Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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M.
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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-50150-029-23757-00-00223-045139"11.408"7/31/20253.88/7/2025
1a. Well Status:Oil SPLUG Other Abandoned Suspended
1b. Well Class:
20AAC 25.105 20AAC 25.110 Development Exploratory
GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test
2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry:
Aband.:
3. Address: 7. Date Spudded: 15. API Number:
4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number:
Surface:
Top of Productive Interval: 1097' FSL, 430' FEL S12 T11N R10E 9. Ref Elevations: KB: 17. Field / Pool(s):
GL:57.40 BF:
Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation:
4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number:
Surface: x- y- Zone- 4
TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD:
Total Depth: x- y- Zone- 4
5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD:
Submit electronic information per 20 AAC 25.050 N/A (ft MSL)
22. Logs Obtained:
23.
BOTTOM
20" L-80 159'9 cubic yards 10 yards
10-3/4" L-80 1937'
7-5/8" L-80 3567'
4-1/2" L-80 3579'
24. Open to production or injection? Yes No 25.
26.
Was hydraulic fracturing used during completion? Yes No
DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED
27.
Date First Production: Method of Operation (Flowing, gas lift, etc.):
Hours Tested: Production for Gas-MCF:
Test Period
Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr):
Press. 24-Hour Rate
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
CASING, LINER AND CEMENTING RECORD
List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion,
6.75"
TUBING RECORD
Tail: 107bbl 15.3ppg Class G
9.875"
5975'4-1/2" 5773'MD/3384'TVD
6353'MD/3532'TVD
BOTTOM
96.50'
P.O.Box 100360, Anchorage, AK 99510-0360
562426
1654' FNL, 1418' FWL S12 T11N R10E
4903' FNL, 639' FWL S7 T11N R11E
8/15/2023
1888'MD/1793'TVD
SETTING DEPTH TVD
5965376
HOLE SIZE AMOUNT
PULLEDTOP
SETTING DEPTH MD
GR, RES, DEN, DIR, PWD, NEU, POR, SONIC, CALIPER
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
565880
566955
CEMENTING RECORD
5966087
13.5"
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
ConocoPhillips Alaska, Inc.
WAG
Gas
8/22/2023 223-045
Lead: 341bbl 10.7ppg Class G
Tail: 56bbl 15.8ppg Class G
CASING
50-029-23757-00-00
KRU 1C-501
8/4/2023
7483'MD/3578'TVD
42"
5968586
Kaparuk River Field/ Tertiary Undefined
Water Supply
ADL028243
LONS 01-013
40'
12.6#
40'
6353''
2065'
N/A
TOP
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size
and Number; Date perf'd or liner run):
Liner Ran 8/17/23: 6353'MD-7441'MD/ 3532'TVD-3579'TVD
Gas-Oil Ratio:Choke Size:
suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud
log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing
collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary.
N/A
40'
40'
Per 20 AAC 25.283 (i)(2) attach electronic information
29.7#
7441'
37'
3532'
94#
45.5#
159'
37' 6518'
SIZE DEPTH SET (MD) PACKER SET (MD/TVD)
Sr Res EngSr Pet GeoSr Pet Eng
N/A
Oil-Bbl: Water-Bbl:
Water-Bbl:
PRODUCTION TEST
N/A
Date of Test: Oil-Bbl:
Flow Tubing
Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment
By Grace Christianson at 4:13 pm, Oct 03, 2023
Completed
8/22/2023
JSB
RBDMS JSB 101023
WTRSP
GDSR-10/10/23
Conventional Core(s): Yes No Sidewall Cores:
30.
MD TVD
Surface Surface
1761 1684
1902 1803
2163 2025
2543 2305
Ugnu C 5279 3254
6183 3500
7483 3577
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: Shane McCracken
Digital Signature with Date:
Contact Phone:907-265-6926
General:
Item 1a:
Item 1b:
Item 4b:
Item 9:
Item 15:
Item 19:
Item 20:
Item 22:
Item 23:
Item 24:
Item 27:
Item 28:
Item 30:
Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and
other tests as required including, but not limited to: core analysis, paleontological report, production or well test results.
Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29.
Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool.
If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the
producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,
showing the data pertinent to such interval).
Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit
detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity,
permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology.
Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain).
Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical
laboratory information required by 20 AAC 25.071.
Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion,
suspension, or abandonment; or 90 days after log acquisition, whichever occurs first.
Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
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: shane.m.mccracken@conocophillips.com
Authorized Title: Drilling Engineer
K-15
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:
Ugnu B
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:
Ugnu B
Permafrost - Base
Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov
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Page 1/23
1C-501
Report Printed: 9/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/2/2023
18:00
8/3/2023
00:00
6.00 MIRU, MOVE MOB P DMob and Mob rig to 1C-501 well and
rig up.Split modules and separate, Move
modules around to 1C-501, Spot sub
over new well, Spot pits, pumps,
modules in place.
0.0 0.0
8/3/2023
00:00
8/3/2023
06:00
6.00 MIRU, MOVE MOB P Mob rig to 1C-501 well and rig up.
Move modules around to 1C-501. Spot
in sub, lower stompers to set, and
secure in place for drilling. Skid floor to
drill position.
Mat pits/pump mod footprint. Spot pits
mod to sub, set and secure. Spot pump
mod to pits, set and secure.
Mat courtyard and motors footprint.
Spot motors mod to pump mod, set and
secure.
Spot rock washer via D8 ca(overall
length of SOW/Rockwasher exceeds
pad length t/ set unit w/ truck).
Lay herculite, spot cuttings box, landing
for cuttings box and Magtec vac unit.
0.0 0.0
8/3/2023
06:00
8/3/2023
08:00
2.00 MIRU, MOVE MOB P Cont to lay herculite, spot cuttings box,
landing and MagTec vac unit.
Spot pipe shed mod and take off
suspension
0.0 0.0
8/3/2023
08:00
8/3/2023
11:00
3.00 MIRU, MOVE RURD P Work on rig acceptance check list.
Hook up inner connects around rig.
Swap power from cold starts back to cat
power. Cont rig up: secure all landings
around rig, secure cellar, install skate
rail, ready mud pits and rock washer for
taking on mud. Install 4" valves on
conductor. Swap rig over to high line.
Rig accepted at 11:00
0.0 0.0
8/3/2023
11:00
8/3/2023
12:00
1.00 MIRU, MOVE RURD P Reposition production tree in cellar.
Nipple up surface riser. Obtain RKB’s.
0.0 0.0
8/3/2023
12:00
8/3/2023
18:00
6.00 MIRU, MOVE RURD P Cont to nipple up surface riser. Take on
spud mud to mud pits. Install 2 more
sections of diverter pipe to diverter.
Install 90' mouse hole. Load pipe shed
with drill pipe and HWDP strap and tally.
0.0 0.0
8/3/2023
18:00
8/3/2023
19:30
1.50 MIRU, MOVE RURD P Build stand in 90' mouse hole for
diverter test. Function test diverter w/
Koomey system. Cont to take on spud
mud t/ pits. Double check tools and
equip for spud.
0.0 0.0
8/3/2023
19:30
8/3/2023
20:30
1.00 MIRU, MOVE SEQP P Perform diverter test:
- Koomey draw down test before = 2950
psi, after = 1800 psi, 19 sec for 200 psi
build w/ 2 elec pumps, 65 sec t/ build full
system pressure w/ 2 elec & 2 air
pumps
- N2 6 bottle avg = 1991 psi
- Annular closing time = 26 sec
- Knife valve opening time = 7 sec;
- Test PVT gain/loss, flow out alarms,
LEL and H2S alarms.
Witnessed by AOGCC rep Kam St. John
0.0 0.0
8/3/2023
20:30
8/3/2023
21:45
1.25 MIRU, MOVE RURD P Secure diverter line w/ chains and
barricaded end of diverter off. Install
master bushings. Ready pipeshed and
rig floor tools/equip to PU BHA.
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 8/22/2023
Page 2/23
1C-501
Report Printed: 9/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/3/2023
21:45
8/3/2023
22:30
0.75 MIRU, MOVE SEQP P Line up to fill conductor w/ spud mud, fill
to diverter knife valve (noted slight leak
f/ flange, tightened), fill conductor to
flowline.
0.0 0.0
8/3/2023
22:30
8/4/2023
00:00
1.50 MIRU, MOVE BHAH P PJSM. P/U conductor cleanout BHA as
per SLB rep T/ 41'. P/U & S/O = 52k
0.0 41.0
8/4/2023
00:00
8/4/2023
00:45
0.75 MIRU, MOVE BHAH P Continue to pick up surface drilling
conductor cleanout BHA as per SLB DD
Rep to 41', P/U S/O WT 52k, RIH and
tag bottom@41', Pick up and establish
circulation (good returns), pressure test
surface lines to 3500 psi(good)
0.0 41.0
8/4/2023
00:45
8/4/2023
02:45
2.00 SURFAC, DRILL BKRM P From 41' to 110' MD Ream and
Cleanout conductor with GPM 250, PSI
227, RT/ WT- 56K with RPM 40 TQ 2K,
Pump 30bbl LCM pill, POOH with
cleanout BHA assy.
41.0 110.0
8/4/2023
02:45
8/4/2023
04:30
1.75 SURFAC, DRILL DDRL P Drill 13 1/2” Surface hole section from
110‘ MD to 226‘ MD 226‘ TVD
WOB = 2-5K
GPM = 250
PSI ON = 227
PSI OFF = 220,
RPM = 40
TQ ON = 2-4K
F/O = 14%
ECD = 9.3
P/U WT = 58K
S/O WT = 54K
RT WT = 56K
Max gas units =106
110.0 226.0
8/4/2023
04:30
8/4/2023
05:15
0.75 SURFAC, DRILL BKRM P From 226' to 41' BROOH with GPM 250,
PSI 178, RPM 40 TQ 2k, laydown
conductor cleanout BHA components as
per SLB DD, P/U and S/O weight 50K
226.0 41.0
8/4/2023
05:15
8/4/2023
07:30
2.25 SURFAC, DRILL BHAH P Make up 13 1/2" surface drilling BHA as
per SLB DD, from 41' to179' MD
P/U/S/O weight 67K
41.0 179.0
8/4/2023
07:30
8/4/2023
08:00
0.50 SURFAC, DRILL SRVY P MWD / reset computer soft ware 179.0 179.0
8/4/2023
08:00
8/4/2023
09:00
1.00 SURFAC, DRILL WASH P Wash down from 179’ MD to 211' MD,
GPM 160, PSI 140, F/O 7%, Tag up at
211' MD, Obtain gyro survey, continue to
wash and ream from 211' MD to 226'
MD, GPM 450, PSI 640, F/O
20% ,RPM 40, TQ 1K.
179.0 226.0
8/4/2023
09:00
8/4/2023
12:00
3.00 SURFAC, DRILL DDRL P Drill 13 1/2” Surface hole from 226‘ MD
to 405‘ MD 404‘ TVD,
WOB = 1-2K
GPM = 500,
PSI 860,
RPM 40,
TQ 1K
F/O 22%
ECD 9.83 PPG
P/U WT 74K
S/O WT 66K
RT WT 69K
AST 0.25
ART 2.74
ADT 2.74
Total Bit Hrs 2.74
JAR HRS 0
Max Gas Units 145
226.0 405.0
Rig: DOYON 142
RIG RELEASE DATE 8/22/2023
Page 3/23
1C-501
Report Printed: 9/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/4/2023
12:00
8/4/2023
18:00
6.00 SURFAC, DRILL DDRL P Drill 13 1/2” Surface hole from 405‘MD
to 831‘MD 828‘TVD
WOB 1-2K
GPM 500
PSI 887
RPM = 40
TQ 1K
F/O 20%
ECD = 9.90 PPG
P/U WT 85K
S/O WT 85K
RT WT 84K
AST1.25
ART 1.58
ADT 2.83
Total Bit Hrs 5.57
Jar Hrs 0.42
Max Gas Units 261
405.0 831.0
8/4/2023
18:00
8/5/2023
00:00
6.00 SURFAC, DRILL DDRL P Drill 13 1/2” Surface Hole from 831‘MD
to1302‘MD 1284‘TVD,
WOB 8K,
GPM 500
PSI 1270,
RPM 40,
TQ ON 5K, F/O 26%,
ECD 9.96 PPG
P/U WT 95K,
S/O WT 94K,
RT WT 94K,
AST 2.33,
ART 1.71,
ADT 4.04,
Total 9.61,
Jar Hrs 4.46,
Max Gas Units 10,199, @1182' Due to
Gas Hydrates
Mud Cur from 9.2 to 9.0 PPG
Mud No losses
831.0 1,302.0
8/5/2023
00:00
8/5/2023
06:00
6.00 SURFAC, DRILL DDRL P Drill 13 1/2” Surface hole from 1302‘ MD
to 1867‘ MD 1773‘ TVD
WOB = 9K
GPM = 500
PSI ON 1403
RPM 40
TQ 5K
FLOW OUT 27%,
ECD 10.74 PPG
P/U WT 103K
S/O WT 98K
RT WT 100K
AST 2.11
ART 1.90
ADT 4.01
TOTAL BIT HRS 13.62
Total jars 8.47
Max gas 5162
1,302.0 1,867.0
Rig: DOYON 142
RIG RELEASE DATE 8/22/2023
Page 4/23
1C-501
Report Printed: 9/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/5/2023
06:00
8/5/2023
08:30
2.50 SURFAC, DRILL DDRL P Drill 13 1/2” Surface hole from 1867‘ MD
to 2070‘ MD 1941' TVD
WOB 4K
GPM 500
PSI ON 1242
RPM 40
TQ 5K
FLOW OUT 28%
ECD 10.42 PPG
P/U WT 114K
S/O WT 101K
RT WT 101K
AST 0.17
ART 1.23
ADT 1.40
Total bit hrs 15.02
Total jars= 9.87
Max gas units 1115
Shoot final survey and send downlink
for tool data as per SLB DD. Obtain final
torque and drag at TD. Pump down fluid
caliper oats for a surface-to-surface
volume, chase with 30bbls 40ppb nut
plug sweep while pumping at drilling
rate.
1,867.0 2,070.0
8/5/2023
08:30
8/5/2023
08:45
0.25 SURFAC, TRIPCAS OWFF P OWFF (Static) 2,070.0 2,070.0
8/5/2023
08:45
8/5/2023
12:00
3.25 SURFAC, TRIPCAS BKRM P BROOH from 2070‘MD to 1290‘MD
GPM 500
PSI 1120
RPM 40
TQ 3K
F/O 33%
ECD 10.6PPG
P/U WT 91K
S/O WT 93K
RT WT 88K
Max gas units 9018
2,070.0 1,290.0
8/5/2023
12:00
8/5/2023
15:45
3.75 SURFAC, TRIPCAS BKRM P BROOH from 1290‘MD - TO 179‘MD
GPM 50
PSI 884
RPM 40
TQ 2K
F/O 31%
ECD 10.62PPG
P/U WT 62K
S/O WT 61K
RT WT 66K
Max gas 758
@ 160’ Pump 30bbl nut plug sweep to
scour BHA.
1,290.0 179.0
8/5/2023
15:45
8/5/2023
16:00
0.25 SURFAC, TRIPCAS OWFF P OWFF(Static) SIMOPS- Laydown stand
heavy weight drill pipe from derrick to
pipe shed.
179.0 179.0
8/5/2023
16:00
8/5/2023
18:45
2.75 SURFAC, TRIPCAS BHAH P PJSM, Laydown BHA as per SLB DD
and MWD. From 179' to surface.
179.0 0.0
8/5/2023
18:45
8/5/2023
19:45
1.00 SURFAC, TRIPCAS CLEN P Clean and clear rig floor. Laydown BHA
tools via beaver slide
0.0 0.0
8/5/2023
19:45
8/5/2023
20:30
0.75 SURFAC, CASING WWSP P Dummy run 10-3/4” casing hanger,
verify seat as per Vault Rep.
0.0 0.0
8/5/2023
20:30
8/5/2023
22:00
1.50 SURFAC, CASING RURD P Rig up 10-3/4” 45.5# L-80 HYD563
surface casing running equipment as
per Doyon casing Rep.
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 8/22/2023
Page 5/23
1C-501
Report Printed: 9/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/5/2023
22:00
8/6/2023
00:00
2.00 SURFAC, CASING PUTB P PJSM, Run 10-3/4” 45.5# L-80 HYD563
surface casing as per tally to 405’ Baker
Loc shoe track verify floats holding
(Good). M/U torque 16k. Double bump
each connection. Fill on fly top off every
10 joints. Monitoring displacement on
pits #1 and #2
0.0 405.0
8/6/2023
00:00
8/6/2023
06:00
6.00 SURFAC, CASING PUTB P PJSM, Run 10-3/4 45.5# L-80 HYD563
surface casing as per tally. from 405' to
2021' M/U torque 16,000 ft/lbs. double
bump connections. fill on fly top off
every joints. monitoring displacement on
pit #2. SOW 90k
405.0 2,021.0
8/6/2023
06:00
8/6/2023
06:30
0.50 SURFAC, CASING PUTB P From 2012' to 2065' make up hanger
assy. to landing jt. and run in the hole,
washdown with 0.5 BPM 136psi to land
on seat, S/O 88k.
2,021.0 2,065.0
8/6/2023
06:30
8/6/2023
08:30
2.00 SURFAC, CEMENT CIRC P @2065' circulate and condition while
reciprocating casing staging pumps up
to final circulation rate @ 6bpm/172psi,
P/U 135 S/O 100K, drop fluid caliper
oats and circulate surface to surface
volume, SIMOPS- Prepare for cement
job, laydown excess casing tools and
equipment.
2,065.0 2,065.0
8/6/2023
08:30
8/6/2023
10:45
2.25 SURFAC, CEMENT CIRC P Rig up cement line to volant CRT,
continue to circulate and condition mud
system with 6bpm/186psi for 1377bbls
total pumped P/U 137k and S/O 96k.
