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HomeMy WebLinkAbout201-077 TT RR AA NN SS MM II TT TT AA LL
FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl
ConocoPhillips Alaska, Inc. AOGCC
P.O. Box 100360 330 W. 7
th Ave., Suite 100
Anchorage AK 99510-0360 Anchorage, Alaska 99501
RE: Schlumberger Wireline Backlog – Kuparuk River Unit
DATE: 12/19/2023
Transmitted:
North Slope, Kuparuk River Unit
Via hard drive data drop
Kuparuk
1A-09 50-029-20669-00
181152_1A-09_IPROF_27May2022
1A-15 50-029-20711-00
182017_1A-15_iProf_02Jun2022
1A-22 50-029-22127-00
191003_1A-22_RBP-LSL_22June2022
191003_1A-22_SBHPS-RBP_09June2022
1B-101 50-029-23173-00
203133_1B-101_MechCut_24Jun2023
1B-14 50-029-22452-00
194030_1B-14_CHC_15Mar2022
194030_1B-14_RCT Cutter_24Feb2022
194030_1B-14_UPCT Cutter_20Jun2022
194030_1B-14_Whipstock_13Apr2022
19430_1B-14_CHC_21Mar2022
1C-09 50-029-20859-00
182185_1C-09_IPROF_15Jan2023
1C-133 50-029-23013-00
201077_1C-133_RBP_07Apr2022
1C-152 50-029-23548-00
215114_1C-152_IPROF_20Mar2023
1C-15L1 50-029-22932-60
203032_1C-15L1_CHC_04Feb2022
1D-01 50-029-20393-00
179059_1D-01_PPROF_25Jun2023
1of 12
Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com
Receipt: Date:
Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512
T38308
T38309
T38310
T38312
T38311
T38274
T38276
T38314
T38315
T38316
2/29/2024
1C-133 50-029-23013-00
201077_1C-133_RBP_07Apr2022
Kayla
Junke
Digitally signed
by Kayla Junke
Date: 2024.02.29
11:11:35 -09'00'
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-133 (PTD 201-077) Report of suspect IA pressure decrease resuming
Date:Tuesday, October 24, 2023 8:14:31 AM
Attachments:AnnComm Surveillance TIO for 1C-133.pdf
From: Byrne, Jan <Jan.Byrne@conocophillips.com>
Sent: Monday, October 23, 2023 12:39 PM
To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>
Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>
Subject: KRU 1C-133 (PTD 201-077) Report of suspect IA pressure decrease resuming
Chris,
KRU 1C-133 (PTD 201-077) IA pressure has resumed the previously exhibited slow IA pressure fall
off. DHD charged the IA on 10/8/23, but the IA pressure has continued to decrease. The immediate
plan is to shut in and freeze protect the well. The proper paperwork for continued injection or
corrective action will be submitted once a path forward has been determined. A 90-day TIO trend
and wellbore schematic are attached.
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-133 90-Day Bleed History
WELL DATE STR-PRES END-PRES DIF-PRES CASING
1C-133 2023-10-08 500 200 -300 IA
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag: RKB (149' Below Top Perf, & 132' Above Bottom Perf) 4,198.0 1C-133 10/23/2021 zembaej
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Pull 2.72" P2P RBP 1C-133 5/4/2023 rogerba
Notes: General & Safety
Annotation End Date Last Mod By
NOTE: Weld Slv on PC from 2" below starter to 12' 6" w/ 6" 5L-X65 .432 wall pipe, OAL=12' 4.5" 4/15/2012 ninam
NOTE: View Schematic w/ Alaska Schematic9.0 8/12/2010 ninam
Casing Strings
Csg Des OD (in) ID (in) Top (ftKB)
Set Depth
(ftKB)
Set Depth
(TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread
CONDUCTOR 16 15.06 42.0 161.0 161.0 62.58 H-40 WELDED
PRODUCTION
5.5x3.5@3952'
5 1/2 4.95 40.8 4,600.1 4,316.9 15.50 L-80 BTC-MOD
Tubing Strings: string max indicates LONGEST segment of string
Top (ftKB)
38.3
Set Depth …
3,952.0
Set Depth …
3,669.5
String Ma…
3 1/2
Tubing Description
TUBING
Wt (lb/ft)
9.30
Grade
L-80
Top Connection
EUE8RDMOD
ID (in)
2.99
Completion Details: excludes tubing, pup, space out, thread, RKB...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal
ID (in)
38.3 38.3 0.00 HANGER 8.000 VETCO GRAY HANGER 3.500
3,866.1 3,584.0 6.66 GAS LIFT 4.725 CAMCO KBG-2-9 2.900
3,910.1 3,627.7 5.55 NIPPLE 3.780 CAMCO DS NIPPLE w/ 2.812 NO
GO PROFILE
2.812
3,948.2 3,665.7 4.59 NO GO SUB 4.500 BAKER NO GO SUB 3.000
3,949.0 3,666.5 4.57 SEAL ASSY 4.500 BAKER SEAL ASSEMBLY 3.000
Mandrel Inserts : excludes pulled inserts
Top (ftKB)
Top (TVD)
(ftKB)
Top
Incl (°)
St
ati
on
No
/S Serv
Valve
Type
Latch
Type
OD
(in)
TRO Run
(psi) Run Date Com Make Model
Port
Size (in)
3,866.1 3,584.0 6.66 1 GAS LIFT DMY INT 1 0.0 6/7/2001 0.000
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
4,050.0 4,080.0 3,767.3 3,797.2 WS D, 1C-133 6/23/2001 4.0 IPERF 2.5" HSD DP, 60 deg ph, 3IJ
UJ HMX
4,110.0 4,140.0 3,827.2 3,857.2 WS B, 1C-133 6/23/2001 4.0 IPERF 2.5" HSD DP, 60 deg ph, 3IJ
UJ HMX
4,154.0 4,176.0 3,871.2 3,893.1 WS A4, 1C-133 6/23/2001 4.0 IPERF 2.5" HSD DP, 60 deg ph, 3IJ
UJ HMX
4,196.0 4,206.0 3,913.1 3,923.1 WS A3, 1C-133 6/23/2001 4.0 IPERF 2.5" HSD DP, 60 deg ph, 3IJ
UJ HMX
4,212.0 4,226.0 3,929.1 3,943.0 WS A3, 1C-133 6/22/2001 4.0 IPERF 2.5" HSD DP, 60 deg ph
4,230.0 4,242.0 3,947.0 3,959.0 WS A3, 1C-133 6/22/2001 4.0 IPERF 2.5" HSD DP, 60 deg ph
4,260.0 4,330.0 3,976.9 4,046.9 WS A2, 1C-133 6/22/2001 4.0 IPERF 2.5" HSD DP, 60 deg ph
1C-133, 5/5/2023 2:01:38 PM
Vertical schematic (actual)
PRODUCTION 5.5x3.5@3952';
40.8-4,600.1
IPERF; 4,260.0-4,330.0
IPERF; 4,230.0-4,242.0
IPERF; 4,212.0-4,226.0
IPERF; 4,196.0-4,206.0
IPERF; 4,154.0-4,176.0
IPERF; 4,110.0-4,140.0
IPERF; 4,050.0-4,080.0
GAS LIFT; 3,866.1
CONDUCTOR; 42.0-161.0
KUP INJ
KB-Grd (ft)
46.59
RR Date
6/3/2001
Other Elev…
1C-133
...
TD
Act Btm (ftKB)
4,615.0
Well Attributes
Field Name
WEST SAK
Wellbore API/UWI
500292301300
Wellbore Status
INJ
Max Angle & MD
Incl (°)
36.43
MD (ftKB)
2,149.02
WELLNAME WELLBORE1C-133
Annotation
Last WO:
End DateH2S (ppm) DateComment
SSSV: NONE
From:Wallace, Chris D (OGC)
To:AOGCC Records (CED sponsored)
Subject:FW: [EXTERNAL]FW: KRU 1C-133 (PTD 201-077) Intent to BOI
Date:Tuesday, August 8, 2023 9:05:17 AM
Attachments:image001.png
From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com>
Sent: Thursday, July 27, 2023 12:40 PM
To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>
Subject: RE: [EXTERNAL]FW: KRU 1C-133 (PTD 201-077) Intent to BOI
Yes, I’ll look into it and get back to you. I’m not familiar with the history of this one myself so it might take a bit to run down the particulars.
Thanks,
Travis
From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>
Sent: Wednesday, July 26, 2023 4:19 PM
To: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com>
Subject: [EXTERNAL]FW: KRU 1C-133 (PTD 201-077) Intent to BOI
CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender
and know the content is safe.
Jan is out – if you could look at this well in his absence.
Thanks
Chris
From: Wallace, Chris D (OGC)
Sent: Wednesday, July 26, 2023 4:14 PM
To: Byrne, Jan <Jan.Byrne@conocophillips.com>
Subject: FW: KRU 1C-133 (PTD 201-077) Intent to BOI
Jan,
We have the MIT 6/6/2023 but that appears to be a long way into the restart. Was there an earlier MIT completed that AOGCC doesn’t
have, or is there a TIO plot showing the restart was start/stop and not able to stabilize, or did CPAI wait/delay the test for another reason?
Production casing repair was completed 3/16/2023 according to the 10-404 (Sundry 322-216). MITIA was supposed to be performed once
online and stabilized – see below. RBDMS shows production in May and June (commencing 5/7?):
Thanks and Regards,
Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907)
276-7542 (fax), chris.wallace@alaska.gov
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas
Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential
and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are
an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the
mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov.
From: Byrne, Jan <Jan.Byrne@conocophillips.com>
Sent: Thursday, May 4, 2023 10:53 AM
To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>
Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>
Subject: KRU 1C-133 (PTD 201-077) Intent to BOI
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.
Chris,
KRU 1C-133 (PTD 201-077) was previously reported for slow IA pressure fall off and the well recently completed a production casing repair
attempt (sundry 322-216). During the repair attempt ~22’ of conductor was removed and cement was removed from the exterior of the PC
to facilitate diagnostics. All pressure manipulations during diagnostics were unable to activate a leak. All welds on the existing PC sleeve
were UT inspected and found to have no damage. Being unable to activate a leak and with all inspections showing no damage, the
conductor was reinstalled after passing an MITIA to 3000 psi. I’ve attached a copy of the 10-404 which has a more detailed description of
the work performed.
The plan is to bring the well back on water injection with a 90 day monitor period to observe whether the previously noted IA pressure fall
off will activate. A SW MITIA will also be performed once the well is online and stabilized.
Please let me know if you disagree or have any questions with this plan.
Regards,
Jan Byrne
Well Integrity Specialist
ConocoPhillips Alaska, Inc.
