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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
16-1/2" H-40 110'
9-5/8" J-55 3118'
7" J-55 6244'
2-3/8" L-80 5874'
24. Open to production or injection? Yes No 25.
26.
Was hydraulic fracturing used during completion? Yes No
DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED
27.
Date First Production: Method of Operation (Flowing, gas lift, etc.):
Hours Tested: Production for Gas-MCF:
Test Period
Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr):
Press. 24-Hour Rate
Sr Res EngSr Pet GeoSr Pet Eng
N/A
Oil-Bbl: Water-Bbl:
Water-Bbl:
PRODUCTION TEST
N/A
Date of Test: Oil-Bbl:
Flow Tubing
INJECTION
Slotted Liner: 6450-12000' MD and 5894-5874' TVD
Gas-Oil Ratio:Choke Size:
Per 20 AAC 25.283 (i)(2) attach electronic information
26#
12000'
29'
5894'
65.5#
36#
110'
29' 6890'
SIZE DEPTH SET (MD)
6225' MD/ 5712' TVD
PACKER SET (MD/TVD)
24"
12-1/4"
248 sx CS II
30'780 sx AS III, 410 sx Class G
4.6#
31'
6450'
3119'30'
31'
CASING WT. PER
FT.GRADE
11/25/2022
CEMENTING RECORD
5979840
1640' MD/ 1640' TVD
SETTING DEPTH TVD
5984747
TOP HOLE SIZE AMOUNT
PULLED
520551
522079
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.
6457' MD/ 5899' TVD
Kuparuk River Field/ Kuparuk River Oil Pool
BOTTOM
9. Ref Elevations: KB: 95'
50-029-21279-60-00
KRU 2W-02L1
ADL 25642
1279' FNL, 202' FEL, Sec. 33, T12N, R9E, UM
1104' FNL, 2265' FEL, Sec. 27, T12N, R9E, UM
ALK 2573
11/18/2022
12000 MD/ 5874' TVD
N/A
P.O. Box 100360, Anchorage, AK 99510-0360
518887 5979283
727' FNL, 1465' FWL, Sec. 34, T12N, R9E, UM
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
ConocoPhillips Alaska, Inc.
WAG
Gas
11/27/2022 222-131
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
280 sx Class G8-1/2"
6537'3-1/2"
Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment
By James Brooks at 10:39 am, Dec 27, 2022
Completed
11/27/2022
JSB
RBDMS JSB 010523
GDSR-1/9/23
WINJ
222-131
Service
Kuparuk River Field/ Kuparuk River Oil Pool
KRU 2W-02L1
WCB - 2023-07-14
Conventional Core(s): Yes No Sidewall Cores:
N/A
30.
MD TVD
Surface Surface
1640' 1640'
Top of Productive Interval
6412' 5862'
N/A
Kuparuk C4 12000' 5874'
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: Dusty Ward
Digital Signature with Date:Contact Email: dusty.ward@conocophillips.com
Contact Phone:(907) 265-6531
Senior RWO/CTD 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 C4
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:
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
Page 1/9
2W-02
Report Printed: 12/20/2022
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)
11/16/2022
00:00
11/16/2022
06:00
6.00 MIRU, MOVE RURD P Continue with rig down checklists // prep
for rig transport to 2W-02 // Trucks on
location
0.0 0.0
11/16/2022
06:00
11/16/2022
06:30
0.50 MIRU, MOVE MOB P Cruz pick up shop and halfway house
for tranport
0.0 0.0
11/16/2022
06:30
11/16/2022
07:00
0.50 MIRU, MOVE SFTY P Pre-job meeting with Cruz for pulling off
well and moving to 2W pad
0.0 0.0
11/16/2022
07:00
11/16/2022
07:15
0.25 MIRU, MOVE MOB P Jack service module , sow up , pull mats 0.0 0.0
11/16/2022
07:15
11/16/2022
07:30
0.25 MIRU, MOVE MOB P Pull service module from well row and
spot on pad
0.0 0.0
11/16/2022
07:30
11/16/2022
07:45
0.25 MIRU, MOVE MOB P Jack sub module , sow up scarf area
around sow and turn arc for additional
tracktion pull mats
0.0 0.0
11/16/2022
07:45
11/16/2022
08:00
0.25 MIRU, MOVE MOB P Pull sub off well and spot on pad for
jeep up
0.0 0.0
11/16/2022
08:00
11/16/2022
08:30
0.50 MIRU, MOVE MOB P Drop pull sows , jeep up both modules
sow up , perform final walk arounds
verify final safe out
0.0 0.0
11/16/2022
08:30
11/16/2022
13:42
5.20 MIRU, MOVE MOB P Mob rig 09:30 CPF3 // 11:30 Oliktok Y //
13:20 CPF2 // Park CPF2 pad till 13:42
for fuel of sows
0.0 0.0
11/16/2022
13:42
11/16/2022
15:45
2.05 MIRU, MOVE MOB P Mob from CPF2 to 2W pad 0.0 0.0
11/16/2022
15:45
11/16/2022
16:00
0.25 MIRU, MOVE MOB P Stage on pad, remove jeeps prep for
spotting on well
0.0 0.0
11/16/2022
16:00
11/16/2022
17:45
1.75 MIRU, MOVE RURD P Drop jeep from sub, prep well , mat and
herulite , spot sub over well // spot mats
under rig
0.0 0.0
11/16/2022
17:45
11/16/2022
19:00
1.25 MIRU, MOVE RURD P Spot mats for pits // spot pits in place //
finish installing mats //
0.0 0.0
11/16/2022
19:00
11/16/2022
22:00
3.00 MIRU, MOVE RURD P Safe out rig // work rig up checklists // 0.0 0.0
11/16/2022
22:00
11/16/2022
23:00
1.00 MIRU, WHDBOP NUND P Nipple up BOPs *** Rig Accepted
23:00 11/16/2022 ***
0.0 0.0
11/16/2022
23:00
11/17/2022
00:00
1.00 MIRU, WHDBOP CTOP P Change out riser // RKBs // load fresh
water into pits for circulating // start
greasing valves and prepping for bop
test
0.0 0.0
11/17/2022
00:00
11/17/2022
03:00
3.00 MIRU, WHDBOP CTOP P Complete grease of stack // Valve crew
grease tree // flood up surface lines with
fresh water // pressure test PUTZ no
leaks // fluid pack surface lines and
stack // Shell test good
0.0 0.0
11/17/2022
03:00
11/17/2022
04:12
1.20 MIRU, WHDBOP BOPE P BOP test wintess waived by Sean
Sullivan 250/3500 psi
Test 1. Swab 2 - Pass
Test 2. Blind/Shear, BOP TV2, Charlie
4, 5, 8, &12 - Pass
Test 3. BOP TV 1, Charlie 3, 7, & 11-
Pass
Test 4. Manual choke D & Super choke
C - Pass
0.0 0.0
11/17/2022
04:12
11/17/2022
05:00
0.80 MIRU, WHDBOP BOPE T Test 5. Romeo 3, Bleeder 3, Tango 2,
Charlie 2, & 10 -Fail / Pass
grease valve and retest - good test
0.0 0.0
Rig: NABORS CDR3-AC
RIG RELEASE DATE 11/27/2022
Page 2/9
2W-02
Report Printed: 12/20/2022
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)
11/17/2022
05:00
11/17/2022
10:30
5.50 MIRU, WHDBOP BOPE P Test 6. Charlie 1, 9, Bravo 5, and Tango
1 – install TIW test joint
Test 7. Lower 2” pipe slip rams, TIW #1,
Romeo 1, Bleeder 1
Test 8. Annular BOP 250/2500
Test 9. Upper 2” pipe slip rams, Bravo
6, & 8
Test 10. Bravo 7 –
Test 11. 2-3/8” pipe slip rams, TIW#2 –
check N2 levels
Test 12. Draw down accumulator
Test 13. Stab injector and line up to
reverse circulate coil, test inner reel
valve and stripper.
Tested all gas detectors, pits, cellar,
Verified flow alarms - PVT
0.0 0.0
11/17/2022
10:30
11/17/2022
12:00
1.50 PROD1, WHPST CTOP P Unstab injector, make up drillers side
PDL, PT - good. Unstab and stoe, stab
ODS PDL, flood up to tiger tank, PT
both - good.
**Swap to high line power 12:00
0.0 0.0
11/17/2022
12:00
11/17/2022
14:00
2.00 PROD1, WHPST PULD P PJSM, PU BHA #1, window milling
assembly, coil trak, 1° Fixed bend motor,
string mill and diamond speed mill
* guage in 2.80" no go on both speed
mill and reamer
0.0 78.1
11/17/2022
14:00
11/17/2022
15:30
1.50 PROD1, WHPST TRIP P RIH W BHA #1, window milling
assembly, close EDC and spin the bit
while RIH and flushing well with
seawater taking returns to the tiger tank.
