Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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1058 Baker Hughes Drive
Broussard, LA 70518, USA
Dec 20, 2022
AOGCC
Attention: Kayla Junke
333 W. 7th Ave., Suite 100
Anchorage, Alaska 99501-3539
Subject:Final Log Distribution for ConocoPhillips Alaska, Inc.
3B-13L1
Kuparuk River
API #: 50-029-21286-60-00
Permit No: 222-126
Rig: CDR3
The final Coil deliverables were uploaded via https://copsftp.sharefile.com/ for the above well.
Items delivered: Digital Las Data, Graphic Images CGM/PDF and Survey Files.
Thank you.
Signature of receiver & date received:
Please return transmittal letter to:
Jenny Jones
Jenny.E.Jones@conocophillips.com
Luis G Arismendi
Luis.arismendi@bakerhughes.com
By Meredith Guhl at 7:41 am, Dec 20, 2022
222-126
T37393
Meredith Guhl Digitally signed by Meredith Guhl
Date: 2022.12.20 07:42:28 -09'00'
1a. Well Status:Oil SPLUG Other Abandoned Suspended
1b. Well Class:
20AAC 25.105 20AAC 25.110 Development Exploratory
GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test
2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry:
Aband.:
3. Address: 7. Date Spudded: 15. API Number:
4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number:
Surface:
Top of Productive Interval:17. Field / Pool(s):
GL: 0.0 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:
GR/Res
23.
BOTTOM
16" H-40 117'
9-5/8" J-55 3210'
7" J-55 6289'
2-3/8" L-80 5839'
24. Open to production or injection? Yes No 25.
26.
Was hydraulic fracturing used during completion? Yes No
DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED
27.
Date First Production: Method of Operation (Flowing, gas lift, etc.):
Hours Tested: Production for Gas-MCF:
Test Period
Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr):
Press. 24-Hour Rate
Sr Res EngSr Pet GeoSr Pet Eng
124 bean
N/A
Oil-Bbl: Water-Bbl:
231
Water-Bbl:
PRODUCTION TEST
11/21/2022
Date of Test: Oil-Bbl:
4473171 1294
11/23/2022 17.6
Flow Tubing
331
603
5980438
Gas Lift
Slotted Liner: 7497-12263' MD and 5873-5839' TVD
177
Gas-Oil Ratio:Choke Size:
Per 20 AAC 25.283 (i)(2) attach electronic information
26#
12263'
24'
5873'
62.5#
36#
117'
24' 8023'
SIZE DEPTH SET (MD)
7261' MD/ 5691' TVD
PACKER SET (MD/TVD)
24"
12-1/4"
229 sx PF "C"
30'900 sx AS III, 500 sx Class G,
92 sx AS I top job
4.6#
33'
7497'
3658'30'
33'
AMOUNT
PULLED
517763
515927
TOP
SETTING DEPTH MD
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.
BOTTOM
1500' MD/ 1497' TVD
7580' MD/ 5939' TVD
N/A
CASING WT. PER
FT.GRADE
11/14/2022
CEMENTING RECORD
5987099
SETTING DEPTH TVD
5982895
TOP HOLE SIZE
50-029-21286-60-00
KRU 3B-13L149' FSL, 786' FEL, Sec. 16, T12N, R9E, UM
2339' FSL, 2137' FWL, Sec. 28, T12N, R9E, UM
P.O. Box 100360, Anchorage, AK 99510-0360
518248 5991170
1259' FSL, 1290' FEL, Sec. 21, T12N, R9E, UM Kuparuk River Field/ Kuparuk River Oil Pool
ADL0025633, ADL0025642
ALK 2566
November 6, 2022
N/A
12263' MD/ 5839' TVD
9. Ref Elevations: KB: 85 ft
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
ConocoPhillips Alaska, Inc.
WAG
Gas
11/16/2022 222-126
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date perf'd or liner run):
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,
3"
TUBING RECORD
350 sx Class G, 250 sx AS I8-1/2"
7491' MD/ 5868' TVD
7655' MD3-1/2"
Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment
By James Brooks at 8:38 am, Dec 15, 2022
Completed
11/16/2022
JSB
RBDMS JSB 121622
G
Oil
Development
Permit to Drill Number /
KRU 3B-13L1
DSR-1/23/23
11/16/2022
WCB - 2023-07-14
Kuparuk River Field/ Kuparuk River Oil Pool
222-126
Date Comp
Conventional Core(s): Yes No Sidewall Cores:
N/A
30.
MD TVD
Surface Surface
1500' 1500'
Top of Productive Interval
7547' 5913'
7585' 5943'N/A
Kuparuk C 12263' 5839'
31. List of Attachments: Schematics, Definitive Survey, Summary of Operations
32. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Contact Name: Adam Klem
Digital Signature with Date:Contact Email: adam.klem@conocophillips.com
Contact Phone: (907) 263-4529
Senior CTD/ RWO Engineer
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:
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.
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.
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.
Kuparuk C
Authorized Title:
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.
TPI (Top of Producing Interval).
Authorized Name and
Formation Name at TD:
Bottom Kuparuk B
INSTRUCTIONS
Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
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.
Yes No
Well tested? Yes No
28. CORE DATA
If Yes, list intervals and formations tested, briefly summarizing test results for
each. Attach separate pages if needed and submit detailed test info including
reports and Excel or ASCII tables per 20 AAC 25.071.
NAME
Permafrost - Top
Permafrost - Base
29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS
Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov
Adam Klem Digitally signed by Adam Klem
Date: 2022.12.14 15:26:54 -09'00'
Page 1/12
3B-13
Report Printed: 11/18/2022
Operations Summary (with Timelog Depths)
Job: DRILLING SIDETRACK
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/4/2022
00:00
11/4/2022
02:30
2.50 MIRU, MOVE MOB P PJSM with Cruz, Jack up and pull pit
module off well. Install jeep on pits. Jack
up sub. Pull off well
0.0 0.0
11/4/2022
02:30
11/4/2022
04:30
2.00 MIRU, MOVE MOB P On the road to 3B 0.0 0.0
11/4/2022
04:30
11/4/2022
05:30
1.00 MIRU, MOVE MOB P On location, Pull jeeps off, Set mats,
R/U cellar spill containment
0.0 0.0
11/4/2022
05:30
11/4/2022
06:30
1.00 MIRU, MOVE MOB P Spot sub over well. Place mats. Set
down sub
0.0 0.0
11/4/2022
06:30
11/4/2022
07:30
1.00 MIRU, MOVE MOB P Spot pit module 0.0 0.0
11/4/2022
07:30
11/4/2022
08:30
1.00 MIRU, MOVE MOB P Safe out rig, stairs and landing.
Emergency exits.
0.0 0.0
11/4/2022
08:30
11/4/2022
12:00
3.50 MIRU, MOVE RURD P MIRU, Rig up interconnect, Rig up cellar
contanment, Spot is shop and half way
house, Prep for BOPE test
0.0 0.0
11/4/2022
12:00
11/4/2022
12:12
0.20 MIRU, MOVE SFTY P Crew change out, PJSM, Nipple up
BOPE, Accept Rig 12:00
0.0 0.0
11/4/2022
12:12
11/4/2022
14:24
2.20 MIRU, MOVE NUND P Nipple up BOPE, Grease crew out to
service tree
0.0 0.0
11/4/2022
14:24
11/4/2022
15:42
1.30 MIRU, MOVE NUND P Flood stack, get final valve alignment 0.0 0.0
11/4/2022
15:42
11/4/2022
15:54
0.20 MIRU, MOVE BOPE P Shell test BOPE to 3500 PSI 0.0 0.0
11/4/2022
15:54
11/4/2022
16:54
1.00 MIRU, WHDBOP BOPE P Start full BOPE test. Test witnessed by
Brian Bixbie AOGCC, 250 low, 3500 PSI
high
Test one swab valve # 2- Good
Test two, Blind shear, TV2, C-4,5,8, &12
- Good
Test three, TV1, C 3,6,7,11
0.0 0.0
11/4/2022
16:54
11/4/2022
22:30
5.61 MIRU, WHDBOP BOPE P Test four, Super choke C, Manual Choke
D Good
Test five Charlie1 & 3 & Tango 1 - Good
test
Test six lower2" pipe slips TIW , R1 &
BL1 Good test
Test seven Annular - Good test
Test eight upper 2" pipe slps Bravo 6 , 8
Lower TIW -Good test
'Test nine Bravo 7 , 5 Fail ' Pass - Good
test
Test ten 2 3/8" pipe rams - Good Test
Draw down test Accumulator - Pass
Test striper & inner reell valve - Good
0.0 0.0
11/4/2022
22:30
11/4/2022
23:30
1.00 MIRU, WHDBOP BOPE P Test taiger tank line
Test PDL'S
Check Accumulator bottles pre charge
0.0 0.0
11/4/2022
23:30
11/5/2022
00:00
0.50 PROD1, WHPST BOPE P Prep to pick up Whipstock & baker BHA 0.0 0.0
11/5/2022
00:00
11/5/2022
00:00
0.00 PROD1, WHPST PULD P PJSM PD whipstock & baker tools 0.0 0.0
11/5/2022
00:00
11/5/2022
02:00
2.00 PROD1, WHPST WPST P Have to RE- WIRE UQC 0.0 0.0
11/5/2022
02:00
11/5/2022
03:00
1.00 PROD1, WHPST WPST P M/U QC stab injector tag up set depths
RIH
74.7 7,410.0
11/5/2022
03:00
11/5/2022
05:30
2.50 PROD1, WHPST WPST P At 7410 tie into K-1 -2' Correction close
EDC set top of whipstock 7580' bottom
75892.7 set 3 k down
7.0 7,598.0
11/5/2022
05:30
11/5/2022
07:06
1.60 PROD1, WHPST WPST P Open EDC POOH 7,598.0 73.0
11/5/2022
07:06
11/5/2022
08:12
1.10 PROD1, WHPST WPST P At surface, Tag up, Space out, PUD
BHA #1
73.0 0.0
Rig: NABORS CDR3-AC
RIG RELEASE DATE 11/16/2022
Page 2/12
3B-13
Report Printed: 11/18/2022
Operations Summary (with Timelog Depths)
Job: DRILLING SIDETRACK
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/5/2022
08:12
11/5/2022
09:12
1.00 PROD1, WHPST WPST P PD BHA #2 window milling BHA with 1°
fixed bend motor, 2.80 window mill, and
2.80 string reamer. Make up to coil and
surface test. Stab on injector. Tag up
and set counters
0.0 78.3
11/5/2022
09:12
11/5/2022
10:48
1.60 PROD1, WHPST WPST P RIH, BHA #2, shallow test BHA @ 500'.
Diff 900 PSI. Continue in
78.3 7,440.0
11/5/2022
10:48
11/5/2022
11:00
0.20 PROD1, WHPST WPST P Log K1 for no correction, PUW=28K 7,440.0 7,467.0
11/5/2022
11:00
11/5/2022
11:18
0.30 PROD1, WHPST WPST P Continue in well, displace to milling fluid,
shut EDC. ease in to dry tag whipstock.
7,467.0 7,584.0
11/5/2022
11:18
11/5/2022
11:24
0.10 PROD1, WHPST WPST P PUH, PUW=28K, Bring pumps online
1.8 BPM @ 4577 PSI FS, 635 PSI Diff,
BHP=3430
7,584.0 7,584.1
11/5/2022
11:24
11/5/2022
14:18
2.90 PROD1, WHPST WPST P 7584.1, Milling window 1.8 BPM @ 4577
PSI FS, Diff=711
7,584.1 7,587.5
11/5/2022
14:18
11/5/2022
16:18
2.00 PROD1, WHPST WPST P Started loosing fluid, ~ .8 BPM,
WHP=240 PSI. Oened up choke zero
WHP. ECD=11.06. Pump 150+ LSRV hi
vis pill. Little to no effect on returns
7,587.5 7,589.7
11/5/2022
16:18
11/5/2022
18:50
2.54 PROD1, WHPST WPST P Try working WHP up to increase ECD's
at window before full exit, 40 PSI WHP
11.1PPG ECD @ .3 BPM losses
7,589.7 7,605.0
11/5/2022
18:50
11/5/2022
22:30
3.66 PROD1, WHPST WPST P Exit window BOW 7592' bottom of rat
hole 7605' ream window ream through
window 30° right and 30° left dry drift
clean drift tagged at 7605' pumped a
5x5 gel sweep
7,605.0 7,605.0
11/5/2022
22:30
11/6/2022
00:00
1.50 PROD1, WHPST WPST P POOH PU WT 31 k chase 5x5 to
surface At 500' continue OOH
7,605.0 7,605.0
11/6/2022
00:00
11/6/2022
00:18
0.30 PROD1, DRILL PULD P PUD window milling assembly L/D BHA
mill 2.79" no go tsing reamer 2.80" no
go stab back on well jet BOP stack
0.0 0.0
11/6/2022
00:18
11/6/2022
01:18
1.00 PROD1, DRILL PULD P PJSM PD Build section drilling BHA #3 0.0 0.0
11/6/2022
01:18
11/6/2022
02:18
1.00 PROD1, DRILL TRIP P M?U QC stab injector on well tag up set
depth RIH
72.2 7,605.0
11/6/2022
02:18
11/6/2022
08:36
6.30 PROD1, DRILL DRLG P At 7420 tie into K1 -2' RIH close EDC
start drilling @ 7605'
Bore 4085
Ann 3510 @ 1.7 BPM
pump 4220
WHP 285
7,605.0 7,755.0
11/6/2022
08:36
11/6/2022
10:36
2.00 PROD1, DRILL TRIP P Call EOB, Pump 5 X 5 sweeps, Trip out
for lateral BHA
7,755.0 73.0
11/6/2022
10:36
11/6/2022
11:00
0.40 PROD1, DRILL PULD P PJSM, PUD BHA #3 73.0 73.0
11/6/2022
11:00
11/6/2022
15:00
4.00 PROD1, DRILL PULD T High bend motor stuck in tree ~ 22
inches up. Check all tree valves, SSV
fully pressured up. Cycle tree valves in
attemt to move tools, Cycle bag, Unstab
PDL. Hook up to BHA. Change
orientation. Stab back on. tool still hung
up. Reconfigure injector lubricator to be
able to strip on higher tool string. Make
up injector. PUH for space out number.