2,065.0 2,065.0
8/6/2023
10:45
8/6/2023
12:00
1.25 SURFAC, CEMENT CMNT P PJSM, Surface cement job, Cement 10
3/4'' surface csg as per Halliburton
pump sch., flood lines 5 bbls H2O@ 4
BPM, 43PSi, Pressure test lines to 3500
psi, pump 56.7 bbl, 10.17 ppg tuned
prime space with 8lb red dye @ 4 BPM,
70 PSI,
2,065.0 2,065.0
8/6/2023
12:00
8/6/2023
15:30
3.50 SURFAC, CEMENT CMNT P Cont. Cement 10-3/4 surface csg as per
Halliburton pump schedule, Shutdown
and drop bottom plug. Pump 347 BBLS
10.7 PPG lead cement @ 4 BPM, 112
PSI. Pump 56 bbls 15.8 PPG tail cmt @
6 BPM, 58 PSI. Shutdown and drop top
plug. Flush with 20 bbls fresh H2O, line
up to rig pumps to displace with 164
bbls @ 5 BPM, 90 PSI for 1580 strokes,
slow rate to 3 BPM 347 PSI for final
stroke, bump plug @ 1645 strokes initial
347 PSI, pressure up to 840 PSI. Hold
for 5 min. Check floats, (good) cement
in place @ 14:48 hrs. 143 BBLS cement
returns to surface.
2,065.0 2,065.0
8/6/2023
15:30
8/6/2023
17:00
1.50 SURFAC, WHDBOP RURD P Rig down surface casing running
equipment, Volant, bail extenders,
elevators, laydown landing joint, drain
stack and flush conductor ports and
starting head ports, flush the surface
annular with black H2O, disconnect
knife valve and function surface annular
3x, drain stack final and ready to nipple
down surface riser equipment.
2,065.0 2,065.0
Rig: DOYON 142
RIG RELEASE DATE 8/22/2023
Page 6/23
1C-501
Report Printed: 9/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/6/2023
17:00
8/7/2023
00:00
7.00 SURFAC, WHDBOP NUND P Nipple down surface riser, surface
annular, starting head, diverter tee, knife
valve, speed head, clean cellar box,
install wellhead test to 2000psi f/10mins.
as per vault rep, verify orientation as per
CPAI operations. Nipple up spacer
spool, bop stack, kill line and torque to
spec.
2,065.0 2,065.0
8/7/2023
00:00
8/7/2023
03:00
3.00 SURFAC, WHDBOP NUND P Continue nipple up choke line, Dutch
riser, riser, mouse hole, annular valves.
Obtain RKB’s. Install 4'' plug caps on
conductor.
0.0 0.0
8/7/2023
03:00
8/7/2023
04:15
1.25 SURFAC, WHDBOP WWSP P Set test plug with 7-5/8” test joint as per
vault Rep. Rig up BOP test equipment,
grease choke manifold. (SIMOPS-load
pipeshed with 4''dp)
0.0 0.0
8/7/2023
04:15
8/7/2023
07:00
2.75 SURFAC, WHDBOP WWSP P Flood lines, choke manifold, shell test
BOP's. Purge lines with air and check
for leaks. SIMOP's - Wrap and test
conductor ports for analysis.
0.0 0.0
8/7/2023
07:00
8/7/2023
12:00
5.00 SURFAC, WHDBOP BOPE P Test BOPE. All tests to 250 low 5,000
high for 5 charted minutes with
exception of manual operated & super
choke tested to 250 low & 2,000 psi for
5 charted minutes, with 7 5/8" test joint
test annular, 7 5/8" upper pipe ram, with
5" test jt test annular 2 7/8" x 5" lower
pipe ram, test choke valves 1-15,
manual operated & super choke, choke
& kill manuals & HCR’s, 4" valve on kill
line, 5" FOSV 2x, 5" dart valve, upper &
lower IBOP; blind/ shear rams; perform
Koomey drawdown, acc = 3000 psi.
manifold. = 1500 PSI. acc = 1850 PSI
after all functions on bottles, 9 seconds
for 200 psi. build with 2 electrics pumps,
55 seconds to build full system.
pressure with 2 electric & 2 air pumps, 6
bottle avg.= 1983psi, closing times
annular = 12 seconds. upper pipe rams
= 7 seconds. blind / shears = 7 seconds.
lower pipe rams = 7 seconds. choke
HCR = 2 seconds. kill HCR = 2
seconds; test PVT gain/loss and flow
out alarms, test LEL and H2S alarms;
witnessed by AOGCC Rep Brian Bixby
0.0 0.0
8/7/2023
12:00
8/7/2023
13:00
1.00 SURFAC, WHDBOP BOPE P Continue test BOPE, blinds and 5" dart
valve to 250 psi low 5,000 psi high for 5
charted minutes.
0.0 0.0
8/7/2023
13:00
8/7/2023
13:30
0.50 SURFAC, WHDBOP RURD P Pull test plug, rig down test equipment 0.0 0.0
8/7/2023
13:30
8/7/2023
13:45
0.25 SURFAC, WHDBOP WWSP P Install wear bushing per Vault Rep, ID =
12 3/8", OD = 13 3/8" length= 33”.
0.0 0.0
8/7/2023
13:45
8/7/2023
14:15
0.50 SURFAC, DRILLOUT CLEN P Clean rig floor, rig up and prep tools to
run BHA
0.0 0.0
8/7/2023
14:15
8/7/2023
16:15
2.00 SURFAC, DRILLOUT BHAH P PJSM, P/U 9 7/8" intermediate BHA as
per SLB DD from surface to 155' MD,
U/D wt.- 60k
0.0 155.0
8/7/2023
16:15
8/7/2023
19:00
2.75 SURFAC, DRILLOUT TRIP P From 155' to 1847' MD, RIH with
5"HWDP from derrick for 3 stands,
Single in the hole from the pipeshed
with 5" drill pipe for 39 jts, SOW=88k
155.0 1,847.0
8/7/2023
19:00
8/7/2023
20:00
1.00 SURFAC, DRILLOUT SRVY P Shallow hole test MWD tool as per SLB
DD. 450 gpm, 630 psi, 32% F/O. Wash
down from 1847' MD to TOC @1962'.
Tag with 10k WOB to verify. SOW=88k
1,847.0 1,976.0
Rig: DOYON 142
RIG RELEASE DATE 8/22/2023
Page 7/23
1C-501
Report Printed: 9/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/7/2023
20:00
8/7/2023
21:45
1.75 SURFAC, DRILLOUT PRTS P R/U test 10-3/4'' surface casing.
3000psi, for 30 minutes charted.
Pumped 30stks, 3bbls, at 1/2 bpm with
3bbl bleed back. 9.5ppg mud weight.
Good Test
1,976.0 1,900.0
8/7/2023
21:45
8/8/2023
00:00
2.25 SURFAC, DRILLOUT COCF P Wash down to plugs and float collar @
1976' MD 450 gpm, 612 psi, 30% F/O.
Drill shoe track adjusting parameters
450 gpm, 615 psi, 40 RPM, 4k torque,
WOB=2-8k. ROT= 90k (SIMOPS, P/U
4'' drill pipe with single joint elevators
and rack back in derrick 16 stands)
1,900.0 1,976.0
8/8/2023
00:00
8/8/2023
06:00
6.00 SURFAC, DRILLOUT DRLG P Continue drilling shoe track adjusting
parameters as needed. GPM 450, PSI
605, RPM 40, TQ 4K, WOB 2-9k.
Drilling plugs/float collar, RPM 80, TQ 2-
5k, WOB 2-3. Drilling cement/float shoe
to 2,070' MD. Drill 20' of rat hole to
depth of 2090' MD. Work through shoe
4x. Continue making up and rack back
29 stands of 4'' drill pipe for production
section offline via single joint elevators.
ADT .25, Bit hours .25, Jar hours 10.12
1,976.0 2,090.0
8/8/2023
06:00
8/8/2023
06:30
0.50 SURFAC, DRILLOUT BKRM P From 2090' to 2030' MD, Pull out of the
hole and rack stand to derrick for LOT/
FIT test space out, circulate and
condition mud while conducting MWD
survey with GPM 555, PSI 835, U/D wt
92k.
2,090.0 2,030.0
8/8/2023
06:30
8/8/2023
07:45
1.25 SURFAC, DRILLOUT LOT P Rig up for FIT/LOT test, break
circulation (good), formation integrity
test - pumped 10stks/1bbl to observe
leak off pressure at 350 psi / 13.0 ppg
EMW. MAx pressure observerd 454 psi.
Shutdown and isolate while monitoring
pressure, bleed off pressure to pits (1bbl
bleed back), rig down test equipment,
make up stand from derrick and ready
pits for displacement.
2,030.0 2,030.0
8/8/2023
07:45
8/8/2023
08:30
0.75 SURFAC, DRILLOUT CIRC P Pump up survey for MWD with GPM
550, PSI 835, U/D wt. 91k. Set depth at
the connection, pump the 32 bbl hi-vis
spacer for displacing to 9 ppg FWP
(Noted mud loss at the drag chain chute
to rockwasher, immediately shutdown to
assess the spill at the rockwasher.)
2,030.0 2,030.0
8/8/2023
08:30
8/8/2023
10:45
2.25 SURFAC, DRILLOUT CLEN T Clean up spill from pits drag chain chute
to rockwasher (obstructed with cuttings),
overflow to rockwasher roof, determined
2/5bbls in containment to rig mats below
at ground level.
2,030.0 2,030.0
8/8/2023
10:45
8/8/2023
11:30
0.75 SURFAC, DRILLOUT CIRC P Displace well from 9.6 PPG Spud Mud
to 9 PPG FWP with GPM 550, PSI 854,
U/D wt.= 92k.
2,030.0 2,090.0
Rig: DOYON 142
RIG RELEASE DATE 8/22/2023
Page 8/23
1C-501
Report Printed: 9/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/8/2023
11:30
8/8/2023
12:00
0.50 INTRM1, DRILL DDRL P Drill 9 7/8” Intermediate hole from 2090‘
MD to 2129‘ MD 1989‘ TVD
WOB 12
GPM 650
PSI 864
RPM 60
TQ 3k
F/O 22%
ECD 9.83 PPG
P/U wt 95k
S/O wt 93k
RT wt 92k
ADT.68
Total Bit hrs.93
Total Jar hrs 10.80
2,090.0 2,129.0
8/8/2023
12:00
8/8/2023
18:00
6.00 INTRM1, DRILL DDRL P Drill 9 7/8” intermediate hole from
2129‘MD to 2506‘MD 2274‘TVD
WOB 1,
GPM 700
PSI 926
RPM 120
TQ 3k
F/O 70%
ECD 9.71 PPG
P/U wt 101k
S/O wt 99k
RT wt 99k
ADT 4.08
Total Bit hrs 5.01
Total Jar hrs 14.88
2,129.0 2,506.0
8/8/2023
18:00
8/9/2023
00:00
6.00 INTRM1, DRILL DDRL P Drill 9 7/8” intermediate hole from
2506‘MD to 3071‘MD 2593‘TVD,
WOB 3
GPM 700
PSI 1046
RPM 120
TQ 3k
F/O 70%
ECD 10.09 PPG
P/U wt 104k
S/O wt 99k
RT wt 101k
ADT 4.20
Total Bit hrs 9.21
Total Jar hrs 19.08
2,506.0 3,071.0
8/9/2023
00:00
8/9/2023
06:00
6.00 INTRM1, DRILL DDRL P Drill 9 7/8” Intermediate hole from
3071‘MD to 3690‘MD, TVD 2785,
WOB 3,
GPM 700,
PSI 1157,
RPM 120,
TQ 3k,
F/O 79%,
ECD 10.36 PPG
P/U wt 107k,
S/O wt 98k,
RT wt 101k,
Max gas 182
ADT 4.48,
Total bit hrs13.69,
Total jar hrs 23.56
3,071.0 3,690.0
Rig: DOYON 142
RIG RELEASE DATE 8/22/2023
Page 9/23
1C-501
Report Printed: 9/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/9/2023
06:00
8/9/2023
12:00
6.00 INTRM1, DRILL DDRL P Drill 9 7/8” Intermediate hole from
3690‘MD to 4299‘MD 2967‘TVD
WOB 5
GPM 700
RPM 120
TQ 5k
F/O 69%
ECD 10.56 PPG
P/U wt 118k
S/O wt 97k
RT wt 105k,
Max gas 194
ADT 4.17
Total bit hrs17.86
Total jar hrs 27.73
3,690.0 4,299.0
8/9/2023
12:00
8/9/2023
18:00
6.00 INTRM1, DRILL DDRL P Drill 9 7/8” Intermediate hole from
4299‘MD to 4864‘MD 3125‘TVD
WOB 5
GPM 700
PSI 1356
RPM 120
TQ 5k
F/O 69%
ECD 10.68 PPG
P/U wt 118k
S/O wt 100k
RT wt 108k
ADT 4.62
Total bit hrs 22.48
Total jar hrs 32.35
Max gas unit 171
4,299.0 4,864.0
8/9/2023
18:00
8/10/2023
00:00
6.00 INTRM1, DRILL DDRL P Drill 9 7/8” Intermediate hole from
4864‘MD to 5526‘MD 3314‘TVD
WOB 8
GPM 700
PSI on 1518
RPM 120
TQ 7k
F/O 69%
ECD 11.04 PPG
P/U wt 124k
S/O wt 102k
RT wt 109k
ADT 4.07
Total bit hrs 26.55
Total jar hrs 36.42
Max gas unit 118
4,864.0 5,526.0
8/10/2023
00:00
8/10/2023
06:00
6.00 INTRM1, DRILL DDRL P Drill 9 7/8” Intermediate hole from
5526‘MD to 6050‘MD 3456‘TVD
WOB 5
GPM 700
PSI on 1583
RPM 120
TQ 7k
F/O 69%
ECD 11.07 PPG
P/U wt 124k
S/O wt 103k
RT wt 110k
ADT 4.72
Total bit hrs 31.27
Total jar hrs 41.14
Max gas unit 202
5,526.0 6,050.0
Rig: DOYON 142
RIG RELEASE DATE 8/22/2023
Page 10/23
1C-501
Report Printed: 9/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/10/2023
06:00
8/10/2023
10:30
4.50 INTRM1, DRILL DDRL P Drill 9 7/8” Intermediate hole from
6050‘MD to 6521‘MD 3568‘TVD
WOB 5
GPM 700
PSI on 1613
RPM 120
TQ 7k
F/O 69%
ECD 11.07 PPG
P/U wt 130k
S/O wt 108k
RT wt 117k
ADT 2.82
Total bit hrs 34.09
Total jar hrs 43.96
Max gas unit 170
6,050.0 6,521.0
8/10/2023
10:30
8/10/2023
11:30
1.00 INTRM1, TRIPCAS CIRC P @ 6521' MD Obtain final survey, SPR's.
and Torque and drag values. Drop
Ellison fluid caliper oats and Circulate to
suface as per Ellison Rep.
6,521.0 6,521.0
8/10/2023
11:30
8/10/2023
12:00
0.50 INTRM1, TRIPCAS BKRM P BROOH from 6521'MD to 6472'MD
GPM 700
PSI 1613
RPM 100
TQ 3k
F/O 69
ECD 11.07
P/U wt 130
S/O wt 106
RT wt 116k
6,521.0 6,472.0
8/10/2023
12:00
8/10/2023
12:30
0.50 INTRM1, TRIPCAS OWFF P OWFF - well static. 6,472.0 6,472.0
8/10/2023
12:30
8/10/2023
18:00
5.50 INTRM1, TRIPCAS BKRM P BROOH from 6472'MD to 4678'MD
GPM 700
PSI 1613
RPM 100
TQ 3k
F/O 69
ECD 11.01
P/U wt 125
S/O wt 106
RT wt 110k
6,472.0 4,678.0
8/10/2023
18:00
8/11/2023
00:00
6.00 INTRM1, TRIPCAS BKRM P BROOH from 4678'MD to 2875'MD
GPM 700
PSI 1613
RPM 100
TQ 3k
F/O 69
ECD 10.68
P/U wt 115
S/O wt 101
RT wt 96k
4,678.0 2,875.0
8/11/2023
00:00
8/11/2023
04:00
4.00 INTRM1, TRIPCAS BKRM P BROOH from 2875' MD to 2030' MD.
GPM 700
PSI 1613
RPM 100
TQ 3k
F/O 69
ECD 10.68
P/U wt 115
S/O wt 101
RT wt 96k
2,875.0 2,030.0
Rig: DOYON 142
RIG RELEASE DATE 8/22/2023
Page 11/23
1C-501
Report Printed: 9/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/11/2023
04:00
8/11/2023
05:00
1.00 INTRM1, TRIPCAS CIRC P From 2030' MD to 1850' MD @ shoe
pumped 10 PPG 30 BBL nut plug
sweep. Circulate and Condition mud 2x
bottoms up.
GPM 700
PSI 1000
ECD 10.46
RPM 60
TQ 1.5k
2,030.0 1,850.0
8/11/2023
05:00
8/11/2023
05:15
0.25 INTRM1, TRIPCAS OWFF P OWFF well static. 1,850.0 1,850.0
8/11/2023
05:15
8/11/2023
06:15
1.00 INTRM1, TRIPCAS TRIP P POOH on elevators from 1850' MD to
430' MD. Monitoring displacement on
trip tank. P/U 75k.
1,850.0 430.0
8/11/2023
06:15
8/11/2023
07:00
0.75 INTRM1, TRIPCAS PULD P POOH laying down heavy weight drill
pipe from 430' MD to 151' MD P/U 56k.
430.0 151.0
8/11/2023
07:00
8/11/2023
07:15
0.25 INTRM1, TRIPCAS OWFF P OWFF well static. 151.0 151.0
8/11/2023
07:15
8/11/2023
09:15
2.00 INTRM1, TRIPCAS BHAH P PJSM, Lay down 9-7/8" Intermediate
BHA as per SLB DD and MWD P/U 47k.
151.0 0.0
8/11/2023
09:15
8/11/2023
10:00
0.75 INTRM1, TRIPCAS CLEN P Clean and clear rig floor of excess BHA
tools and handling equipment. Ready
tools to pull wear bushing.
0.0 0.0
8/11/2023
10:00
8/11/2023
11:30
1.50 INTRM1, TRIPCAS WWWH P Pull wear bushing as per Vault Rep.
(Large amount of clay cuttings pull to
surface). Wash stack and well head
profile 4x. GPM 800, PSI 81.
0.0 0.0
8/11/2023
11:30
8/11/2023
13:30
2.00 INTRM1, CASING RURD P Rig up Doyon casing handling tools for 7
-5/8" casing as per Doyon casing Rep.
