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By James Brooks at 7:59 am, Sep 27, 2022
Completed
8/26/2022
JSB
RBDMS JSB 10132022
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Digitally signed by Elliott Tuttle
DN: C=US, OU=CTD/ RWO Drilling Engineer, O="Conoco Phillips, Inc", CN=Elliott Tuttle,
E=elliott.tuttle@conocophillips.com
Reason: I am the author of this document
Location: Anchorage, AKDate: 2022.09.26 09:54:23-08'00'Foxit PDF Editor Version: 11.2.1
Elliott Tuttle
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag: ELM 9,775.0 3G-20 7/4/2022 pproven
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Set Northern Solutions LTP 3G-20 8/29/2022 zembaej
Notes: General & Safety
Annotation End Date Last Mod By
NOTE:8/31/2010 pproven
Casing Strings
Casing Description
CONDUCTOR
OD (in)
16
ID (in)
15.06
Top (ftKB)
36.0
Set Depth (ft…
115.0
Set Depth …
115.0
Wt/Len (lb/ft)
62.58
Grade
H-40
Top Connection
WELDED
Casing Description
SURFACE
OD (in)
9 5/8
ID (in)
8.92
Top (ftKB)
35.0
Set Depth (ft…
4,675.6
Set Depth …
3,220.2
Wt/Len (lb/ft)
36.00
Grade
J-55
Top Connection
BUTT
Casing Description
PRODUCTION
OD (in)
7
ID (in)
6.28
Top (ftKB)
33.0
Set Depth (ft…
10,100.0
Set Depth …
6,075.0
Wt/Len (lb/ft)
26.00
Grade
J-55
Top Connection
AB-MOD
Tubing Strings: string max indicates LONGEST segment of string
Top (ftKB)
31.3
Set Depth …
5,810.0
String Ma…
3 1/2
Tubing Description
TUBING
Set Depth (ftKB)
9,601.6
Wt (lb/ft)
9.30
Grade
J-55
Top Connection
EUE-MOD
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)
31.3 31.3 0.09 HANGER 8.000 WKM GEN IV HANGER 3.500
1,803.6 1,596.4 47.61 SAFETY VLV 5.620 OTIS FMX SERIES 10 SAFETY
VALVE (LOCKED OUT 4/11/2009)
Flapper & control line exposed to
wellbore psi
2.813
3,047.7 2,299.8 56.67 GAS LIFT 5.620 MERLA TMPD 2.875
5,328.6 3,611.6 54.73 GAS LIFT 5.620 MERLA TMPD 2.875
6,498.4 4,214.9 60.83 GAS LIFT 5.620 MERLA TMPD 2.875
7,302.5 4,613.0 59.88 GAS LIFT 5.620 MERLA TMPD 2.875
8,107.6 5,013.3 58.81 GAS LIFT 5.620 MERLA TMPD 2.875
8,756.7 5,356.3 57.39 GAS LIFT 5.620 MERLA TMPD 2.875
9,508.6 5,760.6 57.88 GAS LIFT 5.687 MACCO SMP-2 2.867
9,561.9 5,788.9 57.88 PBR 5.625 OTIS OEJ 10' STROKE PBR 4 1/16"
SEAL BORE
2.937
9,574.9 5,795.8 57.88 PACKER 5.937 CAMCO HRP-1-SP RETRIEVABLE
PACKER
2.867
9,591.2 5,804.5 57.88 NIPPLE 4.540 CAMCO D NIPPLE NO GO(Milled
out 5/17/22 was 2.75)
2.800
9,600.8 5,809.6 57.88 SOS 4.500 BAKER SHEAR OUT SUB 2.992
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top (ftKB)
Top (TVD)
(ftKB) Top Incl (°) Des Com Make Model SN ID (in)
9,588.0 5,802.8 57.88 PACKER 2.72" NORTHERN SOLUTIONS
MONO PAK LINER TOP PACKER
W/ 1.78" RX NIPPLE (9.4' OAL / 8'
FROM FISH NECK TO RX
NIPPLE)
1.780
9,736.0 5,881.5 57.88 WHIPSTOCK HEW set @ 9736 TOWS Northern
Solutions
HEW 0.000
9,827.0 5,929.9 57.88 FISH 10.9' Dyna Star Strip Left in Well
(8/7/91)
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)
3,047.7 2,299.8 56.67 1 GAS LIFT DMY BK 1 0.0 1/3/1991 0.000
5,328.6 3,611.6 54.73 2 GAS LIFT DMY BK 1 0.0 1/3/1991 0.000
6,498.4 4,214.9 60.83 3 GAS LIFT DMY BK 1 0.0 1/3/1991 0.000
7,302.5 4,613.0 59.88 4 GAS LIFT DMY BK 1 0.0 1/3/1991 0.000
8,107.6 5,013.3 58.81 5 GAS LIFT DMY BK 1 0.0 1/3/1991 0.000
8,756.7 5,356.3 57.39 6 GAS LIFT DMY BK 1 0.0 1/3/1991 0.000
9,508.6 5,760.6 57.88 7 GAS LIFT DMY RK 0.0 0.0 12/26/2014 0.000
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
9,686.0 9,700.0 5,854.9 5,862.3 C-4, UNIT B, 3G
-20
8/9/1991 8.0 APERF 90 deg ph; 2 1/8" Dyna Strip
9,720.0 9,760.0 5,873.0 5,894.2 A-4, A-3, 3G-20 8/8/1991 8.0 APERF 90 deg ph; 2 1/8" Dyna Strip
9,780.0 9,820.0 5,904.9 5,926.1 A-2, 3G-20 1/2/1991 4.0 IPERF 180 deg. ph; 4.5" Hollow
Carrier
3G-20, 9/21/2022 3:05:07 PM
Vertical schematic (actual)
PRODUCTION; 33.0-10,100.0
FISH; 9,827.0
IPERF; 9,780.0-9,820.0
WHIPSTOCK; 9,736.0
APERF; 9,720.0-9,760.0
APERF; 9,686.0-9,700.0
Slotted Liner; 9,593.3-12,439.0
PACKER; 9,588.0
PACKER; 9,574.9
GAS LIFT; 9,508.7
GAS LIFT; 8,756.7
GAS LIFT; 8,107.6
GAS LIFT; 7,302.5
GAS LIFT; 6,498.4
GAS LIFT; 5,328.6
SURFACE; 35.0-4,675.6
GAS LIFT; 3,047.7
SAFETY VLV; 1,803.6
CONDUCTOR; 36.0-115.0
KUP INJ
KB-Grd (ft)
37.01
RR Date
9/13/1990
Other Elev…
3G-20
...
