-11-10T00:00:00 Validated: Yes Version:
Depth From Depth To Survey/Plan Tool
155.00 2025.88 1C-158 Srvy 1 SDI_URSA1_I4
2119.52 11887.66 1C-158 Srvy 2 MWD+IFR2+SAG+MS
11887.66 12300.00 1C-158 (ST) wp16 (1C-158 (ST))MWD-INC_ONLY
12300.00 21985.21 1C-158 (ST) wp16 (1C-158 (ST))MWD+IFR2+SAG+MS
Ground / 58.30
CASING DETAILS
TVD MD Name
4005.19 11920.00 7-5/8" Intermediate Casing
3962.40 21985.21 4-1/2" Production Liner
Mag Model & Date: BGGM2023 10-Oct-23
Magnetic North is 14.38° East of True North (Magnetic Declinatio
Mag Dip & Field Strength: 80.64° 57201.79nT
SECTION DETAILS
Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation
1 11887.66 82.02 350.70 4000.77 -1349.42 6872.69 0.00 0.00 -3082.22 Start DLS 2.15 TFO -69.89
211920.00 82.26 350.04 4005.19 -1317.83 6867.34 2.15 -69.89 -3050.33 Start DLS 16.00 TFO 45.00
311933.00 83.73 351.52 4006.78 -1305.10 6865.27 16.00 45.00 -3037.49 Start 20.00 hold at 11933.00 MD
411953.00 83.73 351.52 4008.96 -1285.43 6862.34 0.00 0.00 -3017.74 Start DLS 2.50 TFO -16.57
5 12216.30 90.04 349.65 4023.25 -1026.21 6819.33 2.50 -16.57 -2756.22 Start 294.62 hold at 12216.30 MD
612510.91 90.04 349.65 4023.02 -736.39 6766.38 0.00 0.00 -2462.57 Start DLS 2.00 TFO -31.47
712572.79 91.10 349.00 4022.40 -675.59 6754.92 2.00 -31.47 -2400.87 1C-158 (ST) Tgt 02 100223 Start 1500.00 hold at 12572.79 MD
814072.79 91.10 349.00 3993.60 796.58 6468.75 0.00 0.00 -904.80 Start DLS 2.00 TFO -88.52
914442.19 91.28 341.61 3985.92 1153.57 6375.14 2.00 -88.52 -535.74 Start 1144.11 hold at 14442.19 MD
1015586.31 91.28 341.61 3960.33 2239.00 6014.33 0.00 0.00 606.09 Start DLS 2.00 TFO 107.60
11 15632.84 91.00 342.50 3959.40 2283.27 6000.00 2.00 107.60 652.55 Start DLS 2.00 TFO 125.20
1215702.85 90.19 343.64 3958.67 2350.24 5979.62 2.00 125.20 722.51 Start 1261.38 hold at 15702.85 MD
1316964.23 90.19 343.64 3954.43 3560.56 5624.41 0.00 0.00 1983.53 Start DLS 2.00 TFO -128.31
1416979.78 90.00 343.40 3954.40 3575.48 5620.00 2.00 -128.31 1999.08 Start DLS 2.00 TFO -128.18
1517113.81 88.34 341.29 3956.34 3703.17 5579.36 2.00 -128.18 2132.94 Start 355.01 hold at 17113.81 MD
16 17468.82 88.34 341.29 3966.60 4039.28 5465.54 0.00 0.00 2487.06 Start DLS 2.00 TFO -123.17
1717545.94 87.50 340.00 3969.40 4112.00 5440.00 2.00 -123.17 2563.91 Start DLS 2.00 TFO -115.31
18 17598.74 87.05 339.04 3971.91 4161.40 5421.55 2.00 -115.31 2616.40 Start 565.48 hold at 17598.74 MD
19 18164.22 87.05 339.04 4001.02 4688.77 5219.58 0.00 0.00 3178.08 Start DLS 2.00 TFO 45.08
2018373.01 90.00 342.00 4006.40 4885.51 5150.00 2.00 45.08 3386.12 Start DLS 2.00 TFO 42.52
21 18442.14 91.02 342.93 4005.79 4951.42 5129.18 2.00 42.52 3455.18 Start 957.44 hold at 18442.14 MD
2219399.58 91.02 342.93 3988.76 5866.56 4848.24 0.00 0.00 4411.85 Start DLS 1.00 TFO 85.88
2319526.44 91.11 344.20 3986.40 5988.22 4812.36 1.00 85.88 4538.64 1C-158 (ST) Tgt 07 100223 Start DLS 1.00 TFO 12.35
2419529.54 91.14 344.21 3986.34 5991.20 4811.52 1.00 12.35 4541.74 Start 1425.75 hold at 19529.54 MD
25 20955.29 91.14 344.21 3957.97 7362.85 4423.55 0.00 0.00 5967.07 Start DLS 2.00 TFO 178.83
2621012.31 90.00 344.23 3957.40 7417.72 4408.04 2.00 178.83 6024.08 1C-158 (ST) Tgt 08 100223 Start DLS 2.00 TFO 179.28
27 21027.15 89.70 344.23 3957.44 7432.00 4404.01 2.00 179.28 6038.92 Start 958.07 hold at 21027.15 MD
28 21985.22 89.70 344.23 3962.40 8354.01 4143.70 0.00 0.00 6996.89 1C-158 (ST) Tgt 09 100223 TD at 21985.22
FORMATION TOP DETAILS
No formation data is available
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
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12000 12150 12300 12450 12600
Partial Measured Depth
1C
-
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5
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1C-158 (ST) wp16 Ladder View
0
150
300
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Measured Depth
1C
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1
5
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1C
-
2
2
1C
-
2
3
1C
-
2
3
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SURVEY PROGRAM
Depth From Depth To Survey/Plan Tool
155.00 2025.88 1C-158 Srvy 1 SDI_URSA1_I4
2119.5211887.66 1C-158 Srvy 2 MWD+IFR2+SAG+MS
11887.6612300.00 1C-158 (ST) wp16 (1C-158 (ST)) MWD-INC_ONLY
12300.0021985.21 1C-158 (ST) wp16 (1C-158 (ST)) MWD+IFR2+SAG+MS
13:44, October 03 2023
CASING DETAILS
TVD MD Name
4005.21 11920.00 7-5/8" Intermediate Casing
21985.21 4-1/2" Production Liner
11888 11900
11900 12200
12200 12400
12400 12600
12600 13000
13000 13800
13800 13900
13900 15550
15550 15650
15650 21982
1C-158 (ST) wp16 TC View
35
35
70
70
105
105
140
140
175
175
0
90
180
270
30
210
60
240 120
300
150
330
Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [70 usft/in]
1190011925119501197512000120251205012075121001212512149121741219912224122491227312298123231234812373123981242312448124721249712522125471257212597126221264612671126961272112745127701279512820128451286912894
12919129441296912994130191304413069130941311913144
13169
131941321913243132681329313318133431336813393134181344313468134931351813543135671359213617136421366713692137171374113766137911381613841138661389113916139411396613991140161404114066
14091141171414314168141941421914245142701429614322143471437314399144241445014475145001452514550145751460014625146501467514700
147251475014775148001482514850148751490014925149501497514999150241504915074150991512415149151741519915224152491527415299153241534915374
153991542415449154741549915524155491557415599156241564815673156971572215747
157721579715822158471587215897159221594715972159971602216047
16072160971612216147161721619716222162471627216297163221634716372163971642216447164721649716522165471657216597166221664716672
1669716722167471677216797168211684616871168961692116946169721699717023170481707417099171241714917174171991722417249
172741729917324173491737417399174241744917474175001752617551
175771760217627176521767717702177271775217777178021782717852178771790217927179521797718002180271805218077181021812718152181771820118226182331C-158
15606 15608 15610 15612 15614 15616 15618 15620 15623 15625 15627 15629 156311C-22
13859 13857 13855 13853 13851 13849 13847 1C-23
SURVEY PROGRAM
Date: 2014-11-10T00:00:00 Validated: Yes Version:
From To Tool
155.00 2025.88 SDI_URSA1_I4
2119.52 11887.66 MWD+IFR2+SAG+MS
11887.66 12300.00 MWD-INC_ONLY
12300.00 21985.21 MWD+IFR2+SAG+MS
CASING DETAILS
TVD MD Name
4005.21 11920.00 7-5/8" Intermediate Casing
21985.21 4-1/2" Production Liner
SECTION DETAILS
Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation
1 11887.66 82.02 350.70 4000.77 -1349.42 6872.69 0.00 0.00 -3082.22 Start DLS 2.15 TFO -69.89
