Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
Loading...
HomeMy WebLinkAbout201-084CAUTION: 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.
From:Wallace, Chris D (OGC)
To:AOGCC Records (CED sponsored)
Subject:FW: KRU 1C-123 (PTD 201-084) Suspect IA pressure update
Date:Wednesday, April 24, 2024 4:24:34 PM
Attachments:MIT KRU 1C-123 diagnostic MITIA 03-19-24.xlsx
AnnComm Surveillance TIO for 1C-123.pdf
From: Byrne, Jan <Jan.Byrne@conocophillips.com>
Sent: Wednesday, April 24, 2024 3:56 PM
To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>
Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com>
Subject: KRU 1C-123 (PTD 201-084) Suspect IA pressure update
Chris,
KRU 1C-123 (PTD 201-084) was reported on 3/18/24 for suspect IA pressure increase. DHD
performed a passing MITIA and pack off tests. The well was then brought on injection for a 30-day
monitor and exhibited no signs of annular communication. The well does exhibit an IA pressure that
swings with localized injection rate changes. CPAI plans to return this well to ‘normal’ status. If any
annular communication is observed or suspected in the future it will be reported at that time.
Please let me know if you disagree or have any questions with this plan.
Regards,
Jan Byrne
Well Integrity Specialist | ConocoPhillips Alaska
O: (907) 265-6471 | M: (808) 345-6886
Submit to:
OPERATOR:
FIELD / UNIT / PAD:
DATE:
OPERATOR REP:
AOGCC REP:
Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min.
PTD 2010840 Type Inj N Tubing 450 568 450 4501 Type Test P
Packer TVD 3688 BBL Pump 2.4 IA 76 2500 2450 2425 Interval O
Test psi 1500 BBL Return OA Result P
Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes
W = Water P = Pressure Test I = Initial Test P = Pass
G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail
S = Slurry V = Required by Variance I = Inconclusive
I = Industrial Wastewater O = Other (describe in notes)
N = Not Injecting
ConocoPhillips Alaska Inc,
Kuparuk / KRU / 1C Pad
Hills
03/19/24
Notes:Diagnostic MITIA. Dual string tubing. 2nd tubing string presures: Pretest= 1180. Initial= 1180. 15 min= 1180 psi. 30 min= 1180 psi.
Notes:
1C-123S
Notes:
Notes:
Notes:
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
Mechanical Integrity Test
jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov
Form 10-426 (Revised 01/2017)MIT KRU 1C-123 diagnostic MITIA 03-19-24 (002)
1C-123 90-Day Bleed History
WELL DATE STR-PRES END-PRES DIF-PRES CASING
Last Tag
Annotation Depth (ftKB) End Date Wellbore Last Mod By
Last Tag: SLM (Short String) 4,897.0 6/6/2019 1C-123 zembaej
Last Rev Reason
Annotation End Date Wellbore Last Mod By
Rev Reason: Changed GLM#2 to INJ and corrected PACKER(@4,915')
ID to 1.995"
4/6/2021 1C-123 pproven
Casing Strings
Casing Description
CONDUCTOR
OD (in)
16
ID (in)
15.06
Top (ftKB)
41.0
Set Depth (ftKB)
158.0
Set Depth (TVD) …
158.0
Wt/Len (l…
62.50
Grade
H-40
Top Thread
WELDED
Casing Description
PRODUCTION 8
5/8 x 7 5/8"
OD (in)
7 5/8
ID (in)
6.87
Top (ftKB)
42.2
Set Depth (ftKB)
5,439.9
Set Depth (TVD) …
4,275.8
Wt/Len (l…
29.70
Grade
L-80
Top Thread
BTCM
Casing Description
GRAVEL PACK LINER
OD (in)
4 9/16
ID (in)
3.96
Top (ftKB)
4,943.5
Set Depth (ftKB)
5,145.3
Set Depth (TVD) …
3,985.4
Wt/Len (l…Grade Top Thread
SLHT
Liner Details
Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com
Nominal ID
(in)
4,943.5 3,786.9 10.36 PBR BAKER 80-40 PBR 4.000
4,947.5 3,790.8 10.36 XO 3.5 x 4.5 4.500
4,949.8 3,793.0 10.36 ANCHOR BAKER 80-40 ANCHOR LATCH 3.000
4,950.6 3,793.8 10.36 PACKER BAKER B-40 SC-1 PACKER 4.000
4,955.4 3,798.5 10.35 SBE UPPER EXTENSION 4.000
4,959.3 3,802.3 10.35 SLEEVE SLIDING SLEEVE 4.240
4,961.9 3,804.9 10.34 SEAL BAKER 80-40 SEAL BORE 4.000
4,963.3 3,806.4 10.34 SBE LOWER EXTENSION 4.000
4,971.9 3,814.8 10.33 XO CROSSOVER 5" x 4" 4.000
4,972.6 3,815.5 10.33 NIPPLE OTIS 'XN' NIPPLE 3.313
4,974.0 3,816.9 10.33 SOS BAKER GPR-24 SHEAR OUT SAFETY JOINT 3.500
4,977.1 3,819.9 10.33 SCREEN BAKER 4" EXCLUDER 2000 SCREEN 3.958
4,986.7 3,829.3 10.32 SCREEN 4" BAKERWELD SCREEN 140 315 ss 4"x.020 GA 3.958
4,996.2 3,838.7 10.31 SCREEN 4" BAKERWELD SCREEN 140 315 ss 4"x.020 GA 3.958
5,033.3 3,875.1 10.28 SCREEN 4" BAKERWELD SCREEN 140 315 ss 4"x.020 GA 3.958
5,070.3 3,911.6 10.24 SCREEN 4" BAKERWELD SCREEN 140 315 ss 4"x.020 GA 3.958
5,107.7 3,948.4 10.21 SCREEN 4" BAKERWELD SCREEN 140 315 ss 4"x.020 GA 3.958
5,144.8 3,984.9 10.09 PLUG 4" BULL PLUG 0.000
Tubing Strings
Tubing Description
INJ TUBING (Blue)
String Ma…
2 3/8
ID (in)
2.00
Top (ftKB)
36.2
Set Depth (ft…
4,930.1
Set Depth (TVD) (…
3,773.6
Wt (lb/ft)
4.60
Grade
L-80
Top Connection
Hydrill 511
Completion Details
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des Com
Nominal
ID (in)
36.2 36.2 0.00 HANGER VETCO GRAY DUAL TUBING HANGER 2.375
4,843.4 3,688.6 12.10 PACKER BAKERE GT47D4 DUAL PACKER (LONG STRING SET) 1.995
4,851.0 3,696.1 11.95 SWIVEL 2.375" TELESCOPING SWIVEL SUB 1.995
4,860.4 3,705.3 11.78 SLEEVE-C CMD SLEEVE (CLOSED 8/15/2005) 1.990
4,889.9 3,734.2 11.23 NIPPLE HES 'X' NIPPLE 1.750
4,909.7 3,753.7 10.86 SEAL BORE SEAL BORE 1.875
4,912.0 3,755.9 10.82 PACKER BAKER GT47D4 DUAL PACKER (LONG STRING SET) 1.995
4,928.0 3,771.6 10.52 NIPPLE HES 'XN' NIPPLE 1.875
4,929.0 3,772.6 10.50 WLEG 1.995
Tubing Description
INJ TUBING (Red)
String Ma…
3 1/2
ID (in)
2.99
Top (ftKB)
36.2
Set Depth (ft…
4,943.5
Set Depth (TVD) (…
3,786.9
Wt (lb/ft)
9.30
Grade
L-80
Top Connection
HYDRIL
Completion Details
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des Com
Nominal
ID (in)
36.2 36.2 0.00 HANGER VETCO GRAY DUAL TUBING HANGER 3.500
4,735.3 3,583.9 16.25 NIPPLE Weatherford Landing NO GO Nipple w/5' Seal Bore/ Polished Bore 2.680
4,740.0 3,588.4 16.08 XO 3.5 x 2.375 2.992
4,839.0 3,684.3 12.23 ANCHOR BAKER K-22 ANCHOR 2.688
4,839.4 3,684.7 12.21 Scoophead BAKER 47D SCOOPHEAD wSEAL BORE 2.375
4,846.4 3,691.6 12.04 PACKER BAKER GT 47D4 DUAL PACKER (LONG STRING SET) 1.995
4,855.1 3,700.1 11.88 BLAST JT BLAST JOINT (OAL=59') 1.995
4,915.1 3,758.9 10.76 PACKER BAKER GT 47D4 DUAL PACKER (LONG STRING SET) 1.995
4,921.8 3,765.5 10.64 BLAST JT BLAST JOINT PUP (OAL=10') 1.995
4,931.7 3,775.2 10.46 NIPPLE HES 'X' NIPPLE 1.875
4,932.7 3,776.2 10.44 BLAST JT BLAST JOINT PUP (OAL=10') 1.995
4,942.5 3,785.9 10.36 SHOE BAKER 80-40 SS22 SNAP LATCH w/RACHETING MULESHOE 2.375
Tubing Description
COIL TUBING
String Ma…
2
ID (in)
1.69
Top (ftKB)
41.0
Set Depth (ft…
4,735.0
Set Depth (TVD) (…
3,583.6
Wt (lb/ft) Grade Top Connection
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top
(ftKB)
Top
(TVD)
(ftKB)
Top Incl
(°) Des Com Run Date ID (in) SN
4,729.0 3,577.8 16.48 PBR Blount Tool PBR 10/27/2001 1.562
4,928.0 3,771.6 10.52 REGULATOR XXN & BF Baker Flow Regulator-Set 520
BWPD w/14/64" Orifice
5/29/2002 0.219
5,146.0 3,986.1 10.08 PLUG 7 5/8" BAKER N-1 BRIDGE PLUG 7/29/2001
5,240.0 4,078.7 9.76 CEMENT 7/29/2001
1C-123, 4/6/2021 5:04:18 PM
Vertical schematic (actual)
PRODUCTION 8 5/8 x 7
5/8"; 42.2-5,439.9
CEMENT; 5,240.0
PLUG; 5,146.0
GRAVEL PACK LINER; 4,943.5-
5,145.3
IPERF; 5,116.0-5,136.0
FRAC; 5,116.0
IPERF; 5,040.0-5,070.0
FRAC; 5,020.0
IPERF; 5,020.0-5,034.0
IPERF; 4,994.0-5,000.0
FRAC; 4,980.0
IPERF; 4,980.0-4,986.0
IPERF; 4,932.0-4,944.0
REGULATOR; 4,928.0
PACKER; 4,915.1
PACKER; 4,912.0
GAS LIFT; 4,896.8
IPERF; 4,868.0-4,900.0
PACKER; 4,846.4
PACKER; 4,843.4
GAS LIFT; 4,791.3
PBR; 4,729.0
CONDUCTOR; 41.0-158.0
KUP INJ
KB-Grd (ft)
46.09
Rig Release Date
6/21/2001
1C-123
...
TD
Act Btm (ftKB)
5,445.0
Well Attributes
Field Name
WEST SAK
Wellbore API/UWI
500292301600
Wellbore Status
INJ
Max Angle & MD
Incl (°)
56.43
MD (ftKB)
2,416.90
WELLNAME WELLBORE1C-123
Annotation
Last WO:
End DateH2S (ppm) DateComment
SSSV: NONE
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft
)Type Com
4,868.0 4,900.0 3,712.7 3,744.1 WS D, 1C-123 8/2/2001 4.0 IPERF 4.5" BH
4,932.0 4,944.0 3,775.5 3,787.3 WS B, 1C-123 8/2/2001 4.0 IPERF 4.5" BH
4,980.0 4,986.0 3,822.7 3,828.7 WS A4, 1C-123 7/28/2001 12.0 IPERF 4.5" BH
4,994.0 5,000.0 3,836.5 3,842.4 WS A4, 1C-123 7/28/2001 12.0 IPERF 4.5" BH
5,020.0 5,034.0 3,862.1 3,875.9 WS A3, 1C-123 7/25/2001 12.0 IPERF 4.5" BH
5,040.0 5,070.0 3,881.8 3,911.3 WS A3, 1C-123 7/25/2001 12.0 IPERF 4.5" BH
5,116.0 5,136.0 3,956.6 3,976.3 WS A2, 1C-123 7/22/2001 12.0 IPERF 4.5" BH
Stimulation Intervals
Interva
l
Numbe
r Type Subtype Start Date Top (ftKB) Btm (ftKB)
Proppant
Designed (lb)
Proppant
Total (lb)
Vol Clean
Total (bbl)
Vol Slurry
Total (bbl)
1 FRAC 7/22/2001 5,116.0 5,136.0 0.0 0.00 0.00
2 FRAC 7/25/2001 5,020.0 5,070.0 0.0 0.00 0.00
3 FRAC 7/29/2001 4,980.0 5,000.0 0.0 0.00 0.00
Mandrel Inserts
St
ati
on
N
o/Top (ftKB)
Top (TVD)
(ftKB) Make Model OD (in) Serv
Valve
Type
Latch
Type
Port Size
(in)
TRO Run
(psi) Run Date Com
1 4,791.3 3,637.9 CAMCO KBMM 1 GAS LIFT DMY BK-5 0.000 0.0 3/21/2002
2 4,896.8 3,741.0 CAMCO KBMG-
W
1 INJ RFW-1 BK-5 0.125 0.0 5/3/2002
Notes: General & Safety
End Date Annotation
11/19/2003 NOTE: PRODUCTION STRING CONVERTED TO INJECTION
5/3/2002 NOTE: Flange for wellwork access to 2 3/8" tbg: S/N 4979635
5/3/2002 NOTE: Flange for wellwork access to 3.5" tbg S/N 4979625
1C-123, 4/6/2021 5:04:19 PM
Vertical schematic (actual)
PRODUCTION 8 5/8 x 7
5/8"; 42.2-5,439.9
CEMENT; 5,240.0
PLUG; 5,146.0
GRAVEL PACK LINER; 4,943.5-
5,145.3
IPERF; 5,116.0-5,136.0
FRAC; 5,116.0
IPERF; 5,040.0-5,070.0
FRAC; 5,020.0
IPERF; 5,020.0-5,034.0
IPERF; 4,994.0-5,000.0
FRAC; 4,980.0
IPERF; 4,980.0-4,986.0
IPERF; 4,932.0-4,944.0
REGULATOR; 4,928.0
PACKER; 4,915.1
PACKER; 4,912.0
GAS LIFT; 4,896.8
IPERF; 4,868.0-4,900.0
PACKER; 4,846.4
PACKER; 4,843.4
GAS LIFT; 4,791.3
PBR; 4,729.0
CONDUCTOR; 41.0-158.0
KUP INJ 1C-123
...
WELLNAME WELLBORE1C-123
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.
From:Wallace, Chris D (OGC)
To:AOGCC Records (CED sponsored)
Subject:FW: KRU 1C-123 (PTD 201-084) Report of suspect IA pressure
Date:Monday, March 18, 2024 1:15:43 PM
Attachments:AnnComm Surveillance TIO for 1C-123.pdf
From: Byrne, Jan <Jan.Byrne@conocophillips.com>
Sent: Monday, March 18, 2024 1:10 PM
To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>
Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com>
Subject: KRU 1C-123 (PTD 201-084) Report of suspect IA pressure
Chris,
KRU 1C-123 (PTD 201-084) was reported by Operations to be exhibiting suspect IA pressure. The
well has been shut in and freeze protected. The plan is for DHD to mobilize to the well and perform
initial diagnostics including an MITIA and pack off tests. If the MITIA passes the well will be put on a
30-day injection monitor. Any required paperwork for continued injection or corrective action will
be submitted upon completion of the diagnostics and monitor period.
Please let me know if you disagree or have any questions with this plan.
Regards,
Jan Byrne
Well Integrity Specialist | ConocoPhillips Alaska
O: (907) 265-6471 | M: (808) 345-6886
1C-123 90-Day Bleed History
WELL DATE STR-PRES END-PRES DIF-PRES CASING
Last Tag
Annotation Depth (ftKB) End Date Wellbore Last Mod By
Last Tag: SLM (Short String) 4,897.0 6/6/2019 1C-123 zembaej
Last Rev Reason
Annotation End Date Wellbore Last Mod By
Rev Reason: Changed GLM#2 to INJ and corrected PACKER(@4,915')
ID to 1.995"
4/6/2021 1C-123 pproven
Casing Strings
Casing Description
CONDUCTOR
OD (in)
16
ID (in)
15.06
Top (ftKB)
41.0
Set Depth (ftKB)
158.0
Set Depth (TVD) …
158.0
Wt/Len (l…
62.50
Grade
H-40
Top Thread
WELDED
Casing Description
PRODUCTION 8
5/8 x 7 5/8"
OD (in)
7 5/8
ID (in)
6.87
Top (ftKB)
42.2
Set Depth (ftKB)
5,439.9
Set Depth (TVD) …
4,275.8
Wt/Len (l…
29.70
Grade
L-80
Top Thread
BTCM
Casing Description
GRAVEL PACK LINER
OD (in)
4 9/16
ID (in)
3.96
Top (ftKB)
4,943.5
Set Depth (ftKB)
5,145.3
Set Depth (TVD) …
3,985.4
Wt/Len (l…Grade Top Thread
SLHT
Liner Details
Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com
Nominal ID
(in)
4,943.5 3,786.9 10.36 PBR BAKER 80-40 PBR 4.000
4,947.5 3,790.8 10.36 XO 3.5 x 4.5 4.500
4,949.8 3,793.0 10.36 ANCHOR BAKER 80-40 ANCHOR LATCH 3.000
4,950.6 3,793.8 10.36 PACKER BAKER B-40 SC-1 PACKER 4.000
4,955.4 3,798.5 10.35 SBE UPPER EXTENSION 4.000
4,959.3 3,802.3 10.35 SLEEVE SLIDING SLEEVE 4.240
4,961.9 3,804.9 10.34 SEAL BAKER 80-40 SEAL BORE 4.000
4,963.3 3,806.4 10.34 SBE LOWER EXTENSION 4.000
4,971.9 3,814.8 10.33 XO CROSSOVER 5" x 4" 4.000
4,972.6 3,815.5 10.33 NIPPLE OTIS 'XN' NIPPLE 3.313
4,974.0 3,816.9 10.33 SOS BAKER GPR-24 SHEAR OUT SAFETY JOINT 3.500
4,977.1 3,819.9 10.33 SCREEN BAKER 4" EXCLUDER 2000 SCREEN 3.958
4,986.7 3,829.3 10.32 SCREEN 4" BAKERWELD SCREEN 140 315 ss 4"x.020 GA 3.958
4,996.2 3,838.7 10.31 SCREEN 4" BAKERWELD SCREEN 140 315 ss 4"x.020 GA 3.958
5,033.3 3,875.1 10.28 SCREEN 4" BAKERWELD SCREEN 140 315 ss 4"x.020 GA 3.958
5,070.3 3,911.6 10.24 SCREEN 4" BAKERWELD SCREEN 140 315 ss 4"x.020 GA 3.958
5,107.7 3,948.4 10.21 SCREEN 4" BAKERWELD SCREEN 140 315 ss 4"x.020 GA 3.958
5,144.8 3,984.9 10.09 PLUG 4" BULL PLUG 0.000
Tubing Strings
Tubing Description
INJ TUBING (Blue)
String Ma…
2 3/8
ID (in)
2.00
Top (ftKB)
36.2
Set Depth (ft…
4,930.1
Set Depth (TVD) (…
3,773.6
Wt (lb/ft)
4.60
Grade
L-80
Top Connection
Hydrill 511
Completion Details
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des Com
Nominal
ID (in)
36.2 36.2 0.00 HANGER VETCO GRAY DUAL TUBING HANGER 2.375
4,843.4 3,688.6 12.10 PACKER BAKERE GT47D4 DUAL PACKER (LONG STRING SET) 1.995
4,851.0 3,696.1 11.95 SWIVEL 2.375" TELESCOPING SWIVEL SUB 1.995
4,860.4 3,705.3 11.78 SLEEVE-C CMD SLEEVE (CLOSED 8/15/2005) 1.990
4,889.9 3,734.2 11.23 NIPPLE HES 'X' NIPPLE 1.750
4,909.7 3,753.7 10.86 SEAL BORE SEAL BORE 1.875
4,912.0 3,755.9 10.82 PACKER BAKER GT47D4 DUAL PACKER (LONG STRING SET) 1.995
4,928.0 3,771.6 10.52 NIPPLE HES 'XN' NIPPLE 1.875
4,929.0 3,772.6 10.50 WLEG 1.995
Tubing Description
INJ TUBING (Red)
String Ma…
3 1/2
ID (in)
2.99
Top (ftKB)
36.2
Set Depth (ft…
4,943.5
Set Depth (TVD) (…
3,786.9
Wt (lb/ft)
9.30
Grade
L-80
Top Connection
HYDRIL
Completion Details
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des Com
Nominal
ID (in)
36.2 36.2 0.00 HANGER VETCO GRAY DUAL TUBING HANGER 3.500
4,735.3 3,583.9 16.25 NIPPLE Weatherford Landing NO GO Nipple w/5' Seal Bore/ Polished Bore 2.680
4,740.0 3,588.4 16.08 XO 3.5 x 2.375 2.992
4,839.0 3,684.3 12.23 ANCHOR BAKER K-22 ANCHOR 2.688
4,839.4 3,684.7 12.21 Scoophead BAKER 47D SCOOPHEAD wSEAL BORE 2.375
4,846.4 3,691.6 12.04 PACKER BAKER GT 47D4 DUAL PACKER (LONG STRING SET) 1.995
4,855.1 3,700.1 11.88 BLAST JT BLAST JOINT (OAL=59') 1.995
4,915.1 3,758.9 10.76 PACKER BAKER GT 47D4 DUAL PACKER (LONG STRING SET) 1.995
4,921.8 3,765.5 10.64 BLAST JT BLAST JOINT PUP (OAL=10') 1.995
4,931.7 3,775.2 10.46 NIPPLE HES 'X' NIPPLE 1.875
4,932.7 3,776.2 10.44 BLAST JT BLAST JOINT PUP (OAL=10') 1.995
4,942.5 3,785.9 10.36 SHOE BAKER 80-40 SS22 SNAP LATCH w/RACHETING MULESHOE 2.375
Tubing Description
COIL TUBING
String Ma…
2
ID (in)
1.69
Top (ftKB)
41.0
Set Depth (ft…
4,735.0
Set Depth (TVD) (…
3,583.6
Wt (lb/ft) Grade Top Connection
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top
(ftKB)
Top
(TVD)
(ftKB)
Top Incl
(°) Des Com Run Date ID (in) SN
4,729.0 3,577.8 16.48 PBR Blount Tool PBR 10/27/2001 1.562
4,928.0 3,771.6 10.52 REGULATOR XXN & BF Baker Flow Regulator-Set 520
BWPD w/14/64" Orifice
5/29/2002 0.219
5,146.0 3,986.1 10.08 PLUG 7 5/8" BAKER N-1 BRIDGE PLUG 7/29/2001
5,240.0 4,078.7 9.76 CEMENT 7/29/2001
1C-123, 4/6/2021 5:04:18 PM
Vertical schematic (actual)
PRODUCTION 8 5/8 x 7
5/8"; 42.2-5,439.9
CEMENT; 5,240.0
PLUG; 5,146.0
GRAVEL PACK LINER; 4,943.5-
5,145.3
IPERF; 5,116.0-5,136.0
FRAC; 5,116.0
IPERF; 5,040.0-5,070.0
FRAC; 5,020.0
IPERF; 5,020.0-5,034.0
IPERF; 4,994.0-5,000.0
FRAC; 4,980.0
IPERF; 4,980.0-4,986.0
IPERF; 4,932.0-4,944.0
REGULATOR; 4,928.0
PACKER; 4,915.1
PACKER; 4,912.0
GAS LIFT; 4,896.8
IPERF; 4,868.0-4,900.0
PACKER; 4,846.4
PACKER; 4,843.4
GAS LIFT; 4,791.3
PBR; 4,729.0
CONDUCTOR; 41.0-158.0
KUP INJ
KB-Grd (ft)
46.09
Rig Release Date
6/21/2001
1C-123
...
TD
Act Btm (ftKB)
5,445.0
Well Attributes
Field Name
WEST SAK
Wellbore API/UWI
500292301600
Wellbore Status
INJ
Max Angle & MD
Incl (°)
56.43
MD (ftKB)
2,416.90
WELLNAME WELLBORE1C-123
Annotation
Last WO:
End DateH2S (ppm) DateComment
SSSV: NONE
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft
)Type Com
4,868.0 4,900.0 3,712.7 3,744.1 WS D, 1C-123 8/2/2001 4.0 IPERF 4.5" BH
4,932.0 4,944.0 3,775.5 3,787.3 WS B, 1C-123 8/2/2001 4.0 IPERF 4.5" BH
4,980.0 4,986.0 3,822.7 3,828.7 WS A4, 1C-123 7/28/2001 12.0 IPERF 4.5" BH
4,994.0 5,000.0 3,836.5 3,842.4 WS A4, 1C-123 7/28/2001 12.0 IPERF 4.5" BH
5,020.0 5,034.0 3,862.1 3,875.9 WS A3, 1C-123 7/25/2001 12.0 IPERF 4.5" BH
5,040.0 5,070.0 3,881.8 3,911.3 WS A3, 1C-123 7/25/2001 12.0 IPERF 4.5" BH
5,116.0 5,136.0 3,956.6 3,976.3 WS A2, 1C-123 7/22/2001 12.0 IPERF 4.5" BH
Stimulation Intervals
Interva
l
Numbe
r Type Subtype Start Date Top (ftKB) Btm (ftKB)
Proppant
Designed (lb)
Proppant
Total (lb)
Vol Clean
Total (bbl)
Vol Slurry
Total (bbl)
1 FRAC 7/22/2001 5,116.0 5,136.0 0.0 0.00 0.00
2 FRAC 7/25/2001 5,020.0 5,070.0 0.0 0.00 0.00
3 FRAC 7/29/2001 4,980.0 5,000.0 0.0 0.00 0.00
Mandrel Inserts
St
ati
on
N
o/Top (ftKB)
Top (TVD)
(ftKB) Make Model OD (in) Serv
Valve
Type
Latch
Type
Port Size
(in)
TRO Run
(psi) Run Date Com
1 4,791.3 3,637.9 CAMCO KBMM 1 GAS LIFT DMY BK-5 0.000 0.0 3/21/2002
2 4,896.8 3,741.0 CAMCO KBMG-
W
1 INJ RFW-1 BK-5 0.125 0.0 5/3/2002
Notes: General & Safety
End Date Annotation
11/19/2003 NOTE: PRODUCTION STRING CONVERTED TO INJECTION
5/3/2002 NOTE: Flange for wellwork access to 2 3/8" tbg: S/N 4979635
5/3/2002 NOTE: Flange for wellwork access to 3.5" tbg S/N 4979625
1C-123, 4/6/2021 5:04:19 PM
Vertical schematic (actual)
PRODUCTION 8 5/8 x 7
5/8"; 42.2-5,439.9
CEMENT; 5,240.0
PLUG; 5,146.0
GRAVEL PACK LINER; 4,943.5-
5,145.3
IPERF; 5,116.0-5,136.0
FRAC; 5,116.0
IPERF; 5,040.0-5,070.0
FRAC; 5,020.0
IPERF; 5,020.0-5,034.0
IPERF; 4,994.0-5,000.0
FRAC; 4,980.0
IPERF; 4,980.0-4,986.0
IPERF; 4,932.0-4,944.0
REGULATOR; 4,928.0
PACKER; 4,915.1
PACKER; 4,912.0
GAS LIFT; 4,896.8
IPERF; 4,868.0-4,900.0
PACKER; 4,846.4
PACKER; 4,843.4
GAS LIFT; 4,791.3
PBR; 4,729.0
CONDUCTOR; 41.0-158.0
KUP INJ 1C-123
...
WELLNAME WELLBORE1C-123
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Monday, June 13, 2022
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Austin McLeod
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
ConocoPhillips Alaska, Inc.
1C-123
KUPARUK RIV U WSAK 1C-123
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 06/13/2022
1C-123
50-029-23016-00-00
201-084-0
W
SPT
3688
2010840 1500
892 893 894 894
4YRTST P
Austin McLeod
5/15/2022
Monobore. MITIA
30 MinPretestInitial15 Min
Well Name
Type Test
Notes:
Interval P/F
Well
Permit Number:
Type Inj TVD
PTD Test psi
API Well Number Inspector Name:KUPARUK RIV U WSAK 1C-123
Inspection Date:
Tubing
OA
Packer Depth
130 1800 1710 1700IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitSAM220515191714
BBL Pumped:1.3 BBL Returned:1.1
Monday, June 13, 2022 Page 1 of 1
9
9
9
9
9
9
9 9
9
9
James B. Regg Digitally signed by James B. Regg
Date: 2022.06.14 09:46:50 -08'00'
!
" #
" $%
&'( ) $% *
+
,(!
- *)
./
!0 1"! !
2/
./
34 354-0 4
6 .
0
"
*
)
5'7758
7'31
$
)
5'75
+'215
9
7'1,18#5'+,8
:
+'-+8#+'2-,8
.
;''
0 3+61< /#14 7'2+48 +'--7
&
:. *'
0
3
=;
* !6
(
.
0
!6
+
=
5"
&
)
* "
$% * )
/
*
,"
&
>
")/
$
) > >(!?@/@>
*! !6
$%
!
;
$
266343
A&A#74 #'A&>7-)7'
A&>7-)7)
34#417
54#432#3+4,#44#44
)/4435,72
A %44,+4' '
&22541
$/B
/B(/!)> !$ :(! 99((!
3 !
!
7"
A " & 5
)
!
&
! " !
# $" % &
!6 B&
6"
&
? &
'
()) "
28 ,< 518 51
> &/
7'27+8 726,< 5'758 +'2158
5'+218 -561< 5'7748 7'3-,
#####
)
*
( C
)
#A >
#9 " #A
7'2589)+'-278:)'7'17+89)
+',128:)'7'2389)+'-5,8:)
+3#++
;!
;
$
$
7
.=
34 354-4'354-'D3531
"(!?">
-(*
*
*&
9
6 "
23-E
,52#-54,
"(
*
#####
4#747
+63434
"
+4*
Digitally signed by Roger Mouser
DN: O=Conocophillips, CN=Roger Mouser,
E=N1927@conocophilllips.com
Reason: I am the author of this document
Location: your signing location here
Date: 2021.09.11 15:04:55-08'00'
Foxit PDF Editor Version: 11.0.0
Roger Mouser
By Meredith Guhl at 8:16 am, Sep 13, 2021
RBDMS HEW 9/13/2021
DSR-9/13/21VTL 01/24/2022
!"
#$$%
&!' () )'
!*
+!,'
!-
#./
( 0*123 ( 4)5,
*!!." 6%$( % 6'7 78 ,
!7
+"79
!!
!*
+!,
Digitally signed by Roger Mouser
DN: O=Conocophillips, CN=Roger
Mouser, E=N1927@conocophilllips.com
Reason: I am the author of this
document
Location: your signing location here
Date: 2021.09.11 15:03:56-08'00'
Foxit PDF Editor Version: 11.0.0
Roger
Mouser
!"##$% !&'(!$)*+,
-++
.%$ %(!' /%$ / (& %(!"/ !01
21,
1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown
Suspend Perforate Other Stimulate Pull Tubing Change Approved Program
Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________
2.Operator Name:4. Current Well Class:5. Permit to Drill Number:
Exploratory Development
3. Address: Stratigraphic Service 6.API Number:
7. If perforating:8. Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool?N/A
Will planned perforations require a spacing exception?Yes No
9. Property Designation (Lease Number):10. Field/Pool(s):
11.
Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD):
5146'
Casing Collapse
Conductor
Surface
Gravel Pack Liner
Packers and SSSV Type:PKR:Packers and SSSV MD (ft) and TVD (ft):PKR:
12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work:
Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service
14. Estimated Date for 15. Well Status after proposed work:
Commencing Operations:OIL WINJ WDSPL Suspended
16. Verbal Approval:Date:GAS WAG GSTOR SPLUG
Commission Representative: GINJ Op Shutdown Abandoned
Contact Name:
Contact Email:
Contact Phone:
Date:7/2/2021
Conditions of approval: Notify Commission so that a representative may witness Sundry Number:
Plug Integrity BOP Test Mechanical Integrity Test Location Clearance
Other:
Post Initial Injection MIT Req'd? Yes No
Spacing Exception Required? Yes No Subsequent Form Required:
APPROVED BY
Approved by: COMMISSIONER THE COMMISSION Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
659-7506
Baker B-40 SC-1, Baker GT47D4
duel, Baker GT47D4 Duel
MD 4951' TVD 3794', MD
4843' TVD 3689', MD 4912'
TVD 3756'
Size
Authorized Signature:
7/30/2021
2 3/8"
Perforation Depth MD (ft):
L-80
COMMISSION USE ONLY
Authorized Name:
Tubing Grade:Tubing MD (ft):
3713' - 3976'
Perforation Depth TVD (ft):Tubing Size:
4868' - 5136'
Authorized Title:
17. I hereby certify that the foregoing is true and the procedure approved herein will not
be deviated from without prior written approval.