Office phone: (907) 265-6471
Cell phone: (808) 345-6886
From:Wallace, Chris D (OGC)
To:AOGCC Records (CED sponsored)
Subject:FW: [EXTERNAL]FW: KRU 1C-133 (PTD 201-077) Intent to BOI
Date:Thursday, August 3, 2023 12:43:40 PM
Attachments:image001.png
image002.png
image003.png
AnnComm Surveillance TIO for 1C-133.pdfMIT KRU 1C-133 diagnostic MITIA 3-07-23.xlsx
From: Byrne, Jan <Jan.Byrne@conocophillips.com>
Sent: Thursday, August 3, 2023 9:21 AM
To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>
Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>
Subject: RE: [EXTERNAL]FW: KRU 1C-133 (PTD 201-077) Intent to BOI
Hey Chris,
Sorry about the delayed response I was out on vacation. It took a little digging on my part to recall the full story here, but it does look to be copasetic. Post the PC repair attempt
a passing MITIA to 3000 psi was performed on 3/7/23 (10-426 attached). Looking at IP-21 the well was online for a total of 28 days prior to the SW MITIA on 6/6/23. There
were a few contributing factors mainly the initial thermal up and pressure adjustments, then there was some surface subsidence from the previous excavation and spring thaw/
water issues and finally there was offline time that pushed the SW MITIA test date out.
IP-21 shows the well came online on May 3rdfor a few hours, but that is not true there was a plug in hole and the PE had mistakenly attempted to put the well on injection. The
RBP was pulled May 4th and the well was BOI after the RBP was pulled.
Online May 4th
Offline May 22nd through May 27th
Online May 27th
Offline for short periods June 3rd and 4th for ~4.5 hours for pigging
So, in conclusion we were still under the “30 day rule of thumb” and there were a number of contributing factors that pushed the test date out. Additionally, the 90 day monitor
is ending tomorrow so I’d like to close it out with this email. Reviewing the TIO trend there is some decline to the IA pressure, but it correlates with the decline in injection rate
and has not fallen off to zero psi as was previously observed. CPAI intents to return the well to ‘normal’ at this time. As always, the well will continue to be monitored per normal
well operating guidelines and if any suspect annular communication issues are observed the well will be reported at that time. Please give me a call if you have questions over
any of this.
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
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) <chris.wallace@alaska.gov>
Sent: Wednesday, July 26, 2023 4:14 PM
To: Byrne, Jan <Jan.Byrne@conocophillips.com>
Subject: [EXTERNAL]FW: KRU 1C-133 (PTD 201-077) Intent to BOI
CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe.
Jan,
We have the MIT 6/6/2023 but that appears to be a long way into the restart. Was there an earlier MIT completed that AOGCC doesn’t have, or is there a TIO plot showing the
restart was start/stop and not able to stabilize, or did CPAI wait/delay the test for another reason?
Production casing repair was completed 3/16/2023 according to the 10-404 (Sundry 322-216). MITIA was supposed to be performed once online and stabilized – see below.
RBDMS shows production in May and June (commencing 5/7?):
Thanks and Regards,
Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of
Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such
information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC
is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov.
From: Byrne, Jan <Jan.Byrne@conocophillips.com>
Sent: Thursday, May 4, 2023 10:53 AM
To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>
Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>
Subject: KRU 1C-133 (PTD 201-077) Intent to BOI
Chris,
KRU 1C-133 (PTD 201-077) was previously reported for slow IA pressure fall off and the well recently completed a production casing repair attempt (sundry 322-216). During the
repair attempt ~22’ of conductor was removed and cement was removed from the exterior of the PC to facilitate diagnostics. All pressure manipulations during diagnostics were
unable to activate a leak. All welds on the existing PC sleeve were UT inspected and found to have no damage. Being unable to activate a leak and with all inspections showing
no damage, the conductor was reinstalled after passing an MITIA to 3000 psi. I’ve attached a copy of the 10-404 which has a more detailed description of the work performed.
The plan is to bring the well back on water injection with a 90 day monitor period to observe whether the previously noted IA pressure fall off will activate. A SW MITIA will also
be performed once the well is online and stabilized.
Please let me know if you disagree or have any questions with this plan.
Regards,
Jan Byrne
Well Integrity Specialist
ConocoPhillips Alaska, Inc.
Office phone: (907) 265-6471
Cell phone: (808) 345-6886
1C-133 90-Day Bleed History
WELL DATE STR-PRES END-PRES DIF-PRES CASING
1C-133 2023-05-16 3 400 397 IA
1C-133 2023-06-10 353 502 149 IA
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag: RKB (149' Below Top Perf, & 132' Above Bottom Perf) 4,198.0 1C-133 10/23/2021 zembaej
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Pull 2.72" P2P RBP 1C-133 5/4/2023 rogerba
Notes: General & Safety
Annotation End Date Last Mod By
NOTE: Weld Slv on PC from 2" below starter to 12' 6" w/ 6" 5L-X65 .432 wall pipe, OAL=12' 4.5" 4/15/2012 ninam
NOTE: View Schematic w/ Alaska Schematic9.0 8/12/2010 ninam
Casing Strings
Csg Des OD (in) ID (in) Top (ftKB)
Set Depth
(ftKB)
Set Depth
(TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread
CONDUCTOR 16 15.06 42.0 161.0 161.0 62.58 H-40 WELDED
PRODUCTION
5.5x3.5@3952'
5 1/2 4.95 40.8 4,600.1 4,316.9 15.50 L-80 BTC-MOD
Tubing Strings: string max indicates LONGEST segment of string
Top (ftKB)
38.3
Set Depth …
3,952.0
Set Depth …
3,669.5
String Ma…
3 1/2
Tubing Description
TUBING
Wt (lb/ft)
9.30
Grade
L-80
Top Connection
EUE8RDMOD
ID (in)
2.99
Completion Details: excludes tubing, pup, space out, thread, RKB...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal
ID (in)
38.3 38.3 0.00 HANGER 8.000 VETCO GRAY HANGER 3.500
3,866.1 3,584.0 6.66 GAS LIFT 4.725 CAMCO KBG-2-9 2.900
3,910.1 3,627.7 5.55 NIPPLE 3.780 CAMCO DS NIPPLE w/ 2.812 NO
GO PROFILE
2.812
3,948.2 3,665.7 4.59 NO GO SUB 4.500 BAKER NO GO SUB 3.000
3,949.0 3,666.5 4.57 SEAL ASSY 4.500 BAKER SEAL ASSEMBLY 3.000
Mandrel Inserts : excludes pulled inserts
Top (ftKB)
Top (TVD)
(ftKB)
Top
Incl (°)
St
ati
on
No
/S Serv
Valve
Type
Latch
Type
OD
(in)
TRO Run
(psi) Run Date Com Make Model
Port
Size (in)
3,866.1 3,584.0 6.66 1 GAS LIFT DMY INT 1 0.0 6/7/2001 0.000
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
4,050.0 4,080.0 3,767.3 3,797.2 WS D, 1C-133 6/23/2001 4.0 IPERF 2.5" HSD DP, 60 deg ph, 3IJ
UJ HMX
4,110.0 4,140.0 3,827.2 3,857.2 WS B, 1C-133 6/23/2001 4.0 IPERF 2.5" HSD DP, 60 deg ph, 3IJ
UJ HMX
4,154.0 4,176.0 3,871.2 3,893.1 WS A4, 1C-133 6/23/2001 4.0 IPERF 2.5" HSD DP, 60 deg ph, 3IJ
UJ HMX
4,196.0 4,206.0 3,913.1 3,923.1 WS A3, 1C-133 6/23/2001 4.0 IPERF 2.5" HSD DP, 60 deg ph, 3IJ
UJ HMX
4,212.0 4,226.0 3,929.1 3,943.0 WS A3, 1C-133 6/22/2001 4.0 IPERF 2.5" HSD DP, 60 deg ph
4,230.0 4,242.0 3,947.0 3,959.0 WS A3, 1C-133 6/22/2001 4.0 IPERF 2.5" HSD DP, 60 deg ph
4,260.0 4,330.0 3,976.9 4,046.9 WS A2, 1C-133 6/22/2001 4.0 IPERF 2.5" HSD DP, 60 deg ph
1C-133, 5/5/2023 2:01:38 PM
Vertical schematic (actual)
PRODUCTION 5.5x3.5@3952';
40.8-4,600.1
IPERF; 4,260.0-4,330.0
IPERF; 4,230.0-4,242.0
IPERF; 4,212.0-4,226.0
IPERF; 4,196.0-4,206.0
IPERF; 4,154.0-4,176.0
IPERF; 4,110.0-4,140.0
IPERF; 4,050.0-4,080.0
GAS LIFT; 3,866.1
CONDUCTOR; 42.0-161.0
KUP INJ
KB-Grd (ft)
46.59
RR Date
6/3/2001
Other Elev…
1C-133
...
TD
Act Btm (ftKB)
4,615.0
Well Attributes
Field Name
WEST SAK
Wellbore API/UWI
500292301300
Wellbore Status
INJ
Max Angle & MD
Incl (°)
36.43
MD (ftKB)
2,149.02
WELLNAME WELLBORE1C-133
Annotation
Last WO:
End DateH2S (ppm) DateComment
SSSV: NONE
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED
REPORT OF SUNDRY WELL OPERATIONS I By Kayla Junke at 12:53pm, Mar 17,2023
1. Operations Susp Well Insp❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing 11 Operations shutdown ❑
Performed: Install Whipstock❑ Perforate ❑ Other Stimulate ❑ Alter Casing 21 Change Approved Program ❑
Mod Artificial Lift❑ Perforate New Pool ❑ Repair Well Q Coiled Tubing Ops ❑ Other: PC Repair 0
2. Operator Name
4. Well Class Before Work:
5. Permit to Drill Number:
ConocoPhillips Alaska, Inc.