78.1 6,286.0
11/17/2022
15:30
11/17/2022
15:42
0.20 PROD1, WHPST DLOG P tie into the K1 for a -5.5' correction 6,286.0 6,351.9
11/17/2022
15:42
11/17/2022
16:18
0.60 PROD1, WHPST DISP P Displace well to power pro 6,286.0 6,351.9
11/17/2022
16:18
11/17/2022
16:30
0.20 PROD1, WHPST TRIP P Bring power pro back inside, RIH and
dry tag TOW @ 6,459.47' with a 2.1'
pinch point, corrected TOWS - 6,457.4'
6,351.9 6,459.0
11/17/2022
16:30
11/17/2022
16:42
0.20 PROD1, WHPST CIRC P PU Wt 37 k lbs, PUH and set rate, RBIH
WH 26 psi, IA 0 psi, OA 2 psi, CT 4133
psi @ 1.86 in and out,BHP 3164 psi,
Free spin 750 CT RIH W Wt 22.76 k lbs
6,459.0 6,459.2
11/17/2022
16:42
11/18/2022
00:00
7.30 PROD1, WHPST WPST P Milling 2.80" exit window, F/ 6459.2
T/6465.8
6,459.2 6,465.8
11/18/2022
00:00
11/18/2022
06:12
6.20 PROD1, WHPST WPST P Mill ahead on window F/ 6465.8 T/
6470
Exit 4.5" @ 6467.3
6,465.8 6,471.0
11/18/2022
06:12
11/18/2022
07:30
1.30 PROD1, WHPST WPST P Drilling ahead in formation. WH 0, IA
506 psi, OA 15 psi, CT 4481 psi @ 1.88
bpm in and 1.72 bpm out. BHP 3126
psi, 10.2 ppg EMW at the window.
Experiancing heavy losses when
attempting to hold 11.8 ppg at the
window.
6,471.0 6,480.0
11/18/2022
07:30
11/18/2022
09:06
1.60 PROD1, WHPST MILL P TD rat hole at 6,480'. PU Wt 33 k lbs,
Perform reaming passews at HS, 30L,
30R, and 180 ROHS. Dry drift - clean,
Tag bottom
6,480.0 6,480.0
11/18/2022
09:06
11/18/2022
10:30
1.40 PROD1, WHPST TRIP P PU Wt 32 k lbs, PUH into casing, jog
tubing, open EDC stage pump to 2.34
bpm in POOH ~100 ft/min, getting ~1.9
bpm back
6,480.0 78.1
11/18/2022
10:30
11/18/2022
11:54
1.40 PROD1, WHPST PULD P Bump up, space out, PJSM, PUD BHA
#1.
**Mills no go out 2.80"
78.1 0.0
Rig: NABORS CDR3-AC
RIG RELEASE DATE 11/27/2022
Page 3/9
2W-02
Report Printed: 12/20/2022
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)
11/18/2022
11:54
11/18/2022
12:24
0.50 PROD1, DRILL CIRC P Stab injector and jet stack, unstab. 0.0 0.0
11/18/2022
12:24
11/18/2022
12:54
0.50 PROD1, DRILL CTOP P Swap out hour'd out upper quick
connect, wire tested at 85.2 Ohms and
greater than 550 M Ohms
0.0 0.0
11/18/2022
12:54
11/18/2022
14:24
1.50 PROD1, DRILL PULD P PD BA #2, build drilling assembly, 2.5 -°
AKO motor with rebuild HCC bicenter
bit.
0.0 72.2
11/18/2022
14:24
11/18/2022
15:42
1.30 PROD1, DRILL CTOP P RIH with BHA #2 72.2 6,288.0
11/18/2022
15:42
11/18/2022
15:54
0.20 PROD1, DRILL CTOP P Tie into the K1 for a -10' correction,
close EDC, PU Wt 34 k lbs.
6,288.0 6,320.0
11/18/2022
15:54
11/18/2022
16:03
0.15 PROD1, DRILL TRIP P RIH, PU Wt 34 k lbs, pass thorough
window - clean
Set rate and gather parameters.
WH 0 psi, IA 15 psi, OA 19 psi, CT 4006
psi at 1.87 bpm in and 1.78 bpm out,
coke wide open and 10.32 EMW at the
window. BHP 3152 psi. Free spin 525
psi.
6,320.0 6,480.0
11/18/2022
16:03
11/18/2022
18:03
2.00 PROD1, DRILL DRLG P OBD - CT Wt 20 k lbs, CT 4032 psi,
WOB 1.5 k lbs, ROP ~ 80
TD 6590' MD 5861TVD 46.5 average
DLS
6,480.0 6,590.0
11/18/2022
18:03
11/18/2022
19:33
1.50 PROD1, DRILL TRIP P POOH for lateral assembly // Tag up and
space out 1.2' for pressure un-deploy
6,590.0 75.0
11/18/2022
19:33
11/18/2022
20:33
1.00 PROD1, DRILL PULD P PJSM , Pressure un-deploy BHA# 2
build assembly
75.0 0.0
11/18/2022
20:33
11/18/2022
22:00
1.45 PROD1, DRILL PULD P Pick up and deploy BHA# 3 lateral
bha .5° AKO w/ nov agitator and
Dynamus Bit
0.0 78.0
11/18/2022
22:00
11/18/2022
23:06
1.10 PROD1, DRILL TRIP P RIH w/ BHA # 3 0.0 6,300.0
11/18/2022
23:06
11/18/2022
23:21
0.25 PROD1, DRILL DLOG P Log K1 for depth control // -11'
correction //
6,300.0 6,336.0
11/18/2022
23:21
11/18/2022
23:36
0.25 PROD1, DRILL TRIP P RIH to bottom // Log RA tag for depth
Tag @ 6464// RIH to bottom
6,336.0 6,590.0
11/18/2022
23:36
11/19/2022
00:00
0.40 PROD1, DRILL DRLG P Drill ahead F/ 6590' T/ 6608' 6,590.0 6,608.0
11/19/2022
00:00
11/19/2022
02:15
2.25 PROD1, DRILL DRLG P Drill Ahead F/ 6608 T/ 6786
790 diff free spin
4710 pp 1.88 in 1.38 out Ann 3517
Drilling break 200'/hr
stall 5.5k DHWOB
6,608.0 6,786.0
11/19/2022
02:15
11/19/2022
02:24
0.15 PROD1, DRILL WPRT P Wiper up to 6600' poor returns check
hole conditions // Pu Wt 32K
6,786.0 6,786.0
11/19/2022
02:24
11/19/2022
05:12
2.80 PROD1, DRILL DRLG P Drill Ahead F/ 6786 T/ 6987
890 diff free spin
6,786.0 6,987.0
11/19/2022
05:12
11/19/2022
05:27
0.25 PROD1, DRILL WPRT P PU Wt 32 k lbs, PUH on scheduled
wiper #1
6,987.0 6,602.0
11/19/2022
05:27
11/19/2022
05:42
0.25 PROD1, DRILL WPRT P RBIH, RIH Wt 19-18 k lbs 6,602.0 6,987.0
11/19/2022
05:42
11/19/2022
12:36
6.90 PROD1, DRILL DRLG P BOBD, WH 299 psi, IA 339 psi, OA 24
psi, CT 4776 psi at 1.87 bpm in and
1.52 bpm out. Free spin 858 psi. CT
Wt 17 k lbs, WOB 0.5 to 3 k, ROP
variable.
Longer hard spot 7,246 - 7,255' - 30 min
BHA wipe, PU Wt 35 klbs
Pushed wiper ~ 100 feet
6,987.0 7,503.0
11/19/2022
12:36
11/19/2022
12:51
0.25 PROD1, DRILL WPRT P PU Wt 35 k lbs, PUH on wiper #2 7,503.0 6,700.0
Rig: NABORS CDR3-AC
RIG RELEASE DATE 11/27/2022
Page 4/9
2W-02
Report Printed: 12/20/2022
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)
11/19/2022
12:51
11/19/2022
13:06
0.25 PROD1, DRILL WPRT P RBIH 6,700.0 7,503.0
11/19/2022
13:06
11/19/2022
16:48
3.70 PROD1, DRILL DRLG P BOBD, WH 300 psi, IA 535 psi, OA 26
psi. CT 4,544 psi @ 1.88 bpm in and
1.73 BPM out, BHP 11.4 ppg, Free spin
diff 725 psi.
7,503.0 8,008.0
11/19/2022
16:48
11/19/2022
18:48
2.00 PROD1, DRILL WPRT P PU Wt 35 k lbs, PUH on long wiperr for
tie in chasing 5x5 sweep, lanch second
sweep to timne out for build. Tie in +1'
correction, Jetted 4.5", run back in hole
to drill
8,008.0 8,008.0
11/19/2022
18:48
11/19/2022
19:18
0.50 PROD1, DRILL DRLG P BOBD F/ 8008' T/ 8056
1.8 bpm 725 diff
8,008.0 8,056.0
11/19/2022
19:18
11/20/2022
00:00
4.70 PROD1, DRILL DDRL P Time drill to drop angel F/ 8056' T/
8092'
Set 30 min then push 10'/hr for 3 feet
unable to drop angle
Trough attempt to make shelf
8,056.0 8,092.0
11/20/2022
00:00
11/20/2022
01:18
1.30 PROD1, DRILL DDRL P Time drill to drop angel F/ 8092' T/
8115'
Set 30 min then push 10'/hr for 3 feet
unable to drop angle
Trough attempt to make shelf
8,092.0 8,115.0
11/20/2022
01:18
11/20/2022
03:48
2.50 PROD1, DRILL DRLG P Drill ahead F/ 8115 T/ 8326 8,115.0 8,326.0
11/20/2022
03:48
11/20/2022
04:18
0.50 PROD1, DRILL WPRT P Geo wiper unable to drop angle for
planned TVD drop
8,326.0 8,326.0
11/20/2022
04:18
11/20/2022
06:09
1.85 PROD1, DRILL DRLG P BOBD F/ 8326 T/ 8800
1.8 bpm 5100pp 725 diff free spin
8,326.0 8,800.0
11/20/2022
06:09
11/20/2022
06:27
0.30 PROD1, DRILL WPRT P PU Wt 35 k lbs, PUH on scheduled
wiper #2, slight WOG tugs to -1.5 k lbs
from 8,492 - 8,362'.