RIH to 150' pumping. POOH. Tag up
and space out
73.0 74.6
11/6/2022
15:00
11/6/2022
16:00
1.00 PROD1, DRILL PULD T PJSM, PUD BHA # 3 74.6 0.0
11/6/2022
16:00
11/6/2022
17:30
1.50 PROD1, DRILL PULD P Lay down BHA #3 0.0 0.0
Rig: NABORS CDR3-AC
RIG RELEASE DATE 11/16/2022
Page 3/12
3B-13
Report Printed: 11/18/2022
Operations Summary (with Timelog Depths)
Job: DRILLING SIDETRACK
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/6/2022
17:30
11/6/2022
18:30
1.00 PROD1, DRILL TRIP P M?U BHA #4 lateral assembly .5° AKO
motor m/u QC stab injector on well tag
up set counters RIH shallow hole test
tools
78.2 7,420.0
11/6/2022
18:30
11/6/2022
20:00
1.50 PROD1, DRILL TRIP P At 7420' tie into K1 for a -6' correction
7457.8' AT 7650' WT CK 28 K RIH / WT
15K RA came in at 7587'
7,457.8 7,755.0
11/6/2022
20:00
11/6/2022
20:30
0.50 PROD1, DRILL DRLG P On bottom at 7755' having trouble
getting going pump a bottoms up getting
lots of sand back packing off
7,755.0 7,450.0
11/6/2022
20:30
11/7/2022
00:00
3.50 PROD1, DRILL DRLG P Got a bottoms up RBIH tagged up at
bottom of window made it through
window on bottom drilling/ Continue
drilling
7,755.0 7,926.0
11/7/2022
00:00
11/7/2022
00:00
0.00 PROD1, DRILL DRLG P Continue drilling current depth 7929'
Bore 4695,Ann 3561,Diff 1110, WHP
119, Pump 5200
7,926.0 8,200.0
11/7/2022
00:00
11/7/2022
02:18
2.30 PROD1, DRILL WPRT P At 8200' Wper trip up wt 31K 8,200.0 7,755.0
11/7/2022
02:18
11/7/2022
02:36
0.30 PROD1, DRILL DRLG P pump a 5X5 gel sweep 8,200.0 8,484.0
11/7/2022
02:36
11/7/2022
04:48
2.20 PROD1, DRILL WPRT P At 8484' wiper do to fast drilling came
up to 7770' RBIH
8,484.0 8,484.0
11/7/2022
04:48
11/7/2022
06:18
1.50 PROD1, DRILL DRLG P Back on bottom drilling 8,484.0 8,766.0
11/7/2022
06:18
11/7/2022
06:30
0.20 PROD1, DRILL WPRT P Pull BHA Wiper, PUW=30K 8,766.0 8,766.0
11/7/2022
06:30
11/7/2022
07:06
0.60 PROD1, DRILL DRLG P Drill, 1.85 BPM @ 4736 PSI FS,
BHP=3636, New mud going around
8,766.0 8,885.0
11/7/2022
07:06
11/7/2022
07:12
0.10 PROD1, DRILL WPRT P BHA wiper, PUW=28K 8,885.0 8,885.0
11/7/2022
07:12
11/7/2022
08:06
0.90 PROD1, DRILL DRLG P Drill, 1.85 BPM @ 4832 PSI FS,
BHP=3621
8,885.0 9,050.0
11/7/2022
08:06
11/7/2022
09:06
1.00 PROD1, DRILL WPRT P Long wiper #3 to 7600', Jog 4 1/2 9,050.0 7,600.0
11/7/2022
09:06
11/7/2022
09:12
0.10 PROD1, DRILL DLOG P Log tie in @ RA marker for +2'
correction
7,600.0 7,627.0
11/7/2022
09:12
11/7/2022
09:48
0.60 PROD1, DRILL WPRT P Comtinue wiper trip to bottom 7,627.0 9,050.0
11/7/2022
09:48
11/7/2022
12:24
2.60 PROD1, DRILL DRLG P Drill, 1.83 BPM @ 4713 PSI FS,
BHP=3627
9,050.0 9,452.0
11/7/2022
12:24
11/7/2022
13:54
1.50 PROD1, DRILL TRIP P Unable to drop out of zone, Unable to
build out of zone. Trip to dial up motor
9,452.0 72.0
11/7/2022
13:54
11/7/2022
15:00
1.10 PROD1, DRILL PULD P At surface, Tag up space out. PJSM
PUD BHA #4
72.0 0.0
11/7/2022
15:00
11/7/2022
16:12
1.20 PROD1, DRILL PULD P PD BHA #5 with RR HYC A3 and 1.2°
AKO motor. Surface test tool. Tag up set
counters
0.0 78.3
11/7/2022
16:12
11/7/2022
18:00
1.80 PROD1, DRILL TRIP P RIH BHA #5, Shallow test 500', continue
in EDC open
78.3 7,420.0
11/7/2022
18:00
11/7/2022
18:42
0.70 PROD1, DRILL DLOG P At 7420' tie into K1 for a -6' correction.
continue in hole
7,420.0 9,452.5
11/7/2022
18:42
11/7/2022
19:06
0.40 PROD1, DRILL DRLG P Back on bottom @ 9452.5' Resume
drilling Bore 4594 Ann 3675 Diff 1082
WHP 231 PUH up wt 34 K
9,452.5 9,547.5
11/7/2022
19:06
11/7/2022
19:54
0.80 PROD1, DRILL DRLG P Still unable to get motor to turn down try
time drilling and back reaming
9,574.5 9,560.0
11/7/2022
19:54
11/8/2022
00:00
4.10 PROD1, DRILL DRLG P Pick up drilling speed 9,578.0 9,578.0
11/8/2022
00:00
11/8/2022
02:36
2.60 PROD1, DRILL DRLG P At 9578' continue drilling ahead 100'
wiper
9,578.0 9,795.9
Rig: NABORS CDR3-AC
RIG RELEASE DATE 11/16/2022
Page 4/12
3B-13
Report Printed: 11/18/2022
Operations Summary (with Timelog Depths)
Job: DRILLING SIDETRACK
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/8/2022
02:36
11/8/2022
03:24
0.80 PROD1, DRILL TRIP P Pump a 5X5 gel sweep POOH to pick
up a .5° AKO motor
9,795.9 9,716.0
11/8/2022
03:24
11/8/2022
04:00
0.60 PROD1, DRILL TRIP P While doing injector inspection found
two broken chain link limp OOH to
window
9,716.0 9,716.0
11/8/2022
04:00
11/8/2022
08:18
4.30 PROD1, DRILL TRIP P Continue out of well 9,716.0 77.0
11/8/2022
08:18
11/8/2022
10:00
1.70 PROD1, DRILL PULD P At surface, Tag up. Space out, PUD
BHA #5 and lay down, Pull UQC
77.0 0.0
11/8/2022
10:00
11/8/2022
12:00
2.00 PROD1, DRILL CTOP T Prep to unstab CT from injector,
Remove CT from injector. Secure CT to
storage spool with chain and clamp.
0.0 0.0
11/8/2022
12:00
11/8/2022
17:00
5.00 PROD1, DRILL CTOP T Prep for injector swap. Remove
stripper, Move ODS PDLto clear area
for injector pick. Remove hydraulic amd
electrical lines from injector. Remove
diamond plate grating from cart. Install
rigging to top of injector.
0.0 0.0
11/8/2022
17:00
11/8/2022
20:00
3.00 PROD1, DRILL CTOP T Crane on location. PJSM. Pick injector
from cart and set on rig mats. Prep new
injector for crane pick and install. Clean
injector cart. Pick new injector. Set in
cart.
0.0 0.0
11/8/2022
20:00
11/9/2022
00:00
4.00 PROD1, DRILL CTOP T Reconnect hydraulics and electrical.
Troubleshoot load cell. Function test
new injector.
0.0 0.0
11/9/2022
00:00
11/9/2022
02:00
2.00 PROD1, DRILL CTOP T Continue to function test new injector.
Install gripper blocks. Troubleshoot
hydraulic lines.
0.0 0.0
11/9/2022
02:00
11/9/2022
03:30
1.50 PROD1, DRILL CTOP T Install injector guards. Raise injector
and trolley injector cart back. Prep for
stripper install.
0.0 0.0
11/9/2022
03:30
11/9/2022
08:00
4.50 PROD1, DRILL CTOP T Install stripper and lube line. Load
section of 2" coil into injector for max
pull test. Pull test new injector to 100K.
. Rig up and stab coil to injector.
0.0 0.0
11/9/2022
08:00
11/9/2022
08:30
0.50 PROD1, DRILL CTOP P Rewire UQB, test - Good 0.0 0.0
11/9/2022
08:30
11/9/2022
10:12
1.70 PROD1, DRILL PULD P PJSM, M/U & PD BHA # 6. Make up to
cpol and surface test. Tag up set
counters
0.0 80.2
11/9/2022
10:12
11/9/2022
11:12
1.00 PROD1, DRILL TRIP P RIH BHA #6, Checking counters and
injector operation
80.2 500.0
11/9/2022
11:12
11/9/2022
11:42
0.50 PROD1, DRILL TRIP P 500', Stop and shallow test BHA. 1.84
BPM @5040 PSI FS, 950 PSI Diff, shut
down pump. Open EDC.
500.0 500.0
11/9/2022
11:42
11/9/2022
16:00
4.30 PROD1, DRILL TRIP T Injector throwing error codes, VFD
related. Trouble shoot to failed encode.
replace, RIH. Still getting error
messages, Continue trouble shoot /
repair
500.0 1,505.0
11/9/2022
16:00
11/9/2022
17:30
1.50 PROD1, DRILL TRIP T PJSM, Shut upper and lower 2" pipe
slips. Manually lock in rams. Retract
skates to roll injector. Troubleshoot
derrick side injector chains. Injector
chains do not move freely as they
should.
1,505.0 1,505.0
Rig: NABORS CDR3-AC
RIG RELEASE DATE 11/16/2022
Page 5/12
3B-13
Report Printed: 11/18/2022
Operations Summary (with Timelog Depths)
Job: DRILLING SIDETRACK
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/9/2022
17:30
11/9/2022
18:30
1.00 PROD1, DRILL TRIP T Crew changeout. While troubleshooting
injector motor Electricians finger was
pinched. IP was sent to medic for
evaluation. Reported incident to D&W
HSE. Safety stand down performed
before continuing any further injector
troubleshooting.
1,505.0 1,505.0
11/9/2022
18:30
11/10/2022
00:00
5.50 PROD1, DRILL TRIP T Continued troubleshooting. Found
derrick side right angle drive seized up.
New right angle drive being sent from
Deadhorse.
1,505.0 1,505.0
11/10/2022
00:00
11/10/2022
04:00
4.00 PROD1, DRILL TRIP T Attempt to install new right angle drive.
Found shaft splines on new right angle
drive do not match injector brake.
Requested additional right angle drives
from Deadhorse. Test fit good. Install
right angle drive and injector motor.
1,505.0 1,505.0
11/10/2022
04:00
11/10/2022
05:00
1.00 PROD1, DRILL TRIP T Function test injector. Roll Chains.
Good Test. Manuals out on Pipe/Slip
rams. Grab traction. Pull to neutral Coil
Wt. of 15.5K lbs. Open Upper and
Lower Pipe/Slips. PUH top check coil.