Development ❑ Exploratory ❑
Stratigraphic ❑ Service Q
50-029-23013-00-00 201-077 -WCB
3. Address:
6. API Number:
P.O. Box 100360, Anchorage, AK 99510
201-077 50-029-23013-00-00 -WCB
7. Property Designation (Lease Number):
8. Well Name and Number:
ADL0025649
KUPARUK RIV U WSAK 1C-133
9. Logs (List logs and submit electronic data per 20AAC25.071):
10. Field/Pool(s):
N/A
Kupamk River Field / West Salk Oil Pool
11. Present Well Condition Summary:
Total Depth measured 4,615' feet Plugs measured 3,982' feet
true vertical 4,332' feet Junk measured N/A feet
Effective Depth measured 4,332' feet Packer measured 3,951' feet
true vertical 4,217' feet true vertical 3,668' feet
Casing
Length
Size
MD
TVD
Burst
Collapse
Conductor
134'
16"
181'
181,
Production
4,559'
51/2"
3,952'
3,669'
Liner
649'
31/2"
4,600'
4,319'
PC Sleeve
12' 4 1/2"
6"
12'
12'
Perforation depth Measured depth 4,050'- 4,330' feet
True Vertical depth 3,767'-4,047' feet
Tubing (size, grade, measured and true vertical depth) 3 1/2" L-80 3,952' MD 3,670' TDV
Packers and SSSV (type, measured and true vertical depth) SSSV: None
Packer: SBE-Baker 12' SBE 3,951' --MD 3,668' TDV
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
N/A
Treatment descriptions including volumes used and final pressure:
N/A
13a. Representative Daily Average Production or Injection Data
Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure
Prior to well operation:
Subsequent to operation:
13b. Pools active after work:
14. Attachments (required per 20 AAC 25.070. 25.071, & 25.283)
15. Well Class after work:
Daily Report of Well Operations
Exploratory ❑ Development ❑ Service Q Stratigraphic ❑
Copies of Logs and Surveys Run ❑
f6. Well Status after work: Oil LJ Gas LJ WDSPL LJ
Electronic Fracture Stimulation Data ❑
GSTOR ❑ WINJ 0 WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑
17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt:
UN'. 6llti,,r-[rercoPM1illipe CN=B,'emen fi,m,. E=N 92] 322-216
Brennen Div°.,i"N"
�tow[a0hillip5'.v'mn
Authorized Name and n=a�,:r.m uKewno<orwsaocun,=m
rkM
Digital Signature with Date: Oe itMFM3 0J"29-08., Contact Name: Brennen Green & Roger Mouser
Pout PDFEtliOtt Vasim:130.1
Contact Email: N1927ra)con0c0ohillioS.c0m
Authorized Title: Well Integrity Field Supervisor Contact Phone: 907-659-7506
Sr Pet Eng: I ISr Pet Geo: I I Sr Res Eng: DSR-3/20/23
RBDMS JSB 032123
Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov
ConocoPhillips
Alaska
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
March 16, 2023
Commissioner Jessie Chmielowski
Alaska Oil and Gas Conservation Commission
333 West 7 h Avenue, Suite 100
Anchorage, AK 99501
Commissioner Chmielowski,
Please find the enclosed 10-404 from ConocoPhillips Alaska, Inc. for the Production Casing
repair attempt on KRU 1C-133 (PTD 201-077).
Feel free to contact me or my alternate, Roger Mouser, at 659-7506 if you have any questions.
Digitally signed by Brennen Green
DN: C=US, O=ConocoPhillips, CN=Brennen Green, E_
n 1927@conocophillips. com
Brennen Green Reason: I am the author of this document
Sincerely, Location:
Date: 2023.03.16 07:22:49-08'00'
Brennen Green Foxit PDF Editor Version: 12.0.1
Well Integrity Field Supervisor
N 1927@conocophillips.com
ConocoPhillips Alaska, Inc.
Date Event Summary
Executive
Summary
1C-133 PC Repair: Did not Identify any leaks in the PC after removing -21' 1"of the 16" Conductor,
PT the IA with diesel and N2 to identify leaks in the PC. No leaks were observed. Verified previous
sleeve welds had irate nt . Replaced Me Conductor.
O"7122
SET RBP AT 3962.0FT. MITxT to 26M PSI WI DRAWDOWN TEST JOB COMPLETE
04/10122
(PC REPAIR) PCLD (COMPLETE) T DDT TOO PSI (PASSED) IA DDT TO PSI (PASSED) IA FL
0' 3"
01/14/23
(AC EVAL) T 6 IA DDT (COMPLETE)
01126123
PC REPAIR PREP MONOBORE WELL FOR EXCAVATION,
01/27123
(PC REPAIR) IN PROGRESS- EXCAVATED AROUND WELLHEAD TO 11', ENCOUNTERED
WATER. BEGAN WORK ON BENCH TO ALLOW GROUND TIME TO FREEZE. DISCUSSION
WITH WELL INTEGRITY SPECIALIST FOR PLAN FORWARD
011=23
(PC REPAIR) IN PROGRESS- EVACUATED WATER FROM EXCAVATION. TOP OF ICE 11'
BOTTOM OF EXCAVATION 13'. WATER CONTINUED TO INFLOW. REQUESTED 1CA 35 TO BE
SI AND FP, TO ALLOW SOILANATER TO FREEZE. JOB SUSPENDED FOR THE DAY. LET
WATER IN EXCAVATION FREEZE FOR THE NEXT 6 DAYS
02I03123
(PC REPAIR) EXCAVATED AROUND THE WELL TO 13' -14' DEEP AND EXCAVATED THE
BENCH TO-2.5'DEEP CONTINUED TO EXCAVATE AROUND THE WELLHEAD T022'AND
THE SLOPING THE EGRESS FOR THE NEXT 10 DAYS
02IM123
PC REPAIR RESTACK AND SET SHORING BOX IN THE EXCAVATION
02121123
(PC REPAIR) IN PROGRESS. DIG EGRESS, SET STAIRS. SET UP VAC HOSE FOR WATER
REMOVAL.
0V=23
(PC REPAIR) IN PROGRESS- DEWATERED SHORE -BOX AREA, SCAFFOLD CREW
INSTALLED SCAFFOLD. ARRANGED FOR NIGHT SHIFT TO MONITOR WATER PUMP
THROUGH -OUT THE NIGHT.
02123123
(PC REPAIR) IN PROGRESS. CHANGE -OUT WATER PUMP, DEWATER EXCAVATION, HOOCH
SCAFFOLD. INSTALL PURGE JEWELRY, IA FL 17' 6".
RETURN IN AM TO CLEAN UP GRAVEL ON SCAFFOLDING AND CONDUCTOR THAT
REMAINED AFTER EXCAVATION PROCESS.
0VM23
(PC REPAIR) IN PROGRESS. DEWATER SHORE BOX, CLEAN UP GRAVEL ON SCAFFOLDING
AND CONDUCTOR THAT REMAINED AFTER EXCAVATION PROCESS
02125123
(PC REPAIR) IN PROGRESS- WELDERS CUT AND REMOVED 20' OF 16" 0.375 WALL
CONDUCTOR. BEGAN CEMENT REMOVAL FROM PC.
02128I23
(PC REPAIR) IN PROGRESS, BUFFWRE WHEEL 20' OF PRODUCTION CASING FOR LEAK
DETECT.
02127123
(PC REPAIR) IN PROGRESS- LEAK DETECT INCONCLUSIVE @ 1000 PSI, REPEAT LEAK
DETECT 0 400 PSI AFTER DISCUSSION WITH WELL INTEGRITY SPECIALIST.
02126123
(PC REPAIR) IN PROGRESS- MISTRAS MT ALL WELDS OF PREVIOUS SLEEVE WELD. NO
INDICATORS OF LEAKS AT THE WELDS
CHIPPED OUT CEMENT INSIDE OF CONDUCTOR TO 21' 9' BELOW THE STARTER HEAD.
CONTINUE TO MONITOR FOR LEAK PATH.
03101123
(PC REPAIR) IN PROGRESS. CUT ADDITIONAL 13" OFF PF 16" CONDUCTOR. CLEANED OUT
CEMENT TO 23' BELOW STARTER HEAD.PT TO 1962 PSI WITH N2. IA FLUID LEVEL
DEPRESSED TO -49. BLED IA TO 0 PSI DROPPED STRING LINE DOWN IA TO OBTAIN IA FL
OF 14'
03m2123
(PC REPAIR) PCLD (IN PROGRESS) -DID NOT OBSERVE ANY LEAKING FOR THE DURATION
OF THE JOB•
03M3123
(PC REPAIR) PCLD (IN PROGRESS FOR MONITOR IA @-600 PSI) WRAP THE CONDUCTOR
AND PC (COMPLETE)'DID NOT NOTICE ANY LEAKING FOR THE DURATION OF THE JOB-
03AW23
(PC REPAIR) PCLD (IN PROGRESS FOR MONITOR) T POT (PASS) GRAYLOC SEAL (PASS)
DID NOT NOTICE ANY LEAKING FOR THE DURATION OF THE JOB'
03/05123
(PC REPAIR) PCLD (IN PROGRESS)'DID NOT NOTICE ANY LEAKING FOR THE DURATION OF
THEJOB'
03M7123
(PC REPAIR) MIT -IA (PASS T03000 PSI)IA DDT (PASS) PREP FOR CONDUCTOR (COMPLETE)
'DID NOT NOTICE ANY LEAKS FOR THE DURATION OF THE JOB'
03/0M23
STATE INSPECTOR KAM STJOHN WAIVED WITNESS OF THE PC
03111123
PC REPAIR DENBO WRAPPED THE PC COMPLETE
03112123
(PC REPAIR) WELD THE CONDUCTOR (21' 2" LONG X 16" DIAMETER X 0.375 WALL 62.58#)
COMPLETE DEMO SCAFFOLD IN PROGRESS
03113123
PC REPAIR RIG DOWN SCAFFOLDING COMPLETE
O31IW23
PC REPAIR REMOVE SHORING BOX AND STAIRS COMPLETE
R&P READY FOR BACKFILL OPERATIONS
W
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is provided to the AOGCC with permission to copy for'
its own use. Copying for any other purpose or by
other party is prohibited without the express consent
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Copyright 2023. All rights reserved. This
' ihotograph is provided to the AOGCC withl
lermission to copy for its own use. Copying for
ny other purpose or by other party is
irohibited without the express consent of
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or by other party is prohibited without
the express consent of ConocoPhillips
Alaska,lnc."
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:opyright 2023. All rights reserved. This photograph
provided to the AOGCC with permission to copy for ;
own use. Copying for any other purpose or by
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ConocoPhillips Alaska, Inc."��
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"Copyright 2023. All rights reserved. This photograph is provided
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any other purpose or by other party is prohibited without the
express consent of ConocoPhillips Alaska, Inc."
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KUP INJ WELLNAME 1C-133 WELLBORE 1C-133
C011000 1IllIp$
Well Attributes Max Angle&MD
TO
Alaska. Inc.
FIeN Name WNIbore APWWI Welill-litalue Id(°)
WET AK 2 2 1 IN 6.43
Mn(nKRI
2,149.02
MBtm (nKR)
4,615.0
mmniaps
Caromed H2SIppm) Due
AnmtNicn
End pole
KBGN pa RR
pate
Other Ekv..