TD
Act Btm (ftKB)
10,100.0
Well Attributes
Field Name
KUPARUK RIVER UNIT
Wellbore API/UWI
501032014100
Wellbore Status
INJ
Max Angle & MD
Incl (°)
60.84
MD (ftKB)
6,500.00
WELLNAME WELLBORE3G-20
Annotation
Last WO:
End DateH2S (ppm) DateComment
SSSV: LOCKED OUT
Casing Strings
Casing Description
Slotted Liner
OD (in)
2.7
ID (in)
1.69
Top (ftKB)
9,593.3
Set Depth (ft…
12,439.0
Set Depth …
5,906.2
Wt/Len (lb/ft)
3.25
Grade
L-80
Top Connection
ST-L
Liner Details: excludes liner, pup, joints, casing, sub , shoe , float...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des Com Make Model
Nominal ID
(in)
9,813.3 5,906.6 86.60 Packer - Swell Swell Packer - PESI Reactive Swell
Pkr.
1.992
11,366.0 5,930.7 87.42 Deployment Sleeve NSAK 350-238 OH Permanent QCLL Nothern
Solution
s
QCLL 1.992
3G-20L1, 9/21/2022 3:05:08 PM
Vertical schematic (actual)
Slotted Liner; 9,593.3-12,439.0
PRODUCTION; 33.0-10,100.0
PACKER; 9,588.0
PACKER; 9,574.9
GAS LIFT; 9,508.7
GAS LIFT; 8,756.7
GAS LIFT; 8,107.6
GAS LIFT; 7,302.5
GAS LIFT; 6,498.4
GAS LIFT; 5,328.6
SURFACE; 35.0-4,675.6
GAS LIFT; 3,047.7
SAFETY VLV; 1,803.6
CONDUCTOR; 36.0-115.0
KUP SVC
KB-Grd (ft)
37.01
RR Date
9/13/1990
Other Elev…
3G-20L1
...
TD
Act Btm (ftKB)
12,432.0
Well Attributes
Field Name
KUPARUK RIVER UNIT
Wellbore API/UWI
501032014160
Wellbore Status
SVC
Max Angle & MD
Incl (°)
98.88
MD (ftKB)
12,189.73
WELLNAME WELLBORE3G-20
Annotation End DateH2S (ppm) DateComment
Page 1/8
3G-20
Report Printed: 9/21/2022
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)
8/18/2022
00:00
8/18/2022
04:00
4.00 MIRU, MOVE DMOB P Disconnected Tiger tank line
Removed ground strap
Romeo valves, Inner reel valve and
choke manifold are greased
Checked pre-charge on koomey bottles
Prep for moving off well, laid out dance
floor
RD PUTZ and secure landing and
stairways
Warmed up jacks, sercured shop and
halfway house for move
0.0 0.0
8/18/2022
04:00
8/18/2022
08:30
4.50 MIRU, MOVE MOB P Trucks on location, PJSM
Move off well , leap frog mats around
pad to pull sub off well // install jeeps
and clean up around well, prep for mob
to 3G
0.0 0.0
8/18/2022
08:30
8/18/2022
13:30
5.00 MIRU, MOVE MOB P Mob rig from 3R to 3G 0.0 0.0
8/18/2022
13:30
8/18/2022
14:00
0.50 MIRU, MOVE MOB P Remove jeeps // prep well for backing
over well
0.0 0.0
8/18/2022
14:00
8/18/2022
15:15
1.25 MIRU, MOVE RURD P Spot sub over well // spot mats under
sub // set down and level
0.0 0.0
8/18/2022
15:15
8/18/2022
16:30
1.25 MIRU, MOVE RURD P Set inside mats for pits // spot pits // set
mats around pits
0.0 0.0
8/18/2022
16:30
8/18/2022
18:00
1.50 MIRU, MOVE RURD P Rig up checklists // Safe out rig // set
tiger tank // set drilling support materials
and mats around rig
0.0 0.0
8/18/2022
18:00
8/18/2022
20:30
2.50 MIRU, MOVE RURD P Come online with steam/air/water
Prep pad for support modules
Spot in Halway house and shop
0.0 0.0
8/18/2022
20:30
8/18/2022
23:00
2.50 MIRU, MOVE RURD P Secure cellar, call out KDTH to help
inspect scaffolding, make modifications
Hook up manage pressure line, lift
scaffolding off SSSV, prep WH for stack
Load SW into pits 200 bbls
Load Milling Fluid 271 bbls
0.0 0.0
8/18/2022
23:00
8/19/2022
00:00
1.00 MIRU, MOVE NUND P Nipple up stack, grease stack, unlock
Koomey unit
Stab
Rig Accepted 0000 8/19/2022
0.0 0.0
8/19/2022
00:00
8/19/2022
00:45
0.75 MIRU, WHDBOP CTOP P Install QTS, obtain RKB's, Fluid pack
surface lines, coil reel, stack. Obtain
containment test 2,500 psi (good)
0.0 0.0
8/19/2022
00:45
8/19/2022
01:45
1.00 MIRU, WHDBOP CTOP P Prep coil, stab INJH, perform slack
management @ 2.8 bpm, (heard wire
move ~5-7 sec., unstab INJH, rig up
tubing cutter, trim coil to find wire 68',
trim addtional 7' to find clean pipe,
*** New Coil Length = 15,425'
0.0 0.0
8/19/2022
01:45
8/19/2022
03:15
1.50 MIRU, WHDBOP CTOP P Dress free end of coil, install CTC, pull
test CTC 35 k CTSW
0.0 0.0
8/19/2022
03:15
8/19/2022
04:00
0.75 MIRU, WHDBOP CTOP P Re-head BHI Upper quick 0.0 0.0
8/19/2022
04:00
8/19/2022
04:24
0.40 MIRU, WHDBOP CTOP P PT re-head, 4,500 psi, (good test),
remove test plate
0.0 0.0
8/19/2022
04:24
8/19/2022
06:00
1.60 MIRU, WHDBOP CTOP P Obtain Shell test // Swab 2 leaking
grease crew called move on to BOP test
0.0 0.0
Rig: NABORS CDR3-AC
RIG RELEASE DATE 8/26/2022
Page 2/8
3G-20
Report Printed: 9/21/2022
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)
8/19/2022
06:00
8/19/2022
16:00
10.00 MIRU, WHDBOP BOPE P BOP test wintess by Adam Earl
250/3500 psi
Test 1. Swab 2 - Fail/Pass Greased re-
test good
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
Test 5. Romeo 3, Bleeder 3, Tango 2,
Charlie 2, & 10
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 – swap out 2” test joint
for 2-3/8”
Test 11. 2-3/8” pipe slip rams, TIW#2 –
check N2 levels, swap to 2” test joint
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
8/19/2022
16:00
8/19/2022
21:30
5.50 MIRU, WHDBOP BOPE T Replace B5 and retest and chart 0.0 0.0
8/19/2022
21:30
8/19/2022
22:15
0.75 MIRU, WHDBOP CTOP P Line up to pump 1 coil volume forward
to completion slack management.