211920.00 82.26 350.04 4005.19 -1317.83 6867.34 2.15 -69.89 -3050.33 Start DLS 16.00 TFO 45.00
311933.00 83.73 351.52 4006.78 -1305.10 6865.27 16.00 45.00 -3037.49 Start 20.00 hold at 11933.00 MD
411953.00 83.73 351.52 4008.96 -1285.43 6862.34 0.00 0.00 -3017.74 Start DLS 2.50 TFO -16.57
512216.30 90.04 349.65 4023.25 -1026.21 6819.33 2.50 -16.57 -2756.22 Start 294.62 hold at 12216.30 MD
612510.91 90.04 349.65 4023.02 -736.39 6766.38 0.00 0.00 -2462.57 Start DLS 2.00 TFO -31.47
712572.79 91.10 349.00 4022.40 -675.59 6754.92 2.00 -31.47 -2400.87 1C-158 (ST) Tgt 02 100223 Start 1500.00 hold at 12572.79 MD
8 14072.79 91.10 349.00 3993.60 796.58 6468.75 0.00 0.00 -904.80 Start DLS 2.00 TFO -88.52
9 14442.19 91.28 341.61 3985.92 1153.57 6375.14 2.00 -88.52 -535.74 Start 1144.11 hold at 14442.19 MD
1015586.31 91.28 341.61 3960.33 2239.00 6014.33 0.00 0.00 606.09 Start DLS 2.00 TFO 107.60
11 15632.84 91.00 342.50 3959.40 2283.27 6000.00 2.00 107.60 652.55 Start DLS 2.00 TFO 125.20
1215702.85 90.19 343.64 3958.67 2350.24 5979.62 2.00 125.20 722.51 Start 1261.38 hold at 15702.85 MD
1316964.23 90.19 343.64 3954.43 3560.56 5624.41 0.00 0.00 1983.53 Start DLS 2.00 TFO -128.31
1416979.78 90.00 343.40 3954.40 3575.48 5620.00 2.00 -128.31 1999.08 Start DLS 2.00 TFO -128.18
1517113.81 88.34 341.29 3956.34 3703.17 5579.36 2.00 -128.18 2132.94 Start 355.01 hold at 17113.81 MD
1617468.82 88.34 341.29 3966.60 4039.28 5465.54 0.00 0.00 2487.06 Start DLS 2.00 TFO -123.17
1717545.94 87.50 340.00 3969.40 4112.00 5440.00 2.00 -123.17 2563.91 Start DLS 2.00 TFO -115.31
1817598.74 87.05 339.04 3971.91 4161.40 5421.55 2.00 -115.31 2616.40 Start 565.48 hold at 17598.74 MD
1918164.22 87.05 339.04 4001.02 4688.77 5219.58 0.00 0.00 3178.08 Start DLS 2.00 TFO 45.08
2018373.01 90.00 342.00 4006.40 4885.51 5150.00 2.00 45.08 3386.12 Start DLS 2.00 TFO 42.52
21 18442.14 91.02 342.93 4005.79 4951.42 5129.18 2.00 42.52 3455.18 Start 957.44 hold at 18442.14 MD
2219399.58 91.02 342.93 3988.76 5866.56 4848.24 0.00 0.00 4411.85 Start DLS 1.00 TFO 85.88
2319526.44 91.11 344.20 3986.40 5988.22 4812.36 1.00 85.88 4538.64 1C-158 (ST) Tgt 07 100223 Start DLS 1.00 TFO 12.35
2419529.54 91.14 344.21 3986.34 5991.20 4811.52 1.00 12.35 4541.74 Start 1425.75 hold at 19529.54 MD
25 20955.29 91.14 344.21 3957.97 7362.85 4423.55 0.00 0.00 5967.07 Start DLS 2.00 TFO 178.83
2621012.31 90.00 344.23 3957.40 7417.72 4408.04 2.00 178.83 6024.08 1C-158 (ST) Tgt 08 100223 Start DLS 2.00 TFO 179.28
27 21027.15 89.70 344.23 3957.44 7432.00 4404.01 2.00 179.28 6038.92 Start 958.07 hold at 21027.15 MD
28 21985.22 89.70 344.23 3962.40 8354.01 4143.70 0.00 0.00 6996.89 1C-158 (ST) Tgt 09 100223 TD at 21985.22
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14:12, October 03 2023
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1C-158wp16 Surface Location
1C-158wp16 Surface Location
# Schlumberger-Confidential
1C-158wp16 Top Whipstock
1C-158wp16 Top Whipstock
# Schlumberger-Confidential
1C-158wp16 TD
1C-158wp16 TD
# Schlumberger-Confidential
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
BOPE Test Report for:
Reviewed By:
P.I. Suprv
Comm ________KUPARUK RIV U WSAK 1C-158
JBR 10/17/2023
MISC. INSPECTIONS:
FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK:
ACCUMULATOR SYSTEM:MUD SYSTEM:
P/F P/F
P/FP/FP/F
Visual Alarm
QuantityQuantity
Time/Pressure
SizeQuantity
Number of Failures:2
Fail/pass on Annular 4 way on koomey, leaking in open and closed positions. Mechanic replaced the valve and was retested
with a closing time of 11 seconds. Fail/pass on audible cellar H2S detector. Electrician replaced rain head and retested. Passed
both visual and audible. All gauges and the Barton chart recorder had current calibration stickers.
Test Results
TEST DATA
Rig Rep:Matt Sam / Kelly HaugOperator:ConocoPhillips Alaska, Inc.Operator Rep:Byron Marmon / Adam Dorr
Rig Owner/Rig No.:Doyon 142 PTD#:2230560 DATE:9/8/2023
Type Operation:DRILL Annular:
250/5000Type Test:INIT
Valves:
250/5000
Rams:
250/5000
Test Pressures:Inspection No:bopJDH230908151344
Inspector Josh Hunt
Inspector
Insp Source
Related Insp No:
INSIDE REEL VALVES:
Quantity P/F
(Valid for Coil Rigs Only)
Remarks:
Test Time 7.0
MASP:
1252
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" 5M P
#1 Rams 1 7 5/8" 5M P
#2 Rams 1 Blind/Shear P
#3 Rams 1 3 1/2x6" VBR P
#4 Rams 0 NA
#5 Rams 0 NA
#6 Rams 0 NA
Choke Ln. Valves 1 3 1/8" 5M P
HCR Valves 2 3 1/8" 5M P
Kill Line Valves 3 3 1/8" 5M P
Check Valve 0 NA
BOP Misc 0 NA
System Pressure P3000
Pressure After Closure P1800
200 PSI Attained P14
Full Pressure Attained P48
Blind Switch Covers:Pall stations
Bottle precharge P
Nitgn Btls# &psi (avg)P6@1958
ACC Misc NA
P PTrip Tank
P PPit Level Indicators
P PFlow Indicator
P PMeth Gas Detector
P FPH2S Gas Detector
0 NAMS Misc
Inside Reel Valves 0 NA
Annular Preventer FP37
#1 Rams P7
#2 Rams P7
#3 Rams P7
#4 Rams NA0
#5 Rams NA0
#6 Rams NA0
HCR Choke P1
HCR Kill P1
99
9
9 9 9 9
9
9
9
9
9
17(VHFRQGVUHTXLUHGIRU$QQXODUFORVH
FP37
Fail/pass on Annular 4 way retested
with a closing time of 11 seconds.Fail/pass on audible cellar H2S detector.
FP
Alaska Oil and Gas
Conservation Commission
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
Chris Brillon
Wells Engineering Manager
Conoco Phillips Alaska, Inc.
700 G Street
Anchorage, AK, 99501
Re: Kuparuk River Field, West Sak Pool, 1C-158
Conoco Phillips Alaska, Inc.
Permit to Drill Number: 223-056
Surface Location: 3825' FSL, 4303' FEL, S12 T11N R10E
Bottomhole Location: 1513' FSL, 165' FEL, S36 T12N R10E
Dear Mr. Brillon:
Enclosed is the approved application for the permit to drill the above referenced well.
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well
logs run must be submitted to the AOGCC within 90 days after completion, suspension, or
abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first.
This permit to drill does not exempt you from obtaining additional permits or an approval required
by law from other governmental agencies and does not authorize conducting drilling operations
until all other required permits and approvals have been issued. In addition, the AOGCC reserves
the right to withdraw the permit in the event it was erroneously issued.
Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska
Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply
with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code,
or an AOGCC order, or the terms and conditions of this permit may result in the revocation or
suspension of the permit.
Sincerely,
Brett W. Huber, Sr.
Chair, Commissioner
DATED this ___ day of August 2023. 9
Brett W.