1,505.0 1,505.0
11/10/2022
05:00
11/10/2022
08:00
3.00 PROD1, DRILL TRIP P Continue in well, Pick up every 1000' to
check coil for scrape marks. Clean down
to tie in
1,505.0 7,420.0
11/10/2022
08:00
11/10/2022
08:24
0.40 PROD1, DRILL DLOG P Log K1 for -11' correction, PUW=35K,
Close EDC
7,420.0 7,458.2
11/10/2022
08:24
11/10/2022
08:54
0.50 PROD1, DRILL TRIP P Continue in, Clean through window, Set
down 7670 to 7675, Pick up run through
7,458.2 8,090.0
11/10/2022
08:54
11/10/2022
09:54
1.00 PROD1, DRILL DLOG P Perform MADD pass, Sensor 8050 to
8550 sensor depth, 8 FPH
8,090.0 8,600.0
11/10/2022
09:54
11/10/2022
10:36
0.70 PROD1, DRILL TRIP P RIH to drill 8,600.0 9,775.0
11/10/2022
10:36
11/10/2022
11:36
1.00 PROD1, DRILL DRLG P 9820 Drill, 1.86 BPM @ 5179 PSI FS,
BHP=3791 PSI
9,775.0 9,915.0
11/10/2022
11:36
11/10/2022
13:30
1.90 PROD1, DRILL DRLG P Unable to drop inclination. PUH for a
couple of troughing passes, PUW=39K.
Perform troughing pass @ 5 FPM. 1.84
BPM @ 5,007 psi. BHP = 3746 psi.
9,915.0 9,915.0
11/10/2022
13:30
11/10/2022
14:30
1.00 PROD1, DRILL DRLG P Time Drill 1 FPH. WOB = 0.2Klbs. CT
Wt = 17.4Klbs. 1.84 BPM. BHP = 3722
psi.
9,915.0 9,916.0
11/10/2022
14:30
11/10/2022
15:30
1.00 PROD1, DRILL DRLG P Time Drill 2 FPH. WOB = 0.2Klbs. CT
Wt = 18.7Klbs. 1.84 BPM. BHP = 3727
psi.
9,916.0 9,918.0
11/10/2022
15:30
11/10/2022
16:12
0.70 PROD1, DRILL DRLG P Time Drill 20 FPH. WOB = 0.8Klbs. CT
Wt = 13.8Klbs. 1.84 BPM. BHP = 3727
psi.
9,918.0 9,935.0
11/10/2022
16:12
11/10/2022
17:30
1.30 PROD1, DRILL DRLG P Increase ROP. Avg 50 FPH. 1.84 BPM
@ 3,749 psi. Avg WOB = 1.6K lbs. Avg
CT WT 10K lbs. Holding 50 ROP to
maintain drop. Geo targeting 87 - 88
deg.
9,935.0 10,044.0
11/10/2022
17:30
11/10/2022
17:36
0.10 PROD1, DRILL WPRT P PUH to 9,958' for BHA wiper. PUW =
35 K lbs. 1.84 BPM. BHP = 3693 psi.
10,044.0 9,958.0
11/10/2022
17:36
11/10/2022
18:00
0.40 PROD1, DRILL WPRT P BOB Drilling. 1.84 BPM. BHP = 3,736
psi. WOB = 1.1K lbs. CT WT = 9.5K
lbs. Geo targeting 89-90 deg.
9,958.0 10,044.0
Rig: NABORS CDR3-AC
RIG RELEASE DATE 11/16/2022
Page 6/12
3B-13
Report Printed: 11/18/2022
Operations Summary (with Timelog Depths)
Job: DRILLING SIDETRACK
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/10/2022
18:00
11/10/2022
18:45
0.75 PROD1, DRILL DRLG P Drill ahead to 10,200'. Avg ROP = 160
FPH. WOB = 1.7K lbs. CT Wt = 6.3
Klbs. 1.84 BPM. BHP = 3773 psi. Geo
targetting 90-91 deg.
10,044.0 10,200.0
11/10/2022
18:45
11/10/2022
19:00
0.25 PROD1, DRILL WPRT P PUH for short wiper trip #1 to 9350'
chasing sweep uphole. PUW = 37K.
10,200.0 9,350.0
11/10/2022
19:00
11/10/2022
19:15
0.25 PROD1, DRILL WPRT P BOB. Avg CT Wt = 13 Klbs. 1.84 BPM
@ 5,029 psi. BHP = 3765 psi. IA = 630
psi. OA = 380 psi.
9,350.0 10,200.0
11/10/2022
19:15
11/10/2022
21:15
2.00 PROD1, DRILL DRLG P OBD. 1.84 BPM in / 1.78 out @ 5154
psi. WHP = 161, IA = 668, OA = 381
psi. BHP = 3769 psi. Holding 11.4 ppg
at the window. Avg. WOB = 1K lbs. Avg
ROP = 130 FPH.
10,200.0 10,400.0
11/10/2022
21:15
11/10/2022
21:18
0.05 PROD1, DRILL WPRT P Perform 100' BHA from 10,400' to
10,300'. Noticed ROP reduction drilling
up through transition zone. PUW = 34 K
lbs.
10,400.0 10,300.0
11/10/2022
21:18
11/10/2022
21:21
0.05 PROD1, DRILL WPRT P BOB drilling after BHA wiper. 10,300.0 10,400.0
11/10/2022
21:21
11/10/2022
22:39
1.30 PROD1, DRILL DRLG P Continue to drill ahead at reduced ROP
through transition zone per DD. 1.83
BPM @ 5,160 psi. WHP = 147, IA =
625, OA = 389 psi. Avg. WOB = -2 Klbs.
Avg ROP = 10 FPH. Diff = 1074 psi.
10,400.0 10,434.0
11/10/2022
22:39
11/10/2022
22:45
0.10 PROD1, DRILL WPRT P Perform 100' BHA wiper due to CT Wt of
-3Klbs and minimal motor work. PUW =
39K lbs. Send 5x5 gel sweep to clean
hole.
10,434.0 10,300.0
11/10/2022
22:45
11/10/2022
23:15
0.50 PROD1, DRILL WPRT P BOB drilling after BHA wiper. 1,100 psi
free spin. Drilled footage on current
mud system = 1,802'. 0.8% drill solids.
Swap to new mud.
10,300.0 10,434.0
11/10/2022
23:15
11/11/2022
00:00
0.75 PROD1, DRILL DRLG P Attempt to drill ahead @ 10,434'.
Seeing no motor work. 0 ROP. Diff. =
1,072 psi. WOB = 3.1 K lbs. CT Wt = -
4 K lbs. 1.83 BPM @ 4,739 psi. WHP =
189, IA = 557, OA = 392 psi. Suspect
worn bit or motor. Attempt to work
through.
10,434.0 10,434.0
11/11/2022
00:00
11/11/2022
00:30
0.50 PROD1, DRILL DRLG P Made multiple attempts to drill ahead.
Stacked -4 K lbs CT Wt. with WOB of
3.2 K lbs. Seeing no motor work or
differential. After 2 hours of no progress
decision was made to POOH and
inspect the BHA.
10,434.0 10,434.0
11/11/2022
00:30
11/11/2022
03:00
2.50 PROD1, DRILL TRIP T POOH with BHA #6. Clean drift through
window. Open EDC at 7,550'. At
surface. Bump up.
10,434.0 80.2
11/11/2022
03:00
11/11/2022
04:15
1.25 PROD1, DRILL PULD T PJSM. PUD BHA #6. Blowdown and
inspect all components. Hycalog Bit is
in good shape. Strider ERT checked
out ok. Baker motor failed. Can spin
the bit box by hand. Will replace Baker
motor for BHA #7.
80.2 0.0
11/11/2022
04:15
11/11/2022
04:45
0.50 PROD1, DRILL BOPE P Function test BOP's. Pipe/Slips, Blind,
Bag.
0.0 0.0
Rig: NABORS CDR3-AC
RIG RELEASE DATE 11/16/2022
Page 7/12
3B-13
Report Printed: 11/18/2022
Operations Summary (with Timelog Depths)
Job: DRILLING SIDETRACK
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/11/2022
04:45
11/11/2022
05:45
1.00 PROD1, DRILL PULD T MU and PD BHA #7 - new 0.5 deg AKO
motor with Strider and rerun same
Hycalog 3" bi-center bit. Make up
injector and surface test. Tag up and set
counters
0.0 80.2
11/11/2022
05:45
11/11/2022
07:18
1.55 PROD1, DRILL TRIP T RIH BHA #7, Shallow test @ 599;1.83
BPM @ 4623 PSI FS 930 PSI Diff,
Continue in
80.2 7,420.0
11/11/2022
07:18
11/11/2022
07:48
0.50 PROD1, DRILL DLOG T Log K1 for -15' correction, Clean &
adjust counter wheel in injector,
PUW=33K
7,420.0 7,457.0
11/11/2022
07:48
11/11/2022
09:06
1.30 PROD1, DRILL TRIP T Continue in well, Clean trip through
window and build, Tag up @ 10,434'
8 Hrs NPT for BHI Motor failure
7,457.0 10,434.0
11/11/2022
09:06
11/11/2022
14:18
5.20 PROD1, DRILL DRLG P Drill, 1.83 BPM @ 4664 PSI FS,
BHP=3738, Go to 95° inc. ROP mostly
20-30 FPH with breaks to 89-90 short
lived as we are climbing through
intervals. Multiple clean BHA wipers,
Good weight transfer
10,434.0 10,713.0
11/11/2022
14:18
11/11/2022
14:30
0.20 PROD1, DRILL WPRT P Short wiper trip, PUW=37K 10,713.0 10,713.0
11/11/2022
14:30
11/11/2022
16:18
1.80 PROD1, DRILL DRLG P OBD, 1.85 BPM @ 4998 PSI FS,
BHP=3858, ROP still variable
10,713.0 10,850.0
11/11/2022
16:18
11/11/2022
16:48
0.50 PROD1, DRILL WPRT P Short 400' wiper trip #1 to 10,000',
PUW=37K
10,850.0 10,000.0
11/11/2022
16:48
11/11/2022
17:03
0.25 PROD1, DRILL WPRT P Wiper back down to 10,850'. 10,000.0 10,850.0
11/11/2022
17:03
11/11/2022
18:33
1.50 PROD1, DRILL DRLG P OBD, 1.86 BPM @ 4880 PSI FS,
BHP=3759. Bore Press = 4691. Diff =
896 psi. WHP = 273, IA = 366, OA =
371. Avtg WOB = 1.3 K lbs. Avg. ROP
= 50 FPH. Send 5x5 gel piill.
10,850.0 10,988.0
11/11/2022
18:33
11/11/2022
18:39
0.10 PROD1, DRILL WPRT P Short BHA wiper chasing gel sweep.
PUW = 42K.
10,988.0 10,905.0
11/11/2022
18:39
11/11/2022
18:45
0.10 PROD1, DRILL WPRT P Wiper back in hole. 10,905.0 10,988.0
11/11/2022
18:45
11/11/2022
20:00
1.25 PROD1, DRILL DRLG P BOBD. 1.86 BPM in / 4876 psi. 1.75
BPM out. BHP = 3772. WHP = 255 IA
= 349 OA = 372. Avg CT Wt = 5 Klbs.
Avg. WOB = 0.7 K lbs. Avg ROP = 50
FPH
10,988.0 11,046.0
11/11/2022
20:00
11/11/2022
20:03
0.05 PROD1, DRILL WPRT P BHA wiper. CT WT = -6 Klbs. Poor
weight transfer to bit. PUW = 40K lbs.
11,046.0 10,935.0
11/11/2022
20:03
11/11/2022
20:06
0.05 PROD1, DRILL WPRT P Wiper back in hole. 10,935.0 11,046.0
11/11/2022
20:06
11/11/2022
22:06
2.00 PROD1, DRILL DRLG P BOBD. 1.85 BPM in @ 4908 psi. 1.75
BPM out. BHP = 3809. WHP = 257 IA =
381 OA = 373 psi. Avg. WOB = 1 Klbs.
Avg ROP = 70 FPH. Avg CT Wt. = 3
Klbs.
11,046.0 11,163.0
11/11/2022
22:06
11/11/2022
22:09
0.05 PROD1, DRILL WPRT P BHA wiper. Poor weight transfer to bit.
PUW = 36K lbs.
11,163.0 11,115.0
11/11/2022
22:09
11/11/2022
22:12
0.05 PROD1, DRILL WPRT P Wiper back in hole. 11,115.0 11,163.0
11/11/2022
22:12
11/11/2022
22:24
0.20 PROD1, DRILL DRLG P BOBD. 1.86 BPM @ 4930 psi. 1.76
BPM out. BHP = 3784. WHP = 211, IA
= 415, OA = 378. Poor weight transfer
to bit.
11,163.0 11,181.0
11/11/2022
22:24
11/11/2022
22:30
0.10 PROD1, DRILL WPRT P BHA wiper. Slow pump rate and by-
pass HP screens. Begin pumping
1#/bbl beaded sweeps to improve
weight transfer.
11,181.0 11,104.0
Rig: NABORS CDR3-AC
RIG RELEASE DATE 11/16/2022
Page 8/12
3B-13
Report Printed: 11/18/2022
Operations Summary (with Timelog Depths)
Job: DRILLING SIDETRACK
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/11/2022
22:30
11/11/2022
22:36
0.10 PROD1, DRILL WPRT P Wiper back in hole. Pump 5 bbl beaded
sweep.