0.0 0.0
8/19/2022
22:15
8/19/2022
23:45
1.50 MIRU, WHDBOP CTOP P Test Tiger tank line and PDL's, blow
down TT Line
0.0 0.0
8/19/2022
23:45
8/20/2022
00:00
0.25 MIRU, WHDBOP CTOP P Line up, open up well
WHP = 2,245 psi
0.0 0.0
8/20/2022
00:00
8/20/2022
00:30
0.50 PROD1, RPEQPT BHAH P Close well in, bleed pressure off 2,245
psi,
PJSM, load PDL, MU motor, under-
reamer, and jars up in pipeshed
*** Note: WHP 2,245 psi
0.0 0.0
8/20/2022
00:30
8/20/2022
02:45
2.25 PROD1, RPEQPT PULD P PD BHA #1, w/Under-reamer 7" blades
(6.1"-6.151"), 2.13" OD BOT Motor, jars,
and BHI CoilTrak tools.
Install upper float valves into upper
quick
0.0 60.2
8/20/2022
02:45
8/20/2022
04:45
2.00 PROD1, RPEQPT TRIP P Tag up, reset counters, RIH 60.2 9,560.0
8/20/2022
04:45
8/20/2022
08:00
3.25 PROD1, RPEQPT DLOG P Log formation// Log HRZ and K1 and C
sand confirm depth correction +34 // drift
to 9800 confirm clean pass for CCL //
9,560.0 9,800.0
8/20/2022
08:00
8/20/2022
08:54
0.90 PROD1, RPEQPT CIRC P Circulate Milling fluid into well 9,800.0 9,800.0
8/20/2022
08:54
8/20/2022
10:30
1.60 PROD1, RPEQPT REAM P Under ream
F/ 9719 T/ 9761' .8 bpm 2604pp 505
diff
3 Passes down
9,719.0 9,761.0
8/20/2022
10:30
8/20/2022
12:06
1.60 PROD1, RPEQPT TRIP P POOH w/ open EDC for WS setting
tools // Tag up space out 1.2' //
9,761.0 75.0
8/20/2022
12:06
8/20/2022
13:30
1.40 PROD1, RPEQPT PULD P PJSM // PUD BHA# 1 Underreamer 75.0 0.0
Rig: NABORS CDR3-AC
RIG RELEASE DATE 8/26/2022
Page 3/8
3G-20
Report Printed: 9/21/2022
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)
8/20/2022
13:30
8/20/2022
15:00
1.50 PROD1, RPEQPT PULD P PD BHA# 2 HEW Setting Assembly 0.0 75.0
8/20/2022
15:00
8/20/2022
17:00
2.00 PROD1, RPEQPT TRIP P RIH w/ HEW 75.0 9,200.0
8/20/2022
17:00
8/20/2022
17:12
0.20 PROD1, RPEQPT DLOG P Log the HRZ, - 8.0' 9,200.0 9,265.0
8/20/2022
17:12
8/20/2022
17:18
0.10 PROD1, RPEQPT TRIP P RIH 9,265.0 9,700.0
8/20/2022
17:18
8/20/2022
17:30
0.20 PROD1, RPEQPT DLOG P Log C Sand + 3.0' 9,700.0 9,730.2
8/20/2022
17:30
8/20/2022
17:42
0.20 PROD1, RPEQPT TRIP P RIH to set point 9,730.2 9,743.8
8/20/2022
17:42
8/20/2022
17:54
0.20 PROD1, RPEQPT TRIP P PUH 9,744.0 9,700.0
8/20/2022
17:54
8/20/2022
18:12
0.30 PROD1, RPEQPT DLOG P Log CCL 9,700.0 9,780.0
8/20/2022
18:12
8/20/2022
18:18
0.10 PROD1, RPEQPT TRIP P PUH 9,780.0 9,743.8
8/20/2022
18:18
8/20/2022
18:30
0.20 PROD1, RPEQPT CTOP P Close EDC, pressure up slowly 0.6 bpm
to shear pressure 4,100 psi.