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL0025649
201-084
P.O. Box 100630, Anchorage, Alaska 99508 50029230160000
ConocoPhillips Alaska, Inc.
Kuparuk Riv U WSAK 1C-123
Kupararuk River / West Sak Oil
3986'
PRESENT WELL CONDITION SUMMARY
Length TVD Burst
4930'
MD
4276'
3985'
5440'
4943'
158'158'
5145'
117'16"
7 5/8"
4 9/16"
5398'
Well Integrity Field Supervisor
Roger Mouser / Roger Winter
n1927@conocophillips.com
m
n
P
s
66
t
y t
_
c
Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval.
By Samantha Carlisle at 7:46 am, Jul 02, 2021
321-331
Digitally signed by Roger Winter
DN: CN=Roger Winter, E=n1927@conocophillips.com, C=US
Reason: I am the author of this document
Location: your signing location here
Date: 2021.07.02 05:23:46-08'00'
Foxit PhantomPDF Version: 10.1.3
Roger Winter
DSR-7/6/21
4,281
SFD 7/2/2021
SFD 7/2/2021
3,9855,145
X
X 10-404
ext conductor
Photo document pre and post extension
VTL 7/14/21
5,445
50-029-23016-00-00
JLC 7/14/2021
Jeremy Price Digitally signed by Jeremy Price
Date: 2021.07.14 11:29:33
-08'00'
RBDMS HEW 7/14/2021
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
01 July 2021
Commissioner Jessie Chmielowski
Alaska Oil & Gas Commission
333 West 7th Avenue, Suite 100
Anchorage, AK 99501
Dear Commissioner Chmielowski,
Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips
Alaska, Inc. well KUP 1C-123 (PTD 201-084) to extend conductor.
Summary: Conductor has subsided or well has grown 8” or more so we would like to add
conductor to cover the surface casing.
Please contact Roger Winter or Roger Mouser at 659-7506 if you have any questions.
Sincerely,
Roger Winter
Well Integrity Field Supervisor
ConocoPhillips Alaska, Inc.
Digitally signed by Roger Winter
DN: CN=Roger Winter,
E=n1927@conocophillips.com, C=US
Reason: I am the author of this document
Location: your signing location here
Date: 2021.07.02 05:23:16-08'00'
Foxit PhantomPDF Version: 10.1.3
Roger Winter
Conductor has subsided or well has grown 8” or more
Last Tag
Annotation Depth (ftKB) End Date Wellbore Last Mod By
Last Tag: SLM (Short String) 4,897.0 6/6/2019 1C-123 zembaej
Last Rev Reason
Annotation End Date Wellbore Last Mod By
Rev Reason: Changed GLM#2 to INJ and corrected PACKER(@4,915')
ID to 1.995"
4/6/2021 1C-123 pproven
Casing Strings
Casing Description
CONDUCTOR
OD (in)
16
ID (in)
15.06
Top (ftKB)
41.0
Set Depth (ftKB)
158.0
Set Depth (TVD) …
158.0
Wt/Len (l…
62.50
Grade
H-40
Top Thread
WELDED
Casing Description
PRODUCTION 8
5/8 x 7 5/8"
OD (in)
7 5/8
ID (in)
6.87
Top (ftKB)
42.2
Set Depth (ftKB)
5,439.9
Set Depth (TVD) …
4,275.8
Wt/Len (l…
29.70
Grade
L-80
Top Thread
BTCM
Casing Description
GRAVEL PACK LINER
OD (in)
4 9/16
ID (in)
3.96
Top (ftKB)
4,943.5
Set Depth (ftKB)
5,145.3
Set Depth (TVD) …
3,985.4
Wt/Len (l…Grade Top Thread
SLHT
Liner Details
Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com
Nominal ID
(in)
4,943.5 3,786.9 10.36 PBR BAKER 80-40 PBR 4.000
4,947.5 3,790.8 10.36 XO 3.5 x 4.5 4.500
4,949.8 3,793.0 10.36 ANCHOR BAKER 80-40 ANCHOR LATCH 3.000
4,950.6 3,793.8 10.36 PACKER BAKER B-40 SC-1 PACKER 4.000
4,955.4 3,798.5 10.35 SBE UPPER EXTENSION 4.000
4,959.3 3,802.3 10.35 SLEEVE SLIDING SLEEVE 4.240
4,961.9 3,804.9 10.34 SEAL BAKER 80-40 SEAL BORE 4.000
4,963.3 3,806.4 10.34 SBE LOWER EXTENSION 4.000
4,971.9 3,814.8 10.33 XO CROSSOVER 5" x 4" 4.000
4,972.6 3,815.5 10.33 NIPPLE OTIS 'XN' NIPPLE 3.313
4,974.0 3,816.9 10.33 SOS BAKER GPR-24 SHEAR OUT SAFETY JOINT 3.500
4,977.1 3,819.9 10.33 SCREEN BAKER 4" EXCLUDER 2000 SCREEN 3.958
4,986.7 3,829.3 10.32 SCREEN 4" BAKERWELD SCREEN 140 315 ss 4"x.020 GA 3.958
4,996.2 3,838.7 10.31 SCREEN 4" BAKERWELD SCREEN 140 315 ss 4"x.020 GA 3.958
5,033.3 3,875.1 10.28 SCREEN 4" BAKERWELD SCREEN 140 315 ss 4"x.020 GA 3.958
5,070.3 3,911.6 10.24 SCREEN 4" BAKERWELD SCREEN 140 315 ss 4"x.020 GA 3.958
5,107.7 3,948.4 10.21 SCREEN 4" BAKERWELD SCREEN 140 315 ss 4"x.020 GA 3.958
5,144.8 3,984.9 10.09 PLUG 4" BULL PLUG 0.000
Tubing Strings
Tubing Description
INJ TUBING (Blue)
String Ma…
2 3/8
ID (in)
2.00
Top (ftKB)
36.2
Set Depth (ft…
4,930.1
Set Depth (TVD) (…
3,773.6
Wt (lb/ft)
4.60
Grade
L-80
Top Connection
Hydrill 511
Completion Details
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des Com
Nominal
ID (in)
36.2 36.2 0.00 HANGER VETCO GRAY DUAL TUBING HANGER 2.375
4,843.4 3,688.6 12.10 PACKER BAKERE GT47D4 DUAL PACKER (LONG STRING SET) 1.995
4,851.0 3,696.1 11.95 SWIVEL 2.375" TELESCOPING SWIVEL SUB 1.995
4,860.4 3,705.3 11.78 SLEEVE-C CMD SLEEVE (CLOSED 8/15/2005) 1.990
4,889.9 3,734.2 11.23 NIPPLE HES 'X' NIPPLE 1.750
4,909.7 3,753.7 10.86 SEAL BORE SEAL BORE 1.875
4,912.0 3,755.9 10.82 PACKER BAKER GT47D4 DUAL PACKER (LONG STRING SET) 1.995
4,928.0 3,771.6 10.52 NIPPLE HES 'XN' NIPPLE 1.875
4,929.0 3,772.6 10.50 WLEG 1.995
Tubing Description
INJ TUBING (Red)
String Ma…
3 1/2
ID (in)
2.99
Top (ftKB)
36.2
Set Depth (ft…
4,943.5
Set Depth (TVD) (…
3,786.9
Wt (lb/ft)
9.30
Grade
L-80
Top Connection
HYDRIL
Completion Details
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des Com
Nominal
ID (in)
36.2 36.2 0.00 HANGER VETCO GRAY DUAL TUBING HANGER 3.500
4,735.3 3,583.9 16.25 NIPPLE Weatherford Landing NO GO Nipple w/5' Seal Bore/ Polished Bore 2.680
4,740.0 3,588.4 16.08 XO 3.5 x 2.375 2.992
4,839.0 3,684.3 12.23 ANCHOR BAKER K-22 ANCHOR 2.688
4,839.4 3,684.7 12.21 Scoophead BAKER 47D SCOOPHEAD wSEAL BORE 2.375
4,846.4 3,691.6 12.04 PACKER BAKER GT 47D4 DUAL PACKER (LONG STRING SET) 1.995
4,855.1 3,700.1 11.88 BLAST JT BLAST JOINT (OAL=59') 1.995
4,915.1 3,758.9 10.76 PACKER BAKER GT 47D4 DUAL PACKER (LONG STRING SET) 1.995
4,921.8 3,765.5 10.64 BLAST JT BLAST JOINT PUP (OAL=10') 1.995
4,931.7 3,775.2 10.46 NIPPLE HES 'X' NIPPLE 1.875
4,932.7 3,776.2 10.44 BLAST JT BLAST JOINT PUP (OAL=10') 1.995
4,942.5 3,785.9 10.36 SHOE BAKER 80-40 SS22 SNAP LATCH w/RACHETING MULESHOE 2.375
Tubing Description
COIL TUBING
String Ma…
2
ID (in)
1.69
Top (ftKB)
41.0
Set Depth (ft…
4,735.0
Set Depth (TVD) (…
3,583.6
Wt (lb/ft) Grade Top Connection
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top
(ftKB)
Top
(TVD)
(ftKB)
Top Incl
(°) Des Com Run Date ID (in) SN
4,729.0 3,577.8 16.48 PBR Blount Tool PBR 10/27/2001 1.562
4,928.0 3,771.6 10.52 REGULATOR XXN & BF Baker Flow Regulator-Set 520
BWPD w/14/64" Orifice
5/29/2002 0.219
5,146.0 3,986.1 10.08 PLUG 7 5/8" BAKER N-1 BRIDGE PLUG 7/29/2001
5,240.0 4,078.7 9.76 CEMENT 7/29/2001
1C-123, 4/6/2021 5:04:18 PM
Vertical schematic (actual)
PRODUCTION 8 5/8 x 7
5/8"; 42.2-5,439.9
CEMENT; 5,240.0
PLUG; 5,146.0
GRAVEL PACK LINER; 4,943.5-
5,145.3
IPERF; 5,116.0-5,136.0
FRAC; 5,116.0
IPERF; 5,040.0-5,070.0
FRAC; 5,020.0
IPERF; 5,020.0-5,034.0
IPERF; 4,994.0-5,000.0
FRAC; 4,980.0
IPERF; 4,980.0-4,986.0
IPERF; 4,932.0-4,944.0
REGULATOR; 4,928.0
PACKER; 4,915.1
PACKER; 4,912.0
GAS LIFT; 4,896.8
IPERF; 4,868.0-4,900.0
PACKER; 4,846.4
PACKER; 4,843.4
GAS LIFT; 4,791.3
PBR; 4,729.0
CONDUCTOR; 41.0-158.0
KUP INJ
KB-Grd (ft)
46.09
Rig Release Date
6/21/2001
1C-123
...
TD
Act Btm (ftKB)
5,445.0
Well Attributes
Field Name
WEST SAK
Wellbore API/UWI
500292301600
Wellbore Status
INJ
Max Angle & MD
Incl (°)
56.43
MD (ftKB)
2,416.90
WELLNAME WELLBORE1C-123
Annotation
Last WO:
End DateH2S (ppm) DateComment
SSSV: NONE
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft
)Type Com
4,868.0 4,900.0 3,712.7 3,744.1 WS D, 1C-123 8/2/2001 4.0 IPERF 4.5" BH
4,932.0 4,944.0 3,775.5 3,787.3 WS B, 1C-123 8/2/2001 4.0 IPERF 4.5" BH
4,980.0 4,986.0 3,822.7 3,828.7 WS A4, 1C-123 7/28/2001 12.0 IPERF 4.5" BH
4,994.0 5,000.0 3,836.5 3,842.4 WS A4, 1C-123 7/28/2001 12.0 IPERF 4.5" BH
5,020.0 5,034.0 3,862.1 3,875.9 WS A3, 1C-123 7/25/2001 12.0 IPERF 4.5" BH
5,040.0 5,070.0 3,881.8 3,911.3 WS A3, 1C-123 7/25/2001 12.0 IPERF 4.5" BH
5,116.0 5,136.0 3,956.6 3,976.3 WS A2, 1C-123 7/22/2001 12.0 IPERF 4.5" BH
Stimulation Intervals
Interva
l
Numbe
r Type Subtype Start Date Top (ftKB) Btm (ftKB)
Proppant
Designed (lb)
Proppant
Total (lb)
Vol Clean
Total (bbl)
Vol Slurry
Total (bbl)
1 FRAC 7/22/2001 5,116.0 5,136.0 0.0 0.00 0.00
2 FRAC 7/25/2001 5,020.0 5,070.0 0.0 0.00 0.00
3 FRAC 7/29/2001 4,980.0 5,000.0 0.0 0.00 0.00
Mandrel Inserts
St
ati
on
N
o/Top (ftKB)
Top (TVD)
(ftKB) Make Model OD (in) Serv
Valve
Type
Latch
Type
Port Size
(in)
TRO Run
(psi) Run Date Com
1 4,791.3 3,637.9 CAMCO KBMM 1 GAS LIFT DMY BK-5 0.000 0.0 3/21/2002
2 4,896.8 3,741.0 CAMCO KBMG-
W
1 INJ RFW-1 BK-5 0.125 0.0 5/3/2002
Notes: General & Safety
End Date Annotation
11/19/2003 NOTE: PRODUCTION STRING CONVERTED TO INJECTION
5/3/2002 NOTE: Flange for wellwork access to 2 3/8" tbg: S/N 4979635
5/3/2002 NOTE: Flange for wellwork access to 3.5" tbg S/N 4979625
1C-123, 4/6/2021 5:04:19 PM
Vertical schematic (actual)
PRODUCTION 8 5/8 x 7
5/8"; 42.2-5,439.9
CEMENT; 5,240.0
PLUG; 5,146.0
GRAVEL PACK LINER; 4,943.5-
5,145.3
IPERF; 5,116.0-5,136.0
FRAC; 5,116.0
IPERF; 5,040.0-5,070.0
FRAC; 5,020.0
IPERF; 5,020.0-5,034.0
IPERF; 4,994.0-5,000.0
FRAC; 4,980.0
IPERF; 4,980.0-4,986.0
IPERF; 4,932.0-4,944.0
REGULATOR; 4,928.0
PACKER; 4,915.1
PACKER; 4,912.0
GAS LIFT; 4,896.8
IPERF; 4,868.0-4,900.0
PACKER; 4,846.4
PACKER; 4,843.4
GAS LIFT; 4,791.3
PBR; 4,729.0
CONDUCTOR; 41.0-158.0
KUP INJ 1C-123
...
WELLNAME WELLBORE1C-123
• •
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE: Wednesday,May 16,2018
TO: Jim Reggege, 4
P.I.Supervisor ` , 5 l SUBJECT: Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA,INC.
1C-123
FROM: Austin McLeod KUPARUK RIV U WSAK 1C-123
Petroleum Inspector
Src: Inspector
Reviewed B�
P.I.SuprvJ''
NON-CONFIDENTIAL Comm
Well Name KUPARUK RIV U WSAK 1C-123 API Well Number 50-029-23016-00-00 Inspector Name: Austin McLeod
Permit Number: 201-084-0 Inspection Date: 5/12/2018 ✓
Insp Num: mitSAM180513200709
Rel Insp Num:
Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min
Well l 1C-123 ' Type Inj W TVD 3688 . Tubing 871 871 " 866 - 865 '
PTD 2010840 - Type Test SPT 1Test psi 1500 IA 150 1800 - 1720 - 1700
BBL Pumped: 1.1 ' BBL Returned: 1.1 OA
Interval
4YRTST P/F P
Notes: MIT-IA.No OA.
SCANS JUN 0 4:Z02
Wednesday,May 16,2018 Page 1 of 1
• •
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE: Wednesday,October 28,2015
TO: Jim Regg
P.I.Supervisor efet I/I 3II S SUBJECT: Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA INC
1C-123
FROM: Jeff Jones KUPARUK RIV U WSAK IC-123
`B
Petroleum Inspector SCANNED , _1 0 �. _ Li lb
Src: Inspector
Reviewed By:
P.I.Supry _—
NON-CONFIDENTIAL Comm
Well Name KUPARUK RIV U WSAK 1C-123 API Well Number 50-029-23016-00-00 Inspector Name: Jeff Jones
Permit Number: 201-084-0 Inspection Date: 10/16/2015
Insp Num: mitJJ151017071744
Rel Insp Num:
Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min
Well] ]c 123 Type Inj w` TVD 3688Tubing��1 672 672
673 654 r
H
PTD 2010840 Type Test SPT Test psi 1500 I IA r 1520 ' 2310 - 2260 - 2240 -
Intervall4vRTST p�F P OA I
Notes: Monobore injector. 1 well inspected,no exceptions noted.
Wednesday,October 28,2015 Page 1 of 1
MEMORANDUM • State of Alaska •
Alaska Oil and Gas Conservation Commission
TO. DATE: Tuesday, May 25, 2010
Jim Regg ~
P.I. Supervisor ~ ~ ~ ~(25I IG SUBJECT: Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA INC
1 C-123
FROM: John Crisp KUPARUx xIV U wsAx ]c-123
Petroleum Inspector
Src: Inspector
NON-CONFIDENTIAL
Reviewed By:
P.I. Suprv '~~~
Comm
Well Name: KUPARUK RIV U WSAK 1C-123
Insp Num: mitJCr100S23173145
Rel Insp Num: API Well Number: 50-029-23016-00-00
Permit Number: 201-084-0 Inspector Name: John Crisp
Inspection Date: 5/21/2010
Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
~,ep ]x123Type Inj. ~' TVD ! 36as i IA 600 2220 z19o
- 21 so
P.T.D~ zo]osa~T p st sPT Test ps oo / O,~ ~
Interval aYRTST p~ P ,~ Tubing i ] ]06 nos nos ]]o~
NOtes: 1.3 bbls pumped for test. Monobore injectoi. Emergency slips set with casing displacing slips but casing is still centered.
eg~,~ .. - f ~j~r
Tuesday, May 25, 2010 Page 1 of 1
•
WELL LOG TRANSMITTAL
To: Alaska Oil and Gas Conservation Comm.
Attn.: Christine Mahnken
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
RE: Shut-in Bottom Hole Pressure: 1C-123
Run Date: 7/2/2009
November 20, 2009
The technical data listed below is being submitted herewith. Please address any problems or
concerns to the attention of:
Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518
1 C-123 _ ~.. _. _~,.~'...
Digital Data in LAS format, Digital Log Image file 1 CD Rom
50-029-23016-00
~'~l#~~~~ JAi~ ~ ~ 2Q1~
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE
TRANSMITTAL LETTER TO THE ATTENTION OF:
Halliburton
Wireline & Perforating
Attn: Rafael Barreto
6900 Arctic Blvd.
Anchorage, Alaska 99518
Office: 907-273-3527
Fax: 907-273-3535
rafael.barreto@halliburton:com
V `~- ~ ~_~~~-l
j ~~~~
Date: _ Signed:
.
.
~
ConocoPhillips
Alaska
JUL 1) 3 2007
8{
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
July 2,2007
QD t - D <64-
Mr. Tom Maunder
Alaska Oil & Gas Commission
333 West ih Avenue, Suite 100
Anchorage, AK 99501
~CANNED JUL 0 5 2007
Dear Mr. Maunder:
Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Some of
these wells were found to have a void in the conductor by surface casing annulus. The volume of
annular void subsequently was filled with a corrosion inhibiter engineered to prevent water from
entering the annular space. As per previous agreement with the AOGCC, this letter and
spreadsheet serves as notification that the treatments took place and meets the requirements of
form 10-404, Report of Sundry Operations.
Please call Perry Klein or M.J. Loveland at 907-659-7043, if you have any questions.
~~
M.J. Loveland
ConocoPhillips Well Integrity Supervisor
e------/
.
.
ConocoPhillips Alaska Inc.
Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off
Report of Sundry Operations (10-404)
Kuparuk Field
Date
7/1/2007
Corrosion
Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/
Well Name PTO# cement pumped cement date inhibitor sealant date
ft bbls ft na Qal
1C-19 203-054 28" none 28" na 12 6/24/2007
1 C-123 201-084 22" none 22" na 24 7/1/2007
1C-127 201-114 18" none 18" na 12 7/1/2007
1 C-133 201-077 16" none 16" na 8.5 7/1/2007
~ 203-003 I~ 27" none 27" __nn 1011III ...
-
3K-12 186-165 6" none 6" na 3 6/24/2007
3K-19 201-108 6" none 6" na 3 6/24/2007
3K-20 201-088 4" none 4" na 1 6/24/2007
3K-23 197-097 8" none 8" na 5 6/24/2007
3K-24 198-249 4" none 4" na 1 6/24/2007
3K-25 198-081 6" none 6" na 3 6/24/2007
3K-26 197-077 8" none 8" na 5 6/24/2007
3K-27 197-046 6" none 6" na 3 6/24/2007
3K-31 198-082 8" none 8" na 5 6/24/2007
3K-34 198-077 7" none 7" na 4 6/24/2007
3K-35 197-109 3" none 3" na 2 6/24/2007
.
.
ConocJ'Phillips
Robert Buchholz / Robert Christensen
Production Engineering Tech.
Greater Kuparuk Unit, NSK-69
PO Box 196105
Anchorage, AK 99519-6105
Phone: (907) 659-7535
Fax: 659-7314
March 9, 2007
R. ECEI' Ir:: r1
" ',';' ~_"J:".ð
MAR 1 3 I ì
Tom Maunder, P.E.
Senior Petroleum Engineer
State of Alaska, Oil & Gas Conservation Commission
33 W. ih Ave. Ste. 100
Anchorage, AK 99501
Alaska Oil & Gas Com" Cürnmission
Anchoragc
Dear Mr. Maunder,
ConocoPhillips Alaska, Inc. has completed the West Sak EOR Pilot Project.
Enclosed you will find 10-404 Report of Sundry Well Operation for ConocoPhillips
Alaska, Inc. well1C-123 (PTD 201-084). The report records the change of well status
from WAG Injection to Water Injection Service.
If you have any questions regarding this matter, please contact myself or Robert
Buchhloz at 659-7535.
sCANNED MAR 2 0 2007
Sincerely,
M~
Robert D. Christensen
Attachments
· MAR 1 3 2007
STATE OF ALASKA . Alaska Oil & Gas Con3 C "
ALASKA OIL AND GAS CONSERVATION COMMISSION Anchora . omm;sslon
REPORT OF SUNDRY WELL OPERATIONS ge
158' 158'
135' 135'
5440' 4276'
5144' 3984'
5145' 3985' ,
\.-,~,~'¿) ~Co",\~~¿'\Ð~()..~~~à hi
~\<CJd-\S~\<~ ~\~\(!:~'\~-\~~
~ \ \. ~\O\Q:c..~ co~\~ð ~s\;;b:Jfa,
~~~~ ~ \~~~~Q~~~\S\\dÖcc.,
~\\~~~~~ ,~~«:.~\-...)~ ql\-o~
Packers & SSSV (type & measured depth) pkr- BAKER GT 4704 DUAL PACKER; BAKER GT 4704 DUAL PACKER; BAKER GT 4704 DUAL PACKER; BAKER GT 4704
DUAL PACKER; BAKER GT 4704 DUAL PACKER pkr- 4843'; 4912'; 4843', 4912': 4951'
no SSSV no SSSV
12. Stimulation or cement squeeze summary:
Repair Well D
Pull Tubing D
Operat. ShutdownD
1. Operations Performed: Abandon D
Alter Casing D
Change Approved Program D
2. Operator Name:
ConocoPhillips Alaska, Inc.
3. Address:
P. O. Box 100360, Anchorage, Alaska 99510
7. KB Elevation (ft):
RKB 102'
8. Property Designation: f
Kuparuk River Unit ~!:>~ 7$(,'; }r> ~.I~· ø 1
11. Present Well Condition Summary:
Total Depth
5445' /
measured
true vertical
4281' .
Effective Depth
measured
true vertical
Casing
Structural
CONDUCTOR
PRODUCTION
PRODUCTION
SCREEN
LINER
Length
Size
158'
33'
5305'
167'
194'
16"
7-5/8"
7-5/8"
4-1/2"
3-1/2"
Perforation depth:
Measured depth:
4868
true vertical depth:
Tubing (size, grade, and measured depth)
2-3/8", L-80, 4934' MD.
Intervals treated (measured)
Treatment descriptions including volumes used and final pressure:
13.
Plug Perforations D
Perforate New Pool D
Perforate D
4. Current Well Status:
Development D
Stratigraphic D
Stimulate D
Waiver D
Time Extension
o
D
D
\GIN to WlNJ
Other
Service
Re-enter Suspended Well
5. Permit to Drill Number:
201-084 1 -
6. API Number:
50-029-23016-00 /
Exploratory D
o
9. Well Name and Number:
1C-123,
10. Field/Pool(s):
Kuparuk River Field I West Sak Oil Pool /
feet
feet
feet
feet
Plugs (measured)
Junk (measured)
MD
TVD
Burst
Collapse
3713
Representative Daily Average Production or Injection Data
Oil-Bbl Gas-Met Water-Bbl Casin Pressure
182
182
Prior to well operation
Subsequent to operation
14. Attachments
Copies of Logs and Surveys run _
Daily Report of Well Operations _
Tubin Pressure
15. Well Class after proposed work:
Exploratory D Development D Service 0
16. Well Status after proposed work:
oilD GasD WAGD GINJD WINJ 0
WDSPL D
Contact
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Sundry Number or N/A if C.O. Exempt:
N/A
Form 10-404 Revised 04/2004
Title
Phone 659-7535
Production Engineering Technician
Date 3 'q ()
R8UMS BfL MAR 1 9 2007 A'b 3 / / ¿ -l>7
SUb~~:6?
fìDI~I~\!~f
MEMORANDUM
e
State of Alaska
e
Alaska Oil and Gas Conservation Commission
DATE: Wednesday, May 31,2006
SUBJECT: Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA INC
1C-123
KUPARUK RIV U WSAK lC-123
v t6 L\'
;)..,0 \ ""
TO:
Jim Regg
P.I. Supervisor
--.
FROM:
Jeff Jones
Petroleum Inspector
Src: Inspector
Reviewed By:
P.I. Suprv , .-r§L
Comm
NON-CONFIDENTIAL
Well Name: KUPARUK RIY U WSAK IC-123 API Well Number SO-029-230 16-00-00 Inspector Name: Jeff Jones
Insp Num: mitlJ0605301628S7 Permit Number: 20 I -084-0 Inspection Date: S/30/2006
Rei Insp N urn
Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
-~ ' I I i IA ! i
Well i IC-123 !Type Inj. I N I TVD 3688 0 1850 1770 I 1750
i .~ ¡
P.T. i 2010840 ITypeTest i SPT i Test psi OA I ---¡--- I
1500 i ¡
f-- ! I -+
Interval 4YRTST P/F P Tubing i 400 I 400 i 400 I 400
Notes 2.S bbls diesel pumped. 1 well house inspected; no exceptions noted. Monobore injector (no OA).
"f'" ..... U\\.ic:r JUN ~. S
'.)'VtlïJ~~"~~'"~ j... ~-
Wednesday, May 31,2006 Page 1 of 1
e
e
~~--,
,
"'r;¡¡¡;'::r
"'. II;
MICROFILMED
07/25/06
DO NOT PLACE
ANY NEW MATERIAL
UNDER THIS PAGE
F: \LaserFiche\CvrPgs _ Inserts\Microfi 1m _ Marker. doc
MEM 0 RAND UM
State of Alaska
Alaska Oil and Gas Conservation Commission
TO:
Jim Regg
P.I. Supervisor
~~tt 1~11~~
DATE: Friday, October 0 I, 2004
SUBJECT: Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA INC
IC-123
KUPARUK RIV U WSAK IC-123
FROM:
John Spaulding
Petroleum Inspector
Src: Inspector
Reviewed By: J
P.I. Suprv 3ß/<. D I( (04~
Comm
NON-CONFIDENTIAL
Well Name: KUPARUK RIV U WSAK IC-123 API Well Number: 50-029-23016-00-00 Inspector Name: John Spaulding
Insp Num: miUS0409241 05948 Permit Number: 201-084-0 Inspection Date: 9/312004
Rei Insp Num:
Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
Well IC-123 Type Inj. N TVD 3688 IA 950 1900 1885 1880
P.T. 2010840 TypeTest SPT Test psi 922 OA
Interval !NIT AL P/F P Tubing 1025 \100 \100 \100
Notes:
Friday, October 01, 2004
Page 1 of 1
(~tiÒns P~rfòtme(f
STATE OF ALASKA
AlA~KA Oil AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
AbandôQ. 'd~ ", Sus~rid[j' O~,~~~Q'Shutdo~"::'O' "
.' Àlterc~¡ngtJ 'R~pa!rW~II[J "/~Iu§~é~~~~,~~~r~~o,,,
~~g,~eA¡i~~þ';è~,prog;~fn':O P~II j~pfng 'q, ~.rf~rat~tt~~.~1 ,d.,,'
2. Operator Name: ; '4:9~i'f.~nt~~IIT;
ConocoPhillips Alaska, Inc. 'Oévelopmé~t P'
3. Address:~tr:apø~ç . 0
P. O. Box 100360
7. KB Elevation (ft):
RKB 102'
~
r"\
() /L ~ úJJ:,UJ
, ,,;äpìôifitõ~ 0
, , ';Ser.íice 0" ,
J?eri6(atf{O .' ,Variancë . 0 Annular Disp. 0
stjfhú~~te q" «:'" . 11me ~~êf\Si9n 0 "Other 0,
, '~~ent~~\Jspendød Well 0 ' , . ,
5. Permit to Drill Number:
--.-..2001"084 1-
6. API Number:
50-029-23016-00
" " '
, , ,
9. Well Name and Number:
1C-123l
8. Property Designation:
Kuparuk River Unit
11. Present Well Condition Summary:
10. FieldlPool(s):
West Sak
Total Depth measured 5445' feet
true vertical 4281' feet
Effective Depth measured feet
true vertical feet
Casing Length Size MD
Structural
CONDUCTOR 158' 16" 158'
PRODUCTION 33' 7-5/8" 135'
PRODUCTION 5305' 7-5/8" 5440'
SCREEN 167' 4-1/2" 5144'
LINER 194' 3-1/2" 5145'
Plugs (measured)
Junk (measured)
TVD
Burst
Collapse
158'
135'
4276'
3984'
Perforation depth:
Measurød depth: 4868-5136
Tubing (size, grade, and measured depth)
2-318", L-80, 4934' MD.
RECEIVED
MAY 2 8 2004
true vertical depth: 3713-3976
Packers & SSSV (type & measured depth) pkr= 4843'; 4912'; 4843'; 4912'; 4951'
no SSSV no SSSV
12.5tirhulation'or çement sqUeeze surymíary:
Alaska Oil & Gas Cons. Commission
Anf'.ht)p'g~
Intervals treated (measured)
N/A
Treatment descriptions including v~llImes used and finalpressu~e: ,
13. Reprø:~rit'atîv~Qa¡!y 'Avèragø~[pdùCtion:orlrijeêÿon Data
Oil"BbI ' Gãš'MCf' V/ater-Bbl
4 21 553
~ .,"
193
15.Well Classáft'er þ'toposedÍNþ.rk:
E,q::¡loratoryO ' . Deve.topment" 0 Service 0,
. . , ' .
1 q. Well 'Status after prbposed work:
ouO . GasO WAGD GINJO .WINJ 0
17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt:
Contact Jeff Spencer @ 659"7226
Printed Namyj If ~~ D)1J~nsen I
Signatu~~
Prior to well operation
Sub.s~\J.ef)t to Qþer¡;¡tiof)
14. Attåc;hmerits '
COpies of Logs and Surveys run -
Daily Report of Well Operations_X
CasinQ Pressure
985
.~~20
TúbÍl1,q Pressure:
1005
1008
WDSPLO
Title
Phone
Production Engineering Technician. d
659-7535 Dæe~~~f')'
RBDMS BFL SUBMIJOifl(J~~A"2ÐO~
Form 10-404 Revised 2/2003 .