SSSV: NONE
Last WO:
46.59 61312001
1G33, MY102221fi2➢PMI
Last Tag
VxM1A ecl-un piwa0
AnnWtlon
Nepal glagg
End Date
Wellhore
Ile M-1 Ry
Lasl Tag: R1B(149Bel ow Top Perf, 8132' Above
4,198.0
IOI2 UI I
lGIJJ
zembaej
BaRom Perf)
I
Last Rev Reason
HANGER; 3l.3
gnrwtdion
Ode
WNlborc
Last Mctl By
Rev Reas0n: Set 2J2" P2P REP
.1
4l]I2022
1G133
Iconne
Casing Strings
Caning Deviation op
pn) IDpnl
Top IRKBI Set OeOhlnKBISND,IhITVDI...WLLen
Ob_0mde
TUP connMion
CONDUCTOR 16
15.O6
42.0 151.0 161.0
62.58 H40
WELDED
Cuing Descnp0an Op
tin) IDlin)
iop lRHB) sNpepin lnlcal Set
Delrtb lrVDl...
wLLen gb.. Grade
Top connMicn
PRODUCTION 5.5x3.5@3952' 5112
4.95
40.8 4,600.1 4,316.9
15.50 L-90
BIG -MOD
corvoucTOR:.za,a,.e
Tubing Strings: string max indicates LONGEST segment of string
Tubing DucNption String...ID (in) T.p3gaGI Depth lfl... Set Depth OVD... M gling Grade Tap Con-*,
Ise
TUBING 3112 2.99 383,952.0 3,669.5 9.30 L-80 EUEBRDMOD
I
Completion Details: excludes tubing, pup, space out, thread, RKB...
Top ITVDI
Nominal
0NomiOD
rTW
GAS J.. a.e.,
Top(ME)
IRKBI
Topind
P) Mm Dae
(n)
(in)
New
Mctlel
38.3
X3
0.00
HANGER
3.500
8.000
3,866.1
3,584.0
6.66
GAS LIFT
2.900
4.725
CAMCO KBGd-9
3,910.1
3,627.7
5.55
NIPPLE
2.812
3.780
3,948.2
3,665.7
4.59
NO GO SUB
3.000
4.500
NIPPLE;a910.1
3,949.0
3,666.5
4.57
SEALASSY
3.000
4.500
Other In Hole
(Wireline
retrievable plugs, valves, pumps, fah, etc.)
op
TaP ITNO)
Top Intl
(nKB) (nKR)
rI
Des
tom
Run Date
ID Iin)
sN
3,981.8 61699.1
3.66
PLUG 2.72-
P2P RED(0PP35214) wl Equalizing
U712022
0.000
Valve
(CPEG35015) and fill extension. GAL
=T.981
Max OD=2.72". MOE=3981.75,
TOP
= 3979.3'
Mandrel Inserts
: excludes
pulled inserts
SEAL A85Y; 3,8a5A
at
N Top (nKRI
Tap ITVDI
InNRI
Top
IicI I°I
Make
Mwavi
OD(in)
RwN
Valve
Type
Latch
Tali(In)
PotlSe
TRORun
Ipag
Run Date
Lom
0
3,866.1
3,584.0
6.fifi
1
GAS LIFT
DMY
INT
UA00
0.0
fil]I2001
perforations & Slots
snot
De
mp
Btm(rvDI
Iahonm
Topl50.0 nlminKBl
KIN
(3K6)
(3K9)
Unkind!01Zone
pole
)
Type
Conn
pwG; awls
4,050.0
4,080.0
3,T6].3
3,]9].2 WS
D,iC-133
612312001
4.O IPERF
2.5"HSDDP, 60 deg ph, JlJ
UJ HMX
4,110.0
4,140.0
3,827.2
3,857.2 WS
B, 10-133
6I2312001
4.0 IPERF
2.5" HSD DP, 60 deg ph, 31J
UJ HMX
4,154.0
4,176.0
3,871.2
3,893.1 WS
A4, 16133
6I23,2001
4.0 IPERF
2.5" HSD DP, 60 deg ph, 31J
UJ HMX
WERE', 4.oe0 460.0
4,196.0
4,206.0
3,913.1
3,923.1 WSA3,
1C-133
6123,2001
4.0 IPERF
2.5" HSD DP, 60 deg ph, 31J
UJ HMX
4,212.0
4,226.0
3,929.1
3,943.0 WS
A3,1G133
6IM2001
4.0 IPERF
2.5" HSD DP, 60 deg ph
4,230.0
4,2420
3,94T.0
3,859.0 WS
A3, 1G133
6=001
4.O IPERF
2.5" HSD BE, 60 deg ph
4,Zm.0 I
4,330.0 I
3,916.9
I 4,U4fi.9 WS
A2, 1G133
bR ZUU1 I
4.0 I IPERF
2.5"HSDDP, uUm9pN
WER%an0.011a60
Notes: General
& Safety
End Date
MnWalwn
411WO12
NOTE: Weill Slv on PC from 2- below starter to 12' 6" wl6" 5L-X65.432 wall pipe, OAL=12' 4.5'
W12I2010
NOTE: View Schematic wl Alaska Schematic9.0
WERE 4,IE4.0�117all�
PERF', 4,196.Da,2A.0
IPERP, 4212.o,l M0
HERE', a.ZW.O will
IPERF', 4.Za0.N=O
PRODUCTION 55,9.e®AST;
4n.a4zel.1_
Submit to:
OPERATOR:
FIELD / UNIT / PAD:
DATE:
OPERATOR REP:
AOGCC REP:
Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min.
PTD 2010770 Type Inj W Tubing 4 35 36 35 Type Test P
Packer TVD 3666 BBL Pump 0.9 IA 620 3025 2978 2969 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
Green
03/07/23
Notes:Diagnostic MITIA
Notes:
1C-133
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-133 diagnostic MITIA 3-07-23 (002)
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Wednesday, July 26, 2023
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Brian Bixby
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
ConocoPhillips Alaska, Inc.
1C-133
KUPARUK RIV U WSAK 1C-133
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 07/26/2023
1C-133
50-029-23013-00-00
201-077-0
W
SPT
3666
2010770 1500
995 997 992 990
4YRTST P
Brian Bixby
6/6/2023
No OA monobore completion.
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-133
Inspection Date:
Tubing
OA
Packer Depth
250 1810 1740 1730IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitBDB230607094300
BBL Pumped:0.4 BBL Returned:0.4
Wednesday, July 26, 2023 Page 1 of 1
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-133 (PTD 201-077) Intent to BOI
Date:Thursday, May 4, 2023 11:31:01 AM
Attachments:1C-133 PC Repair 10-404.pdf
From: Byrne, Jan <Jan.Byrne@conocophillips.com>
Sent: Thursday, May 4, 2023 10:53 AM
To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>
Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>
Subject: KRU 1C-133 (PTD 201-077) Intent to BOI
Chris,
KRU 1C-133 (PTD 201-077) was previously reported for slow IA pressure fall off and the well recently
completed a production casing repair attempt (sundry 322-216). During the repair attempt ~22’ of
conductor was removed and cement was removed from the exterior of the PC to facilitate
diagnostics. All pressure manipulations during diagnostics were unable to activate a leak. All welds
on the existing PC sleeve were UT inspected and found to have no damage. Being unable to activate
a leak and with all inspections showing no damage, the conductor was reinstalled after passing an
MITIA to 3000 psi. I’ve attached a copy of the 10-404 which has a more detailed description of the
work performed.
The plan is to bring the well back on water injection with a 90 day monitor period to observe
whether the previously noted IA pressure fall off will activate. A SW MITIA will also be performed
once the well is online and stabilized.
Please let me know if you disagree or have any questions with this plan.
Regards,
Jan Byrne
Well Integrity Specialist
ConocoPhillips Alaska, Inc.
Office phone: (907) 265-6471
Cell phone: (808) 345-6886
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
March 16, 2023
Commissioner Jessie Chmielowski
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, AK 99501
Commissioner Chmielowski,
Please find the enclosed 10-404 from ConocoPhillips Alaska, Inc. for the Production Casing
repair attempt on KRU 1C-133 (PTD 201-077).
Feel free to contact me or my alternate, Roger Mouser, at 659-7506 if you have any questions.
Sincerely,
Brennen Green
Well Integrity Field Supervisor
N1927@conocophillips.com
ConocoPhillips Alaska, Inc.
1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown
Performed:Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program
Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: PC Repair
Development Exploratory
Stratigraphic Service 6. API Number:
7. Property Designation (Lease Number):8. Well Name and Number:
9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s):
11. Present Well Condition Summary:
Total Depth measured 4,615' feet 3,982'feet
true vertical 4,332' feet N/A feet
Effective Depth measured 4,332' feet 3,951'feet
true vertical 4,217'feet 3,668'feet
Perforation depth Measured depth 4,050'- 4,330'feet
True Vertical depth 3,767'-4,047'feet
Tubing (size, grade, measured and true vertical depth)3 1/2"L-80 3,952' MD 3,670' TDV
Packers and SSSV (type, measured and true vertical depth)SSSV: None
Packer:SBE- Baker 12' SBE 3,951' MD 3,668' TDV
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure:
13a.
Prior to well operation:
Subsequent to operation:
13b. Pools active after work:
15. Well Class after work:
Daily Report of Well Operations Exploratory Development Service Stratigraphic
Copies of Logs and Surveys Run 16. Well Status after work:Oil Gas WDSPL
Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG
Sundry Number or N/A if C.O. Exempt:
Authorized Name and
Digital Signature with Date:Contact Name:
Contact Email:
Authorized Title:Contact Phone:
Liner 649'3 1/2"4,600'4,319'
measured
Burst Collapse
5 1/2"
measured
TVD
Production
PC Sleeve
4,559'
12' 4 1/2"
Casing
3,669'
6"
3,952'
12'12'
Plugs
Junk
181'Conductor 16"
Size
181'
N/A
5. Permit to Drill Number:2. Operator Name
Name:
4. Well Class Before Work:
ADL0025649
Kuparuk River Field / West Sak Oil Pool
ConocoPhillips Alaska, Inc.
3. Address:
P.O. Box 100360, Anchorage, AK 99510
KUPARUK RIV U WSAK 1C-133
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
50-029-23013-00-00
201-077
14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283)
MD
N/A
measured
true vertical
Packer
Representative Daily Average Production or Injection Data
Casing Pressure Tubing Pressure
N/A
Length
134'
322-216
Sr Pet Eng:Sr Pet Geo:Sr Res Eng:
WINJ WAG
Water-BblOil-Bbl
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Brennen Green & Roger Mouser
N1927@conocophillips.com
907-659-7506Well Integrity Field Supervisor
Gas-Mcf
Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov
Date Event Summary
Executive
Summary
1C-133 PC Repair: Did not Identify any leaks in the PC after removing ~21' 1" of the 16" Conductor.
PT the IA with diesel and N2 to identify leaks in the PC. No leaks were observed. Verified previous
sleeve welds had integrity. Replaced the Conductor.
04/07/22 SET RBP AT 3982.0FT. MITxT to 2500 PSI W/ DRAWDOWN TEST JOB COMPLETE
04/10/22 (PC REPAIR) PCLD (COMPLETE) T DDT TO 0 PSI (PASSED) IA DDT TO 0 PSI (PASSED) IA FL
@ 10' 3"
01/14/23 (AC EVAL) T & IA DDT (COMPLETE)
01/26/23 (PC REPAIR) PREP MONOBORE WELL FOR EXCAVATION.