Set down 5 k DHWOB
9,743.8 9,735.0
8/20/2022
18:30
8/20/2022
20:30
2.00 PROD1, RPEQPT TRIP P POOH, PUW 33 k 9,735.0 73.0
8/20/2022
20:30
8/20/2022
21:42
1.20 PROD1, WHPST BHAH P Tag up, spaceout, PUD/LD BHA #2,
HEW setting tools
73.0 0.0
8/20/2022
21:42
8/20/2022
22:00
0.30 PROD1, WHPST BHAH P PD, milling assembly BHA #3 0.0 77.2
8/20/2022
22:00
8/20/2022
22:45
0.75 PROD1, WHPST RGRP P Pause step #67, finish servicing INJH,
coupler on righ angle drive slipped, re-
adjust and tighten back up
77.2 77.2
8/20/2022
22:45
8/20/2022
23:54
1.15 PROD1, WHPST BHAH P Continue PD, inspect pac-off (good) 77.2 77.2
8/20/2022
23:54
8/21/2022
00:00
0.10 PROD1, WHPST TRIP P Tag up, reset counter depths 77.2 77.2
8/21/2022
00:00
8/21/2022
01:48
1.80 PROD1, WHPST TRIP P RIH with Window Milling assembly BHA
#3
77.2 9,562.0
8/21/2022
01:48
8/21/2022
02:00
0.20 PROD1, WHPST TRIP P Set down PBR 2.867" ID TF @ 90°
ROHS
PUH clean
RBIH slowly rotating TF 0° High Side
Pass by, continue IH
9,562.0 9,670.0
8/21/2022
02:00
8/21/2022
02:12
0.20 PROD1, WHPST DLOG P Log formation Lower Kalubik Gamma
Ray Marker
Correction -7'
9,670.0 9,721.0
8/21/2022
02:12
8/21/2022
02:18
0.10 PROD1, WHPST TRIP P PUW 34 k, Close EDC 9,721.0 9,721.0
8/21/2022
02:18
8/21/2022
02:30
0.20 PROD1, WHPST TRIP P Continue IH to find pinch point 9,721.0 9,740.0
8/21/2022
02:30
8/21/2022
09:24
6.90 PROD1, WHPST MILL P PUH, get pump parameters
1.83 bpm/4,278 psi/WHP 321, BHP
3,808, IA 293, OA 0
Start milling exit @ 9,739.3'
Exit Pipe start drilling rat hole 9742.6'
9,740.0 9,756.0
8/21/2022
09:24
8/21/2022
14:24
5.00 PROD1, WHPST WAIT T Power failure on 3 side black out rig,
canrig system would not come on line,
Houston working on issue re-load
program into canrig computer
9,756.0 9,756.0
8/21/2022
14:24
8/21/2022
16:24
2.00 PROD1, WHPST WPST P Continue milling rat hole 9,756.0 9,768.4
Rig: NABORS CDR3-AC
RIG RELEASE DATE 8/26/2022
Page 4/8
3G-20
Report Printed: 9/21/2022
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)
8/21/2022
16:24
8/21/2022
16:42
0.30 PROD1, WHPST WPST P Ream passes, HS, 30° ROHS, 30°
LOHS, 180°
Dry drift eixt clean to bottom 9,768'
9,768.4 9,768.4
8/21/2022
16:42
8/21/2022
18:27
1.75 PROD1, WHPST TRIP P POOH
Pull tight @ 9,562', 9,509'
Stuck/stalled motor/bit stuck @ 8,757'
Work pipe and pump weak point is the
BHI HOT tool @ -19k, Motor @ +12,5K
9,768.4 8,757.0
8/21/2022
18:27
8/21/2022
20:27
2.00 PROD1, WHPST TRIP P Continue OOH clean past all remaining
jewelry.
8,757.0 77.2
8/21/2022
20:27
8/21/2022
21:39
1.20 PROD1, DRILL BHAH P At surface, spaceout, PUD/LD milling
assembly BHA #3
*** Note: Mills Gauged 2.80" no-go
77.2 0.0
8/21/2022
21:39
8/21/2022
23:09
1.50 PROD1, DRILL CTOP T Dicuss plan forward with Town Team,
dession was made to make a Cleanout
Run
Call out Quadco w/2.625" Venturi, 2
instring flow through magnets, 3' barrel,
and 30° mule shoe
0.0 0.0
8/22/2022
00:00
8/22/2022
00:45
0.75 PROD1, DRILL WAIT T Wait on tools
Service Rig Equipment, INJH
0.0 0.0
8/22/2022
00:45
8/22/2022
01:15
0.50 PROD1, DRILL CTOP T Quadco, tools on location, load into
pipeshed
0.0 0.0
8/22/2022
01:15
8/22/2022
02:27
1.20 PROD1, DRILL BHAH T MU/PD cleanout assembly BHA #4
w/Ventrui
Surface test BHI CoilTrak tools (good)
0.0 53.6
8/22/2022
02:27
8/22/2022
04:42
2.25 PROD1, DRILL TRIP T Tag up, reset counter depths,RIH 0.0 9,655.0
8/22/2022
04:42
8/22/2022
05:00
0.30 PROD1, DRILL DLOG T Log formation (LKGR) for depth control
Correction of - 5.0'
9,655.0 9,691.0
8/22/2022
05:00
8/22/2022
05:18
0.30 PROD1, DRILL TRIP T Continue IH, set down 9,737', PUH, try
again set down same spot 9,736'
9,691.0 9,736.0
8/22/2022
05:18
8/22/2022
07:18
2.00 PROD1, DRILL TRIP T POOH, PUW 32 k CTSW 9,736.0 55.4
8/22/2022
07:18
8/22/2022
08:33
1.25 PROD1, DRILL PULD T At surface, spaceout, PUD Cleanout
Assembly // Found sheer bolt from
setting assembly in venturi basket
55.4 0.0
8/22/2022
08:33
8/22/2022
10:33
2.00 PROD1, DRILL PULD T Pickup HOT add to assembly // PD
BHA# 5
0.0 64.0
8/22/2022
10:33
8/22/2022
12:33
2.00 PROD1, DRILL TRIP T RIH w/ Venturi 64.0 9,670.0
8/22/2022
12:33
8/22/2022
12:48
0.25 PROD1, DRILL DLOG T Log LKGR for -6.5' correction 9,670.0 9,700.0