0.0 0.0
8/11/2023
13:30
8/11/2023
13:45
0.25 INTRM1, CASING SFTY P PJSM, Running 7-5/8" Intermediate
casing with all hands involved.
0.0 0.0
8/11/2023
13:45
8/11/2023
18:00
4.25 INTRM1, CASING PUTB P M/U 7-5/8” Shoe and Float assy as per
Doyon casing Rep. Baker Lok Joints 1-
4. Check floats. Witness By CPAI Rep.
P/U and run 7-5/8” 29.7# L-80 R3
HYD563 intermediate casing as tally to
1625’. Make up torque 10,300 Ft-lbs. Fill
pipe on the fly and top off every 10
joints. Monitor displacement on pit #1.
SOW 84k.
0.0 1,625.0
8/11/2023
18:00
8/11/2023
19:00
1.00 INTRM1, CASING PUTB P P/U and run 7-5/8” 29.7# L-80 R3
HYD563 intermediate casing as tally
from 1625’ MD to 2041’ MD. Make up
torque 10,300 Ft-lbs. Fill pipe on the fly
and top off every 10 joints. Monitor
displacement on pit #1. SOW 94k.
1,625.0 2,041.0
8/11/2023
19:00
8/11/2023
20:00
1.00 INTRM1, CASING CIRC P Circulate and Recipicate @ surface
shoe from 2041' MD to 2069' MD. While
staging up pump rate in 0.5 bbls
increments to final rate of 6 BPM, PSI
164, F/O 16%, P/U 93k, S/O 94k . Total
strokes pumped 2169.
2,041.0 2,069.0
8/11/2023
20:00
8/12/2023
00:00
4.00 INTRM1, CASING PUTB P P/U and Run 7-5/8” 29.7# L-80 R3
HYD563 intermediate casing as tally
from 2069' MD to 3766’ MD. Make up
torque 10,300 Ft-lbs. Fill pipe on the fly
and top off every 10 joints. Monitor
displacement on pit #1. SOW 102k.
2,069.0 3,766.0
8/12/2023
00:00
8/12/2023
06:30
6.50 INTRM1, CASING PUTB P P/U and Run 7-5/8” 29.7# L-80 R3
HYD563 intermediate casing as tally
from 3766'' MD to 6433’ MD. Make up
torque 10,300 Ft-lbs. Fill pipe on the fly
and top off every 10 joints. Monitor
displacement on pit #1. SOW 150k.
3,766.0 6,433.0
Rig: DOYON 142
RIG RELEASE DATE 8/22/2023
Page 12/23
1C-501
Report Printed: 9/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/12/2023
06:30
8/12/2023
07:30
1.00 INTRM1, CASING PUTB P Make up 7-5/8" x 10-3/4" mandrel
hanger and landing joint. Drain stack,
land out hanger at 6518.1' MD. Verfiied
by Vault Rep. SOW 154k.
6,433.0 6,518.1
8/12/2023
07:30
8/12/2023
10:15
2.75 INTRM1, CEMENT CIRC P Circulate, reciprocate, and condition
mud for cement job from 6514‘MD to
6504‘MD. Stage up pumps in 1/2 BPM
increment. 1 bpm - 216 PSI, 6 BPM -
435 PSI, F/O 18%, P/U wt 133k, S/O wt
107k. Total pumped strokes 7678.
6,518.1 6,518.0
8/12/2023
10:15
8/12/2023
12:00
1.75 INTRM1, CEMENT CMNT P Perform cement job for 7-5/8''
Intermediate casing as per Halliburton
pump schedule. Flood lines w/ 5 BBLS
H2O, 4.5 BPM @ 500 PSI. Pressure
test lines to 4000 PSI. Drop #1 bottom
plug. Pump 58 BBLS 10.5ppg tuned
spacer @ 4.3 BPM 450 PSI, F/O 13%.
Drop #2 bottom plug. Pump 102 BBLS
15.3 PPG Tail cement @ 2-4 BPM FCP
200psi @ 3 BPM.
6,518.0 6,518.0
8/12/2023
12:00
8/12/2023
13:30
1.50 INTRM1, CEMENT CMNT P Cont. Perform cement job for 7-5/8''
Intermediate casing as per Halliburton
cement schedule. Drop top plug. Pump
20 BBLS H2O @ 5 BPM @ 180 PSI.
Line up to rig pumps to displace @
6bpm, ICP 70 PSI, FCP 960 PSI.
Reduce pump rate to 3 BPM @ 2500
strokes, ICP 637 PSI, FCP 762 PSI.
Bump plug @ 2721 strokes, 274 BBLS.
Pressure up to 1300 PSI. Hold for 5
minutes and bleed off. Check floats
(holding). Final P/U 123k, S/O 90k. Max
pump pressure 960 PSI. Cement in
place @ 13:12hrs.
6,518.0 6,518.0
8/12/2023
13:30
8/12/2023
14:15
0.75 INTRM1, CEMENT PRTS P Pressure test 7-5/8'' Intermediate casing
to 3000psi, for 30 minutes charted.
Pump @ 1/2 BPM 72strokes to 7.2
BBLS. Bleed back volume 4 BBLS.
6,518.0 6,518.0
8/12/2023
14:15
8/12/2023
15:45
1.50 INTRM1, CEMENT RURD P Rig down casing and cement
equipment. Clean cement valves.
0.0 0.0
8/12/2023
15:45
8/12/2023
18:30
2.75 INTRM1, WHDBOP WWSP P Install and test 7-5/8'' pack-off to
5000psi for 10minutes as per Vault rep.
Witnessed by CPAI Rep.
0.0 0.0
8/12/2023
18:30
8/12/2023
21:30
3.00 INTRM1, WHDBOP SVRG P Change 7-5/8" upper rams to 3-1/2" x 6"
VBR’s. SIMOPS change NC-50 saver
sub to XT-39. Clean under shakers &
mud trough.
0.0 0.0
8/12/2023
21:30
8/13/2023
00:00
2.50 INTRM1, WHDBOP BOPE P R/U to test jt, dart, 2 FOSV to test
BOPE. Set test plug per Vault Rep.
Flood lines and test equipment to
prepare for shell test.
0.0 0.0
8/13/2023
00:00
8/13/2023
01:00
1.00 INTRM1, WHDBOP WWWH P Flush stack with fresh water,
function/clear ram cavities & annular of
drilling mud/debris, shell test BOPE.
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 8/22/2023
Page 13/23
1C-501
Report Printed: 9/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/13/2023
01:00
8/13/2023
08:30
7.50 INTRM1, WHDBOP BOPE P Test BOPE all tests to 250 PSI low,
3,500 PSI high for 5 charted minutes
with exception of manual operated &
super choke tested to 2500 psi charted,
with 4" test joint test annular, 3 1/2" x 6"
upper pipe ram, 2 7/8" x 5" lower pipe
ram, with 4 1/2" test joint test annular 3
1/2" x 6" upper pipe ram, 2 7/8" x 5"
lower pipe ram, with 2 7/8" test jt
annular & 2 7/8" x 5" lower pipe ram,
test choke valves 1-15, manual
operated & super choke, choke & kill
manuals & HCR’s, 4" valve on kill line,
4" FOSV, 4" dart valve, upper & lower
IBOP, blind shear rams, perform
Koomey drawdown, accumulator 3000
PSI. manifold 1400 PSI, accumulator
1800 PSI after all functions on bottles, 8
sec for 200 PSI. Build pressure with 2
electric pumps, 53 seconds to build full
system pressure with 2 electric & 2 air
pumps, closing times annular 15
seconds, upper pipe rams 7 sec, blind /
shears 7 seconds, Lower pipe rams 7
seconds, choke HCR 2 seconds, kill
HCR 2 seconds, test PVT gain/loss and
flow out alarms, test LEL and H2S
alarms; AOGCC Rep Guy Cook waived
witness @ 16:22 hrs on 08/10/23.
0.0 0.0
8/13/2023
08:30
8/13/2023
09:00
0.50 INTRM1, WHDBOP RURD P Pull test plug, rig down test equipment,
blow down kill/choke lines. Line up
choke manifold to drill position
0.0 0.0
8/13/2023
09:00
8/13/2023
09:15
0.25 INTRM1, WHDBOP WWSP P Install wear bushing as per Vault Rep.
ID 9'' OD 13-1/2'' Length= 14-3/4''
0.0 0.0
8/13/2023
09:15
8/13/2023
10:00
0.75 INTRM1, DRILLOUT BHAH P Mobilize production BHA to rig floor via
beaverslide
0.0 0.0
8/13/2023
10:00
8/13/2023
12:00
2.00 INTRM1, DRILLOUT BHAH P PJSM, pick up 6-3/4'' production BHA as
per SLB DD, MWD from surface to 385'
P/U, S/O wt=60k.
0.0 385.0
8/13/2023
12:00
8/13/2023
14:00
2.00 INTRM1, DRILLOUT TRIP P TIH with 6-3/4'' production BHA from
385‘MD to 2266‘MD, P/U 27 joint of 4”
drill pipe from pipeshed. SOW = 70k.
Monitor disp. on pit #1, pill pit #2. Filling
pipe every 20stds.
385.0 2,266.0
8/13/2023
14:00
8/13/2023
14:45
0.75 INTRM1, DRILLOUT SRVY P Shallow hole test MWD tools. Send a
downlink to turn on Sonicscope for
cement logging. GPM 220, PSI 1109,
F/O 15%
2,266.0 2,266.0
8/13/2023
14:45
8/13/2023
15:15
0.50 INTRM1, DRILLOUT DLOG P Cement logs in real time with
Sonicscope, logging speed 450 FPH,
pump rate GPM 220, PSI 1070, F/O
15% from 2266'MD to 2365'MD. S/O
70k.
2,266.0 2,365.0
8/13/2023
15:15
8/13/2023
16:30
1.25 INTRM1, DRILLOUT TRIP P TIH with 6-3/4'' production BHA from
2365‘MD to 3690‘MD, Monitor
displacement on pit #1, pill pit #2. Filling
pipe every 20stds. S/O 80k.
2,365.0 3,690.0
8/13/2023
16:30
8/13/2023
17:30
1.00 INTRM1, DRILLOUT DLOG P Cement logs in real time with
Sonicscope, logging speed 450 FPH,
pump rate GPM 220, PSI 1205, F/O
15% from 3690'MD to 3879'MD. S/O
80k.
3,690.0 3,879.0
8/13/2023
17:30
8/13/2023
17:45
0.25 INTRM1, DRILLOUT TRIP P TOOH from 3879'MD to 3407'MD
P/U=86k. Begin cement logging at
higher depth to verify top of cement.
3,879.0 3,407.0
Rig: DOYON 142
RIG RELEASE DATE 8/22/2023
Page 14/23
1C-501
Report Printed: 9/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/13/2023
17:45
8/13/2023
20:45
3.00 INTRM1, DRILLOUT DLOG P Cement log in real time with
Sonicscope. logging speed 800 FPH,
pump rate GPM 230, Psi 1255, F/O 15%
from 3407'MD to 4066'MD. S/O 80k.
3,407.0 4,066.0
8/13/2023
20:45
8/13/2023
21:15
0.50 INTRM1, DRILLOUT TRIP P TIH from 4066'MD to 4500'MD logging
@ 1800 FPH. TIH from 4500'MD to
5316’MD logging @ 5400 FPH. S/O
78k.
4,066.0 5,316.0
8/13/2023
21:15
8/13/2023
22:45
1.50 INTRM1, DRILLOUT FRZP P R/U to perform injectivity test on OA.
Perform injectivity test @ 5 SPM, 102
total strokes. Fluid pack OA with 5
BBLS. Observed practical break over at
380 PSI continue pressure up to max
pressure 430 PSI with 3.8 BBLS,
monitor OA PSI, after 20 minutes, OA
pressure bled down to 180 psi. Bled
remaining PSI with 2.3 bbl return. R/D &
blow down injection line.
5,316.0 5,316.0
8/13/2023
22:45
8/14/2023
00:00
1.25 INTRM1, DRILLOUT TRIP P Cont. TIH from 5316'MD to 6245'MD.
Logging @ 5400 FPH. S/O 81k
5,316.0 6,245.0
8/14/2023
00:00
8/14/2023
01:00
1.00 INTRM1, DRILLOUT WASH P Wash and Ream from 6245‘MD to tag
float collar @ 6434‘MD, GPM 230, psi
1565, F/O 29%, RPM 40, TQ 4.5k, S/O
93k, RT 93k.
6,245.0 6,436.0
8/14/2023
01:00
8/14/2023
08:00
7.00 INTRM1, DRILLOUT DRLG P Drill out 7 5/8" float shoe per SLB DD
from 6436’MD to 6518’MD. GPM 240,
PSI 1589, F/O 28%, ECD 10.37 PPG,
100 RPM, TQ 6k, WOB 2-4k. Drill 20' of
new hole to 6541'MD. Work through
shoe 4x, RT 90k. (SIMOP’S lay down 5''
Drill pipe from derrick with single joint
elevators). ADT 0.29 Hrs, Bit 0.29 Hrs,
Jars 0.29 Hrs.
6,436.0 6,541.0
8/14/2023
08:00
8/14/2023
09:15
1.25 INTRM1, DRILLOUT CIRC P Circulate, Rotate & Reciprocate.
Condition mud for FIT/LOT from
6521‘MD to 6506‘MD, GPM 245, PSI
1620, F/O 28%, RPM 40, TQ 6k, ECD
10.24 PPG, P/U 90k, S/O 94k, RT 90k,
total pumped strokes 4850.
6,521.0 6,506.0
8/14/2023
09:15
8/14/2023
10:00
0.75 INTRM1, DRILLOUT LOT P R/U for FIT/LOT test @ 6517' MD 3568'
TVD. Shut 3-1/2'' x 5'' upper rams. Mud
weight 9.4+ PPG. Pumped
11strokes/1.1bbls @ 1/2 BPM. 1BBL
bleed back. Observed leak off pressure
at 880psi/ 14.2 ppg EMW Max pressure
observe 940 psi.
6,517.0 6,517.0
8/14/2023
10:00
8/14/2023
10:15
0.25 INTRM1, DRILLOUT OWFF P OWFF (static). 6,517.0 6,517.0
8/14/2023
10:15
8/14/2023
12:00
1.75 INTRM1, DRILLOUT DISP P PJSM, displace well over to 9.0 PPG Flo
-pro as per pump schedule. GPM 200,
PSI 1315, F/O 14%, RPM 20, TQ 5k, RT
90k. OWFF (static) obtain SPR's.
6,517.0 6,517.0
8/14/2023
12:00
8/14/2023
15:00
3.00 INTRM1, DRILLOUT DISP P Shut down, clean shakers, underflow,
dress shakers to 170's, top off pits with
9.2ppg Flo-pro NT, prep/clean pits for
Flo-pro.
6,517.0 6,517.0
Rig: DOYON 142
RIG RELEASE DATE 8/22/2023
Page 15/23
1C-501
Report Printed: 9/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/14/2023
15:00
8/14/2023
18:00
3.00 PROD1, DRILL WASH P Wash and Ream 6-3/4” production hole
from 6518‘MD to 6541' MD 3594‘TVD,
WOB 2k
GPM 275
PSI 1940
RPM 120
TQ 4k
F/O 18%
ECD 10.3 PPG
P/U 104k
S/O 87k
RT 93k
ADT 2.39
Bit hrs 2.68
Jar hrs 2.68
6,518.0 6,541.0
8/14/2023
18:00
8/15/2023
00:00
6.00 PROD1, DRILL DDRL P Drill 6-3/4" production hole f/ 6541‘MD
to 7289‘MD 3582‘TVD
WOB 2k
GPM 270
PSI 2055
RPM 100
TQ 4.5k
F/O 18%
ECD 10.44 PPG
P/U 109k
S/O 84k
RT 97k
ADT 4.72
Bit hrs 7.40
Jar Hrs 7.40
6,541.0 7,289.0
8/15/2023
00:00
8/15/2023
02:30
2.50 PROD1, DRILL DDRL P Drill 6-3/4" production hole f/ 7289‘MD
to 7483‘MD 3577‘TVD
WOB 2k
GPM 270
PSI 2088
RPM 100
TQ 4.5k
F/O 18%
ECD 10.44 PPG
P/U 111k
S/O 90k
RT 101k
ADT 2.02
Bit hrs 9.42
Jar Hrs 9.42
7,289.0 7,483.0
8/15/2023
02:30
8/15/2023
03:00
0.50 PROD1, TRIPCAS CIRC P Obtain final survey and torque & drag,
SPR's
7,483.0 7,483.0
8/15/2023
03:00
8/15/2023
04:30
1.50 PROD1, TRIPCAS BKRM P BROOH from 7483'MD to 7248'MD .
Rack stand back per bottoms up.
Circulated 2x bottoms up.
GPM 270
PSI 2006
RPM 100
TQ 4k
ECD 10.33 PPG
F/O 17%
P/U 94
S/O 94
RT 94
7,483.0 7,248.0
Rig: DOYON 142
RIG RELEASE DATE 8/22/2023
Page 16/23
1C-501
Report Printed: 9/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/15/2023
04:30
8/15/2023
07:30
3.00 PROD1, TRIPCAS BKRM P BROOH from 7248'MD to 6517'MD.
GPM 275
PSI 1835
RPM 100
TQ 4k
ECD 10.18 PPG
F/O 17%
P/U 98
S/O 98
RT 98
7,248.0 6,517.0
8/15/2023
07:30
8/15/2023
08:00
0.50 PROD1, TRIPCAS CIRC P Drop 1.75" ball to open Well
Commander. Wait 5 minutes before
pumping @ 2BPM @ 327 PSI, F/O 11%,
Ball on seat @ 234 strokes, 23.5 BBLS.
Pressure up to 1000 PSI, Hold for 30
seconds, Increase pressure 500 PSI,
continue increasing pressure until tool
open @ 2000 PSI.
6,517.0 6,517.0
8/15/2023
08:00
8/15/2023
09:00
1.00 PROD1, TRIPCAS CIRC P Circulate, Rotate & Reciprocate through
Well Commander from 6517‘MD to
6430‘MD, with GPM 450, PSI 1429,
FLOW OUT 25%, RPM 100, TQ 3K,
RT WT 86K, Total strokes pumped
6835.