0 q , r-, , f\f A ,
REPORT OF SUNDRY WELL OPERATIONS
I. Operations Ped'ormed: Abandon [~ Suspend [] Op~tion Shutdo~m
Re'pa~
II
.. :
. 'Al{er Casing .~' ~ Peffoations ~ :.. 'Time S~nsion .':- O~er ~.~
"Change'Approved program ' ~ Pa,.~ing ~' ' Pe~o~te N~w'~ ..:~........ '~ ' : ~". · 'Re-enter Saspended.well ~ ' '"
2. Operator Name: 4. Current,Well'.Status:'" . ~';" ".,.': 5. Pe~it to D~II Number:
ConocoPhillips Alaska, Inc. . Dwel~pm'~nt ~ . E~lomlo~ '~ 201-084 /
3. Address: . Stmtigra~hic ~ '. ' So,ice ' ~ 6. APl Number:
P. O. Box 1OO360 50-029-23016-00
7. KB Elevation (E): 9. Well Name and Number:
RKB 102' 1C-123L
8. Prope~ Designation: 10. Fiel~P~l(s):
Kuparuk River Unit West Sak
11. Present Well Condition Summa~:
Total Depth measured 5445' feet
true ve~ical 4281' feet Plugs (measured)
Effective Depth measured feet Junk (measured)
true ve~ical feet
Casing Len~h Size MD ~D Burst Collapse
Structural
CONDUCTOR 158' 16" 158' 158'
PRODUCTION 33' 7-5/8" 135' 135'
PRODUCTION 5305' 7-5/8" 5~0' 4276'
SCREEN 167' 4-1/2" 5144' 3984'
LINER 194' 3-1/2" 5145'
Pedomtion depth: Measured depth: 4868-5136
true ve~ical depth: 3713-3976
Tubing (size, grade, and measured depth) 2-3/8", L-80, 4934' MD.
Packers & SSSV (type & measured depth) pkr= 4843'; 4912'; 4843'; 4912'; 4951'
no SSSV no SSSV
· =.q;12;.stimul~ti0n. b.~:cemeht ~qUe~ze'sum~a~'f.==.~:.::.,'.:'~:;:.. :.~ .... :: :h..." ....... "' '~..:.. '.'..'= :'.~:.: .;:: .':... :. ::: ....'...= . ' ' ......::;.': · =;'.:..":." ...'.:' '.. ;': ~:.~::::~ 7:... :.. ;~:: ...:~::.: .'. ".'.'~
;;:.=;'; . .. :...~ · ... -... ..'. · :.; .'.','... · ...': .= ...;.... '. .~.~..:...' ... · .~.. .:: :..'...= =....... =. ... ... .. . .. '; .. =.:..:...;.... · .=. .... · . · . .... . .... · ,..~. =.. . · .....: . :. · .. . . ....:
:'~;:'~. ~Tr~a{~'ht aes:~ipti~'~;ihduding~'voi~';~sea"a~d.finaJ pressure:.. ". · '...' .' .... ' ;;..="~." ·
:~ ~:t ~;.;.=:'. ;'.. 7'.'.==':'~'" ~=. ";':= ~:. ::' '::~.'' ~.'". ~::''' "='.. :" v.. :'.=.;..:.~': .'..."!.' :~
':~".:. ;"':' ~:..:"~'":..' ...". ;' .'' ':;. "'= ..~ ';. ': ": ." '.:"..:" ':.
. :;;;'.~;:.~ ~Pr~;;~'~.~.=~:~t~';.'~: ;..: ':'. ;' '.: ': '=.;
· .,~4;;A~ch.me;nt~.:::.:' .= ~=.. . .? :?.:. .. .. :; :..= =: · :. :..,. ~. =. :r ...=
::'.=~'.' ' .. bai'l~';Rep$~';~['Weil'~O~{~0ds:'".:.:x" .~::.:' ~:: .:'
17. i hereby ce~i~ that the foregoing is true and correct to the best of my knowledge. ~ Sund~ Number or N/A if C.O. Exempt:
l
'~:ff:S"en'~er'~'65~'7~''e[ p c ~-~o " '' .... ' '~' "'""'" ..... ..'. · ' ' ..'.=" '': '".. ~. :". "':':. ""." '
.Contact
. . .:... . . .. . .. : . · . , ;" . . '. ..
.'Printed Name ~ ~ D.'C~ist~nsen .= '..' · Title' · ...... . Pr0dU'Cti~n Engineering TechniCian ~:~.: .'
Signature ~~~ Phone .... '659.7535 Date /~/~ ~.,.,
Form 10-404 Revisad 2,'2003 ..... , . ORIGINAL
.'"',,'.-.,,.:-,'.':',",.,'...:'- ' DEC,
SUBMIT IN DUPLICATE
1C-123 [..,
DESCRIPTION OF WORK COMPLETED
SUMMARY
Date Event Summary
111101031C~'mrti'~r~Cb'd.WAG'EOR:!nje'dtiOn=.. . .,: :i:' ..: '" .'....i"'. ......... '". ' ..'.:. ":
Re: 1C-123L Conversion
,7
Subjei;t: Re: 1C-123L Conversion
Date: Fri, 5 Sep 2003 16:48:53 -0800
From: "NSK Problem Well Supv" <n1617@conocophillips.com>
To: Tom Maunder <tom_maunder@admin.state.ak.us>
Tom
The plan is to pull the jet pump and standing valve with slickline, and
inject down through the coil string.
Let me know if you have any additional questions
MJ Loveland
Problem Well Supervisor
ConocoPhillips Alaska Inc.
(907) 659-7224, 659-7043
Tom Maunder <tom_maunder@admin.state.ak.us>
09/05/2003 03:06 PM
To: NSK Problem Well Supv/PPCO@Phillips
cc:
Subject: 1C-123L Conversion
M J,
I am looking at the sundry request and on the drawing it shows that
there is a coil string in the long string. Will that be pulled??
Tom
(See attached file: tom_maunder.vcf)
i Torn Maunde~r <tom maunder~admin.state.ak.us>
Sr. Petroleum Engineer
Alaska Oil and Gas Conservation Commission
L
9/6/2003 2:39 PM
ConocoPhillips
Alaska
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
September 2, 2003
Mr. Tom Maunder
Alaska Oil & Gas Co'mmission
333 West 7th Avenue, Suite 100
Anchorage, AK 99501
Dear Mr. Maunder:
Enclosed please find 10-403 Sundry Notice requests for ConocoPhillips Alaska, Inc., wells, 3N-
11. and 1. C-123L. The 3N-1.1 Sundry :is for approval to set a patch across an identified leak in the
tubing. It has a discussion/action plan and a well sche'matic attached.
The IC-123L Sundry is for approval to convert the production leg of a dual string completion to
water injection. The discussion and a well schematic are also attached.
Please call. Nina Woods or me at 907-659-7224 if you have any questions.
Since:rely,
ConocoPhi. llips Problem We.Ii Supe:rvisor
Attachme'nts
ORIGINAL
STATE OF ALASKA ("
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVAL
20 AAC 25.280
1. Type of Request: Abandon [--]
Alter casing
Change approved program
Suspend [] Operation Shutdown [-'] Perforate E~ Variance [-']
Repair well r'-] Plug Perforations E~ Stimulate r~ Time Extension
Pull Tubing [] Perforate New Pool [~] Re-enter Suspended Well E~]
Annular Disp. ~
Other ['~
2. Operator Name:
ConocoPhillips Alaska, Inc.
3. Address:
P. O. Box 100360
4. Current Well Class: I 5. Permit to Dril~j/mber:
Development _ ~'] Exploratory [--] 201-084
Stratigraphic [] Service E~ I 6. APl Number:
150-029-23016-00
7. KB Elevation (ft):
RKB 102'
9. Well Name and Number:
1C-123L
8. Property Designation: 10. Field/Pool(s):
West Sak West Sak Oil Pool
11. PRESENT WELL CONDITION SUMMARY
Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured):
Total depth MD (ft):
5445'
4281'
Casing Length Size MD
CONDUCTOR 158' 16" 158'
PRODUCTION 33' 7-5/8" 135'
PRODUCTION 5305' 7-5/8" 5440'
SCREEN 167' 4-1/2" 5144'
LINER 194' 3-1/2" 5145'
Perforation Depth MD (ft): Perforation Depth TVD (ft):
See attached schematic see attached schematic
Packers and SSSV Type: Packers and SSSV MD (ft)
TVD Burst Collapse
158
135 6490 4100
4276 6890 4790
3984
3985
Tubing Size: Tubing Grade: Tubing MD (ft):
2-3/8" L-80 4934'
pkr= BAKER GT 47D4 DUAL PACKER; BAKER GT 47D4 DUAL
no SSSV
12. Attachments: Description Summary of Proposal ['~
Detailed Operations Program
r-~ BoP Sketch
14. Estimated Date for
Commencing Operations: ASAP
16. Verbal Approval: Date:
pkr=4843'; 4912'; 4843" 4912'; 4951'
no SSSV
13. Well Class after proposed work:
Exploratory BI Development r-]
15. Well Status after proposed work:
Oil r--] Gas r-~
WAG r'-I GINJ ~
17. I hereby certify that the foregoing is true an~,correct to t~st of my knowledge.
Printed Name UJ Lovel~,a,~d
Signature .,,~/~
/ - ' Commission Use Only
Service []
Contact:
Title:
Phone 659-7224
Plugged D Abandoned [--1
WIN0 r'~ WDSPL ~
MJ Loveland/Nina Woods @ 659-7224
Problem Well Supervisor
Date ¢~,~/~'~
Conditions of approval: Notify Commission so that a representative may witness
ISundry Number:.,~c.~..~ _ O(,= ¢
Plug Integrity E~ BOP Test
Mechanical Integrity Test
Location Clearance [] ,
Other:
Subsequent Form Required:
Approved by:
COMMISSIONER
BY ORDER OF
THE COMMISSION
Form 10-403 Revised 2/2003 ·
BFL SEP 8
ORIGINAL
Date:
SUBMIT IN DUPLICATE
1C-123/..
DESCRIPTION OF WORK PROPOSED
ConocoPhillips Alaska Inc. requests approval to change the approved progam for well 1C-123L from oil
production to water injection service. Well 1C-123 is a dual string completion with one leg, 1C-123S,
approved for and currently injecting into the B & D sands and the other leg, 1C-123L approved for
production from the A sands. This request is specifically for conversion of the oil leg, 1C-123L, to water
injection. A USIT log was run on 07/11/01 showing good cement and a passing MITIA to 2425 psi was
completed on 4/27/02.
After Conversion a 10-404 will be submitted
ConocoPhil~ips A]aska, Inc,
1C-123
Thread
WELDED
BTCM
Size
2375
; PRODUCTION COMPLETION
Size
2 0O0
3500
2375
Thread
Thread
Comment
Comment
A2 FRAC, 217,000#
A4 FRAC, 58,0O0#
(494~4947,
OD:5 938)
(4947M951,
OD:4 000)
PRODUCTION JEWELRY ((YELLOW))
Description
lipple (SEE TOOL
10/27/2002)
1.562
2680
1 995
1 995
3000
1875
1995
- INJECTOR JEWELRY ((GREEN))
Description
FRAC
(4980.5000}
FRAC
(502~5070)
Description
Note
Permit to Drill 2010840
DATA SUBMITTAL COMPLIANCE REPORT
713012003
Well Name/No. KUPARUK RIV U WSAK 1C-123 Operator CONOCOPHILLIPS ALASKA INC
APl No. 50-029-23016-00-00
MD 5445 TVD 4281 Completion Dat 8/4/2001 Completion Statu lO-WI Current Status lO-WI UI~
ZZZ'i~-_-'--7_-2.2- %_~ _~-_~_7'_~.Zi ~ --'%'_ _-_-- - -- -- -_7~_7 -' __ _ _ ~.- __ ...............................................................................................................................
REQUIRED INFORMATION
Mud Log N.__gq Sample N__Qo Directional Survey No
DATA INFORMATION
Types Electric or Other Logs Run:
Well Log Information:
Log/
Data Digital Digital
Type. s. Media Fmt
(data taken from Logs Portion of Master Well Data Maint)
~.7 L
ED C GR Gamma Ray
L~, GR Gamma Ray
GR Gamma Ray
Rpt Ver LIS Verification
Interval
Log Log Run OH I Dataset
Name Scale Media No Start Stop CH Received Number Comments
Cement Bond Log 5 --Ffl'q~L 4492 5222 CH 8/3/2001 4492-5222 Color Print
1 161 5445 Open 12/6/2002 ,--1'~33
25 Blu 1 161 5445 Open 12/6/2002
25 Blu 1 161 5445 Open 12/6/2002
1 174 4163 Open 12/6/2002
Well Cores/Samples Information:
Name
Interval Dataset
Start Stop Sent Received Number Comments
ADDITIONAL INFORMATION
Well Cored? Y/~)
Chips Received? ~
Analysis ~
R~.c.~.iv~.d ?
Daily History Received? ~_~/N
Formation Tops ~;; / N
Comments:
Date:
Transmittal Form
INTEQ
To:
AOGCC
333 West 7th Ave, Suite 100
Anchorage, Alaska
99501
Attention: Lisa Weepie
Anchorage GEOScience Center
Reference: 1C-123
Contains the following:
1 LDWG Compact Disc
(Includes Graphic Image files)
1 LDWG lister summary
1 blueline- MPR Measured Depth Log
1 blueline- MPR TVD Log
LAC Job#: 160411
Sent By: Glen Horel
Received B~ ~
I
Date: Dec 5, 2002
Date:
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING
OR FAXING YOUR COPY
FAX: (907) 267-6623
Baker Hughes INTEQ
7260 Homer Drive
Anchorage, Alaska
99518
Direct: (907) 267-6612
FAX: (907) 267-6623
MEMORANDUM
State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Camille Taylor LC'
Chair
THRU: Tom Maunder
DATE: April 25, 2002
SUBJECT: Mechanical Integrity Tests
Phillips Alaska Inc.
1C
P.I. Supervisor
FROM: John H. Spaulding
Petroleum Inspector
NON- CONFIDENTIAL
119, 123
Kuparuk River Unit
Kuparuk River Field
Pretest Initial 15 Min.
Packer Depth
30 ivlin~. '~ cx-¢2 ~
P.T.D.I 2011390ITypetestl P ITestpsil 883 I CasingI 1100119501195011950I P/F I __PI
Notes:
I
vve,I I I I I I I I I
P.T.D.I 2010840 ITypetestl P ITestpsil 922 I Casingl I I I I P/F I ~
Notes: IA did not pressure up. Diagnostics in progress.
WellI I Type Inj.
P.T.D. I I Type test
Notes:
WellJ J Type Inj.
P.T.D. J JType test
Notes:
J we, J J Type Inj.
P.T.D. J J Type test
Notes:
Type INJ. Fluid Codes
F = FRESH WATER INJ.
G - GAS INJ.
S = SALT WATER INJ.
N = NOT INJECTING
Type Test
M= Annulus Monitoring
P= Standard Pressure Test
R= Internal Radioactive Tracer Survey
A= Temperature Anomaly Survey
D= Differential Temperature Test
Interval
I= Initial Test
4= Four Year Cycle
V= Required by Variance
W= Test during Workover
O= Other (describe in notes)
Test's Details
Type the test details in here. Expand or cotract the row height as needed. The sheet is protected so you will need to
unprotect first, there is no password.
Type the .test details in here. Expand or cotract the row height as needed. The sheet is protected so you will need to
unprotect first, there is no password.
M.I.T.'s performed:
Attachments:
Number of Failures:
Total Time during tests:
cc: ,
MIT report form
5/12/00 L.G. mit's KRU 1C 4-25-02 Revised js.xls 7/8/2002
Re: Jet Pumped Wells
Subject: Re: Jet Pumped Wells
From: "NSK Problem Well Supv" <n1617@lconocophil1ips.com>
Date: Sat~ 7 Dec 2002 14:07:01 -0900
To: Tom Ì\'launder <toffi_maunder@admin.state.ak.us>
CC: "n 1617" <n 1617@conocophillips.com>
Tom: 1 requested a list of surface powered jet pump wells from our PE's.
The follow~ng should be the current total for the Kuparuk area:
West Sak wells:
~lC-123 (PTD 2010840) was recently S1 for high watercut
lC-135 (PTD 2012200) is a huff and puff well and was recently put on water
injection cycle
CPF 2 are as follows:
2L-307 (PTD 1982560)
2L-313 (PTD 1982190)
2L-315 (PTD 1982180)
2L-321 (PTD 1982620)
2L-325 (PTD 1982090)
2N-303 (PTD 2001690)
2N-304 (PTD 2011300)
2N-305 (PTD 2001350)
2N-318 (PTD 2001000)
2N-319 (PTD 1981970)
2N-332 (PTD 2000790)
2N-337 (PTD 1981220)
2N-339 (PTD 1981000)
2P-415 (PTD 2012260)
There are no surface powered jet pump wells at CPF3.
I hope this answers your question. Let me know if you need more
information.
Jerry Dethlefs
ConocoPhillips Problem Well Supervisor
Tom Maunder <tom maunder@admin.scate.ak.us>
12/06/2002 09:00 AM
To:
NSK Problem Well Supv/PPCO@Phillips
cc:
Subject:
Jet Pumped Wells
Pete and or Jerry,
I have some emails f h'l b
rom a w 1 e ack regarding the wells out chere on
jet pumps. Would you please provide an updated listing of the wells
presently on jet pumps in greater KRU??
Thanks in advance.
Tom
PHILLIPS Alaska, Inc.
Subsidiary of PHILLIPS PETROLEUM COMPANY
Post Office Box 100360
Anchorage, Alaska 99510-0360
C. Mallary
Phone (907) 265-6434
Fax: (907) 265-6224
January 3, 2002
Commissioner Cammy Oechsli Taylor
State of Alaska
Alaska Oil & Gas Conservation Commission
333 West 7th Avenue Suite 100
Anchorage, Alaska 9950 !
Subject: Completion Report for 1C-123 (201-084 / 301-191)
Dear Commissioner:
Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the West
Sak well 1C-123. This well is a dual completion well with oil production from the West Sak A
sands and the water injection from the West Sak B & D sands.
If you have any questions regarding this matter, please contact Steve McKeever at 265-6826.
Sincerely,
Drilling Engineering Supervisor
PA1 Drilling
CM/skad
RECEIVED
JAN 04 200t
AlaSka 0il & Gas Cons. Commission
Anchorage
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
1. Status of well Classification of Service Well
NOTE: DUAL PURPOSE STRING IN THIS WELL: PRODUCER FOR WEST SAK A SANDS AND WATER INJECTOR INTO WEST SAK B & D SANDS
Oil r~ Gas [~] Suspended [] Abandoned r~ service r'~ SEE NOTE ABOVE
2. Name of Operator ~ ~ 7. Permit Number
Phillips Alaska, Inc. LOCA~.~. 201-084 / 301-191
:3. Address ~ 8. APl Number
P. O. Box 100360, Anchorage, AK 99510-0360 ~---,,,,~ 50-029-23016-00
4. Location of well at surface j C{;'"'i_,'L :'i!~i;ii" iL.~, ~ '6~' 9. Unit or Lease Name
1605' FNL, 873' FWL, Sec. 12, T11N, R10E, UM~_.-~.; ~.~, j ii ,..- ~:A;i~ A. ! (AS 1881, 59 Kuparuk River Unit
At Top Producing Interval ~~I 10. Well Number
1969' FSL, 1250' FEL, Sec. 11, T11 N, R10E, UM 'i~_~~. (ASP: 559773, 5966907) 1(;;-123
At Total Depth 11. Field and Pool
1923' FSL, 1308' FEL, Sec. 11, T11 N, R10E, UM (ASP: 559715, 5966861 ) West Sak Oil Pool
5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Kuparuk River Field
AMSL102'I ADL 25649 ALK 467
12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions
June 14, 2001 June 17, 2001 August 4, 2001 I N/A feet MSL 1
17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + 1-VD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost
5445' MD/4281'TVD 5145' MD/3985'TVD YES [~ No [~I N/A feetMD 2010'
22. Type Electric or Other Logs Run
GR/Res, USIT
23. CASING, LINER AND CEMENTING RECORD
SE'I-rING DEPTH MD
CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED
16" 62.5# H-40 Surface 161' 24" 3oo sx AS 1
8.625" x 36# N-80 Surface 135' 9.875" 453 bbl AS III Lite, 64 bbl Class G
7.625" 29.7# L-80 135' 5440' 9.875" tapered string - cemented above
bridge plug set @ 5148'
24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD
interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD)
2.375" 4930' 4843' & 4912'
5116' - 5136' MD 3957' - 3976' TVD 12 spf 3.5" X 2.375" 4943' 4843', 4912'
5040' - 5070' MD 3882' - 3911' TVD 12 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
5020' - 5034' MD 3862' - 3876' TVD 12 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED
4994' - 5000' MD 3837' - 3843' TVD 12 spf West Sak sand frac 217M# 12/20 sand behind pipe, 100 ppa on perfs
4980' - 4986' MD 3823' - 3829' TVD 12 spf West Sak A3 sand 120M# behind pipe, 12 ppa on perfs
4932' - 4944' MD 3776' - 3787' TVD 4 spf West Sak A4 sand 58M# 12/20 sand behind pipe, 10 ppa on perfs
4868'- 4900' MD 3713'- 3744'TVD 4 spf
27. PRODUCTION TEST
Date First Production Method of Operation (Flowing, gas lift, etc.)
December 9, 2001 JET PUMP
.Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO
12/14/2001 6 hours Test Period > 73 0 17 100I 24
Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr)
)ress. 199 psi not available 24-Hour Rate > 274 7 72 not available
28. CORE DATA
Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips.
RECEIVED
JAN 04 2002
C0mmissi0r
Anchorage
Form 10-407 Rev. 7-1-80
CONTINUED ON REVERSE SIDE
Submit in duplicate
RBDHS BFL JAN 7
29. ~'~ 30.
GEOLOGIC MARKER~ FORMATION TESTS
NAME Include interval tested, pressure data, all fluids recovered and gravity.
MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase.
West Sak D 4867' 3712'
West Sak A3 5016' 3858'
West Sak Base 5304' 4142'
Annulus left open - freeze protected with diesel.
"' 31. LIST OF'ATTACHMENTS
Summary of Daily Operations, Directional Survey
32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Steve McKeever 265-6826
Signed ~ 1.~" Title Drillinq Enqineerinq Supervisor Date ~1.. D ?,__
C. Mallary
Prepared by Sharon AIIsup-Orake
INSTRUCTIONS
General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and
leases in Alaska.
Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water
supply for injection, observation, injection for in-situ combustion.
Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other
spaces on this form and in any attachments.
Item. 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in
item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each
additional interval to be separately produced, showing the data pertinent to such interval.
Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.).
Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location
of the cementing tool.
Item 27.' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection,
Shut-in, Other-explain.
Item 28: If no cores taken, indicate "none".
Form 10-407
PHILLIPS ALASKA INC. Page:l of 11
Operations Summa Report
Legal Well Name: 1 C-123
Common Well Name: 1C-123 Spud Date: 6/11/2001
Event Name: ROT - DRILLING Start: 6/11/2001 End: 8/6/2001
Contractor Name: n1268@ppco.com Rig Release: 8/6/2001 Group:
Rig Name: Nabors 245 Rig Number: 245
Date From- To Hours Code Sub Phase Description of Operations
Code
6/13/2001 02:00-05:30 3.50!MOVE MOVE MOBMIR M/I and R/U Nabors 245E
05:30-14:00 8.50 DRILL RIRD PROD N/U Diverter system, allign rig over center o
f hole, set utility module(PJSM), change out
saver sub on top drive to fit 5" DP. 4 1/2 I
F, install bell guide on top drive, tighten st
orm clamps, R/U iron roughneck for 5" DP, c
hange out handling tools.
14:00-15:00 1.00 WELCTLBOPE PROD P/U stand of 5" DP and test diverter system
15:00-22:00 7.00 DRILL PULD PROD P/U 5" DP, torque and stand back in derrick.
Total of 50 stds. set back in derrick
22:00-00:00 2.00 DRILL PULD PROD P/U HWDP, torque and stand back in derrick
Had 9 out of 10 stands back at report time
6/14/2001 00:00-01:00 1.00 DRILL PULD PROD P/U 5" HWDP & Flex DC's and stand back in
derrick
:01:00-05:30 4.50 DRILL PULD PROD P/U~ BHA #1- 8" motor, MWD, Orient tools, Io
ad MWD and test.
05:30-06:00 0.50 DRILL CIRC PROD Break circ., RIH, tag fill at 150', wash fill t
o 161'
06:00-06:30 0.50 DRILL DRLG PROD Spud well at 0600, 06/14/01. Drill to 183', v
is on mud dropped from 200+- to 61
06:30-07:00 0.50 DRILL CIRC PROD Circ. and cond mud back to a 200 vis
07:00-08:00 1.00 DRILL DRLG PROD Drill from 183' to 282', shakers blinding off,
loosing to much fluid
08:00-09:30 1.50 DRILL RIRD PROD Work pipe while changing shaker screens to
a larger mesh
09:30-10:00 0.50 DRILL DRLG PROD Drill from 282' to 300', survey part of MWD
not working
10:00-11:30 1.50 DRILL DEQT PROD Couldn't get survey pulse with MWD, Proble
m thought to be pump inte'rference, check pu
Isation dampeners for pressure, switch to di
fferent pumps, MWD finially worked with pu
Imp #1
11:30-14:30 3.00 DRILL DRLG PROD 'Drill from 300' to 612', shakers started blin
ding. off again
14:30-16:00 1.50 DRILL RIRD !PROD Circ. at slow rate while changing shaker scr
eens
16:00-16:30 0.50 RIGMNTRSRV PROD Rig Service
16:30-00:00 7.50 DRILL DRLG PROD' Drill from 612' to 1377' MD ( 1333 TVD )
6/15/2001 00:00-07:30 7.50 DRILL DRLG PROD Drill from 1333' to 2122'
07:30-08:00 0.50 DRILL CIRC PROD Circ. bottoms up
08:00-11:30 3.50 DRILL WIPR PROD Wiper trip to 16" conductor, had drag from 2
028.' to 1747' pulling 5 to 15K over, Back re
am and work tight areas from 1747' to 642',
hole trying to pack off
11:30-12:00 0.50 DRILL ClRC PROD Pump and circ. up 30 bbl high vis sweep
12:00-13:00 1.00 DRILL WIPR PROD FiniSh wiper trip to 16" conductor
13:00-15:30 2.50 DRILL WIPR PROD RIH, wash and ream from 950' to 1194', fini
sh RIH to bottom
15:30-16:00 0.50 RIGMNT RSRV PROD Rig service
16:00-23:00 7.00 DRILL DRLG PROD Drill from 2122' to 2964' MD ( 2322' TVD ),
the last 6 survey's (540') have showed the s
ame asimuth, even after trying to turn to th
Printed: 12/18/2001 11:12:18 AM
PHILLIPS ALASKA INC. Page 2 of 11
Operations Summa Report
Legal Well Name: 1 C-123
Common Well Name: 1C-123 Spud Date: 6/11/2001
Event Name: ROT - DRILLING Start: 6/11/2001 End: 8/6/2001
Contractor Name: n1268@ppco.com Rig Release: 8/6/2001 Group:
Rig Name: Nabors 245 Rig Number: 245
Sub ~Phase Description of Operations
Date FrOm - To Hours Code Code
6/15/2001 16:00-23:00 7.00 DRILL DRLG PROD e right, Baker thinking tool could have faile
d. Asimuth reading 230.48
23:00-00:00 1.00 DRILL TRIP PROD POOH to last known change in survey, 2309'
and take survey, survey showed asimuth at
228.34, RIH to 2580' and take survey, surve
y showed 230.48. Tool seems OK, proceed w
ith going to bottom at report time.
6/16/2001 00:00-01:00 1.00 DRILL TRIP PROD Finish RIH, wash last stand to bottom
01:00-16:00 15.00 DRILL DRLG PROD Drill from 2964' to 4219', ReP dropped off,
couldn't make bit drill, sticky pulling off bet
tom
16:00-17:00 1.00 DRILL ClRC PROD Circ. hole clean
17:00-21:30 4.50 DRILL TRIP PROD POOH, had tight spot at 1300', took 35K to
pull thru, never seen it again
21:30-22:00 0.50 DRILL PULD PROD L/D old bit and P/U new bit
22:00-00:00 2.00 DRILL PULD PROD Down load MWD, L/D MWD tool and P/U new
tool. At report time we are ready to go in
hole
6/17/2001 00:00-04:30 4.50 DRILL TRIP PROD RIH with BHA, test MWD tools, RIH to botto
m - tight spots at 642', 3150', 3520', 3708',
work these areas clean, wash last stand to
bottom.
04:30-20:30 16.00 DRILL DRLG PROD Drill from 4219' to 5445', TMD ( TVD 4281'
)
20:30-21:30 1.00 DRILL CIRC PROD Circ. and ¢ond. hole.
21:30-22:00 0.50 DRILL SFTY PROD Monitor well while having pre-job safety mee
ting for wiper trip.
22:00-00:00 2.00 DRILL WlPR PROD 15 stand wiper trip to 4080', tight pulling ou
t from 4460' to 4260', had to work several a
reas, RIH had to wash and ream thru at 412
5' and 4155' At report time we were going
in at 4350'
6/18/2001 00:00-01:00 1.00 DRILL WlPR PROD Finish RIH w/ wiper trip, no fill on bottom
01:00-03:30 2.50 DRILL CIRC PROD Circ. and cond. mud and hole, pump sweep,
hold pre-job safety meeting for tripping, slu
g pipe
03:30-08:00 4.50 DRILL TRIP PROD POOH to run casing, had no tight hole
08:00-08:30 0.50 DRILL RIRD PROD Download MWD info.
08:30-09:00 0.50 DRILL SFTY PROD Had floor hand injured leg, by stepping in re
~tary hole after picking off bit breaker. Had
a safety meeting to discuss the accident.
09:00-09:30 0.50 DRILL RIRD PROD Drain mud motor and stand back in derrick
09:30-13:00 3.50 CASE RURD PROD .IRig up equipment to run 7 5/8" casing
13:00-13:30 0.50 CASE SFTY PROD Pre-job safety meeting
13:30-23:30 10.00 CASE RUNC PROD RIH w/ Baker ECP and 122 jts 7 5/8" 29.7# L
,-80 BTC casing, change over and run 2 jts o
f 8 5/8" 36# N-80 HYDRIL casing, screw on
Vet¢o Gray hanger and landing jr. and attem'
pt to land casing, casing run in hole with
no problems, pick up weight off bottom 260
K and set down weight 125 K
23:30-00:00 0.50 CASE RUNC PROD Casing hanger tagging up 3.1" from being la
nded in Vetco landing ring. Discovered the h
Printed: 12/18/2001 11:12:18 AM
PHILLIPS ALASKA INC. Page 3 of 11
Operations Summary Report
Legal Well Name: 1C-123
Common Well Name: 1C-123 Spud Date: 6/11/2001
Event Name: ROT - DRILLING Start: 6/11/2001 End: 8/6/2001
Contractor Name: n1268@ppco.com Rig Release: 8/6/2001 Group:
Rig Name: Nabors 245 Rig Number: 245
Sub Phase DeScription of Operations
Date From - To Hours Code Code
6/18/2001 23:30-00:00 0.50 CASE RUNC PROD anger is 16 3/8" OD and the spool under the
diverter is 14"
6/19/2001 00:00-01:30 1.50 CASE CIRC PROD P/U XO & CIRCULATING HEAD, CIRC & CON
D MUD.
,01:30-03:30 2.00 CASE OTHR PROD LAY DOWN CIRC HEAD, 9-5/8" XO, HANGER
& LANDING JT, P/U 7-5/8" JT TO REPLACE
LDG JT, P/U XO'S & CEMENTING HEAD.
03:30-05:30 2.00 CEMEN'[CIRC PROD CIRCULATE & CONDITION HOLE.
05:30-07:30 2.00 CEMEN'rPUMP PROD R/U DOWELL, TEST LINES, MIX & PUMP 70
BBL PREFLUSH, DROP BTM PLUG, 50 BBL S
!PACER, 451 BBL LEAD CMT @10.7 PPG, 63
BBL TAIL CMT @ 15.8 PPG, DROP TOP PLU
G, 29 BBL TAIL CMT ON TOP OF PLUG, DIS
PLACE W/RIG W/MUD, BUMPED PLUG W/3 B
BL OVER CALC. FLOATS HELD, 100 BBL EX
CESS CMT TO SURFACE.
07:30-08:30 1.00 CEMEN'I'NFLT PROD INFLATE EXT CSG PACKER W/'DOWELL. PA
CKER INFLATED W/1 BBL CMT @ 2000 PSI
OVER CIRC PRESSURE(TOTAL 3000 PSI)
08:30-11:30 3.00 CASE OTHR PROD FLUSH STACK, LOWER BELL NIPPLE, R/U T
O LIFT ANNULAR & SET EMERGENCY SLIPS.
11:30-13:00 1.50 CASE NUND PROD DRAIN LANDING JT, R/D CEMENTING HEAD
& RELATED EQUIPMENT, CLEAN UP CEMENT
lNG LINE & CEMENTING HEADE, PICKUP RI
G FLOOR, LAY DOWN CEMENTING HEAD & L
ANDING JT.
13:00-16:30 3.50 CASE NUND PROD WASH OUT DIVERTER STACK, SET DIVERTE
R STACK DOWN, NIPPLE DOWN RISER & SE
T BACK ON STUMP.