8/22/2022
12:48
8/22/2022
13:03
0.25 PROD1, DRILL FISH T Venturi down to botttom of HEW trey 9,700.0 9,742.0
8/22/2022
13:03
8/22/2022
15:03
2.00 PROD1, DRILL TRIP T POOH for build assembly 9,742.0 64.0
8/22/2022
15:03
8/22/2022
16:21
1.30 PROD1, DRILL PULD T Tag up space out 1.2' // PJSM // PUD
BHA# 5 Venturi w/ HOT
64.0 0.0
8/22/2022
16:21
8/22/2022
16:51
0.50 PROD1, DRILL CIRC P Flush Stack 0.0 0.0
8/22/2022
16:51
8/22/2022
18:36
1.75 PROD1, DRILL PULD P PD BHA# 6 Build Assembly 2.4°+ AKO
motor w/ Dynamus Bit
0.0 75.0
8/22/2022
18:36
8/22/2022
20:51
2.25 PROD1, DRILL TRIP P RIH w/ build assembly // Tie in -7' //
continue through window clean // Up wt
window 34K
75.0 9,680.0
8/22/2022
20:51
8/23/2022
00:00
3.15 PROD1, DRILL DRLG P OBD F/ 9768' T/ 242
1.85bpm 4188pp 624diff 3681 ann
9,680.0 9,979.0
8/23/2022
00:00
8/23/2022
00:45
0.75 PROD1, DRILL DRLG P OBD, 1.84 BPM/4,183 psi, WHP 216,
BHP 3,718, IA 317, OA 0
9,979.0 10,150.0
Rig: NABORS CDR3-AC
RIG RELEASE DATE 8/26/2022
Page 5/8
3G-20
Report Printed: 9/21/2022
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)
8/23/2022
00:45
8/23/2022
02:33
1.80 PROD1, DRILL DRLG P BHA wiper up hole, PUW 38 k
Fighting weight transfer BHA Wipers @
10,195' and 10,272'
10,150.0 10,290.0
8/23/2022
02:33
8/23/2022
05:33
3.00 PROD1, DRILL TRIP P TD build section, Wiper to the wiindow,
PUW 38 k
Jog the 7inch with sweep 5x5
Pull tight @ 9,509'
Continue pulling to surface
*** Note: Avg DLGS 42.92°
*** Note: Pull tight @ 9,509', rotate TF
30 ROHS to pass
10,290.0 72.2
8/23/2022
05:33
8/23/2022
07:03
1.50 PROD1, DRILL BHAH P At surface, spaceout, PUD BHA #6 Build
Assembly
*** Note: Sim-ops blow down return MM
72.2 0.0
8/23/2022
07:03
8/23/2022
08:33
1.50 PROD1, DRILL BHAH P PD Lateral ERD drilling assembly BHA
#7
0.0 80.2
8/23/2022
08:33
8/23/2022
10:21
1.80 PROD1, DRILL TRIP P Tag up, reset coutner dephts RIH 80.2 9,685.0
8/23/2022
10:21
8/23/2022
10:33
0.20 PROD1, DRILL DLOG P Log formation for depth control - 7.0'
Close EDC, PUW 36 k CTSW
9,685.0 9,723.7
8/23/2022
10:33
8/23/2022
10:45
0.20 PROD1, DRILL CTOP P Obtain static pressure above window
*** 12.011 ppg, 3,649 psi, TVD 5,847.97'
9,723.7 9,723.7
8/23/2022
10:45
8/23/2022
10:57
0.20 PROD1, DRILL DLOG P Log RA marker
Offical Window Depths
TOWS 9,736'
TOW 9,740'
RA/BOW 9,743'
9,723.7 9,765.0
8/23/2022
10:57
8/23/2022
11:15
0.30 PROD1, DRILL TRIP P RIH 9,765.0 10,290.0
8/23/2022
11:15
8/23/2022
13:15
2.00 PROD1, DRILL DRLG P OBD, 1.8 bpm/4,023 psi/Diff 830, WHP
248, BHP 3,747, IA 266. OA 0
10,290.0 10,600.0
8/23/2022
13:15
8/23/2022
14:00
0.75 PROD1, DRILL DRLG P OBD, 1.83 bpm/4,226 psi/Diff 1,003 10,600.0 10,700.0
8/23/2022
14:00
8/23/2022
14:15
0.25 PROD1, DRILL WPRT P Wiper trip to the EOB
PUW 38 k CTSW
10,700.0 10,295.0
8/23/2022
14:15
8/23/2022
14:30
0.25 PROD1, DRILL WPRT P Wiper back in hole, RIW 9 k CTSW 10,295.0 10,700.0
8/23/2022
14:30
8/23/2022
16:30
2.00 PROD1, DRILL DRLG P BOBD, 1.8 bpm/4,052 psi/DIff 754, WHP
278, BHP 3,825, IA 278, OA 0
10,700.0 10,800.0
8/23/2022
16:30
8/23/2022
18:00
1.50 PROD1, DRILL DRLG P OBD, 1.81 bpm/4,142 psi/Diff 888, WHP
424, BHP 3,803, IA 289, OA 0
10,800.0 11,100.0
8/23/2022
18:00
8/23/2022
18:45
0.75 PROD1, DRILL WPRT P 750' wiper 11,100.0 11,100.0
8/23/2022
18:45
8/23/2022
22:00
3.25 PROD1, DRILL DRLG P BOBD F/ 11100 T/ 11500
1.82bpm 4050pp 725diff 3833ann
11,100.0 11,500.0
8/23/2022
22:00
8/23/2022
23:09
1.15 PROD1, DRILL WPRT P Wiper to window for tie in // Jet 7" // Tie
in LKGR +4' correction //
11,500.0 9,740.0
8/23/2022
23:09
8/24/2022
00:00
0.85 PROD1, DRILL TRIP P Trip in hole to drill ahead 9,740.0 11,500.0
8/24/2022
00:00
8/24/2022
04:30
4.50 PROD1, DRILL DRLG P OBD F/ 11500 T/11,900'
1.81bpm 4160pp 672diff 3892ann
11,500.0 11,900.0
8/24/2022
04:30
8/24/2022
05:00
0.50 PROD1, DRILL WPRT P 11,900', 800' wiper, PUW 44 k CTSW 11,900.0 11,100.0
8/24/2022
05:00
8/24/2022
05:18
0.30 PROD1, DRILL WPRT P 11,100', Wiper back in hole, RIW 8 k
CTSW
11,100.0 11,900.0
8/24/2022
05:18
8/24/2022
06:48
1.50 PROD1, DRILL DRLG P BOBD, 1.78 bpm/4,583 psi/Diff 825,
WHP 197, BHP 3,948, IA 305, OA 2
11,900.0 12,033.0
Rig: NABORS CDR3-AC
RIG RELEASE DATE 8/26/2022
Page 6/8
3G-20