8,800.0 7,990.0
11/20/2022
06:27
11/20/2022
06:45
0.30 PROD1, DRILL WPRT P RBIH, Ct Wt 16 - 12 k lbs on trip, similar
WOB bobbls to 0.3 k lbs an trip in from
8,326-8496'.
7,990.0 8,800.0
11/20/2022
06:45
11/20/2022
07:03
0.30 PROD1, DRILL DRLG P BOBD, WH 308 psi, IA 754 psi, OA 31
psi. CT 4635 psi at 1.84 bpm in and 1.6
bpm out. Free spin 704 psi, BHP 3647',
targeting 11.4 ppg EMW
8,800.0 8,849.0
11/20/2022
07:03
11/20/2022
09:30
2.45 PROD1, DRILL DRLG P Roll TF to LS and drill ahead to hard
bottom stop stick. Near bit inc 88.31°
Make 5 gouging passes, PUH at 15
ft/min one BHA length ~ 70', RBIH at 3'
ft/min until seeing WOB ~8,850' Make
repeated gouging passes for a total of 5
times
8,849.0 8,849.0
11/20/2022
09:30
11/20/2022
12:18
2.80 PROD1, DRILL DRLG P RIH to 8850, WOB increase, park stick
for 20 minutes at full rate, TF LS
Time drill at 1 ft/hr from 8849.03', near
bit inc 88.15°, stage up ROP in
incremets to 5 ft/hr. Stacking pipe, bit
not moving, diff sticking. Break out and
drill past troughing.
8,849.0 8,874.0
11/20/2022
12:18
11/20/2022
14:54
2.60 PROD1, DRILL DRLG P PU, bypass HP screens, add 2 ppb
beads to the Hi-vis sweep, pump 5x5
sweep, Weight transfer at slow coil
speeds improved but still unable to drop
angle.
8,874.0 8,965.0
11/20/2022
14:54
11/20/2022
16:54
2.00 PROD1, DRILL TRIP T PU Wt 35 k lbs, POOH for higher bend
motor. Slight WOB tug to 1.2 k lbs @
7529'.
Window clean. Open edc, Pump out of
hole targeting 11.4 ppg EMW
8,965.0 78.3
Rig: NABORS CDR3-AC
RIG RELEASE DATE 11/27/2022
Page 5/9
2W-02
Report Printed: 12/20/2022
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)
11/20/2022
16:54
11/20/2022
18:24
1.50 PROD1, DRILL PULD T PUD BHA # 3 ERD drilling assembly. 78.3 0.0
11/20/2022
18:24
11/20/2022
20:00
1.60 PROD1, DRILL PULD T PD BHA# 4 High bend assembly for
breaking through Siderite cap / 1.2°
AKO w/ Re-run dynamus
0.0 72.0
11/20/2022
20:00
11/20/2022
22:30
2.50 PROD1, DRILL TRIP T RIH with high bend assembly // Tie in K1
+14' correction // Close EDC // PU Wt.
at window 32K //
72.0 8,965.0
11/20/2022
22:30
11/20/2022
23:00
0.50 PROD1, DRILL DRLG T OBD F/ 8965' T/ 9002
1.8 bpm 450 diff
34K pick up
8,965.0 9,002.0
11/20/2022
23:00
11/21/2022
00:00
1.00 PROD1, DRILL DDRL T Unable to drop angle start time drilling 9,002.0 9,002.0
11/21/2022
00:00
11/21/2022
03:54
3.90 PROD1, DRILL DDRL T Time drill trough for time drilling //9011 9,002.0 9,011.0
11/21/2022
03:54
11/21/2022
04:06
0.20 PROD1, DRILL WPRT T BHA wiper to aidin weight transfer 9,011.0 9,011.0
11/21/2022
04:06
11/21/2022
06:12
2.10 PROD1, DRILL DDRL T Drilling ahead with reduced pump rate
targeting higher WOB, 1.2 bpm in, WOB
to 3 k lbs attempting to side track -
unsuccessful
9,011.0 9,060.0
11/21/2022
06:12
11/21/2022
09:12
3.00 PROD1, DRILL DDRL T Make 3 low side troughing passes ~ 70
feet, make an additonal pass back 35'.
RIH and target higher WOB with
reduced pump rate to 1.5 bpm.
9,060.0 9,106.0
11/21/2022
09:12
11/21/2022
09:45
0.55 PROD1, DRILL DDRL T Broke through, Inc fell to 83 °. Drop in
structure and drill ahead to stall at
9146'.
9,106.0 9,146.0
11/21/2022
09:45
11/21/2022
10:00
0.25 PROD1, DRILL DDRL T Unable to pump through coil / BHA after
stall. Trouble shoot and attempt to cear.
Issue is the BHA, most probably the
motor. Bleed pumps, open EDC, regain
target ECD of 11.4 PPG @ the window.
9,146.0 9,078.0
11/21/2022
10:00
11/21/2022
11:00
1.00 PROD1, DRILL TRIP T POOH in open hole with BHA # 4, hole
relatively clean and window clean.
9,078.0 6,434.0
11/21/2022
11:00
11/21/2022
12:24
1.40 PROD1, DRILL TRIP T Slow troll the 4.5" big tail pipe jetting
cuttings.
6,434.0 77.8
11/21/2022
12:24
11/21/2022
14:06
1.70 PROD1, DRILL PULD T PUD BHA # 4 medium bend motor.
Cycle EDC to test at surface post
pumping beads and opening in open
hole. EDC sealed but produced an error
code. Due to risk of opening EDC then
having checks fail and not being able to
close the EDC PUD following failed
check checklist with EDC closed.
77.8 0.0
11/21/2022
14:06
11/21/2022
14:30
0.40 PROD1, DRILL CTOP T Reconfigure coiltrack tool 0.0 78.0
11/21/2022
14:30
11/21/2022
16:18
1.80 PROD1, DRILL PULD T PD BHA #5, 0.5 ° AKO with RB HCC
dynamus
0.0 78.0
11/21/2022
16:18
11/21/2022
19:03
2.75 PROD1, DRILL TRIP T RIH with ERD drilling assembly.// Tie in
K1 -8.5' correction // Window clean // PU
WT 34K //
78.0 9,149.0
11/21/2022
19:03
11/21/2022
22:27
3.40 PROD1, DRILL DRLG P BOBD F/ 9149 T/ 9506'
1.8 bpm 4923pp 699diff
9,149.0 9,506.0
11/21/2022
22:27
11/21/2022
23:15
0.80 PROD1, DRILL WPRT P 1000' wiper // Pu.Wt. 41K 9,506.0 9,506.0
11/21/2022
23:15
11/22/2022
00:00
0.75 PROD1, DRILL DRLG P BOBD F/ 9506' T/ 9573
1.8bpm 5200psi 750diff 3824ann
1.82bpm in
9,506.0 9,573.0
11/22/2022
00:00
11/22/2022
04:15
4.25 PROD1, DRILL DRLG P BOBD F/ 9573' T/ 9830
1.8bpm 5200psi 750diff 3824ann
1.82bpm in 1.85 out
9,573.0 9,830.0
Rig: NABORS CDR3-AC
RIG RELEASE DATE 11/27/2022
Page 6/9
2W-02
Report Printed: 12/20/2022
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)
11/22/2022
04:15
11/22/2022
05:33
1.30 PROD1, DRILL WPRT P Wiper to window to clean hole, clean
window
9,830.0 6,480.0
11/22/2022
05:33
11/22/2022
05:45
0.20 PROD1, DRILL DLOG P Tie into the RA tag for a +1.5' correction. 6,480.0 6,498.8
11/22/2022
05:45
11/22/2022
06:03
0.30 PROD1, DRILL CIRC P Jet the 4.5" tailpipe 6,498.8 6,407.0
11/22/2022
06:03
11/22/2022
07:15
1.20 PROD1, DRILL TRIP P RBIH, catch 9150-9165' with a MAD
pass. Return truck on location, roll to 2
pit system, start exporting mud to the
tiger tank for mud swap.
6,407.0 9,830.0
11/22/2022
07:15
11/22/2022
13:03
5.80 PROD1, DRILL DRLG P BOBD, as new mud exited the bit. Dril
lahead ~100-180 ft/hr w ~1.4 WOB.
PU Wt 32 k lbs, Pick up for new mud
parameters @ 9,910'
WH 346, IA 903 psi, OA 31 psi CT 4737
psi @ 1.82 bpm in and 1.6 bpm out.