6,517.0 6,430.0
8/15/2023
09:00
8/15/2023
09:30
0.50 PROD1, TRIPCAS CIRC P Drop 1.75" ball to open Well
Commander. Wait 5 minutes before
pumping @ 2BPM @ 327 PSI, F/O 11%,
Ball on seat @ 234 strokes 23.5 BBLS.
Pressure up to 1000 PSI, Hold for 30
seconds, Increase pressure 500 PSI,
continue increasing pressure until tool
open @ 2000 PSI.
6,430.0 6,430.0
8/15/2023
09:30
8/15/2023
12:00
2.50 PROD1, TRIPCAS CLEN P Shut down. Clean and prepare pits for
FLO-PRO SF mud.
6,430.0 6,430.0
8/15/2023
12:00
8/15/2023
13:15
1.25 PROD1, TRIPCAS TRIP P TIH from 6517‘MD to 7480‘MD, with 4”
drill pipe. S/O WT 94K; Monitor
displacement on Pit#1, Pill Pit#2.
6,517.0 7,480.0
8/15/2023
13:15
8/15/2023
15:45
2.50 PROD1, TRIPCAS CIRC P Circulate, Rotate & Reciprocate from
7480‘MD to 7440‘MD, GPM =250, PSI
=1870, F/O 21%, RPM 40, TQ 4K, ECD
10.16PPG, RT WT 101K, Total strokers
pumped 8508. SIMOP'S, Clean pits #
5,6,7 Pill Pit #1. Clean under flow line
troughs prepare pits for FLO=PRO SF
mud.
7,480.0 7,440.0
8/15/2023
15:45
8/15/2023
18:00
2.25 PROD1, TRIPCAS CIRC P PJSM, displace well to 9.2PPG FLO-
PRO SF. Continue circulation pending
PST results in and out well. GPM 220,
PSI 1195, F/O 22, RPM, TQ 4K, RT
97K.
7,480.0 7,480.0
8/15/2023
18:00
8/15/2023
20:00
2.00 PROD1, TRIPCAS CIRC P Circulate surface to surface while
reciprocating. From 7,477' MD to 7,443'
MD GPM 124 , PSI 400 , F/O 16%, P/U
115K S/O 77-90K. Total strokes pumped
3200. PST test mud.
7,477.0 7,433.0
8/15/2023
20:00
8/15/2023
20:15
0.25 PROD1, TRIPCAS CIRC P Obtain SPR’s Rack stand back to
7443’MD.
7,433.0 7,433.0
8/15/2023
20:15
8/15/2023
21:15
1.00 PROD1, TRIPCAS CIRC P Drop 1.75" ball to close Well
Commander. GPM 84, Ball on seat @
368 STROKES, 36.8 BBLS. Hold for 5
minutes, Bleed off, Pressure up to 1900
PSI, close Well Commander. OWFF
Prior to POOH - well static.
7,433.0 7,433.0
8/15/2023
21:15
8/15/2023
22:15
1.00 PROD1, TRIPCAS TRIP P POOH from 7,443‘MD to 6517‘MD, with
4” Drill pipe, Rack pipe in derrick, P/U
114K, Monitor displacement at pit #1.
7,433.0 6,517.0
Rig: DOYON 142
RIG RELEASE DATE 8/22/2023
Page 17/23
1C-501
Report Printed: 9/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/15/2023
22:15
8/16/2023
00:00
1.75 PROD1, TRIPCAS CIRC P Circulate and reciprocate from 6517‘MD
to 6423‘MD, GPM 210, PSI 1042,
FLOW OUT 26%, P/U 112K, S/O 78K,
Total strokes pumped 5100. Confirm two
passed PST test.
6,517.0 6,423.0
8/16/2023
00:00
8/16/2023
00:30
0.50 PROD1, TRIPCAS CIRC P Cont. Circulate and reciprocate from
6517‘MD to 6423‘MD, GPM 210, PSI
1042, FLOW OUT 26%, P/U 112K, S/O
78K, Total strokes pumped 5100.
Confirm two passed PST test.
6,423.0 6,517.0
8/16/2023
00:30
8/16/2023
04:30
4.00 PROD1, TRIPCAS TRIP P TOOH from 6517'MD to 400'MD with 4"
drill pipe, racking stands back in derrick.
P/U 54k, Monitoring well on pit #1.
6,517.0 400.0
8/16/2023
04:30
8/16/2023
04:45
0.25 PROD1, TRIPCAS SFTY P PJSM on laying down BHA, OWFF well
static.
400.0 400.0
8/16/2023
04:45
8/16/2023
07:00
2.25 PROD1, TRIPCAS BHAH P L/D directional BHA as per SLB DD,
MWD from 400'MD to surface.
400.0 0.0
8/16/2023
07:00
8/16/2023
08:30
1.50 PROD1, TRIPCAS CLEN P Clean and clear rig floor, Offload BHA
tools and equipment via beaver slide.
0.0 0.0
8/16/2023
08:30
8/16/2023
11:15
2.75 COMPZN, CASING RURD P R/U Doyon casing handling equipment
and tools, Prepare to P/U and run 4.5"
lower completion
0.0 0.0
8/16/2023
11:15
8/16/2023
11:45
0.50 COMPZN, CASING SFTY P PJSM with all hands involved with
running 4.5" lower completion.
0.0 0.0
8/16/2023
11:45
8/16/2023
12:00
0.25 COMPZN, CASING PUTB P M/U 4.5" HYD563 Float/Shoe and
drillable packoff bushing as per Baker
Tool Rep.
0.0 20.0
8/16/2023
12:00
8/16/2023
14:00
2.00 COMPZN, CASING PUTB P P/U and Run 4.5" OHSAS Lower
Completion 12.6# L-80 HYD563 as per
detail from 20' to 994'. Make up torque
3800 FT/BLS. Monitor well on pit #1.
P/U 50k, S/O 54k. Set liner in tension
prior to rigging up to run 2-7/8" wash
pipe.
20.0 944.0
8/16/2023
14:00
8/16/2023
16:00
2.00 COMPZN, CASING RUNL P R/U to run 2-7/8" wash pipe. False
rotary table and casing handling
equipment.
944.0 944.0
8/16/2023
16:00
8/16/2023
18:45
2.75 COMPZN, CASING PUTB P PJSM, Run 2-7/8" wash pipe as per
detail. 6.5#, L-80, H511 R2 tubing .
Make up torque 800 FT/LBS. Tag pack
off bushing at 924'. L/D 2 joints 2-7/8",
while running space out numbers.
944.0 944.0
8/16/2023
18:45
8/16/2023
23:30
4.75 COMPZN, CASING PUTB P M/U space pups, M/U FLCV, M/U Baker
HRDE ZXP 5.5 X 7.63 Hanger packer,
M/U SBE, M/U inner string and screen
assy, torque to spec as per Baker Reps.
C/O handling equipment to 4". Remove
false bowl. Batch up and fill tieback with
Xanplex.
944.0 944.0
8/16/2023
23:30
8/17/2023
00:00
0.50 COMPZN, CASING RUNL P M/U cross overs from drill pipe to well
commander sub back to drill pipe.
944.0 944.0
8/17/2023
00:00
8/17/2023
06:00
6.00 COMPZN, CASING RUNL P TIH with Baker lower completion from
1113‘MD to 7440‘MD, with 4” drill pipe
from derrick, P/U 122K, S/O 75K.
Monitor displacement on pit #1.
1,113.0 7,440.0
Rig: DOYON 142
RIG RELEASE DATE 8/22/2023
Page 18/23
1C-501
Report Printed: 9/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/17/2023
06:00
8/17/2023
10:00
4.00 COMPZN, CASING THGR P Circulate string volume 650 strokes,
65BBLS. Drop 1.125 ball pump down @
3BPM, 363 PSI. Reduce to 1.5BPM
187PSI. Ball on seat @ 509 strokes
51BBLS. Pressure up 2215 PSI Holding
for 2 minutes. Slack off 40K to confirm
hanger set. Pressure up to 3600PSI,
hold for 5minutes, bleed off psi. P/U to
verify liner weight loss, observe 4k
overpull indicating not released from
liner. Repeat process 7x, decision was
made to pressure up to blow ball seat
with 4600psi. P/U to neutral weight
125k, observe no overpull indicating
liner released. TOL 6352' P/U 125 S/O
75k
7,440.0 7,440.0
8/17/2023
10:00
8/17/2023
10:15
0.25 COMPZN, CASING RURD P Set in slips, R/U cement head pin to
circulate (conduct PJSM on displacing
wellbore to 9.2ppg filtered brine)
7,440.0 7,440.0
8/17/2023
10:15
8/17/2023
12:00
1.75 COMPZN, CASING DISP P Displace well to 9.2ppg filter brine.
Followed by one full circulation, total
strokes pump 4170 @ 4bpm, 765psi
7,440.0 7,440.0
8/17/2023
12:00
8/17/2023
13:00
1.00 COMPZN, CASING DISP P Displace well to 9.2ppg filter brine.
Followed by one full circulation, total
strokes pump 7399 @ 4.5 bpm, 823psi
7,440.0 7,440.0
8/17/2023
13:00
8/17/2023
15:00
2.00 COMPZN, CASING CLEN P Shut down clean trough, under flow, pit
#1. Screen up shaker #3 to 325 mesh.
7,440.0 7,440.0
8/17/2023
15:00
8/17/2023
16:30
1.50 COMPZN, CASING CIRC P Circulate hole volume 3000 strokes 300
BBLS. Running return though filter unit.
Prior to pumping down hole. BPM 4.5,
PSI 817 psi, F/O 12%.
7,440.0 7,440.0
8/17/2023
16:30
8/17/2023
18:30
2.00 COMPZN, CASING CIRC P Circulate hole volume 3000 strokes 300
BBLS. Running return though filter unit.
Prior to pumping down hole. BPM 4.5,
PSI 817 psi, F/O 12%.
7,440.0 7,440.0
8/17/2023
18:30
8/17/2023
20:00
1.50 COMPZN, CASING OWFF P Monitor well via hole fill, while offloading
pits to prep for acid treatment #1.
7,440.0 7,440.0
8/17/2023
20:00
8/17/2023
23:00
3.00 COMPZN, CASING CIRC P Pump additional full circulation, @ GPM
190, PSI 765 psi, F/O 9%, total strokes
pumped 3874, Offload pits, take on new
solids free brine for acid job #1.
7,440.0 7,440.0
8/17/2023
23:00
8/18/2023
00:00
1.00 COMPZN, CASING SFTY P Hold PJSM with SLB & Rig crew on
spotting formic acid #1, SLB to R/U &
test sensor lines.
7,440.0 7,440.0
8/18/2023
00:00
8/18/2023
01:00
1.00 COMPZN, CASING CIRC P SLB flood lines with fresh water and
pressure test lines to 1000 PSI low and
3600 PSI high. SLB pump 50 BBLS of
9.4 PPG formic acid. Followed by 10
BBLS fresh water @ 4 BPM, 662 PSI,
F/O 7%, Swap over to rig pumps and
spot acid with 54 BBLS 9.2 PPG filtered
brine @ 5 BPM, 950 PSI, F/O 9%. Acid
in place @ 0035 hrs.
7,440.0 7,437.0
8/18/2023
01:00
8/18/2023
07:30
6.50 COMPZN, CASING OWFF P Start 6 HR acid soak. Line up well on
trip and monitior losses every 15
minutes. Total loss 71 BBLS. General
housekeeping and working on MP2.
Blow lines back to SLB.
7,437.0 7,437.0
Rig: DOYON 142
RIG RELEASE DATE 8/22/2023
Page 19/23
1C-501
Report Printed: 9/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/18/2023
07:30
8/18/2023
09:15
1.75 COMPZN, CASING CIRC P Circulated out the acid at 5 bpm taking
returns to pits 1-4. Once the pH
dropped to 4.0 at 2,080 strokes (209
bbls), returns were diverted to open top
kill tank SST-029. The pH was
monitored in the cellar until the sample
port plugged off. By the time the mud
engineer reached the open top tank, the
pH reached 8.0 and the pumps were
shut down at 2,802 strokes (282 bbls).
73 bbls of acid and interface were
collected in SST-029.
7,437.0 7,437.0
8/18/2023
09:15
8/18/2023
09:45
0.50 COMPZN, CASING SFTY P PJSM on pumping acid with all hand
involved with job task.
7,437.0 7,437.0
8/18/2023
09:45
8/18/2023
10:30
0.75 COMPZN, CASING CIRC P SLB flood lines with fresh water and
pressure test lines to 1000 PSI low and
3600 PSI high. SLB pump 53 BBLS of
9.4 PPG formic acid. Followed by 10
BBLS fresh water @ 4 BPM, 600 PSI,
F/O 7%, Swap over to rig pumps and
spot acid with 53 BBLS 9.2 PPG filtered
brine @ 5 BPM, 893 PSI, F/O 9%. Acid
in place 10.35 hrs.
7,437.0 7,437.0
8/18/2023
10:30
8/18/2023
16:30
6.00 COMPZN, CASING OWFF P Start 6 HR acid soak. Line up well on
trip and monitior losses every 15
minutes. Total loss 46 BBLS. General
housekeeping and working on MP2.
Blow lines back to SLB.
7,437.0 7,437.0
8/18/2023
16:30
8/18/2023
16:45
0.25 COMPZN, CASING SFTY P PJSM on circulating out Formic acid 7,437.0 7,437.0
8/18/2023
16:45
8/18/2023
18:00
1.25 COMPZN, CASING CIRC P Circulated out the acid at 4 bpm taking
returns to pits 1-4. Once the pH
dropped to 4.0 at 2,052 strokes (207
bbls), returns were diverted to open top
kill tank SST-029. Once the pH reached
5.3, the pumps were shut down at 2,713
strokes (273 bbls). 66 bbls of acid and
interface were collected in SST-029.
65 bbls of 50 ppb Soda Ash pill
73 bbls from the first Acid Job
66 bbls from the second Acid Job
204 bbls of 9.87 pH neutralized acid
sent to disposal
7,437.0 7,437.0
8/18/2023
18:00
8/18/2023
19:30
1.50 COMPZN, CASING OWFF P Montioring well filling across the top with
trip tank.
7,437.0 7,437.0
8/18/2023
19:30
8/18/2023
20:30
1.00 COMPZN, CASING CIRC P Shut down trip pump, line up and spot
corrosion inhibited filter brine by
pumping 44 BBLS @ 170 GPM, 578
PSI, 8% FO, chasing with 58 BBLS of
filtered brine.
7,437.0 7,437.0
8/18/2023
20:30
8/18/2023
21:45
1.25 COMPZN, CASING PACK P Set liner top packer as per Baker Reps,
pick up string and observe free travel
110K P/U, rotate 20 RPM, with 3.5 K TQ
and 93K rotate down. Set down to 42K
(Block Weight). Observing dog sub and
packer set, pick up 10 feet and set back
down to 42k, to confirm set, space out
for closing rams, test liner top packer by
pumping at 20 GPM to 2,000 PSI, shut
in and hold for 30 minutes charted. 2
bbls bleed back.
7,437.0 7,437.0
8/18/2023
21:45
8/18/2023
23:00
1.25 COMPZN, CASING TRIP P POOH from 7,375'MD to 6,389'MD
racking back in the derrick. P/U 108k.
7,375.0 6,389.0
Rig: DOYON 142
RIG RELEASE DATE 8/22/2023
Page 20/23
1C-501
Report Printed: 9/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/18/2023
23:00
8/18/2023
23:15
0.25 COMPZN, CASING PACK P Kelly up, close IBOP, close annular, strip
from 6,389'MD to 6,351'MD, P/U 106k,
open annular and monitor well
confirming flapper valve is closed, pull
remaining stand, and lay down into pipe
shed, from 6,351'MD.
6,389.0 6,351.0
8/18/2023
23:15
8/19/2023
00:00
0.75 COMPZN, WELLPR CIRC P At 6,351'MD displace well over to
corrosion inhibited filtered brine at 170
GPM, 440 PSI, 8% F/O, 1,200 strokes.
6,351.0 6,351.0
8/19/2023
00:00
8/19/2023
00:30
0.50 COMPZN, WELLPR DISP P Continue displace well to ci filtered brine
with 170 GPM, 440 PSI, F/O 8%, 2,222
total strokes pumped.
6,351.0 6,351.0
8/19/2023
00:30
8/19/2023
01:00
0.50 COMPZN, WELLPR OWFF P OWFF well for flow (static), blow down
top drive.
6,351.0 6,351.0
8/19/2023
01:00
8/19/2023
04:45
3.75 COMPZN, WELLPR TRIP P POOH laying down drill pipe into pipe
shed from 6,294'MD to 3,324'MD, P/U
81k, monitoring well via trip tank.
6,294.0 3,324.0
8/19/2023
04:45
8/19/2023
05:15
0.50 COMPZN, WELLPR OWFF P OWFF well (static) 3,324.0 3,324.0
8/19/2023
05:15
8/19/2023
08:30
3.25 COMPZN, WELLPR TRIP P Continue, POOH laying down drill pipe
into pipe shed from 3,324'MD to packer
running tool, P/U 46k, monitoring well
via trip tank
3,324.0 0.0
8/19/2023
08:30
8/19/2023
09:15
0.75 COMPZN, WELLPR BHAH P L/D running tool per Baker Rep 0.0 0.0
8/19/2023
09:15
8/19/2023
10:30
1.25 COMPZN, WELLPR TRIP P L/D 31 joints of 2 7/8" inner string. 976.0 0.0
8/19/2023
10:30
8/19/2023
12:00
1.50 COMPZN, WELLPR CLEN P Break down triple connect x-over, L/D
Baker tools, clean/clear rig floor, kick out
2 7/8" handling equipment.
0.0 0.0
8/19/2023
12:00
8/19/2023
15:00
3.00 COMPZN, WELLPR PULD P RIH with 20 stands of 4" drill pipe from
derrick, POOH laying down pipe into
pipe shed. Monitor displacement on trip
tank.
0.0 0.0
8/19/2023
15:00
8/19/2023
16:00
1.00 COMPZN, WELLPR WWWH P Drain stack, pull wear ring per Vault
Rep, M/U stack washer, wash stack 4x
830 GPM, F/O 25%, 132 PSI 10 RPM,
L/D stack washer.