Report Printed: 9/21/2022
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)
8/24/2022
06:48
8/24/2022
07:06
0.30 PROD1, DRILL WPRT P 1000' wiper from 12,033', PUW 40 k
CTSW
12,033.0 11,000.0
8/24/2022
07:06
8/24/2022
07:24
0.30 PROD1, DRILL WPRT P Wiper back in hole, RIW 8 k CTSW 11,000.0 12,033.0
8/24/2022
07:24
8/24/2022
08:48
1.40 PROD1, DRILL DRLG P BOBD, 1.82 bpm/4,646 psi/Diff 825,
WHP 224, BHP 3,941, IA 306, OA 0
12,033.0 12,108.0
8/24/2022
08:48
8/24/2022
09:00
0.20 PROD1, DRILL WPRT P 200' Wiper up hole, PUW 40 k 12,108.0 11,874.0
8/24/2022
09:00
8/24/2022
09:12
0.20 PROD1, DRILL WPRT P Wiper back in hole, RIW 8 k CTSW 11,874.0 12,108.0
8/24/2022
09:12
8/24/2022
09:27
0.25 PROD1, DRILL DRLG P BOBD, 1.9 bpm/4,663 psi/Diff 902, WHP
222, BHP 3,956, IA 306, OA 0
12,108.0 12,117.0
8/24/2022
09:27
8/24/2022
09:42
0.25 PROD1, DRILL WPRT P 200' Wiper up hole do to weight transfer,
PUW 43 k CTSW
12,117.0 12,117.0
8/24/2022
09:42
8/24/2022
11:18
1.60 PROD1, DRILL DRLG P BOBD, 1.9 bpm/4,663 psi/Diff 902, WHP
515, BHP 3,956, IA 300, OA 0
12,117.0 12,194.0
8/24/2022
11:18
8/24/2022
11:36
0.30 PROD1, DRILL WPRT P 200' Wiper up hole do to weight transfer,
PUW 44 k CTSW
12,194.0 12,194.0
8/24/2022
11:36
8/24/2022
12:06
0.50 PROD1, DRILL DRLG P BOBD, 1.9 bpm/4,663 psi/Diff 845, WHP
491, BHP 3,956, IA 294, OA 0
12,194.0 12,221.0
8/24/2022
12:06
8/24/2022
12:24
0.30 PROD1, DRILL WPRT P 200' Wiper up hole do to weight transfer,
PUW 48 k CTSW
12,221.0 12,221.0
8/24/2022
12:24
8/24/2022
14:09
1.75 PROD1, DRILL DRLG P BOBD, 1.72 bpm/4,358 psi/Diff 756,
WHP 491, BHP 3,956, IA 294, OA 0
12,221.0 12,349.0
8/24/2022
14:09
8/24/2022
14:39
0.50 PROD1, DRILL WPRT P 350' Wiper up hole, PUW 48 k CTSW, 12,349.0 12,349.0
8/24/2022
14:39
8/24/2022
16:39
2.00 PROD1, DRILL DRLG P BOBD, 1.4 bpm/3,400 psi/Diff 489, WHP
524, BHP 3,893, IA 282, OA 0
12,349.0 12,432.0
8/24/2022
16:39
8/24/2022
17:09
0.50 PROD1, DRILL WPRT P TD well 12,432', pump 10x10 sweep 12,432.0 12,432.0
8/24/2022
17:09
8/24/2022
21:09
4.00 PROD1, DRILL WPRT P Swab wiper // Jet 7" casing // 12,432.0 75.0
8/24/2022
21:09
8/24/2022
23:09
2.00 PROD1, DRILL TRIP P Trip in hole to confirm depth // Tie in
formation -5.5' Correction //
75.0 9,720.0
8/24/2022
23:09
8/24/2022
23:27
0.30 PROD1, DRILL CTOP P Pressure Survey @ window for KWF
MD- 9720.15
Sensor TVD - 5846.13
Annular - 3674
Equiv Md. Wt. = 12.09ppg
9,720.0 9,720.0
8/24/2022
23:27
8/25/2022
00:00
0.55 PROD1, DRILL TRIP P RIH confirm TD // PU Wt. @ window
36K // Paint TD EOP Flag 11297.1 //
Top of liner running pill 9300' // Window
EOP Flag 8491.6
9,720.0 11,500.0
8/25/2022
00:00
8/25/2022
02:15
2.25 PROD1, DRILL TRIP P RIH confirm TD // Friction slowing
progress // Confirm TD 12,440
11,500.0 12,440.0
8/25/2022
02:15
8/25/2022
03:00
0.75 PROD1, DRILL CIRC P Circ beads and LRP to bit for well kill
ops
12,440.0 12,440.0
8/25/2022
03:00
8/25/2022
06:00
3.00 PROD1, DRILL DISP P Pump 40bbls 12.3ppg LRP to window
up to 9,350' Displace well to 12.3+ppg
KWF
12,440.0 75.0
8/25/2022
06:00
8/25/2022
06:30
0.50 PROD1, DRILL OWFF P Check well for flow, PJSM
Loss rate 2.0 bph
75.0 75.0
8/25/2022
06:30
8/25/2022
08:00
1.50 PROD1, DRILL BHAH P LD drilling assembly over a dead well
*** Note: Bit grade - 1-1-CT-S-X-I-NO-
TD
75.0 0.0
8/25/2022
08:00
8/25/2022
08:30
0.50 COMPZN, CASING PUTB P Prep RF for Liner OPS 0.0 0.0
Rig: NABORS CDR3-AC
RIG RELEASE DATE 8/26/2022
Page 7/8
3G-20
Report Printed: 9/21/2022
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)
8/25/2022
08:30
8/25/2022
09:15
0.75 COMPZN, CASING PUTB T Work on return MM
Try and clear internal tube
Unsuccessful, make back up to move
forward, work on another solution out of
critcal path
0.0 0.0
8/25/2022
09:15
8/25/2022
11:00
1.75 COMPZN, CASING PUTB P PU Liner segment #1 w/35 joints slotted,
non-ported bullnose
0.0 1,073.0
8/25/2022
11:00
8/25/2022
11:30
0.50 COMPZN, CASING BHAH P PU BHI & NS Liner running assembly
BHA #8
Inspect Pac-off
1,073.0 1,116.9
8/25/2022
11:30
8/25/2022
13:00
1.50 COMPZN, CASING RUNL P Tag up, reset counter depths, RIH 1,116.9 9,623.0
8/25/2022
13:00
8/25/2022
13:12
0.20 COMPZN, CASING RUNL P Correct to EOP flag (window)
Correction - 8.5'