Free spin 720 psi, RIH wt 12 k lbs,
BOBD,
** New mud at the bit 9,830'
9,830.0 10,236.0
11/22/2022
13:03
11/22/2022
13:21
0.30 PROD1, DRILL WPRT P PU Wt 44 k lbs. PUH on scheduled
wiper #1 - clean trip
10,236.0 9,400.0
11/22/2022
13:21
11/22/2022
13:39
0.30 PROD1, DRILL WPRT P RBIH, CT Wt 15-12 k lbs - clean trip 9,400.0 10,236.0
11/22/2022
13:39
11/22/2022
20:00
6.35 PROD1, DRILL DRLG P WH 307 psi, IA 920 psi, OA 31 psi, CT
5,031 psi @ 1.85 in 1.72 bpm out, free
spin 720 psi, BHP 3818 psi targeting
11.4 ppg EMW at the window, 12.49 ppg
at the bit. OBD, CT Wt 8 k lbs, WOB 1 k
lbs.
10,236.0 10,628.0
11/22/2022
20:00
11/22/2022
20:45
0.75 PROD1, DRILL WPRT P Geo Wiper for extension of polygon 10,628.0 10,628.0
11/22/2022
20:45
11/23/2022
00:00
3.25 PROD1, DRILL DRLG P WH 279 psi, IA 503 psi, OA 31 psi, CT
5,031 psi @ 1.85 in 1.72 bpm out, free
spin 720 psi, BHP 3818 psi targeting
11.4 ppg EMW at the window, 12.49 ppg
at the bit. OBD, CT Wt -8 k lbs, WOB 1
k lbs.
10,628.0 10,878.0
11/23/2022
00:00
11/23/2022
02:45
2.75 PROD1, DRILL DRLG P WH 279 psi, IA 503 psi, OA 31 psi, CT
5,031 psi @ 1.85 in 1.72 bpm out, free
spin 720 psi, BHP 3818 psi targeting
11.4 ppg EMW at the window, 12.49 ppg
at the bit. OBD, CT Wt -8 k lbs, WOB 1
k lbs.
10,878.0 10,974.0
11/23/2022
02:45
11/23/2022
04:24
1.65 PROD1, DRILL WPRT P PU Wt 33 k lbs, Wiper to window for tie
in and clean hole
10,974.0 6,490.0
11/23/2022
04:24
11/23/2022
04:33
0.15 PROD1, DRILL DLOG P Tie into the RA tag for a +3' correction 6,490.0 6,500.0
11/23/2022
04:33
11/23/2022
04:39
0.10 PROD1, DRILL DLOG P Pull to 6448' MD - 5,757.56' TVD park
and trap 3,502 psi.
Bleed pressure to 3,415' and monitor,
stable at 11.4 ppg EMW
6,500.0 6,448.0
11/23/2022
04:39
11/23/2022
04:51
0.20 PROD1, DRILL DLOG P Pull to 6448' MD - 5,757.56' TVD park
and trap 3,502 psi.
Bleed pressure to 3,415' and monitor,
stable at 11.4 ppg EMW
6,500.0 6,448.0
11/23/2022
04:51
11/23/2022
06:39
1.80 PROD1, DRILL TRIP P RBIH - RIH wt 3 k lbs 6,448.0 10,974.0
Rig: NABORS CDR3-AC
RIG RELEASE DATE 11/27/2022
Page 7/9
2W-02
Report Printed: 12/20/2022
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)
11/23/2022
06:39
11/23/2022
19:09
12.50 PROD1, DRILL DRLG P WH 186 psi, IA 516 psi, OA 30 psi, CT
5,430 psi @ 1,86 bpm in and 1.73 bpm
out. Free spin 791 psi. BHP 3911 psi
targeting 11.4 EMW getting 12.8 ppg at
the bit.
OBD - CT Wt 5 to -5 k lbs, WOB 0.5-2 k
lbs, ROP slow, in narpy rock
Geo says Ankerite in the samples
10,974.0 11,350.0
11/23/2022
19:09
11/23/2022
20:09
1.00 PROD1, DRILL WPRT P 800' wiper 11,350.0 11,350.0
11/23/2022
20:09
11/24/2022
00:00
3.85 PROD1, DRILL DRLG P WH 177 psi, IA 656 psi, OA 35 psi, CT
5,430 psi @ 1,86 bpm in and 1.73 bpm
out. Free spin 791 psi. BHP 3911 psi
targeting 11.4 EMW getting 12.8 ppg at
the bit.
OBD - CT Wt 5 to -5 k lbs, WOB 0.5-2 k
lbs, ROP slow, in narpy rock
11,350.0 11,500.0
11/24/2022
00:00
11/24/2022
05:30
5.50 PROD1, DRILL DRLG P WH 336 psi, IA 506 psi, OA 28 psi, CT
5,067 psi @ 1,86 bpm in and 1.78 bpm
out. Free spin 791 psi. BHP 3875 psi
targeting 11.4 EMW getting 12.8 ppg at
the bit.
OBD - CT Wt 5 to -5 k lbs, WOB 0.5-2 k
lbs, ROP slow, in narpy rock
11,500.0 11,662.0
11/24/2022
05:30
11/24/2022
05:48
0.30 PROD1, DRILL WPRT P PU Wt 32 k lbs PUH on wiper trip #1, 11,662.0 10,950.0
11/24/2022
05:48
11/24/2022
06:12
0.40 PROD1, DRILL WPRT P RBIH, Ct Wt 9.5-2.5 k lbs 10,950.0 11,662.0
11/24/2022
06:12
11/24/2022
15:42
9.50 PROD1, DRILL WPRT P WH 311 psi, IA 598 psi, OA 33 psi, CT
5030 psi @ 1.82 bpm in and out. Free
spin 770 psi. BHP 3920 psi targeting
11.4 ppg at the window, running 12.85
ppg at the bit. Drill ahead pumping 10
bbl (1ppb beaded sweeps) continuously
as one exits the coil, one enters. CT Wt
0 to -5 k lbs, WOB ~ 0.8 to 0.5 k lbs.
11,662.0 11,995.0
11/24/2022
15:42
11/24/2022
19:54
4.20 PROD1, DRILL WPRT P PU Wt 32 k lbs PUH on wiper trip.//Tag
up
11,995.0 78.0
11/24/2022
19:54
11/24/2022
21:18
1.40 PROD1, DRILL TRIP P RIH to window confirm KWF // Tie in K1
-11' correction
78.0 6,450.0
11/24/2022
21:18
11/24/2022
21:33
0.25 PROD1, DRILL CTOP P Static at window for KWF
6449.99 MD
5854.43 TVD
Ann 3389
Eqiv Md Wt. = 11.13
KWF 11.4
6,450.0 6,450.0
11/24/2022
21:33
11/25/2022
00:00
2.45 PROD1, DRILL TRIP P RIH to confirm TD, stack out in window
work through, pick up and run through
window again slight WOB bobble,
continue in to confirm TD @ 12000'
6,450.0 12,000.0
11/25/2022
00:00
11/25/2022
00:30
0.50 PROD1, DRILL CIRC P Circulate LRP to bit 12,000.0 12,000.0
11/25/2022
00:30
11/25/2022
03:45
3.25 PROD1, DRILL DISP P POOH laying in 11.4 LRP // Paint TD
EOP flag 10621.4' end of coil //
12,000.0 81.0
11/25/2022
03:45
11/25/2022
04:00
0.25 PROD1, DRILL OWFF P Flow check well // PJSM laying down
tools dead well
81.0 81.0
11/25/2022
04:00
11/25/2022
04:45
0.75 PROD1, DRILL PULD P Lay down BHA# 4 on dead well 81.0 0.0
11/25/2022
04:45
11/25/2022
05:00
0.25 COMPZ1, CASING BOPE P Function test BOPs 0.0 0.0
11/25/2022
05:00
11/25/2022
05:45
0.75 COMPZ1, CASING CTOP P Rig up to pick up liner // inspect blocks
and liner running equipment
0.0 0.0
Rig: NABORS CDR3-AC
RIG RELEASE DATE 11/27/2022
Page 8/9
2W-02
Report Printed: 12/20/2022
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)
11/25/2022
05:45
11/25/2022
07:30
1.75 COMPZ1, CASING PUTB P PU Lower L1 completion 44 joints of 4.6
lb/ft slotted 3-3/8" STL liner over a non
ported bull nose and topped with a
Northern solutions QCLL ( LOA
1315.96')
0.0 1,315.0
11/25/2022
07:30
11/25/2022
08:00
0.50 COMPZ1, CASING PULD P PU BHA # 6, lower liner running
assembly, bump up, set counters,
** lost 13.8 bbls of KW fluid
1,315.0 1,360.0
11/25/2022
08:00
11/25/2022
11:30
3.50 COMPZ1, CASING RUNL P RIH with lower L1 completion, tie into
yellow window flag, found at 6368.75'
Correction -8.44'
Pushed KW away the whole trip in,
suspect its going to the mother bore.
Attempt to tie into the K1, abandoned as
WOB increased, and CT weight
decreased. PU Wt 41 k lbs. Continue
in hole at speed, caught K1 on the drive
by estimate ~ - 2' correction, Saw RA
tag on drive by, +1.5' correction -
essentially on depth. Set liner on
bottom, 11,995.55' PU Wt 44 k lbs,
WOB to -2.7 lk lbs. RBIH, stack -9 k CT
Wt, WOB 3.26 k lbs, pump to 1.5 bpm,
wait for dif to climb to 977 psi, PU wt 36
k, lbs, WOB -1 k lbs.