11,104.0 11,181.0
11/11/2022
22:36
11/11/2022
23:36
1.00 PROD1, DRILL DRLG P BOBD. 1.88 BPM @ 5,013. 1.81 BPM
out. BHP = 3790 psi. Drill beads at the
nozzle @ 23:00. Send another 5 bbl
beaded sweep. Avg ROP = 80 FPH.
Avg WOB = 0.5 Klbs. Avg CT Wt = 1.5
Klbs.
11,181.0 11,250.0
11/11/2022
23:36
11/12/2022
00:00
0.40 PROD1, DRILL WPRT P Short wiper trip #2 up to 10,400'. 11,250.0 10,400.0
11/12/2022
00:00
11/12/2022
00:15
0.25 PROD1, DRILL WPRT P Wiper back in hole. Free spin 910 psi. 10,400.0 11,250.0
11/12/2022
00:15
11/12/2022
01:15
1.00 PROD1, DRILL DRLG P BOBD. 1.87 BPM @ 5,235 psi. 1.85
BPM out. BHP = 3829 psi. Continue
pumping 1#/bbl beaded sweeps to
improve weight transfer. WHP = 223, IA
= 433, OA = 379 psi. Differential = 1047
psi. Avg ROP = 100 FPH.
11,250.0 11,331.0
11/12/2022
01:15
11/12/2022
01:18
0.05 PROD1, DRILL WPRT P BHA wiper. Stacking -6.5 Klbs CT Wt,
poor weight transfer. PUW 37 Klbs.
11,331.0 11,310.0
11/12/2022
01:18
11/12/2022
01:21
0.05 PROD1, DRILL WPRT P Wiper back in hole. Free spin 906 psi. 11,310.0 11,331.0
11/12/2022
01:21
11/12/2022
01:54
0.55 PROD1, DRILL DRLG P BOBD. 1.83 BPM @ 4,988 psi. 1.79
BPM out. BHP = 3759 psi. Continue
pumping 1#/bbl beaded sweeps. WHP
= 201, IA = 443, OA = 379 psi.
Differential = 980 psi. Avg ROP = 60
FPH.
11,331.0 11,359.0
11/12/2022
01:54
11/12/2022
02:00
0.10 PROD1, DRILL WPRT P BHA wiper chasing gel sweep. PUW =
34K lbs.
11,359.0 11,297.0
11/12/2022
02:00
11/12/2022
02:06
0.10 PROD1, DRILL WPRT P Wiper back in hole. Free spin = 909 psi. 11,297.0 11,359.0
11/12/2022
02:06
11/12/2022
03:21
1.25 PROD1, DRILL DRLG P BOBD. 1.88 BPM @ 5,210 psi. BHP =
3807 psi. WHP = 185, IA = 458, OA =
381 psi. Differential = 1024 psi. Avg
ROP =
11,350.0 11,413.0
11/12/2022
03:21
11/12/2022
03:24
0.05 PROD1, DRILL WPRT P Stacking -6 K lbs CT Wt. with WOB =
0.3 K lbs. BHA wiper. PUW = 34 Klbs.
11,413.0 11,300.0
11/12/2022
03:24
11/12/2022
03:27
0.05 PROD1, DRILL WPRT P Wiper back in hole. Free spin = 905 psi.
Continue 1 #/bbl beaded sweeps to
improve weight transfer.
11,300.0 11,413.0
11/12/2022
03:27
11/12/2022
05:27
2.00 PROD1, DRILL DRLG P BOBD. 1.87 BPM in @ 5258 psi. 1.79
BPM out. BHP = 3816. WHP = 173, IA
= 473, OA = 381 psi. Avg diff = 990 psi.
Bump 1#/bbl beaded pill volumes up to
10 bbl sweeps. Current lube
concentration is 1% Lube 776.
11,413.0 11,503.0
11/12/2022
05:27
11/12/2022
05:39
0.20 PROD1, DRILL WPRT P BHA wiper, PUW=35K 11,503.0 11,503.0
11/12/2022
05:39
11/12/2022
06:51
1.20 PROD1, DRILL DRLG P Drill, 1.87 BPM @ 5230 PSI FS,
BHP=3820
11,503.0 11,592.0
11/12/2022
06:51
11/12/2022
07:03
0.20 PROD1, DRILL WPRT P BHA Wiper, PIW=35K 11,592.0 11,592.0
11/12/2022
07:03
11/12/2022
08:21
1.30 PROD1, DRILL DRLG P Drill, 1.85 NPM @ 5000 PSI FS,
BHP=3806
11,592.0 11,650.0
11/12/2022
08:21
11/12/2022
10:18
1.95 PROD1, DRILL WPRT P Long wiper to window with tie in,
PUW=39K, Rig blacked out @ 10,925'
for ~ 15 minutes, Continue out of hole. .
Pull up through window Jet 4 1/2 tubing
up to 7520
11,650.0 7,580.0
11/12/2022
10:18
11/12/2022
10:24
0.10 PROD1, DRILL DLOG P Tie into RA for + 2.5' 7,580.0 7,625.0
Rig: NABORS CDR3-AC
RIG RELEASE DATE 11/16/2022
Page 9/12
3B-13
Report Printed: 11/18/2022
Operations Summary (with Timelog Depths)
Job: DRILLING SIDETRACK
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/12/2022
10:24
11/12/2022
11:54
1.50 PROD1, DRILL WPRT P Wiper trip back to bottom. 4' from
bottom well started taking fluid ~ 1.2
BPM. WHP=245 holding 11.4 PPG at
window.
7,625.0 11,650.0
11/12/2022
11:54
11/12/2022
14:06
2.20 PROD1, DRILL DRLG P Drill, 1.86 BPM @ 5191 PSI FS,
BHP=3844. Returns .8 BPM. Work WHP
down to get more return rate. Returns
erratic. Get down to 200 PSI still under 1
BPM returns. Consult town.
11,650.0 11,776.0
11/12/2022
14:06
11/12/2022
14:24
0.30 PROD1, DRILL WPRT P Decide to shut choke, Pull 400' wiper
before shutting well in. returns .5 to .3
BPM, PUW=38K
11,776.0 11,776.0
11/12/2022
14:24
11/12/2022
16:57
2.55 PROD1, DRILL DRLG P Drill, 1.83 BPM @ 4660PSI FS, BHP
=3643. Shut in choke for low returns .2
- .4 BPM. Avg WOB = 1.5 Klbs.
11,776.0 11,896.0
11/12/2022
16:57
11/12/2022
17:09
0.20 PROD1, DRILL WPRT P Short BHA wiper back to 11,831'. PUW
= 38K lbs.
11,896.0 11,896.0
11/12/2022
17:09
11/12/2022
18:21
1.20 PROD1, DRILL DRLG P BOBD, 1.83 BPM @ 5008 PSI, BHP
=3743. Choke still shut-in. Drilling on
100% losses. WHP =
11,896.0 11,933.0
11/12/2022
18:21
11/12/2022
18:33
0.20 PROD1, DRILL WPRT P Short BHA wiper back to 11,863'. PUW
= 44 K lbs Free spin = 901 psi
11,933.0 11,933.0
11/12/2022
18:33
11/12/2022
19:33
1.00 PROD1, DRILL DRLG P BOBD, 1.86 BPM @ 5008 PSI, BHP
=3743. Choke shut-in. Drilling on 100%
losses. WHP = 657, IA = 0, OA = 346
psi. Avg ROP = 35 FPH. Avg WOB =
3.3 K lbs. Diff = 1020 psi.
11,933.0 11,973.0
11/12/2022
19:33
11/12/2022
19:39
0.10 PROD1, DRILL WPRT P Short BHA wiper back to 11,935'. PUW
= 53K lbs. Increase short wiper trip
frequency to monitor increasing PU
weights.
11,973.0 11,973.0
11/12/2022
19:39
11/12/2022
20:15
0.60 PROD1, DRILL DRLG P BOBD, 1.87 BPM @ 5225 PSI, BHP
=3761. Choke shut-in. Drilling on 100%
losses. WHP = 729, IA = 0, OA = 345
psi. Avg ROP = 30 FPH. Avg WOB =
1.36 K lbs. Diff = 1011 psi. Level 4
vibrations @ 11,994' at 20:15. Drilling
hard formation. ROP down to 9 FPH.
11,973.0 11,994.0
11/12/2022
20:15
11/12/2022
20:21
0.10 PROD1, DRILL WPRT P BHA wiper back up to 11,977'. PUW =
52K lbs.
11,994.0 11,994.0
11/12/2022
20:21
11/12/2022
22:45
2.40 PROD1, DRILL DRLG P BOBD w/ choke closed holding 11.8# at
the window. 1.87 BPM @ 5185 psi.
BHP = 3796 psi. WHP = 664 psi. IA =
0, OA = 343 psi. Avg ROP = 20 FPH.
Avg WOB = 1 Klbs. Diff = 987 psi.
Level 2 and 3 vibrations while drilling
hard formation.
11,994.0 12,050.0
11/12/2022
22:45
11/12/2022
23:30
0.75 PROD1, DRILL WPRT P Short Wiper #1 back to 11,200'. PUW =
35 K lbs. Attempt to establish returns.
No Joy. Max returns 0.5 BPM dropped
off to 0.2 BPM. Closed choke back in.
RBIH clean past fault @ 11,760'. CT
Wt. bobble at 11,850'. Lowered pump
rate to 1 BPM to get through.
12,050.0 12,050.0
11/12/2022
23:30
11/13/2022
00:00
0.50 PROD1, DRILL DRLG P BOBD with choke closed in, holding
11.8# at the window. 1.85 BPM @
5,107 psi. BHP = 3795 psi. WHP =
677, IA = 0, OA = 353. Diff = 1057 psi.
Avg ROP = 25 FPH. Avg WOB = 1 K
lbs.
12,050.0 12,066.0
11/13/2022
00:00
11/13/2022
00:33
0.55 PROD1, DRILL DRLG P Drilled to 12,088' with choke closed.
Continue pumping beaded sweeps to
maintain weight transfer.
12,066.0 12,088.0
Rig: NABORS CDR3-AC
RIG RELEASE DATE 11/16/2022
Page 10/12
3B-13
Report Printed: 11/18/2022
Operations Summary (with Timelog Depths)
Job: DRILLING SIDETRACK
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/13/2022
00:33
11/13/2022
00:39
0.10 PROD1, DRILL WPRT P BHA wiper to 12,071' . PUW = 53K lbs. 12,088.0 12,088.0
11/13/2022
00:39
11/13/2022
03:09
2.50 PROD1, DRILL DRLG P BOBD. 1.80 BPM @ 4810 psi. WHP =
768 , IA = 0 , OA = 351 psi. Diff = 950
psi. Avg ROP = 40 FPH Avg WOB =
1.2 Avg CT Wt.= 5. Near bit Inc = 99.
12,088.0 12,196.0
11/13/2022
03:09
11/13/2022
03:15
0.10 PROD1, DRILL WPRT P BHA wiper up to 12,179'. PUW = 43K 12,196.0 12,196.0
11/13/2022
03:15
11/13/2022
04:45
1.50 PROD1, DRILL DRLG P BOBD with choke closed. 1.88 BPM @
4971 psi. WHP = 807 , IA = 0 , OA =
357 psi. Diff = 1008 psi. Avg ROP = 30
FPH Avg WOB = 1 Avg CT Wt.= 2.
12,196.0 12,230.0
11/13/2022
04:45
11/13/2022
04:51
0.10 PROD1, DRILL WPRT P BHA wiper to 12,204'. PUW = 45K. 12,230.0 12,230.0
11/13/2022
04:51
11/13/2022
06:36
1.75 PROD1, DRILL DRLG P BOBD. 12,230.0 12,260.0
11/13/2022
06:36
11/13/2022
08:30
1.90 PROD1, DRILL TRIP T BHA has blugged off, BHA will hold
6500 PSI. Can not pump down CT.
POOH. Line up across top to maintain
BHP
12,260.0 7,564.0
11/13/2022
08:30
11/13/2022
10:12
1.70 PROD1, DRILL TRIP T Stop and open EDC, Able to pump down
coil, Continue out
7,564.0 66.0
11/13/2022
10:12
11/13/2022
11:30
1.30 PROD1, DRILL PULD T PJSM, PUD BHA #7, Talk about
potential trapped pressure in BHA. EDC
has motor fault erro, high amperage.