01/27/23
(PC REPAIR) IN PROGRESS- EXCAVATED AROUND WELLHEAD TO 11', ENCOUNTERED
WATER. BEGAN WORK ON BENCH TO ALLOW GROUND TIME TO FREEZE. DISCUSSION
WITH WELL INTEGRITY SPECIALIST FOR PLAN FORWARD
01/28/23
(PC REPAIR) IN PROGRESS- EVACUATED WATER FROM EXCAVATION. TOP OF ICE 11'
BOTTOM OF EXCAVATION 13'. WATER CONTINUED TO INFLOW. REQUESTED 1C-135 TO BE
SI AND FP, TO ALLOW SOIL/WATER TO FREEZE. JOB SUSPENDED FOR THE DAY. LET
WATER IN EXCAVATION FREEZE FOR THE NEXT 6 DAYS
02/03/23
(PC REPAIR) EXCAVATED AROUND THE WELL TO 13' - 14' DEEP AND EXCAVATED THE
BENCH TO ~2.5' DEEP CONTINUED TO EXCAVATE AROUND THE WELLHEAD TO 22' AND
THE SLOPING THE EGRESS FOR THE NEXT 10 DAYS
02/20/23 (PC REPAIR) RESTACK AND SET SHORING BOX IN THE EXCAVATION
02/21/23 (PC REPAIR) IN PROGRESS. DIG EGRESS, SET STAIRS. SET UP VAC HOSE FOR WATER
REMOVAL.
02/22/23
(PC REPAIR) IN PROGRESS- DEWATERED SHORE-BOX AREA, SCAFFOLD CREW
INSTALLED SCAFFOLD. ARRANGED FOR NIGHT SHIFT TO MONITOR WATER PUMP
THROUGH-OUT THE NIGHT.
02/23/23
(PC REPAIR) IN PROGRESS. CHANGE-OUT WATER PUMP, DEWATER EXCAVATION, HOOCH
SCAFFOLD. INSTALL PURGE JEWELRY, IA FL 17' 6".
RETURN IN AM TO CLEAN UP GRAVEL ON SCAFFOLDING AND CONDUCTOR THAT
REMAINED AFTER EXCAVATION PROCESS.
02/24/23 (PC REPAIR) IN PROGRESS. DEWATER SHORE BOX, CLEAN UP GRAVEL ON SCAFFOLDING
AND CONDUCTOR THAT REMAINED AFTER EXCAVATION PROCESS
02/25/23 (PC REPAIR) IN PROGRESS- WELDERS CUT AND REMOVED 20' OF 16" 0.375 WALL
CONDUCTOR. BEGAN CEMENT REMOVAL FROM PC.
02/26/23 (PC REPAIR) IN PROGRESS, BUFF/WIRE WHEEL 20' OF PRODUCTION CASING FOR LEAK
DETECT.
02/27/23 (PC REPAIR) IN PROGRESS- LEAK DETECT INCONCLUSIVE @ 1000 PSI, REPEAT LEAK
DETECT @ 400 PSI AFTER DISCUSSION WITH WELL INTEGRITY SPECIALIST.
02/28/23
(PC REPAIR) IN PROGRESS- MISTRAS MT ALL WELDS OF PREVIOUS SLEEVE WELD- NO
INDICATORS OF LEAKS AT THE WELDS
CHIPPED OUT CEMENT INSIDE OF CONDUCTOR TO 21' 9" BELOW THE STARTER HEAD.
CONTINUE TO MONITOR FOR LEAK PATH.
03/01/23
(PC REPAIR) IN PROGRESS. CUT ADDITIONAL 13" OFF PF 16" CONDUCTOR. CLEANED OUT
CEMENT TO 23' BELOW STARTER HEAD.PT TO 1962 PSI WITH N2. IA FLUID LEVEL
DEPRESSED TO ~48'. BLED IA TO 0 PSI DROPPED STRING LINE DOWN IA TO OBTAIN IA FL
OF 14'
03/02/23 (PC REPAIR) PCLD (IN PROGRESS) *DID NOT OBSERVE ANY LEAKING FOR THE DURATION
OF THE JOB*
03/03/23 (PC REPAIR) PCLD (IN PROGRESS FOR MONITOR IA @ ~600 PSI) WRAP THE CONDUCTOR
AND PC (COMPLETE) *DID NOT NOTICE ANY LEAKING FOR THE DURATION OF THE JOB*
03/04/23 (PC REPAIR) PCLD (IN PROGRESS FOR MONITOR) T POT (PASS) GRAYLOC SEAL (PASS)
*DID NOT NOTICE ANY LEAKING FOR THE DURATION OF THE JOB*
03/05/23 (PC REPAIR) PCLD (IN PROGRESS) *DID NOT NOTICE ANY LEAKING FOR THE DURATION OF
THE JOB*
03/07/23 (PC REPAIR) MIT-IA (PASS TO 3000 PSI) IA DDT (PASS) PREP FOR CONDUCTOR (COMPLETE)
*DID NOT NOTICE ANY LEAKS FOR THE DURATION OF THE JOB*
03/08/23 STATE INSPECTOR, KAM STJOHN, WAIVED WITNESS OF THE PC
03/11/23 (PC REPAIR) DENSO WRAPPED THE PC (COMPLETE)
03/12/23 (PC REPAIR) WELD THE CONDUCTOR (21' 2" LONG X 16" DIAMETER X 0.375 WALL 62.58#)
(COMPLETE) DEMO SCAFFOLD (IN PROGRESS)
03/13/23 (PC REPAIR) RIG DOWN SCAFFOLDING (COMPLETE)
03/14/23 (PC REPAIR) REMOVE SHORING BOX AND STAIRS (COMPLETE)
R&P READY FOR BACKFILL OPERATIONS
Last Tag
Annotation Depth (ftKB) End Date Wellbore Last Mod By
Last Tag: RKB (149' Below Top Perf, & 132' Above
Bottom Perf)
4,198.0 10/23/2021 1C-133 zembaej
Last Rev Reason
Annotation End Date Wellbore Last Mod By
Rev Reason: Set 2.72" P2P RBP 4/7/2022 1C-133 jconne
Casing Strings
Casing Description
CONDUCTOR
OD (in)
16
ID (in)
15.06
Top (ftKB)
42.0
Set Depth (ftKB)
161.0
Set Depth (TVD) …
161.0
Wt/Len (lb…
62.58
Grade
H-40
Top Connection
WELDED
Casing Description
PRODUCTION 5.5x3.5@3952'
OD (in)
5 1/2
ID (in)
4.95
Top (ftKB)
40.8
Set Depth (ftKB)
4,600.1
Set Depth (TVD) …
4,316.9
Wt/Len (lb…
15.50
Grade
L-80
Top Connection
BTC-MOD
Tubing Strings: string max indicates LONGEST segment of string
Tubing Description
TUBING
String …
3 1/2
ID (in)
2.99
Top (ftKB)
38.3
Set Depth (ft…
3,952.0
Set Depth (TVD…
3,669.5
Wt (lb/ft)
9.30
Grade
L-80
Top Connection
EUE8RDMOD
Completion Details: excludes tubing, pup, space out, thread, RKB...
Top (ftKB)
Top (TVD)
(ftKB) Top Incl (°) Item Des
Nominal ID
(in)
OD
Nominal
(in)Make Model
38.3 38.3 0.00 HANGER 3.500 8.000
3,866.1 3,584.0 6.66 GAS LIFT 2.900 4.725 CAMCO KBG-2-9
3,910.1 3,627.7 5.55 NIPPLE 2.812 3.780
3,948.2 3,665.7 4.59 NO GO SUB 3.000 4.500
3,949.0 3,666.5 4.57 SEAL ASSY 3.000 4.500
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top
(ftKB)
Top
(TVD)
(ftKB)
Top Incl
(°) Des Com Run Date ID (in) SN
3,981.8 3,699.1 3.88 PLUG 2.72" P2P RBP (CPP35214) w/ Equalizing
Valve (CPEQ35015) and fill extension. OAL
= 7.98', Max OD = 2.72". MOE = 3981.75',
TOP = 3979.3'
4/7/2022 0.000
Mandrel Inserts : excludes pulled inserts
St
ati
on
N
o/Top (ftKB)
Top (TVD)
(ftKB)
Top
Incl (°) Make Model OD (in) Serv
Valve
Type
Latch
Type
Port Size
(in)
TRO Run
(psi) Run Date Com
1 3,866.1 3,584.0 6.66 1 GAS LIFT DMY INT 0.000 0.0 6/7/2001
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft
)Type Com
4,050.0 4,080.0 3,767.3 3,797.2 WS D, 1C-133 6/23/2001 4.0 IPERF 2.5" HSD DP, 60 deg ph, 3IJ
UJ HMX
4,110.0 4,140.0 3,827.2 3,857.2 WS B, 1C-133 6/23/2001 4.0 IPERF 2.5" HSD DP, 60 deg ph, 3IJ
UJ HMX
4,154.0 4,176.0 3,871.2 3,893.1 WS A4, 1C-133 6/23/2001 4.0 IPERF 2.5" HSD DP, 60 deg ph, 3IJ
UJ HMX
4,196.0 4,206.0 3,913.1 3,923.1 WS A3, 1C-133 6/23/2001 4.0 IPERF 2.5" HSD DP, 60 deg ph, 3IJ
UJ HMX
4,212.0 4,226.0 3,929.1 3,943.0 WS A3, 1C-133 6/22/2001 4.0 IPERF 2.5" HSD DP, 60 deg ph
4,230.0 4,242.0 3,947.0 3,959.0 WS A3, 1C-133 6/22/2001 4.0 IPERF 2.5" HSD DP, 60 deg ph
4,260.0 4,330.0 3,976.9 4,046.9 WS A2, 1C-133 6/22/2001 4.0 IPERF 2.5" HSD DP, 60 deg ph
Notes: General & Safety
End Date Annotation
4/15/2012 NOTE: Weld Slv on PC from 2" below starter to 12' 6" w/ 6" 5L-X65 .432 wall pipe, OAL=12' 4.5"
8/12/2010 NOTE: View Schematic w/ Alaska Schematic9.0
1C-133, 4/7/2022 2:16:20 PM
Vertical schematic (actual)
PRODUCTION 5.5x3.5@3952';
40.8-4,600.1
IPERF; 4,260.0-4,330.0
IPERF; 4,230.0-4,242.0
IPERF; 4,212.0-4,226.0
IPERF; 4,196.0-4,206.0
IPERF; 4,154.0-4,176.0
IPERF; 4,110.0-4,140.0
IPERF; 4,050.0-4,080.0
PLUG; 3,981.8
SEAL ASSY; 3,949.0
NIPPLE; 3,910.1
GAS LIFT; 3,866.1
CONDUCTOR; 42.0-161.0
HANGER; 38.3
KUP INJ
KB-Grd (ft)
46.59
RR Date
6/3/2001
Other Elev…
1C-133
...