*** TOL 10,684'
1,360.0 11,982.0
11/25/2022
11:30
11/25/2022
15:00
3.50 COMPZ1, CASING TRIP P PUH, park and remove liner length.
Displace liner running pill to bit, paint
yellow flag @ 4543.06', continue out of
hole.
11,982.0 62.3
11/25/2022
15:00
11/25/2022
15:36
0.60 COMPZ1, CASING PULD P Flow check while PJSM, LD BHA # 6,
lower liner running assembly.
62.3 0.0
11/25/2022
15:36
11/25/2022
16:12
0.60 COMPZ1, CASING CTOP P Prep floor for running liner, inspect liner
running equip. and blocks
0.0 0.0
11/25/2022
16:12
11/25/2022
19:00
2.80 COMPZ1, CASING PUTB P PU Middle L1 completion 57 joints of
4.6 lb/ft slotted 3-3/8" STL liner over a
QCLL dissolving bull nose and topped
with a Northern solutions QCLL ( LOA
1791.88' )
0.0 1,791.9
11/25/2022
19:00
11/25/2022
19:30
0.50 COMPZ1, CASING PULD P Rig down liner running equipment // Pick
up baker BHA
1,791.9 1,791.9
11/25/2022
19:30
11/25/2022
22:15
2.75 COMPZ1, CASING RUNL P RIH with L1 mid completion , tie into
yellow window flag @ 6345.86' ,
correction -11' correction , Pushed away
returns while running in hole, pass
through window clean continue in hole,
ran to bottom clean latched into lower
section @ 10861' PU 50K confirm latch
pump off liner
1,791.9 10,684.0
11/25/2022
22:15
11/25/2022
22:45
0.50 COMPZ1, CASING CIRC P Circulate LRP to GS 10,684.0 10,650.0
11/25/2022
22:45
11/26/2022
00:00
1.25 COMPZ1, CASING TRIP P POOH laying in LRP to window continue
to surface
10,650.0 5,360.0
11/26/2022
00:00
11/26/2022
01:00
1.00 COMPZ1, CASING TRIP P Continue out of hole for second liner run 5,360.0 88.0
11/26/2022
01:00
11/26/2022
01:48
0.80 COMPZ1, CASING PULD P PJSM and flow check, lay down BHA# 7
dead well
88.0 0.0
11/26/2022
01:48
11/26/2022
04:48
3.00 COMPZ1, CASING PUTB P Pick up 77 jts 2-3/8" liner and 3 solid
pups
Total liner footage picked up 2440.15
0.0 2,440.2
11/26/2022
04:48
11/26/2022
05:18
0.50 COMPZ1, CASING PULD P PU BHA #8, check pack offs - good,
bump up, set counters
2,440.2 2,485.2
Rig: NABORS CDR3-AC
RIG RELEASE DATE 11/27/2022
Page 9/9
2W-02
Report Printed: 12/20/2022
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)
11/26/2022
05:18
11/26/2022
07:00
1.70 COMPZ1, CASING RUNL P RIH w/ BHA # 8, upper L1 liner running
assembly. Tie into the flag for a -7'
correction. PU Wt 31 k lbs. WOB -8.6 k
lbs. Continue in hole. Find liner top At
8881' CTMD, WOB tot 11 k lbs. PU Wt ,
50 k lbs, WOB -20 k lbs. RBIH, stack 11
k WOB, CT wt, 9 k lbs. Pump 1.5 bpm,
dif to 936 psi, PU Wt 28 k lbs, WOB 0.1
k lbs. Liner released on depth
** TOL 6450'
2,485.2 8,891.8
11/26/2022
07:00
11/26/2022
08:51
1.85 COMPZ1, CASING DISP P PUH, park and reset depth to reflect
dropped off liner. Chase seawater to
the bit and then surface, walking rate up
to minimize losses and maximize time
efficiency
8,891.8 6,425.8
11/26/2022
08:51
11/26/2022
09:12
0.35 COMPZ1, CASING DLOG P Park @ 6475.76 CTMD 6962.69' TVD
to sensor. Off pump, choke closed, trap
3490 psi, observe pressure fall slowly,
bleed into stable 3,356 psi or 11.0 ppg
EMW
6,425.8 6,475.0
11/26/2022
09:12
11/26/2022
11:06
1.90 COMPZ1, CASING TRIP P Line up to LRS, pump 25 bbls diesel
while PUH to 2,500 feet.
6,475.0 40.0
11/26/2022
11:06
11/26/2022
12:36
1.50 COMPZ1, CASING PULD P PUD BHA #8, liner running assembly.
***Final pressure T/I/O= 812/0/18 psi
40.0 0.0
11/26/2022
12:36
11/26/2022
13:30
0.90 DEMOB, WHDBOP CIRC P Install nozzle, stab injector, jet stack. 0.0 0.0
11/26/2022
13:30
11/26/2022
16:00
2.50 DEMOB, WHDBOP CTOP P Pop off, cut CTC. Trim pipe - Cut 20'
feet, new length old 18,967'. Install
new CTC. Pull test to 35 k lbs. Re
head and test wire, 81.3 Ohms, Meg'd >
550 M ohms. Pressure test connector
to 3,500 psi. - good
** Off shore power and back on
generators
0.0 0.0
11/26/2022
16:00
11/26/2022
22:00
6.00 DEMOB, WHDBOP CTOP P Vac stack, Bore-O-Scope stack. Install
night cap, flush and blow down to tiger
tank.
0.0 0.0
11/26/2022
22:00
11/27/2022
00:00
2.00 DEMOB, WHDBOP NUND P Nipple down BOPs, cap stack Rig
Released 00:00 on 11/27/22
0.0 0.0
Rig: NABORS CDR3-AC
RIG RELEASE DATE 11/27/2022
DTTMSTART JOBTYP SUMMARYOPS
9/15/2022 ACQUIRE DATA DRIFT W/ 15' X 2 1/8" OD DMY DRIFT DOWN TO NIPPLE REDUCER @ 6529' RKB;
MEASURED BHP (3533 PSI) @ 6450' RKB; PULLED DV @ 6194' RKB; SET 1.812" CA-2
PLUG IN NIPPLE REDUCER @ 6529' RKB (OBTAIN PT & DDT ON PLUG). READY FOR E-
LINE TUBING CUT.
9/22/2022 ACQUIRE DATA
PERFORM TUBING CUTS W/ 2.0" RCT CUTTER FOR UPCOMING RIG WORK OVER
RUN 1: CUT TUBING AT 6513.7' RKB, CCL TO CUTTER = 13.2', CCL STOP DEPTH =
6500.5' RKB
RUN 2: CUT TUBING AT 6384.2' RKB, CCL TO CUTTER = 13.2', CCL STOP DEPTH =
6371.0' RKB
RUN 3: CUT TUBING AT 6213.2' RKB, CCL TO CUTTER = 13.2', CCL STOP DEPTH =
6200.0' RKB
JOB COMPLETE, READY FOR RIG
10/5/2022 MAINTAIN WELL PUMPED 8 BBLS METHANOL DOWN FL TO FREEZE PROTECT
JOB COMPLETE
10/13/2022 RECOMPLETION Blow down steam and water in pits. Unhook interconnect. Bridle up. L/D derrick. Haul
equipment T/ 2W. Pull pits away from sub. Load shop and office. Transport pits, shop and
office T/ 2W. Set shop and office. Stage pits on pad. Pull sub off of well. Clean up around
3B-13. Moving sub to 2W-02
10/14/2022 RECOMPLETION Continue moving sub to 2W. Spot sub over well. Spot pits. Spot auxiliary equipment. Hook
up steam and air to pits. Raise derrick. Berm in rig. Bridal down. Get measurements for
riser height from tubing spool height. Rig up circ manifold in cellar. Take initial pressures
T/IA/OA. Pressure test circ manifold & tiger tank T/ 3500 PSI. Bleed free gas off tubing & IA.
Bullhead 260 Bbls seawater down IA @ 3 BPM. Bleed free gas off of tubing. Bullhead 85
Bbls seawater down tubing @ 3 BPM. Record shut in pressure of 275 PSI. Developed plan
to blend new KWF of 9.6 PPG.
10/15/2022 RECOMPLETION Condition 10.6 PPG NaCl/NaBr down T/ 9.6 PPG NaCl/NaBr. Bullhead 260 Bbls 9.6 PPG
NaCl/NaBr down IA @ 3 BPM. Bleed free gas off of tubing. Bullhead 85 Bbls 9.6 PPG
NaCl/NaBr down tubing @ 3 BPM. Allow formation to relax. 30 minute no flow check.
Install ISA BPV. Test from below. Nipple down tree and adaptor spool. Install blanking plug.
Nipple up DSA and BOP. Install flow nipple. Fill stack with fresh water. Test BOPE to sundry
requirements.
10/16/2022 RECOMPLETION
Pull blanking plug and rig down testing equipment. Make up landing joint. BOLDS. Pull
hanger to rig floor. Lay down hanger and landing joint. Circulate bottoms up. Lay down 500'
of completion. Make up 6" drift and run through well head. Lay down drift. Continue pulling
completion. Make up BHA #1 Overshot. Run in hole picking up drill pipe T/ 5584'.