16:30-00:00 7.50 CASE OTHR PROD WELD GRAY WELDON WELLHEAD ON CASIN
G & LET COOL.
6/20/2001 00:00-06:30 6.50 CASE NUND PROD N/U WELLHEAD & RISER, INSTALL 3-1/2" IF
SAVER SUB, BOWEL PROTECTOR & ELEVAT
ORS, P/U BHA TO RIG FLOOR, INSTALL WE
AR BUSHING, FINISH PREP RIG FLOOR FOR
P/U HWDP.
06:30-07:00 0.50 DRILL OTHR PROD PJSM, SURFACE TEST RISER & FLOWLINES.
07:00-09:00 2.00 DRILL PULD PROD P/U BIT, SCRAPPER & XO'S, 4 JTS HWDP.
09:00-09:30 0.50 DRILL PULD PROD M/U TOPDRIVE, CIRC & WORK SCRAPER TH
RU 8-5/8" CSG SECTION TO REMOVE ANY C
EMENT SHEATH REMAINING.
09:30-13:30 4.00 DRILL TRIP PROD PJSM, RIH, TAG CEMENT @ 4843', BREAK C
IRCULATION.
13:30-00:00 10.50 DRILL REAM PROD DRLD FIRM TO HARD CEMENT F/4843-5180'.
DRLD @' ~40'/HR W/PDC BIT.
6/21/2001 00:00-02:00 2.00 DRILL DRLG PROD DRLD HARD CEMENT F/5180-5240'
02:00-03:30 1.50 DRILL CIRC PROD PUMP HI VIS SWEEP FOLLOWED BY 30 BBL
DIRTY H20 FOLLOWED BY 529 BBL SEA H20
@ 12 BPM.
03:30 - 05:30 2.00 DRILL TRIP PROD P O H T O 2 5 0 0'
05:30-06:30 1.00 DRILL CIRC PROD PUMP 104 BBL DIESEL F/FREEZE PROTECT.
Printed: 12/18/2001 11:12:18 AM
PHILLIPS ALASKA INC. Page 4 of 11
Operations Summar Report
Legal Well Name: 1 C-123
Common Well Name: 10-123 Spud Date: 6/11/2001
'Event Name: ROT - DRILLING Start: 6/11/2001 End: 8/6/2001
Contractor Name: n1268@ppco.com Rig Release: 8/6/2001 Group:
Rig Name: Nabors 245 Rig Number: 245
Sub Phase Description of Operations
Date From- TO HOurS Code Code
6/21/2001 06:30-10:30 4.00 RIGMNTRSRV PROD CUT & SLIP DRLG LINE, SERVICE TOP DRIV
E & FILL LUBRICATORS.
10:30-14:00 3.50 DRILL TRIP PROD POH, LAY DOWN 66 JTS DRILLPIPE, 15 HWD
P, BIT & SCRAPER.
14:00-17:00 3.00 DRILL PULD PROD MOVE 5" DP & HWDP, 2 STANDS DCLRS TO
DRILLERS SIDE OF DERRICK.
17:00-19:00 2.00 DRILL PULD PROD CHANGE SAVER SUB ON TOP DRIVE & REPA
IR PIPE GRABS ON TOP DRIVE.
19:00-22:00 3.00 DRILL RIRD PROD PJSM, NIPPLE DOWN RISER STACK, PULL W
EAR BUSHING, M/U SWAB VALVE, PREP CEL
LAR FOR RIG MOVE. RIG RELEASED 2200
HR 06/21/2001.
22:00-00:00 2.00 MOVE MOVE DEMOB RAISE CELLAR BOX, JACK UP UTILITY MOD
ULE, JACK UP DRILL MODULE, MOVE RIG F
ROM 10-123 60' TO 10-127
7/18/2001 00:00-01:30 1.50 MOVE MOVE MOBMIR Rig released f/ 10-111 for move to 10-123 (
180'). Move CPM and lay mats.
01:30-02:00 0.50 MOVE MOVE MOBMIR Move rig 60' to well slot 10-115, stop and m
ate modules together. Lower cellar box. Pre
pare to remove BOP's from Cellar area of ri
g.
02:00-18:00 16.00 WELCTLNUND CMPLTN Niple down 13 5/8" 5m Annular and 13 5/8" 5
m double gate rams. PU 13 5/8" 5m x 1 1" 5m
DSA, 11" 5m double gate Shaffer LWS ram,
and 11" 5m Hydril GK Annular. Build lifting
ring adapter 'to handle BOP stack with bridg
e crane.
18:00-19:00 1.00 MOVE ~MOVE MOBMIR PU cellar box. Move modules f/ 10-115 slot
to 10-123 (120' more). Rig accepted 10-123
@ 0300 hrs 7/18/2001. (Based on moving ti
me and deducting NU/ND in the middle of mo
ve)
19:00-20:00 1.00 MOVE POSN MOBMIR Skid rig 4" out (away from pipe shed). Nippl
ing down master valve and cleaning pits.
20:00-21:00 1.00 WELCTLNUND CMPLTN ND 11" flange and 7" valve from wellhead.
21:00-00:00 3.00 WELCTI. NUND CMPLTN NU BOPE on tubing spool.
7/19/2001 00:00-12:00 12.00 WELCTLNUND CMPLTN PU and set BOP stack on riser. Install and t
ighten bolts and turnbuckles. Change out ma
nual valve on kill line side with HCR valve.
Change top pipe rams to 3 1/2" Install chok
e and kill lines. Modify and install adapter f
/ bell nipple. Bring test tools to rig floor.
12:00-13:00 1.00 WELCTLBOPE CMPLTN RU test equipment.
13:00-20:00 7.00 WELCTLBOPE CMPLTN Test BOPE. AOGCC rep. John Crisp witnesse
d test. Tested annular @ 350 psi, and 3500
psi. All other equip tested @ 350 psi & 5000
psi. # 13 valve in Choke manifold failed . V
alve will be repaired prior to perforating cas
ing.
20:00-21:00 1.00 WELCTLBOPE CMPLTN Rig down test equip. Blow down choke manif
old, choke line and kill line. Install wear bu
shing.
21:00-21:30 0.50 RIGMNTRSRV CMPLTN Service rig and top drive.
Printed: 12/18/2001 11:12:18 AM
PHILLIPS ALASKA INC. Page 5 of 11
Operations Summar Report
Legal Well Name: 1 C-123
Common Well Name: 1C-123 Spud Date: 6/11/2001
Event Name: ROT - DRILLING Start: 6/11/2001 End: 8/6/2001
Contractor Name: n1268@ppco.com Rig Release: 8/6/2001 Group:
Rig Name: Nabors 245 Rig Number: 245
Sub Phase Description of Operations
Date From -To Hours Code Code
7/19/2001 21:30-23:00 1.50 CMPLTNOTHR CMPLTN RU Nabors casing tongs to make up 3 1/2" w
ork string.
23:00-23:30 0.50 CMPLTNPULD CMPLTN PU & MU mule shoe and 9 joints pipe. Torqu
e guage not acting right. Slow reponse time.
23:30-00:00 0.50 RIGMNTRGRP CMPLTN Change out tongs for another set with better
/different type torque guage.
7/20/2001 00:00-01:30 1.50 RIGMNTRGRP CMPLTN Change out power tongs and hydraulic fittin
gs
01:30-02:00 0.50 CMPLTNPULD CMPLTN PU 3 1/2" tubing. Tag ice plug @ 538'.
02:00-03:00 1.00 CMPLTNOTHR CMPLTN RU and wash through ice plug with warm sea
water.
03:00-06:00 3.00 CMPLTi~PULD CMPLTN Continue to PU 3 1/2" tubing to 2820'.
06:00-07:30 1.50 CEMEN'IRURD CMPLTN RU &circ diesel out of hole.
07:30-09:00 1.50 CMPLTI~TRIP CMPLTN =CCH w/ mule shoe.
09:00-16:30 7.50 CMPLTkTRIP CMPLTN PU BHA & RIH w/ 6 3/4" bit and tandum scra
per to PBTD @ 5240'.
16:30-19:30 3.00 CMPLTNOTHR CMPLTN Pit inspection and walk through with valve s
ystem on rig.
19:30-21:00 1.50 CMPLTN;CIRC CMPLTN Circulate hole clean.
21:00-21:30 0.50 CMPLTNCIRC CMPLTN Pump through surface equipment
21:30-22:30 1.00 CMPLTNOTHR CMPLTN RU & test 7 5/8" casing to 3500psi.
22:30-00:00 1.50 CMPLTNOTHR CMPLTN R/D test equipment & RU to circ& recip, pip
e.
7/21/2001 00:00-05:00 5.00 CMPLTNCIRC ~CMPLTN 1'ransfer 8.7 filtered brine to rig, check NTU
s. PJSM prior to pumping caustic flush. Pu
mp 25 bbls push pill, 50 bbls 8.7 ppg brine,
75 bbls caustic wash, follow with clean filte
red 8.7 ppg brine. Take returns of 270 bbls
to vac truck, therefore minimizing human co
ntact with caustic.
05:00-07:00 2.00 CMPLTNClRC CMPLTN Circulate 610 bbls, 8.7 ppg clean brine whil
e checking NTU's. Achieve 25-30 NTU.
07:00-09:00 2.00 CMPLTNCIRC CMPLTN PJSM on pickle job . Pump pickle down drill
!pipe. Reverse out to tank outside of rig tota
I of 58 bbls brine., minimizing human contac
t with fluid.
09:00-12:00 3.00 CMPLTNCIRC CMPLTN Reverse circulate 8.7 ppg brine while checki
ng NTU's. Pumped approx 190 bbls brine. Ac
hieve 70 NTU.
12:00-12:30 0.50 RIGMNTRSRV CMPLTN Service rig and top drive.
12:30-16:30 4.00 CMPLTN CMPLTN Filter 8.7 brine and reverse circulate 1 1/2
hole volumes (325 bbls). NTU's @ 15
16:30-19:30 3.00 CMPLTNTRIP CMPLTN Calibrate TOTCO block sensing device for d
epth tracking, POOH with tandum casing scr
apers.
19:30-23:00 3.50 CMPLTNPERF CMPLTN Install lubricator in annular an'd RU Schlumb
erger for perforating.
23:00-00:00 1.00 CMPLTNPERF CMPLTN PU perforating gun
7/22/2001 00:00-01:30 1.50 CMPLTNPERF CMPLTN RIH with 4 1/2" 12spf per/ gun to per/ A2 @
5116' 5136' Guns did not fire
01:30-05:00 3.50 CMPLTNPERF CMPLTN Out of hole. No shots fired. Arrrange for an
other gun to be brought to location.
Printed: 12/18/2001 11:12:18 AM
PHILLIPS ALASKA INC. Page 6 of 11
Operations Summa Report
Legal Well Name: 1C-123
Common Well Name: 1C-123 Spud Date: 6/11/2001
Event Name: ROT - DRILLING Start: 6/11/2001 End: 8/6/2001
Contractor Name: n1268@ppco.com Rig Release: 8/6/2001 Group:
Rig Name: Nabors 245 Rig Number: 245
Date From-To Hours Code Sub
Code Phase Description of Operations
7/22/2001 05:00-07:00 2.00 CMPLTNPERF CMPLTN RIH w/4 1/2" perf gun. Shoot A2 @ 5116-51
36' 1 2 spf
07:00-08:00 1.00 CMPLTNPERF CMPLTN R/D wireline lubricator and wireline.
08:00-11:00 3.00 CMPLTNSTIM CMPLTN PJSM. RIH w/ mule shoe and workstring for f
rac job.
11:00-11:30 0.50 RIGMNT RSRV CMPLTN Service rig and top drive.
11:30-15:00 3.50 CMPLTNSTIM CMPLTN Change bails and rig up for frac job with Sc
hlumberger.
15:00-15:30 0.50 CMPLTNSFTY CMPLTN Pre job safety meeting on frac job.
15:30-16:00 0.50 CMPLTNSTIM CMPLTN Test frac lines to 9500 psi. for frac job with
Schlumberger.
16:00-20:30 4.50 CMPLTNSTIM CMPLTN Frac job as planned.
20:30-21:30 1.00 CMPLTNSTIM CMPLTN R/D frac equipment on floor.
21:30-22:30 1.00 CMPLTNSTIM CMPLTN RU to take frac returns to outside tank thro
ugh choke.
22:30-00:00 1.50 CMPLTNSTIM CMPLTN Flow back to outside flowback tank @ 1/2 bp
m. Initial shut in pressure 720 psi prior to f
owback.
7/23/2001 00:00-13:00 13.00 CMPLTNSTIM CMPLTN Flow back well pressure thru choke to outsi
de tank @ approx 1 BPM, recording prssure
reduction and volume flowed back. Total ret
urns 351 bbls, Annulus pressure 15 psi.
13:00-14:00 1.00 CMPLTI~TRIP CMPLTN R/D flowback setup. RIH to 5164' No sand.
Pull up to 5096'.
14:00-15:00 1.00 CMPLTNClRC CMPLTN Reverse out @ 3BPM 600 psi a total of 168
bbls fluid.
15:00- 15:30 0.50 CMPLTI~!TRIP CMPLTN P O O H to 4 8 9 0'.
15:30-16:30 1.00 CMPLTI~SIPB CMPLTN Shut well in. Record pressure. Built to 92 p
si in 1 hr.
16:30-18:00 1.50 CMPLTI~SLIN CMPLTN RU Halliburton slick line to RIH through 3 1/
2" work string.
18:00-22:30 4.50 CMPLTI~SLIN CMPLTN RIH w/ guage ring, then RIH w/ Protechnics
RA tracer logging tool. R/D Halliburton slick
line.
22:30-00:00 1.50 CMPLTNOBSV CMPLTN Bleeding pressure off workstring. Monitor fl
owback.
7/24/2001 00:00-13:00 13.00 CMPLTNOBSV CMPLTN IBleed pressure and monitor well. Total 11.5
bbls returned.
13:00-13:30 0.50 CMPLTNTRIP CMPLTN RIH, tag sand @ 5174'.
13:30-15:00 1.50 CMPLTNCIRC CMPLTN Reverse out sand to 5232'- returns to outsid
e open top tank.
15:00-16:00 1.00 CMPLTNClRC CMPLTN Continue to reverse to pits, filtering brine.
16:00-16:30 0.50 CMPLTNTRIP CMPLTN Pull 2 stands to 5040'
16:30-20:30 4.00 CMPLTNOBSV CMPLTN Monitor well. Pressure built to 14 psi in 4 hr
s.
20:30-21:00 0.50 CMPLTNTRIP CMPLTN RIH to 5200' to fill 7 5/8" casing with sand t
o above A2 perfs.
21:00-22:30 1.50 CMPLTNOTHR CMPLTN Press test lines to 5000 psi. Spot sand fro
m 5232' to 5070'. 4700#, 24 bbls slurry , 6
#/gal prop, 11.6#/gal slurry. Pump 5 bbls ge
I, 24 bbls sand slurry, 5 bbls gel, displace
w/ 20 bbls brine.
22:30-23:30 1.00 CMPLTNTRIP CMPLTN POOH to 4640'. pump 5 bbls brine to clear t
Printed: 12/18/2001 11:12:18AM
PHILLIPS ALASKA INC. Page 7 of 11
Operations Summar Report
Legal Well Name: 1C-123
Common Well Name: 1C-123 Spud Date: 6/11/2001
'Event Name: ROT - DRILLING Start: 6/11/2001 End: 8/6/2001
Contractor Name: n1268@ppco.com Rig Release: 8/6/2001 Group:
Rig Name: Nabors 245 Rig Number: 245
Date From To Hours Code Sub Phase Description of Operations
Code
7/24/2001 22:30-23:30 1.00 CMPLTF, TRIP CMPLTN bg of sand and let settle.
23:30-00:00 0.50 CMPLTNTRIP CMPLTN RIH tag sand plug @ 5083'
7/25/2001 00:00-01:00 1.00 CMPLTNCIRC CMPLTN after tagging sand, RU, Reverse out to outsi
de tank @ 5083'
01:00-02:00 1.00 CMPLTNCIRC CMPLTN Reverse out sand @ 3 BPM , 200 psi. Monito
r well.
02:00-02:30 0.50 CMPLTNOTHR CMPLTN Change out bales, Install short bales.
02:30-05:00 2.50 CMPLTNTRIP CMPLTN POOH w/ workstring. No problems.
05:00-12:00 7.00 CMPLTNPERF CMPLTN PJSM w/ Schlumberger. RIH perf 5050'-5070'
RIH perf 5040'-5050' RIH perf 5020-5034'.
12:00-13:00 1.00 CMPLTNPERF CMPLTN R/D Schlumberger, L/D lubricator/riser.
13:00-15:00 2.00 CMPLTNTRIP CMPLTN RIH w/ mule shoe and 3 1/2" work string f/ f
ra¢ of A3 sands.
15:00-15:30 0.50 CMPLTNCIRC CMPLTN Reverse out and check temperature of fluid i
n hole.
15:30-18:30 3.00 CMPLTNSTIM ~CMPLTN RU Schlumberger/Dowell for frae of A3 sand
S.
18:30-19:00 0.50 CMPLTNSFTY CMPLTN PJSM of upcoming frac job.
19:00-00:00 5.00 CMPLTNSTIM CMPLTN ;Pressure test lines @ 8000 psi. Pump scour
and data frac as planned.
7/26/2001 00:00-01:00 1.00 CMPLTNSTIM CMPLTN Bleed off pressure & move block valve inline
with workstring.
01:00-04:30 3.50 CMPLTNSTIM CMPLTN PJSM on frae job f/ A3. Test lines to 8000 p
si. Frae per program.
04:30-05:00 0.50 CMPLTNSTIM CMPLTN Monitor well pressure.
05:00-06:00 1.00 CMPLTNSTIM CMPLTN R/D frae lines.
06:00-13:30 7.50 CMPLTNSLIN CMPLTN PJSM. W/ Halliburton slick line. RU lubricat
or. RIH # 1- temperature log. Reached 5116'
WLM.
13:30-15:00 1.50 CMPLTNSLIN CMPLTN Monitor well pressure.
15:00-17:00 2.00 CMPLTNSLIN CMPLTN R/D lubricator. Change out W/L units.
17:00-19:30 2.50 CMPLTNSLIN CMPLTN Pressure test lubricator to 2000 psi. Run Sp
ectoscan RA tracer log. Reached 5037' WLM
RIH to 4600', log to 5037', pull up to 4600
' logging. (TD f/ Protechnics logging tool 50
22')
19:30-21:30 2.00 CMPLTNSLIN CMPLTN Check log data. R/D lubricator and wireline
tools.
21:30-00:00 2.50 CMPLTI~OTHR CMPLTN RU choke, bleed well to outside tank and mo
niter pressure. 25 bbls returned @ midnight.
7/27/2001 00:00-07:30 7.50 CMPLTI~IOTHR CMPLTN Continue to bleed well to outside tank while
monitoring returns. Total of 62 bbls bleed b
ack from start of bleed yesterday. Change b
aleson top drive to short bales f/ tripping.
07:30-08:30 1.00 CMPLTI~ClRC CMPLTN Reverse cir¢ fluid 75 bbls to outside tank.
Monitor well.
08:30-09:00 0.50 CMPLTI~TRIP CMPLTN RIH w/ workstring to tag sand. Tag sand @ 5
035' Pull to 5015'.
09:00-12:00 3.00 CMPLTI~CIRC CMPLTN RU to reverse circ. Reverse ¢irc 60 bbls to
outside tank. Monitor well. Pump 50 bbls flu
id down workstring take returns to ball mill.
Printed: 12/18/2001 11:12:18AM
PHILLIPS ALASKA INC. Page 8 of 11
Operations Summa Report
Legal Well Name: 1C-123
Common Well Name: 1C-123 Spud Date: 6/11/2001
Event Name: ROT - DRILLING Start: 6/11/2001 End: 8/6/2001
Contractor Name: n1268@ ppco.com Rig Release: 8/6/2001 Group:
Rig Name: Nabors 245 Rig Number: 245
Sub Phase Description of Operations
Date From - To Hours COde Code
7/27/2001 12:00-15:30 3.50 CMPLTNTRIP CMPLTN Monitor well. POOH w/ mule shoe assembly.
15:30-16:00 0.50 WELCTLBOPE CMPLTN Pull wear bushingo
16:00-17:00 1.00 WELCTLBOPE CMPLTN Monitor well. RU equipment to test BOPE.
17:00-22:30 5.50 WELCTLBOPE CMPLTN Test BOPE. Witness of test waived by AOGC
C rep. John Spaulding. Test all components
to 250 psi Iow, all except for the annular te
sted@ 5000 psi high. The annular was teste
d @ 3500 psi high.
22:30-00:00 1.50 WELCTLBOPE CMPLTN ,Pull test plug. Set wear bushing. R/D test e
quipment.
7/28/2001 00:00-05:30 5.50 CMPLTNPERF CMPLTN PJSM w/ Schlumberger, rig suprv, tourpushe
r and crews. RIH w/ perf guns, tag @ 4987'
WLM. POOH w/ guns, L/D lubricator & wireli
ne.
05:30-08:00 2.50 CMPLTNTRIP CMPLTN RIH w/ 3 1/2" workstring and mule shoe.Tag
@ 4993' DPM.
08:00-10:00 2.00 CMPLTNCIRC CMPLTN RU to reverse circulate. Reverse circ to 504
0'. Returns to outside tank for 120 bbls. Re
verse 120 bbls to pits. Monitor well.
10:00-12:00 2.00 CMPLTNCIRC CMPLTN Reverse circ 9.0 ppg KCL/Brine -- Displace
8.7 ppg out of hole.
12:00-13:00 1.00 CMPLTNOBSV CMPLTN Monitor well.
13:00-15:30 2.50 CMPLTI~TRIP CMPLTN POOH w/ 3 1/2" workstring.
15:30-17:00 1.50 CMPLTNPERF CMPLTN PJSM. RU Schlumberger to perf.
17:00-19:00 2.00 CMPLTI~PERF CMPLTN Schlumberger RIH w/ perf guns to 5045' WL
M. Perferate 4980'-4986' & 4994'-5000' @ 1
2 spf.
19:00-20:00 1.00 CMPLTI~PERF CMPLTN R/D Schlumberger wireline.
20:00-22:00 2.00 CMPLTI~TRIP CMPLTN RIH w/ 3 1/2" workstring and muleshoe. Tag
@ 5056' DPM.
22:00-00:00 2.00 CMPLTF, OTHR CMPLTN Change bales on top drive to long bales. PU
2 joints 3 1/2" RU Dowell/Schlumberger to
fill sand in 7 5/8" to 5000'
7/29/2001 00:00-01:30 1.50 CMPLTI~OTHR CMPLTN PJSM w/ rig suprv. Toolpusher & Schlumberg
er/Dowell. Test lines to 5000 psi. Pump san
d plug.
01:30-02:30 1.00 CMPLTI~TRIP CMPLTN POOH to 4422'. Pump 5 bbls down workstrin
g.
02:30-03:30 1.00 CMPLTNTRIP CMPLTN TIH. Tag sand plug @ 5051' Stand back 2 s
rands.
03:30-05:00 1.50 CMPLTNTRIP CMPLTN TIH. Tag sand plug @ 5022' Stand back 2 s
rands.
05:00-06:00 1.00 CMPLTNTRIP CMPLTN TIH. Tag sand plug @ 5017'. Pooh to 4798'
PU (2) 9' pup joints.
06:00-10:00 4.00 CMPLTNSTIM CMPLTN PJSM w/ rig suprv., tourpusher, schlumberg
er/dowell. RU for frac A4 sands. Test lines
@ 8000 psi. Frac per program.
10:00-16:30 6.50 CMPLTNSTIM CMPLTN Monitor well. Bleed off pressure while monit
oring well. Bleed @ 1/2 bpm till 1230 hrs, th
en @ l bpm.
16:30-20:30 4.00 CMPLTNOBSV CMPLTN Shut in well. No build up in 15 min. Open we
II. Fill annulus w/ 55 bbls fluid.
20:30-21:00 0.50 CMPLTNCIRC CMPLTN Reverse out workstring volume +. (40 bbls)
Printed: 12/18/2001 11:12:18 AM
PHILLIPS ALASKA INC. Page 9 of 11
Operations Summa Report
Legal Well Name: 1 C-123
Common Well Name: 1C-123 Spud Date: 6/11/2001
Event Name: ROT - DRILLING Start: 6/11/2001 End: 8/6/2001
Contractor Name: n1268@ppco.com Rig Release: 8/6/2001 Group:
Rig Name: Nabors 245 Rig Number: 245
Sub Phase Description of Operations
Date From-To Hours Code Code .
7/29/2001 21:00-22:30 1.50 CMPLTNTRIP CMPLTN Change out bales to short bales for top driv
e. R/D lines, L/D pup joints.
22:30-23:00 0.50 CMPLTNTRIP CMPLTN RIH tag sand @ 4994'.
23:00-00:00 1.00 CMPLTNClRC CMPLTN Reverse wash out sand f/ 4994' to 5075'
7/30/2001 00:00-01:00 1.00 CMPLTNClRC CMPLTN Reverse circ, clean out sand f/ 5075' to 516
8'. Take returns to outside tank.
01:00-02:00 1.00 CMPLTNClRC CMPLTN Reverse circ 50 bbls to outside tank. Contin
ue to reverse taking 50 bbls returns to rig p
ts.
02:00-05:00 3.00 CMPLTNOTHR CMPLTN Monitor well.
05:00-07:00 2.00 CMPLTNClRC CMPLTN Pump9.0 ppg brine surface to surface, displ
=acing 8.7 ppg out of hole. Fill trip tank w/
9.0 ppg.
07:00-08:00 1.00 CMPLTNOTHR CMPLTN Monitor well.
08:00-10:30 2.50 CMPLTNTRIP CMPLTN POOH w/ muleshoe and 3 1/2" workstring.
10:30-13:30 3.00 CMPLTNTRIP CMPLTN PJSM. Change elevators, PU BHA with 3 boo
t baskets and 6 3/4" watermelon mill.
13:30-15:30 2.00 CMPLTNTRIP CMPLTN RIH to 5168' with workstring.
15:30-20:00 4.50 CMPLTNCIRC CMPLTN Reverse circ hole clean. Displace well to 9.
2 ppg KCL brine.
20:00-20:30 0.50 CMPLTNOTHR CMPLTN Monitor well.
20:30-22:00 1.50 CMPLTI~iTRIP CMPLTN POOH w/ 6 3/4" mill and boot baskets.
22:00-23:30 1.50 CMPLTI'qlTRIP CMPLTN L/D BHA. Calc fill 28.8 bbls, actual 71 bbls.
Approx 13 bbl/hr loss.
23:30-00:00 0.50 CMPLTNOTHR CMPLTN Clear rig floor of excess tools.
7/31/2001 00:00-05:00 5.00 CMPLTNOTHR CMPLTN PJSM w/ Company man, Toolpusher, Schulmb
erger. R/U Schulmberger & RIH w/ bridgeplu
g. Set BP @ 5148' WLM.
05:00-11:00 6.00 CMPLTI~SCRN CMPLTN PJSM on running Gravel Pack equip. Run Gr
avel pack Assy. as per procedure, Clear rig
floor of tools.
11:00-16:00 5.00 CMPLTI~SCRN CMPLTN RIH w/ Gravel Pack Assy. Slow.
16:00-17:00 1.00 CMPLTNSCRN CMPLTN Tag BP @ 5145.32' DP measurements. Space
out screens. Install long bales.
17:00-20:00 3.00 CMPLTI~RURD CMPLTN Rig Up Dowell lines, flow meter & choke.
20:00-21:00 1.00 CMPLTNSFTY CMPLTN Pump 10 bbls, Drop 1-7/8" ball. Hold PJSM
while ball dropping with team members. Up
Wt, 123K, Dn Wt 105K.
21:00-22:00 1.00 CMPLTNPCKR CMPLTN Set down 15K on bridge plug. Set packer w/
rig pumps, (3500 psi). Push / Pull test pack
er w/ 30K. Close annular & pressure up to 1
500 psi to release running tool. Pulled free
@ 125K.
22:00-22:30 0.50 CMPLTI~OTHR CMPLTN Close annular & pressure up to 500 psi, P/U
9' & reverse out ball.
22:30-00:00 1.50 CMPLTNGRVL CMPLTN Lower to circ position (30k Dn on BP). Pump
Gravel pack @ 10 bpm taking 2 bpm return
s w/ 1800 psi. 1.5 ppg sand. 4456 lbs sand i
nto formation before screening out. Switch o
ver & reverse out sand @ 4 bpm w/ 425 psi.
(100 bbls). P/U 10' to dump seals. Lower to
circ position & Test pack.
8/1/2001 00:00-03:00 3.00 CMPLTNGRVL CMPLTN Establish rate, Pump 1000 lbs sand restress
Printed: 12/18/2001 11:12:18 AM
~i~~' PHILLIPS ALASKA INC. Page lO of 11
Operations Summary Report
iLegal Well Name: 1C-123
Common Well Name: 1C-123 Spud Date: 6/11/2001
:Event Name: ROT- DRILLING Start: 6/11/2001 End: 8/6/2001
Contractor Name: n1268@ppco.com Rig Release: 8/6/2001 Group:
Rig Name: Nabors 245 Rig Number: 245
Date From- To Hours Code Sub Phase Description of Operations
Code
8/1/2001 00:00-03:00 3.00 CMPLTI~GRVL CMPLTN pack, screened out some sand behind pipe,
reverse out sand. Establish rate (6 bpm) P
ump 1000 lbs sand, Screened out (very little
sand outside pipe) Reverse out sand. Esta
blish rate (6 bpm), pump 1000 lbs sand, scr
eened out (no sand out), Reverse out sand.
Establish rate (6 bpm) pump 300 lbs sand @
1/2 ppg. Screened out, reverse out sand.
03:00-11:00 8.00 CMPLTNOBSV CMPLTN POOH to 4718'. Monitor well, flowing back a
t rate of 24 bbls/ hour. Rate decreasing ste
adly. Gained total of 69 bbls. Shut in well n
o pressure build.
11:00-14:30 3.50 CMPLTNTRIP CMPLTN RIH to 5004' to packer top is open. Monitor
well flowing slightly. POOH to running tools
14:30-16:30 2.00. CMPLTNTRIP CMPLTN Change elevators, rig up GBR & L/D Baker t
ools. Change elevators, R/D GBR.
16:30-17:30 1.00 CMPLTNSLIN CMPLTN Rig up to Halliburton slick line.
17:30-19:00 1.50 CMPLTNSLIN CMPLTN Wait on running tools.
19:00-21:30 2.50 CMPLTNSLIN CMPLTN Run & set XN nipple reducer on slickline.
21:30-00:00 2.50 CMPLTNTRIP CMPLTN P/U Baker paker plug & running tool. RIH w/
tools.
8/2/2001 00:00-01:00 1.00 CMPLTNTRIP CMPLTN RIH w/ Packer plug, Tag @ 4952', Latch plu
g into packer & release f/ same. Test to 100
0 psi / 5 min. (OK)
01:00-02:00 1.00 CMPLTNOTHR CMPLTN Dump sand down DP, Pump 20 bbls, allow sa
nd to fall 30 min. Tag sand @ 4949'
02:00-04:30 2.50 CMPLTNTRIP CMPLTN POOH, L/D Running tools.
04:30-05:00 0.50 CMPLTNSEQT CMPLTN PJSM on testing BOP's, Pull wear bushing.
05:00-08:00 3.00 CMPLTNSEQT CMPLTN Test BOP's, Annular to 250 & 3500, All rams
, valves, manifolds, lines to 250 & 5000, Pe
rform Accumulator test. Witnessing of test w
aived by AOGCC Rep. Chuck Scheve.
08:00-08:30 0.50 CMPLTNSEQT CMPLTN Install Wear Bushing.
08:30-10:30 2.00 CMPLTNPERF CMPLTN ,Rig up Schlumberger to Perf. Hold Safety m
eeting with crews,
10:30-18:00 7.50 CMPLTNPERF CMPLTN Perf from 4944' to 4932', 4900' to 4868' w/
BH, 4 spf, 60 degree phasing. R/D Schlumbe
rger.
18:00-20:00 2.00 CMPLTNTRIP CMPLTN P/U Baker tools & RIH
20:00-21:30 1.50 CMPLTNClRC CMPLTN Latch onto packer plug & circ bttms up
21:30-23:30 2.00 CMPLTNTRIP CMPLTN POOH, L/D Tools.
23:30-00:00 0.50 CMPLTNTRIP CMPLTN P/U PBR & anchor latch.
:8/3/2001 00:00-02:30 2.50 CMPLTNTRIP CMPLTN PJSM. RIH w/ PBR.