9,623.0 9,616.0
8/25/2022
13:12
8/25/2022
13:48
0.60 COMPZN, CASING RUNL P Continue IH
PUW 40 k CTSW
9,616.0 10,730.0
8/25/2022
13:48
8/25/2022
14:00
0.20 COMPZN, CASING RUNL P Log formatoin + 2.0' 10,730.0 10,771.0
8/25/2022
14:00
8/25/2022
16:00
2.00 COMPZN, CASING RUNL P Continue IH
Initial set down 10,785', work liner to
bottom
10,771.0 12,439.0
8/25/2022
16:00
8/25/2022
16:15
0.25 COMPZN, CASING RUNL P PUW 50 k CTSW, set back down , bring
pump online 1.5 bpm/4,425 psi/Diff
1,140 psi, 1.8 k DHWOB, PUH, PUW 38
k CTSW
Remove liner length from counters
12,439.0 11,320.8
8/25/2022
16:15
8/25/2022
18:15
2.00 COMPZN, CASING CIRC P Wait on second beaded LRP 11,320.8 11,320.0
8/25/2022
18:15
8/25/2022
21:09
2.90 COMPZN, CASING TRIP P POOH for second liner run 11,320.0 45.0
8/25/2022
21:09
8/25/2022
21:39
0.50 COMPZN, CASING PULD P Check for flow // No flow // PJSM // Lay
down BHA dead well
45.0 0.0
8/25/2022
21:39
8/25/2022
22:24
0.75 COMPZN, CASING RURD P Rig up run liner // service blocks and
Elevators
0.0 0.0
8/25/2022
22:24
8/26/2022
00:00
1.60 COMPZN, CASING PUTB P PJSM // Pick up liner
50-Jts 2-3/8" Slotted ST-L 4.6# Liner
1- 9.82' Pup
1- Swell Packer
7- Jts 2-3/8" Solit ST-L 4.6# Liner
1- Seal Bore Recepticle
Total Length - 1772.65'
0.0 1,773.0
8/26/2022
00:00
8/26/2022
02:00
2.00 COMPZN, CASING PUTB P Pick up liner
50-Jts 2-3/8" Slotted ST-L 4.6# Liner
1- 9.82' Pup
1- Swell Packer
7- Jts 2-3/8" Solit ST-L 4.6# Liner
1- Seal Bore Recepticle
Total Length - 1772.65'
1,773.0 1,773.0
8/26/2022
02:00
8/26/2022
02:15
0.25 COMPZN, CASING RURD P Rig down liner running equipment 1,773.0 1,773.0
8/26/2022
02:15
8/26/2022
02:57
0.70 COMPZN, CASING PULD P Pick up Baker BHA // Put cart on well 1,773.0 1,817.0
8/26/2022
02:57
8/26/2022
05:03
2.10 COMPZN, CASING RUNL P Tag up set depth // RIH w/ BHA# 9 Liner
Run 2 // -4.96' correction @ window
flag // Pu. Wt. @ window 40K
Continue IH
1,817.0 10,829.0
8/26/2022
05:03
8/26/2022
06:48
1.75 COMPZN, CASING RUNL P Initial set down 10,829', work liner IH 10,829.0 11,366.0
Rig: NABORS CDR3-AC
RIG RELEASE DATE 8/26/2022
Page 8/8
3G-20
Report Printed: 9/21/2022
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)
8/26/2022
06:48
8/26/2022
07:12
0.40 DEMOB, WHDBOP RUNL P PUW 53 k CTSW confirm liner is latched
in, set back down, birng pump up to rate
1.55 bpm/3,664 psi/Diff 1,146 psi, PUW
30
TOL = 9,593.3'
11,366.0 9,593.3
8/26/2022
07:12
8/26/2022
07:24
0.20 DEMOB, WHDBOP CTOP P Obtain static pressure @ 9,570.3'
CTMD, Sensor TVD 5,785.8, Sensor
SSTVD 5,695.8, Annular Pressure 3,688
psi, 12.27 ppg
** Check and tighten Tree Bolts
9,593.3 9,593.3
8/26/2022
07:24
8/26/2022
09:54
2.50 DEMOB, WHDBOP DISP P Displace well to SW 9,593.3 2,500.0
8/26/2022
09:54
8/26/2022
11:12
1.30 DEMOB, WHDBOP FRZP P Freeze protect, LRS on location spot in
equipment and PT liner to 3,500 psi,
Load 30 bbl of diesel into coil tubing
reel, RD LRS
Take over with rig pump
2,500.0 2,500.0
8/26/2022
11:12
8/26/2022
11:42
0.50 DEMOB, WHDBOP TRIP P POOH, pumping freeze protect from
2,500'
2,500.0 44.2
8/26/2022
11:42
8/26/2022
13:12
1.50 DEMOB, WHDBOP BHAH P Tag up, spaceout, PUD/LD setting tools
*** Final Tubing Pressure 1,294 psi
44.2 0.0
8/26/2022
13:12
8/26/2022
14:24
1.20 DEMOB, WHDBOP CTOP P Tools OOH, RU to flush surface lines
and stack
Pull BHI upper quick float valves
0.0 0.0
8/26/2022
14:24
8/26/2022
15:09
0.75 DEMOB, WHDBOP CTOP P Blow down stack and surface lines 0.0 0.0
8/26/2022
15:09
8/26/2022
15:39
0.50 DEMOB, WHDBOP CTOP P Boro-scope stack (good) 0.0 0.0
8/26/2022
15:39
8/26/2022
15:51
0.20 DEMOB, WHDBOP CTOP P Freeze protect tree 0.0 0.0
8/26/2022
15:51
8/26/2022
16:51
1.00 DEMOB, WHDBOP CTOP P Work RD/Pre-move checklist 0.0 0.0
8/26/2022
16:51
8/26/2022
18:00
1.15 DEMOB, WHDBOP NUND P Nipple down BOP's *** Rig Released
18:00 8/26/22 *** // RKB's // change out
Riser for shorter well
0.0 0.0
Rig: NABORS CDR3-AC
RIG RELEASE DATE 8/26/2022
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1058 Baker Hughes Drive
Broussard, LA 70518, USA
Aug 30, 2022
AOGCC
Attention: Kayla Junke
333 W. 7th Ave., Suite 100
Anchorage, Alaska 99501-3539
Subject:Final Log Distribution for ConocoPhillips Alaska, Inc.