10/17/2022 RECOMPLETION Continue picking up drill pipe. Engage fish @ 6205'. Jar fish free. Circulate out gas and light
weight fluid. Pull out of hole. Pull out of hole. Lay down BHA #1 and fish. Seals and packer
down to second cut recovered. Make up BHA #2 overshot and run in hole engage fish. Jar
blast joints free. Circulate well. Pull out of hole. Lay down BHA #2 overshot. Rig up tubing
handling equipment.
10/18/2022 RECOMPLETION
Lay down blast ring fish. Clean and clear rig floor. Make up BHA #3 clean out assembly.
Run in hole. Wash and ream from 6100' to tubing stub 6504'. Pump hi-vis pill around. Pull
out of hole laying down drill pipe and BHA #3. Pull wear bushing. Rig up GBR tubing
equipment. Verify joint count and running order. Run 3 1/2" completion string T/ 246'.
10/19/2022 RECOMPLETION Continue running 3 1/2" completion string. Wash overshot onto tubing stub. Fully located.
Pick up space out. Make up hanger and landing joint. Circulated 9.6 PPG CI NaCl around.
Land hanger. RILDS. Drop ball and rod. Pressure up and set tandem HES MFT packers.
Test tubing to 3500 PSI for 30 min. Test IA to 3000 PSI for 30 MIn. Shear out SOV. Set HP
BPV. Test BPV from below. Perform rig repair on annular preventer, change out drum clutch
on draw works.
2W-02 CTD
Summary of Operations
Test tubing to 3500 PSI for 30 min. Test IA to 3000 PSI for 30 MIn Shear out SOV
PERFORM TUBING CUTS W / 2.0" RCT CUTTER FOR UPCOMING RIG WORK
JOB COMPLETE, READY FOR RIG
Continue running 3 1/2" completion string. Wash overshot onto tubing stub. Fully located.
Pick up space out. Make up hanger and landing joint
Land hanger.
10/20/2022 RECOMPLETION Continue perform rig repair on annular preventer. Nipple down BOP. Set tree test plug.
Nipple up adaptor spool and tree. Pressure test hanger void T/ 5000 PSI for 15 min. Rig up
LRS, circ manifold and tiger tank. Pressure test tree T/ 5000 PSI for 15 min. Pull tree test
dart and HP BPV. LRS pump 71 Bbls diesel freeze protect down IA. Rig down LRS. U-tube
well. Rig down circ manifold. Secure tree and cellar. Pull pits away from sub and stage on
pad. RDMO
10/23/2022 ACQUIRE DATA (PRE CTD) TREE VALVE TESTS POSTIVE/NEGATIVE (ALL PASS)
10/26/2022 ACQUIRE DATA SHAKE OFF BAITED BALL & ROD PULLING TOOL @ 6300' RKB. PULLED SOV @ 6165'
RKB & SET DMY. IN PROGRESS.
10/27/2022 ACQUIRE DATA PULLED BAITED PULLING TOOL & BALL n' ROD @ 6497' RKB. PULLED 2.81'' RHC @
6503' RKB. DRIFTED W/ 2.625'' x 17' DMY WHIPSTOCK TO TAG TBG CUT @ 6513' RKB
(NO ANOMALIES). SET 2.81'' XX PLUG @ 6503' RKB (OBTAIN TBG TEST TO 2500).
READY FOR E-LINE.
11/3/2022 ACQUIRE DATA LOG GR/CCL FROM 6497' RKB (JUST ABOVE XX PLUG @ 6404' RKB). TIE INTO K1
MARKER @ 6286' FOR MINUS 8 FT CORRECTION (CBL DATED 3/8/85).
JOB IS READY FOR ELINE TO SET WS (WHEN SLB BACK IN FIELD)
11/14/2022 ACQUIRE DATA SET TOP OF BAKER HUGHES GEN II DELTA WHIPSTOCK 2 DEG LOHS AT 6455.0' PDC,
CCL TO TOP OF WHIPSTOCK = 14.1', CCL STOP DEPTH = 6440.9'
JOB COMPLETE, READY FOR CDR
11/16/2022 DRILLING
SIDETRACK Completed rig down checklists, prepped for move to 2W-02 // Mob rig to 2W-02 spot and rig
up over well // NU bops rig accepted @ 23:00 // change out riser and prep for bop test
11/17/2022 DRILLING
SIDETRACK Grease and fluid pack bop and surface lines, perform shell test, test bops 250/3500 witness
waived AOGCC Sean Sullivan // Completed BOP test, test surface lines, Pick up BHA# 1
deploy, RIH, flush well with seawater, swap to milling fluid and mill window F/6459.2
11/18/2022 DRILLING
SIDETRACK
Completed 2.80" exit , pooh deployed BHA# 2 2.5° lite AKO, Drilled build T/ 6590 MD 5861
TVD, POOH for lateral BHA , RIH with ER Lateral BHA .5° AKO w/ Dynamus bit, log RA tag
for WS depth, tag bottom drill ahead
11/19/2022 DRILLING
SIDETRACK Drilled ahead pulling wipers every 400' , 8068 started time drilling to attempt to drop angle
11/20/2022 DRILLING
SIDETRACK Continued to drill ahead, 8065 encountered siderite cap unable to drop angle for planned TVD
drop in lateral, multiple attempts to time mill or break through cap unsuccessful, pooh for
higher bend motor to "break through", Deployed BHA# 4 1.2° AKO motor with re-run dynamus
, RIH tie in +14' correction, clean counter, start drilling unable to drop angle, start time drilling
11/21/2022 DRILLING
SIDETRACK
Continued with time drilling, broke through hard layer @ 9080' , motor stalled @ 9149'
plugged off with beads, pooh for ER lateral assembly, RIH w/ lateral assembly tie in -8.5'
correction drilled to midnight depth 9573
11/22/2022 DRILLING Continued to drill ahead in C1 trying to build angle loosing coil wt
11/23/2022 DRILLING Continued drilling ahead slowly toward TD @ 11861
11/24/2022 DRILLING
SIDETRACK
Continued to drill ahead toward new TD @ 11,995', TD well, perform swab wiper, RIH tie in
K1 -11' correction, stacked in BOW 3 times, Passed through continued to bottom confirming
@ 12,000',
11/25/2022 DRILLING
SIDETRACK
After confirming TD @ 12,000 pump 70bbls 11.4 liner running pill laying in to window,
continued to pooh displacing well to 11.4 kwf, Pick up L1 lower liner completion 44 jts slotted
liner, RIH with lower completion dropping on bottom leaving top of liner 10,681', pump liner
running pill for second liner run, pooh and pick up second run 57 jts slotted liner, ran in hole
and latched into lower completion pu wt 50K confirm latch, pump off liner TOL 8892', pump 20
bbls liner running pill start pooh for upper completion
11/26/2022 DRILLING
SIDETRACK Pick up and run L1 upper section of completion, latch into mid completion confirm latch, pump
off completion check tree bolts, pump sea water and check reservoir pressure @ 11ppg, pooh
swapping well to seawater, freeze protect 2500' to surface, continue out of hole perform end
of well ops, rig down checklists and nipple down stack rig released 00:00 11/27/22
12/1/2022 ACQUIRE DATA DRIFT TO TOP OF LINER @ 6450' RKB.MEASURE SBHP AT 6450' RKB (2786 psi) JOB
COMPLETE.