02:30-03:00 0.50 CMPLTNOTHR CMPLTN Latch into snap latch & shear off of PBR (25
k over)
03:00-05:00 2.00 CMPLTI~ClRC CMPLTN Circ with heated brine (100'), warm u'p well
bore, circ 380 bbls total.
05:00-12:00 7.00 CMPLTkTRIP CMPLTN POOH, L/D 3-1/2" work string, running tools.
RIH w/ 3 stds f/ derrick & L/D same.
12:00-12:30 0.50 CMPLTI~OTHR CMPLTN Pull wear bushing
12:30-15:00 2.50 WELCTLOTHR CMPLTN nstall 2-3/8" X 3-1/2" Dual rams in double
gates.
Printed: 12/18/2001 11:12:18 AM
PHILLIPS ALASKA INC. Page 11 of 11
Operations Summary Report
:Legal Well Name: 1 C-123
~Common Well Name: 1C-123 Spud Date: 6/11/2001
Event Name: ROT - DRILLING Start: 6/11/2001 End: 8/6/2001
Contractor Name: n1268@ppco.com Rig Release: 8/6/2001 Group:
Rig Name: Nabors 245 Rig Number: 245
Date From- To Hours Code Sub ~ Phase Description of Operations
Code
8/3/2001 15:00-17:00 2.00 WELCTLBOPE CMPLTN Ilnstall dual hanger, landing joints & test du
~al rams to 250 & 5000. L/D landing joints &
dual hanger.
17:00-19:30 2.50 CMPLTNOTHR CMPLTN PJSM on running dual string. R/U GBR dual
equip.
19:30-00:00 4.50 CMPLTNRUNT CMPLTN P/U & run Dual equipment as directed.
8/4/2001 00:00-02:30 2.50 CMPLTNRUNT CMPLTN P/U Dual completion as directed.
02:30-04:30 2.00 CMPLTNRUNT CMPLTN Change inserts in spiders, elevators & tongs
to 3-1/2" X 2-3/8". P/U 3-1/2" jet pump sea
t & pups to balance strings.
04:30-15:30 11.00 CMPLTNRUNT CMPLTN Run Dual Completion. Add pup joints as nee
ded, balance strings. 149 joints total
15:30-18:30 3.00 CMPLTNSOHO CMPLTN Check tallies, balance strings, run to 152 jo
nts. Latch into snap latch, snap out & spac
e out tubing. P/U pup joints.
18:30-22:00 3.50 CMPLTI~SOHO CMPLTN M/U Dual tubing hanger, M/U landing joints
& land tubing. RILDS.
22:00-23:00 1.00 CMPLTI~SEQT CMPLTN Test upper & lower tubing hanger seals to 5
000 psi. Test 2" & 3" insert sleeves to 5000
psi.
23:00-00:00 1.00 CMPLTr~SLIN CMPLTN Rig up Halliburton Slick line & run PX plug i
n long string.
8/5/2001 00:00-02:00 2.00 CMPLTI~SLIN CMPLTN Set PX plug in Long String.
02:00-03:30 1.50 CMPLTNOTHR CMPLTN Rig up Lines & pressure up & on long string
to set packers. Press up to 3500 in increme
nts of 500 psi. Bleed press of slowly. Rig u
p & test casing to 3000 psi / 30 min. Chart t
est. Lost 50 psi. R/D lines.
03:30-08:30 5.00 CMPLTNSLIN CMPLTN Retrieve PX plug w/ Halliburton slick line. R
/U on Short string & retrieve DV f/ top GLM.
R/D Slick line.
08:30-09:00 0.50 CMPLTNOTHR CMPLTN L/D Landing joints, Install BPV's
09:00-10:00 1.00 CMPLTNOTHR CMPLTN Pull Dual rams out of BOP's, Install sigle ra
ms in gates.
10:00-13:00 3.00 CMPLTNNUND CMPLTN NNipple down eBeOP's
13:00-17:30 4.50 CMPLTNNUND CMPLTN ipple up Tr . Pull BPV's & Install TWC.Te
st Tree to 5000 psi. Pull TWC.
17:30-19:30 2.00 CMPLTNFRZP CMPLTN Freeze protect 2.375"x 3.5" x 7.625" Annulu
s w/ 42 bbls diesel. U-tube diesel. Pump do
wn long string w/ 22 bbls diesel. 265 psi sh
ut in press.
19:30-22:00 2.50 CMPLTNOTHR CMPLTN P/U lubricator & set BPV in long string, Set
BPV in short string. R/D lubricator.
22:00-22:30 0.50 CMPLTNOTHR CMPLTN Secure Tree, (3lean cellar.
22:30-00:00 1.50 CMPLTNOTHR (3MPLTN PJSM. Raise cellar box Jack up modules.
8/6/2001 00:00-07:00 7.00 WELCTLEQRP DEMOB PJSM. N/D 11" 5m BOPE & remove same fro
m' rig. Install 13-5/8" BOPE in rig N/U BOP
on stump. Install 13-5/8" riser in cellar.
Printed: 12/18/2001 11:12:18 AM
Date
Comment
1C-123 Event History {"
07/11/01
07/22/01
07/23/01
07/25/01
07/26/01
07/29/01
08/01/01
08/04/01
08/05/01
08/09/01
USIT LOG COMPLETED. GOOD CEMENT FROM 5222' TO 4492' EXCEPT FOR AREA 5050' - 5095' WHICH
HAD POOR CEMENT.
PUMPED INITIAL WEST SAK FRAC. FLUSHED JOB TO COMPLETION. PLACED 217M# 12/20 SAND WITH
RA TRACER BEHIND PIPE, 100 PPA ON PERES. 100% OF DESIGN PLACED. BACKSIDE PRESSURE
DROPPED THROUGHOUT JOB, SUSPECT SIGNIFICANT HEIGHT GROWTH. [FRAC-REFRAC]
LOGGED FROM 4600' SLM TO 5188' SLM W/SPECTRA MEMORY TOOL.
PUMPED WEST SAK A3 FRAC. FLUSHED JOB TO COMPLETION. PLACED 120M# BEHIND PIPE, 12 PPA
ON PERES, 100% OF DESIGN. DID NOT SEE SCREENOUT. DROPPED RATE TO AS LOW AS 2.5 BPM IN
FLUSH IN ATTEMPT TO INDUCE SCREENOUT. [FRAC-REFRAC]
LOGGED DOWN & UP FROM 4600' WLU TO 5037' WLU [PRESSURE DATA]
COMPLETEDED WEST SAK A4 FRAC. PUMPED JOB TO COMPLETION. PLACED 58M# 12/20 SAND
BEHIND PIPE, 10 PPA ON PERES, 100% OF DESIGN. NET PRESSURE INDICATED THE START OF A
TSO AT THE END OF THE JOB. [FRAC-REFRAC]
SET 3.313"X 1.875" XN NIPPLE REDUCER @ 4975' RKB. [MAINTENANCE]
SET 1.875" PX PLUG BODY @ 4932' RKB IN LONG STRING. JOB CONTINEUED INTO 08/05/2001. [PT
TBG-CSG, GEV]
RIG SET & TESTED PER. PULLED PX PLUG @ 4932' RKB IN LONG STRING. PULLED DV @ 4792' RKB IN
SHORT STRING. [PT TBG-CSG, GEV]
PURCHASE OF 2" FLASH FREE COILED TUBING W/SHIPPING COST. PRE JET-PUMP INSTALLATION.
[JET PUMP1
10/15/01
10/22/O 1
10/23/01
10/24/01
10/25/01
10/26/01
10/27/01
10/28/01
10/29/01
11/01/01
12/08/01
MACHINE SHOP + MATERIALS FOR COIL COMPLETION. BHA, NIP, DCV ASYM.
REEL BLOWN DOWN AND UNIT TAKEN TO SHOP FOR COIL SWAP [JET PUMP]
REEL / INJECTOR SWAP; ROPE REBUILT [ESP WORK]
PIPE SWAP/REBUILD INJECTOR & ROPE/MISC. UNIT PREP [ESP WORK]
REEL SWAP/REBUILD ROPE & INJECTOR/MISC. PREP [ESP WORK]
BPV PULLED FROM PROD. COMPLETION; FLOWBACK RIGGED AND READY AS IS CTU#2.2" CT
DRIFTED W/1.5" BALL-GOOD. BHA NIPPLED UP AND READY TO RUN. JOB TO RESUME IN A.M. [ESP
WORK]
2" COILED TUBING SET IN 3-1/8 PROD. TBG. WF/BLOUNT SEAL ASSEMBLY STUNG INTO WF X-
LANDING NIPPLE AT 4735' RKB, HANGING APPROX. 1' FROM NO-GO ON TOP OF NIPPLE TO ALLOW
FOR EXPANSION/STRETCH. CT STRING HUNG OFF OFF IN HANGER PROFILE W/VETCO-GRAY CT
HANGER A
UNIT RIG-DOWN ~,ND REEL BLOWDOWN. [JET PUMP]
REEL SWAP/REBUILT INJECTOR & BOP [JET PUMP]
PERFORMD SBHP INJECTION LAG W/DUAL PANEX GAUGES, DEPTH 4910' WLM,(PRODUCTION LAG)
PULLED 1.5" PUMP THRU PLUG @ 4705' WLM, PRESSURE JUMPED UP TO 1400 PSI WHEN PLUG WAS
PULLED, COMPLETE. [PRESSURE DATA]
INSTALLED PUMPING-DEPLOYED JET PUMP IN PRODUCTION STRING. FLUSHED SURFACE LINES
WITH 50 BBL WATER. FLUSHED WELL WITH 60 BBL DIESEL. USED POWER FLUID TO PUMP JET
PUMP FROM SURFACE TO JET PUMP CAVITY AT 4730'. TURNED WELL OVER TO OPERATIONS FOR
INITIAL
Page 1 of I 12/18/2001
sURvEy CALCULATION AND FIELD WORKSHEET'
Job No. 0450-00091
Company PHILLIPS ALASKA, INC.
Well Name &-No. PAD 10/123
Rig Contractor & N°, Nabors Alaska Drlng - Rig: #245E
SurveY Section Name Definitive Survey
r ii I
Sidetrack No. Page
Field KUPARUK RIVER UNIT
BHI Rep. LYNN HENSLEY
!
1 of 3
WELL DATA
Target 'I'VD __
Target Description
Target Direction
Date
14-JUN-01
14-JUN-01
14-JUN-01
14-J UN-01
14-JUN-01
14-JUN-O1
14-JUN-01
14-JUN-O1
14-JUN-01
14-JUN-01
14-JUN-01
14-JUN-01
14-JUN-01
14-JUN-01
14-JUN-01
15-JUN-01
15-JUN-01
15-JUN-01
15-JUN-01
15-JUN-01
15-JUN-01
15-JUN-01
15-JUN-01
(FT)
Survey
Depth
(Fr)
0.00
161.00
212109
291.80
382.41
472.91
563.73·
654.74
745.13
835.83
926.53
1017.23
1111.51
1205.36
1297.11
1388.20
1481.32
1575.15
1668.36
1762.33
1855.95
1950.08
..
2042.98
2136.66
(DD)
Target Coord. N/S ' Slot Coord. N/S
Target C°ord. EJW Slot Coord. F_JW
Build\Walk\OL per: 100ffB 30m[~ lOm[~ Vert. Sec. Azim.
HOle
Direction
(DD)
0.00
Course
Length
(F'r)
TVD
(F'r)
0.00
0,00 161 .O0 161 .OO
143.99 51.09 212.09
170.71 79.71 291.80
90.50
226.96
232;94
228.37 90.82
232.94 91.01
239;97 90.39
239~27 90.70
382.38
472.74
563.27
653.74
'742.98
831.61
235.40 90.70 919.42.
232.94 1006.23
90.70-
94.28
93.85
91.75
234;35
233.29
232.24
231.53
91.09
1094.66
11'80.57
1262.83
1342.45
1420.61
231.18 93.12
230.13 93.83 1495.57
228.72 93.21 1565.85
229.42 93.97 1632.60
229.77
93.62 1694.66
230.13 94.13 1751.64
229.42 92.90 1804.78
93.68
229.07
SURVEY DATA
Vertical
Section
'0.00
0.00
0.00
0.16
1.99
6.97
14.20
24.01
38.29
57.32
79.93
106.17
i 38.80
176.55
217.16
261.37
311.95
368.34
429.45
495.48
565.48
640.31
-1605.00 Grid Correction
873.00 Magn. Declination
232.22 Magn. to Map Corr.
Total Coordinate
1868.07
N(+) / S(-)
(FT)
0.00
0.00
-O.13
-0.63
-2.11
-5.25
-9.85
-16.0i
-23.80
-33.51·
-45.80
-61.21
-80.52
-102.83
-127.42
-154.72
-186.32
-222.10
-261.92
-305.24
-350.65
-398.84
7! 6.44 -448.05
793.39 I -4~,35
Build Rate
E(+) /W(-) Build (+)
(FT) Drop (-)
0.~
0.~
0.~
0.28
-0.88
-4.75
-10.~
-17.97
-30.~
-46.55
-65.63
-86.89
-113.20
-143.66
-175.99
-210.77
-250.27
-293.88
-340.33
-390.30
-443.66
-501.00
-559.18
-617.54I 0.41I
0.69
0.11
1.84
2.33
0.77
2.80
3.70
3.10
1.94
3.20
4.20
3.18
2.30
3.77
4.63
4.03
4.71
3.18
4.79
4.30
0.75
-0.28
0.000
0.000
0.000
Depths Measured From: RKB ~] MSL[~ SS~-
Calculation Method MINIMUM CURVATURE
Map North to: OTHER
Walk Rate I
Right (+) I
Left (-)
TIE IN POINT
Comment
5.02
7.78
-0.77
-4.27
-2.71
1.50
-1.13
-1.14
-0.78
-0.38
-1.12
-1.51
0.74
0.37
0.38
-0.76
-0.37
..
CompanY PHILLIPS ALASKA, INC.
Well Name & No. PAD 1 C/123
Rig Contractor & No. Nabors Alaska Drlng - Rig: #245E
Survey Section Name Definitive Survey
WELL DATA
Field
Page 2 of 3
. ._
KUPARUK RIVER UNIT
BHI Rep.'LYNN HENSLEY
Target TVD (FT) Target Coord. N/S Slot Coord. N/S -1605.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~_] SS~-
~Target Description Target Coord. F__JW ' SI°t Coord. E/W 873.00 Magn. Declination . 0.000 Calculation Method MINIMUM CURVATURE
Survey ' 'H°le Course Vertical ~~ ~'-~--- Build + Ri ht (+) Comment
Date Depth Direction Length 'I'VD Section N(+) / S(-) E(+) / W(-) ( ) g
15;JUN-01
15-JUN-01
15-JUN-01
15-JUN-01
15-JUN-01
15-JUN-01
15-JUN-01
15-JUN-01
16-JUN-01
16-JUN-01
16-JUN-01
16-JUN-01
16-JUN-01
16-JUN-01
16-JUN-01
16-jUN-01
16-JUN-01
16-JUN-01
16-JUN-01
16-JUN-01
16-JUN-01
17~JUN.01
17-JUN-01
2229.45
2323.07
2416.88
2511.78
2605.85
2697.88
2791.40
2883.55
2978.05
3070.77
3163.02
3255.24
3346~86
3441.01
3534.66
3626.61
3719.03
3813.03
3905.95
3999.56
4091.97
4189.59
..
4284.33
4377.27
228.72
92.79 1911.26 869.29
230.83 93.62 1964.47 946.24
230.48 93.81 1024.14
2016.70
. .
230.48 2069.24 1103.13
230.48
230.48
94.90
94.07
92.03
2121.44
2172.63
230.48 93.52 2224.83
231 92.15 2276.66
94.50 2330.36
92.72 2383.51
231.53
231,53
231.18 92.25 2436.93
1181.35
1257.80
1335.36
1411.53
1489.29
1565.26
i640.46
231.53 92.22-
230.83 91.62
230.83 94.15
230.83
93.65
230.48 91,95
231.18 92.42
231.08 94.00
2490.78 1715.31
2544.68 1789.39
2600.42 1865.25
2656.21 1940.44
-548.33
-598.06
-847.47
-697.76
-747.56
-796.22
-645:6O
-893.37
-941.56
-988.82
(F'r)
-674.83
-733.64
-793.90
-854.87
-915.24
-974.23
-1034.09
-1093.45
-1154.48
-1213.96
-1035.79
-1082.54
-1128.98
-1176.91
-1272.70
-1331.17
-1388.90
-1447,72
-1224.42 -1506.04
2711.49 2013.89 -1271.00 -1562.86
2768.24 2086.81 -1317.07 -1619.41
2828.09 2159.27 -1362.56 -1675.84
232.24 92.92 2890.43 2228.15
93.61 2956.52
92.41 3024.21
97.62 3098.80
232.59
232.59
232.59
233.29
2294.45
2357~34
2420.30
94.74' 3175.21 2476.26
234.35 92.94 3254.28 2525.04
-1405.30
-1445.74
-1483.95
-1522.20
-1555.94
-1564,77
'1729.85
-1782.38
-1832.34
-1882.35
-1927.00
-1966.37
Drop (-)
-0.39 -0.38
1.13 2.25
0,56 -0.37
-0,09 0.OO
-O. 10 0.00
-0.10 0.00
-0,18 0,00
-0.48 1.52
-0.37 -0.37
-0.39 0.00
-0.48 -0.38
-0.28 0.38
-0.38 -0.76
-0.19 0.00
-0.37 0.00
-0,48 -0.38
-1.51 0,76
-2.06 -0.11
-3,50 1.25
-2.44 0.37
-2.28 0.00
-3.42 0.00
-4.82 0.74
-4.83 1.14
SURVEY CALCULATION AND FIELD WORKSHEET Job.o.
Company PHILLIPS ALASKA, INC. Rig Contractor & No. Nabors Alaska Drlng - Rig: #245E
Well Name & No. PAD lC/123~ Survey Section Name Definitive Survey
WELL DATA
Target TVD ........
Target Description
Target Direction
Date
17-JUN-01
17-JUN-01
17-JUN-01
17-JUN-01
17-JUN-01
17-JUN-01
17-JUN-01
17-jUN-01
17-JUN-01
17-JUN-01
17-JUN-01
-17-JUN-01
Sidetrack No. Page ___
Field KUPARUK RIVER UNIT
BHI Rep. LYNN HENSLEY
3 of 3
(F'r) Target Coord. N/S
(DD)
Survey
Depth
(FT)
4470.98
4563.31
4655.86
.
4749.50
4841.54
4936.27
5027.70
5121.21
52i 4.51
5307.94
5366.73
5445100
Target Coord. E/W
Build~Walk\DL per: lOOft[~ 30m[~ 1OmU
HOle Course
Direction Length TVD
(DD) (Fl) (Fl)
232.59
229;77
230.83
231.53
232.94
Slot Coord. N/S
Slot Coord. E/W
Vert. Sec. Azim.
SURVEY DATA
Vertical
Section
93.71 3337.38 2568.30
92.33 3421.70 2605.89
92.55 3508.18 2638.78
93.64 3597.50
92.04 3686.82
-1605.00 Grid Correction 0.000
873.00 Magn. Declination 0.000
232.22 Magn. to Map Corr. 0.000
Total Coordinate
N(+) / S(-) E(+) / W(-)
(F'r) (F-D
-1610.49 -2001.17
-1634.02 -2030.50
- 1655.05 -2055.80
2666.84 -1672.66 -2077.66
2688.99 -1686.26 -2095.15
2707.47
233.99 94.73 3779.73
233.29 91.43 3869.68
230.83 93.51 3961.70
231.53 93.30 4053;59
232194 93.43 4145.66
2723.85
2740.47
2756.64
2772.47
232.24 58.79 4203.61 2782;39
232.24 78,27 - 4280.77 2795.54
-1697.27 -2109.99
-1706.98 -2123.19
-1717.20 -2136.29
-1727.34 -2148.89
-1737.04 -2161.41
-1743.06 -2169.29
-1751.11 -2179.68
Depths Measured From: RKB~ MSL~ SS[-
Calculation Method MINIMUM CURVATURE
Map North to: OTHER
Build Rate Walk Rate
Build (+) Right (+)
Drop (-) Left (-)
4.12 -1.88
-3.34 -3.05
-3.61 1.15
-3.66 0.75
-3.91 1.53
-1.86 1.11
-0.10 -0.77
-0.47 0.75
0.00 1.51
-0.15 -1.19
0.~ 0.~
Comment
Projected Data - NO SURVEY
Phillips Alaska, Inc.
Pad lC
123
slot #123
Kuparuk River Unit
North Slope, Alaska
SURVEY LISTING
by
Baker Hughes INTEQ
Your ref : MWD <0-5445'>
Our ref : svy6544
License :
Date printed : 31-Jul-2001
Date created : 15-Jun-2001
Last revised : 26-Jun-2001
Field is centred on n70 16 18.576,w150 5 56.536
Structure is centred on n70 19 45.173,w149 30 19.124
Slot location is n70 19 29.388,w149 29 53.643
Slot Grid coordinates are N 5968630.430, E 561879.573
Slot local coordinates are 1605.00 S 873.00 E
Projection type: alaska - Zone 4, Spheroid: Clarke - 1866
Reference North is True North
Phillips Alaska, Inc.
Pad 1C,123
Kuparuk River Unit,North Slope, Alaska
SURVEY LISTING Page 1
Youz ref : M~D <0-5445'>
Last reviaed : 26-Jun-2001
Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C O 0 R D S
Depth Degrees Degrees Depth
0.00 0.00 0.00 0.00
161.00 0.00 0.00 161.00
212.09 0.35 143.99 212.09
291.80 0.44 170.71 291.80
382.41 2.11 226.96 382.38
472.91 4.22 232.94 472.74
563.73 4.92 228.37 563.27
654.74 7.47 232.94 653.74
745.13 10.81 239.97 742.98
835.83 13.62 239.27 831.61
926.53 15.38 235.40 919.42
1017.23 18.28 232.94 1006.23
1111.51 22.24 234.35 1094.66
1205.36 25.22 233.29 1180.57
1297.11 27.33 232.24 1262.83
1388.20 30.76 231.53 1342.46
1481.32 35.07 231.18 1420.61
1575.15 38.85 230.13 1495.57
1668.36 43.24 228.72 1565.85
1762.33 46.23 229.42 1632.60
1855.95 50.71 229.77 1694.66
1950.08 54.76 230.13 1751.64
2042.98 55.46 229.42 1804.78
2136.66 55.20 229.07 1858.07
2229.45 54.84 228.72 1911.26
2323.07 55.90 230.83 1964.47
2416.88 56.43 230.48 2016.70
2511.78 56.34 230.48 2069.24
2605.85 56.25 230.48 2121.44
2697.88 56.16 230.48 2172.63
2791.40 55.99 230.48 2224.83
2883.55 55.55 231.88 2276.66
2978.05 55.20 231.53 2330.36
3070.77 54.84 231.53 2383.51
3163.02 54.40 231.18 2436.93
3255.24 54.14 231.53 2490.78
3346.86 53.79 230.83 2544.68
3441.01 53.61 230.83 2600.42
3534.66 53.26 230.83 2656.21
3626.61 52.82 230.48 2711.49
3719.03 51.42 231.18 2768.24
3813.03 49.48 231.08 2828.09
3905.95 46.23 232.24 2890.43
3999.56 43.95 232.59 2956.52
4091.97 41.84 232.59 3024.21
4189.59 38.50 232.59 3098.80
4284.33 33.93 233.29 3175.21
4377.27 29.44 234.35 3254.28
4470.98 25.58 232.59 3337.38
4563.31 22.50 229.77 3421.70
C O O R D I N A T E S Deg/100ft Sect Easting Northing
0.00N
0.00N
0.13S
0.63S
2.11S
5.25S
9.85S
16.01S
23.80S
33.51S
45.80S
61.21S
80.52S
102.83S
127.42S
154.72S
186.32S
222.10S
261.92S
305.24S
350.65S
398.84S
448.05S
498.35S
548.33S
598.06S
647.47S
697.76S
747.56S
796.22S
845.60S
893.37S
941.55S
988.82S
1035.79S
1082.54S
1128.98S
1176.91S
1224.42S
1271.00S
1317.07S
1362.56S
1405.30S
1445.74S
1483.95S
1522.20S
1555.94S
1584.77S
1610.49S
1634.02S
0.00E 0.00 0.00 561879.57 5968630.43
0.00E 0.00 0.00 561879.57 5968630.43
0.09E 0.69 0.00 561879.67 5968630.30
0.28E 0.25 0.16 561879.86 5968629.81
0.88W 2.10 1.99 561878.71 5968628.32
4.75W 2.36 6.97 561874.86 5968625.14
10.33W 0.87 14.20 561869.32 5968620.50
17.9TW 2.85 24.01 561861.73 5968614.28
30.00W 3.89 38.29 561849.77 5968606.39
46.55W 3.10 57.32 561833.30 5968596.54
65.63W 2.21 79.93 561814.32 5968584.10
86.89W 3.29 106.17 561793.19 5968568.53
113.20W 4.23 138.80 561767.05 5968549.00
143.66W 3.21 176.55 561736.76 5968526.44
175.99W 2.35 217.16 561704.64 5968501.60
210.77W 3.78 261.37 561670.09 5968474.02
250.27W 4.63 311.95 561630.85 5968442.10
293.88W 4.08 368.34 561587.54 5968405.97
340.33W 4.81 429.45 561541.41 5968365.78
390.30W 3.22 495.48 561491.80 5968322.06
443.66W 4.79 565.48 561438.82 5968276.22
501.00W 4.31 640.31 561381.88 5968227.57
559.18W 0.98 716.44 561324.11 5968177.89
617.54W 0.41 793.39 561266.16 5968127.13
674.83W 0.50 869.29 561209.29 5968076.69
733.64W 2.17 946.24 561150.89 5968026.48
793.90W 0.64 1024.14 561091.03 5967976.59
854.87W 0.09 1103.13 561030.49 5967925.81
915.24W 0.10 1181.35 560970.53 5967875.53
974.23W 0.10 1257.80 560911.94 5967826.39
1034.09W 0.18 1335.36 560852.49 5967776.53
1093.45W 1.34 1411.53 560793.53 5967728.29
1154.48W 0.48 1489.29 560732.90 5967679.61
1213.96W 0.39 1565.26 560673.81 5967631.87
1272.70W 0.57 1640.46 560615.45 5967584.43
1331.17W 0.42 1715.32 560557.37 5967537.21
1388.90W 0.73 1789.39 560500.03 5967490.30
1447.72W 0.19 1865.25 560441.60 5967441.91
1506.04W 0.37 1940.44 560383.68 5967393.93
1562.86W 0.57 2013.89 560327.25 5967346.89
1619.41W 1.63 2086.81 560271.08 5967300.36
1675.84W 2.07 2159.28 560215.03 5967254.43
1729.86W 3.62 2228.16 560161.36 5967211.25
1782.39W 2.45 2294.45 560109.17 5967170.39
1832.34W 2.28 2357.34 560059.53 5967131.78
1882.36W 3.42 2420.30 560009.83 5967093.13
1927.00W 4.84 2476.26 559965.47 5967059.03
1966.37W 4.87 2525.04 559926.34 5967029.88
2001.17W 4.21 2568.30 559891.75 5967003.88
2030.50W 3.56 2605.90 559862.62 5966980.12
Ail data in feet unless otherwise stated. Calculation uses minimum curvature method.
Coordinates from slot %123 and TVD from RKB 102' (N-245E) (102.00 Ft above mean sea level).
Bottom hole distance is 2795.97 on azimuth 231.22 degrees from wellhead.
Vertical section is from wellhead on azimuth 232.22 degrees.
Grid is alaska - Zone 4.
Grid coordinates in FEET and computed using the Clarke - 1866 spheroid
Presented by Baker Hughes INTEQ
Phillips Alaska, Inc.
Pad 1C,123
Kuparuk River Unit,North Slope, Alaska
Measured Inclin
Depth Degrees Degrees
4655.86 19.16 230.83
4749.50 15.73 231.53
4841.54 12.13 232.94
4936.27 10.37 233.99
5027.77 10.28 233.29
5121.21 10.20 230.83
5214.51 9.76 231.53
5307.94 9.76 232.94
5366.73 9.67 232.24
5445.00 9.67 232.24
Azimuth True Vert R E C T A N G U L A R Dogleg Vert
Depth C O O R D I N A T E S Deg/100ft Sect
3508.18 1655.05S 2055.80W
3597.50 1672.66S 2077.66W
3686.82 1686.26S 2095.15W
3779.73 1697.27S 2109.99W
3869.75 1706.99S 2123.20W
3961.70 1717.20S 2136.29W
4053.59 1727.34S 2148.89W
4145.67 1737.04S 2161.41W
4203.61 1743.06S 2169.29W
4280.77 1751.11S 2179.68W
3.63 2638.78
3.67 2666.84
3.93 2689.00
1.87 2707.47
0.17 2723.87
0.48 2740.47
0.49 2756.64
0.26 2772.48
0.25 2782.40
0.00 2795.54
SURVEY LISTING Page 2
Your ref : M~D <0-5445 ' >
Last revised : 26-Jun-2001
GRID C OORD S
Easting Northing
559837.49 5966958.88
559815.78 5966941.09
559798.40 5966927.36
559783.65 5966916.23
559770.53 5966906.40
559757.51 5966896.09
559745.00 5966885.85
559732.56 5966876.05
559724.73 5966869.96
559714.40 5966861.82
Ail data in feet unless otherwise stated. Calculation uses minimum curvature method.
Coordinates from slot #123 and TVD from RKB 102' (N-245E) (102.00 Ft above mean sea level).
Bottom hole distance is 2795.97 on azimuth 231.22 degrees from wellhead.
Vertical section is from wellhead on azimuth 232.22 degrees.
Grid is alaska - Zone 4.
Grid coordinates in FEET and computed using the Clarke - 1866 spheroid
Presented by Baker Hughes INTEQ
Phillips Alaska, Inc.
Pad 1C,123
Kuparuk River Unit,North Slope, Alaska
SURVEY LISTING Page 3
Your ref : M~D <0-5445'>
Last revised : 26-Jun-2001
Comments in wellpath
MD TVD Rect~ngular Coords. Co~ent
5445.00 4280.77 1751.11S 2179.68W Projected Data - NO SURVEY
Casing positions in string 'A'
Top MD Top TVD Rectangular Coords. BotMD Bot TVD Rectangular Coords. Casing
0.00 0.00 0.00N 0.00E 5439.00 4274.86 1750.50S 2178.89W 7 7/8" Casing
Targets associated with this wellpath
Target name Geographic Location T.V.D. Rectangular Coordinates Revised
WS lC K4(lC-123) Rvs 559729.170,5966935.320,0.0000 3849.00 1677.73S 2164.32W 6-Apr-2001
7/31/2001
Schlumberger
Schlumberger Technology Corporation, by and through is Geoquest Division
3940 Arctic Blvd, Suite 300
Anchorage, AK 99503-5711
ATTN: Sherrie
NO. 1338
Company:
Alaska Oil & Gas Cons Comm
Attn: Lisa Weepie
333 West 7th Ave, Suite 100
Anchorage, AK 99501
Field: Kuparuk
Well Job # Log Description Date BL Sepia CD Color
1 D-125A INJECTION PROFILE 07120101
1 D-t 32 INJECTION PROFILE 07120101
2C-12 PRODUCTION PROFILE 07123/01
2W-11 PRODUCTION PROFILE 07124101
1 D-130 INJECTION PROFILE 07119/01
lC-123 21345 CBL/USlT 07/11/01
1 C-127 21346 CBL/USlT 07113101
DATE:
Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) $61-8317. Thank you.
RECEIVED
0 5 2001
Anchorage
PHILLIPS Alaska, Inc.
A Subsidiary of PHILLIPS PETROLEUM COMPANY
Post Office Box 100360
Anchorage, Alaska 99510-0360
Randy Thomas
Phone (907) 265-6830
Fax: (907) 265-1535
3uly 6, 2001
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue
Suite 100
Anchorage, Alaska 99501
(907) 279-1433
Re:
Application for Sundry Approvals, West Sak Dual Purpose Well lC-123.
Permit to Drill # 201-084
APl # 50-029-23016-00
RECEIVED
JUL 0 6 2001
Alaska Oil & Gas Cons. Commission
Anchorage
Dear Commissioners:
Further to a change in drilling procedure authorized by Tom Maunder on .lune 19, 2001, Phillips Alaska,
]:nc. hereby requests a Sundry Approval for a well in the West Sak Oil Pool, designated #1C-123
Please find attached for the review of the Commission Form 10-403, and two attachments:
-a copy of the e-mail from Tom Maunder, authorizing the change in procedure.
-a copy of the Proposed Drilling Program which was submitted with the Application for Permit to Drill,
with approved changes shown.
you have any questions or require any further information, please contact me at 265-6830 or Steve
McKeever at 265-6826.