0.0 0.0
8/19/2023
16:00
8/19/2023
20:30
4.50 COMPZN, RPCOMP RURD P Rig up to run 4.5" upper completion,
pick up all Summit tools and equipment,
bring up 184 Cannon clamps, spot ESP
spooler and install drum, pick, and hang
sheave, C/O handling equipment, pull
ESP cable to floor, un-spool MLE cable
and align for installment, run MLE and
ESP cables though sheave
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 8/22/2023
Page 21/23
1C-501
Report Printed: 9/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/19/2023
20:30
8/20/2023
00:00
3.50 COMPZN, RPCOMP PUTB P P/U and M/U upper completion tools as
per Summit and Yellow Jacket Rep.
Summit Motor, 562 Series, KMS2, 500
HP, 3305V, 93A, SN 13914371
Summit Motor/Sensor Adaptor- PN
260013
Summit, Sensor, GCR, HighTemp,150C
- SN 13938435, PN 10313142798
Summit, 2-3/8" EUE Motor Centralizer -
PN 900070132
Summit Seal, BPBSL - SN 13925099
Summit Seal, BPBSL - SN 13911313
Pump, 538 Series, 066 Stage SJ10000,
1 3/16 Inconel Shaft, #11 Housing 1:1
AR
Summit Intake Gas Separator, S/R-
X2.513 - PN 900620001
4-1/2", 12.6#, L-80, Hyd 563, R3, Tubing
Pup joint, 4-1/2" 12.6#, L-80, Hyd 563
HES, XN Nipple, 3.813 (No-Go, 3.725"),
4-1/2" 12.6#, L-80, Hyd563, w/RHC
Pup joint, 4-1/2" 12.6#, L-80, Hyd 563
4-1/2", 12.6#, L-80, Hyd 563, R3, Tubing
Viking ESP packer 7-58/8” 29.7# x 4-
1/2” 12.6# H563 SN VCTP023-154-01
Install temp sensor capillary tube, slack
off to top of motor while clamping
service cable down, make MLE pothead
splice to motor, continue slacking off
and clamping service cable while
purging air and filling seal assembly with
mineral oil.
0.0 89.0
8/20/2023
00:00
8/20/2023
01:00
1.00 COMPZN, RPCOMP PUTB P Continue purging air and filling seal
assembly with mineral oil, installing
clamps on the way down to 188'MD.
188.0 188.0
8/20/2023
01:00
8/20/2023
01:30
0.50 COMPZN, RPCOMP RURD P Rig up Doyon casing tongs, test MLE
cable for continuity.
188.0 188.0
8/20/2023
01:30
8/20/2023
02:00
0.50 COMPZN, RPCOMP PUTB P Pick up 4.5" tubing as per running order
to 188'MD, torquing to 3,800 FT/BLS.
188.0 188.0
8/20/2023
02:00
8/20/2023
03:00
1.00 COMPZN, RPCOMP PUTB P @ the Viking packer Summit and Yellow
Jacket Reps install Paker penetrators
and get measurements for splicing MLE
to packer penetrators.
188.0 188.0
8/20/2023
03:00
8/20/2023
05:30
2.50 COMPZN, RPCOMP PUTB P Summit Reps splice MLE cable to
packer penetrator, and install into
packer.
188.0 188.0
8/20/2023
05:30
8/20/2023
10:30
5.00 COMPZN, RPCOMP PUTB P Pick up joint #3, Summit Reps splice top
of packer penetrator to ESP cable.
188.0 188.0
8/20/2023
10:30
8/20/2023
12:00
1.50 COMPZN, RPCOMP PUTB P Run 4.5" ESP upper completion as per
detail, BOL 2000 AG dope on pin ends
only, make up torque 3800 ft/lbs,
monitor displacement via trip tank, from
188'MD to 1008'MD, S/O 60k.
188.0 1,008.0
8/20/2023
12:00
8/20/2023
19:30
7.50 COMPZN, RPCOMP PUTB P Run 4.5" ESP upper completion as per
detail, BOL 2000 AG dope on pin ends
only, make up torque 3800 ft/lbs,
monitor displacement via trip tank, from
1008'MD to 5936'MD, P/U 96k, S/O 76k.
1,008.0 5,936.0
8/20/2023
19:30
8/20/2023
20:00
0.50 COMPZN, RPCOMP THGR P Pick up landing joint and make up
hanger as per Vault Rep.
5,936.0 5,936.0
8/20/2023
20:00
8/21/2023
00:00
4.00 COMPZN, RPCOMP THGR P Summit Reps, obtain hanger penetrator
measurements, conduct penetration
splice, install penetrator into hanger and
secure, obtain final conductivity test
(good).
5,936.0 5,936.0
Rig: DOYON 142
RIG RELEASE DATE 8/22/2023
Page 22/23
1C-501
Report Printed: 9/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/21/2023
00:00
8/21/2023
02:00
2.00 COMPZN, RPCOMP THGR P Upon landing hanger, it was noticed that
the hanger O-ring had rolled off, brought
hanger back to rig floor and replace O-
ring as per Vault Rep.
0.0 0.0
8/21/2023
02:00
8/21/2023
03:00
1.00 COMPZN, RPCOMP THGR P Land hanger as per Vault Rep, run in
lock down screws, test hanger seals to
5,000 psi for 10 minutes Company Rep
witnessed.
0.0 0.0
8/21/2023
03:00
8/21/2023
06:00
3.00 COMPZN, RPCOMP PACK P Drop 1 7/8" ball and rod, rig up xo, 1502
equipment, and cement hose, attempt to
pump ball and rod down but already on
seat, bleed off pressure, pump at 1/2
bpm pressuring up to 4,000 psi setting
Viking packer, shut in and test tubing for
30 min, hold an additional 20 min to get
a straight line on the chart, bleed tubing
down to 200 psi, line up on inner
annulus, pump at 2 spm pressuring up
to 1,500 psi, hold for 30 min charted,
bleed off tubing, pressure up annulus to
2,500 psi and attempt to shear out valve
with no success, bleed off and pressure
back up to 2,500 psi at 8 spm, observe
shear out of valve
0.0 0.0
8/21/2023
06:00
8/21/2023
06:30
0.50 COMPZN, RPCOMP OWFF P OWFF for 30 minutes (static), R/D x-
over, 1502 equipment, and cement
hose.
0.0 0.0
8/21/2023
06:30
8/21/2023
07:30
1.00 COMPZN, RPCOMP MPSP P L/D landing jt, install BPV per Vault Rep,
pressure test BPV to 1500 psi for 10
minutes (charted).
0.0 0.0
8/21/2023
07:30
8/21/2023
12:00
4.50 COMPZN, RPCOMP RURD P Blow down hole fill lines prior to nipple
down, pull risers, break cap on annular
to prep for changing out element,
disconnect choke & kill lines, break
stack from adapter flange and rack back
stack, SIMOPS - flush pumps, and
discharge line with deep clean pill.
0.0 0.0
8/21/2023
12:00
8/21/2023
19:00
7.00 COMPZN, WHDBOP THGR P R/D adapter flanges, Summit button
up/test ESP cables, Vault rep test void -
CPAI Rep witnessed, nipple up tree per
Vault rep, Summit reps change out
fitting on ESP - Vault rep re-test void
after fitting changed. SIMOPS - NOV
reps installed 4.4.2 update on Novos
system, electrician troubleshoot
drawworks encoder.
0.0 0.0
8/21/2023
19:00
8/21/2023
19:30
0.50 COMPZN, WHDBOP FRZP P Rig up injection line and equipment onto
outer annulus for injectivity rate and
freeze protection.
0.0 0.0
8/21/2023
19:30
8/21/2023
22:30
3.00 COMPZN, WHDBOP FRZP P Spot Little Red Services by cellar, rig up
LRS onto tree, pressure test lines to
5,000 psi, flood tree with diesel and test
250 psi low 5,000 psi high charted, Vault
Rep pull BPV.
0.0 0.0
8/21/2023
22:30
8/22/2023
00:00
1.50 COMPZN, WHDBOP FRZP P Rig up on outer annulus, pressure test
lines to 3,000 psi, using rig pump
establish injection rate while pumping
fresh water at 1/2 bpm down the outer
annulus, 6.5 bbls pumped, formation
started taking water at 735 psi, shut
down and monitor for 10 minutes,
annulus bled to 295 psi, line up LRS and
pump 85 bbls diesel down the annulus
at 1.9 bpm, 690 psi, shut in annulus and
monitor for 20 minutes, shut in annulus
with 608 psi left on it, rig down lines.
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 8/22/2023
Page 23/23
1C-501
Report Printed: 9/7/2023
Operations Summary (with Timelog Depths)
Job: DRILLING ORIGINAL
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
8/22/2023
00:00
8/22/2023
02:00
2.00 COMPZN, WHDBOP FRZP P Rig up LRS on inner annulus and pump
90 bbls of diesel at 1 bpm with 630 psi
taking returns up the tubing back to the
cuttings box.
0.0 0.0
8/22/2023
02:00
8/22/2023
02:30
0.50 COMPZN, WHDBOP RURD P Install BPV as per Vault rep. 0.0 0.0
8/22/2023
02:30
8/22/2023
06:00
3.50 DEMOB, MOVE CLEN P C/O 1502 flanges to original well head
flanges. Install guages. Clean & clear
cellar.
SIMOPS - N/D annular and upper rams
from BOP stack and stage for annual
maintenance.
Release rig from 1C-501 @ 06:00 hrs,
8/22/2023 for summer maintenance.
0.0 0.0
Rig: DOYON 142
RIG RELEASE DATE 8/22/2023
Page 1/1
1C-501
Report Printed: 9/7/2023
Cement
Cement Details
Description
Surface String Cement
Cementing Start Date
8/6/2023 12:16
Cementing End Date
8/6/2023 14:00
Wellbore Name
1C-501
Comment
PJSM, Surface cement job, Cement 10 3/4'' surface csg as per Halliburton pump sch., flood lines 5 bbls H2O@ 4 BPM, 43PSi, Pressure test lines to 3500 psi,
pump 56.7 bbl, 10.17 ppg tuned prime space with 8lb red dye @ 4 BPM, 70 PSI, Cement 10-3/4 surface csg as per Halliburton pump schedule, Shutdown and
drop bottom plug. Pump 347 BBLS 10.7 PPG lead cement @ 4 BPM, 112 PSI. Pump 56 bbls 15.8 PPG tail cmt @ 6 BPM, 58 PSI. Shutdown and drop top plug.
Flush with 20 bbls fresh H2O, line up to rig pumps to displace with 164 bbls @ 5 BPM, 90 PSI for 1580 strokes, slow rate to 3 BPM 347 PSI for final stroke, bump
plug @ 1645 strokes initial 347 PSI, pressure up to 840 PSI. Hold for 5 min. Check floats, (good) cement in place @ 14:48 hrs.
Cement Stages
Stage # 1
Description
Surface String Cement
Objective Top Depth (ftKB)
40.1
Bottom Depth (ftKB)
2,064.8
Full Return?
Yes
Vol Cement …
143.0
Top Plug?
Yes
Btm Plug?
Yes
Q Pump Init (bbl/m…
5
Q Pump Final (bbl/…
3
Q Pump Avg (bbl/…
5
P Pump Final (psi)
347.0
P Plug Bump (psi)
840.0
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
PJSM, Surface cement job, Cement 10 3/4'' surface csg as per Halliburton pump sch., flood lines 5 bbls H2O@ 4 BPM, 43PSi, Pressure test lines to 3500 psi,
pump 56.7 bbl, 10.17 ppg tuned prime space with 8lb red dye @ 4 BPM, 70 PSI, Cement 10-3/4 surface csg as per Halliburton pump schedule, Shutdown and
drop bottom plug. Pump 347 BBLS 10.7 PPG lead cement @ 4 BPM, 112 PSI. Pump 56 bbls 15.8 PPG tail cmt @ 6 BPM, 58 PSI. Shutdown and drop top plug.
Flush with 20 bbls fresh H2O, line up to rig pumps to displace with 164 bbls @ 5 BPM, 90 PSI for 1580 strokes, slow rate to 3 BPM 347 PSI for final stroke, bump
plug @ 1645 strokes initial 347 PSI, pressure up to 840 PSI. Hold for 5 min. Check floats, (good) cement in place @ 14:48 hrs.
Cement Fluids & Additives
Fluid
Fluid Type
Lead Cement
Fluid Description Estimated Top (ftKB)
40.1
Est Btm (ftKB)
1,564.0
Amount (sacks)
669
Class
G
Volume Pumped (bbl)
341.0
Yield (ft³/sack)
2.85
Mix H20 Ratio (gal/sack)
14.61
Free Water (%) Density (lb/gal)
10.70
Plastic Viscosity (cP) Thickening Time (hr)
22.00
CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Fluid
Fluid Type
Tail Cement
Fluid Description Estimated Top (ftKB)
1,564.0
Est Btm (ftKB)
2,064.8
Amount (sacks)
271
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)
4.63
CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Surface String Cement
Page 1/1
1C-501
Report Printed: 9/7/2023
Cement
Cement Details
Description
Intermediate String 1 Cement
Cementing Start Date
8/12/2023 10:15
Cementing End Date
8/12/2023 13:12
Wellbore Name
1C-501
Comment
Perform cement job from 7-5/8'' Intermediate casing as per Halliburton pump schedule. Flood lines w/ 5 BBLS H2O, 4.5 BPM @ 500 PSI. Pressure test lines to
4000 PSI. Drop #1 bottom plug. Pump 58 BBLS 10.5ppg tuned spacer @ 4.3 BPM 450 PSI, F/O 13%. Drop #2 bottom plug. Pump 102 BBLS 15.3 PPG Tail
cement. @ 2-4 BPM FCP 200psi @ 3 BPM. Drop top plug. Pump 20 BBLS H2O @ 5 BPM @ 180 PSI. Line up to rig pumps to displace @ 6bpm ICP 70 PSI, FCP
960 PSI. Reduce pump rate to 3 BPM @ 2500 strokes ICP 637 PSI, FCP 762 PSI. Bump plug @ 2721 strokes 274 BBLS, pressure up to 1300 PSI. Hold for 5
minutes and bleed off check floats (holding). Final P/U 123k, S/O 90k. Max pump pressure 960 PSI. Cement in place @ 13:12hrs
Cement Stages
Stage # 1
Description
Intermediate String 1
Cement
Objective Top Depth (ftKB)
3,662.0
Bottom Depth (ftKB)
6,518.1
Full Return?
No
Vol Cement …
0.0
Top Plug?
Yes
Btm Plug?
Yes
Q Pump Init (bbl/m…
5
Q Pump Final (bbl/…
5
Q Pump Avg (bbl/…
3
P Pump Final (psi)
960.0
P Plug Bump (psi)
1,300.0
Recip?
Yes
Stroke (ft)
10.00
Rotated?
No
Pipe RPM (rpm)
Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in)
Comment
Perform cement job from 7-5/8'' Intermediate casing as per Halliburton pump schedule. Flood lines w/ 5 BBLS H2O, 4.5 BPM @ 500 PSI. Pressure test lines to
4000 PSI. Drop #1 bottom plug. Pump 58 BBLS 10.5ppg tuned spacer @ 4.3 BPM 450 PSI, F/O 13%. Drop #2 bottom plug. Pump 102 BBLS 15.3 PPG Tail
cement. @ 2-4 BPM FCP 200psi @ 3 BPM. Drop top plug. Pump 20 BBLS H2O @ 5 BPM @ 180 PSI. Line up to rig pumps to displace @ 6bpm ICP 70 PSI, FCP
960 PSI. Reduce pump rate to 3 BPM @ 2500 strokes ICP 637 PSI, FCP 762 PSI. Bump plug @ 2721 strokes 274 BBLS, pressure up to 1300 PSI. Hold for 5
minutes and bleed off check floats (holding). Final P/U 123k, S/O 90k. Max pump pressure 960 PSI. Cement in place @ 13:12hrs
Cement Fluids & Additives
Fluid
Fluid Type
Tail Cement
Fluid Description Estimated Top (ftKB)
3,662.0
Est Btm (ftKB)
6,518.1
Amount (sacks)
485
Class
G
Volume Pumped (bbl)
107.0
Yield (ft³/sack)
1.24
Mix H20 Ratio (gal/sack)
5.57
Free Water (%) Density (lb/gal)
15.30
Plastic Viscosity (cP) Thickening Time (hr)
6.50
CmprStr 1 (psi)
Additives
Additive Type Concentration Conc Unit label
Intermediate String 1 Cement
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PTD: 223-045
T37995
9/13/2023Kayla Junke
Kayla
Junke
Digitally signed by
Kayla Junke
Date: 2023.09.13
10:07:24 -08'00'
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
BOPE Test Report for:
Reviewed By:
P.I. Suprv
Comm ________KUPARUK RIV UNIT 1C-501
JBR 09/28/2023
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:1
Test with 5" and 7 5/8" test joints, Tested all PVT and Gas Alarms,Total of 16 Precharge Bottles, 8 each @ 950psi and 8 each
@ 1000psi.5" Dart Valve Failed was changed out for new one and passed.
Test Results
TEST DATA
Rig Rep:M.SamOperator:ConocoPhillips Alaska, Inc.Operator Rep:B. Marmon
Rig Owner/Rig No.:Doyon 142 PTD#:2230450 DATE:8/7/2023
Type Operation:DRILL Annular:
250/5000Type Test:INIT
Valves:
250/5000
Rams:
250/5000
Test Pressures:Inspection No:bopBDB230808072200
Inspector Brian Bixby
Inspector
Insp Source
Related Insp No:
INSIDE REEL VALVES:
Quantity P/F
(Valid for Coil Rigs Only)
Remarks:
Test Time 6
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 FP
FSV Misc 0 NA
14 PNo. Valves
1 PManual Chokes
1 PHydraulic Chokes
0 NACH Misc
Stripper 0 NA
Annular Preventer 1 13 5/8"P
#1 Rams 1 7 5/8"P
#2 Rams 1 Blind/Shear P
#3 Rams 1 2 7/8"x5"P
#4 Rams 0 NA
#5 Rams 0 NA
#6 Rams 0 NA
Choke Ln. Valves 1 3 1/8"P
HCR Valves 2 3 1/8"P
Kill Line Valves 1 3 1/8"P
Check Valve 0 NA
BOP Misc 0 NA
System Pressure P3000
Pressure After Closure P1850
200 PSI Attained P9
Full Pressure Attained P55
Blind Switch Covers:PYES
Bottle precharge P
Nitgn Btls# &psi (avg)P6@1983
ACC Misc NA0
P PTrip Tank
P PPit Level Indicators
P PFlow Indicator
P PMeth Gas Detector
P PH2S Gas Detector
0 NAMS Misc
Inside Reel Valves 0 NA
Annular Preventer P12
#1 Rams P7
#2 Rams P7
#3 Rams P7
#4 Rams NA0
#5 Rams NA0
#6 Rams NA0
HCR Choke P2
HCR Kill P2
99
9
9999
9
9
.5" Dart Valve Failed
FP
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
DIVERTER Test Report for:
Reviewed By:
P.I. Suprv
Comm ________KUPARUK RIV UNIT 1C-501
JBR 09/29/2023
MISC. INSPECTIONS:
GAS DETECTORS:
DIVERTER SYSTEM:MUD SYSTEM:
P/F
P/F
P/F
Alarm
Visual Alarm
Visual Time/Pressure
Size
Number of Failures:0
Remarks:16 accumulator bottles at 975psi Avg. Annular was tested with 5" drill pipe.