12/7/2022 PUMPING
TRACKING ONLY FREEZE PROTECT FL WITH 8 BBLS METHANOL
Pick up and run L1 upper section of completion, latch into mid completion confirm latch, pump
off completion
After confirming TD @ 12,000
PULLED BAITED PULLING TOOL & BALL n' ROD
pooh and pick up second run 57 jts slotted liner, ran in hole
and latched into lower completion pu wt 50K confirm latch, pump off liner TOL 8892',
TD @ 11,995', TD well
Pick up L1 lower liner completion 44 jts slotted
liner, RIH with lower completion dropping on bottom leaving top of liner 10,681'
SET TOP OF BAKER HUGHES GEN II DELTA WHIPSTOCK 2 DEG LOHS AT 6455.0'
PULLED 2.81'' RHC
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag: RKB (Est. 75' of Fill) 6,643.0 2W-02 3/11/2021 zembaej
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Added 2W-02L1 liner top to "other in hole" 2W-02 11/30/2022 fergusp
General Notes: Last 3 entries
Com Date Last Mod By
Top of liner left at 6450' CTMD. Fluids lost to the well bore during drilling, Power Pro Losses:
1816 bbls, NaBr Losses: 224 bbls, Seawater losses: 43 bbls
11/26/2022 ncdr3cm
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 1/2 31.0 110.0 110.0 65.50 H-40 WELDED
SURFACE 9 5/8 8.92 30.2 3,118.6 3,117.9 36.00 J-55 BTC
PRODUCTION 7 6.28 28.7 6,890.4 6,243.6 26.00 J-55 BTC
Tubing Strings: string max indicates LONGEST segment of string
Top (ftKB)
26.7
Set Depth …
6,512.0
Set Depth …
5,943.4
String Ma…
3 1/2
Tubing Description
Tubing – Gas Injection
Wt (lb/ft)
9.30
Grade
L-80
Top Connection
HYD563
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)
26.7 26.7 0.05 Hanger 7.063 FMC GEN IV Tubing Hanger FMC Gen IV 2.960
478.1 478.1 0.13 Nipple -
Landing
3.939 3.5" 2.81" X-nipple, SN#
0004717612-3
Halliburt
on
X Nipple 2.831
6,164.8 5,663.0 36.16 Mandrel – GAS
LIFT
5.970 3.5" x 1.5" Camco MMG GLM SLB MMG 2.920
6,225.5 5,712.1 35.95 Packer 6.280 3.5" x 7" Halliburton MFT
Feedthrough Packer, SN#
0004534635-2
Halliburt
on
MFT
Packer
2.897
6,254.7 5,735.7 35.95 Nipple -
Landing
3.937 3.5" 2.81" X-nipple, SN#
0004717612-4
Halliburt
on
X Nipple 2.831
6,393.5 5,848.1 36.00 XO - Enlarging 4.500 3.5" 9.3# L-80 8rd EUE x 4.5" HYD
563, XO
2.831
6,397.3 5,851.1 36.00 Centralizer 4.500 4.5" 12.6# Hyd 563 TBG w/Maxwell
Centralizers
Maxwell Offset
Centraliz
er
3.958
6,480.8 5,918.4 36.69 XO - Enlarging 4.500 4.5" 563" x 3.5" 9.3# L-80 8rd EUE,
XO
2.992
6,490.4 5,926.1 36.77 Packer 6.280 3.5" x 7" Halliburton MFT
Feedthrough Packer, SN#
0004537135-2
Halliburt
on
MFT
Packer
2.897
6,503.6 5,936.7 36.86 Nipple -
Landing
3.940 3.5" x 2.813", X-Nipple SN#
0004717612-5
Halliburt
on
X Nipple 2.831
6,510.6 5,942.3 36.88 Overshot 5.900 3-1/2" Overshot 8rd EUE Box Baker Oversho
t
3.625
Top (ftKB)
6,513.7
Set Depth …
6,536.6
Set Depth …
5,963.1
String Ma…
3 1/2
Tubing Description
Tubing – Completion Lower
Wt (lb/ft)
9.30
Grade
J-55
Top Connection
EUE8RDABM
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)
6,514.8 5,945.7 36.89 SEAL ASSY 4.000 BAKER LOCATOR SEAL
ASSEMBLY
3.000
6,515.7 5,946.4 36.90 PACKER 5.875 BAKER FB-1 PACKER 4.000
6,519.0 5,949.0 36.91 SBE 5.000 BAKER SEAL BORE EXTENSION 4.000
6,529.1 5,957.1 36.94 NIPPLE 4.540 CAMCO D NIPPLE NO GO 2.75" ID
w/1.81" NIPPLE REDUCER
2.750
6,535.8 5,962.5 36.96 SOS 3.500 BAKER SHEAR OUT SUB. ELMD
@ 6527' per SWS IPROF on
9/14/2006
2.992
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)
6,450.0 5,893.7 36.43 LINER TOP 2W-02L1 liner top/deployment
sleeve.
11/26/2022 1.992
6,455.0 5,897.7 36.47 WHIPSTOCK 2.625" GEN II BAKER
HUGHES DELTA
WHIPSTOCK, TOWS AT
6455' PDC, OAL 12.97'
BAKER
HUGHE
S
GEN II
DELTA
H1505
04512
11/14/2022 0.000
6,504.0 5,937.0 36.86 TUBING
PLUG
Set XX Plug (OAL 25'' / 8
x .125'' EQ PORTS),
10/27/2022 0.000
6,513.7 5,944.8 36.89 CUT 2" RCT TBG CUT AT 6513.7'
RKB
(pre-RWO Oct 2022)
9/22/2022 2.992
6,529.0 5,957.0 36.94 TUBING
PLUG
1.812" CA-2 PLUG (25" OAL)
9/15/2022
9/15/2022 0.000
6,529.2 5,957.2 36.94 NIPPLE
REDUCER
2.75" NIPPLE REDUCER 10/3/2013 1.810
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)
6,164.8 5,663.0 36.16 1 GAS LIFT DMY RK 1 1/2 0.0 10/26/2022 Schlumb
erger
MMG 0.000
2W-02, 12/19/2022 3:48:29 PM
Vertical schematic (actual)
PRODUCTION; 28.7-6,890.4
IPERF; 6,705.0-6,718.0
IPERF; 6,595.0-6,660.0
TUBING PLUG; 6,529.0
NIPPLE REDUCER; 6,529.2
NIPPLE; 6,529.1
PACKER; 6,515.7
CUT; 6,513.7
TUBING PLUG; 6,504.0
Nipple - Landing; 6,503.6
Packer; 6,490.4
WHIPSTOCK; 6,455.0
Slotted Liner; 6,450.4-12,000.0
WHIPSTOCK; 6,455.0
LINER TOP; 6,450.0
IPERF; 6,413.0-6,478.0
Nipple - Landing; 6,254.7
Packer; 6,225.5
Mandrel – GAS LIFT; 6,164.8
SURFACE; 30.2-3,118.6
Nipple - Landing; 478.1
CONDUCTOR; 31.0-110.0
Hanger; 26.7
KUP INJ
KB-Grd (ft)
34.50
RR Date
2/14/1985
Other Elev…
2W-02
...
TD
Act Btm (ftKB)
6,949.0
Well Attributes
Field Name
KUPARUK RIVER UNIT
Wellbore API/UWI
500292127900
Wellbore Status
INJ
Max Angle & MD
Incl (°)
40.35
MD (ftKB)
4,600.00
WELLNAME WELLBORE2W-02
Annotation
Last WO:
End Date
10/20/2022
H2S (ppm) DateComment
SSSV: LOCKED OUT
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
6,413.0 6,478.0 5,863.9 5,916.2 C-4, C-3, C-1,
UNIT B, 2W-02
3/16/1985 12.0 IPERF 120 deg. phasing, 5"
Dressler Atlas HD
6,595.0 6,660.0 6,009.7 6,061.4 A-4, A-3, 2W-02 3/16/1985 4.0 IPERF 120 deg. phasing, 4"
Dressler Atlas JJ
6,705.0 6,718.0 6,097.0 6,107.3 A-2, 2W-02 3/16/1985 4.0 IPERF 120 deg. phasing, 4"
Dressler Atlas JJ
2W-02, 12/19/2022 3:48:30 PM
Vertical schematic (actual)
PRODUCTION; 28.7-6,890.4
IPERF; 6,705.0-6,718.0
IPERF; 6,595.0-6,660.0
TUBING PLUG; 6,529.0
NIPPLE REDUCER; 6,529.2
NIPPLE; 6,529.1
PACKER; 6,515.7
CUT; 6,513.7
TUBING PLUG; 6,504.0
Nipple - Landing; 6,503.6
Packer; 6,490.4
WHIPSTOCK; 6,455.0
Slotted Liner; 6,450.4-12,000.0
WHIPSTOCK; 6,455.0
LINER TOP; 6,450.0
IPERF; 6,413.0-6,478.0
Nipple - Landing; 6,254.7
Packer; 6,225.5
Mandrel – GAS LIFT; 6,164.8
SURFACE; 30.2-3,118.6
Nipple - Landing; 478.1
CONDUCTOR; 31.0-110.0
Hanger; 26.7
KUP INJ 2W-02
...
WELLNAME WELLBORE2W-02
General Notes: Last 3 entries
Com Date Last Mod By
Top of liner left at 6450' CTMD. Fluids lost to the well bore during drilling, Power Pro Losses:
1816 bbls, NaBr Losses: 224 bbls, Seawater losses: 43 bbls
11/26/2022 ncdr3cm
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 6,450.4 12,000.0 5,874.4 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)
6,455.0 5,897.7 36.46 WHIPSTOCK 2.625" GEN II BAKER
HUGHES DELTA
WHIPSTOCK, TOWS AT
6455' PDC, OAL 12.97'
BAKER
HUGHE
S
GEN II
DELTA
H1505
04512
11/14/2022 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)
6,450.4 5,894.0 36.42 Deployment
Sleeve
2.375 Shorty deployment Sleeve Northern
Solutions
na 1.920
8,892.1 5,871.7 89.94 Deployment
Sleeve
2.375 NSAK 350-238 OH Permanent
QCLL
Northern
Solutions
na 1.920
10,684.0 5,887.9 90.57 Deployment
Sleeve
2.375 NSAK 350-238 OH Permanent
QCLL
Northern
Solutions
na 1.920
2W-02L1, 12/19/2022 3:48:30 PM
Vertical schematic (actual)
Slotted Liner; 6,450.4-12,000.0
WHIPSTOCK; 6,455.0
PRODUCTION; 28.7-6,890.4
WHIPSTOCK; 6,455.0
LINER TOP; 6,450.0
IPERF; 6,413.0-6,478.0
Nipple - Landing; 6,254.7
Packer; 6,225.5
Mandrel – GAS LIFT; 6,164.8
SURFACE; 30.2-3,118.6
Nipple - Landing; 478.1
CONDUCTOR; 31.0-110.0
Hanger; 26.7
KUP SVC
KB-Grd (ft)
34.50
RR Date
2/14/1985
Other Elev…
2W-02L1
...