FVS failed during undeployment. Call
change of scope SM. Go to correct
checklist. Continue PUD
66.0 0.0
11/13/2022
11:30
11/13/2022
13:42
2.20 PROD1, DRILL PULD T Make up BHA #8 with RR motor, NOV
agitator, and RR bit. PD BHA #8, Make
up to coil and surface test. Tag up and
set counters
0.0 68.7
11/13/2022
13:42
11/13/2022
15:42
2.00 PROD1, DRILL TRIP T RIH BHA #8, Shallow test @ 500'1.81
BPM @4349 PSI FS, 670 PSI Diff,
continue in well
68.7 7,420.0
11/13/2022
15:42
11/13/2022
15:48
0.10 PROD1, DRILL DLOG T Log K1 for -14' Correctiom 7,420.0 7,456.0
11/13/2022
15:48
11/13/2022
16:06
0.30 PROD1, DRILL TRIP T RIH to 7559, Sensor 7520 MD, Sensor
TVDSS=5807, Annular 3250,
EMW=10.7 PPG
7,456.0 7,459.0
11/13/2022
16:06
11/13/2022
18:15
2.15 PROD1, DRILL TRIP T Continue RIH to TD. Set down @ 12,
233'. Off Baker trouble time. 9.5 hours
7,459.0 12,233.0
11/13/2022
18:15
11/13/2022
18:30
0.25 PROD1, DRILL DRLG P Pump beaded pill. Set down CT Wt. @
12,233'. Attempt to wash back down to
previous TD of 12,260'. Slowly washed
down to 12,240'.
12,233.0 12,240.0
11/13/2022
18:30
11/13/2022
19:00
0.50 PROD1, DRILL WPRT P BHA Wiper. PUW = 40K. Formation
acting sticky. May have entered D-
shale. WOB = -2K. Annular pressure
showed early signs of pack-off.
Decision made to perform swab wiper
from 12,240'.
12,240.0 12,240.0
11/13/2022
19:00
11/14/2022
00:00
5.00 PROD1, DRILL WPRT P Pump 10 x 10 sweep. Gel sweep at
nozzle. Perform swab wiper to surface
@ 40 FPM. Initial PUW of btm = 45K
lbs. At 9,200' (21:15) opened choke and
established full returns. Slow to 0.3
BPM BPM and 30 FPM, oriented HS
through window. Jog 4 1/2" tubing to
clean up. Continue pulling swab wiper
@ 80 FPM. Tag up. Reset counters.
12,240.0 68.7
Rig: NABORS CDR3-AC
RIG RELEASE DATE 11/16/2022
Page 11/12
3B-13
Report Printed: 11/18/2022
Operations Summary (with Timelog Depths)
Job: DRILLING SIDETRACK
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/14/2022
00:00
11/14/2022
01:24
1.40 PROD1, DRILL TRIP P RIH to 7,400'. Log K-1 for a -13'
correction. Park coil at for pressure
survey.
68.7 7,560.0
11/14/2022
01:24
11/14/2022
01:30
0.10 PROD1, DRILL CTOP P Harvest static pressure at window to
confirm KWF.
CTMD = 7560'
Sensor TVD = 5893'
Annular Pressure = 3335 psi.
EMW = 10.9 ppg
7,560.0 7,560.0
11/14/2022
01:30
11/14/2022
01:39
0.15 PROD1, DRILL TRIP P PUW = 36K. Orient high side with
pumps at min rate.
7,560.0 7,544.0
11/14/2022
01:39
11/14/2022
03:09
1.50 PROD1, DRILL TRIP P RIH and set down at bottom of window
@ 7,594'. PUH and re-drift clean at min
rate. Continue RIH. SI choke @
10,495' to maintain ECD at window
above 11.4#.
7,544.0 10,495.0
11/14/2022
03:09
11/14/2022
04:03
0.90 PROD1, DRILL TRIP P Continue RIH with choke closed. Begin
pumping beaded sweeps to reach
lateral TD. Increased pump rate to 1
BPM to circulate beaded pill down CT.
Set down at 12,263'.
10,495.0 12,263.0
11/14/2022
04:03
11/14/2022
04:57
0.90 PROD1, DRILL CIRC P PUW @ TD of 12,263' = 50K lbs. Mix
and circulate 11.4# LRP to the bit.
12,263.0 12,263.0
11/14/2022
04:57
11/14/2022
08:18
3.35 PROD1, DRILL TRIP P POOH. Lay in 48 bbls of 11.4# LRP.
Pump rate @ 0.5 BPM to reduce losses,
maintaining 11.4# ECD at window. Paint
EOP flags @ 10944' and 6200'.
12,263.0 111.0
11/14/2022
08:18
11/14/2022
08:48
0.50 PROD1, DRILL OWFF P At 111 feet, Perform 30 min flow check,
Good.
111.0 111.0
11/14/2022
08:48
11/14/2022
09:42
0.90 PROD1, DRILL PULD P PJSM. Lay down BHA #8 111.0 0.0
11/14/2022
09:42
11/14/2022
12:12
2.50 COMPZ1, CASING PUTB P PJSM, P/U BHA # 9 - L1 lower liner
segment (40 joints)
0.0 1,269.0
11/14/2022
12:12
11/14/2022
12:42
0.50 COMPZ1, CASING PULD P Make up coiltrak to liner. Make up coil
and surface test. Tag up set counters
1,269.0 1,313.9
11/14/2022
12:42
11/14/2022
14:21
1.65 COMPZ1, CASING RUNL P RIH with 40 joints of 2 3/8" slotted liner
(1,269').
1,313.9 7,514.0
11/14/2022
14:21
11/14/2022
14:27
0.10 COMPZ1, CASING DLOG P Tie into window flag. -24' correction.
PUW = 36K
7,514.0 7,514.0
11/14/2022
14:27
11/14/2022
14:51
0.40 COMPZ1, CASING RUNL P Continue RIH with 1st section of 2 3/8"
liner
7,514.0 8,680.0
11/14/2022
14:51
11/14/2022
14:57
0.10 COMPZ1, CASING DLOG P Tie into K-1. +12' correction. Not
applied to bit depth.
8,680.0 8,680.0
11/14/2022
14:57
11/14/2022
16:39
1.70 COMPZ1, CASING RUNL P Continue RIH with 1st section of liner.
Set down. Release from liner. TOL @
10,993'. PUW = 36K.
8,680.0 12,263.0
11/14/2022
16:39
11/14/2022
16:42
0.05 COMPZ1, CASING DLOG P Correct bit depth to 10,961' for released
liner.
12,263.0 10,961.0
11/14/2022
16:42
11/14/2022
19:36
2.90 COMPZ1, CASING TRIP P POOH pumping LRP. Paint yellow TD
flag @ 9,499'. Continue to POOH.
Perform RA tie-in. no correction. Cont.
POOH.
10,961.0 5,944.0
11/14/2022
19:36
11/14/2022
20:42
1.10 COMPZ1, CASING TRIP P Paint white window flag @ 5,944'.
Continue POOH to surface. Perform No
Flow Test. Good.
5,944.0 44.0
11/14/2022
20:42
11/14/2022
21:18
0.60 COMPZ1, CASING PULD P Lay down BHA #9 over a dead well. 44.0 0.0
11/14/2022
21:18
11/15/2022
00:00
2.70 COMPZ1, CASING PUTB P PJSM, P/U L1 intermediate liner
segment (47 joints). P/U last of
intermediate liner section at midnight.
0.0 1,488.0
11/15/2022
00:00
11/15/2022
00:45
0.75 COMPZ1, CASING PULD P Make up coiltrak to liner. Make up coil
and surface test. Tag up set counters.
1,488.0 1,532.0
Rig: NABORS CDR3-AC
RIG RELEASE DATE 11/16/2022
Page 12/12
3B-13
Report Printed: 11/18/2022
Operations Summary (with Timelog Depths)
Job: DRILLING SIDETRACK
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/15/2022
00:45
11/15/2022
01:45
1.00 COMPZ1, CASING RUNL P RIH with 47 joints of 2 3/8" slotted liner
(1,488') pumping min rate of 0.3 BPM.
1,532.0 7,433.0
11/15/2022
01:45
11/15/2022
02:00
0.25 COMPZ1, CASING DLOG P Tie-in at window flag for a -2.5'
correction. Injector counter off. Clean
debris from wheel. Come off on pumps.
PUW = 35K just above the window.
Cont. RIH.
7,433.0 7,542.0
11/15/2022
02:00
11/15/2022
02:45
0.75 COMPZ1, CASING RUNL P Cont. RIH. Tie-in at RA tag of +18'. Not
applied to bit depth.
7,542.0 9,060.0
11/15/2022
02:45
11/15/2022
03:45
1.00 COMPZ1, CASING RUNL P Cont. RIH with intermediate liner. PUW
@ 10,902' = 45 K lbs. Apply +18' depth
correction based off RA tag. RIH and
latch into lower liner segment @ 10,933.
PU 49 K lbs to confirm latched. WOB =
-10K. Set down. Pump 1.50 BPM to
release. Diff = 1,010 psi. PUW = 33 K.
9,060.0 10,933.0
11/15/2022
03:45
11/15/2022
03:51
0.10 COMPZ1, CASING DLOG P Correct bit depth for released liner.
Liner Length = 1488.94'
10,933.0 9,444.0
11/15/2022
03:51
11/15/2022
06:51
3.00 COMPZ1, CASING TRIP P POOH laying in LRP #3 to window.
Paint White TD flag at 7,492'. Paint
Yellow window flag @ 5,444'. Continue
POOH.
9,444.0 44.0
11/15/2022
06:51
11/15/2022
07:36
0.75 COMPZ1, CASING PULD P No Flow Test. Good. Lay down BHA
#10 over a dead well.
44.0 0.0
11/15/2022
07:36
11/15/2022
10:36
3.00 COMPZ1, CASING PUTB P PU BHA #11 - Upper Liner Segment.
Dissolving bullnose, 48 joints slotted,
swell packer, 16 joint solid, deployment
sleeve.
0.0 2,006.8
11/15/2022
10:36
11/15/2022
11:18
0.70 COMPZ1, CASING PULD P MU Coiltrak to upper liner segment.
M/U injector. Surface test.
2,006.8 2,050.7
11/15/2022
11:18
11/15/2022
13:30
2.20 COMPZ1, CASING RUNL P RIH with upper liner segment and
Coiltrak tools. Set weight to 12 k lbs,
white flag in the horses head. PU Wt 48
k lbs, WOB to neg 14 k lbs - latched up.
RBIH, stack 9 k lbs down weight. Pump
1.40 bpm, diff pressure to 880 psi, PU
Wt 32 k lbs, WOB 0.
Liner set on depth - bottom of upper
section, 9500.96' TOL 7497.27';
2,050.7 9,500.0
11/15/2022
13:30
11/15/2022
15:00
1.50 COMPZ1, CASING DISP P PUH, correct bit depth to reflect dropped
off liner. Displace coil and well bore to
seawater.
9,500.0 7,445.9
11/15/2022
15:00
11/15/2022
15:24
0.40 COMPZ1, CASING DLOG P Park coil, bit depth 7445.90' TVD.
5,821.85' TVD. Trap pressure of 3,440
psi, choke closed. Observe pressure
fall to 3,303 psi. bleed wellhead twice,
***observe pressure stabilize at 3,292
psi - 10.88 ppg EMW.
LRS on location, PJSM, PT to 4,700 psi.
7,445.9 7,446.0
11/15/2022
15:24
11/15/2022
17:54
2.50 COMPZ1, CASING TRIP P PUH while turning coil over to diesel.
Lay diesel on the fly from 2,500' to
surface.
7,446.0 60.0
11/15/2022
17:54
11/15/2022
19:24
1.50 DEMOB, WHDBOP PULD P PUD BHA 480psi under master 60.0 0.0
11/15/2022
19:24
11/15/2022
20:54
1.50 DEMOB, WHDBOP CIRC P Flush stack // pull checks for bop test on
2W
0.0 0.0
11/15/2022
20:54
11/15/2022
21:24
0.50 DEMOB, WHDBOP CTOP P Freeze protect tree // Blow down tiger
tank line and rig down tt line
0.0 0.0
11/15/2022
21:24
11/16/2022
00:00
2.60 DEMOB, WHDBOP RURD P Rig down checklists // Rig Released
from 3B-13 @ 0000 on 11/16/2022
0.0 0.0
Rig: NABORS CDR3-AC
RIG RELEASE DATE 11/16/2022
DTTMSTART JOBTYP SUMMARYOPS
10/19/2022 SUPPORT OTHER
OPERATIONS
SHAKE OFF BAITED PULLING TOOL ABOVE BALL & ROD @ 7600' RKB; PULLED SOV &
SET DV @ 7223' RKB; PULLED DV & SET OV @ 4921' RKB; PULLED DV & SET GLV @
3132' RKB (OBTAIN GOOD TBG TEST); PULLED BAITED PULLING TOOL & BALL n' ROD
@ 7644' RKB. IN PROGRESS.
10/20/2022 SUPPORT OTHER
OPERATIONS
PULLED 2.813" RHC PLUG BODY @ 7638' RKB; DRIFT W/ DMY CEMENT RETAINER
DOWN TO 7643' RKB; PERFORMED STEP RATE INJECTIVITY TEST FROM .5 UP TO 2
BPM @ 775 PSI. READY FOR CTU.