TEST DATA
Rig Rep:M. Sam/H HuningtonOperator:ConocoPhillips Alaska, Inc.Operator Rep:B. Marmon/M. Aurthur
Contractor/Rig No.:Doyon 142 PTD#:2230450 DATE:8/3/2023
Well Class:DEV Inspection No:divKPS230804154617
Inspector Kam StJohn
Inspector
Insp Source
Related Insp No:
Test Time:1
ACCUMULATOR SYSTEM:
Location Gen.:P
Housekeeping:P
Warning Sign P
24 hr Notice:P
Well Sign:P
Drlg. Rig.P
Misc:NA
Methane:P P
Hydrogen Sulfide:P P
Gas Detectors Misc:0 NA
Designed to Avoid Freeze-up?P
Remote Operated Diverter?P
No Threaded Connections?P
Vent line Below Diverter?P
Diverter Size:21.25 P
Hole Size:13.5 P
Vent Line(s) Size:16 P
Vent Line(s) Length:194 P
Closest Ignition Source:97 P
Outlet from Rig Substructure:182 P
Vent Line(s) Anchored:P
Turns Targeted / Long Radius:P
Divert Valve(s) Full Opening:P
Valve(s) Auto & Simultaneous:
Annular Closed Time:26 P
Knife Valve Open Time:7 P
Diverter Misc:0 NA
Systems Pressure:P2950
Pressure After Closure:P1800
200 psi Recharge Time:P19
Full Recharge Time:P65
Nitrogen Bottles (Number of):P6
Avg. Pressure:P1991
Accumulator Misc:NA0
P PTrip Tank:
P PMud Pits:
P PFlow Monitor:
0 NAMud System Misc:
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, Tertiary Undefined Water Supply, 1C-501
Conoco Phillips Alaska, Inc.
Permit to Drill Number: 223-045
Surface Location: 1654' FNL, 1417' FWL, S12 T11N R10E
Bottomhole Location: 234' FSL, 4025' FEL, S7 T11N R11E
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 July 2023. 20th
Brett W.
Huber, Sr.
Digitally signed by
Brett W. Huber, Sr.
Date: 2023.07.20
00:11:56 -05'00'
1a. Type of Work:1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for:
Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates
Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas
2. Operator Name:5. Bond: Blanket Single Well 11. Well Name and Number:
Bond No.
3. Address:6. Proposed Depth: 12. Field/Pool(s):
MD: 7759 TVD:3551
4a. Location of Well (Governmental Section):7. Property Designation:
Surface:
Top of Productive Horizon:8. DNR Approval Number: 13. Approximate Spud Date:
7/15/2023
Total Depth: 9. Acres in Property: 14. Distance to Nearest Property:
233' to ADL028243
4b. Location of Well (State Base Plane Coordinates - NAD 27):10. KB Elevation above MSL (ft): 96.4 15. Distance to Nearest Well Open
Surface: x-562425.5 y- 5968586 Zone- 4 57.4 to Same Pool: 949' to 1C-184
16. Deviated wells: Kickoff depth: 300 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035)
Maximum Hole Angle: 90.1 degrees Downhole: Surface:
Hole Casing Weight Grade Coupling Length MD TVD MD TVD
42"16" 94 H-40 Welded 119 39 39 158 158
13.5"10.75" 45.5 L-80 Hyd563 1991 39 39 2030 1906
9.875"7.625" 29.7 L-80 Hyd563 6466 39 39 6505 3529
6.75"4.5" 12.6 L-80 Hyd563 1434 6325 3504 7759 3551
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: Shane McCracken
Chris Brillon Contact Email:shane.m.mccracken@cop.com
Wells Engineering Manager Contact Phone:907-265-6926
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
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
20 AAC 25.005
ConocoPhillips 59-52-180 1C-501
P.O. Box 100360 Anchorage, Alaska, 99510-0360 Kuparuk River Field
West Sak
1654' FNL, 1417' FWL, S12 T11N R10E ADL025649 / ADL028242
(including stage data)
905' FSL, 157' FEL , S12 T11N R10E LONS 01-013
234' FSL, 4025' FEL, S7 T11N R11E 2560 / 2469
GL / BF Elevation above MSL (ft):
1607 1252
18. Casing Program:Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks
Total Depth MD (ft):Total Depth TVD (ft):Plugs (measured):Effect. Depth MD (ft):Effect. Depth TVD (ft):
2 yds
649 sx 10.7ppg; 272 sx 15.8ppg
457 sx 15.3ppg
Casing Length Size Cement Volume MD
Surface
Conductor/Structural
Liner
Production
Intermediate
Perforation Depth MD (ft):Perforation Depth TVD (ft):
21. I hereby certify that the foregoing is true and the procedure approved herein will not be
deviated from without prior written approval.
Authorized Name:
Authorized Title:
Authorized Signature:
Commission Use Only
See cover letter for other
requirements.
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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 8:58 am, May 12, 2023
BOP test to 3500 psig
Annular test to 2500 psig
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.
X
DSR-5/12/23
Tertiary Undefined Water Supply
VTL 7/19/23
50-029-23757-00-00223-045
MDG 7/13/2023
GCW 07/19/2023JLC 7/19/2023
07/20/23
07/20/23Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr.
Date: 2023.07.20 00:11:34 -05'00'
ConocoPhillips Alaska, Inc.
Post Office Box 100360
Anchorage, Alaska 99510-0360
Telephone 907-276-1215
May 9, 2023
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
Re: Application for Permit to Drill 1C-501
Dear Sir or Madam:
ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore Ugnu water source well from the 1C drilling pad.
The intended spud date for this well is 7/15/2023. It is intended that Doyon 142 be used to drill the well.
1C-501 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 Ugnu formation. 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 C).
The production interval will be comprised of a 6.75” horizontal hole that will be geo-steered in the Ugnu formation. The well
will be completed as a water source well with 4.5” open-hole standalone screens and swell packers. The upper completion will
include GLM’s, an ESP with packer, and 4.5” tubing tied back to surface.
It is requested that a variance of the diverter requirement under 20 AAC 25.035(h)(2) is granted for well 1C-501. There are 7
wells within 500’ of surface hole location (1C-01, 25, 26, 27, 28, 184, 190). Two wells, 1C-25 and 1C-184, observed hydrates
at 1170’ and from 850-1500’, respectively.
Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information
attached to this application includes the following:
1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a)
2. A proposed drilling program
3. A proposed completion diagram
4. A drilling fluids program summary
5. Pressure information as required by 20 ACC 25.035 (d)(2)
6. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b)
Information pertinent to the application that is presently on file at the AOGCC:
1. Diagrams of the BOP equipment 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 Shane McCracken at 907-265-6926
(shane.m.mccracken@conocophillips.com) or Chris Brillon at 907-265-6120.
Sincerely, cc:
1C-501 Well File / Jenna Taylor ATO 1732
Dave Lee ATO 1552
Shane McCracken Chris Brillon ATO 1548
Drilling Engineer John Bertalott ATO 0642
Due to gas hydrates in 1C-25 and 1C-184, and shallow gas observed in 1C-28, I cannot
support this requested variance. M. Guhl 7/12/2023
requested that a variance of the diverter requirement u
Application for Permit to Drill, 1C-501
Saved: 9-May-23
1C-501 PTD
Page 1 of 10
Printed: 9-May-23
1C-501
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)) ......................................... 5
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-501
Saved: 9-May-23
1C-501 PTD
Page 2 of 10
Printed: 9-May-23
1. Well Name (Requirements of 20 AAC 25.005 (f))
The well for which this application is submitted will be designated as 1C-501.
2. Location Summary (Requirements of 20 AAC 25.005(c)(2))
Location at Surface 1654' FNL, 1417' FWL, S12 T11N R10E, UM
NAD 1927
Northings: 5968586
Eastings: 562426
RKB Elevation 96.4’ AMSL
Pad Elevation 57.4’ AMSL
Top of Productive Horizon 905' FSL, 157' FEL , S12 T11N R10E, UM
NAD 1927
Northings: 5965897
Eastings: 566155
Measured Depth, RKB: 6505’
Total Vertical Depth, RKB: 3529’
Total Vertical Depth, SS: 3433’
Total Depth (Toe) 234' FSL, 4025' FEL, S7 T11N R11E, UM
NAD 1927
Northings: 5965235
Eastings: 567219
Measured Depth, RKB: 7759’
Total Vertical Depth, RKB: 3551’
Total Vertical Depth, SS: 3455’
Pad Layout
Application for Permit to Drill, 1C-501
Saved: 9-May-23
1C-501 PTD
Page 3 of 10
Printed: 9-May-23
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-501.
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).
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 3,000 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
10.0 ppg EMW.
10. Drill 9.875” hole to section TD, setting pipe within the Ugnu formation. (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). Chart casing pressure test on plug bump to 3,000 psi for 30 minutes.
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. Chart casing pressure test to 3,000 psi for 30 minutes, if not already tested.
15. Drill out shoe track and 20 feet of new formation. Perform LOT to a maximum of 14.5 ppg. Minimum required
leak-off value is 10.0 ppg EMW.
16. Drill 6.75” hole to section TD (LWD Program: GR/RES/DENS/NEU).
17. Pull out of hole with drilling BHA. Review cement job details and sonic log TOC.
18. Run 4.5” liner with OHSAS, swell packers, and liner hanger to TD.
19. Run 4.5” upper completion with ESP, ESP packer, and gas lift mandrel(s). Displace production casing to
corrosion inhibited fluid, space out and land tubing hanger.
20. Pressure test hanger seals to 5,000 psi.
21. Set ESP packer. Test tubing to 1,500 psi, chart test.
22. Bleed tubing pressure to 500 psi and test IA to 1,500 psi, chart test. Shear shearout valve.
23. Install HP-BPV and test to 1,500 psi.
24. Nipple down BOP.
25. Install tubing head adapter assembly. N/U tree and test to 5000 psi/10 minutes.
26. Freeze protect well.
27. Secure well. Rig down and move out.
Application for Permit to Drill, 1C-501
Saved: 9-May-23
1C-501 PTD
Page 4 of 10
Printed: 9-May-23
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 7-5/8” solid body rams, blind/shear
rams and variable rams while drilling and running casing in the intermediate section of 1C-501.
1C-501 has a MASP of 1244 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 sized to bottom-hole assemblies and drill collars.
ii. One with blind rams
iii. One annular type
Intermediate Drilling/Casing
Proposed Configuration:
x Annular Preventer
x 7-5/8” Solid Body Rams
x Blind/Shear Rams
x 3-1/2” x 6” VBR’
Production
Proposed Configuration:
x Annular Preventer
x 3-1/2” x 6” VBR’s
x Blind/Shear Rams
x 2-7/8” x 5-1/2” VBR’s
Application for Permit to Drill, 1C-501
Saved: 9-May-23
1C-501 PTD
Page 5 of 10
Printed: 9-May-23
5. Diverter System (Requirements of 20 AAC 25.005(c)(7))
It is requested that a variance of the diverter requirement under 20 AAC 25.035(h)(2) is granted for well 1C-501.
There are 7 wells within 500’ of surface hole location (1C-01, 25, 26, 27, 28, 184, 190). Two wells, 1C-25 and 1C-
184, observed gas in returns at 1170’ and from 850-1500’, respectively.
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)
20 158 / 158 10.9 71 74
10.75 2030 / 1906 15.0 862 1244
7.625 6505 / 3529 12.0 1,597 1252
4.5 7759 / 3551 12.0 1,607 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 158 = 74 psi
OR
ASP = FPP – (0.1 x D)
= 862 – (0.1 x 1906) = 671 psi
2. Drilling below 10.75” surface casing
ASP = [(FG x 0.052) – 0.1] D
= [(15.0 x 0.052) – 0.1] x 1906 = 1296 psi
OR
ASP = FPP – (0.1 x D)
= 1597 – (0.1 x 3529) = 1244 psi
Application for Permit to Drill, 1C-501
Saved: 9-May-23
1C-501 PTD
Page 6 of 10
Printed: 9-May-23
3. Drilling below 7.625” intermediate casing
ASP = [(FG x 0.052) – 0.1] D
= [(12.0 x 0.052) – 0.1] x 3529 = 1849 psi
OR
ASP = FPP – (0.1 x D)
= 1607 – (0.1 x 3551) = 1252 psi
(B) data on potential gas zones;
The well bore is not expected to penetrate any shallow gas zones.
(C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation
zones, and zones that have a propensity for differential sticking;
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
10.75 13.5 45.5 L-80 Hyd563 Cement to Surface
7.625 9.875 29.7 L-80 Hyd563 250’ TVD or 500’ MD, whichever is greater, above upper
most producing zone (Ugnu C)
4.5 6.75 12.6 L-80 Hyd563 N/A - OHSAS with swell packers
Cementing Calculations
10.75” Surface Casing run to 2030’ MD / 1906’ TVD
Cement from 2030’ MD to 1530' (500’ of tail) with Class G + Add's @ 15.8 PPG, and from 1530' to surface with
10.7 ppg Arctic Lite Crete. Assume 250% excess annular volume for lead and 50% excess for tail, zero excess in
20” conductor.
Lead slurry from 1530’ MD to surface with Arctic Lite Crete @ 10.7 ppg
Total Volume = 1894 ft3 => 649 sx of 10.7ppg Class G + Add's @ 2.92 ft3 /sk
Tail slurry from 2030’ MD to 1530’ MD with 15.8 ppg Class G + Add's
Total Volume = 316 ft3 => 272 sx of 10.7ppg Class G + Add's @ 1.16 ft3 /sk
Application for Permit to Drill, 1C-501
Saved: 9-May-23
1C-501 PTD
Page 7 of 10
Printed: 9-May-23
7.625” Intermediate Casing run to 6505’ MD / 3529’ TVD
Top of slurry is designed to be at 4369’ MD, which is 500’MD or 250’ TVD above the prognosis shallowest
hydrocarbon bearing zone, Ugnu C. Assume 20% excess annular volume.
Tail slurry from 6505’ MD to 4369’ MD with 15.3 ppg Class G + Add's
Total Volume = 571 ft3 => 457 sx of 15.3 ppg Class G + Add's@ 1.25 ft3/sk
9. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8))
Surface Intermediate Production
Hole Size in. 13.5 9.875 6.75
Casing Size in. 10.75 7.625 4.5
Density PPG 8.6 – 10.5 9.0 – 9.5 9.0 – 9.5
PV cP 20-50 8-15 ALAP
YP lb./100 ft2 35 - 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 - 18 5 - 10
10 Minute Gels lb./100 ft2 50 - 70 <30 6 - 12
API Fluid Loss cc/30 min. N.C. – 10.0 < 10.0 < 6.0
HPHT Fluid Loss cc/30 min. N/A N/A < 10.0
pH 9.5 – 10.0 9.5 – 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 9.0
– 9.5 ppg.
Application for Permit to Drill, 1C-501
Saved: 9-May-23
1C-501 PTD
Page 8 of 10
Printed: 9-May-23
Diagram of Doyon 142 Mud System on file.
Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033.
10. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9))
N/A - Application is not for an exploratory or stratigraphic test well.
11. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10))
N/A - Application is not for an exploratory or stratigraphic test well.
12. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11))
N/A - Application is not for an offshore well.
13. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12))
Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission.
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
Application for Permit to Drill, 1C-501
Saved: 9-May-23
1C-501 PTD
Page 9 of 10
Printed: 9-May-23
9.875” Hole /7.625” Casing Interval
Event Risk Level Mitigation Strategy
Sloughing shale / Tight
hole / Stuck Pipe
Low Good hole cleaning, pre-treatment with LCM,
stabilized BHA, maintain planned mud weights and
adjust as needed, real time equivalent circulating
density (ECD) monitoring
Lost circulation Moderate Reduce pump rates, reduce trip speeds, real time
ECD monitoring, mud rheology, add lost circulation
material
Hole swabbing on trips Moderate Reduce trip speeds, condition mud properties,
proper hole filling, pump out of hole, real time ECD
monitoring, Liner will be in place at TD
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 56 wells currently. 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.
Reservoir Pressure: Offset injection has the potential to increase reservoir pressure over predicted. Although this isjp
unlikely, the rig will be prepared to weight up if required.
Application for Permit to Drill, 1C-501
Saved: 9-May-23
1C-501 PTD
Page 10 of 10
Printed: 9-May-23
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 has readings
for wells with the highest concentrations. We will have H2S sensors on the rig which will be tested, escape packs
staged around the rig, and personal monitors will be worn by the core crew members. A detailed emergency
operating procedure will be communicated to all personnel, in the event H2S is encountered.