Huber, Sr.
Digitally signed by Brett W.
Huber, Sr.
Date: 2023.08.09 14:53:10
-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: 21883 TVD:3992
4a. Location of Well (Governmental Section): 7. Property Designation:
Surface:
Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date:
8/20/2023
Total Depth:9. Acres in Property:14. Distance to Nearest Property:
164.9' 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-561982 y- 5968781 Zone- 4 58.3 to Same Pool: 2994 to 1C-155
16. Deviated wells: Kickoff depth: 300 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035)
Maximum Hole Angle: 91 degrees Downhole: Surface:
Hole Casing Weight Grade Coupling Length MD TVD MD TVD
42" 20" 94 H-40 Welded 116 39 39 155 155
13.5" 10.75" 45.5 L-80 Hyd563 1992 39 39 2031 1,907
9.875" 7.625" 29.7 L-80 Hyd563 12,075 39 39 12,114 4,026
6.75" 4.5" 12.6 L-80 Hyd563 9,949 11,934 3986 21,883 3,992
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: Abby Warren
Chris Brillon Contact Email:abby.warren@conocophillips.com
Wells Engineering Manager Contact Phone:907-240-9293
Date:
Permit to Drill API Number: Permit Approval
Number:Date:
Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales:
Samples req'd: Yes No Mud log req'd: Yes No
H2S measures: Yes No Directional svy req'd: Yes No
Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No
Post initial injection MIT req'd: Yes No
APPROVED BY
Approved by: COMMISSIONER THE COMMISSION Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
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.
Intermediate
Production
Liner
Conductor/Structural
Surface
Casing Length Size Cement Volume MD
1/2 yds
641 sx 10.7ppg; 272 sx 15.8ppg
545 sx 14.0 ppg 225 sx 15.3ppg
Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft):
1607 1252
18. Casing Program:Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks
1964' FSL,2320' FEL,S7 T11N R11E LONS 01-013
1513' FSL, 165' FEL, S36 T12N R10E 2560 / 2469 / 2458
GL / BF Elevation above MSL (ft):
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
20 AAC 25.005
ConocoPhillips 59-52-180 1C-158
P.O. Box 100360 Anchorage, Alaska, 99510-0360 Kuparuk River Field
West Sak
3825' FSL, 4303' FEL, S12 T11N R10E ADL025638 / ADL028242 / ADL047449
(including stage data)
Stratigraphic Test
No Mud log req'd: Yes No
No Directional svy req'd: Yes No
Seabed ReportDrilling Fluid Program 20 AAC 25.050 requirements
BOP SketchDrilling Program Time v. Depth Plot Shallow Hazard Analysis
Single Well
Gas Hydrates
No Inclination-only svy req'd: Yes No
Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal
No
No
Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g)
By Grace Christianson at 9:28 am, Aug 07, 2023
A. Dewhurst
07 AUG 2023
DSR-8/7/23VTL 8/7/2023
223-056
/ 2560
X
4,007
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 may use SonicScope under the attached Conditions of Approval
Surface casing LOT and annular LOT to the AOGCC as soon as available.
A. Dewhurst07 AUG 2023
A. Dewhurst
07 AUG 2023
A. Dewhurst
07 AUG 2023
A.Dewhurst 07 AUG 2023
50-029-23761-00-00
/ ADL025649
GCW 08/09/2023JLC 8/9/2023
08/09/23
08/09/23
Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr.
Date: 2023.08.09 14:53:23 -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'
<ZhϭͲϭϱϴ
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
August 4, 2023
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
Re: Application for Permit to Drill 1C-158
Dear Sir or Madam:
ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore 1C Injector well from the 1C drilling pad. The
intended spud date for this well is 8/20/2023. It is intended that Doyon 142 be used to drill the well.
1C-158 will utilize a 13.5” surface hole drilled to TD and 10.75” 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 9.875” intermediate hole will be drilled and landed in the 1C reservoir. A
7.625” 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 B).
The production interval will be comprised of a 6.75” horizontal hole that will be geo-steered in the 1C formation. The well will
be completed as a Injector with 4.5” slotted liner with swell packers as necessary. The upper completion will include GLMs, 4-
1/2” tubing tied back to surface.
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)
7. Diverter drawing
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
(abby.warren@conocophillips.com) or Chris Brillon at 265-6120.
Sincerely, cc:
1C-158 Well File / Jenna Taylor ATO 1560
David Lee ATO 1552
Abby Warren Chris Brillon ATO 1548
Drilling Engineer John Bertalott ATO 0642
Application for Permit to Drill, 1C-158
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1C-158 PTD
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1C-158
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)) ................................... 5
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)) .................................... 7
10. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9))
................................................................................................................................... 8
11. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) .......................................... 8
12. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) ......................... 8
13. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) ................................... 8
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-158
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1C-158 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-158
2. Location Summary (Requirements of 20 AAC 25.005(c)(2))
Location at Surface 3825' FSL, 4303' FEL, S12 T11N R10E, UM
NAD 1927
Northings: 561982
Eastings: 5968781
RKB Elevation 97.3’ AMSL
Pad Elevation 58.3’ AMSL
Top of Productive Horizon
(Heel) 1964' FSL, 2320' FEL , S7 T11N R11E, UM
NAD 1927
Northings: 568901
Eastings: 5966981
Measured Depth, RKB: 11373’
Total Vertical Depth, RKB: 3936’
Total Vertical Depth, SS: 3839’
Total Depth (Toe) 1513' FSL, 165' FEL, S36 T12N R10E, UM
NAD 1927
Northings: 566048
Eastings: 5977063
Measured Depth, RKB: 21883
Total Vertical Depth, RKB: 3992’
Total Vertical Depth, SS: 3895’
Pad Layout
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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-158
2. Rig up and test riser, dewater cellar as needed.
3. Drill 13.5” hole to the surface casing point as per the directional plan (LWD Program: GR/Res/GWD).
4. Run and cement 10.75” 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 9.875” 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
10.4 ppg EMW.
10. Drill 9.875” hole to section TD, within the 1C Reservoir. (LWD Program: GR/RES).
11. Run 7.625” casing and cement to a minimum of 500’ MD or 250’ TVD above any hydrocarbon bearing zones
(cementing schematic attached). Pressure test casing on plug bump to 3500 psi for 30 minutes and chart.
12. Remove solid body rams and install VBR. Test BOPE to 250 psi low / 3,500 psi high (24-48 Regulatory notice).
13. Pick up and run in hole with 6.75” drilling BHA. Log top of cement with sonic tool in recorded mode.
14. If not tested on plug bump, 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 15.0 ppg. Minimum required
leak-off value is 10.0 ppg EMW.
16. Drill 6.75” 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” slotted liner with swell packers and liner hanger to TD.
19. Set liner top packer. OWFF. TOOH and LD running tools.
20. Run 4.5” upper completion, landing nipple, and gas lift mandrel(s). Displace production casing to corrosion
inhibited fluid, space out and land tubing hanger with tubing stung into seals.
21. Pressure test hanger seals to 5,000 psi.
22. Test tubing to 3,000 psi.
23. Bleed tubing pressure to 2000 psi and test IA to 3,000 psi, chart test. Shear shearout valve
24. Install HP-BPV and test to 2,000 psi.
25. Nipple down BOP.
26. Install tubing head adapter assembly. N/U tree and test to 5000 psi/10 minutes.
27. Freeze protect well.
28. Secure well. Rig down and move out.
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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 7.625” solid body rams,
blind/shear rams and variable rams while drilling and running casing in the intermediate section of 1C-158.
1C-158 has a MASP of 1419 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
Proposed Configuration: Proposed Configuration:
Annular Preventer (iii) Annular Preventer
7-5/8” fixed rams during drilling Intermediate VBRs in Upper Cavity
Blind/Shear Rams (ii) Blind/Shear Rams
VBRs (i) VBRs in Lower Cavity
5. Diverter System (Requirements of 20 AAC 25.005(c)(7))
Please reference the diverter schematic attached.