TD
Act Btm (ftKB)
4,615.0
Well Attributes
Field Name
WEST SAK
Wellbore API/UWI
500292301300
Wellbore Status
INJ
Max Angle & MD
Incl (°)
36.43
MD (ftKB)
2,149.02
WELLNAME WELLBORE1C-133
Annotation
Last WO:
End DateH2S (ppm) DateComment
SSSV: NONE
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By Samantha Carlisle at 8:14 am, Apr 20, 2022
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JLC 5/18/2022
Jeremy Price
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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:Byrne, Jan
To:Loepp, Victoria T (OGC)
Cc:Earhart, Will C; NSK Well Integrity Field Supv
Subject:RE: [EXTERNAL]KRU 1C-133(PTD 201-077, Sundry 322-216) Production Casing Leak Repair
Date:Monday, May 16, 2022 1:56:03 PM
Attachments:1C-133 Well event history.pdf
1C-133.pdf
Victoria,
1C-133 is a single casing well with 3.5” tubing and 5.5” production casing. The well is currently
secured with an RBP at 3982’. The well has passed an MITT, MITIA, and DDT of both the tubing and
IA. The pressure loss from the IA is extremely slow. The production casing was repaired by exterior
sleeve in 2012 which led to the suspicion of a repeat failure. Diagnostics indicate that the existing
sleeve has failed or there is an additional leak very near the sleeve. The plan is to excavate down to
expose the existing production casing sleeve and then identify the exact location of the leak. At that
point the existing sleeve will be repaired or extended as needed. I have attached the well event
history with pertinent testing and diagnostics highlighted. Short summary below.
4.4.2012: The well previously had a production casing leak discovered at 5’8” down from the
OA valve which was repaired by welding a sleeve to the outside of the production casing
(sundry # 310-389).
6.12.21: The well was reported for extremely slow IA pressure fall off.
7.2.21: An MITIA passed to 3000 psi. Pressure monitoring over the next few months showed
that the IA pressure would fall off extremely slowly.
3.22.22: Suspecting that the existing production casing sleeve was leaking, windows were cut
in the conductor to facilitate leak detection.
4.10.22: A small amount of bubbling was observed in the conductor during the leak hunt
corroborating suspicions of a sleeve failure or additional shallow leak.
4.19.22: Submitted 10-403 for production casing repair.
Please let me know if you have any additional questions.
Regards,
Jan Byrne
Well Integrity Specialist
ConocoPhillips Alaska, Inc.
Office phone: (907) 659-7224
Cell phone: (808) 345-6886
From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>
Sent: Monday, May 16, 2022 9:33 AM
To: NSK Well Integrity Field Supv <N1927@conocophillips.com>
Subject: [EXTERNAL]KRU 1C-133(PTD 201-077, Sundry 322-216) Production Casing Leak Repair
CAUTION:This email originated from outside of the organization. Do not click links or open
attachments unless you recognize the sender and know the content is safe.
Roger,
Since this leak is in the production casing and there is not surface casing, please provide well history,
status of well, MIT-IA history. It looks like you plan to weld on the production casing?
Victoria
Victoria Loepp
Senior Petroleum Engineer
State of Alaska
Oil & Gas Conservation Commission
333 W. 7th Ave
Anchorage, AK 99501
Work: (907)793-1247
Victoria.Loepp@alaska.gov
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska
Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended
recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure
of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please
delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you,
contact Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.gov
Last Tag
Annotation Depth (ftKB) End Date Wellbore Last Mod By
Last Tag: RKB (149' Below Top Perf, & 132' Above
Bottom Perf)
4,198.0 10/23/2021 1C-133 zembaej
Last Rev Reason
Annotation End Date Wellbore Last Mod By
Rev Reason: Set 2.72" P2P RBP 4/7/2022 1C-133 jconne
Casing Strings
Casing Description
CONDUCTOR
OD (in)
16
ID (in)
15.06
Top (ftKB)
42.0
Set Depth (ftKB)
161.0
Set Depth (TVD) …
161.0
Wt/Len (lb…
62.58
Grade
H-40
Top Connection
WELDED
Casing Description
PRODUCTION 5.5x3.5@3952'
OD (in)
5 1/2
ID (in)
4.95
Top (ftKB)
40.8
Set Depth (ftKB)
4,600.1
Set Depth (TVD) …
4,316.9
Wt/Len (lb…
15.50
Grade
L-80
Top Connection
BTC-MOD
Tubing Strings: string max indicates LONGEST segment of string
Tubing Description
TUBING
String …
3 1/2
ID (in)
2.99
Top (ftKB)
38.3
Set Depth (ft…
3,952.0
Set Depth (TVD…
3,669.5
Wt (lb/ft)
9.30
Grade
L-80
Top Connection
EUE8RDMOD
Completion Details: excludes tubing, pup, space out, thread, RKB...
Top (ftKB)
Top (TVD)
(ftKB) Top Incl (°) Item Des
Nominal ID
(in)
OD
Nominal
(in)Make Model
38.3 38.3 0.00 HANGER 3.500 8.000
3,866.1 3,584.0 6.66 GAS LIFT 2.900 4.725 CAMCO KBG-2-9
3,910.1 3,627.7 5.55 NIPPLE 2.812 3.780
3,948.2 3,665.7 4.59 NO GO SUB 3.000 4.500
3,949.0 3,666.5 4.57 SEAL ASSY 3.000 4.500
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top
(ftKB)
Top
(TVD)
(ftKB)
Top Incl
(°) Des Com Run Date ID (in) SN
3,981.8 3,699.1 3.88 PLUG 2.72" P2P RBP (CPP35214) w/ Equalizing
Valve (CPEQ35015) and fill extension. OAL
= 7.98', Max OD = 2.72". MOE = 3981.75',
TOP = 3979.3'
4/7/2022 0.000
Mandrel Inserts : excludes pulled inserts
St
ati
on
N
o/Top (ftKB)
Top (TVD)
(ftKB)
Top
Incl (°) Make Model OD (in) Serv
Valve
Type
Latch
Type
Port Size
(in)
TRO Run
(psi) Run Date Com
1 3,866.1 3,584.0 6.66 1 GAS LIFT DMY INT 0.000 0.0 6/7/2001
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft
)Type Com
4,050.0 4,080.0 3,767.3 3,797.2 WS D, 1C-133 6/23/2001 4.0 IPERF 2.5" HSD DP, 60 deg ph, 3IJ
UJ HMX
4,110.0 4,140.0 3,827.2 3,857.2 WS B, 1C-133 6/23/2001 4.0 IPERF 2.5" HSD DP, 60 deg ph, 3IJ
UJ HMX
4,154.0 4,176.0 3,871.2 3,893.1 WS A4, 1C-133 6/23/2001 4.0 IPERF 2.5" HSD DP, 60 deg ph, 3IJ
UJ HMX
4,196.0 4,206.0 3,913.1 3,923.1 WS A3, 1C-133 6/23/2001 4.0 IPERF 2.5" HSD DP, 60 deg ph, 3IJ
UJ HMX
4,212.0 4,226.0 3,929.1 3,943.0 WS A3, 1C-133 6/22/2001 4.0 IPERF 2.5" HSD DP, 60 deg ph
4,230.0 4,242.0 3,947.0 3,959.0 WS A3, 1C-133 6/22/2001 4.0 IPERF 2.5" HSD DP, 60 deg ph
4,260.0 4,330.0 3,976.9 4,046.9 WS A2, 1C-133 6/22/2001 4.0 IPERF 2.5" HSD DP, 60 deg ph
Notes: General & Safety
End Date Annotation
4/15/2012 NOTE: Weld Slv on PC from 2" below starter to 12' 6" w/ 6" 5L-X65 .432 wall pipe, OAL=12' 4.5"
8/12/2010 NOTE: View Schematic w/ Alaska Schematic9.0
1C-133, 4/7/2022 2:16:20 PM
Vertical schematic (actual)
PRODUCTION 5.5x3.5@3952';
40.8-4,600.1
IPERF; 4,260.0-4,330.0
IPERF; 4,230.0-4,242.0
IPERF; 4,212.0-4,226.0
IPERF; 4,196.0-4,206.0
IPERF; 4,154.0-4,176.0
IPERF; 4,110.0-4,140.0
IPERF; 4,050.0-4,080.0
PLUG; 3,981.8
SEAL ASSY; 3,949.0
NIPPLE; 3,910.1
GAS LIFT; 3,866.1
CONDUCTOR; 42.0-161.0
HANGER; 38.3
KUP INJ
KB-Grd (ft)
46.59
RR Date
6/3/2001
Other Elev…
1C-133
...
TD
Act Btm (ftKB)
4,615.0
Well Attributes
Field Name
WEST SAK
Wellbore API/UWI
500292301300
Wellbore Status
INJ
Max Angle & MD
Incl (°)
36.43
MD (ftKB)
2,149.02
WELLNAME WELLBORE1C-133
Annotation
Last WO:
End DateH2S (ppm) DateComment
SSSV: NONE
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Wallace, Chris D (CED)
From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com>
Sent: Tuesday, June 29, 2021 12:43 PM
To: Wallace, Chris D (CED)
Cc: Earhart, Will C
Subject: KRU 1C-133 (PTD 20.1-077) Report of suspect IA pressure decrease
Attachments: 1C-133.pdf, 1C-133 90 day TIO trend 6.29.21 jpg
Chris,
KRU 1C-133 (PTD 201-077) IA pressure was charged on 06/12/21 and appears to be decreasing extremely slowly. The
plan is for DHD to perform an MITIA after which the IA will be left at a higher pressure for more differential and an
extended monitor period. Due to the extremely slow nature of the suspect leak the plan is to monitor for 90 days. This
will allow us to establish a pressure fall off rate and manipulate pressures further if needed. The proper paperwork for
continued injection or corrective action will be submitted once a path forward has been determined. A 90 day TIO trend
and wellbore schematic are attached.
Please let us know if you disagree or have any questions with this plan.
Regards,
Jan Byrne
Well Integrity Specialist
ConocoPhillips Alaska, Inc.
Office phone: (907) 659-7224
Cell phone: (808) 345-6886
•
MEMORANDUt
State of Alaska
Alaska Oil and Gas Conservation Commission
I f✓ DATE: Wednesday,May 16,2018
TO: Jim Re Q��
P.I.SupervisorSG SUBJECT: Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA,INC.