Sincer.~!y, r, ,/
Randy Thomas
GKA Drilling Team Leader
ORiGiNAL,,
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
1. Type of request
Abandon _ Suspend _ Operational shutdown _ Re-enter suspended well _
Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _
Change approved program X Pull tubing _ Variance _ Perforate _
Other_
2. Name of Operator
Phillips Alaska, Inc.
3. Address
P. O. Box 100360
Anchorage, AK 99510-0360
4. Location of well at surface
1609' FNL, 874' FVVL, Section 12, T11N, R10E, UM
At top of productive interval
1999' FSL, 1288' FEL, Section 11, T11 N, R10E, UM
At effective depth
1995' FSL, 1292' FEL, Section 11, T11N, R10E, UM
At total depth
1995' FSL, 1292' FEL, Section 11, T11N, R10E, UM
5. Type of Well:
Development X
Exploratory __
Stratigraphic _
Service _
6. Datum elevation (DF or KB feet)
RKB 41.2 feet above pad, 102' above MSL
7. Unit or Property name
Kuparuk River Unit
8. Well number
1C-123
9. Permit number / approval number
201-084
10. APl number
50-029-23016-00
11. Field / Pool
Kuparuk River Field / West Sak Oil Pool
12. Present well condition summar
Total depth: measured 5445
true vertical 4281
Effective depth: measured 5240
true vertical 4079
Casing Length Size
Conductor 158' 16"
Surface 5398' 8.625" x 7.625"
feet Plugs (measured)
feet
feet Junk (measured)
feet
Cemented
9 cu. Yds High Early
580 sxAS III, 410 sx Class G
Measured Depth TrueverticalDepth
158' 158'
5439' 4275'
Perforation depth: measured No Perforations
true vertical No Perforations
Tubing (size, grade, and measured depth
Packers & SSSV (type & measured depth)
No Tubing Run
No Packers or SSSV"s
RECEIVED
JUL 0 6 2001
Alaska Oil & Gas Cons. Commission
Anchorage
13. Attachments Description summary of proposal)( Detailed operations program __ BOP sketch __
15. Status of well classification as:
14. Estimated date for commencing operation
June 19, 2001
16. If proposal was verbally approved
Name of approver Tom Maunder 6/19/01 Date approved
Oil X
Service _
Gas __ Suspended_
17. I hereby certify that the f0j'egoing is true and correct to the best of my knowledge. Questions? Call Steve McKeever265-6826
Signe ¢'~",,.,e:~ Greater Kuparuk Area Drilling Team Leader Date
Rand)/Thomas Prepared b)/ Steve McKeever
FOR COMMISSION USE ONLY
Conditions of approval: Notify Commission so representative may witness
Plug integrity __ BOP Test _ Location clearance _
Mechanical Integrity Test _ Subsequent form required 10- ['~.f~'~,
____Ap.p_Z.o.v__.e_d b.~L~rd.___e_r of the Commission
Commissioner
Form 10-403 Rev 06/15/88 ·
Approval no..__.~.)[ _ [ ~[ [
Date
SUBMIT IN TRIPLICATE
Tom Maunder <tom_maunder@admin.state.ak. us>
06/19/01 08:36 PM
To: Steve McKeever/PPCO@ Phillips
cc: jane_williamson @ admin.state.ak.us, Nabors 245 Company Man/PPCO @ Phillips, AOGCC North Slope
Office <aogcc_prudhoe_bay @ admin.state.ak.us>
Subject: Re: Well 1C-123 Plan Change regarding BOPE
Steve,
I confirm our discussion of earlier this evening. 20 AAC 25.035 (e) on page
14
of my book provides,
"A well must be equipped with BOPE meeting the requirements of this subsection
from the time that open hole drilling operations begin below the surface
casing
until the drilled portion has been plugged or the well is completed, except if
hydraulic communication to the open hole section is isolated .... "
I discussed your proposal with Lou Grimaldi. His good word of caution is to
insure that precautions are taken to avoid drilling out of the casing while
cleaning out or drilling too far.
Good luck with your operations.
Tom Maunder, PE
Petroleum Engineer
AOGCC
Steve McKeever wrote:
> Per our recent telephone conversation:
>
> Phillips Alaska, Inc. requests the Commission's approval of a change in the
> permitted procedures for West Sak Well 1C-123.
>
> The general procedure which was permitted, included, in part, the following
> steps:
>
> -Run and cement 8-5/8" x 7-5/8" tapered casing string to surface. Displace
> cement with mud and perform stage job or top job if required.
>
> Note: ECP to be inflated as part of primary cement job.
>
> Note: 7-5/8" Port Collar to be installed @ +/- 1,000' TVD.
>
> -Nipple down 21-1/4" diverter, nipple up dual completion well head and
> 13-5/8 x 5000 psi blowout preventer stack and test to 5,000 psi.
> -RIH with drill bit and cleanout well to 50' below bottom A-Sand Perf.
> -Displace well to seawater and POOH. While POOH stop and displace top 2000'
> with diesel to freeze protect. Continue POOH backfilling w/ seawater.
> -Nipple down BOPE and install 7-1/16" x 5,000 psi full bore valve atop
> wellhead.
> -RD Nabors Rig 245e and move off location.
>
> The procedure we would like to follow is, in part, this:
>
> -Run and cement 8-5/8" x 7-5/8" tapered casing string to surface. Displace
> cement with mud and perform stage job or top job if required.
>
> Note: ECP to be inflated as part of primary cement job.
>
> Note: 7-5/8" Port Collar to be installed ~ +/- 1,000' TVD.
>
> -Nipple down 21-1/4" diverter, nipple up flow riser.
> -RIH with drill bit and cleanout well to 50' below bottom A-Sand Perf.
> -Displace well to seawater and POOH. While POOH stop and displace top 2000'
> with diesel to freeze protect. Continue POOH backfilling w/ seawater.
> -Nipple down BOPE and install 7-1/16" x 5,000 psi full bore valve atop
> wellhead.
-RD Nabors Rig 245e and move off location.
Currently we are nippling down the 21-1/4" diverter, having successfully
run the casing to bottom and circulating cement back to surface. The
casing string was pressured to 3000 psi during the ECP inflation process
with no indications of lack of integrity.
Once the riser is on, we anticipate that we will drill out approximately
320 feet of cement, with final plug back TD being +/- 5200 feet. This is
approximately 150 feet above the float collar.
If this change in procedure is acceptable to the Commission, as was
indicated in our earlier phone conversation, can you please provide a
return e-mail so stating?
Thanks kindly for your late consideration of this request.
Steve McKeever
Drilling Engineer
Phillips Alaska, Inc.
907.265.6826 office
907.265.1535 fax
907.275.0369 pager
smckeev~ppco.com
tom_rnaunder.vcf
,.fiction for Sundry Permitl, Well 1C-123
Revision No.O
Saved: 5-Jul-01
Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13)
An app/icat/on for a Permit to DH//must be accompanied by each of the fo//owing items, except For an item a/ready on fi/e w/th the
commission and identified in the app/ication:
The proposed drilling program is listed below.
1. Excavate cellar, install cellar box, set and cement 16". Weld landing ring on conductor.
2. M]:RU Nabors Rig 245e. Tnstall diverter & function test same.
3. Spud and directionally drill 9-7/8" hole to desired target through West Sak interval to the base of the A-
Sand, Run MWD / LWD / PWD logging tools in drill string as required for directional monitoring and
formation data gathering.
4. Perform wiper trip. Circulate and condition hole. POOH.
5. R]:H with 9-7/8" hole opener. Circulate and condition hole to run open hole logs and side wall cores.
POOH.
6. RIH with open hole caliper tool and log West Sak. POOH.
7. R]:H with open hole logging tools (A~I', GR, ND, CMR) and log West Sak. POOH.
8. R]:H and shoot 45 sidewall cores in the West Sak. POOH.
9. R]:H with 9-7/8" hole opener. Circulate and condition hole to run casing. POOH.
10. Run and cement 8-5/8" x 7-5/8" tapered casing string to surface. Displace cement with mud and perform
stage job or top job if required.
Note: ECP to be inflated as part of primary cement job.
Note: 7-5/8" Port Collar to be installed @ +/- 1,000' TVD.
.~..~.,ILl?u~c,...,A,.~a.~,,....~.~L.'t. lA..~L_t.~.ix.,~z::~~.,~nJ~ ~z..x.~.,.~. ~, 1....~ l,~x~iz,, ,~...~ ,, ,,~,.ll ..t,~:x~.. ~ ~ ~3_.t...~ .L.O_..~_~ ~ ~ ~
~. Nipple down 2S-S/4' diverter~ nipple up dual completion well head and flow riser.
~2. R~H with drill bit and cleanout well to 50' below bosom A-Sand Perf.
~3. Displace well to seawater and POOH. While POOH stop and displace top 2000' with diesel to freeze
protect. Continue POOH backfilling w/seawater.
~4. -Nipple down flow riser and install 7-S/~6' x 5,000 psi full bore valve atop wellhead
~5. RD Nabors Rig 245e and move off location.
~6. RU E-Line Unit. Complete cement bond log. RD E-line unit,
~7. N~RU Nabors Rig 245e.
7/6/01
Sundry Application
,.tion for Sundry Permitl, Well 1 C-123
Revision No.O
Saved: 5-Jul-01
:[8. ND full bore valve, nipple up 11" x 5,000 psi BOPE and test to 5,000 psi.
:[9. Pressure casing to 3,000 psi for 30 minutes.
20. RJH with drill bit and casing scrapers.
21. Displace well to filtered brine and perform caustic wash and pickle. POOH.
22. RU E-line unit and RIH with 4-1/2" guns. Perforate A2 / A3-Sands. RD E-Line unit.
23. R]:H with workstring (open ended) and perform A-Sand frac.
24. RTH and clean out frac sand and perforation debris. POOH.
25. PU tubing conveyed perforating guns. RTH and re-perforate the A-Sand as required. POOH.
26. R]:H and set bridge plug +/- 15' below bottom perforation. POOH.
27. PU gravel pack assembly. RTH and tag top of bridge plug. Set packer and perform gravel pack of A sand
as designed. POOH.
28. RU slick line unit. R]:H and set nipple reducer in XN Nipple below gravel pack packer. RD slick line unit.
29. RTH, set packer plug and spot sand on top of packer to catch perforation debris. POOH.
30. RU E-line unit and R]:H with 4-1/2" guns. Perforate B / D-Sands. RD E-Line Unit.
31. RI:H, circulate sand off top of packer and retrieve packer plug. POOH.
32. PU and RTH with dual string completion assembly as designed.
33. R]:H to just above top of gravel pack packer.
34. RU and circulate into top of SBE. PU and perform space out. With seal assembly unstung from SBE,
freeze protect the tubing x 7-5/8" annulus and the 2-3/8" x 3-:[/2" tubing strings. Land tubing.
35. RU Slick Line Unit. R]:H and set plug in XN Nipple below gravel pack packer.
36. Set completion packers as per Service Representative on location.
37. Retrieve plug from XN Nipple. RD slick line unit.
38. ND BOPE, NU Dual Tree and pressure test.
39. RD Nabors 245e and move off.
After the rig has moved off a jet pump will be landed in a nipple in the 3-:[/2" tubing string and tied back
to surface with 2" coil tubing. 'A' sand production will occur up the 2" coil by 3-1/2" tubing annulus when
jet pump power fluid is pumped down the 2" coil tubing.
7/6/01
Sundry Application
ALASKA 0IL AND GAS
CONSERYA~ION COPI~iSSION
TONY KNOWLES, GOVERNOR
333 W. 7TM AVENUE, SUITE 100
ANCHORAGE, ALASKA 99501-3539
PHONE (907) 279-1433
FAX (907) 276-7542
James Trantham
Drilling Engineering Supervisor
Phillips Alaska, Inc.
PO Box 100360
Anchorage, AK 99510
Re:
Kuparuk River Unit 1 C- 123
Phillips Alaska, Inc.
Permit No: 201-084
Sur Loc: 1609' FNL, 874' FWL, Section 12, Tll 1N, R10E, UM
Btmhole Loc. 1995' FSL, 1292' FEL, Section 11, T1 IN, R10E, UM
Dear Mr. Trantham:
Enclosed is the approved application for permit to drill the above referenced well.
The permit to drill does not exempt you from obtaining additional permits required by law from
other governmental agencies, and does not authorize conducting drilling operations until all other
required permitting determinations are made.
Based on our information no annular is currently approved for disposal on IC pad.
Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035.
Sufficient notice (approximately 24 hours) must be given to allow a representative of the
Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given
by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607.
Sincerely,
Julie M. Heusser
Commissioner
BY ORDER OF ~.HE COMMISSION
DATED this J'~"Yday of. May, 2001
j jo/Enclosures
cc: Department offish & Game, Habitat Section w/o encl.
Department of Environmental Conservation w/o encl.
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
2O AAC 25.005
la. Type of work: Drill [] Redrill Ii I lb. Type of well. Exploratory [] StratigraphicTest [] Development Oil[]
Re-entry [] Deepen []I Service [] Development Gas [] SingleZone [] Multiple Zone[]
2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool
Phillips Alaska, Inc. RKB = 102 feet AMSL Kuparuk River Field
3. Address 6. Property Designation West Sak Oil Pool
P.O. Box 100360 Anchorage, AK 99510-036~ ADL 25649 ALK 467
4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251)
1609' FNL, 874' FWL, Section 12, T11N, R10E, UM Kuparuk River Unit Statewide
At top of productive interval 8. Well number Number
1999' FSL, 1288' FEL, Section 11, T11N, R10E, UM 1C-123 #59-52-180
At total depth 9. Approximate spud date Amount
1995' FSL, 1292' FEL, Section 11, T11N, R10E, UM May 20, 2001 $200,000
12. Distance to nearest property line 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD)
1995' @ TD feet 1 C- 10, 98' feet 2560 5528' MD / 4278' TVD
16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2))
Kickoff depth: 300' MD Maximum hole angle 62 deg Maximum surface 1459 psig At total depth (TVD) 1919 psig
18. Casing program Setting Depth
size Specifications Top Bottom Quantity of Cement
Hole Casing Weight Grade Coupli%l Le%lth MD TVD MD TVD (include sta~e data)
24" 16" 62.5# H-40 Weld 120' 41.2' 41.2' 161' 161' 225 cf AS 1
9.875" 8.625" 36# N-80 Hyd 511 79' 41.2' 41.2' 120' 120' 590 sx AS III L & 390 sx Class G
9.875" 7.625" 29.7# L-80 BTCM 5408 120' 120' 5528' 4278' Tapered String - Cemented above
19. To be completed for Redrill, Re-entry, and Deepen Operations.
Present well condition summary
Total Depth: measured feet Plugs (measured)
tree vertical feet
Effective Depth: measured feet Junk (measured)
tree vertical feet
Casing Length Size Cemented Measured depth True Vertical depth
Conductor
Surface
o RECEIVED
0'7 2001
Perforation depth: measured *~t. Jaska Oil & Ga~ Cof)s. ,.,v ~I¢',-,rrltTl:ss,Oi1
true vertical '4'rlchorage
20. Attachments Filing fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling program[]
Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements []
21. I hereby certify that the foregoing is true and correcl to the best of my knowledge Questions? Call Steve McKeever265-682~
Signed /,.~ / ~-"~~ Title:DrillingEngineeringSupervisor Date
James Trantham
Commission Use Onl~
Perm, Number APInumber I Approvaldate ¢ )~ 0/ I See cover letter
20 / - ~ ~/ 5o- o -> ? - .z 3o/~: , ' Iforother requirements
Conditions of approval Samples required [] Yes ,~ No Mudlog required [] Yes .~ No
Hydrogen sulfide measures [] Yes ,,~ No Directional survey required .~ Yes [] No
Required working pressure for BOPE BI 2M; [] 3M; [] 5M; [] 10M;[] []
Other:
Approved by ,~,[J. ~. HS[I~ commissioner the commission Date _ '
Form 10-401 Rev. 12/1/85 ·
ORIGINAL
Submit in triplicate
Ap~ "ion for Permit to Drill, Well 1 C-123
, ~ Revision No.0
Saved: 7-May-01
Permit It- West Sak Well #1 C-123
App//cat/on for Perm/t to Dr///Document
MaxWell
Maximize
Well VoluE
Table of Contents
1
1
1
1
SM
w
m
Si
SM
10.
11.
12.
Well Name ................................................................................................................. 2
Requirements of 20 AAC 25.005 (f) ........................................................................................................ 2
Location Summary ................................................................................... ., ............... 2
Requirements of 20 AAC 25.005(c)(2) ................................................................................................... 2
Requirements of 20 AAC 25.050(b) ........................................................................................................ 3
Blowout Prevention Equipment Information ................................. , ....................... 3
Requirements of 20 AAC 25. 005(c)(3) ................................................................................................... 3
Drilling Hazards Information ................................................................................... 3
Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 3
Procedure for Conducting Formation Integrity Tests ................... , ....................... 4
Requirements of 20 AAC 25. 005 (c)(5) .............................................................................. : ................... 4
Casing and Cementing Program ............................................................................. 4
Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 4
Diverter System Information ............................................................ ' ....................... 4
Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 4
Drilling Fluid Program .............................................................................................. 4
Requirements of 20 AAC 25. 005(c)(8) ................................................................................................... 4
Abnormally Pressured Formation Information ...................................................... 5
Requirements of 20 AAC 25. 005 (c)(9) .................................................................................................. 5
Seismic Analysis ....................................................................................... ............... 5
Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 5
Seabed Condition Analysis ..................................................................................... 5
Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 5
Evidence of Bonding ................................................................................ ; ............... 6
Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 6
ORIGINAL
lC- 123 PERMIT IT v2. DOC
Page 1 of 8
Printed: 7-May-01
Ap~: 'tion for Permit to Drill, Well lC-123
Revision No.0
Saved: 7-Ma¥-01
13. Proposed Drilling Program ...................................................................................... 6
Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 6
14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 8
Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 8
15. Attachments ............................................................................................................. 8
Attachment I Directional Plan (10 pages) ............................................................................................. 8
Attachment 2 Diagram and Description of 11" 5,000 psi Blowout Prevention Equipment (1 page) ...... 8
Attachment 3 Drilling Hazards Summary (1 page) ................................................................................ 8
Attachment 4 Cement Loads and CemCADE Summary (1 page) ......................................................... 8
Attachment 5 Well Schematic (3 pages) ................................................................................................ 8
lm
m
Well Name
Requirements of 20 AAC 25.005 (f)
Each well must be identified by a unique name desfgnated by the operator arid a unique API nun?ber as:~qned by the cornrnis~fon
ufider 20 AAC 25.0dO(b). For a well w/th multiple well branches; each branch must similarly be identified by a unique flaflTe a/Td API
number by addifLq a 5uRix to the name designated for the well by the operator and to the number assigned to the well by the
commis~o/7, .
The well for which this Application is submi~ed will be designated as
Location Summary
Requirements of 20 AAC 25.005(c)(2)
An application fbr a Pern#t to Dr/Il must be acconyx~nied by each of the fbi/owing item~ except tbr an item already on file with the
commie,'ion and identified in the
(2) a p/at identifying the property and tt~e property,s' owne~ and showing
(A)~he c~)ordinat~s of lhe proposed location of ~he well at' ff~e sz#face, at' lhe top of each ot¢ective tbrn?ation, and at' to&~l depth,
r~ferenced to govemmental sec?ion lines.
(B) the coordinates of'the proposed location of the well at the sutfbc~; referenc~,d to the state plane coordinate sy.~em tbr this
state as maintained by the National Geodetic Suf~ey in tl~e National Oceanic and Atn?os~heHc Adn~inistfz~tion;
(C) the proposed depth of the well at the top of eadz objective formation and at total depth;
Location at Surface
NGS Coordinates
Northings: 5,968,630.35
1609' FNL~ 874' FWL~ Section 12~ TllN~
t RKB E/ovation
Eastings: 561,880.54 Pad Elevation
R10E~ UM
102.0' AMSL
60.8' AMSL
Location at Top of
Productive Interval 1999' FSL, 1288' FEL, Section 11, T11N, R10E, UM
(West Sak "D" Sand)
NEc Coordinates Measured Depthz RKB: 4951
North/rigs: 5,966,939 East/rigs: 559,733 Total Vert/ca/Depthz RKB: 3701
Total Vertical Depth~ $$: 3600
Location at Total Depth I 1995' FSL~ 1292' FEL~ Section 11~ T11N~ R10E, UM
NG$ Coordinates Measured Depth~ RKB: 5528
Northings: 5,966,935 Eastings: 559,729 Total Vert/ca/Depth~ RKB: 4278
Total l/ertica/ Depth~ ES: 4177
and
ORIGINAL
1C- 123 PERMIT IT v2. DOC
Page 2 of 8
Printed: 7-May-01
i" AF~' ~tion for Permit to Drill, Well 1 C-123
Revision No.0
Saved: 7-May-01
1
(D) other information required by 20 AAC
Requirements of 20 AAC 25.050(b)
Z? a we# is to be intentionally deviated, the application for a Permit to Dr///(Form 10-401) must
(1) include a p/at, drawn to a suitable scale, showing the path of the propozed we#bore, indudhg afl adjacent we~bore.~ within 200
feet of any podion of the proposed well;
Please see A~achment 1: Dire~ional Plan
(2) for ali wells within 200 feet of the propo.~ed we//bore
(A) /Z~t the name~ of the operato~ of tho~e we//~, to the extent that tho.~e name~ a~ known or dZ~cove~Tb/e in pub/i~
and show that ead~ named operator ha~' been furniched a copy of the app//~ation by codified/flail; or
(B) state that the applicant/~ tl~e only affected ownen
The Applicant is the only affe~ed owner,
Blowout Prevention Equipment Information
Requirements of 20 AAC 25.005(c)(3)
An application for a Permit to Drill rnu~t be accompanied by each of the follo~dng il~rn~) e~cept for an item already on file with the
c~nrnrnL~sion and identified in the application:
(3) a die, ram and description of the blowout prevent/bn equipment (BOPE) as' required by 20 AAC 2~.0~ 20 AAC 2~,0~, or
~C 2.~,037, a~ applicable;
Two different configurations of blowout prevention equipment will be used during rig operations on Well
~C-~23. For casing clean out operations an AP~ ~3-5/8" x 5,000 psi BOP stack will be used. A diagram of
this stack is on file with the Commission. Please see "Diagram and Description of the Blowout Prevention
Equipment for Nabors Rig 245e", placed on file with the Commission with the Application for Permit to
Drill for Well ~C-~33, dated April 26th, 200~. During completion operations, an AP~ ~" x 5,000 psi BOP
stack will be used. Please refer to A~achment 2: "Diagram and Description of ~" 5,000 psi Blowout
Prevention Equipment".
Drilling Hazards Information
Requirements of 20 AAG 25. 005 (c)(4)
An application for a Permit to Drill mu.¢t be accompanied by each of the fbflowing item5 ex~pt tbr an item a#~ady on file witt) the
comm/~eion and identified in the application:
(~) in~)rfflation on dri#ing hazards i/zduding
(A) the n~ax#fluflz do~¢nhole pre.¢.~ure that may be encou/~t~re~ ~rit~ria used to determine it, and n?axirflum potenUat .~'urfi~:e
pre~Tzre based on a methane gradient'
The expected rese~oir pressures in the West Sak sands in the ~C pad area va~ from 0.43 to 0.46 psi/fi,
or 8.2 to 8.8 ppg ENW (equivalent mud weight). These are pressures obtained from actual well test data
from the nearby WS~-0~ well.
The maximum potential surface pressue (MPSP) based on the above maximum pressure gradient, a
methane gradient (0.11) and the vertical depth of the expected base of the West Sak formation is 1459
psi, calculated thusly:
MPSP =(4171 ft)(0.46- 0.11 psi/fL)
=1459 psi
(£) data on potent/a/gas zones;'
The well bore is not expected to penetrate any gas zones,
and
(C) data concerning potential Q~use$ o£ hole problem.~' .eucl~ a.e abnormally geo..pr~'sured strata, lo.et circulatk~n zone.~ and zone. e
that have a pmpen.eity ~r differ~ntial stickirLq;
Please see A~achment 3: Drilling Hazards Summa~,
ORIGINAL
10-123 PERMIT IT v2. DOC
Page $ o! 8
Printed: 7-May-01
Ap( t/on for Permit to Drill, Well 1 C-123
t,,.
~ Revision No.0
Saved: 7-May-01
.
Procedure for Conducting Formation Integrity Tests
Requirements of 20 AAC 25.005 (c)(5)
An appfication fo/' a Pem#t to Dr///must be accompanied by each of the fo/lowing items, except for an item a/ready on file w/th the
commi~ion and identified in the application:
(5) a description of tl~e procedure for conducUng formaUon integrity tes~ as required under 20 AAC
As the well will be completed with a single casing string that will not be drilled out, no formation integrity
tests are planned. In the unlikely event that it does become necessary to drill out a casing string with
blowout prevention equipment installed, a formation integrity test will be performed in accordance with
the "Formation ]~ntegrity Test Procedure" that Phillips Alaska placed on file with the Commission with the
Application for Permit to Drill for well 1C-133, dated April 26th, 2001.
6. Casing and Cementing Program
Requirements of 20 AAC 25. 005(c)(6)
An application fo/' a Pern#t to Dr/il must be accompanied by each of the fo/lowing items, except for an item a/ready on file w/th the
commL~s¥on and identified in the app/icaUon:
(6) a complete proposed casing and cemenfin9 pro.gram as required by 20 AAC 2...5: 030, and a description of any slotted liner; pre-
perforated liner, or .~rreen to be insta/led;
Casing and Cementing Program
Hole Top Btm
Csg/'l'bg Size Weight Length MD/I'VD MD/7'VD
OD (in) (in) (Ib/fO Grade Connection (ft) (ft) (ft) Cement Program
16 24 62.5 H-40 Welded 120 41 / 41 161 / 161 Cemented to
surface with
225 cf
ArcticSet 1
8-5/8 9-7/8 36 N-80 Hyd 511 79 41 / 41 120 / 120 Tapered
String
7-5/8 9-7/8 29.7 L-80 BTCM 5408 120 / 120 5528 / ~278 Cemented to
Surface with
590 sx ASLite
Lead, 390 sx
Class G Tail
Additionally, the 'A' Sand will be completed by perforating through the 7-5/8" casing, and then gravel
packing between the casing and a set of screens and excluders inside the casing. See also Attachment 4:
Cement Loads and CemCADE Summary, and Attachment 5: Completion Schematic
m
Diverter System Information
Requirements of 20 AA C 25. 005(c)(7)
An application for a Permit to DH// must be accompanied by each of' the £ollowing items, except fbr an item ,~ready on file with the
comn#ssion and identified//7 the application:
(7) a diagram and description of the diverter systen7 as required by 20 AAC 25: 0.75; unle.~' t/#s requ/ren?ent is waived by the
conm?ission under 20 AAC 25: 035(h)(2);
Please see "Diagram And Description of the Diverter System For Nabors Rig 245e", placed on file with
the Commission with the Application for Permit to Drill for well 1C-133, dated April 26th, 2001.
.
Drilling Fluid Program
Requirements of 20 AAC 25.005(c)(8)
An application fbr a Peru?it to Drill must be accompanied by each of the to/lowing item5 except for an item a/ready 0/7 file w/th the
commission and identified in the application:
(8) a drilling tluid pro.qram, includin9 a d/;.~gram and description of the dri//in9 tluid system, as re. quired by 20 AAC 25.0:?.~
OttI IIVAL
lC-123 PERMIT IT v2. DOC
Page 4 of 8
Printed: 7-May-01
~i .... Ap.j: 'tion for Permit to Drill, Well 10-123
Revision No.0
Saved: 7-May-01
Drilling will be done with a bentonite slurry having the following properites over the listed intervals:
Spud to Base of Permafrost Base of Permafrost to Total Depth
Initial Value Final Value Initial Value Final Value
Density (ppg) 8,5 9.4 - 9.6* 9.4 9.4
Funnel Viscosity 150-200 150-200 150 75
(seconds)
Yield Point 30-60 30-60 25-45 25-45
(cP)
Plastic Viscostiy 8-15 11-22 11-22 11-22
(lb/lO0 sf)
10 second Gel 15-30 10-25 15-30 15-30
Strength (lb~lO0 sf)
10 minute Gel 25-55 25-55 25-55 25-55
Strength (lb/lO0 so
pH 8-9 8-9
APl Filtrate(cc) 8-15 6 5-6 5-6
Solids (%) 5-8 5-8 5-8 6-1 t
1
10.
11.
*9.8 ppg if hydrates are encountered
Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033.
This drilling fluid system of Nabors Rig 245e consists of: (3) Continental Emsco FB-1600 Mud Pumps,
Steel Mud pits with 1100 barrel capacity, Pill Pit, Trip Tank, (3) Derrick FIo-line Shale Shakers (rated at
600 gpm), Brandt Model SRS-2 Desander, Derrick Model 58S Mud Cleaner, (2) Alpha-Laval Model 418-VT-
5 Centrifuges, Degassers, PVT System with visual and audio alarms, Trip Tank, Flow Sensor, and Fluid
Agitators.
Please see "Diagram of Mud System, Nabors Rig 245e", placed on file with the Commission with the
Application for Permit to Drill for well 1C-133, dated April 26th, 2001
Abnormally Pressured Formation Information
Requirements of 20 AAC 25.005 (c)(9)
An app/icat/on for a Permit to/3ri//must be accofr~p,.~fl/ed by ~.zach of the fo/low#Lq item.$ except £or an itefr~ a/ready on fi/e w/th the
comm/".¢sion and identified in the apphbation:
(g) for an exl2/Orato~ or stratL~ra/2hic test' wel~ a tabu/at/on setting out the depths of predictz.~d abnormally geo..prb~s'suf~d s~rata as
required by 20 AAC 2% 033(f)7
Not applicable: Application is not for an explorato~ or stratigraphic test well.
Seismic Analysis
Requirements of 20 AAC 25.005 (c)(10)
An z¢~p/ic~t/on fbra Permit to Dr/ii must be accompanied by eacf) of the fb//ow/rLq /terns; except for an item a/ready on file with the
c'onTnT/ssion and ident/f)~,d in the app/ication:
(10) fbr an exp/or~tory or str~t/~aph/c test we/~ a seismic refract/on or re#ect/on ana/ys/s as f~,qu/red by 20
Not applicable: Application is not for an explorato~ or stratigraphic test well.
Seabed Condition Analysis
Requirements of 20 AAC 25. 005 (o)(11)
An app/icat/on for a Permit to Dr/Ii must be accompanied by each of the ~/Io~ing items, except fbr an item a/ready ~x~ fi/e with the
comm/s~¢ion and identified in the application:
~1) ~r awe// dr/lied from an offsY~ore plat~x'm, mobi/e bottom-founded structure, jack-up r(q, or floating dH//in¢ ves:~ an ana/ysYs
of seabed c~nd/~ions as/'equ/red by 20 ~C 25: 06.1(b);
Not applicable: Application is not for an offshore well.
ORIGINAL
1C- 123 PERMIT IT v2. DOC
Page 5 of 8
Printed: 7~May-01
~1r Apf~ 'ion for Permit to Drill, Well 1C-123
· ~ Revision No.O
Saved: 7-May-01
12. Evidence of Bonding
Requirements of 20 AAC 25.005 (c)(12)
An application fbr a Pern#t to Drill must be accompanie~¢ by each of the fo/lowing items, except for an item a/ready on file with the
comrnission and identified in the application:
(Z2) evidence ~howing that the requ#'ement.~ of 20 AA£ 25.025 (BondifLq.~have been met;
Evidence of bonding for Phillips Alaska, inc. is on file with the Commission.
13. Proposed Drilling Program
Requirements of 20 AAC 25.005 (c)(13)
An application for' a Permit to Dr/Il must be accompaz~/ed by each of the follo~ving items, except for an item a/ready on file with the
commi.~$ior~ and identified in the application:
The proposed drilling program is listed below. Please refer also to Attachment 5, Well Schematic.
1. Excavate cellar, install cellar box, set and cement 16". Weld landing ring on conductor.
2. MIRU Nabors Rig 245e. Install diverter & function test same.
.
Spud and directionally drill 9-7/8" hole to desired target through West Sak interval to the base of the A-
Sand. Run MWD / LWD / PWD logging tools in drill string as required for directional monitoring and
formation data gathering.
4. Perform wiper trip. Circulate and condition hole. POOH.
5. RIH with 9-7/8" hole opener, circulate and condition hole to run open hole logs and side wall cores.
POOH.
6. RIH with open hole caliper tool and log West Sak. POOH.
7. RTH with open hole logging tools (AIT, GR, ND, CMR) and log West Sak. POOH.
8. RIH and shoot 45 sidewall cores in the West Sak. POOH.
9. RIH with 9-7/8" hole opener. Circulate and condition hole to run casing. POOH.
10. Run and cement 8-5/8" x 7-5/8" tapered casing string to surface. Displace cement with mud and perform
stage job or top job if required.