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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
(in)
Csg Setting Depth
MD/TVD(ft)
Fracture
Gradient (ppg)
Pore pressure
(psi)
ASP Drilling
(psi)
20 120 / 120 10.9 51 54
10.75 2031/ 1907 15.0 853 1297
7.625 11379/ 4002 12.2 1,783 1419
4.5 21114.5/ 3967 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)
= 839 – (0.1 x 1907) = 648 psi
2. Drilling below 10.75” 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)
= 1831 – (0.1 x 4002) = 1431 psi
3. Drilling below 7.625” intermediate casing
ASP = [(FG x 0.052) – 0.1] D
= [(12.2 x 0.052) – 0.1] x 4002= 2138 psi
OR
ASP = FPP – (0.1 x D)
= 1815– (0.1 x 3967 )= 1419 psi
155
12114
155
3992
4025
21883
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(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;
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 1/2 yds slurry
10.75 13.5 45.5 L-80 Hyd563 Cement to Surface
7.625 9.875 29.7 L80 Hyd563 250’ TVD or 500’ MD, whichever is greater, above upper
most producing zone (Ugnu B)
4.5 6.75 12.6 L-80 Hyd563 N/A – Slotted liner
Cementing Calculations
10.75” Surface Casing run to 2031’ MD / 1907’ TVD
Cement from 2031’ MD to 1531' (500’ of tail) with Class G + Add's @ 15.8 PPG, and from 1531' to surface with
10.7 ppg Arctic Lite Crete. Assume 225% excess annular volume for lead and 50% excess for tail, zero excess in
20” conductor.
Lead slurry from 1531’ MD to surface with Arctic Lite Crete @ 10.7 ppg
Total Volume = 1831 ft3 => 641 sx of 10.7ppg Class G + Add's @ 2.86 ft3 /sk
Tail slurry from 2031’ MD to 1531’ MD with 15.8 ppg Class G + Add's
Total Volume = 316 ft3 => 272 sx of 15.8 ppg Class G + Add's @ 1.16 ft3/sk
Application for Permit to Drill, 1C-158
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7.625” Intermediate Casing run to 12114’ MD / 4026’ TVD
Top of slurry is designed to be at 7800’ MD, which is 500’MD or 250’ TVD above the prognosis shallowest
hydrocarbon bearing zone, Ugnu B. Assume 20% excess annular volume.
Lead Slurry from 11114’ MD to 7800’MD with 14.0 ppg + add’s
Total Volume = 850 ft3 => 545 sx of 14.0 ppg + add’s @ 1.55 ft3/sk
Tail slurry from 12114’ MD to 11114’ MD with 15.3 ppg Class G + Add's
Total Volume = 278ft3 => 225 sx of 15.3 ppg Class G + Add's@ 1.24 ft3/sk
9. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8))
Surface Intermediate Production
Hole Size in. 13.5 9.875 6.75
Casing Size in. 10.75 7.625 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 9-13
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 6-12
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 10.5 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.
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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.
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
13.5" Hole / 10.75” 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
9.875” Hole /7.625” 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
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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
6.75” 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
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. The rig will have H2S sensors 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.
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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
16. Area of Review for Injection
Attachment one has the offset area of review.
17. Proposed Completion Schematic
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Attachment 1 – 1C-158 Area of Review (AOR)
An Area of Review plot is show below of the 1C-158 Injector planned wellpath and offset wells. 1C-14,
1C-16, 1C-22, 1C-23, and 1C-157 are the offset wells from the planned 1C-158 injector.
Well Name Status Surface Casing
MD / TVD
TOC
(MD/TVD)
Cement Volumes Pumped
1C-14 Injector 7,292’ / 4,526’ Cement to
Surface
Lead: 236 bbls 10.5 ppg
Tail: 130 bbls of tail
2nd Stage Lead: 442 bbls 10.8
2nd stage Tail: 10 bbls
1C-16 Producer 7,404’ / 4,418’ Cement to
Surface
Lead: 699 bbls 10.7 ppg
Tail: 145 bbls 15.8 ppg
1C-22 Injector 9,473’ / 4,510’ Cement to
Surface
Lead: 381 bbls 10.7 ppg
Tail: 175.5 bbls 12.0 ppg
2nd Stage
Lead: 492 bbls 10.7 ppg
Tail: 12 bbls 15.8 ppg
1C-23 Producer 8,894’ / 4,572’ Cement to
Surface
Lead: 1012 bbls 10.7 ppg
Tail: 61 bbls
x 1C-14 is a Kuparuk injector and has 9-5/8” surface casing set below the West Sak interval and is
cemented to surface.
x 1C-16 is a Kuparuk Producer and has 9-5/8” surface casing set below the West Sak interval and is
cemented to surface.
x 1C-22 is a Kuparuk Injector and has 9-5/8” surface casing set below the West Sak interval and is
cemented to surface.
x 1C-23 is a Kuparuk Producer and has 9-5/8” surface casing set below the West Sak interval and is
cemented to surface.
x 1C-157 is currently being drilled as a OHSAS producer.
39 700
700 900
900 1100
1100 1200
1200 1400
1400 1600
1600 2000
2000 2300
2300 2800
2800 3200
3200 3700
3700 4000
4000 5000
5000 5700
5700 7100
7100 7500
7500 8000
8000 8500
8500 13120
13120 13220
13220 14850
14850 14950
14950 21165
1C-158 wp11 Plan Summary
0
4
Do
g
l
e
g
S
e
v
e
r
i
t
y
0 3500 7000 10500 14000 17500 21000
Measured Depth
10-3/4" Surface Casing 7-5/8" Intermediate Casing
4-1/2" Production Liner
30.0
30.0
60.0
60.0
0
90
180
270
30
210
60
240 120
300
150
330
Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [60 usft/in]
1331
1378
1424
1470
1515
15601C-03
1331
1378
1424
1470
1515
15601C-03A
1009
1C-04
1009
1C-04A
1009
1C-04AL1
53103153203253303353403453503552602651
700
749
797
846
1C-05
3950100150
200250300351401452502553603654704755805855
905
955
1004
1053
1102
1150
1199
1247
1295
1C-156
5010015020025030035040045050055160165170275280385390495410041054110411541204125413041353140314521C-157
1106
1149
1191
1230
12691C-178
1106
1149
1191
1230
12691C-178L1
1106
1149
1191
1230
12691C-178L1PB1
1106
1149
1191
1230
12691C-178L1PB2
4696146196246
296346397447497547598648
698
747
797
846
895
943
991
1038
1C-18
2147
2192
2238
2284
2328
23711C-24
2147
2192
2238
2284
2328
23711C-24L1
0
2250
Tr
u
e
V
e
r
t
i
c
a
l
D
e
p
t
h
-7500 -6250 -5000 -3750 -2500 -1250 0
Vertical Section at 300.00°
20" Conductor Casing
10-3/4" Surface Casing
7-5/8" Intermediate Casing
4-1/2" Production Liner
15
30
Ce
n
t
r
e
t
o
C
e
n
t
r
e
S
e
p
a
r
a
t
i
o
n
0 425 850 1275 1700 2125 2550 2975
Measured Depth
Equivalent Magnetic Distance
DDI
7.519
SURVEY PROGRAM
Date: 2014-11-10T00:00:00 Validated: Yes Version:
Depth From Depth To Survey/Plan Tool
39.10 1600.00 1C-158 wp11.1 (1C-158) SDI_URSA1_I4
1600.00 2060.00 1C-158 wp11.1 (1C-158)MWD OWSG
1600.00 2060.00 1C-158 wp11.1 (1C-158) MWD+IFR2+SAG+MS
2060.00 3060.00 1C-158 wp11.1 (1C-158) MWD OWSG
2060.00 12140.00 1C-158 wp11.1 (1C-158) MWD+IFR2+SAG+MS