10/28/2022 SUPPORT OTHER
OPERATIONS
8.5 HOURS OF NPT DUE TO HYDRAULIC HOSE FAILURE, PERFORM TIE IN LOG FROM
7666'' CTMD TO 7000' CTMD AT 50 FPM, STACKED DOWN LUBRICATOR TO REPLACE
LEAKING HYDRAULIC HOSE
10/29/2022 SUPPORT OTHER
OPERATIONS
REPLACED LEAKING HYDRAULIC HOSE ON THE MAST, SET CEMENT RETAINER AT
7640' RKB, PUMP 5 BBLS OF 15.8# CLASS G CEMENT BELOW RETAINER, UN-STING
FROM RETAINER AND CIRCULATE 25 BBLS OF POWER-VIS FOLLOWED BY DIESEL TO
SURFACE, READY FOR SLICKLINE, IN PROGRESS.
10/31/2022 SUPPORT OTHER
OPERATIONS
RUN 2.62" X 10' DMY WHIP STOCK DRIFT TO TOP OF CEMENT RETAINER @ 7640'
RKB, NO TIGHT SPOTS OR WEIGHT SWINGS, CALIPER TBG FROM 7640' RKB TO 6640'
RKB, REQUESTED QUICK TURN AROUND FOR CALIPER DATA. STILL NEED TO MIT-T
TBG.
11/1/2022 SUPPORT OTHER
OPERATIONS
MIT-T TO 1500 PSI *PASSED*. PUMPED 0.4 BBLS DSL DOWN TBG TO REACH TEST
PRESSURE. BLED TBG, BLED BACK 0.4 BBLS. RDMO. (JOB COMPLETE)
11/4/2022 DRILLING
SIDETRACK
MOB 3G to 3B-13, Complete initial BOPe test, test witnessed by Brian Bixby, AOGCC. PT
deployment lubricators and tiger tank line.
11/5/2022 DRILLING
SIDETRACK
Set TOWS @ 7580 HS milled window from TOW 7584' to BOW 7592 'drilled 13' of rat hole
7605' ' reamed window / reamed through 30° ROHS & 30° LOHS dry drift. Drill build section
7605 to 7755'. AVG DLS 37.75°
11/6/2022 DRILLING
SIDETRACK
P/U build section BHA. Drill build to 7755'. Trip for lateral BHA. High bend motor hung in tree.
Get free. PD BHA #4 lateral assembly drilling from 7755' toward TD
11/7/2022 DRILLING
SIDETRACK
Tripped OOH to pick up a 1.2° AKO motor not able to get the .5° to drop. Still having troubles
getting the 1.2° to drop time drill trying to get it to drop
11/8/2022 DRILLING
SIDETRACK
Drilled to 9,796'. POOH to pick up 0.5° AKO motor. While POOH found two broken chain
links during injector inspection. Continue to POOH. PUD BHA #5. Swap and function test
new Injector.
11/9/2022 DRILLING
SIDETRACK
Finish function testing Injector. Pull test and stab pipe. PD BHA #6. Perform shallow BHA
test @ 500'. Good test. Open EDC. Injector began sending error codes. Troubleshoot.
Replaced bad encoder. RIH to 1,505'. Cont. to experience injector issues. Troubleshoot
derrick side motor/chains. Found right angle drive seized. Replacement sent from
Deadhorse.
11/10/2022 DRILLING
SIDETRACK
Install new right angle drive and injector motor. Function test. RIH and tie into K-1 marker for
-11' correction. Perform MADD pass from 8050' - 8550' sensor depth. RIH and drill from
9,775' - 9,915'. Had difficulty dropping. Make troughing pass and time drill to 9,935'. Drilled
ahead from 9,935' to 10,434' where ROP and motor work fell off.
11/11/2022 DRILLING
SIDETRACK Made multiple attempts to drill past 10,434' without success. POOH and PUD BHA #6.
Inspect. Found Baker motor had failed. Function test BOP's. MU and PD BHA #7 with new
motor. RIH and tied into K-1 for a -15' correction. Drilled from 10,434' to 11,250'.
11/12/2022 DRILLING
SIDETRACK
Performed short wiper #2. RBIH and drilled from 11,250' to 11,650' using beaded sweeps.
Perform long wiper to window. Jet 4 1/2" tubing. Tie into K1 for +2.5' correction. RBIH. 4'
from bottom well started taking fluid. Holding 11.4# at the window. Returns dropped to 0.3 -
0.5 BPM. Discuss with Town. Closed choke and drill ahead on 100% losses toward TD.
Drilled to midnight depth of 12,066'.
11/13/2022 DRILLING
SIDETRACK
Drilled to 12,260' when BHA packed off. POOH. PUD BHA #7. Found Strider ERT tool
locked up. PD and RIH with BHA #8 - motor, NOV agitator, re-run bit. Tie into K-1 for -14'
correction. Cont. RIH to set down at 12,233'. Washed down to 12,240'. See sticky PU's and
signs of pack-off, potential D-shale. Perform swab wiper from 12,240'. At surface @
midnight.
KRU 3B-13 CTD Summary of Operations
11/14/2022 DRILLING
SIDETRACK
RBIH. Tie into K-1 for a -13' correction. Gather BHP at 7,560'. Confirm KWF of 11.4#. Cont.
RIH to TD. Set down @ 12,263'. Circulate 11.4# LRP to bit. POOH laying in LRP. Lay down
BHA #8. PU L1 lower liner section (40 joints slotted). RIH and set lower liner section @
12,263'. TOL section @ 10,993'. Lay in LRP. POOH. Lay bown BHA #9. At midnight, PU
L1 interm. liner section (47 joints).
11/15/2022 DRILLING
SIDETRACK RIH with L1 interm. liner section. (47 joints slotted). Tie into window flag for -2.5' correction.
Cont. RIH and set down at 10,993'. Confirm latched and release from liner. Lay in LRP.
POOH. LD BHA #10. MU BHA #11 - upper liner section. RIH set on depth, pooh freeze
protect F/2500', undeploy bha, flush stack and blow down lines, start rdmo
11/18/2022 MAINTAIN WELL PT FL WITH 10 BBLS DSL
( JOB COMPLETE)
11/20/2022 SUPPORT OTHER
OPERATIONS
TAG LINER TOP W/ MAG STEM & 2.68" MAGNET @ 7497' RKB; MEASURED BHP (2603
PSI) @ 7497' RKB; DISPLACE TBG W/ 65 BBLS OF DIESEL WHILE BRUSH n' FLUSHING
TBG ALONG WITH INSIDE OF LINER TOP;
SET 3.5" NORTHERN SOLUTIONS LINER TOP PACKER (SN: NS9027) W/ 1.78" R PLUG &
SEAL GUIDE @ 7491' RKB; OBTAIN GOOD TBG TEST & PULLED 1.78" R PLUG & SEAL
GUIDE @ 7599' RKB. JOB COMPLETE.
MU BHA #11 - upper liner section. RIH set on depth
SET 3.5" NORTHERN SOLUTIONS LINER TOP PACKER (SN: NS9027) W/ 1.78" R PLUG & ()
SEAL GUIDE @ 7491' RKB; OBTAIN GOOD TBG TEST & PULLED 1.78" R PLUG & SEAL
GUIDE
RIH with L1 interm. liner section. (47 joints slotted). Tie into window flag for -2.5' correction. (j ) g
Cont. RIH and set down at 10,993'. Confirm latched and release from liner.
Set down @ 12,263'. @ygy
PU L1 lower liner section (40 joints slotted). RIH and set lower liner section @
@
12,263'. TOL section @ 10,993'.
3B-13 CTD Schematic
Completion
3-1/2" 9.3# L-80 EUE 8rd MOD Tubing to surface
3-1/2" Camco MMG gas lift mandrels @ 3132, 4922, 7224'
SLB BluePack Packer @ 7261' MD (4" ID)
3-1/2" X nipple @ 7379' MD (2.813" min ID)
4-1/2" Maxwell Joints
3-1/2" X nipple @ 7643' MD (2.813" min ID)
Cement Retainer @ 7,640'
7" CIBP @ ~7675' MD
7" 26# J-55 shoe @
8023' MD
A-sand perfs
7714' - 7808' MD
9-5/8" 36# J-55 shoe
@ 3658' MD
16" 62# H-40
shoe @ 117' MD
C1-sand perfs
7548'-7601' MD
KOP @ 7580' MD
3B-13L1
TD 12,263' MD
Modified by AK 12/08/22
2 3/8" Liner set at 12,263'
Slotted liner from 8,009'-12,263'
Swell Packer at 7,996'
Blank pipe from 7501,-7,996'
SBR at 1,497'
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag RKB (Est. 66' of Rathole) 7,874.0 3B-13 8/26/2020 zembaej
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Set Northern Solutions Liner Top Packer 3B-13 11/19/2022 zembaej
Notes: General & Safety
Annotation End Date Last Mod By
NOTE: Cut off TBG @ 7366'@ middle of full joint above SBR 10/30/1996 WV5.3
Conversio
n
General Notes: Last 3 entries
Com Date Last Mod By
Note: 10/12/22 recompleted tubing tail set at 7650' 10/12/2022 NSKRWOCM
Ball and rod on seat in RHC plug inside X nipple @ 7644' 10/12/2022 nskrwocm
Tubing FP with diesel to 2000'. 8.5# CI seawater from 2000' to 7655' 10/12/2022 NSKRWOCM
Casing Strings
Csg Des OD (in) ID (in) Top (ftKB)
Set Depth
(ftKB)
Set Depth
(TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread
CONDUCTOR 16 15.06 33.0 117.0 117.0 62.50 H-40 WELDED
SURFACE 9 5/8 8.92 30.2 3,657.6 3,210.4 36.00 J-55 BTC
PRODUCTION 7 6.28 23.6 8,022.7 6,289.0 26.00 J-55 BTC
Tubing Strings: string max indicates LONGEST segment of string
Top (ftKB)
23.7
Set Depth …
7,655.0
Set Depth …
5,998.0
String Ma…
3 1/2
Tubing Description
Tubing – Production
Wt (lb/ft)
9.30
Grade
L-80
Top Connection
EUE-M
ID (in)
2.99
Completion Details: excludes tubing, pup, space out, thread, RKB...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal
ID (in)
23.7 23.7 0.08 Hanger 7.063 FMC GEN III Tubing Hanger FMC 2.960
3,132.2 2,829.3 44.27 Mandrel – GAS
LIFT
5.970 3.5" x 1.5" Camco MMG GLM SLB MMG 2.920
4,921.6 4,076.2 47.73 Mandrel – GAS
LIFT
5.970 3.5" x 1.5" Camco MMG GLM SLB MMG 2.920
7,223.8 5,664.0 42.68 Mandrel – GAS
LIFT
5.970 3.5" x 1.5" Camco MMG GLM SLB MMG 2.920
7,260.9 5,691.4 41.91 Packer 6.280 SLB 3.5" x 7" BluePack Packer, SN#
C21P-1855
SLB BluePac
k RH
2.894
7,378.7 5,780.8 39.59 2.81" X nipple 4.500 3.5" x 2.813" L-80, 8rd EUE, X-
Nipple SN# 4180362-18
Halliburt
on
X Nipple 2.813
7,512.7 5,885.7 37.49 XO - Enlarging 3.500 3.5" 9.3# L-80 8rd EUE x 4.5" HYD
563, XO
2.992
7,516.7 5,888.9 37.51 Centralizer 4.500 4.5" TBG w/Maxwell Centralizers Maxwell 3.958
7,600.7 5,955.3 38.08 XO - Reducing 4.500 4.5" 563" x 3.5" 9.3# L-80 8rd EUE,
XO
2.992
7,643.9 5,989.3 38.14 2.81" X-nipple 4.500 3.5" x 2.813" , X-Nipple/RHC Plug
SN# 4180362-17
Halliburt
on
X Nipple 2.813
7,653.0 5,996.5 38.15 Wireline Guide 3.500 3-1/2" EUE 8rd Mule shoe 2' Pup cut
at 30*
2.960
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top (ftKB)
Top (TVD)
(ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in)
7,491.0 5,868.5 37.56 PACKER 2.72" Norther Solutions Liner
Top Packer w/ 1.78" R-Nipple
(10.9' OAL)
Northern
Solutions
Mono-
Pak LTP
NSP0
27
11/19/2022 1.780
7,584.0 5,942.2 37.97 WHIPSTOCK 11/6/2022 0.000
7,640.0 5,986.2 38.14 CEMENT
RETAINER
QUADCO 2.75" SVCR
CEMENT RETAINER
QUADC
O
SVCR 10/29/2022 0.000
7,675.0 6,013.8 38.19 CIBP PRESSURE TEST FAILED.