Note: ECP to be inflated as part of primary cement job.
Note: 7-5/8" Port Collar to be installed @ +/- 1,000' TVD.
11. Nipple down 21-1/4' diverter, nipple up dual completion well head and 13-5/8 x 5000 psi blowout
preventer stack and test to 5,000 psi.
12. RIH with drill bit and cleanout well to 50' below bottom A-Sand Perf.
13. Displace well to seawater and POOH. While POOH stop and displace top 2000' with diesel to freeze
protect.. Continue POOH backfilling w/seawater.
14. Nipple down BOPE and install 7-1/16' x 5,000 psi full bore valve atop wellhead.
15. RD Nabors Rig 245e and move off location.
ORIGINAL
1C- 123 PERMIT IT v2. DOC
Page 6 of 8
Printed: 7-May-01
I Ap~ ~ion for Permit to Drill, Well 1C-123
· ", Revision No.O
Saved: 7-May-01
16. RU E-Line Unit. Complete cement bond log. RD E-line unit,
17. M[RU Nabors Rig 245e.
18. ND full bore valve, nipple up 11" x 5,000 psi BOPE and test to 5,000 psi.
19. Pressure casing to 3,000 psi for 30 minutes.
20. R:[H with drill bit and casing scrapers.
21. Displace well to filtered brine and perform caustic wash and pickle. POOH.
22. RU E-line unit and RTH with 4-1/2" guns. Perforate A2 / A3-Sands. RD E-Line unit.
23. R:[H with workstring (open ended) and perform A-Sand frac.
24. R:[H and clean out frac sand and perforation debris. POOH.
25. PU tubing conveyed perforating guns. RTH and re-perforate the A-Sand as required. POOH.
26. RTH and set bridge plug +/- 15' below bottom perforation. POOH.
27. PU gravel pack assembly. RTH and tag top of bridge plug. Set packer and perform gravel pack of A sand
as designed. POOH.
28. RU slick line unit. RTH and set nipple reducer in XN Nipple below gravel pack packer. RD slick line unit.
29. RTH, set packer plug and spot sand on top of packer to catch perforation debris. POOH.
30. RU E-line unit and R:[H with 4-1/2" guns. Perforate B / D-Sands. RD E-Line Unit.
31. R~[H, circulate sand off top of packer and retrieve packer plug. POOH.
32. PU and RTH with dual string completion assembly as designed.
33. R:[H to just above top of gravel pack packer.
34. RU and circulate into top of SBE. PU and perform space out. With seal assembly unstung from SBE,
freeze protect the tubing x 7-5/8" annulus and the 2-3/8" x 3-1/2" tubing strings. Land tubing.
35. RU Slick Line Unit. RTH and set plug in XN Nipple below gravel pack packer.
36. Set completion packers as per Service Representative on location.
37. Retrieve plug from XN Nipple. RD slick line unit.
38. ND BOPE, NU Dual Tree and pressure test.
39. RD Nabors 245e and move off.
After the rig has moved off a jet pump will be landed in a nipple in the 3-1/2" tubing string and tied back
to surface with 2" coil tubing. 'A' sand production will occur up the 2" coil by 3-1/2" tubing annulus when
jet pump power fluid is pumped down the 2" coil tubing.
O I INi L 1C-123 PERMIT IT v2. DOCpage 7 of 8
Printed: 7-May-01
APl[ %n for Permit to Drill, Well 1 C-123
Revision No.O
Saved: 7-May-01
14. Discussion of Mud and Cuttings Disposal and Annular Disposal
Requirements of 20 AAC 25.005 (c)(14)
An application fora Pern#t to Dr/Ii mustc be accompanied by each of the fo/lowing items, except for an item a/ready on file with the
commission and identified in the application:
(I4) a genera/descn'ption of how the operator plans to dispose of drilling mud and cutt#~gs and a statement of whether the
operator intends to request authorization under 20 AAC 25,080 for an annular disposal operation in the we/L;
Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids
into a permitted annulus on :LC pad, or by hauling the fluids to a KRU Class ]:! disposal well. All cuttings
generated will be either stored temporarily on site or hauled to the Prudhoe Bay Field for temporary
storage and eventual processing for injection down an approved disposal well.
15.
Phillips Alaska does not intend to request authorization for the use of this well for annular disposal
operations.
Attachments
Attachment 1 Directional Plan (10 pages)
Attachment 2 Diagram and Description of 11" 5,000 psi Blowout Prevention Equipment (1 page)
Attachment 3 Drilling Hazards Summary (1 page)
Attachment 4 Cement Loads and CemCADE Summary (1 page)
Attachment 5 Well Schematic (3 pages)
ORIGINAL
1C- 123 PERMIT IT v2. DOC
Page 8 of 8
Printed: 7-May-01
Crecy[ecl by b~hoel FOr': S McKeever
Dote o~otte~: lO-A~r-20Ol
P~l Reference is 125 Ve~ion~5.
C~r~[notos ore ~n f~t re~erlnco s~t ~125.
True Vertical ~p[hs ore reference ~[;mo~ed RKB.
Phillips Alaska, Inc.
Structure : Pod 1C Well : 123
Field : Kuparuk River Unit Location : North Slope, Alaska
250
5OO
750
lOOO
125o
15oo
175o
2000
2250
2500
2750
3000
5250
35OO
5750
4000
4250
4500
232.22 AZIMUTH
EstimotedRKB£levotion: 101' 2738' (TO TARGET)
,*~Plone of Proposal***
KOP
3.00
· 6.00 DLS: 3.00 deg per 100 ft
~ 9.00
12.00
Build 5/1 O0
~ 20.00
'~ 25 O0 DLS: 5.00 deg per 100 ft
'~ 30.00
k Begln Turn
x~x 55.00 Begin Build
~ 40.00 BLS: 5.00 deg per 100 ft
~, 45.00
%m, 50.00 Build/Turn
'~ 53.44
~, 56.56 DLS: 5.00 deg per 100 ft
x'~ 59'84E0C ermofrost
TANGENT ANGLE~~ se In Dro
61.99 DEG ~ ~ ~' ~
~ '56.93 K-15
~ 53.93
~ 50.93
~ 47.93
DLS: 3.00 deg per 100 ft % 44;91393
~ ~s.93
~ 35.95
29.95 k 52.93
26.95 ~
23.93 ~,
u~u %0.93 ~
17.93 ~
' Ugnu B14'95 ~[
~ggnu Al1.95 '~
K-138'93 ~
....... Top W Sok ~5.93
FINAL ANGLE - 62 ~
" " A4 ' i
VERTICAL To~/^~ - ~oc
A2
Al-Bose Pay
Bose W Sok
TD - Csg Pt L
i r i [ i i i i i t i t [ i i i i i i i t
250 500 750 1000 1250 1500 1750 2000 2250 2500 2750
Vertical Section (feet) ->
Azimuth 232.22 with reference 0.00 N, 0.00 E from slot #123
ORIGINAL
<- Wes~ (feet)
3 ...... AZIM[ TIt
;g738' (TO TARGET)
/
/
/
/
/
/
Grid lat long report
page 1 of 4
Phillips Alaska, Inc.
Pad lC
123
slot #123
Kuparuk River Unit
North Slope, Alaska
PROPOSAL LISTING
by
Baker Hughes INTEQ
Your ref
Our ref
License
123 Version#3
prop4378
Date printed
Date created
Last revised
10-Apr-2001
8-Jan-2001
10-Apr-2001
Field is centred on n70 16 18.576,w150 5 56.536
Structure is centred on n70 19 45.173,w149 30 19.124
Slot location is nT0 19 29.388,w149 29 53.643
Slot Grid coordinates are N 5968630.430, E 561879.573
Slot local coordinates are 1605.00 S 873.00 E
Projection type: alaska - Zone 4, Spheroid: Clarke - 1866
Reference North is True North
ORIGINAL
Grid lat long report
page 2 of 4
Phillips Alaska, Inc.
Pad 1C,123
Kuparuk River Unit,North Slope, Alaska
Measured Inclin Azimuth True Vert
Depth Degrees Degrees Depth
0.00 0.00 0.00 0.00
100.00 0.00 236.18 100.00
200.00 0.00 236.18 200.00
300.00 0.00 236.18 300.00
400.00 3.00 236.18 399.95
500.00 6.00 236.18 499.63
600.00 9.00 236.18 598.77
700.00 12.00 236.18 697.08
800.00 15.00 236.18 794.31
900.00 20.00 236.18 889.65
1000.00 25.00 236.18 982.01
1100.00 30.00 236.18 1070.68
1200.00 35.00 236.18 1154.99
1300.00 35.00 244.90 1236.96
1301.11 35.00 245.00 1237.87
1401.11 40.00 245.00 1317.18
1501.11 45.00 245.00 1390.89
1601.11 50.00 245.00 1458.43
1627.26 51.31 245.00 1475.00
1700.00 53.44 241.28 1519.42
1800.00 56.56 236.51 1576.79
1900.00 59.84 232.07 1629.49
1963.22 61.99 229.42 1660.23
2000.00 61.99 229.42 1677.50
2192.72 61.99 229.42 1768.00
2500.00 61.99 229.42 1912.30
3000.00 61.99 229.42 2147.10
3031.36 61.99 229.42 2161.82
3100.00 59.93 229.42 2195.14
3200.00 56.93 229.42 2247.48
3222.74 56.25 229.42 2260.00
3300.00 53.93 229.42 2304.21
3400.00 50.93 229.42 2365.17
3500.00 47.93 229.42 2430.20
3600.00 44.93 229.42 2499.11
3700.00 41.93 229.42 2571.72
3800.00 38.93 229.42 2647.83
3900.00 35.93 229.42 2727.23
4000.00 32.93 229.42 2809.70
4100.00 29.93 229.42 2895.02
4200.00 26.93
4300.00 23.93
4351.94 22.37
4400.00 20 93
4500.00 17 93
4600.00 14 93
4633.19 13 94
4680.44 12 52
4700.00 11 93
4800.00 8 93
229.42 2982.94
229.42 3073.24
229.42 3121.00
229.42 3165.66
229.42 3259.96
229.42 3355.86
229.42 3388.00
229.42 3434.00
229.42 3453.11
229.42 3551.45
PROPOSJ~L LISTING Page 1
Your ref : 123 Version#3
Last revised : 10-Apr-2001
RECTANGULAR GRID C 0 0 R D S GEOGRAPHIC
C O 0 R D I N A T E S Easting Northing C 0 0 R D I N A T E S
0.00N 0.00E 561879.57 5968630.43 n70 19 29.39 w149 29 53.64
0.00N 0.00E 561879.57 5968630.43 n70 19 29.39 w149 29 53.64
0.00N 0.00E 561879.57 5968630.43 n70 19 29.39 w149 29 53.64
0.00N 0.00E 561879.57 5968630.43 nT0 19 29.39 w149 29 53.64
1.46S 2.17W 561877.41 5968628.96 n70 19 29.37 w149 29 53.71
5.82S 8.69W 561870.93 5968624.54 n70 19 29.33 w149 29 53.90
13.09S 19.53W 561860.15 5968617.19 n70 19 29.26 w149 29 54.21
23.23S 34.67W 561845.09 5968606.92 n70 19 29.16 w149 29 54.65
36.22S 54.07W 561825.81 5968593.77 n70 19 29.03 w149 29 55.22
52.95S 79.04W 561800.97 5968576.84 n70 19 28.87 w149 29 55.95
74.25S 110.82W 561769.37 5968555.29 n70 19 28.66 w149 29 56.88
99.94S 149.17W 561731.23 5968529.29 n70 19 28.40 w149 29 58.00
129.83S 193.80W 561686.86 5968499.04 n70 19 28.11 w149 29 59.30
157.98S 243.62W 561637.27 5968470.49 n70 19 27.83 w149 30 00.75
158.25S 244.20W 561636.69 5968470.22 n70 19 27.83 w149 30 00.77
183.97S 299.36W 561581.75 5968444.06 n70 19 27.58 w149 30 02.38
212.51S 360.57W 561520.78 5968415.02 n70 19 27.30 w149 30 04.17
243.66S 427.36W 561454.24 5968383.33 n70 19 26.99 w149 30 06.12
252.20S 445.69W 561435.99 5968374.64 n70 19 26.91 w149 30 06.65
278.25S 497.06W 561384.84 5968348.18 n70 19 26.65 w149 30 08.15
320.59S 567.12W 561315.13 5968305.27 n70 19 26.23 w149 30 10.20
370.23S 636.06W 561246.61 5968255.08 n70 19 25.75 w149 30 12.21
405.20S 678.82W 561204.13 5968219.77 n70 19 25.40 w149 30 13.46
426.32S 703.48W 561179.65 5968198.45 n70 19 25.20 w149 30 14.18
537.01S 832.70W 561051.35 5968086.72 nT0 19 24.11 w149 30 17.95
713.51S 1038.73W 560846.78 5967908.57 n70 19 22.37 w149 30 23.96
1000.70S 1373.98W 560513.90 5967618.69 nT0 19 19.55 w149 30 33.74
1018.71S 1395.01W 560493.03 5967600.51 nT0 19 19.37 w149 30 34.36
1057.75S 1440.58W 560447.78 5967561.11 n70 19 18.98 w149 30 35.69
1113.17S 1505.28W 560383.54 5967505.17 n70 19 18.44 w149 30 37.58
1125.52S 1519.69W 560369.23 5967492.70 n70 19 18.32 w149 30 38.00
1166.74S 1567.81W 560321.45 5967451.10 nT0 19 17.91 w149 30 39.40
1218.30S 1628.00W 560261.69 5967399.05 nT0 19 17.41 w149 30 41.16
1267.71S 1685.68W 560204.41 5967349.18 n70 19 16.92 w149 30 42.84
1314.85S 1740.70W 560149.78 5967301.60 nT0 19 16.46 w149 30 44.45
1359.57S 1792.91W 560097.95 5967256.46 n70 19 16.02 w149 30 45.97
1401.76S 1842.16W 560049.05 5967213.88 n70 19 15.60 w149 30 47.41
1441.29S 1888.31W 560003.22 5967173.97 n70 19 15.21 w149 30 48.75
1478.08S 1931.25W 559960.59 5967136.85 nT0 19 14.85 w149 30 50.01
1512.00S 1970.85W 559921.27 5967102.60 n70 19 14.52 w149 30 51.16
1542.97S 2007.01W 559885.37 5967071.34 n70 19 14.21 w149 30 52.22
1570.91S 2039.62W 559852.99 5967043.15 n70 19 13.94 w149 30 53.17
1584.19S 2055.13W 559837.59 5967029.74 n70 19 13.81 w149 30 53.62
1595.73S 2068.59W 559824.22 5967018.09 n70 19 13.69 w149 30 54.01
1617.37S 2093.86W 559799.13 5966996.25 n70 19 13.48 w149 30 54.75
1635.77S 2115.34W 559779.80 5966977.67 nT0 19 13.30 w149 30 55.38
1641.15S 2121.62W 559771.57 5966972.24 n70 19 13.25 w149 30 55.56
1648.19S 2129.83W 559763.41 5966965.14 nT0 19 13.18 w149 30 55.80
1650.88S 2132.98W 559760.29 5966962.42 n70 19 13.15 w149 30 55.89
1662.66S 2146.73W 559746.64 5966950.53 n70 19 13.03 w149 30 56.29
Ail data in feet unless otherwise stated. Calculation uses minimum curvature method.
Coordinates from slot #123 and TVD from Estimated RKB (101.00 Ft above mean sea level).
Bottom hole distance is 2738.44 on azimuth 232.22 degrees from wellhead.
Total Dogleg for wellpath is 135.15 degrees.
Vertical section is from wellhead on azimuth 232.22 degrees.
Grid is alaska - Zone 4.
Grid coordinates in FEET and computed using the Clarke - 1866 spheroid
Presented by Baker Hughes INTEQ
ORIGINAL
Grid lat long report
page 3 of 4
Phillips Alaska, Inc.
Pad 1C,123
Kuparuk River Unit,North Slope, Alaska
Measured Inclin Azimuth True Vert R E C T A N G
Depth Degrees Degrees Depth C O 0 R D I N
4844.01 7.61 229.42 3595.00 1666.78S
4900.00 5.93 229.42 3650.60 1671.08S
4950.61 4.41 229.42 3701.00 1674.05S
4986.69 3.33 229.42 3737.00 1675.63S
5000.00 2.93 229.42 3750.29 1676.11S
5013.73 2.52 229.42 3764.00 1676.53S
5048.75 1.47 229.42 3799.00 1677.32S
5097.73 0.00 270.00 3847.98 1677.73S
5097.75 0.00 0.00 3848.00 1677.73S
5170.75 0.00 0.00 3921.00 1677.73S
5277.75 0.00 0.00 4028.00 1677.73S
5372.75 0.00 0.00 4123.00 1677.73S
5500.00 0.00 0.00 4250.25 1677.73S
5527.75 0.00 0.00 4278.00 1677.73S
PROPOSAL LISTING Page 2
Your ref : 123 Version#3
Last revised : 10-Apr-2001
U LA R GRID C O 0 R D S G E O
A T E S Easting Northing C 00
2151.54W 559741.86 5966946.37 n70 19
2156.55W 559736.88 5966942.04 n70 19
2160.02W 559733.44 5966939.04 n70 19
2161.87W 559731.60 5966937.44 nT0 19
2162.42W 559731.06 5966936.96 n70 19
2162.92W 559730.56 5966936.53 nT0 19
2163.84W 559729.64 5966935.73 n70 19
2164.32W 559729.17 5966935.32 n70 19
2164.32W 559729.17 5966935.32 n70 19
2164.32W 559729.17 5966935.32 n70 19
2164.32W 559729.17 5966935.32 n70 19
2164.32W 559729.17 5966935.32 n70 19
2164.32W 559729.17 5966935.32 nT0 19
2164.32W 559729.17 5966935.32 n70 19
GRAPHIC
RDINATES
12.99 w149 30 56.43
12.95 w149 30 56.58
12.92 w149 30 56.68
12.91 w149 30 56.74
12.90 w149 30 56.75
12.90 w149 30 56.77
12.89 w149 30 56.79
12.89 w149 30 56.81
12.89 w149 30 56.81
12.89 w149 30 56.81
12.89 w149 30 56.81
12.89 w149 30 56.81
12.89 w149 30 56.81
12.89 w149 30 56.81
All data in feet unless otherwise stated. Calculation uses minimum curvature method.
Coordinates from slot #123 and TVD from Estimated RKB (101.00 Ft above mean sea level).
Bottom hole distance is 2738.44 on azimuth 232.22 degrees from wellhead.
Total Dogleg for wellpath is 135.15 degrees.
Vertical section is from wellhead on azimuth 232.22 degrees.
Grid is alaska - Zone 4.
Grid coordinates in FEET and computed using the Clarke - 1866 spheroid
Presented by Baker Hughes INTEQ
OttI ItVAL
Grid lat long report
page 4 of 4
Phillips Alaska, Inc.
Pad 1C,123
Kuparuk River Unit,North Slope, Alaska
PROPOSAL LISTING Page 3
Your ref : 123 Version#3
Last revised : 10-Apr-2001
Comments in wellpath
====================
MD TVD Rectangular Coords. Comment
300.00 300.00 0 00N 0.00E KOP
800
1200
1301
1627
1963
2192
3031
3222
4351
4633
4680
4844
4950
4986
5013
5048
5097
5097
5170
5277
5372
5527
.00 794.31
.00 1154.99
.11 1237.87
.26 1475.00
.22 1660.23
.72 1768.00
.36 2161.82
.74 2260.00
94 3121.00
19 3388.00
44 3434.00
01 3595.00
61 3701.00
69 3737.00
73 3764.00
75 3799.00
73 3847.98
75 3848.00
75 3921.00
75 4028.00
75 4123.00
75 4278.00
36 22S
129 83S
158 25S
252 20S
405 20S
537 01S
1018 71S
1125 52S
1584 19S
1641.15S
1648.19S
1666.78S
1674.05S
1675.63S
1676.53S
1677.32S
1677.73S
1677.73S
1677.73S
1677.73S
1677.73S
1677.73S
54.07W Build 5/100
193.80W Begin Turn
244.20W Begin Build
445.69W Build/Turn
678.82W EOC
832.70W Base Permafrost
1395.01W Begin Drop
1519.69W K-15
2055.13W Ugnu C
2121.62W Ugnu B
2129.83W Ugnu A
2151.54W K-13
2160.02W Top W Sak D
2161.87W C
2162.92W B
2163.84W A4
2164.32W Target/A3 - EOC
2164.32W WS lC K4(1C-123) Rvsd 4-Apr-01
2164.32W A2
2164.32W Al-Base Pay
2164.32W Base W Sak
2164.32W TD - Csg Pt
Casing positions in string 'A'
==============================
Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing
0.00 0.00 0.00N 0.00E 5527.75 4278.00 1677.73S 2164.32W 7 7/8" Casing
Targets associated with this wellpath
=====================================
Target name Geographic Location T.V.D. Rectangular Coordinates Revised
WS lC K4(1C-123) Rvs 559729.170,5966935.320,0.0000 3848.00 1677.73S 2164.32W 6-Apr-2001
ORIGINAL
l?hiNi~ps AIaska~
Siruc'ure P~d C w~ '23
35S
29 O
2S0
260
220
7O
8O
9C
03
i (/
Summary Clearance Report
Page 1 of l
Phillips Alaska, Inc.
Pad lC
123
slot ~123
Kuparuk River Unit
North Slope, Alaska
SUMMARY CLEARANCE REPORT
by
Baker Hughes INTEQ
Your ref
Our ref
License
123 Version#3
proD4378
Date printed
Date created
Last revised
10-Apr-2001
8-Jan-2001
10-Apr-2001
Field is centred on n70 16 18.576,w150 5 56.536
Structure is centred on n70 19 45.173,w149 30 19.124
Slot location is n70 19 29.388,w149 29 53.643
Slot Grid coordinates are N 5968630.430, E 561879.573
Slot local coordinates are 1605.00 S 873.00 E
Projection type: alaska - Zone 4, Spheroid: Clarke - 1866
Reference North is True North
Object wellpath
1C~117 Version#3,,llT,Pad lC
127 Ver 92,,127,Pad lC
WS lC E1 B-LAT (V.i.C),,106,Pad lC
109 B-Lat vl.c,,109/J5,Pad lC
WS lC G1 B-LAT (V.1.F),,G-1,Pad lC
WS lC G3 B-LAT (V.1.B),,G3,Pad lC
121 Version %2,,121,Pad lC
GMS <0-9700'>,,3,Pad lC
119 V2,,llg,Pad lC
133 Version %3,,133,Pad lC
131 Version #2,,131,Pad lC
GMS <0-7753'>,,5,Pad lC
GMS <0-10243'>,,6,Pad lC
GMS <0-9784'>,,7,Pad lC
Unknown Data,,WS1,Pad lC
PMSS <0 - 10969'),,17,Pad lC
PMSS <0-8677'>,,13,Pad lC
PMSS <0 - l1918'>,,16,Pad lC
MSS <0-7000'>,,9GI,Pad lC
PMSS <0-6529'>,,23 PB1,Pad lC
PMSS <1840-13975>,,23A, Pad lC
PMSS <0-10140'>,,25,Pad lC
PMSS <0-13910'>,,27,Pad 1C
PMSS <0-14630'>,,26,Pad lC
PMSS <0 - 8095'>,,18,Pad lC
GMS <0-7780'>,,1,Pad lC
PMSS <0-9390'>,,15,Pad lC
PMSS <0-10980'>,,14,Pad lC
GMS <0-7575'>,,4,Pad lC
~MS <6948-7570'>,,WS#24,Pad lC
GMS <0-9600'>,,8,Pad lC
PMSS <0-11300'>,,il,Pad lC
PMSS <0-17089'>,,12,Pad lC
GMS <0-7615'>,,2,Pad lC
WS lC A2 (VER.1.B),,A-2,Pad lC
WS lC F2 (VER.1.B),,F-2,Pad lC
101 Version %l,,101/F4,Pad lC
WS lC D2 (VER.1.B),,D-2,Pad lC
PGMS <0-9002'>,,10GI,Pad lC
125 Version#2,,125,Pad lC
129 Version #2,,129,Pad lC
Closest approach with 3-D
Last revised Distance
27-Mar-2001 83.1
26-Mar-2001 60.5
9-Apr-2001 269.3
9-Feb-2001 200.1
29-Jan-2001 299.5
9-Feb-2001 329.8
29-Nar-2001 28.4
18-Dec-1998 292.8
4-Apr-2001 58.4
26-Mar-2001 149.8
29-Mar-2001 120.1
18-Dec-1998 183.0
18-Dec-1998 224.1
18-Dec-1998 309.4
2-Nov-1998 7269.1
2-Dec-1998 374.4
1-Dec-1998 211.3
8-Jan-1999 197.5
2-Jan-1998 369.9
13-Ju1-1999 407.8
8-Jun-1999 407.8
4-Jun-1999 460.7
1-Jan-1999 490.4
24-Aug-1999 476.0
22-Feb-1999 185.9
Il-Mar-1999 503.8
17-Dec-1998 367.1
18-Mar-1998 268.8
18-Dec-1998 213.0
17-Dec-1997 11170.9
18-Dec-1998 413.5
19-Mar-1997 446.6
7-Jan-1998 432.2
18-Dec-1998 393.6
9-Feb-2001 119.5
9-Feb-2001 177.9
12-Feb-2001 345.0
9-Feb-2001 149.8
18-Dec-1998 97.7
28-Mar-2001 29.6
2-Apr-2001 89.9
Minimum Distance method
M.D. Diverging from M.D.
644.4
300.0
200.0
700.0
200.0
200.0
827.3
300.0
827.3
300 0
300 0
100 0
300 0
300 0
1845 5
100 0
200 0
100 0
1027.3
0.0
0.0
322.2
0 0
100 0
300 0
300 0
100 0
100 0
100 0
900 0
0 0
300 0
388 9
300 0
311 1
845 5
322.2
311.1
1190.9
444.4
300.0
5527.8
5527.8
200.0
5031.2
5040.0
5040.0
827.3
5058.5
827.3
5527.8
300.0
100.0
300.0
300.0
1845.5
100.0
200.0
100.0
1027.3
0.0
0.0
322.2
0.0
100.0
300.0
300.0
100.0
5527.8
5527.8
5527.8
388.9
300.0
388.9
5527.8
311.1
845.5
322.2
311.1
1190.9
444.4
300.0
Ot IGINAL
P lh f 1 t i ? s A1 a s k a~ f n c.
Structure : Pad lC Weft : 123
Field : Kuporuk River Unif Location : North Slope, A[~sko
West (fee0
i
v
2200
<- Wesf (reef)
<. West (feet)
<- West (feet)
Diagram and De scription of 1.1" 5,000 I ,si Blowout
P l, tention Equipment
West Sak Dual Purpose Wells, Kuparuk River Unit
Top of Tubing Head: ~ [
Elevation is 55.6 inches ! 2
above pad level. ~,i'
1
8-5/8" Casing ~
16" Casing
KEY:
1. Landing Ring, 16" x 13-5/8", Vetco Gray, with 8-5/8" x 7-5/8"
Casing Landed
2. Tubing Head, 10-3/4" Vetco Gray Quick Connect Bottom x APl
11" 5000 psi Flange Up, Vetco Gray.
3. Spacer Spool, 11" 5000 psi x 11" 5000 psi, Nabors.
4. Single Ram BOP, 11" x 5000 psi, with pipe rams**, Nordic
5. Drilling Spool, 11" x 5000 psi, w/2 Side Outlets, Nordic
6. Double Ram BOP,11" x 5000 psi, with Dual Pipe Rams
(2-3/8" x 3-1/2") on Top and Blind Rams on Bottom, Nordic
7. Annular BOP, 11" x 5000 psi, Hydril GK, Nordic
8. Choke Valve, Manual Operation, 4-1/16" x 5,000 psi, Nabors
9. Choke Valve, Hydraulically Operated, 4-1/16" x 5,000 psi, Nabors
10. Kill Line Valve, Manual Operation, 3-1/8" x 5,000 psi, Nabors
11. Kill Line Valve, Hydraulically Operated, 3-1/8" x 5,000 psi, Nabors
Accumulator Capacity Test
1. Check and fill accumulator reservoir to proper level with hydraulic
fluid.
2. Assure that accumulator pressure is 3000 psi with 1500 psi
downstream of the regulator.
3. Observe time, then close all units simultaneously and record the time
and pressure remaining after all units are closed with the charging
pump off.
4. Record on the IADC report. The acceptable lower limit is 45 seconds
closing time and 1200 psi remaining pressure.
BOP Stack Test
1. Fill BOP stack and manifold with water.
2. Check that all hold-down screws are fully retracted. Predetermine
depth that test plug will seat and seat in wellhead. Run in lock-down
screws in head.
3. Close annular preventer, chokes, and bypass valves on the manifold.
All others open.
4. Test all components to 250 psi and hold for 3 minutes. Increase
pressure to 5000 psi and hold for 3 minutes. Bleed back to zero psi.
5. Open annular preventer and manual kill and choke line valves.
6. Close top pipe rams and HCR valves on kill and choke lines
7. Test to 250 psi and 5000 psi as in step 4. Continue testing all valves,
lines, and chokes with a 250 psi Iow and 5000 psi high. Test as in
step 4. Do not pressure test any choke that is not a full closing
positive seal choke.
8. Open top pipe rams and close bottom pipe rams. Test bottom rams
to 250 psi and 5000 psi for 3 minutes.
9. Open pipe rams. Back off running joint and pull out of hole. Close
blind rams and test to 5000 psi for 3 minutes. Bleed to zero psi.
10. Open blind rams and recover test plug. Make sure manifold and lines
are full of Arctic diesel and all valves are set in the drilling position.
11. Test standpipe valves to 5000 psi for 3 minutes.
12. Test kelly cocks and inside BOP to 5000 psi.
13. Record test information on blowout preventer test form. Sign and
send to drilling supervisor.
14. Perform BOPE test once per week and functionally operate BOPE
daily.
ORIGINAL
prepared by
Steve McKeever
5/06/01
1C-123 Drillin l Hazards Summary_
(SEE WELL PLAN FOR DETAILED DISCUSSION OF THESE RTSKS)
9-7 ! 8" Open Hole ! 8-5! 8" x 7-5 !8" Casin§ :Interval
Hazard I Risk Level I Mitigation Strategy
Broach of Conductor Moderate IVlonitor cellar continuously during interval.
Gas Hydrates Moderate Control drill, Reduced pump rates, Reduced
drilling fluid temperatures, Additions of
driltreat.
Running Sands and Moderate Maintain planned mud parameters,
Gravels Increase mud weight, use weighted
sweeps, run gravel isolation string.
Abnormal Reservoir Low Diver~er drills, increased mud weight.
Pressure
Lost circulation Low Reduced pump rates, mud rheology, LCM
Hole swabbing on trips IVloderate Trip speeds, Proper hole filling, pumping
OUt
ORI IIVAL
1C-133 Drilling Hazards Summary
prepared by Mark Chambers
2/18/01
West Sak 1C-123 Dual Pt ,,ose Well, Cement Loads and CemCADx. _,mnmary.
35 % Excess Below permafrost, 250% Above permafrost with 50 bbls to surface.
9-7/8" Openhole. TD @ 5528' MD. 7-5/8", 29.7# Casing. Base of permafrost @ 2193' MD.
Port collar for no cement to surface contingency. Port Collar @ 1000' MD.
Tail Slurry TOC @ 4451' MD. (500' above D Sand).
ECP at 5049' MD.
Volume Calcs:
Pump 40 bbls CW preflush, 50 bbls MudPUSH XL @ 10.2 ppg. Cement from TD to 4451' MD
with Class G + adds @ 15.8 ppg, and from 4451' to surface with ASLite @ 10.7 ppg.
Leave cement in casing for ECP inflation.
Lead Slurry Requirements:
ASLite @ 10.7 ppg, Class G + 50% D124, 3.5% D44, 0.4% D46, 30% D53,
1.5% S 1, 1.5% D79 - 4.44 ft3/sk
(4451' - 2193') x 0.2148 ft3/ft x 1.35 (35% excess)
2193' x 0.2148 x 3.5 (250% excess)
50 bbls to surface
Total
2584.20 ft3/4.44 ft3/sk
= 654.77 ft3
= 1648.70 ft3
= 280.73 ft3
= 2584.20 ft3
= 582.0 sks
Round upto 590 sks
Tail Slurry Requirements: BATCH MIX for 60 min. prior to pumoin~.