12140.00 13140.00 1C-158 wp11.1 (1C-158) MWD OWSG
12140.00 21883.14 1C-158 wp11.1 (1C-158) MWD+IFR2+SAG+MS
Ground / 58.30
CASING DETAILS
TVD MD Name
135.00 135.00 20" Conductor Casing
1935.00 2066.65 10-3/4" Surface Casing
4027.35 12144.53 7-5/8" Intermediate Casing
3992.40 21883.14 4-1/2" Production Liner
Mag Model & Date: BGGM2023 30-Aug-23
Magnetic North is 14.43° East of True North (Magnetic Declinatio
Mag Dip & Field Strength: 80.65° 57205.86nT
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 1.25
3 500.00 2.50 166.00 499.94 -4.23 1.06 1.25 166.00 -3.03 Start Build 2.00
4 700.00 6.50 166.00 699.28 -19.46 4.85 2.00 0.00 -13.93 Start Build 2.50
5 1955.65 37.89 166.00 1847.40 -473.98 118.18 2.50 0.00 -339.33 Start 126.71 hold at 1955.65 MD
6 2082.37 37.89 166.00 1947.40 -549.49 137.00 0.00 0.00 -393.39 Start Build 2.00
7 2191.72 40.08 166.00 2032.40 -616.24 153.65 2.00 0.00 -441.18 Start 20.00 hold at 2191.72 MD
8 2211.72 40.08 166.00 2047.70 -628.74 156.76 0.00 0.00 -450.13 Start DLS 3.00 TFO -55.49
9 4186.37 85.53 120.75 2963.09 -1860.50 1256.25 3.00 -55.49 -2018.19 Start 3019.53 hold at 4186.37 MD
10 7205.91 85.53 120.75 3198.21 -3399.54 3843.46 0.00 0.00 -5028.30 Start DLS 2.75 TFO -101.58
11 12144.53 85.20 344.00 4027.35 -1099.13 6831.41 2.75 -101.58 -6465.74 Start Build 2.00
1212384.53 90.00 344.00 4037.40 -868.70 6765.33 2.00 0.00 -6293.30 1C-158 Tgt 01 071223 Start DLS 1.00 TFO 78.76
1312960.75 91.12 349.65 4031.76 -307.91 6634.07 1.00 78.76 -5899.23 Start 610.59 hold at 12960.75 MD
1413571.34 91.12 349.65 4019.80 292.63 6524.41 0.00 0.00 -5503.99 Start DLS 2.00 TFO -92.19
1513854.13 90.90 344.00 4014.81 567.82 6460.00 2.00 -92.19 -5310.61 Start DLS 2.00 TFO -90.52
1613942.49 90.88 342.23 4013.43 652.36 6434.34 2.00 -90.52 -5246.12 Start 2638.98 hold at 13942.49 MD
1716581.47 90.88 342.23 3972.74 3165.17 5629.14 0.00 0.00 -3292.39 Start DLS 2.00 TFO -177.89
1816625.68 90.00 342.20 3972.40 3207.26 5615.64 2.00 -177.89 -3259.65 1C-158 Tgt 02 071223 Start DLS 2.00 TFO -179.34
1916750.30 87.51 342.17 3975.11 3325.88 5577.52 2.00 -179.34 -3167.34 Start 922.33 hold at 16750.30 MD
2017672.63 87.51 342.17 4015.22 4203.08 5295.40 0.00 0.00 -2484.41 Start DLS 1.00 TFO -151.55
21 17719.00 87.10 341.95 4017.40 4247.14 5281.13 1.00 -151.55 -2450.02 1C-158 Tgt 03 071223 Start DLS 1.00 TFO -153.08
2217745.94 86.86 341.83 4018.82 4272.71 5272.77 1.00 -153.08 -2430.00 Start 208.61 hold at 17745.94 MD
2317954.54 86.86 341.83 4030.25 4470.62 5207.81 0.00 0.00 -2274.79 Start DLS 2.00 TFO 33.44
2418142.63 90.00 343.90 4035.40 4650.25 5152.42 2.00 33.44 -2137.00 1C-158 Tgt 04 071223 Start DLS 2.00 TFO 38.06
2518161.05 90.29 344.13 4035.35 4667.96 5147.35 2.00 38.06 -2123.76 Start 1700.20 hold at 18161.05 MD
2619861.24 90.29 344.13 4026.75 6303.31 4682.35 0.00 0.00 -903.38 Start DLS 1.00 TFO 10.33
2719901.90 90.69 344.20 4026.40 6342.42 4671.25 1.00 10.33 -874.21 1C-158 Tgt 05 071223 Start DLS 1.00 TFO 11.32
2819932.04 90.99 344.26 4025.96 6371.43 4663.06 1.00 11.32 -852.62 Start 1951.10 hold at 19932.04 MD
29 21883.14 90.99 344.26 3992.40 8249.08 4133.83 0.00 0.00 544.54 1C-158 Tgt 06 071223 TD at 21883.14
FORMATION TOP DETAILS
TVDPath Formation
1682.40 T-5
1800.40 Base Perm
2006.40 T-3
2294.40 K-15
3293.40 Ugnu C
3508.40 Ugnu B
3638.40 Ugnu A
3735.40 N
3936.40 WSAK D
4018.40 Fault 1
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
0
95
0
19
0
0
28
5
0
38
0
0
47
5
0
True Vertical Depth
-6
6
5
0
-
5
7
0
0
-
4
7
5
0
-
3
8
0
0
-
2
8
5
0
-
1
9
0
0
-
9
5
0
0
Ve
r
t
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a
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3
0
0
.
0
0
°
20
"
C
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d
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C
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g
10
-
3
/
4
"
S
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7-
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8
"
I
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4-
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P
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L
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r
1000
2000
3 0 0 0
4 0 00
5 0 0 0
6 0 0 0
7 0 0 0
8 0 00
9 0 0 0
1 00 0 0
11000
12000
13 00 0
14 00 0
150 00
1 600 0
17000
18000
1 9000
20000
2100 0
21883
0°
30°
6 0 °
8 6 °
90°
9 1 °
91 °
88°
87°
90°
9 1 °
1C-158 wp11
T-
5
Ba
s
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P
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T-
3 K-
1
5
Ug
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C
Ug
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Ug
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N
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A
K
D
Fa
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1
1C
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1
5
8
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1
1
8:
5
7
,
J
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1
9
2
0
2
3
Se
c
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V
i
e
w
-2
5
0
0
0
25
0
0
50
0
0
75
0
0
South(-)/North(+)
-5
0
0
0
-
2
5
0
0
0
2
5
0
0
5
0
0
0
7
5
0
0
1
0
0
0
0
1
2
5
0
0
We
s
t
(
-
)
/
E
a
s
t
(
+
)
1C
-
1
5
8
T
g
t
0
6
0
7
1
2
2
3
1C
-
1
5
8
T
g
t
0
1
.
5
A
C
0
7
1
3
2
3
1C
-
1
5
8
T
g
t
0
5
0
7
1
2
2
3
1C
-
1
5
8
T
g
t
0
1
0
7
1
2
2
3
1C
-
1
5
8
T
g
t
0
2
0
7
1
2
2
3
1C
-
1
5
8
T
g
t
0
4
0
7
1
2
2
3
1C
-
1
5
8
T
g
t
0
3
0
7
1
2
2
3
20
"
C
o
n
d
u
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t
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r
C
a
s
i
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g
10
-
3
/
4
"
S
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f
a
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C
a
s
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g
7-
5
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8
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I
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4-
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2
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P
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L
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1C
-
1
5
8
w
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1
1
Wh
i
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p
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,
s
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w
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i
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1
0
0
f
e
e
t
l
a
t
e
r
a
l
l
y
o
f
p
l
a
n
,
u
n
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e
s
s
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i
e
d
o
t
h
e
r
w
i
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e
.