TD
Act Btm (ftKB)
12,000.0
Well Attributes
Field Name
KUPARUK RIVER UNIT
Wellbore API/UWI
500292127960
Wellbore Status
SVC
Max Angle & MD
Incl (°)
101.31
MD (ftKB)
6,740.26
WELLNAME WELLBORE2W-02
Annotation End DateH2S (ppm) DateComment
2W-02 Proposed CTD Schematic
3-1/2" 9.3# L-80 EUE 8rd Tubing to surface
3-1/2" Camco MMG gas lift mandrels @ 6165' RKB
3-½" X landing nipple at 6256' RKB (2.813" min ID)
4.5" Centralized Big Tail Pipe (see details)
3.5" x 7.0" Packer @ 6490' RKB (4" ID)
7" 26# J-55 shoe @
9291' MD
A4-sand perfs
8928' - 8946' MD
9-5/8" 36# J-55 shoe
@ 4814' MD
16" 62# H-40 shoe
@ 115' MD
C1-sand perfs
8680'-8710' MD
KOP @ 6457' MD
2W-02L1
TD: 12,000' MD
Top of Slotted Liner ~6450' MD
Centralized Big Tail Pipe
* 4-1/2" 11.6# L-80 Base Pipe* 6.0" OD Maxwell Centralizers (36' long)* ~42' Total Length* Set up for 4.5" whipstock thru 3.5" tubing.
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1
Regg, James B (OGC)
From:Madson, Robert <Robert.Madson@nabors.com>
Sent:Saturday, November 19, 2022 12:11 PM
To:Brooks, Phoebe L (OGC)
Cc:DOA AOGCC Prudhoe Bay; Regg, James B (OGC); Company Man, Nabors CDR3; Hobbs, Greg S;
Kneale, Michael L
Subject:NABORS CDR3 BOP TEST REPORT 2W-02
Attachments:2W-02 BOP State Report 11-17-2022.xlsx
Categories:Blue Category
Please see attached BOP test report from CDR3 .
Thanks...
Maddy Madson
Rig Manager CDR3 AC
NABORS ALASKA DRILLING INC.
Direct 907.670.6082 I Mobil 907.360.9597
robert.madson@nabors.com I www.nabors.com
*******************************
NABORS EMAIL NOTICE - This transmission may be strictly proprietary and confidential. If you are not the intended
recipient, reading, disclosing, copying, distributing or using the contents of this transmission is prohibited. If you have
received this in error, please reply and notify the sender (only) and delete the message. Unauthorized interception of this
e-mail is a violation of federal criminal law. This communication does not reflect an intention by the sender or the sender's
principal to conduct a transaction or make any agreement by electronic means. Nothing contained in this message or in
any attachment shall satisfy the requirements for a writing, and nothing contained herein shall constitute a contract or
electronic signature under the Electronic Signatures in Global and National Commerce Act, any version of the Uniform
Electronic Transactions Act, or any other statute governing electronic transactions.
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.
KRU 2W-02L1
PTD 2221310
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
*All BOPE reports are due to the agency within 5 days of testing*
Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov
Rig Owner:Rig No.:CDR3AC DATE:11/17/22
Rig Rep.:Rig Email:
Operator:
Operator Rep.:Op. Rep Email:
Well Name:PTD #2221310 Sundry #
Operation:Drilling:X Workover:Explor.:
Test:Initial:X Weekly:Bi-Weekly:Other:
Rams:250/3500 Annular:250/2500 Valves:250/3500 MASP:2657
MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES:
Test Result/Type Test Result Quantity Test Result
Housekeeping P Well Sign P Upper Kelly 0 NA
Permit On Location P Hazard Sec.P Lower Kelly 0 NA
Standing Order Posted P Misc.NA Ball Type 2 P
Test Fluid Water Inside BOP 0 NA
FSV Misc 0 NA
BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm
Stripper 1 2"P Trip Tank NA NA
Annular Preventer 1 7 1/16"P Pit Level Indicators P P
#1 Rams 1 Blind Shear P Flow Indicator P P
#2 Rams 1 2" Combi P Meth Gas Detector P P
#3 Rams 1 2 3/8" Combi P H2S Gas Detector P P
#4 Rams 1 2" Combi P MS Misc 0 NA
#5 Rams 0 NA
#6 Rams 0 NA ACCUMULATOR SYSTEM:
Choke Ln. Valves 1 2 1/16"P Time/Pressure Test Result
HCR Valves 2 2 1/16"P System Pressure (psi)3050 P
Kill Line Valves 5 2 1/16"FP Pressure After Closure (psi)2300 P
Check Valve 0 NA 200 psi Attained (sec)19 P
BOP Misc 3 3 1/8"P Full Pressure Attained (sec)49 P
Blind Switch Covers:All stations Yes
CHOKE MANIFOLD:Bottle Precharge:P
Quantity Test Result Nitgn. Bottles # & psi (Avg.):4@1700 P
No. Valves 12 P ACC Misc 0 NA
Manual Chokes 1 P
Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result
CH Misc 0 NA Annular Preventer 13 P
#1 Rams 3 P
Coiled Tubing Only:#2 Rams 4 P
Inside Reel valves 1 P #3 Rams 4 P
#4 Rams 4 P
Test Results #5 Rams 0 NA
#6 Rams 0 NA
Number of Failures:1 Test Time:7.5 HCR Choke 2 P
Repair or replacement of equipment will be made within Same days. HCR Kill 2 P
Remarks:
AOGCC Inspection
24 hr Notice Yes Date/Time 11-15-22 15:05
Waived By
Test Start Date/Time:11/17/2022 3:00
(date)(time)Witness
Test Finish Date/Time:11/17/2022 10:30
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Sully Sullivan
Nabors
Romeo 3 fail/pass. Grease valve. Re test. Good test. Pit level alarms tested, LEL and H2S alarms tested. Verified flow through
Micromotion.
R.Madson / K.Enfield-Ayon
Conoco Phillips Alaska
P.Klein / C.Erdman
KRU 2W-02L1
Test Pressure (psi):
dr3.toolpusher@conocophillips.co
3.companyman@conocophillips.c
Form 10-424 (Revised 08/2022)2022-1117_BOP_Nabors_CDR3AC_KRU_2W-02L1
J. Regg; 12/27/2022
From:Brooks, James S (OGC) on behalf of AOGCC Reporting (CED sponsored)
To:AOGCC Records (CED sponsored)
Subject:FW: BOP - Nabors CDR3AC
Date:Wednesday, December 28, 2022 9:31:15 AM
Attachments:2022-1117_BOP_Nabors_CDR3AC_KRU_2W-02L1.pdf
James Brooks
research analyst II | alaska oIl and Gas conservatIon commIssIon
department of commerce, communIty and economIc development
907-793-1241|James.Brooks@alaska.Gov
From: Regg, James B (OGC) <jim.regg@alaska.gov>
Sent: Tuesday, December 27, 2022 2:59 PM
To: AOGCC Reporting (CED sponsored) <aogcc.reporting@alaska.gov>
Subject: BOP - Nabors CDR3AC
KRU 2W-02L1 (PTD 2221310)
Jim Regg
Supervisor, Inspections
AOGCC
333 W. 7th Ave, Suite 100
Anchorage, AK 99501
907-793-1236
T + 1 337.856-7201
1058 Baker Hughes Drive
Broussard, LA 70518, USA
Dec 27, 2022
AOGCC
Attention: Kayla Junke
333 W. 7th Ave., Suite 100
Anchorage, Alaska 99501-3539
Subject:Final Log Distribution for ConocoPhillips Alaska, Inc.
2W-02L1
Kuparuk River
API #: 50-029-21279-60-00
Permit No: 222-131
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 8:58 am, Dec 29, 2022
222-131
T37399
Meredith Guhl Digitally signed by Meredith Guhl
Date: 2022.12.29 09:00:44 -09'00'
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
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WELL PERMIT CHECKLISTCompanyConocoPhillips Alaska, Inc.Well Name:KUPARUK RIV UNIT 2W-02L1Initial Class/TypeSER / PENDGeoArea890Unit11160On/Off ShoreOnProgramSERField & PoolWell bore segAnnular DisposalPTD#:2221310KUPARUK RIVER, KUPARUK RIV OIL - 490100NA1Permit fee attachedYesEntire Well lies within ADL0025642.2Lease number appropriateYes3Unique well name and numberYesKuparuk River Oil Pool, governed by CO 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 waitYesArea Injection Order No. 2C - Kuparuk River Unit14Well located within area and strata authorized by Injection Order # (put IO# in comments) (ForYesKRU 2W-01 (185-010), KRU 2W-02 (185-016), KRU 2W-13 (184-236), KRU 2W-14 (184-237),15All wells within 1/4 mile area of review identified (For service well only)NoKRU 2W-15 (184-238), KRU 2W-16 (184-239)16Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)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 reservoir pressurre is 3246 psig(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 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)NoMeasures required: 2W-Pad wells reported 72 to 136 ppm H2S in Dec. 2020.35Permit can be issued w/o hydrogen sulfide measuresYesExpected reservoir pressure is 10.6 ppg EMW. Managed Pressure Drilling Practice will be utilized with36Data presented on potential overpressure zonesNA8.6 ppg mud to maintain a constant bottom-hole pressure of 11.8 ppg EMW at the window and to37Seismic analysis of shallow gas zonesNAensure wellbore stability.38Seabed condition survey (if off-shore)NA39Contact name/phone for weekly progress reports [exploratory only]ApprSFDDate10/21/2022ApprVTLDate10/24/2022ApprSFDDate10/21/2022AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDateJLC 10/25/2022
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