Well Name H2S Date Reading (ppm)
1C-109 04/05/2020 550
1C-135 07/30/2015 / 08/12/2016 300 / 240
1C-178 03/13/2022 240
1C-123 08/04/2002 232
1C-102 04/05/2020 220
1C-02 09/25/2011 / 07/30/2015 200 / 200
1C-151 04/04/2020 200
1C-170 04/04/2020 200
16. Proposed Completion Schematic
H2S on 1C pad – There have been elevated H2S levels noted on the–1C pad post drilling. B
39 500
500 800
800 1100
1100 1400
1400 1700
1700 2000
2000 2500
2500 3000
3000 3500
3500 4000
4000 5000
5000 5500
5500 6000
6000 6500
6500 7000
7000 7500
7500 8000
1C-501 wp12 Plan Summary
0
3
Dogleg Severity0 1500 3000 4500 6000 7500
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]
96109159209259
309358
1C-19
96109159209259
309358
96109159209259309359408458507557607656706
75680685690795710071057110811581C-190
550
600
649
698
747
795
844
892
940
988
1036
1084
1131
1C-27
0
2000
True Vertical Depth0 1000 2000 3000 4000 5000 6000
Vertical Section at 125.43°
10-3/4" Surface Casing
7-5/8" Intermediate Casing
4-1/2" Production Liner
15
30
Centre to Centre Separation0 300 600 900 1200 1500 1800 2100
Measured Depth
Equivalent Magnetic Distance
DDI
6.091
SURVEY PROGRAM
Date: 2018-07-24T00:00:00 Validated: Yes Version:
Depth From Depth To Survey/Plan Tool
39.00 1200.00 1C-501 wp12 (1C-501) GYD-GC-SS
1200.00 2020.00 1C-501 wp12 (1C-501)MWD OWSG
1200.00 2020.00 1C-501 wp12 (1C-501) MWD+IFR2+SAG+MS
2020.00 3020.00 1C-501 wp12 (1C-501)MWD OWSG
2020.00 6500.00 1C-501 wp12 (1C-501) MWD+IFR2+SAG+MS
6500.00 7500.00 1C-501 wp12 (1C-501)MWD OWSG
6500.00 7758.88 1C-501 wp12 (1C-501) MWD+IFR2+SAG+MS
Ground /52.00
CASING DETAILS
TVD MD Name
1906.40 2030.20 10-3/4" Surface Casing
3529.40 6504.91 7-5/8" Intermediate Casing
3551.40 7758.88 4-1/2" Production Liner
Mag Model & Date: BGGM2022 10-May-23
Magnetic North is 14.62° East of True North (Magnetic Declinatio
Mag Dip & Field Strength: 80.64° 57207.99nT
SECTION DETAILS
Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation
1 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00
2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 Start Build 1.50
3 500.00 3.00 135.00 499.91 -3.70 3.70 1.50 135.00 5.16 Start Build 2.00
4 700.00 7.00 135.00 699.11 -16.02 16.02 2.00 0.00 22.35 Start Build 2.50
5 1822.51 35.06 135.00 1736.40 -298.04 298.04 2.50 0.00 415.63 Start 122.17 hold at 1822.51 MD
6 1944.68 35.06 135.00 1836.40 -347.67 347.67 0.00 0.00 484.83 Start 85.52 hold at 1944.68 MD
7 2030.20 35.06 135.00 1906.40 -382.41 382.41 0.00 0.00 533.28 Start 20.00 hold at 2030.20 MD
8 2050.20 35.06 135.00 1922.77 -390.53 390.53 0.00 0.00 544.61 Start DLS 2.75 TFO -16.66
9 3506.62 74.19 123.95 2751.21 -1107.04 1305.13 2.75 -16.66 1705.21 Start 2521.22 hold at 3506.62 MD
10 6027.85 74.19 123.95 3437.99 -2461.75 3317.51 0.00 0.00 4130.28 Start DLS 2.00 TFO -5.65
11 6771.65 89.00 122.50 3546.40 -2863.63 3931.41 2.00 -5.65 4863.48 1C-501 Tgt 01 011223 Start 20.00 hold at 6771.65 MD
12 6791.65 89.00 122.50 3546.75 -2874.38 3948.27 0.00 0.00 4883.45 Start DLS 1.00 TFO -9.51
13 6905.64 90.12 122.31 3547.62 -2935.46 4044.51 1.00 -9.51 4997.27 Start 556.50 hold at 6905.64 MD
14 7462.13 90.12 122.31 3546.41 -3232.92 4514.83 0.00 0.00 5552.94 Start DLS 1.00 TFO -174.62
15 7474.61 90.00 122.30 3546.40 -3239.59 4525.38 1.00 -174.62 5565.40 1C-501 Tgt 02 011223 Start DLS 1.00 TFO -168.47
16 7609.45 88.68 122.03 3547.95 -3311.37 4639.51 1.00 -168.47 5700.01 Start 149.43 hold at 7609.45 MD
17 7758.88 88.68 122.03 3551.40 -3390.60 4766.16 0.00 0.00 5849.14 1C-501 Tgt 03 011223 TD at 7758.88
FORMATION TOP DETAILS
TVDPath Formation
1676.40 T-5
1786.40 Base Perm
2015.40 T-3
2278.40 K-15
3236.40 Ugnu C
3459.40 Ugnu B
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
D142: Plan 57.4+39 @ 96.40usft
07001400210028003500True Vertical Depth0 700 1400 2100 2800 3500 4200 4900 5600Vertical Section at 125.43°10-3/4" Surface Casing7-5/8" Intermediate Casing4-1/2" Production Liner1000200030004000500060007000 77590°30°35°60°74°90°90 °1C-501wp12T-5Base PermT-3K-15Ugnu CUgnu B1C-501 wp129:51, February 02 2023Section View
-3000-2400-1800-1200-6000South - / orth0 600 1200 1800 2400 3000 3600 4200 4800est - / ast1C-501 Tgt 03 0112231C-501 Tgt 02 0112231C-501 Tgt 01 01122310-3/4" Surface Casing7-5/8" Intermediate Casing4-1/2" Production Liner1C-501 wp12While drilling production section, stay within 100 feet laterally of plan, unless notified otherwise.9:53, February 02 20233ODQ9LHZ
0
30
60
Centre to Centre Separation0 450 900 1350 1800 2250
Partial Measured Depth1C-1901C-27Equivalent Magnetic Distance
1C-501 wp12 Ladder View
0
150
300
Centre to Centre Separation0 1500 3000 4500 6000 7500
Measured Depth1C-011C-01L11C-01L1-011C-01L1-021C-01L1-031C-021C-141C-14A1C-151C-15L11C-15L21C-15L2PB11C-1501C-1551C-1841C-191C-19L11C-1901C-201C-20PB11C-211C-21L11C-21L21C-21L31C-221C-231C-23A1C-23AL11C-23AL21C-23AL2-011C-23AL2-021C-23PB11C-241C-24L11C-251C-25L11C-261C-271C-281C-28L11C-28PB11C-157wp121C-158wp07Equivalent Magnetic Distance
SURVEY PROGRAM
Depth From Depth To Survey/Plan Tool
39.00 1200.00 1C-501 wp12 (1C-501) GYD-GC-SS
1200.00 2020.00 1C-501 wp12 (1C-501) MWD OWSG
1200.00 2020.00 1C-501 wp12 (1C-501) MWD+IFR2+SAG+MS
2020.00 3020.00 1C-501 wp12 (1C-501) MWD OWSG
2020.00 6500.00 1C-501 wp12 (1C-501) MWD+IFR2+SAG+MS
6500.00 7500.00 1C-501 wp12 (1C-501) MWD OWSG
6500.00 7758.88 1C-501 wp12 (1C-501) MWD+IFR2+SAG+MS
9:59, February 02 2023
CASING DETAILS
TVD MD Name
1906.40 2030.20 10-3/4" Surface Casin
3529.40 6504.91 7-5/8" Intermediate Casin
3551.40 7758.88 4-1/2" Production Line
39 500
500 800
800 1100
1100 1400
1400 1700
1700 2000
2000 2500
2500 3000
3000 3500
3500 4000
4000 5000
5000 5500
5500 6000
6000 6500
6500 7000
7000 7500
7500 8000
1C-501 wp12C 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 A imuth (TFO+A I) vs Travelling Cylinder Separation 60 usft/in
102202302403503602
701
799
896
991
1084
1174
1C-01
102202302403503602
701
799
896
991
1084
1174
102202302403503602
701
799
896
991
1084
1174
102202302403503602
701
799
896
991
1084
1174
102202302403503602
701
799
896
991
1084
1174
102202302400496592
687
1C-02
295
392
487
582
675
765
854
942
1C-15
295
391
487
581
674
765
854
942
295
392
487
582
675
765
854
942
295
392
487
582
675
765
854
942
96109209309405500596
691
784
1C-184
96109209
309407505
602
700
794
888
980
1071
1C-19
96109209
309407505
602
700
794
888
980
1071
96109209309408507 607 706806907
1007
1108
1208
1309
14101511
1612
1713
18141914
2014
2115
2217
2318
2418
2516
2612
2705
1C-190
68109209309406503
600
694
786
876
964
1C-22
101201300399
496
592
687
782
875
967
1057
1144
1229
1C-23
101201300399
496
592
687
782
875
967
1057
1144
1229
101201300399
496
592
687
782
875
967
1057
1144
1229
101201300399
496
592
687
782
875
967
1057
1144
1229
101201300399
496
592
687
782
875
967
1057
1144
1229
101201300399
496
592
687
782
875
967
1057
1144
1229
101201300399
496
592
687
782
875
967
1057
1144
1229
5695195295393491588
6847808741C-24 5695195295393491588
684780874
102
202302401500598
696
792
887
980
1073
1165
1256
1347
1436
1C-25
102
202302401500598
696
792
887
980
1073
1165
1256
1347
1436
102202302402501600699797
894991
1086
1180
1C-26
101201301401
501
600
698
795
892
988
1084
1177
1271
1363
1455
1C-27
7566
7607
1C-157 wp12
SURVEY PROGRAM
Date 2018-07-24T00 00 00 Validated Yes Version
From To Tool
39.00 1200.00 GYD-GC-SS
1200.00 2020.00 MWD OWSG
1200.00 2020.00 MWD+IFR2+SAG+MS
2020.00 3020.00 MWD OWSG
2020.00 6500.00 MWD+IFR2+SAG+MS
6500.00 7500.00 MWD OWSG
6500.00 7758.88 MWD+IFR2+SAG+MS
CASING DETAILS
TVD MD Name
1906.40 2030.20 10-3/4" Surface Casing
3529.40 6504.91 7-5/8" Intermediate Casing
3551.40 7758.88 4-1/2" Production Liner
SECTION DETAILS
Sec MD Inc A i TVD +N/-S +E/-W Dleg TFace VSect Target Annotation
1 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00
2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 Start Build 1.50
3 500.00 3.00 135.00 499.91 -3.70 3.70 1.50 135.00 5.16 Start Build 2.00
4 700.00 7.00 135.00 699.11 -16.02 16.02 2.00 0.00 22.35 Start Build 2.50
5 1822.51 35.06 135.00 1736.40 -298.04 298.04 2.50 0.00 415.63 Start 122.17 hold at 1822.51 MD
6 1944.68 35.06 135.00 1836.40 -347.67 347.67 0.00 0.00 484.83 Start 85.52 hold at 1944.68 MD
7 2030.20 35.06 135.00 1906.40 -382.41 382.41 0.00 0.00 533.28 Start 20.00 hold at 2030.20 MD
8 2050.20 35.06 135.00 1922.77 -390.53 390.53 0.00 0.00 544.61 Start DLS 2.75 TFO -16.66
9 3506.62 74.19 123.95 2751.21 -1107.04 1305.13 2.75 -16.66 1705.21 Start 2521.22 hold at 3506.62 MD
10 6027.85 74.19 123.95 3437.99 -2461.75 3317.51 0.00 0.00 4130.28 Start DLS 2.00 TFO -5.65
11 6771.65 89.00 122.50 3546.40 -2863.63 3931.41 2.00 -5.65 4863.48 1C-501 Tgt 01 011223 Start 20.00 hold at 6771.65 MD
12 6791.65 89.00 122.50 3546.75 -2874.38 3948.27 0.00 0.00 4883.45 Start DLS 1.00 TFO -9.51
13 6905.64 90.12 122.31 3547.62 -2935.46 4044.51 1.00 -9.51 4997.27 Start 556.50 hold at 6905.64 MD
14 7462.13 90.12 122.31 3546.41 -3232.92 4514.83 0.00 0.00 5552.94 Start DLS 1.00 TFO -174.62
15 7474.61 90.00 122.30 3546.40 -3239.59 4525.38 1.00 -174.62 5565.40 1C-501 Tgt 02 011223 Start DLS 1.00 TFO -168.47
16 7609.45 88.68 122.03 3547.95 -3311.37 4639.51 1.00 -168.47 5700.01 Start 149.43 hold at 7609.45 MD
17 7758.88 88.68 122.03 3551.40 -3390.60 4766.16 0.00 0.00 5849.14 1C-501 Tgt 03 011223 TD at 7758.88
1CͲ501wp12͘ϭACFlipbookSURVEY PROGRAMDepth From Depth To Tool39.00 1200.00 GYD-GC-SS1200.00 2020.00 MWD OWSG1200.00 2020.00 MWD+IFR2+SAG+MS2020.00 3020.00 MWD OWSG2020.00 6500.00 MWD+IFR2+SAG+MS6500.00 7500.00 MWD OWSG6500.00 7758.88 MWD+IFR2+SAG+MSCASING DETAILSTVDMDName1906.402030.2010-3/4" Surface Casing3529.406504.917-5/8" Intermediate Casing3551.407758.884-1/2" Production Liner20204040606080801001001201201401400901802703021060240120300150330Travelling Cylinder A imuth (TFO+A I) vs Travelling Cylinder Separation 40 usft/in521021522022523023524034535035526026527017507998488969439911037108411291C-01521021522022523023524034535035526026527017507998488969439911037108411291C-01L1521021522022523023524034535035526026527017507998488969439911037108411291C-01L1-01521021522022523023524034535035526026527017507998488969439911037108411291C-01L1-02521021522022523023524034535035526026527017507998488969439911037108411291C-01L1-03961091592092593093584074565055546026516997477948418899349801C-19961091592092593093584074565055546026516997477948418899349801C-19L196109159209259309359408458507557607656706756806856907957100710571108115812081259130913601410146115111562161216631713176418141864191419641C-190681091592092593093584064555035515996476947397868318761C-2251101151201251301350399447496544592639687735782828875921967101310571101114411871C-2351101151201251301350399447496544592639687735782828875921967101310571101114411871C-23A51101151201251301350399447496544592639687735782828875921967101310571101114411871C-23AL151101151201251301350399447496544592639687735782828875921967101310571101114411871C-23AL251101151201251301350399447496544592639687735782828875921967101310571101114411871C-23AL2-0151101151201251301350399447496544592639687735782828875921967101310571101114411871C-23AL2-0251101151201251301350399447496544592639687735782828875921967101310571101114411871C-23PB156951451952452953443934424915395886361C-2456951451952452953443934424915395886361C-24L15210215220225230235240145150054959864769674479283988793498010271073111911651211125613021C-255210215220225230235240145150054959864769674479283988793498010271073111911651211125613021C-25L1521021522022523023524024515015516006496997487978468949439911C-2651101151201251301351401451501550600649698747795844892940988103610841131117712241271131713631C-2739 500500 800800 11001100 14001400 17001700 20002000 25002500 30003000 35003500 40004000 50005000 55005500 60006000 65006500 70007000 75007500 8000From Colour To MD39.00To2000.00MD A i TFace39.00 0.00 0.00300.00 0.00 0.00500.00 135.00 135.00700.00 135.00 0.001822.51 135.00 0.001944.68 135.00 0.002030.20 135.00 0.002050.20 135.00 0.003506.62 123.95 -16.666027.85 123.95 0.006771.65 122.50 -5.656791.65 122.50 0.006905.64 122.31 -9.517462.13 122.31 0.007474.61 122.30 -174.627609.45 122.03 -168.477758.88 122.03 0.00
1CͲ501wp12͘ϭACFlipbookSURVEY PROGRAMDepth From Depth To Tool39.00 1200.00 GYD-GC-SS1200.00 2020.00 MWD OWSG1200.00 2020.00 MWD+IFR2+SAG+MS2020.00 3020.00 MWD OWSG2020.00 6500.00 MWD+IFR2+SAG+MS6500.00 7500.00 MWD OWSG6500.00 7758.88 MWD+IFR2+SAG+MSCASING DETAILSTVDMDName1906.402030.2010-3/4" Surface Casing3529.406504.917-5/8" Intermediate Casing3551.407758.884-1/2" Production Liner20204040606080801001001201201401400901802703021060240120300150330Travelling Cylinder A imuth (TFO+A I) vs Travelling Cylinder Separation 40 usft/in2014206421152166221722682318236824182467251625641C-19039 500500 800800 11001100 14001400 17001700 20002000 25002500 30003000 35003500 40004000 50005000 55005500 60006000 65006500 70007000 75007500 8000From Colour To MD2000.00To4000.00MD A i TFace39.00 0.00 0.00300.00 0.00 0.00500.00 135.00 135.00700.00 135.00 0.001822.51 135.00 0.001944.68 135.00 0.002030.20 135.00 0.002050.20 135.00 0.003506.62 123.95 -16.666027.85 123.95 0.006771.65 122.50 -5.656791.65 122.50 0.006905.64 122.31 -9.517462.13 122.31 0.007474.61 122.30 -174.627609.45 122.03 -168.477758.88 122.03 0.00
1CͲ501wp12͘ϭACFlipbookSURVEY PROGRAMDepth From Depth To Tool39.00 1200.00 GYD-GC-SS1200.00 2020.00 MWD OWSG1200.00 2020.00 MWD+IFR2+SAG+MS2020.00 3020.00 MWD OWSG2020.00 6500.00 MWD+IFR2+SAG+MS6500.00 7500.00 MWD OWSG6500.00 7758.88 MWD+IFR2+SAG+MSCASING DETAILSTVDMDName1906.402030.2010-3/4" Surface Casing3529.406504.917-5/8" Intermediate Casing3551.407758.884-1/2" Production Liner454590901351351801802252252702703153150901802703021060240120300150330Travelling Cylinder A imuth (TFO+A I) vs Travelling Cylinder Separation 90 usft/in74417468749475197543756675877607762576427657767076831C-157 wp1240084057410641554204425343024351440044494498454745964645469447434793484248914940498950385087513651855234528353325381543054795528557756275676572557745823587259215970601960726127618262376292634864036459651465706626668167376790684268946943699270407088713671837230727673227367741174557498753975811C-158 wp0739 500500 800800 11001100 14001400 17001700 20002000 25002500 30003000 35003500 40004000 50005000 55005500 60006000 65006500 70007000 75007500 8000From Colour To MD4000.00To8000.00MD A i TFace39.00 0.00 0.00300.00 0.00 0.00500.00 135.00 135.00700.00 135.00 0.001822.51 135.00 0.001944.68 135.00 0.002030.20 135.00 0.002050.20 135.00 0.003506.62 123.95 -16.666027.85 123.95 0.006771.65 122.50 -5.656791.65 122.50 0.006905.64 122.31 -9.517462.13 122.31 0.007474.61 122.30 -174.627609.45 122.03 -168.477758.88 122.03 0.00
1C-501 wp12pider 10:2 , February 02 202339 00 5Northing (3500 usft/in)Easting (3500 usft/in)4 04244464850525456586062646668701C-014 042444648505254565860626466 1C-01L14 042444648505254565860626466 1C-01L1-014 042444648505254565860626466 1C-01L1-024 042444648505254565860626466 1C-01L1-03404244464850525456586062646 6681C-024 04244464850525456586 0626466681C-034 04244464850525456586 062641C-03A4042444648505254565860626466681C-0440424446485052545658606264
1C-04A40424446485052545658606264
1C-04AL1404244464850525456586062646668701C-05404244464850525456586062646668701C-0640424446485052545658606264
1C-06L140424446485052545658606264