9:
0
1
,
J
u
l
y
1
9
2
0
2
3
3O
D
Q
9
L
H
Z
0
35
Ce
n
t
r
e
t
o
C
e
n
t
r
e
S
e
p
a
r
a
t
i
o
n
0 500 1000 1500 2000 2500
Partial Measured Depth
1C-03
1C-03A
1C-05
1C-156
1C-157
1C-178
1C-178L1
1C-178L1PB1
1C-178L1PB2
1C-18
1C-24
1C-24L1
Equivalent Magnetic Distance
1C-158 wp11 Ladder View
0
150
300
Ce
n
t
r
e
t
o
C
e
n
t
r
e
S
e
p
a
r
a
t
i
o
n
0 3500 7000 10500 14000 17500 21000
Measured Depth
1C-02
1C-03
1C-03A
1C-04
1C-04A
1C-04AL1
1C-05
1C-06
1C-06L1
1C-06L1-01
1C-06L1-02
1C-10
1C-117
1C-119
1C-121
1C-123
1C-125
1C-127
1C-13
1C-131
1C-133
1C-135
1C-135PB1
1C-14
1C-14A
1C-150
1C-151
1C-152
1C-153
1C-154
1C-156
1C-157
1C-16
1C-170
1C-170PB1
1C-172
1C-172A
1C-172AL1
1C-172AL2
1C-172AL2PB1
1C-172AL2PB2
1C-174
1C-178
1C-178L1
1C-178L1PB1
1C-178L1PB2
1C-18
1C-20
1C-20PB1
1C-21
1C-21L1
1C-21L2
1C-21L3
1C-22
1C-23
1C-23A
1C-23AL1
1C-23AL2
1C-23AL2-01
1C-23AL2-02
1C-24
1C-24L1
1C-28
1C-28L1
1C-28PB1
1C-501
wp12.1
Equivalent Magnetic Distance
SURVEY PROGRAM
Depth From Depth To Survey/Plan Tool
SDI_URSA1_I4
MWD OWSG
MWD+IFR2+SAG+MS
MWD OWSG
MWD+IFR2+SAG+MS
MWD OWSG
39.101600.001C-158 wp11 (1C-158)
1600.002060.001C-158 wp11 (1C-158)
1600.002060.001C-158 wp11 (1C-158)
2060.003060.001C-158 wp11 (1C-158)
2060.0012140.001C-158 wp11 (1C-158)
12140.0013140.001C-158 wp11 (1C-158)
12140.0021883.141C-158 wp11 (1C-158)MWD+IFR2+SAG+MS
9:12, July 19 2023
CASING DETAILS
TVD MD Name
135.00 135.00 20" Conductor Casing
1935.00 2066.65 10-3/4" Surface Casing
4027.35 12144.53 7-5/8" Intermediate Casing
3992.40 21883.14 4-1/2" Production Liner
39 700
700 900
900 1100
1100 1200
1200 1400
1400 1600
1600 2000
2000 2300
2300 2800
2800 3200
3200 3700
3700 4000
4000 4400
4400 5000
5000 5600
5600 8300
8300 8600
8600 9000
9000 13700
13700 14000
14000 15400
15400 15800
15800 21884
1C-158 wp11 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]
1037
1088
1138
1188
1236
1284
1331
1378
1424
147015151560
1604
1647
1690
1731
1C-03
1037
1088
1138
1188
1236
1284
1331
1378
1424
147015151560
1604
1647
1690
1731
1C-03A
53103153203
253303354405456507558609660710
761
811
861
911
960
1009
1057
1104
1151
1197
1242
1285
1328
1370
1410
1C-04
53103153203
253303354405456507558609660710
761
811
861
911
960
1009
1057
1104
1151
1197
1242
1285
1328
1370
1410
1C-04A
53103153203
253303354405456507558609660710
761
811
861
911
960
1009
1057
1104
1151
1197
1242
1285
1328
1370
1410
1C-04AL1
53103153203253303353403453503552602651
700
749
797
846
893
941
988
1034
1080
1126
1171
1215
1C-05
53103153203253303352401450499547594
642
688
7331C-06
53103153203253303352401450499547594
642
688
7331C-06L1
53103153203253303352401450499547594
642
688
7331C-06L1-01
53103153203253303352401450499547594
642
688
7331C-06L1-02
4696145195245
295345394443492540589637685
733
780
827
873
919
1C-13
1149
1200
1251
1302
1352
1402
1451
1500
1550
1599
1647
1696
1744
1793
1841
1889
1C-133
39621121622122623113604084565041C-151
3950100150
200250300351401452502553603654704755805855
905
955
1004
1053
1102
1150
1199
1247
1295
1343
1391
1439
1486
1534
1580
1627
1674
1720
1766
1812
18571C-156
5010015020025030035040045050055160165170275280385390495410041054110411541204125413041353140314521502155116001650169917481797184618941943
1992
4676
4723
4771
4819
1C-157
4696146196246296345395444493
541
589
636
682
728
772
816
858
1C-16
3960110160210260310
360410460509559608
657
706
754
802
848
894
940
984
1C-170
3960110160210260310
360410460509559608
657
706
754
802
848
894
940
984
1C-170PB1
39
60110160210260310360410460510560
609
658
706
754
801
8461C-172
39
4797147197247297347397447497546
596
645
694
741
788
834
1C-172A
39
4797147197247297347397447497546
596
645
694
741
788
834
1C-172AL1
39
4797147197247297347397447497546
596
645
694
741
788
834
1C-172AL2
39
4797147197247297347397447497546
596
645
694
741
788
834
1C-172AL2PB1
39
4797147197247297347397447497546
596
645
694
741
788
834
1C-172AL2PB2
3960110160210260310361411461510
560
608
656
704
750
795
839
882
924
964
1002
1C-174
820869919
967
1015
1061
1106
1149
1191
1230
1269
1305
1339
13701C-178
820869919
967
1015
1061
1106
1149
1191
1230
1269
1305
1339
13701C-178L1
820869919
967
1015
1061
1106
1149
1191
1230
1269
1305
1339
13701C-178L1PB1
820869919
967
1015
1061
1106
1149
1191
1230
1269
1305
1339
13701C-178L1PB2
4696146196246
296346397447497547598648698
747
797
846
895
943
991
1038
1085
1131
1177
1222
1267
1311
1C-18
13878
13869
13861
1C-23
13878
13869
13861
1C-23A
13878
13869
13861
1C-23AL1
13878
13869
13861
1C-23AL2
13878
13869
13861
1C-23AL2-01
13878
13869
13861
1C-23AL2-02
1914
1962
2008
2054
2100
2147
2192
2238
2284
2328
2371
2413
2453
2492
25301C-24
1914
1962
2008
2054
2100
2147
2192
2238
2284
2328
2371
2413
2453
2492
25301C-24L1
47961461962462961C-2847961461962462961C-28L147961461962462961C-28PB1
SURVEY PROGRAM
Date: 2014-11-10T00:00:00 Validated: Yes Version:
From To Tool
39.10 1600.00 SDI_URSA1_I4
1600.00 2060.00 MWD OWSG
1600.00 2060.00 MWD+IFR2+SAG+MS
2060.00 3060.00 MWD OWSG
2060.00 12140.00 MWD+IFR2+SAG+MS
12140.00 13140.00 MWD OWSG
12140.00 21883.14 MWD+IFR2+SAG+MS
CASING DETAILS
TVD MD Name
135.00 135.00 20" Conductor Casing1935.00 2066.65 10-3/4" Surface Casing4027.35 12144.53 7-5/8" Intermediate Casing
3992.40 21883.14 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 1.25
3 500.00 2.50 166.00 499.94 -4.23 1.06 1.25 166.00 -3.03 Start Build 2.00
4 700.00 6.50 166.00 699.28 -19.46 4.85 2.00 0.00 -13.93 Start Build 2.50
5 1955.65 37.89 166.00 1847.40 -473.98 118.18 2.50 0.00 -339.33 Start 126.71 hold at 1955.65 MD
6 2082.37 37.89 166.00 1947.40 -549.49 137.00 0.00 0.00 -393.39 Start Build 2.00
7 2191.72 40.08 166.00 2032.40 -616.24 153.65 2.00 0.00 -441.18 Start 20.00 hold at 2191.72 MD
8 2211.72 40.08 166.00 2047.70 -628.74 156.76 0.00 0.00 -450.13 Start DLS 3.00 TFO -55.49
9 4186.37 85.53 120.75 2963.09 -1860.50 1256.25 3.00 -55.49 -2018.19 Start 3019.53 hold at 4186.37 MD
10 7205.91 85.53 120.75 3198.21 -3399.54 3843.46 0.00 0.00 -5028.30 Start DLS 2.75 TFO -101.58
11 12144.53 85.20 344.00 4027.35 -1099.13 6831.41 2.75 -101.58 -6465.74 Start Build 2.00
1212384.53 90.00 344.00 4037.40 -868.70 6765.33 2.00 0.00 -6293.30 1C-158 Tgt 01 071223 Start DLS 1.00 TFO 78.76
1312960.75 91.12 349.65 4031.76 -307.91 6634.07 1.00 78.76 -5899.23 Start 610.59 hold at 12960.75 MD
1413571.34 91.12 349.65 4019.80 292.63 6524.41 0.00 0.00 -5503.99 Start DLS 2.00 TFO -92.19
1513854.13 90.90 344.00 4014.81 567.82 6460.00 2.00 -92.19 -5310.61 Start DLS 2.00 TFO -90.52
1613942.49 90.88 342.23 4013.43 652.36 6434.34 2.00 -90.52 -5246.12 Start 2638.98 hold at 13942.49 MD
1716581.47 90.88 342.23 3972.74 3165.17 5629.14 0.00 0.00 -3292.39 Start DLS 2.00 TFO -177.89
1816625.68 90.00 342.20 3972.40 3207.26 5615.64 2.00 -177.89 -3259.65 1C-158 Tgt 02 071223 Start DLS 2.00 TFO -179.34
1916750.30 87.51 342.17 3975.11 3325.88 5577.52 2.00 -179.34 -3167.34 Start 922.33 hold at 16750.30 MD
2017672.63 87.51 342.17 4015.22 4203.08 5295.40 0.00 0.00 -2484.41 Start DLS 1.00 TFO -151.55
21 17719.00 87.10 341.95 4017.40 4247.14 5281.13 1.00 -151.55 -2450.02 1C-158 Tgt 03 071223 Start DLS 1.00 TFO -153.08
2217745.94 86.86 341.83 4018.82 4272.71 5272.77 1.00 -153.08 -2430.00 Start 208.61 hold at 17745.94 MD
2317954.54 86.86 341.83 4030.25 4470.62 5207.81 0.00 0.00 -2274.79 Start DLS 2.00 TFO 33.44
2418142.63 90.00 343.90 4035.40 4650.25 5152.42 2.00 33.44 -2137.00 1C-158 Tgt 04 071223 Start DLS 2.00 TFO 38.06
2518161.05 90.29 344.13 4035.35 4667.96 5147.35 2.00 38.06 -2123.76 Start 1700.20 hold at 18161.05 MD
2619861.24 90.29 344.13 4026.75 6303.31 4682.35 0.00 0.00 -903.38 Start DLS 1.00 TFO 10.33
2719901.90 90.69 344.20 4026.40 6342.42 4671.25 1.00 10.33 -874.21 1C-158 Tgt 05 071223 Start DLS 1.00 TFO 11.32
2819932.04 90.99 344.26 4025.96 6371.43 4663.06 1.00 11.32 -852.62 Start 1951.10 hold at 19932.04 MD
29 21883.14 90.99 344.26 3992.40 8249.08 4133.83 0.00 0.00 544.54 1C-158 Tgt 06 071223 TD at 21883.14
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1C-03
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1C-03A
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3538
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1C-154
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3 538404245
1C-16
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35
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3 538
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3 5 38
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3 5 38
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3 5 38