3G-20L1
Kuparuk River
API #: 50-103-20141-60-00
Permit No: 222-093
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
PTD:222-093
T36950
Kayla Junke Digitally signed by Kayla Junke
Date: 2022.08.30 12:48:42 -08'00'
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
BOPE Test Report for:
Reviewed By:
P.I. Suprv
Comm ________KUPARUK RIV UNIT 3G-20L1
JBR 09/06/2022
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:3
Long test with lots of troubleshooting to find the leaks. Walk down rig with Mr. Coyne, test pit alarms, LEL and H2s with rig
electrician and verified flow through the micromotion meter (all good). Swab 2 failed/greased/re-tested /passed. Romeo 1
failed/greased/re-tested/passed. B-5 (HRC Kill Valve) failed/greased/retested/failed/change out valve/re-tested /passed.
Test Results
TEST DATA
Rig Rep:Cleve CoyneOperator:ConocoPhillips Alaska, Inc.Operator Rep:Chase Erdman
Rig Owner/Rig No.:Nabors CDR3AC PTD#:2220930 DATE:8/19/2022
Type Operation:DRILL Annular:
250/2500Type Test:INIT
Valves:
250/3500
Rams:
250/3500
Test Pressures:Inspection No:bopSTS220823155155
Inspector Sully Sullivan
Inspector
Insp Source
Related Insp No:
INSIDE REEL VALVES:
Quantity P/F
(Valid for Coil Rigs Only)
Remarks:
Test Time 15.5
MASP:
3289
Sundry No:
CLOSURE TIME (sec)
Time/Pressure 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" combi 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" swab FP
System Pressure P3100
Pressure After Closure P2400
200 PSI Attained P21
Full Pressure Attained P48
Blind Switch Covers:Yall stations
Bottle precharge P
Nitgn Btls# &psi (avg)P4/1750
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 P13
#1 Rams P4
#2 Rams P4
#3 Rams P4
#4 Rams P4
#5 Rams NA0
#6 Rams NA0
HCR Choke P1
HCR Kill P1
9
9
9
9
9 9 9
9
9
9
99
9 9
9
lots of troubleshooting to find the leaks.
Swab 2 failed/Romeo 1
failed/B-5 (HRC Kill Valve) failed/
FP
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
James Ohlinger
Senior CTD Engineer
ConocoPhillips Alaska, Inc.
PO Box 100360
Anchorage, AK 99510-0360
Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3G-20L1
ConocoPhillips Alaska, Inc.
Permit to Drill Number: 222-093
Surface Location: 2538' FNL, 170' FEL, Sec 23, T12N, R8E, UM
Bottomhole Location: 765' FNL, 2450' FEL, Sec. 26, T12N, R8E, UM
Dear Mr. Ohlinger:
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 190-123, API Number
50-103-20141-00-00. 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,
Jeremy M. Price
Chair
DATED this ___ day of July, 2022.
Jeremy Price
Digitally signed by
Jeremy Price
Date: 2022.07.20
17:29:05 -08'00'
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dts 7/20/2022 JLC 7/20/2022
7/20/22
Jeremy Price Digitally signed by Jeremy Price
Date: 2022.07.20 17:29:26 -08'00'
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Date: 2022.07.18 08:15:48 -08'00'
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WELL PERMIT CHECKLISTCompanyConocoPhillips Alaska, Inc.Well Name:KUPARUK RIV UNIT 3G-20L1Initial Class/TypeSER / PENDGeoArea890Unit11160On/Off ShoreOnProgramSERField & PoolWell bore segAnnular DisposalPTD#:2220930KUPARUK RIVER, KUPARUK RIV OIL - 490100NA1Permit fee attachedYes2Lease number appropriateYes3Unique well name and numberYes4Well located in a defined poolYes5Well located proper distance from drilling unit boundaryYes6Well located proper distance from other wellsYes7Sufficient acreage available in drilling unitYesDirectional plan view included, no land plat.8If 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 waitYes14Well located within area and strata authorized by Injection Order # (put IO# in comments) (ForYes15All wells within 1/4 mile area of review identified (For service well only)No3G-20L1 well will not be pre-produced.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 csgNA21CMT vol adequate to tie-in long string to surf csgNoProductive interval will be completed with uncemented slotted liner22CMT will cover all known productive horizonsYes23Casing designs adequate for C, T, B & permafrostYesRig has steel tanks; all waste to approved disposal wells24Adequate tankage or reserve pitNA25If a re-drill, has a 10-403 for abandonment been approvedYes26Adequate wellbore separation proposedNA27If diverter required, does it meet regulationsYesMax formation pressure is 3877 psig(12.67 ppg EMW); will drill w/ 8.6 ppg EMW and maintaing overbal w/ MPD28Drilling fluid program schematic & equip list adequateYes29BOPEs, do they meet regulationYesMPSP is 3289 psig; will test BOPs to 3500 psig30BOPE press rating appropriate; test to (put psig in comments)Yes31Choke manifold complies w/API RP-53 (May 84)Yes32Work will occur without operation shutdownYesH2S measures required33Is presence of H2S gas probableYes3G-13 to be abd; #g-19 P&A'd34Mechanical condition of wells within AOR verified (For service well only)No3G-Pad wells are H2S-bearing. H2S measures are required.35Permit can be issued w/o hydrogen sulfide measuresYes36Data presented on potential overpressure zonesNA37Seismic analysis of shallow gas zonesNA38Seabed condition survey (if off-shore)NA39Contact name/phone for weekly progress reports [exploratory only]ApprDLBDate7/19/2022ApprVTLDate7/20/2022ApprDLBDate7/18/2022AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDate-03JLC 7/20/2022