PLUG NOT ISOLATING A-
SANDS
Baker ACT 10/10/2022 0.000
7,742.0 6,066.4 38.18 FISH 3" JDC Dog Retainer Lost in
hole
7/14/1991
7,874.0 6,170.5 37.42 FISH 3 PIECES OF HEX PLUG
SLIP ENDS (.25X.25X.50")
8/26/2020 0.000
Mandrel Inserts : excludes pulled inserts
Top (ftKB)
Top (TVD)
(ftKB)
Top
Incl (°)
St
ati
on
No
/S Serv
Valve
Type
Latch
Type
OD
(in)
TRO Run
(psi) Run Date Com Make Model
Port
Size (in)
3,132.2 2,829.3 44.27 1 GLV RK 1 1/2 1,257.0 10/19/2022 Schlumb
erger
MMG 0.188
4,921.6 4,076.2 47.73 2 OV RK 1 1/2 0.0 10/19/2022 Schlumb
erger
MMG 0.250
7,223.8 5,664.0 42.68 3 DMY RK 1 1/2 0.0 10/19/2022 Schlumb
erger
MMG 0.000
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
7,548.0 7,601.0 5,913.7 5,955.6 C-4, C-3, C-1,
UNIT B, 3B-13
5/13/1985 12.0 IPERF 120 deg. phasing, 5"
Scalloped Csg Gun
7,714.0 7,762.0 6,044.4 6,082.1 A-4, A-3, 3B-13 5/13/1985 4.0 IPERF 120 deg. phasing, 4" Carrier
JJ II Csg
7,780.0 7,808.0 6,096.3 6,118.3 A-2, 3B-13 5/13/1985 4.0 IPERF 120 deg. phasing, 4" Carrier
JJ II Csg
SLANT, 3B-13, 12/6/2022 4:04:16 PM
Vertical schematic (actual)
PRODUCTION; 23.6-8,022.7
FISH; 7,874.0
IPERF; 7,780.0-7,808.0
FISH; 7,742.0
IPERF; 7,714.0-7,762.0
CIBP; 7,675.0
2.81" X-nipple; 7,643.9
CEMENT RETAINER; 7,640.0
WHIPSTOCK; 7,584.0
IPERF; 7,548.0-7,601.0
PACKER; 7,491.0
2.81" X nipple; 7,378.7
Packer; 7,260.9
Mandrel – GAS LIFT; 7,223.8
Mandrel – GAS LIFT; 4,921.5
SURFACE; 30.2-3,657.6
Mandrel – GAS LIFT; 3,132.2
CONDUCTOR; 33.0-117.0
Hanger; 23.7
KUP PROD
KB-Grd (ft)
36.51
RR Date
3/11/1985
Other Elev…
3B-13
...
TD
Act Btm (ftKB)
8,040.0
Well Attributes
Field Name
KUPARUK RIVER UNIT
Wellbore API/UWI
500292128600
Wellbore Status
PROD
Max Angle & MD
Incl (°)
47.90
MD (ftKB)
5,400.00
WELLNAME WELLBORE3B-13
Annotation
Last WO:
End Date
11/1/2006
H2S (ppm)
150
Date
11/25/2016
Comment
SSSV: NIPPLE
General Notes: Last 3 entries
Com Date Last Mod By
Note: 10/12/22 recompleted tubing tail set at 7650' 10/12/2022 NSKRWOCM
Ball and rod on seat in RHC plug inside X nipple @ 7644' 10/12/2022 nskrwocm
Tubing FP with diesel to 2000'. 8.5# CI seawater from 2000' to 7655' 10/12/2022 NSKRWOCM
Casing Strings
Csg Des OD (in) ID (in) Top (ftKB)
Set Depth
(ftKB)
Set Depth
(TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread
Slotted Liner 2 3/8 1.99 7,497.3 12,263.0 4.60 L-80 STL
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top (ftKB)
Top (TVD)
(ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in)
7,584.0 5,942.1 38.74 WHIPSTOCK 11/6/2022 0.000
Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal ID
(in)
7,995.7 5,962.4 100.0
9
Swell Packer 2.700 NSAK 350-238 OH Permanent
QCLL
Halliburto
n
Swell Pkr. 1.686
9,504.1 5,920.2 90.38 Deployment
Sleeve
2.375 NSAK 350-238 OH Permanent
QCLL
Northern
Solutions
1.920
10,993.0 5,892.2 92.11 Deployment
Sleeve
2.375 Northern
Solutions
1.920
SLANT, 3B-13L1, 12/6/2022 4:04:17 PM
Vertical schematic (actual)
Slotted Liner; 7,497.3-12,263.0
WHIPSTOCK; 7,584.0
PRODUCTION; 23.6-8,022.7
PACKER; 7,491.0
2.81" X nipple; 7,378.7
Packer; 7,260.9
Mandrel – GAS LIFT; 7,223.8
Mandrel – GAS LIFT; 4,921.5
SURFACE; 30.2-3,657.6
Mandrel – GAS LIFT; 3,132.2
CONDUCTOR; 33.0-117.0
KUP PROD
KB-Grd (ft)
36.51
RR Date
3/11/1985
Other Elev…
3B-13L1
...
TD
Act Btm (ftKB)
12,263.0
Well Attributes
Field Name
KUPARUK RIVER UNIT
Wellbore API/UWI
500292128660
Wellbore Status
PROD
Max Angle & MD
Incl (°)
100.85
MD (ftKB)
7,891.08
WELLNAME WELLBORE3B-13
Annotation End DateH2S (ppm)
150
Date
11/25/2016
Comment
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3$'&8 /&$$ '%& %3$/8&6 ,3$8&/ 3 8&$%3$ &6 %3/$3' &6 % 83 '&% $& $3 '&6, !.2. ;()
3$/&8 /&%% '$&$ %3$/6&/ ,3$$,&$ 3 6/& %3$'/&/ %3/$3,,&6 % 83 $& 6& $3 6,& 8 !.2. ;()
3$%/&6 /6&, & 6 %3$/& ,3/ &% 3 86&%3$'$& %3/$3% &, % 83 '& &8 $3 ,8&6% !.2. ;()
3$/&/ /6&, &8 %3$/'&6 ,3/6 &/ 3 $ &,%3$'%&6 %3/$3& % 83'$%&$ &$ $3'/& !.2. ;()
3/&6 /%&8 '$&$ %3$$,&$ ,3/8$& 3 /8&$%3$'&$ %3/$3 /8&/ % 83','&$ /&8 $3/&'6 !.2. ;()
3/6/&8 /8&' '8& %3$$%& ,3// &6 3'$&$%3$''& %3/$3 ,&, % 83'%$&$ $& $386&/% !.2. ;()
3/,/& /8&6' '6&,8 %3$$&' $3' $& 3 &%%3,/,&' %3/$3 6,& % 83'68& %&6 $3/6& !.2. ;()
3' & /8&, //&%' %3$,$&6 $3'6,&6 3&%%3,/&6 %3/$3 ,&, % 83'6& 8&6 $38&'' !.2. ;()
3'/&$ /,& $ //& , %3$,%&' $3',6& 36&/%3,/'&' %3/$3'/'&/ % 83'%&' & $3%6&, !.2. ;()
3','&8 //&, //& ' %3$,'&8 $3 '&' 3%&/%3,$%&8 %3/$3'8&' % 83' %&' 8&$ $3$6&$$ !.2. ;()
3'//& //&6' '&6 %3$88&' $3 /& 38& %3,$ &' %3/$3'%&, % 83''6&/ %&' $36 &'$ !.2. ;()
3 6& //&,% '6&$ %3$8'& $3 8'&$ 3,,&%3,,%& %3/$3''6& % %3//'&/ 6&' $366,&6$ !.2. ;()
3 %/& //&% '$&88 %3$%8&' $3 $&/ 3$$&%3,, &' %3/$3/$&' % %3/,/&$ %& $36,&'$ !.2. ;()
3 $/& //&8 '&, %3$% &' $3'$&8 3'&'%3,88&' %3/$3/%8& % %3/8%& 8&$ $3%' & !.2. ;()
3 /&6 //&', &6 %3$68& $3&/ 3 $&%%3,8 & %3/$3/ &' % %3/6/&, %&/ $3%'&' !.2. ;()
38&' //&', &6 %3$/& $3,'& 36 &8%3,%6& %3/$3$/6&8 % %3/8&, '&' $3%,&8 !.2. ;()
( *
From:Taylor, Jenna
To:Brooks, James S (OGC)
Cc:Aleshire, Lynn
Subject:RE: [EXTERNAL]FW: KRU 3B-13 10-404 Whipstock & KRU 3B-13L1 10-407
Date:Wednesday, January 11, 2023 8:41:49 AM
Attachments:image001.png
James – Just spoke with our production engineer, Lynn. Who is cc’d on this email.
When we do the daily rate, it is corrected not just a straight calculation. The corrections, simply put, convert reservoir values to stock tank values. So, gas liberation, compressibility, etc. are accounted for in the final well test rate. So, I
don’t know how to account for that. For water, the issue is compressibility. We can just do a straight calculation of the well, but that’s not how we account for it in our allocation process.
If you still have questions, we can set up a quick call to discuss.
Jenna
From: Brooks, James S (OGC) <james.brooks@alaska.gov>
Sent: Wednesday, January 11, 2023 8:16 AM
To: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com>
Subject: RE: [EXTERNAL]FW: KRU 3B-13 10-404 Whipstock & KRU 3B-13L1 10-407
The water value 4473 is flagging.
thanx
-$0(6%522.6
5(6($5&+$1$/<67,,E$/$6.$2,/$1'*$6&216(59$7,21&200,66,21
'(3$570(172)&200(5&(&20081,7<$1'(&2120,&'(9(/230(17
E-$0(6%522.6#$/$6.$*29
From: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com>
Sent: Tuesday, January 10, 2023 11:01 AM
To: Brooks, James S (OGC) <james.brooks@alaska.gov>
Subject: RE: [EXTERNAL]FW: KRU 3B-13 10-404 Whipstock & KRU 3B-13L1 10-407
James –
See attached production test data. Does this continue to flag your system if you enter these values?
From: Brooks, James S (OGC) <james.brooks@alaska.gov>
Sent: Monday, January 9, 2023 10:41 AM
To: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com>
Subject: FW: [EXTERNAL]FW: KRU 3B-13 10-404 Whipstock & KRU 3B-13L1 10-407
Hi,
I am following up on this issue:
The reported water value under 24 hr rate of 4473 is still being flagged.
Can you look into this ?
thanx
-$0(6%522.6
5(6($5&+$1$/<67,,E$/$6.$2,/$1'*$6&216(59$7,21&200,66,21
'(3$570(172)&200(5&(&20081,7<$1'(&2120,&'(9(/230(17
E-$0(6%522.6#$/$6.$*29
From: Brooks, James S (OGC)
Sent: Friday, December 16, 2022 3:59 PM
To: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com>
Subject: RE: [EXTERNAL]FW: KRU 3B-13 10-404 Whipstock & KRU 3B-13L1 10-407
This is still off.
thanx
-$0(6%522.6
5(6($5&+$1$/<67,,E$/$6.$2,/$1'*$6&216(59$7,21&200,66,21
'(3$570(172)&200(5&(&20081,7<$1'(&2120,&'(9(/230(17
E-$0(6%522.6#$/$6.$*29
From: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com>
Sent: Friday, December 16, 2022 3:00 PM
To: Brooks, James S (OGC) <james.brooks@alaska.gov>
Subject: RE: [EXTERNAL]FW: KRU 3B-13 10-404 Whipstock & KRU 3B-13L1 10-407
James – Looks like the highlighted number should be 3331bpd not 331.
Jenna
From: Brooks, James S (OGC) <james.brooks@alaska.gov>
Sent: Friday, December 16, 2022 10:02 AM
To: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com>
Subject: [EXTERNAL]FW: KRU 3B-13 10-404 Whipstock & KRU 3B-13L1 10-407
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.
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.
Hi,
Concerning KRU 3B-13L1:
Box 27:
Water = 331
Water (24-hour rate) = 4473
Is being flagged.
Can you look into this ?
thanx
-$0(6%522.6
5(6($5&+$1$/<67,,E$/$6.$2,/$1'*$6&216(59$7,21&200,66,21
'(3$570(172)&200(5&(&20081,7<$1'(&2120,&'(9(/230(17
E-$0(6%522.6#$/$6.$*29
From: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov>
Sent: Thursday, December 15, 2022 8:22 AM
To: Brooks, James S (OGC) <james.brooks@alaska.gov>
Subject: FW: KRU 3B-13 10-404 Whipstock & KRU 3B-13L1 10-407
Good morning James,
I’m just forwarding you the 407.
Thanks!
Anne Prysunka
Executive Secretary| AOGCC
Alaska Oil and Gas Conservation Commission
Direct: (907) 793-1230
From: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com>
Sent: Wednesday, December 14, 2022 4:44 PM
To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov>
Cc: Klem, Adam <Adam.Klem@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Conklin, Amy A <Amy.A.Conklin@conocophillips.com>
Subject: KRU 3B-13 10-404 Whipstock & KRU 3B-13L1 10-407
See attached permits for KRU 3B-13 10-404 & KRU 3B-13L1 10-407. Please let me know if you need additional information.