1C-172AL2
3 5 38 1C-172AL2PB1
3 5 38
1C-172AL2PB2
35
3
8
1C-174
35
3
8
1C-178
35
3
8
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35
1C-178L1PB1
35
1C-178L1PB2
3
5
3
8
4
0
4
2
4
5
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35
3
8 1C-184
3538404245
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3538404245
35
38
40
42
45
1C-20
35
38
40
42
45
1C-20PB1
3538404245
1C-21
3538404245
1C-21L1
3538404245
1C-21L2
3538404245
1C-21L3
3 5
3 840
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1C-22
35
3 8
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1C-23
35
3 8
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1C-23A
35
3 8
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35
3 8
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1C-23AL2
35
3 8
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1C-23AL2-01
35
3 8
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4 2
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1C-23AL2-02
3 5
3 8
1C-23PB1
3538404245
1C-24
3538404245
1C-24L1
35
38
40
42
45
1C-26
35 38
40
42 45
1C-27
35
38
40
42
45
1C-28
35
38
40
42
45
1C-28L1
35
38
40
42
45
1C-28PB1
35
1C-501 wp12.1
35
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0
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3 6
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1C-01L1-02
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3 6
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1C-01L1-03
2
02
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36 38 40 42 44
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20
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2 6
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1C-03
20
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2 8
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1C-03A
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2 2
24
2 6
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3 81C-04
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3 6
3 81C-04A
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24
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3 4
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2
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201C-06L1-01
201C-06L1-02
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2 2
4 2
6 2
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2 3
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0 4
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1C-10
20
22
24
26
1C-117
1C-119
20
22
24
26
28
30
32
34
36
38
40
42
44
1C-12
1C-121
2 0
2 2
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1C-125
20
22
24
26
1C-127
2022241C-13
20 22 24 26 28 3
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2 3
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1C-131
20 2
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6 2
8 3
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2
3
4
3
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2
0
2
2
2
4
2
6
2
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3
2 1C-135
2
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2
2
2
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2
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3
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2 0
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24
1C-14
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1C-14A
20
22
24
26
28
30
32
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2
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2
2
2
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2
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3
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1C-172
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1C-172AL1
1C-172AL2
1C-172AL2PB1
1C-172AL2PB2
20
1C-174
20
1C-178
20
1C-178L1
20
1C-178L1PB1
20
1C-178L1PB2
202
2
2
4
2
6
2
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3
0
3
2
3
4
3
6
3
8
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0
4
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1C-18
20
22
24
26
28
30
32
34
36
3
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2
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26
28
30
32
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20
22
24
26
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30
32
34
36
38
40
42
44
1C-21
20
22
24
26
28
30
32
34
36
38
40
42
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1C-21L1
20
22
24
26
28
30
32
34
36
38
40
42
44
1C-21L2
20
22
24
26
28
30
32
34
36
38
40
42
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20
22
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20
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36
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20
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28
30
32
34
36
38
40
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24
26
28
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32
34
36
38
40
42
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1C-27
20
22
24
26
28
30
32
34
36
38
40
42
1C-28
20
22
24
26
28
30
32
34
36
38
40
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20
22
24
26
28
30
32
34
36
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2
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22
24
26
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123
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1C-158wp11Surface Location
1C-158wp11Surface Location
#SchlumbergerͲConfidential
1C-158wp1Surface Casing
1C-158wp11Surface Casing
#SchlumbergerͲConfidential
1C-158wp11West Sak D
1C-158wp11West Sak D
#SchlumbergerͲConfidential
1C-158wp11Intermediate 1 Csg
1C-158wp11Intermediate 1 Csg
#SchlumbergerͲConfidential
1C-158wp11TD
1C-158wp11TD
#SchlumbergerͲConfidential
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1
Dewhurst, Andrew D (OGC)
From:Dewhurst, Andrew D (OGC)
Sent:Monday, August 7, 2023 2:18 PM
To:Warren, Abby
Cc:Loepp, Victoria T (OGC); Guhl, Meredith D (OGC); Davies, Stephen F (OGC); Hobbs, Greg S
Subject:RE: [EXTERNAL]KRU-1C-158 (PTD 223-056) - Questions
Abby,
Thanks.Iwillmakethosechanges.
Andy
From:Warren,Abby<Abby.Warren@conocophillips.com>
Sent:Monday,August7,20232:13PM
To:Dewhurst,AndrewD(OGC)<andrew.dewhurst@alaska.gov>
Cc:Loepp,VictoriaT(OGC)<victoria.loepp@alaska.gov>;Guhl,MeredithD(OGC)<meredith.guhl@alaska.gov>;Davies,
StephenF(OGC)<steve.davies@alaska.gov>;Hobbs,GregS<Greg.S.Hobbs@conocophillips.com>
Subject:RE:[EXTERNAL]KRUͲ1CͲ158(PTD223Ͳ056)ͲQuestions
HiAndrew,
Commentsbelow.Feelfreetogivemeacallifyouwanttodiscuss.
Thanks
Abby
907Ͳ240Ͳ9293
From:Dewhurst,AndrewD(OGC)<andrew.dewhurst@alaska.gov>
Sent:Monday,August7,202311:47AM
To:Warren,Abby<Abby.Warren@conocophillips.com>
Cc:Loepp,VictoriaT(OGC)<victoria.loepp@alaska.gov>;Guhl,MeredithD(OGC)<meredith.guhl@alaska.gov>;Davies,
StephenF(OGC)<steve.davies@alaska.gov>
Subject:RE:[EXTERNAL]KRUͲ1CͲ158(PTD223Ͳ056)ͲQuestions
Abby,
Thanksforthoseupdates.
x IseeyouaddedtheADL47449leasetotheapplication,butitlookslikeADL25649gotdroppedoff.I’lladdit
back.
I’vealsoaddedtheacresofSection31inADL47449.
Pleaseconfirmtheseeditsarecorrect.Ifso,nofurtheractionneeded.
2
Looksgood,IconfirmedwithourlandpersonthatADL025649isgoodandshouldhaveanacreageof2560,but
accordingtoherADL047449is2458
x ItalsoappearsthatChapter6MASPCalculationtabledidn’tgetupdatedfromthelatestdirectionalplan.Please
confirmtheeditsshownbelowarecorrect.Again,iftheyare,nofurtheractionisneeded.
x Looksgood
x Finally,intheCasingProgramsectionIamcalculatedadifferentTVDforthetopofthe4.5”liner.Mycalculation
forthe11,900’MDis4,004’TVD.Wouldyoucheckthatplease?
Goodcatch–lookingatoursoftwareitis4007TVD,myprogramdidn’tupdatewhenIputinthenewMD
Thanks,
Andy
From:Warren,Abby<Abby.Warren@conocophillips.com>
Sent:Friday,August4,20234:21PM
To:Dewhurst,AndrewD(OGC)<andrew.dewhurst@alaska.gov>
Subject:RE:[EXTERNAL]KRUͲ1CͲ158(PTD223Ͳ056)ͲQuestions
HiAndy
Belowaremyanswers.Feelfreetogivemeacallifyouhaveanyquestions.Apologiesforthedelay,Iamoutofoffice.
x Idon’tseeaprognosedtopfortheWestSakformation.Wouldyoupleaseprovidethat?[AAC25.005(c)(2)(C)]
o WhenIupdatedtheprogramIputtheseintheretoreflectthetopoftheWestSakD
You don't often get email from abby.warren@conocophillips.com. Learn why this is important
CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open
attachments unless you recognize the sender and know the content is safe.