1C-133
FROM: Austin McLeod KUPARUK RIV U WSAK 1C-133
Petroleum Inspector
Src: Inspector
Reviewed By:
P.I.Supry
NON-CONFIDENTIAL Comm
Well Name KUPARUK RIV U WSAK 1C-133 API Well Number 50-029-23013-00-00 Inspector Name: Austin McLeod
Permit Number: 201-077-0 Inspection Date: 5/12/2018 —
Insp Num: mitSAM180513203053
Rel Insp Num:
Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min
Well ' 1C-133 - 1Type Inj W ''TVD 3666 - Tubing l 984 985 985 985 -
PTD 2010770 ' Type Test EITest psi 1500 - IA 430 1830 - 1770 - 1770 -
BBL Pumped: 0.4 BBL Returned: 0.4 - OA
Interval 4YRTST P/F P '�
Notes: MIT-IA.5.5"x3.5"-No OA
SCANNED JUN 0 1 2018
Wednesday,May 16,2018 Page 1 of 1
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ConocoPhillips
Alaska
P.O. BOX 100360
ANCHORAGE, ALASKA 99510 -0360
May 15, 2012 0 1
a
Commissioner Dan Seamount
Alaska Oil & Gas Commission
333 West 7 Avenue, Suite 100
SLUttED AU LU`i�
Anchorage, AK 99501
Commissioner Dan Seamount:
Enclosed are the spreadsheets with a list of wells from the Alpine field (CRU), and the Kuparuk
field (KRU). Each of these wells was found to have a void in the conductor. These voids were
filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular
space. As per previous agreement with the AOGCC, this letter and spreadsheets serves as
notification that the treatments took place and meets the requirements of form 10 -404, Report of
Sundry Operations.
The cement was pumped in the spring of 2012. The corrosion inhibitor /sealant was pumped in
the months of April and May 2012. The attached spreadsheet presents the well name, top of
cement depth prior to filling, and volumes used on each conductor.
Please call MJ Loveland or Martin Walters at 907 - 659 -7043, if you have any questions.
Sincerely,
Martin Walters
ConocoPhillips Well Integrity Projects Supervisor
• •
•
ConocoPhillips Alaska Inc. -
Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off
Report of Sundry Operations (10 -404)
Kuparuk Field
Date 5/15/2012 1C,1D,1E,2L,3H PAD
Corrosion
Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/
Well Name API ,# PTD # cement pumped cement date inhibitor sealant date
ft bbls ft gal
) C -133 50029230130000 2010770 16" 3.9 12" 5/8/2012 6.8 5/14/2012
C 1D-116 50029229150000 1981720 10" 1.2 10" 5/8/2012 4.3 5/15/2012
1E -123 50029232080000 2040740 5" n/a 18" n/a 5.1 4/9/2012
2L -304 50103206130000 2100110 _ 31" 0.30 20" 3/30/2012 4.3 5/14/2012
2L -306 50103206300000 2101820 8" n/a 8" n/a 3.4 5/14/2012
2L -310 50103206160000 2100280 25" 0.25 12" 3/30/2012 2.6 5/14/2012
2L -312 50103206260000 2101640 13" n/a 13" n/a 2.5 5/14/2012
2L -319 50103205520000 2071120 112" 1.00 20" 3/30/2012 6 5/14/2012
2L -320 50103206270000 2101660 36' 1.00 50" 3/30/2012 3.4 5/14/2012
31-1-17 50103200810000 1870990 19" n/a 19" n/a 3.4 4/9/2012
• •
ConocoPhillips
SIPV
Alaska
P.O. BOX 100360
ANCHORAGE, ALASKA 99510 -0360
April 14, 2012 RECEI
APR 17 20 \
Commissioner Dan Seamount A 0 600
Alaska Oil and Gas Conservation Commission f"��`'"
333 West 7 Avenue, Suite 100
Anchorage, AK 99501
Migkeii APR 3. 82012
Commissioner Seamount:
Enclosed please find the 10 -404 Report of Sundry Operations for ConocoPhillips Alaska,
Inc., well 1C -133, PTD 201 -077, Sundry 310 -389 surface casing repair.
Please call MJ Loveland or Martin Walters at 659 -7043 if you have any questions.
Sincerely,
Martin Walters
ConocoPhillips
Well Integrity Projects Supervisor
STATE OF ALASKA •
ALAS OIL AND GAS CONSERVATION COMMISSION
. REPORT OF SUNDRY WELL OPERATIONS
1. Operations Performed: Abandon r Repair well r Rug Perforations r Stimulate r Other SC repair
Alter Casing r Pull Tubing r Perforate New Fool r Waiver r Time Extension r
Change Approved Program r Operat. Shutdown r Perforate T Re -enter Suspended Well r
2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number:
ConocoPhillips Alaska, Inc. Development r Exploratory r _ - 201 -077
3. Address: 6. API Number:
Stratigraphic r Service r'
P. O. Box 100360, Anchorage, Alaska 99510 - 50-029-23013-00'' 00
7. Property Designation (Lease Number): _ 8. Well Name and Number: ,.
ADL0025649 1C-133
9. Field /Pool(s):
Kuparuk River Field / West Sak Oil Pool
10. Present Well Condition Summary:
Total Depth measured 4615 feet Plugs (measured) None
true vertical 4332 feet Junk (measured) None
Effective Depth measured 4500 feet Packer (measured) 3951
true vertical 4217 feet (true vertucal) 3668
Casing Length Size MD TVD Burst Collapse
CONDUCTOR 134 16 181 181 1640 630
PRODUCTION 4559 5.5 3952 3669 7000 4990
Liner 649 3.5 4600 4319 10159 10533
SLEEVE 12' 4.5" 6" .432 wall X65
Perforation depth: Measured depth: 4154- 4176, 4196- 4206,4212 - 4226,4230- 4242,4260 -4330 RECEIVED
True Vertical Depth: 3871 - 3893, 3913 - 3923,3929- 3943,3947- 3959,3976 -4046
APR 17 2012
Tubing (size, grade, MD, and ND) 3.5, L -80, 3952 MD, 3669 TVD AOGCC
Packers & SSSV (type, MD, and ND) Packer = BAKER 12' SBE @ 3951 MD and 3668 ND
SSSV = None
11. Stimulation or cement squeeze summary:
Intervals treated (measured): N/A
Treatment descriptions including volumes used and final pressure:
12. Representative Daily Average Production or Injection Data
Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure
Prior to well operation N/A N/A N/A N/A N/A
Subsequent to operation N/A N/A N/A N/A N/A
13. Attachments 14. Well Class after work:
Copies of Logs and Surveys run Exploratory r Development r Service F Stratigraphic r
15. Well Status after work: _ Oil r Gas r WDSPL r
Daily Report of Well Operations X
GSTOR r WIND rJ WAG r- GINJ r SUSP r SPLUG r.
16. 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:
310 -389
Contact MJ Loveland /Martin Walters
Printed Name Martin Walters Title Well Integrity Project Supervisor
Signature Phone: 907 - 659 -7043 Date: 04/14/2012
ii<eiW/7?-•i' .
R$DMS APR 17 I ir4-7 _ 17-12-
it Original Only 10-404 Revised 10/2010 . i� � L�� / /'�"" " 9 Y
• •
1C-133
DESCRIPTION OF WORK COMPLETED
SUMMARY
Date Event Summary
12/31/11 Cut two 18 X 20" windows out in wellhead conductor and remove cement/sealant. Buffed SC
and cleaned for upcoming k kivik inspection.
a spection .
03 /19 /12IRemoved 21' 7" of 16" conductor.
03/20/12 Chipped cement off of surface casing . Found areas of corrosion 6' below starter head and
looks like good pipe around 12'.
03/22/12 Cut emergency slips off SC and Buffed to inspect for curosion and to locate hole. PT'd the IA t ,/
to 300 PSI and found hole @ 5' 8" @ 5 O'clock on wellhead.
03 /28112INotified Stateman of opportunity to witness SC damage,
04 104 /121Welded 12' 4.5" X 6" 5L- X65# .432 sleeve onto SC.
04/07/12 Post SC repair MITIA. (Passed) Initial T /I= si0 /0. Pressured up IA to 3000 psi with 1 bb Is of
diesel for 30 minute test.Starting T /I =si0 /3000. —
15 min T/I= si0/3025.
30 min T /I= si0/3025.
Bled IA back to 0 psi.
Final T /I= si0 /0.
04 /08 /121Insulators installed denso wrap over SC sleeve
04/08/12 Welded 21' 11 3/4" long 16" .375 wall 62.58# pipe, conductor extension onto existing
conductor.
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• •
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Jim Regg 4 )(011 DATE: 3/28/2012
P. I. Supervisory //
l /
FROM: Matt Herrera SUBJECT: Surface Casing Inspection
Petroleum Inspector KRU 1C-133
PTD 2010770 -
Kuparuk River Unit
CPAI
March 28, 2012: I traveled to Kuparuk River Unit (KRU) 1C pad to inspect the
excavation of the surface casing in KRU 1 C -133. CPAI project lead at the -
location was Roger Winter (Wells Supervisor).
The wells group had the ground excavated to approximately 20 feet below
surface and had identified some concerns with erosion /corrosion. They had
identified a hole in the surface casing approximately 67 inches down from the -
casing hanger. They will move forward with repairs and contact AOGCC when
complete.
Summary: I observed excavated surface casing for KRU 1C-133. A section of -
the casing was compromised and will be repaired.
Attachments: 2 photos courtesy of CPAI
NM%) P ,` 4 /_ ;,'q
• 0
Surface Casing Corrosion Inspection
KRU 1C -133 (PTD 2011770)
Photos courtesy of CPAI
3/28/2012
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y . This photo is copyright by
'. , � - v + r : e.:. ConocoPhriips Alaska Inc.
;` i and cannot be released or
i. - , publishedw1
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published without ress
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ConocoPhillips Al8$ka
w
• •
6. 1 D -106 — Single casing well. MITIA failed 7/16/2010. Well last injected 6/2010. Comments
on the sheet indicate you have located the deep leak.
— Single casing well. MITIA failed 5/21/2010. Well last injected 5/2010. `— ®t
4. 1C-10 — AA 2B.036 issued 8/25/2008.
From: Maunder, Thomas E (DOA)
Sent: Monday, January 03, 2011 11:13 AM EP JAN 1 8 i
To: 'NSK Problem Well Supv'
Cc: NSK Well Integrity Proj
Subject: RE: ConocoPhillips Monthly Injector Report - Dec 2010
Martin, et al,
am conducting a review of December's Monthly report. I have just gotten started and wanted to
pass back the comments /questions I am developing.
I also am doing some editing /formatting on the spreadsheet to facilitate printing it off when
necessary. I have only edited the 1A-07, 1A-12 and 1B-02 in the attached spreadsheet. The
edits are highlighted in yellow. Can these changes be accommodated without a lot of hassle ??
Thanks in advance for looking at this.
Tom Maunder, PE
AOGCC
3. 1 B -02 — TxIA communication reported 5/6/09. Well last operated 6/09.
2. 1A-12 — AA 2B.049 issued 6/9/2010.