Jenna
From:Aleshire, Lynn
To:Brooks, James S (OGC)
Subject:RE: [EXTERNAL]FW: KRU 3B-13 10-404 Whipstock & KRU 3B-13L1 10-407
Date:Friday, January 13, 2023 1:50:29 PM
Attachments:image002.png
image003.png
Hi Jenna,
Here’s the straight calcs they want:
From: Brooks, James S (OGC) <james.brooks@alaska.gov>
Sent: Wednesday, January 11, 2023 10:40 AM
To: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com>
Cc: Aleshire, Lynn <Lynn.Aleshire@conocophillips.com>; Roby, David S (OGC) <dave.roby@alaska.gov>
Subject: RE: [EXTERNAL]FW: KRU 3B-13 10-404 Whipstock & KRU 3B-13L1 10-407
Hi,
This is our Senior Petroleum Engineer’s response after looking at the number:
The calculated 24 hour rate is 4,572 Bbls, or about 2.2% higher than what’s being reported.
The well testing info reported on the 407 should just be whatever the test results show for however many hours the test occurred then converting those numbers to a 24 hour rate.
Thanks,
-$0(6%522.6
5(6($5&+$1$/<67,,E$/$6.$2,/$1'*$6&216(59$7,21&200,66,21
'(3$570(172)&200(5&(&20081,7<$1'(&2120,&'(9(/230(17
E-$0(6%522.6#$/$6.$*29
From: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com>
Sent: Wednesday, January 11, 2023 8:42 AM
To: Brooks, James S (OGC) <james.brooks@alaska.gov>
Cc: Aleshire, Lynn <Lynn.Aleshire@conocophillips.com>
Subject: RE: [EXTERNAL]FW: KRU 3B-13 10-404 Whipstock & KRU 3B-13L1 10-407
James – Just spoke with our production engineer, Lynn. Who is cc’d on this email.
When we do the daily rate, it is corrected not just a straight calculation. The corrections, simply put, convert reservoir values to stock tank values. So, gas liberation, compressibility, etc. are accounted for in the final well test rate. So, I
don’t know how to account for that. For water, the issue is compressibility. We can just do a straight calculation of the well, but that’s not how we account for it in our allocation process.
If you still have questions, we can set up a quick call to discuss.
Jenna
From: Brooks, James S (OGC) <james.brooks@alaska.gov>
Sent: Wednesday, January 11, 2023 8:16 AM
To: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com>
Subject: RE: [EXTERNAL]FW: KRU 3B-13 10-404 Whipstock & KRU 3B-13L1 10-407
The water value 4473 is flagging.
thanx
-$0(6%522.6
5(6($5&+$1$/<67,,E$/$6.$2,/$1'*$6&216(59$7,21&200,66,21
'(3$570(172)&200(5&(&20081,7<$1'(&2120,&'(9(/230(17
E-$0(6%522.6#$/$6.$*29
From: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com>
Sent: Tuesday, January 10, 2023 11:01 AM
To: Brooks, James S (OGC) <james.brooks@alaska.gov>
Subject: RE: [EXTERNAL]FW: KRU 3B-13 10-404 Whipstock & KRU 3B-13L1 10-407
James –
See attached production test data. Does this continue to flag your system if you enter these values?
From: Brooks, James S (OGC) <james.brooks@alaska.gov>
Sent: Monday, January 9, 2023 10:41 AM
To: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com>
Subject: FW: [EXTERNAL]FW: KRU 3B-13 10-404 Whipstock & KRU 3B-13L1 10-407
Hi,
I am following up on this issue:
The reported water value under 24 hr rate of 4473 is still being flagged.
Can you look into this ?
thanx
-$0(6%522.6
5(6($5&+$1$/<67,,E$/$6.$2,/$1'*$6&216(59$7,21&200,66,21
'(3$570(172)&200(5&(&20081,7<$1'(&2120,&'(9(/230(17
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.
E-$0(6%522.6#$/$6.$*29
From: Brooks, James S (OGC)
Sent: Friday, December 16, 2022 3:59 PM
To: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com>
Subject: RE: [EXTERNAL]FW: KRU 3B-13 10-404 Whipstock & KRU 3B-13L1 10-407
This is still off.
thanx
-$0(6%522.6
5(6($5&+$1$/<67,,E$/$6.$2,/$1'*$6&216(59$7,21&200,66,21
'(3$570(172)&200(5&(&20081,7<$1'(&2120,&'(9(/230(17
E-$0(6%522.6#$/$6.$*29
From: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com>
Sent: Friday, December 16, 2022 3:00 PM
To: Brooks, James S (OGC) <james.brooks@alaska.gov>
Subject: RE: [EXTERNAL]FW: KRU 3B-13 10-404 Whipstock & KRU 3B-13L1 10-407
James – Looks like the highlighted number should be 3331bpd not 331.
Jenna
From: Brooks, James S (OGC) <james.brooks@alaska.gov>
Sent: Friday, December 16, 2022 10:02 AM
To: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com>
Subject: [EXTERNAL]FW: KRU 3B-13 10-404 Whipstock & KRU 3B-13L1 10-407
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.
Hi,
Concerning KRU 3B-13L1:
Box 27:
Water = 331
Water (24-hour rate) = 4473
Is being flagged.
Can you look into this ?
thanx
-$0(6%522.6
5(6($5&+$1$/<67,,E$/$6.$2,/$1'*$6&216(59$7,21&200,66,21
'(3$570(172)&200(5&(&20081,7<$1'(&2120,&'(9(/230(17
E-$0(6%522.6#$/$6.$*29
From: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov>
Sent: Thursday, December 15, 2022 8:22 AM
To: Brooks, James S (OGC) <james.brooks@alaska.gov>
Subject: FW: KRU 3B-13 10-404 Whipstock & KRU 3B-13L1 10-407
Good morning James,
I’m just forwarding you the 407.
Thanks!
Anne Prysunka
Executive Secretary| AOGCC
Alaska Oil and Gas Conservation Commission
Direct: (907) 793-1230
From: Taylor, Jenna <Jenna.L.Taylor@conocophillips.com>
Sent: Wednesday, December 14, 2022 4:44 PM
To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov>
Cc: Klem, Adam <Adam.Klem@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Conklin, Amy A <Amy.A.Conklin@conocophillips.com>
Subject: KRU 3B-13 10-404 Whipstock & KRU 3B-13L1 10-407
See attached permits for KRU 3B-13 10-404 & KRU 3B-13L1 10-407. Please let me know if you need additional information.
Jenna
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
BOPE Test Report for:
Reviewed By:
P.I. Suprv
Comm ________KUPARUK RIV UNIT 3B-13L1
JBR 12/21/2022
MISC. INSPECTIONS:
FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK:
ACCUMULATOR SYSTEM:MUD SYSTEM:
P/F P/F
P/FP/FP/F
Visual Alarm
QuantityQuantity
Time/Pressure
SizeQuantity
Number of Failures:2
R3 and B5 both failed, grease and both passed retest, Test all gas alarms and PVT's, Precharge bottles = 8each 4@1050psi
and 4@1100psi.
Test Results
TEST DATA
Rig Rep:C. Coyne / R. BeardOperator:ConocoPhillips Alaska, Inc.Operator Rep:J. Newell / L. Imm
Rig Owner/Rig No.:Nabors CDR3AC PTD#:2221260 DATE:11/4/2022
Type Operation:DRILL Annular:
250/2500Type Test:INIT
Valves:
250/3500
Rams:
250/3500
Test Pressures:Inspection No:bopBDB221106095657
Inspector Brian Bixby
Inspector
Insp Source
Related Insp No:
INSIDE REEL VALVES:
Quantity P/F
(Valid for Coil Rigs Only)
Remarks:
Test Time 7.5
MASP:
2896
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 0 NA
Lower Kelly 0 NA
Ball Type 2 P
Inside BOP 0 NA
FSV Misc 0 NA
12 PNo. Valves
1 PManual Chokes
1 PHydraulic Chokes
0 NACH Misc
Stripper 1 2"P
Annular Preventer 1 7 1/16"P
#1 Rams 1 Blind/Shear P
#2 Rams 1 2" Combi P
#3 Rams 1 2 3/8"P
#4 Rams 1 2" Combi P
#5 Rams 0 NA
#6 Rams 0 NA
Choke Ln. Valves 1 2 1/16"P
HCR Valves 2 2 1/16"FP
Kill Line Valves 5 2 1/16"FP
Check Valve 0 NA
BOP Misc 3 3 1/8"P
System Pressure P2975
Pressure After Closure P2350
200 PSI Attained P24
Full Pressure Attained P58
Blind Switch Covers:PYES
Bottle precharge P
Nitgn Btls# &psi (avg)P4@1700
ACC Misc NA0
NA NATrip Tank
P PPit Level Indicators
P PFlow Indicator
P PMeth Gas Detector
P PH2S Gas Detector
0 NAMS Misc
Inside Reel Valves 1 P
Annular Preventer P12
#1 Rams P3
#2 Rams P4
#3 Rams P4
#4 Rams P3
#5 Rams NA0
#6 Rams NA0
HCR Choke P1
HCR Kill P1
R3 and B5 both failed, grease and both passed retest, Test all gas alarms and PVT's, Precharge bottles = 8each 4@1050psi
FP
FP
Alaska Oil and Gas
Conservation Commission
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
Adam Klem
Senior RWO/CTD Engineer
ConocoPhillips Alaska Inc.
P.O. Box 100360
Anchorage, Alaska 99510
Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3B-13L1
ConocoPhillips Alaska, Inc.
Permit to Drill Number: 222-126
Surface Location: 49’ FSL, 786’ FEL, Sec. 16, T12N, R9E, UM
Bottomhole Location: 2293’ FSL, 2113’ FEL, Sec. 28, T12N, R9E, UM
Dear Mr.Klem:
Enclosed is the approved application for the permit to drill the above referenced well.
The permit is for a new wellbore segment of existing well Permit Number 185-023. API Number 50-
029-21286-00-00. Production from or injection into this wellbore must be reported under the original
API Number stated above.
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,
Jessie L. Chmielowski
Commissioner
DATED this ___ day of October 2022. 21
Jessie L.
Chmielowski
Digitally signed by Jessie L.
Chmielowski
Date: 2022.10.21 21:21:12
-08'00'
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By Anne Prysunka at 1:07 pm, Oct 06, 2022
Adam Klem Digitally signed by Adam Klem
Date: 2022.10.06 08:17:45 -08'00'
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Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski
Date: 2022.10.21 21:21:32 -08'00'
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WELL PERMIT CHECKLISTCompanyConocoPhillips Alaska, Inc.Well Name:KUPARUK RIV UNIT 3B-13L1Initial Class/TypeDEV / PENDGeoArea890Unit11160On/Off ShoreOnProgramDEVField & PoolWell bore segAnnular DisposalPTD#:2221260KUPARUK RIVER, KUPARUK RIV OIL - 490100NA1Permit fee attachedYesSurface Location lies within ADL0025633; Top Prod Int & TD lie within ADL0025642.2Lease number appropriateYes3Unique well name and numberYesKuparuk River Oil Pool, governed by Conservation Order No. 432E4Well located in a defined poolYes5Well located proper distance from drilling unit boundaryYes6Well located proper distance from other wellsYes7Sufficient acreage available in drilling unitYes8If deviated, is wellbore plat includedYes9Operator only affected partyYes10Operator has appropriate bond in forceYes11Permit can be issued without conservation orderYes12Permit can be issued without administrative approvalYes13Can permit be approved before 15-day waitNA14Well located within area and strata authorized by Injection Order # (put IO# in comments) (ForNA15All 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)NA18Conductor string providedNA19Surface casing protects all known USDWsNA20CMT vol adequate to circulate on conductor & surf csgNo21CMT vol adequate to tie-in long string to surf csgNoslotted liner22CMT 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 proposedNA27If diverter required, does it meet regulationsYesMax formation pressure is 3246 psi(10.6 ppg EMW); will drill w/ 8.6 ppg EMW and maintain overbal w/ MPD28Drilling fluid program schematic & equip list adequateYes29BOPEs, do they meet regulationYesMPSP is 2657 psig; will test BOPs to 3500 spig30BOPE 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 probableNA34Mechanical condition of wells within AOR verified (For service well only)NoH2S measures required: 136 ppm H2S reported for parent well KRU 3B-13 on 12/25/21.35Permit can be issued w/o hydrogen sulfide measuresYesParent well measured 8.1 ppg EMW on 7/16/22; maximum pressure in vicinity measured 11.46 ppg EMW due to n36Data presented on potential overpressure zonesNAgas injection. Some potential to encounter free gas. Faults may be crossed. MPD technique will37Seismic analysis of shallow gas zonesNAbe used with 8.6 ppg mud to manage pressures encountered and maintain wellbore stability.38Seabed condition survey (if off-shore)NA39Contact name/phone for weekly progress reports [exploratory only]ApprSFDDate10/7/2022ApprVTLDate10/10/2022ApprSFDDate10/7/2022AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDateJLC 10/21/2022
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