Expanding Cement @ 15.8 ppg, Class G + 0.45% D65, 0.3% M117, 2.0 gps D600, 0.1%
D35, 0.2% D47, 3.0% D174 - 1.20 ft3/sk
(5528' - 4451') x 0.2148 ft3/ft x 1.35 (35% excess)
80' (shoe joints) x 0.2578 ft3/ft
(5448' - 5049') x 0.2578 ft3/ft (fill from float to ECP)
(5 bbls above ECP)
Total
463.87 ft3/1.20 ft3/sk
= 312.31 ft3
= 20.62 ft3
= 102.86 ft3
= 28.08 ft3
= 463.87 ft3
= 385.5 sks
Round upto 390 sks
CemCADE* Summary:
Fluid sequence: Establish circulation using FW. 40 bbl CW100 preflush, Drop Bottom
Plug, 50 bbls 10.2 ppg MudPUSH XL spacer, 590 sks (466 bbls) ASLite Lead, 280 sks
(60 bbls) Class G + adds, Drop Top Plug, Pump additional 110 sks (23.5 bbls) Class G
+ adds on top of the plug. Displacement is approximately 227 bbls.
Circulation:
Circulation and cementing at or less than 6 bpm is within safe ECD to avoid breaking
down the formation. Recommend dropping the rate below 3 bpm for the last 20 bbls of
displacement for bumping the plug as well as maintaining returns. Estimated maximum
surface pressure during the job is 1050 psi. Run dye marker in the spacer to provide
insight into the decision to open port collar or performing a top job.
Recommended Conditioned Mud Properties:
9.6 ppg, PV < 12, Ty < 12, as thin and light as possible for effective mud removal.
04-27-2001
AT
OttI IIVAL
Well # 1C-123, AFE #AK0173
West Sak Dual Purpose Well
Completion Schematic
Sheet I of 3: Casing String Details
Tubing Head,
Vetco-Gray Horizontal for Dual
Completion, APl 11" 5000 psi Flange up x
Vetco 13-5/8" Female Overshot Bottom
Landing Ring:
Vetco-Gray, 16" Weld on Bottom x
13-5/8" Male Overshot Top
PHILLIPS Alaska, Inc.
A Subsidiary of PHILLIPS PETROLEUM COMPANY
Nabors Rig 245 RKB @ 0'
Eastings: 561,880.54
Northings: 5,968,630.35
Elevation: 102.0' AMSL
A...~~ Casing Hanger:
Vetco-Gray, with 8-5/8", 36#,
Hydril 511 pin down x Acme
box up
16" Conductor
@ +/- 161' MD
(2) Joints Casing:
8-5/8", 36#, L-80, Hydril 511
Crossover:
8-5/8", 36#, L-80 Hydril 511 Box by 7-
5/8", 29.7#, L-80, BTC Pin
Port Collar:
TAM, 7-5/8", 29.7#, L-80, BTC Pin
Set @ +/- 1000' MD / 982' TVD
(x) Joints Casing:
7-5/8", 29.7#, L-80, BTCM
External Casing Packer
Baker Model CTC 'Payzone', 40 ft
length, 7-5/8", 29.7#, L-80, BTCM
Set at depth to isolate 'B' Sand from
'A' Sand
, (x) Joints Casing:
7-5/8", 29.7#, L-80, BTCM
Float Collar:
Weatherford 7-5/8", 29.7#,BTCM
(2) Joints Casing:
7-5/8", 29.7#, L-80, BTCM
..~- Float Shoe:
Weatherford 7-5/8", 29.7#,BTCM
TD 9-7/8" Hole:
5,528' MD / 4,278' TVD
OtTI II AL
1C- 123 Completion Schematic
Sheet 1 of 3: Casing Stri/~g Details
prepared by Steve McKeever
May 7, 2001
Well # 1C-123, AFE #AK0173
West Sak Dual Purpose Well
Completion Schematic
Sheet 2 of 3: 'A' Sand Completion Details
PHILLIPS Alaska, Inc.
Subsidiary of PHILLIPS PETROLEUM COMPANY
See Sheet 3 for 'B' and 'D'
Sand Completion Details
External Casing
Packer
'A' Sand
Perforations
Packer:
Baker Model SC-l, w/80-40 Seal Bore Extension
and Sliding Sleeve.
Set Above Top A-Sand Perforation.
Gravel Pack Extension:
Baker Model "S", Size 80-40 with Sliding Sleeve and
lower extension, 5-1/2", 18#, SLHT Pin x 5" 18#
SLHT Pin
XO:
5", 18#, SLHT Box by 4", 9.5#, SLHT Pin
Tubing Pup:
4 ft long, 4", 9.5#, SLHT Box x Pin
Nipple:
'XN',, 2-3/8", with 1.875" Polished Bore and 1.791"
No-Go, installed into nipple reducer of 4" 'XN' Nipple
Nipple:
'XN',, 4", 9.5#, SLHT Box x Pin, with 3.313"
Polished Bore and 3.135" No-Go, with nipple
reducer XN lock installed.
Shear Out Safety Joint:
Baker Model GPR-24, 4", 9.5#, SLHT Box x Pin
Excluder:
Baker 2000, 4", 9.5#, SLHT Box x Pin
Screen:
Bakerweld 140, 4", 9.5#, SLHT Box x Pin
Plug Back TD
@ +/- 5,330 MD
Bull Plug:
Baker, 4", 9.5#, SLHT Box up
Bridge Plug:
Baker Model N-l, 7-5/8", 29.7#, Size 4AA
Set +/- 10 feet below bottom perforation.
7-5/8", 29.7#, L-80
casing @ 5,528' MD /
4,278' TVD
ORIGINAL
1C- 123 Completion Schematic
Sheet 2 of 3: 'A' Sand Gravel Pack Details
prepared by Steve McKeever
May 7, 2001
Well # 1 C-123, AFE #AK0173
West Sak Dual Purpose Well
Completion Schematic
Sheet 3 of 3: 'B' & 'D' Completion Details
2" Coil Tubing:
Jet Pump:
Weatherford, for 2.813" Polished Bore, and
connection to 2" Coil
2-3/8" Tubing
4.6#, L-80, Hydri1511
Gaslift Mandrel:
camco Model KBMM, 2-3/8", with 6' Handling
Pups top and bottom
2-3/8" Tubing Pups
4.6#, L-80, Hydri1511
Telescoping Swivel:
Baker, with 2 ft stroke, 2-3/8", 4.6# with XO on bottom
from 2-3/8" NU 10rd to Hydri1511pin
2-3~8" Tubing
4.6#, L-80, Hydri1511
Sliding Sleeve:
Baker Model Slimline CMU, 2-3/8" x 1.875",with XO's
top and bottom from 2-3/8" RTS-8 to Hydri1511,
Set above Top Perforation.
2-3/8" Tubing:
4.6#, L-80, Hydril 511
Landing Nipple:
Halliburton 'X', 2-3/8", 1.875" Polished Bore,
Hydri1511 Box and Pin
Waterflood Mandrel:
Camco Model KBMGW, 2-3/8", with 6' Handling
Pups top and bottom
Polished Bore Receptacle:
Baker, 2-3/8" x 1.875°' Bore, 2-3/8", Hydri1511
Tubing Joint:
30 ft long, 2-3/8", 4.6#, L-80, Hydril 511
Landing Nipple:
Halliburton 'XN', 2-3/8", 1.875" Polished Bore,
1.791" No-Go, Hydri1511 Box and Pin
Tubing Pup Joint:
10 ft long, 2-3/8", 4.6#, L-80, Hydri1511
Wireline Entry Guide:
2-3/8", 4.6#, Hydril 511 box
7-5/8" External Casing Packer
See Sheet 2 for 'A' Sand
Completion Details
PHILLIPS Alaska, Inc.
Subsidiary of PHILLIPS PETROLEUM COMPANY
Wellhead & Tree:
ABB Vetco Gray, Dual Horizontal with Coil Hanger
3-1/2" Tubing, 9.2#, L-80, Hyddl 511
Landing Nipple:
for Weatherford Jet Pump, with 5' x 2.813"
Polished Bore and No-Go at Top.
/2" Tubing, 9.2#, L-80, Hydril 511
XO:
3-1/2" 9.2#, L-80, Hydril 511 Box by 2-3/8" 4.6#
L-80 Hydriol 511 Pin
2-3/8" Tubing, 4.6#, L-80, Hydril 511
Tubing Anchor:
Baker Parallel K22, 2-3/8" x 2.688", w/XO's
above to 2-3/8" Hydril 511 box
ScoopHead:
Baker, Size 47D, 2-3/8" x 2.688", with XO's
below to Hydril 511, Made up in long string.
2-3~8" Tubing, 4.6#, L-80, Hydril 511
Dual Packer @ +/- 4950' (Top of 'D'):
Baker Model 47D4 GT, w/XO's above & below
to Hydril 511 from NU 10rd pins top & bottom.
2-3/8" Tubing, 4.6#, L-80, Hydril 511
Blast Joints:
2-3/8", 4.6#, Hydril 511, Spaced out to be
opposite the Slidign Sleeve
2-3/8" Tubing, 4.6#, L-80, Hydril 511
Blast Joints:
2-3/8", 4.6#, Hydril 511, Spaced out to be
opposite the Gas Lift mandrel
2-3/8" Tubing, 4.6#, L-80, Hydril 511
Dual Packer @ +/- 4990' (Mid 'C' Shale):
Baker Model 47D4 GT, w/XO's above & below
to Hydril 511 from NU 10rd pins top & btm.
2-3/8" Tubing, 4.6#, L-80, Hydril 511
Blast Joints:
2-3/8", 4.6#, Hydril 511
2-3/8" Tubing, 4.6#, L-80, Hydril 511
Seal Assembly:
Baker, 80-40 with Snap Latch, Indexing
Mule Shoe, 14 ft long, w/6 foot handling
pup (2-3/8", 4.6#, Hydril 511)
Packer @ +/- 5048' (Top 'A-4' Sand)
Baker Model SC-l, w/80-40 Seal Bore
Extension and Sliding Sleeve. Set Above
Top A-Sand Perforation prior to 'A' Sand
gravel pack.
IC- 123 Completion Schematic
Sheet 3 of 3: 'B' and 'D' Sand Completion Details
prepared by Steve McKeever
May 7, 2001
PHILLIP(' Alaska, Inc.
A Subsidiary of PHILLIPS PETROLEUM COMPANY
Post Office Box 100360
Anchorage, Alaska 99510-0360
James Trantham
Phone (907) 265-6434
Fax: (907) 265-1535
Emaih jtranth@ppco.com
May 7, 2001
Daniel T. Seamount, .lr., Chairman
Alaska Oil and Gas Conservation Commission
333 West 7~ Avenue
Suite 100
Anchorage, Alaska 99501
(907) 279-1433
Re: Application for Permit to Drill, West Sak Dual Purpose Well 1C-123.
Dear Commissioner Seamount:
Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore well in the West Sak Oil Pool, #1C-
123. This well will be completed with two strings of tubing, with one string being used for injection to
provide pressure support for production from the West Sak "D" and "8" sands, and the other string being
used for oil production from the West Sak "A' sand. The expected spud date for this well is May 20,
2001.
Please find attached for the review of the Commission Form 10-401 and the information required by 20
ACC 25.005.
If you have any questions or require any further information, please contact me at 263-6434 or Steve
McKeever at 265-6826.
Sincerely,
]ames Trantham
Drilling Engineering Supervisor
RECEIVED
0"? 2001
Alaska Oil & Gas Cons. Commission
Ancho~e
Oii INAL
Note to File t~
PPCO lC-~'3~ (201-084)
This well is the first of 3 multi-purpose wells proposed by Phillips. The wells will be
completed with dual tubing strings. The deep string will produce from the West Sak A
sands. The shallower string will inject water for enhanced recovery into the West Sak b
and C sands.
Phillips intends to batch drill the three wells and then batch complete. They plan to us®
Nabors 245e (formerly Parker 245).
The program is pretty straight forward, although they do not propose to perform a full
casing pressure test prior to moving the rig to the next well. Their reasoning is that their
cement job is critical and they do not want to risk stressing the cement during its setting
process. Their intent is to prevent the formation of a micro annulus that would
compromise their isolation integrity.
I believe their proposal is prudent. Although they will not have accomplished the full
pressure test they ultimately intend, they will have bumped the plug during the
cementing operation with a pressure in excess of their "lifting" pressure. This process
can be considered a reasonable pressure test at that time. Based on the TVD at the top
of the D (3701') the required MIT test pressure by regulation is only 925 psi.
I have spoken with Mark Chambers with regard to their intended freeze protection
procedure. Their original intent is to displace the wellbore to diesel from 2000' when
pulling out of the hole. As additional pipe is removed, they will fill with seawater keeping
the diesel on top. I suggested he investigate a procedure employed in the mid 80s. At
that time after bumping the plug with completion brine, the uppermost 120' of hole would
be blown dry using air. This technique was successfully employed on several hundred
wells with no adverse effect that I am aware of. The advantage of this technique is that
it eliminates having diesel in the BOP stack while tripping. Personnel safety and
environmental protection can be enhanced through the use of this procedure. Mark
indicated he would look into employing it.
Tom Maunder, PE
May 10, 2001
American Express®
Cash Advance Draft
131
issued by Inteir~ted Payment System, Inc.
En,~lewood, Color'-~do ' NOT VALID FOR AMOUNT OVER $1000
Payable ,t Norwest Bank of GrandJunctJon - Downtown, N.A. ,(~..~*/ SHARON,,~T~LSU
Grand Junction. C. olomdo
': ;i,D ;~ ;i, DDhDD': 5 5 ,,,D
WELL PERMIT CHECKLIST COMPANY ,/~,~ ~/,//x/g, ~' WELL NAME/~-.-/'2 c~ PROGRAM: exp ~ dev. .
FIELD & POOL ~ 7o/.5'~ INIT CI~S~S ~z-.' /- <= 2 GEOL AREA
,,~ redril ~ serv .... wellbore seg ~
UNIT#
N
N
N
N
N
N
N.
N
N ,-
N
N
N
N
N
.N
N
ann. disposal para req ~
ON/OFF SHORE
ADMINISTRATION
DATE
1. Permit fee attached .......................
2. Lease number appropriate ...................
3. Unique well name and number ..................
4. Well located in a defined pool ..................
5. Well located proper distance from drilling unit boundary ....
6. Well located proper distance from other wells ..........
7. Sufficient acreage available, in drilling unit ............
8. If deviated, is wellbore plat included ............. ·..
9. Operator only affected party ...................
10. Operator has appropriate bond in force .............
11. Permit can be issued without conservation order ........
12. Permit can.be issued without administrative approval ......
13. Can permit be approved before 15-day wait ...........
ENGINEERING 14.
15.
16.
17.
18.
19.
20.
21.
22.
23.
24.
25.
TE 26.
~/~1.~ 27.
28.
29.
GEOLOGY . 30.
31.
32.
,,~R D.,~T,E 33.
34.
Conductor string provided ...................
Surface casing protects all known USDWs ...........
CMT vol adequate to circulate on conductor & surf csg .....
CMT vol adequate to tie-in long string to surf csg .... ' ....
CMT will cover all known productive horizons ..... ' .....
Casing designs adequate for C, T, B & permafrost .......
Adequate tankage or reserve pit .................
If a re-drill, has a 10-403 for abandonment been approved...
Adequate wellbore separation proposed .............
If diverter required, does it meet regulations ...........
Drilling.fluid program schematic & equip list adequate.. ~ . .
BOPEs. do they meet regulation .....
BOPE press rating appropriate; test to ~;:~-~ ''
Choke manifold complies w/APl RP-53 (May 84) ........
Work will occur without operation shutdown ...........
Is presence of H2S gas probable .................
Permit can be issued wlo hydrogen sulfide measures ......
Data presented on potential overpressure zones .......
Seismic analysis of shallow gas zones .............
/.--
Seabed condition survey (if off-shore) ............. /~'Y N
Contact name/phone for weekly progress reports [exploratory ofily] Y N
ENGINEERING:. UICIAnnular
~:> , ,
~,NNULAR DISPOSAL35. With proper cementing records, this plan
(A) will contain waste in a suitable receiving zonei ....... Y N
APPR 'DATE (B) will not contaminate freshwater; or cause drilling waste... Y N
to surface; '
(C) will not impair mechanical integrity of the Well used for diSposal; Y N
(D) will not damage producing formation or impair recovery from a Y N
pool; and
(E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N
GEOLOGY: COMMISSION:
co
c:~msoffice\wordian~iana\checklist (rev. 111011100)
Comments/Instructions:
J§
I§
Z
--I
-1-
Well History File
APPENDIX
Information of detailed nature that is not
particularly germane to the Well Permitting Process
but is part of the history file.
To improve the readability of the Well History file and to
simplify finding infOrmatiOn, information, of this.
.nature is accumulated at the end of the file under APPENDIXi
.,
No 'special'effort has been made to chronologically
organize this category of information.
01-o
**** REEL HEADER ****
LDWG
02/12/05
AWS
01
**** TAPE HEADER ****
LDWG
02/12/05
01
*** LIS COM~ENT RECORD ***
!!!!!!!!!!!!!!!!!!! LDWG File Version 1.000
!!!!!!!!!!!!!!!!!!! Extract File: LISTAPE.HED
TAPE HEADER
WEST SAK UNIT
MWD/MAD LOGS
WELL NAME:
API NUMBER:
OPERATOR:
LOGGING COMPANY:
TAPE CREATION DATE:
JOB DATA
JOB NUMBER:
LOGGING ENGINEER:
OPERATOR WITNESS:
SURFACE LOCATION
SECTION:
TOWNSHIP:
RANGE:
FNL:
FSL:
FEL:
FWL:
ELEVATION(FT FROM MSL 0)
KELLY BUSHING:
DERRICK FLOOR:
GROUND LEVEL:
WELL CASING RECORD
1ST STRING
2ND STRING
3RD STRING
PRODUCTION STRING
lC-123
500292301600
Phillips Alaska, Inc.
BAKER HUGHES INTEQ
05-DEC-02
REMARKS:
MWD RUN 1 MWD RUN 2
1 2
S. FRANK R. MADARAPU
R. SPRINGER R. SPRINGER
OPEN HOLE
12
liN
10E
102.00
PER PHILLIPS ALASKA STANDING ORDER FOR WEST SAK, THE
MWD RUN 3
24.000 16.000 161.0
9.875 5445.0
CASING DRILLERS
BIT SIZE (IN) SIZE (IN) DEPTH (FT)
GAMMA RAY CURVE FROM THIS LOG IS THE DEPTH REFERENCE
FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN
APPLIED.
INDIVIDUAL MW-D RUN DATA WAS MERGED IN THE FIELD
PRIOR TO DELIVERY FROM WELL SITE.
SURFACE LOCATION:
LAT: N70 DEG 19' 12.887"
LONG: W149 DEG 30' 56.800"
LOG MEASURED FROM D.F. AT 102.0 FT. ABOVE PERM. DATUM
(M.S.L.) .
BAKER HUGHES INTEQ RUNS 1 AND 2 UTILIZED MULTIPLE
PROPAGATION-RESISTIVITY (MPR) SERVICES IN A STEERABLE
ASSEMBLY FROM 161 - 5445' MD (161 - 4281' TVD).
NO DATA WAS LOGGED FROM 161 TO 174 FEET MD (161 -
174' TVD) DUE TO INSUFFICIENT FLOW TO POWER UP THE
MWD SENSORS.
PER PAI GEOSCIENCE REQUEST, THE CURVE "RS60", A 60"
FIXED DEPTH OF INVESTIGATION RESISTIVITY RESULT
FROM INTEQ'S POST PROCESSING ROUTINE (MPRTEQ), IS
INCLUDED IN THIS LDWG OUTPUT. MPRTEQ PROCESSING
WAS REQUESTED OVER AND IS ONLY PRESENTED FOR THE
INTERVAL FROM 4180 - 5400' MD.
1) 16" CASING DEPTH - LOGGER: 161' MD (161' TVD)
RESISTIVITY DATA RECORDED OVER THE INTERVAL FROM 174 -
2035 FEET MD (174 - 1800' TVD) IS ERRATIC DUE TO THE
PRESENCE OF PERMAFROST.
2) THE INTERVAL FROM 2063 TO 2120 FEET MD (1810-1857'
TVD) WAS LOGGED UP TO 8.2 HOURS AFTER BEING DRILLED
DUE TO A SHORT TRIP.
3) THE INTERVAL FROM 4163 TO 4220 FEET MD (3079-3123'
TVD) WAS LOGGED UP TO 11.7 HOURS AFTER BEING DRILLED
DUE TO A TRIP OUT OF THE HOLE TO CHANGE THE BIT.
4) THE INTERVAL FROM 5387 - 5445' MD (4224 - 4281'
TVD) WAS NOT LOGGED DUE TO SENSOR OFFSET AT TD.
$
Tape Subfile: 1
77 records...
Minimum record length:
Maximum record length:
8 bytes
132 bytes
**** FILE HEADER ****
LDWG .001
1024
*** LIS COMMENT RECORD ***
!!!!!!!!!!!!!!!!!!! LDWG File Version 1.000
!!!!!!!!!!!!!!!!!!! Extract File: FILE001.HED
FILE HEADER
FILE NUMBER: 1
EDITED MERGED MWD
Depth shifted and clipped curves; all bit runs merged.
DEPTH INCREMENT: .5000
FILE SUMYLARY
PBU TOOL CODE START DEPTH STOP DEPTH
MWD 174.0 5445.0
$
#
BASELINE CURVE FOR SHIFTS:
CURVE SHIFT DATA (MEASURED DEPTH)
EQUIVALENT UNSHIFTED DEPTH
BASELINE DEPTH
$
MERGED DATA SOURCE
PBU TOOL CODE
$
REMARKS:
BIT RUN NO MERGE TOP MERGE BASE
1 174.0 4163.0
2 4163.0 5445.0
MERGED PASS.
PER PHILLIPS ALASKA STANDING ORDER FOR WEST SAK, THE
GAMMA RAY CURVE FROM THIS LOG IS THE DEPTH REFERENCE
FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN
APPLIED.
THE CURVE "RS60" IS THE 60" FIXED DEPTH OF INVESTIGA-
TION RESISTIVITY RESULT FROM INTEQ'S MPRTEQ POST
PROCESSING ROUTINE. IT IS PRESENTED OVER THE INTERVAL
FROM 4180 - 5400' MD ONLY.
$
*** INFORMATION TABLE: CONS
MNEM VALU
WDFN lwd 5.xtf
LCC 150--
CN Phillips Alaska, Inc.
WN 1C-123
FN West Sak
COUN North Slope
STAT Alaska
*** INFORMATION TABLE: CIFO
MNEM CHAN DIMT CNAM
ODEP
GR GR GRAM 0.0
RPD RPD RPD 0.0
RPM RPM RPM 0.0
RPS RPS RPS 0.0
RPX RPX RPX 0.0
RS60 RS60 RES60 0.0
ROP ROP ROPS 0.0
FET FET RPTH 0.0
MTEM MTEM TCDM 0.0
FORMAT RECORD (TYPE# 64)
Data record type is: 0
Datum Frame Size is: 40 bytes
Logging direction is down (value= 255)
Optical Log Depth Scale Units: Feet
Frame spacing: 0.500000
Frame spacing units: [F ]
Number of frames per record is: 25
One depth per frame (value= 0)
Datum Specification Block Sub-type is:
FRAME SPACE = 0.500 * F
ONE DEPTH PER FRAME
Tape depth ID: F
9 Curves:
Name Tool Code Samples Units
1 GR MWD 68 1 GAPI
2 RPD MWD 68 1 OHMM
3 RPM MWD 68 1 OHMM
4 RPS MWD 68 1 OH/M~
5 RPX MWD 68 1 OHM~
6 RS60 TEQ 68 1 OHMM
7 ROP MWD 68 1 FPHR
8 FET MWD 68 1 HR
9 MTEM MWD 68 1 DEGF
Total Data Records: 422
Size Length
4 4
4 4
4 4
4 4
4 4
4 4
4 4
4 4
4 4
36
Tape File Start Depth = 174.000000
Tape File End Depth = 5445.000000
Tape File Level Spacing = 0.500000
Tape File Depth Units = feet
**** FILE TRAILER ****
Tape Subfile: 2
472 records...
Minimum record length:
Maximum record length:
8 bytes
4124 bytes
**** FILE HEADER ****
LDWG .002
1024
*** LIS COMMENT RECORD ***
!!!!!!!!!!!!!!!!!!! LDWG File Version 1.000
!!!!!!!!!!!!!!!!!!! Extract File: FILE011.HED
FILE HEADER
FILE NUMBER: 2
RAW MWD
Curves and log header data for each bit run in separate files.
BIT RUN NO: 1
DEPTH INCREMENT: .2500
FILE SUMY~ARY
VENDOR TOOL CODE START DEPTH
MWD 174.0
$
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME):
STOP DEPTH
4163.0
16-JUN-01
MSB 18655
6.75 MPR
MEMORY
TD DRILLER (FT):
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT):
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG)
MINIMUM ANGLE:
MAXIMUM ANGLE:
4220.0
174.0
4163.0
0
.0
56.4
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE
DIR DIRECTIONAL COLLAR
MPR MULT. PROP. RESIST.
GRAM GAMMA RAY
$
TOOL NUMBER
DAS12160
MPR 4859
SRIG5073
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT):
9.875
161.0
BOREHOLE CONDITIONS MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY S):
MUD PH:
MUD CHLORIDES PPM):
FLUID LOSS (C3 :
RESISTIVITY (OHMI~) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TEMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
FW SPUD
9.40
.0
.0
200
.0
.000
.000
.000
.000
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
.00
.000
TOOL STANDOFF (IN) :
EWR FREQUENCY (HZ) :
.0
0
REMARKS:
BIT RUN 1 (MWD RUN 1).
GR/MPR.
CURVE GLOSSARY:
GRAM - GAMPLA RAY APPARENT (MWD-API)
RPCL - DEEP PHASE RESISTIVITY (OHMS)
RPSL - MEDIUM PHASE RESISTIVITY (OHMM),
RPCH - SHALLOW PHASE RESISTIVITY (OHPIM)
RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM)
ROPS - RATE OF PENETRATION (FPHR)
RPTH - FORMATION EXPOSURE TIME (MIN)
TCDM - BOREHOLE TEMPERATURE (DEGF)
$
.0
80.0
.0
.0
*** INFORMATION TABLE: CONS
MNEM VALU
WDFN lwd.xtf
LCC 150
CN Phillips Alaska, Inc.
WN lC-123
FN West Sak
COUN North Slope
STAT Alaska
*** INFORMATION TABLE: CIFO
MNEM CHAN DIMT CNAM
ODEP
GRAM GRAM GRAM
RPCL RPCL RPCLM
RPSL RPSL RPCSLM
RPCH RPCH RPCHM
RPSH RPSH RPCSHM
ROPS ROPS ROPS
RPTH RPTH RPTHM
TCDM TCDM TCDM
* FORMAT RECORD (TYPE# 64)
Data record type is: 0
Datum Frame Size is: 36 bytes
Logging direction is down (value= 255)
Optical Log Depth Scale Units: Feet
Frame spacing: 0.250000
Frame spacing units: [F ]
Number of frames per record is: 28
One depth per frame (value= 0)
Datum Specification Block Sub-type is:
FRAME SPACE = 0.250 * F
ONE DEPTH PER FRAME
Tape depth ID: F
8 Curves:
Name Tool Code Samples Units
1 GRAM MWD 68 1 GAPI
2 RPCL MWD 68 1 OHMS4
3 RPSL MWD 68 1 OHM~
4 RPCH MWD 68 1 OHM~
5 RPSH MWD 68 1 OHMM
6 ROPS MWD 68 1 FPHR
7 RPTH MWD 68 1 MINS
8 TCDM MWD 68 1 DEGF
Total Data Records: 570
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
Size Length
4 4
4 4
4 4
4 4
4 4
4 4
4 4
4 4
32
Tape File Start Depth = 174.000000
Tape File End Depth = 4163.000000
Tape File Level Spacing = 0.250000
Tape File Depth Units = feet
**** FILE TRAILER ****
Tape Subfile: 3
Minimum record length:
Maximum record length:
656 records...
8 bytes
4124 bytes
**** FILE HEADER ****
LDWG .003
1024
*** LIS COMMENT RECORD ***
!!!!!!!! !!!!!!!!!!! LDWG File Version 1.000
!!!!!!!!!!!!!!!!!!! Extract File: FILE012.HED
FILE HEADER
FILE NUMBER: 3
RAW MWD
Curves and log header data for each bit run in separate files.
BIT RUN NO: 2
DEPTH INCREMENT: .2500
FILE SUMMARY
VENDOR TOOL CODE START DEPTH STOP DEPTH
MWD 4163 . 0 5445 . 0
$
LOG HEADER DATA
DATE LOGGED: 17-JUN-01
SOFTWARE
SURFACE SOFTWARE VERSION: MSB 18655
DOWNHOLE SOFTWARE VERSION: 6.75 MPR
DATA TYPE (MEMORY OR REAL-TIME): MEMORY
TD DRILLER (FT): 5445.0
TOP LOG INTERVAL (FT): 4163.0
BOTTOM LOG INTERVAL (FT): 5389.0
BIT ROTATING SPEED (RPM): 0
HOLE INCLINATION (DEG)
MINIMUM ANGLE: 9.6
MAXIMUM ANGLE: 41.8
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE TOOL NUMBER
DIR DIRECTIONAL COLLAR DAS5059196
MPR MULT. PROP. RESIST. MPR 4859
GRAM GAMMA RAY SRIG5073
$
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN): 9.875
DRILLER'S CASING DEPTH (FT) : 161.0
BOREHOLE CONDITIONS
MUD TYPE: FW SPUD
MUD DENSITY (LB/G): 9.40
MUD VISCOSITY (S): .0
MUD PH: .0
MUD CHLORIDES (PPM): 200
FLUID LOSS (C3): .0
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT): .000 .0
MUD AT MAX CIRCULATING TEMPERATURE: .000 72.0
MUD FILTRATE AT MT: .000 .0
MUD CAKE AT MT: .000 .0
NEUTRON TOOL
MATRIX:
MATRIX DENSITY: .00
HOLE CORRECTION (IN): .000
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
.0
0
REMARKS:
BIT RUN 2 (MWD RUN 2).
GR/MPR.
CURVE GLOSSARY:
GRAM - GAMMA RAY APPARENT (MW-D-API)
RPCL - DEEP PHASE RESISTIVITY (OHM/~)
RPSL - MEDIUM PHASE RESISTIVITY (O~)
RPCH - SHALLOW PHASE RESISTIVITY (OHPIM)
RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM)
RS60 - MPRTEQ 60" FIXED DEPTH OF INVEST. RESIS. (OHMM)
ROPS - RATE OF PENETRATION (FPHR)
RPTH - FORMATION EXPOSURE TIME (MIN)
TCDM - BOREHOLE TEMPERATURE (DEGF)
$
*** INFORMATION TABLE: CONS
MNEM VALU
WDFN lwd.xtf
LCC 150
CN Phillips Alaska, Inc.
WN 1C-123
FN West Sak
COUN North Slope
STAT Alaska
*** INFORMATION TABLE: CIFO
MNEM CHAN DIMT CNAM
ODEP
GRAM GRAM GRAM 0.0
RPCL RPCL RPCLM 0.0
RPSL RPSL RPCSLM 0.0
RPCH RPCH RPCHM 0.0
RPSH RPSH RPCSHM 0.0
RS60 RS60 RES60 0.0
ROPS ROPS ROPS 0.0
RPTH RPTH RPTHM 0.0
TCDM TCDM TCDM 0 . 0
* FORMAT RECORD (TYPE# 64)
Data record type is: 0
Datum Frame Size is: 40 bytes
Logging direction is down (value= 255)
Optical Log Depth Scale Units: Feet
Frame spacing: 0.250000
Frame spacing units: IF ]
Number of frames per record is: 25
One depth per frame (Value= 0)
Datum Specification Block Sub-type is:
FRAME SPACE = 0.250 * F
ONE DEPTH PER FRAME
Tape depth ID: F
9 Curves:
Name Tool Code Samples Units
1 GRAM MWD 68 1 GAPI
Size Length
2 RPCL MWD 68 1 O~
3 RPSL MWD 68 1 OH~M
4 RPCH MWD 68 1 OH/~4
5 RPSH MWD 68 1 OHMM
6 RS60 TEQ 68 1 OHMM
7 ROPS MWD 68 1 FPHR
8 RPTH MWD 68 1 MINS
9 TCDM MWD 68 1 DEGF
Total Data Records: 206
36
Tape File Start Depth = 4163.000000
Tape File End Depth = 5445.000000
Tape File Level Spacing = 0.250000
Tape File Depth Units = feet
**** FILE TRAILER ****
Tape Subfile: 4
Minimum record length:
Maximum record length:
294 records...
8 bytes
4124 bytes
**** TAPE TRAILER ****
LDWG
02/12/05
01
**** REEL TRAILER ****
LDWG
02/12/05
AWS
O1
Tape Subfile: 5
Minimum record length:
Maximum record length:
2 records...
132 bytes
132 bytes