3
Top of Productive Horizon
(Heel) 1964' FSL, 2320' FEL , S7 T11N R11E, UM
NAD 1927
Northings: 568901
Eastings: 5966981
Measured Depth, RKB: 11373’
Total Vertical Depth, RKB: 3936’
Total Vertical Depth, SS: 3839’
x Itappearsthatthewellpath(briefly)crossesintotheHilcorpleaseADL047449.Ididn’tseethatcalledoutinthe
application.Canyouconfirmthisisbothcorrectandyourintention?Ifso,Iwillupdatetheapplicationtoreflect
it.
o Ispokewithourlandgroupaboutthis.TheADL47449leasestraddlesthePBU/KRUboundaryandis
partiallywithinbothunits.TheDNRhasHilcorpasnotificationlessee,butCPAIandtheKRUWIO’sown
theSW/4oftheleasethatiswithintheKRU.
x DoyouplanonpreͲproducingthisinjector?
o Itwillbeflowedbackfor2weeksforcleanup,nolongerthan30days
x Outofcuriosity,youmentionthatthe1CͲ157isanOHSASproducer.Whatdoesthatstandfor?
o SorryIgetintheacronymwritingandshouldhavewrittenthatout.OHSAS–openholestandalone
screens
Thankyou!
AbbyWarren
From:Dewhurst,AndrewD(OGC)<andrew.dewhurst@alaska.gov>
Sent:Thursday,August3,20233:33PM
To:Warren,Abby<Abby.Warren@conocophillips.com>
Cc:Davies,StephenF(OGC)<steve.davies@alaska.gov>;Guhl,MeredithD(OGC)<meredith.guhl@alaska.gov>;Loepp,
VictoriaT(OGC)<victoria.loepp@alaska.gov>;Roby,DavidS(OGC)<dave.roby@alaska.gov>
Subject:[EXTERNAL]KRUͲ1CͲ158(PTD223Ͳ056)ͲQuestions
CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you
recognize the sender and know the content is safe.
Abby,
InmyreviewofthePTDforthe1CͲ158injector,Ihaveafewquestionsforyou.
x Idon’tseeaprognosedtopfortheWestSakformation.Wouldyoupleaseprovidethat?[AAC25.005(c)(2)(C)]
x Itappearsthatthewellpath(briefly)crossesintotheHilcorpleaseADL047449.Ididn’tseethatcalledoutinthe
application.Canyouconfirmthisisbothcorrectandyourintention?Ifso,Iwillupdatetheapplicationtoreflect
it.
x DoyouplanonpreͲproducingthisinjector?
x Outofcuriosity,youmentionthatthe1CͲ157isanOHSASproducer.Whatdoesthatstandfor?
Iunderstandyouarealsointendingtoupdatethewellplan(extendingTD).
Thanks,
Andy
AndrewDewhurst
SeniorPetroleumGeologist
AlaskaOilandGasConservationCommission
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.
Kuparuk River West Sak Oil Pool
KRU 1C-158
X
223-056
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Ye
s
24
Ad
e
q
u
a
t
e
t
a
n
k
a
g
e
o
r
r
e
s
e
r
v
e
p
i
t
NA
25
If
a
r
e
-
d
r
i
l
l
,
h
a
s
a
1
0
-
4
0
3
f
o
r
a
b
a
n
d
o
n
m
e
n
t
b
e
e
n
a
p
p
r
o
v
e
d
Ye
s
26
Ad
e
q
u
a
t
e
w
e
l
l
b
o
r
e
s
e
p
a
r
a
t
i
o
n
p
r
o
p
o
s
e
d
Ye
s
27
If
d
i
v
e
r
t
e
r
r
e
q
u
i
r
e
d
,
d
o
e
s
i
t
m
e
e
t
r
e
g
u
l
a
t
i
o
n
s
Ye
s
Ma
x
r
e
s
e
r
v
o
i
r
p
r
e
s
s
u
r
e
i
s
1
6
0
7
p
s
i
g
(
8
.
4
p
p
g
E
M
W
)
;
w
i
l
l
d
r
i
l
l
w
/
9
.
0
-
1
0
.
5
p
p
g
E
M
W
28
Dr
i
l
l
i
n
g
f
l
u
i
d
p
r
o
g
r
a
m
s
c
h
e
m
a
t
i
c
&
e
q
u
i
p
l
i
s
t
a
d
e
q
u
a
t
e
Ye
s
29
BO
P
E
s
,
d
o
t
h
e
y
m
e
e
t
r
e
g
u
l
a
t
i
o
n
Ye
s
MP
S
P
i
s
1
2
5
2
p
s
i
g
;
w
i
l
l
t
e
s
t
B
O
P
s
t
o
5
0
0
0
p
s
i
g
i
n
i
t
i
a
l
l
y
a
n
d
3
5
0
0
p
s
i
g
s
u
b
s
e
q
u
e
n
t
l
y
30
BO
P
E
p
r
e
s
s
r
a
t
i
n
g
a
p
p
r
o
p
r
i
a
t
e
;
t
e
s
t
t
o
(
p
u
t
p
s
i
g
i
n
c
o
m
m
e
n
t
s
)
Ye
s
31
Ch
o
k
e
m
a
n
i
f
o
l
d
c
o
m
p
l
i
e
s
w
/
A
P
I
R
P
-
5
3
(
M
a
y
8
4
)
Ye
s
32
Wo
r
k
w
i
l
l
o
c
c
u
r
w
i
t
h
o
u
t
o
p
e
r
a
t
i
o
n
s
h
u
t
d
o
w
n
Ye
s
33
Is
p
r
e
s
e
n
c
e
o
f
H
2
S
g
a
s
p
r
o
b
a
b
l
e
Ye
s
34
Me
c
h
a
n
i
c
a
l
c
o
n
d
i
t
i
o
n
o
f
w
e
l
l
s
w
i
t
h
i
n
A
O
R
v
e
r
i
f
i
e
d
(
F
o
r
s
e
r
v
i
c
e
w
e
l
l
o
n
l
y
)
No
Th
e
r
e
h
a
v
e
b
e
e
n
e
l
e
v
a
t
e
d
H
2
S
l
e
v
e
l
s
n
o
t
e
d
o
n
t
h
e
1
C
p
a
d
p
o
s
t
d
r
i
l
l
i
n
g
35
Pe
r
m
i
t
c
a
n
b
e
i
s
s
u
e
d
w
/
o
h
y
d
r
o
g
e
n
s
u
l
f
i
d
e
m
e
a
s
u
r
e
s
No
Ex
p
e
c
t
e
d
r
e
s
e
r
v
o
i
r
p
r
e
s
s
u
r
e
i
s
a
b
o
u
t
8
.
7
p
p
g
E
M
W
;
w
i
l
l
b
e
d
r
i
l
l
e
d
w
i
t
h
8
.
7
t
o
9
.
5
p
p
g
m
u
d
36
Da
t
a
p
r
e
s
e
n
t
e
d
o
n
p
o
t
e
n
t
i
a
l
o
v
e
r
p
r
e
s
s
u
r
e
z
o
n
e
s
NA
37
Se
i
s
m
i
c
a
n
a
l
y
s
i
s
o
f
s
h
a
l
l
o
w
g
a
s
z
o
n
e
s
NA
38
Se
a
b
e
d
c
o
n
d
i
t
i
o
n
s
u
r
v
e
y
(
i
f
o
f
f
-
s
h
o
r
e
)
NA
39
Co
n
t
a
c
t
n
a
m
e
/
p
h
o
n
e
f
o
r
w
e
e
k
l
y
p
r
o
g
r
e
s
s
r
e
p
o
r
t
s
[
e
x
p
l
o
r
a
t
o
r
y
o
n
l
y
]
Ap
p
r
AD
D
Da
t
e
8/
7
/
2
0
2
3
Ap
p
r
VT
L
Da
t
e
8/
7
/
2
0
2
3
Ap
p
r
AD
D
Da
t
e
8/
7
/
2
0
2
3
Ad
m
i
n
i
s
t
r
a
t
i
o
n
En
g
i
n
e
e
r
i
n
g
Ge
o
l
o
g
y
Ge
o
l
o
g
i
c
Co
m
m
i
s
s
i
o
n
e
r
:
Da
t
e
:
En
g
i
n
e
e
r
i
n
g
Co
m
m
i
s
s
i
o
n
e
r
:
Da
t
e
Pu
b
l
i
c
Co
m
m
i
s
s
i
o
n
e
r
Da
t
e
GCW 08/09/2023
JL
C
8
/
9
/
2
0
2
3