1C-06L1-0140424446485052545658606264661C-06L1-02404244464850525456586062646668701C-07404244464850525456586062641C-07A404244464850525456586062641C-07AL1404244464850525456586062641C-07AL1PB1404244464850525456586062641C-07APB1404244464850525456586062646668701C-08404244464850525456586062641C-08L1404244464850525456586062641C-08L1-01404244464850525456586062641C-08L1PB14 04244464850525456586062646668701C-09404244464850525456586062646668701C-101C-1021C-102L11C-1041C-104L11C-104PB11C-1091C-109L1404244464850525456586062646668701C-1140424446485052545658606264661C-11L140424446485052545658606264661C-11L1-0140424446485052545658606264661C-11L1-0240424446485052545658606264661C-11L2404244464850525456586062641C-11L2-0140424446485052545658606264661C-11L2-0240421C-11140421C-11740421C-11940424446485052545658606264661C-12401C-12140421C-123401C-12540421C-12740424446485052545658606264661C-1340421C-13140421C-1331C-1351C-135PB14 0424446485052545658606264661C-144 0424446485052545658606264661C-14A4 042444648505254565860626466681C-154 0424446485052545658606264661C-15L14 0424446485052545658606264661C-15L24 0424446485052545658606264661C-15L2PB11C-1501C-1511C-1521C-1531C-1541C-15540424446485052545658606264661C-1640424446485052545658606264661C-171C-1701C-170PB11C-1721C-172A1C-172AL11C-172AL21C-172AL2PB11C-172AL2PB21C-1741C-1781C-178L11C-178L1PB11C-178L1PB240424446485052545658606264661C-181C-1844042444648505254565860626466681C-1940424446485052545658606264661C-19L11C-190404244464850525456586062646 61C-20404244464850525456586062641C-20PB1404244464850525456586062641C-21404244464850525456586062641C-21L1404244464850525456586062641C-21L2404244464850525456586062641C-21L34 042444648505254565860626466681C-2240
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4 648
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6 264
6 61C-234 0
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5 8
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6 264
1C-23A4 0
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4 648
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5 8
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6 2641C-23AL14 0
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4 648
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6 2641C-23AL2-014 0
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6 264 1C-23AL2-021C-23PB140424446485052545658606 2
6 4
1C-2440424446485052545658606 2
6 41C-24L140424446485052545658606264661C-25404244464850525456586062641C-25L140424446485052545658606264661C-2640424446485052545658606264 1C-27404244464850525456586062641C-28404244464850525456586062641C-28L1404244464850525456586062641C-28PB11C-156wp13-permit1C-157wp12401C-158wp071C-501wp12
1C-501 wp12pider 10:30, February 02 202339 00 5Northing (950 usft/in)Easting (950 usft/in)2 0222426
2 8
3 0
3 2
3 4
3 6
3 8
4 0
4 2
4 4464850525456586062646668701C-012 0222426
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4 44648505254565860626466 1C-01L12 0222426
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4 44648505254565860626466 1C-01L1-012 0222426
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4 44648505254565860626466
1C-01L1-022 0222426
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4 44648505254565860626466 1C-01L1-032022242628303234363840424446485052545658606264666 81C-022 0
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1C-032 0
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1C-03A2 0
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3 61C-04AL12022242628303234363840421C-052022241C-062022241C-06L12022241C-06L1-012022241C-06L1-02202224261C-07202224261C-07A202224261C-07AL1202224261C-07AL1PB1202224261C-07APB12022242628301C-082022242628301C-08L12022242628301C-08L1-012022242628301C-08L1PB12 0222426283032343638404244464850525456586062646668701C-09202224262830323436384042444648505254565860626466681C-10201C-102201C-102L11C-1041C-104L11C-104PB1202224262 83 0 323436381C-109202224262 83 0 3234361C-109L1201C-11201C-11L1201C-11L1-01201C-11L1-02201C-11L2201C-11L2-01201C-11L2-021C-11120221C-1171C-1192022242628303234363840424446481C-121C-12120221C-1231C-1252022241C-1272022242628301C-132022242628303234363840421C-1312022242628303234363840421C-13320222426283032341C-13520222426283032341C-135PB120
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5 01C-15L2PB12022242628303234361C-1502022242628303234361C-15120222426283032341C-1522 0222426283032341C-1532 022
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3 032341C-154202224262 8
303234361C-1552022241C-16201C-1720222426281C-17020222426281C-170PB120221C-17220221C-172A20221C-172AL120221C-172AL220221C-172AL2PB120221C-172AL2PB2201C-174201C-178201C-178L1201C-178L1PB1201C-178L1PB22022242628303234363840424446481C-18202224262830323436381C-18420222426281C-1920222426281C-19L1202224262830323436381C-190202224262830323436381C-20202224262830323436381C-20PB120222426283032343638404244464850525456586062641C-2120222426283032343638404244464850525456586062641C-21L120222426283032343638404244464850525456586062641C-21L220222426283032343638404244464850525456586062641C-21L32 0
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22
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40
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3 81C-23PB12022242628303234363840424446485052545658606 2
1C-242022242628303234363840424446485052545658606 21C-24L120
22
24
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28
30
32
34
36
38
40
42
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545658
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64661C-2520
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545658
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1C-25L120222426283032343638404244464850525456586062641C-262 0
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303234363840424446485052545658
60621C-272022242628303234363840424446481C-282022242628303234363840424446481C-28L12022242628303234363840424446481C-28PB12022242628303234363 81C-156 wp13 - permit20222426283032343 6381C-157 wp122022242628303234
3 638401C-158wp0720222426283032341C-501 wp12
1C-501 wp12pider 10: 2, February 02 202339 00 5Northing (200 usft/in)Easting (200 usft/in)24681012141 6
1 8
2 0
2 2
2 4
2 6
28
3 0
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3 4
3 61C-0124681012141 6
1 8
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28
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3 61C-01L124681012141 6
1 8
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28
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3 61C-01L1-0124681012141 6
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28
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1C-04246810
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6
1C-111246 8
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1C-117246
8
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1C-119681 0
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1 41618 202224261C-122468
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1C-1212468
10121C-123246
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1C-12524 681012141C-1272468101214161820221C-132468
101214161C-131246 81012141618201C-1332 4 681012141C-1352 4 681012141C-135PB124
6
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221C-27246810121416182022241C-28246810121416182022241C-28L1246810121416182022241C-28PB12468101214161820221C-156wp13 -permit02468101214161820221C-157wp12024681012141618201C-158wp0724681012141618201wp12
1C-501 wp12pider 10: 3, February 02 202339 00 5Northing (30 usft/in)Easting (30 usft/in)1234567891011121314151 6
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1C-501 wp121C-011C-01L11C-01L1-011C-01L1-021C-01L1-031C-03A1C-041C-051C-061C-06L11C-06L1-011C-06L1-021C-071C-07A1C-07AL1PB11C-07APB11C-091C-1091C-109L11C-111C-11L11C-11L1-011C-11L1-021C-11L21C-11L2-021C-1171C-1231C-1271C-131C-1311C-1331C-141C-151C-15L11C-15L2PB11C-161C-170PB11C-181C-191C-19L11C-21L11C-21L21C-23PB11C-24L11C-251C-25L13- View1C-501 wp1210 51 Fe ruary 02 2023
1C-501 wp121C-01L11C-01L1-011C-01L1-021C-01L1-031C-021C-031C-03A1C-041C-091C-101C-1021C-102L11C-1041C-104L11C-104PB11C-1091C-109L11C-1171C-1211C-1231C-1251C-1271C-1311C-1331C-135PB11C-1721C-172A1C-172AL11C-172AL21C-172AL2PB11C-172AL2PB21C-1841C-1901C-23PB11C-241C-24L13- View1C-501 wp1210 51 Fe ruary 02 2023
1C-501 wp123- View1C-501 wp1210 52 Fe ruary 02 2023
-5000-4000-3000-2000-10000South(-)/North(+) (1000 usft/in)-2000 -1000 0 1000 2000 3000 4000 5000 6000e - a 1000 u i
33531C-013353
1C -0 1L 1
3353 1C-01L1-013353 1C-01L1-023353 1C-01L1-0333531C -021 C -0 31C-0333 53
1C-033 53
1C-033 53
1C-0L11C-051 C -01C-0L11C-0L1-011C-0L1-021C-01C-01C-0L11C-0L111C-011C-01C-0L11C-0L1-011C-0L1133531C-0933531C-101C-1021C-102L11C-101C-10L11C-10133531C-10933531C-109L11C-111C-11L11C-11L1-011C-11L1-021C-11L21C-11L2-011C-11L2-021C-1111C-111C-11933531C-121C-1211C -12 31C-1251C-121C-1333531C-13133531C-13333531C-13533531C-13511 C -11C-11C -151C-15L11 C -1 5 L 2
1 C -1 5 L 2 1
31C-1501C-1511C-1521C-1531C-153351C-1551 C -1
1C-11C-101C-1011C-121C-121C-12L11C-12L21C-12L211C-12L221C-11C-11C-1L11C-1L111C-1L1233531C-133531C-11C-191C-19L133531C-19033531C-2033531 C -2 0 1
33531C-2133531C-21L133531C-21L233531C-21L31 C -2 2
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31C-233
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31C-23L13
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31C-23L2-023
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3
3531C-253
3531C-2 5 L 1
33531C-233531C-233531C-233531C-2L133531C-2133531C-15wp13-peri33531C-15wp123
3 5
31C-15wp03351C-501wp121C-501 wp12uar er i e View10:5 , February 02 2023WELLBORE TARGET DETAILS (MAP CO-ORDINATES)Name TVD Shape1C-501 Tgt 01 011223 3546.40 Circle (Radius 100.00)1C-501 Tgt 02 011223 3546.40 Circle (Radius 100.00)1C-501 Tgt 03 011223 3551.40 Circle (Radius 100.00)1C-501 Tgt 01 M 3546.40 Circle (Radius 1320.00)1C-501 Tgt 03 M 3551.40 Circle (Radius 1320.00)
-5000-4000-3000-2000-10000South(-)/North(+) (1000 usft/in)-2000 -1000 0 1000 2000 3000 4000 5000 6000e - a 1000 u i33531C-1233531C-2033531C-233531C-15wp1333531C-15wp123
3 5
3
1C-15wp03351C-501wp121C-501 wp12uar er i e View10:5 , February 02 2023WELLBORE TARGET DETAILS (MAP CO-ORDINATES)Name TVD Shape1C-501 Tgt 01 011223 3546.40 Circle (Radius 100.00)1C-501 Tgt 02 011223 3546.40 Circle (Radius 100.00)1C-501 Tgt 03 011223 3551.40 Circle (Radius 100.00)1C-501 Tgt 01 M 3546.40 Circle (Radius 1320.00)1C-501 Tgt 03 M 3551.40 Circle (Radius 1320.00)
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1C-501wp12
1C-501wp12
SchlumbergerͲConfidential
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From:McCracken, Shane M
To:Guhl, Meredith D (OGC); Hobbs, Greg S; Zanto, Emily J
Cc:Loepp, Victoria T (OGC); Davies, Stephen F (OGC); Roby, David S (OGC)
Subject:RE: 1C-501 Permit to Drill Application
Date:Tuesday, July 11, 2023 6:58:42 AM
Good Morning Meredith,
ConocoPhillips agrees with the change to Tertiary Undefined Water Supply pool. We appreciate your
assistance in reviewing and making the update.
Regards,
Shane McCracken
ConocoPhillips
Drilling Engineer
Anchorage
Office +1 (907) 265-6926
Cell +1 (907) 301-9571
From: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>
Sent: Monday, July 10, 2023 9:19 AM
To: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; McCracken, Shane M
<Shane.M.McCracken@conocophillips.com>; Zanto, Emily J <Emily.Zanto@conocophillips.com>
Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Davies, Stephen F (OGC)
<steve.davies@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>
Subject: [EXTERNAL]RE: 1C-501 Permit to Drill Application
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.
Greg, Shane, Emily,
The permit to drill for KRU 1C-501 is in review. Kuparuk water supply wells (WSW 2 through 11)
report to the Tertiary Undefined Water Supply (aka TERT UNDF WTRSP) pool (Field/Pool code
490168), and all appear to be completed in the Ugnu.
Should perhaps the pool for KRU 1C-501 be Tertiary Undefined Water supply instead of Ugnu
Undefined?
Thank you,
Meredith
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.
Meredith Guhl (she/her)
Petroleum Geology Assistant
Alaska Oil and Gas Conservation Commission
333 W. 7th Ave, Anchorage, AK 99501
meredith.guhl@alaska.gov
Direct: (907) 793-1235
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas
Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain
confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state
or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so
that the AOGCC is aware of the mistake in sending it to you, contact Meredith Guhl at 907-793-1235 or
meredith.guhl@alaska.gov.
From: "Hobbs, Greg S" <Greg.S.Hobbs@conocophillips.com>
Date: July 7, 2023 at 1:39:46 PM MDT
To: "Davies, Stephen F (OGC)" <steve.davies@alaska.gov>, "Loepp,
Victoria T (OGC)" <victoria.loepp@alaska.gov>
Cc: "McCracken, Shane M" <Shane.M.McCracken@conocophillips.com>,
"Zanto, Emily J" <Emily.Zanto@conocophillips.com>
Subject: 1C-501 Permit to Drill Application
Hello Steve and Victoria,
As the the field production engineering team was preparing for the
upcoming 1C-501 well, we had a discussion on what the pool should be
for the well. We are thinking it should be Ugnu Undefined. Shane used
the West Sak pool as that was a defined pool in the area. I could not find
a definition for the Ugnu undefined pool as I looked into it with the field
production engineer. The well is next on the schedule for Doyon 142,
anticipated to spud within 2 weeks, so I am hoping to have caught the
item before the package went to the Commissioners for signature.
Thank-you!
Greg
<image001.png>
Greg Hobbs, P.E.
Regulatory Engineer | Wells Team
ConocoPhillips Alaska Inc.
Office: 907-263-4749
Cell: 907-231-0515
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.
Tertiary Undefined Water Supply
KRU 1C-501
X
223-045
X
Kuparuk River
X
WELL PERMIT CHECKLISTCompanyConocoPhillips Alaska, Inc.Well Name:KUPARUK RIV UNIT 1C-501Initial Class/TypeSER / WTRSPGeoArea890Unit11160On/Off ShoreOnProgramSERField & PoolWell bore segAnnular DisposalPTD#:2230450KUPARUK RIVER, TERT UNDF WTRSP - 49016NA1Permit fee attachedYesSurf Loc & Top Prod Int lie in ADL0025649; TD lies in ADL0028242.2Lease number appropriateYes3Unique well name and numberNoKUPARUK RIVER, TERT UNDF WTRSP - 490168 - governed by Statewide Regs4Well located in a defined poolYes5Well located proper distance from drilling unit boundaryNA6Well located proper distance from other wellsYes7Sufficient acreage available in drilling unitYes8If deviated, is wellbore plat includedYes9Operator only affected partyYes10Operator has appropriate bond in forceYes11Permit can be issued without conservation orderYes12Permit can be issued without administrative approvalYes13Can permit be approved before 15-day waitNA14Well located within area and strata authorized by Injection Order # (put IO# in comments) (For servNAWater supply service well15All wells within 1/4 mile area of review identified (For service well only)NA16Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)Yes119'18Conductor string providedYes2030' MD SC shoe19Surface casing protects all known USDWsYes200% excess20CMT vol adequate to circulate on conductor & surf csgNo21CMT vol adequate to tie-in long string to surf csgNo22CMT will cover all known productive horizonsYes23Casing designs adequate for C, T, B & permafrostYes24Adequate tankage or reserve pitNA25If a re-drill, has a 10-403 for abandonment been approvedYes26Adequate wellbore separation proposedYesDiverter variance denied;27If diverter required, does it meet regulationsYesMax formation pressure is 1607 psig(8.7 ppg EMW) will drill w/ 8.0-10.5 ppg EMW28Drilling fluid program schematic & equip list adequateYes29BOPEs, do they meet regulationYesMPSP is 1252 psig; will test BOPs to 3500 psig30BOPE press rating appropriate; test to (put psig in comments)Yes31Choke manifold complies w/API RP-53 (May 84)Yes32Work will occur without operation shutdownYes33Is presence of H2S gas probableYes34Mechanical condition of wells within AOR verified (For service well only)NoH2S measures are required; rig has sensors and alarms.35Permit can be issued w/o hydrogen sulfide measuresYesExpected pressure range is 0.449 to 0.452 psi/ft (8.7 ppg EMW). Operator's planned mud program appears36Data presented on potential overpressure zonesNAsufficient to control anticipated pressures and maintain wellbore stability.37Seismic analysis of shallow gas zonesNAModerate risk of swabbing, lost circulation, differential sticking, and running liner to bottom. Realtime ECD38Seabed condition survey (if off-shore)NAmonitoring, LCM material, and reduced speeds are all identified as mitigation strategies.39Contact name/phone for weekly progress reports [exploratory only]ApprMDGDate7/12/2023ApprVTLDate7/17/2023ApprMDGDate7/13/2023AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDateJLC 7/19/2023