1. 1A -07 — It is noted that an MITIA failed on 11/13/09, however I have not been able to find that
information in our files. I have an email from July 28,2009 that reports failure of a diagnostic
MITIA, that the well will be SI, added to the monthly report and diagnostic troubleshooting will
begin as soon as feasibly possible. On December 15, 2009 it was reported that a surface casing
leak was suspected and that the well is SI and on the monthly report. According to our injection
records, the well has not operated since April, 2008.
From: NSK Problem Well Supv [mailto:n1617 @conocophillips.com]
Sent: Saturday, January 01, 2011 10:55 AM
To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA)
Cc: NSK Well Integrity Proj; NSK Problem Well Supv
Subject: ConocoPhillips Monthly Injector Report - Dec 2010
Jim/Tom /Guy,
Attached for your records is the ConocoPhillips monthly injector report for December 2010.
Please contact me at your convenience if you have questions or comments.
Martin
Martin Walters / Brent Rogers
Problem Wells Supervisor
ConocoPhillips Alaska Inc.
•
The following information is received monthly from CPAI. Reporting this information is a
requirement of the administrative approval issued that authorizes continued injection /operation of
the well where some integrity compromise is known. As of December, 2010 a total of 65 wells
are on this report. Not all wells are actively injecting.
From: NSK Problem Well Supv [mailto:n1617 @conocophillips.com]
Sent: Saturday, January 01, 2011 10:55 AM
To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA)
Cc: NSK Well Integrity Proj; NSK Problem Well Supv
Subject: ConocoPhillips Monthly Injector Report - Dec 2010
Jim/Tom /Guy,
Attached for your records is the ConocoPhillips monthly injector report for December 2010.
Please contact me at your convenience if you have questions or comments.
Martin
Martin Walters / Brent Rogers
Problem Wells Supervisor
ConocoPhillips Alaska Inc.
Office 907 - 659 -7224
CeII 907 - 943 -1720 / 1999
Pager 907 - 659 -7000 #909
• •
ConocoPhillips Well 1C-133 Injection Data
• Tbg Psi IA Psi • OA Psi I
4000
3500
3000
a -
� 2500
a 2000
1500
1000
500
0
09/10 10/10 11/10 12/10 01/11
Date
PTD 201 -077
Single casing (monobore) well.
Reason: Failed MITIA 5/21/2010
PC leak @ —22' 6"
Under evaluation for repair options
Well last injected 5/10
07/03/10 - Caliper survey performed
07/06/10 - Magnetic thicknes log performed
07/22/10 - Plug set at 3982' to secure well
12/02/10 - Received approved sundry for surface casing repair
• •
ConocoPhillips Well 1C-133 Injection Data
• Water Injection 0 Gas Injection I
4000
3500 -
3000
1 2500 -
a
a 2000
x
1500
1000 -
500
0
0 0.2 0.4 0.6 0.8 1
Injection Rate, bwpd or mscfpd
Water Tubing
Date of Gas Injected IA Pressure OA Pressure
Injected Pressure
Injection (bwpd) (mscfpd) (psi) (psi) (psi)
31- Dec -10 0 0 106 10
30- Dec -10 0 0 103 10
29- Dec -10 0 0 98 10
28- Dec -10 0 0 96 10
27- Dec -10 0 0 98 10
26- Dec -10 0 0 97 10
25- Dec -10 0 0 99 10
24- Dec -10 0 0 100 10
23- Dec -10 0 0 96 10
22- Dec -10 0 0 99 10
21- Dec -10 0 0 106 10
20- Dec -10 0 0 106 10
19- Dec -10 0 0 101 10
18- Dec -10 0 0 98 10
17- Dec -10 0 0 99 10
16- Dec -10 0 0 100 10
15- Dec -10 0 0 101 10
14- Dec -10 0 0 97 10
13- Dec -10 0 0 101 10
12- Dec -10 0 0 100 10
11- Dec -10 0 0 98 10
10- Dec -10 0 0 100 10
9- Dec -10 0 0 102 10
8- Dec -10 0 0 101 10
7- Dec -10 0 0 98 10
6- Dec -10 0 0 99 10
5- Dec -10 0 0 101 10
•
4- Dec -10 0 0 97 10
3- Dec -10 0 0 100 10
2- Dec -10 0 0 103 10
1- Dec -10 0 0 104 10
30- Nov -10 0 0 98 10
29- Nov -10 0 0 103 10
28- Nov -10 0 0 107 10
27- Nov -10 0 0 107 10
26- Nov -10 0 0 110 10
25- Nov -10 0 0 112 10
24- Nov -10 0 0 110 10
23- Nov -10 0 0 118 10
22- Nov -10 0 0 116 10
21- Nov -10 0 0 113 10
20- Nov -10 0 0 118 10
19- Nov -10 0 0 115 10
18- Nov -10 0 0 120 10
17- Nov -10 0 0 110 10
16- Nov -10 0 0 104 10
15- Nov -10 0 0 102 10
14- Nov -10 0 0 106 10
13- Nov -10 0 0 104 10
12- Nov -10 0 0 107 10
11- Nov -10 0 0 111 10
10- Nov -10 0 0 109 10
9- Nov -10 0 0 110 10
8- Nov -10 0 0 115 10
7- Nov -10 0 0 114 10
6- Nov -10 0 0 113 10
5- Nov -10 0 0 112 10
4- Nov -10 0 0 105 10
3- Nov -10 0 0 105 10
2- Nov -10 0 0 108 10
1- Nov -10 0 0 112 10
31- Oct -10 0 0 112 10
30- Oct -10 0 0 117 10
29- Oct -10 0 0 117 10
28- Oct -10 0 0 112 10
27- Oct -10 0 0 114 10
26- Oct -10 0 0 115 10
25- Oct -10 0 0 116 10
24- Oct -10 0 0 112 10
23- Oct -10 0 0 109 10
22- Oct -10 0 0 112 10
21- Oct -10 0 0 111 10
20- Oct -10 0 0 111 10
19- Oct -10 0 0 110 10
18- Oct -10 0 0 105 10
17- Oct -10 0 0 103 10
16- Oct -10 0 0 104 10
15- Oct -10 0 0 105 10
14- Oct -10 0 0 106 10
• •
13- Oct -10 0 0 106 10
12- Oct -10 0 0 106 10
11- Oct -10 0 0 107 10
10- Oct -10 0 0 105 10
9- Oct -10 0 0 102 10
8- Oct -10 0 0 98 10
7- Oct -10 0 0 106 10
6- Oct -10 0 0 108 10
5- Oct -10 0 0 110 10
4- Oct -10 0 0 108 10
3- Oct -10 0 0 109 10
2- Oct -10 0 0 103 10
Cu
SEAN PARNELL, GOVERNOR
L
AIASHLA OIL AND GAS 333 W. 7th AVENUE, SUITE 100
CONSERVATION COMUSSION ANCHORAGE, ALASKA 99501-3539
PHONE (907) 279-1433
FAX (907) 276-7542
MJ Loveland
Well Integrity Project Supervisor
ConocoPhillips Alaska, Inc. r17
P.O. Box 100360 ao
Anchorage, AK 99510
Re: Kuparuk River Field, West Sak Oil Pool, 1 C -133
Sundry Number: 310-389
* dqiw
Dear Ms. Loveland: V LIEU Zulu
Enclosed is the approved Application for Sundry Approval relating to the above
referenced well. Please note the conditions of approval set out in the enclosed
form.
As provided in AS 31.05.080, within 20 days after written notice of this
decision, or such further time as the Commission grants for good cause shown,
a person affected by it may file with the Commission an application for
reconsideration. A request for reconsideration is considered timely if it is
received by 4:30 PM on the 23rd day following the date of this letter, or the
next working day if the 23rd day falls on a holiday or weekend.
Sincerely,
Daniel T. Seamount, Jr.
Chair
DATED this 3C) -/ day of November, 2010.
Encl.
ConocoPhillips A F CE I VE�r
Alaska
P.O. Box 100360 NOV 2 3 2010
ANCHORAGE, ALASKA 99510 -0360
o' s aa "
Cons. Ctjyrer
Ang orA00
November 21, 2010
Commissioner Dan Seamount
Alaska Oil and Gas Conservation Commission
333 West 7 Avenue, Suite 100
Anchorage, AK 99501
Dear Commissioner Seamount:
Enclosed please find the 10 -403 Application for Sundry Approvals for ConocoPhillips
Alaska, Inc. well 1C -133, PTD 201 -077 surface casing inspection and repair.
Please call Perry Klein or me at 659 -7043 if you have any questions.
Sincerely,
1,61
Miv�o veland
ConocoPhillips
Well Integrity Projects Supervisor
Enclosures
+ STATE OF ALASKA
ALASIMIL AND GAS CONSERVATION COMMISSO �' k!D
APPLICATION FOR SUNDRY APPROVALS ���
20 AAC 25.280
1. Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair w ell Change Approved Program
Suspend r Plug Perforations r Perforate r Pull Tubing r Time Extension r
Operational Shutdown r Re -enter Susp. Well r Stimulate r After casing
Other: SC repair r
2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number:
ConocoPhillips Alaska, Inc. Development r Exploratory r 201 - 077
3. Address: Stratgraphic r Service F7 6. API Number:
P. 0. Box 100360, Anchorage, Alaska 99510 50 029 - 23013 - 00
7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number:
where ownership or landownership changes:
Spacing Exception Required? Yes r No r 1C -133
9. Property Designation (Lease Number): 10. Field / Pool(s):
ADL 25649 ALK 467 Kuparuk River Field / West Sak Oil Pool
11. PRESENT WELL CONDITION SUMMARY
Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured):
4615 ' 4332 • 4500' 4217'
Casing Length Size MD TVD Burst Collapse
CONDUCTOR 134 16 181' 181'
PRODUCTION 4559 5.5 3952' 3669'
Liner 649 3.5 4600' 4319'
Perforation Depth MD (ft):4050 -4080, 4110 -4140 Perforation Depth TVD (ft): 3767-3787,3827-3867 Tubing Size: Tubing Grade: Tubing MD (ft):
4154 - 4176,4196 -4206 ,4212 -0226,4230- 4242,4260 -4330 3671 - 3693, 39133923,39293943,3947-3959,3976 -4046 3.5 L-80 3952
Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft)
SBE - BAKER 12' SBE MD= 3951 TVD= 3668
None - Type Not Found (Manual Entry Required) No SSSV
12. Attachments: Description Summary of Proposal r 13. Well Class after proposed work:
Detailed Operations Program r BOP Sketch r Exploratory r Development r Service r'
14. Estimated Date for Commencing Operations: 01/15/11 15. Well Status after proposed work:
Oil T- Gas r WDSPL r Suspended r
16. Verbal Approval: Date: WINJ ,; r GINJ r WAG r Abandoned r
Commission Representative: GSTOR r SPLUG r
17. 1 hereby certify that the foregoing is true and correct to the best of y knowledge. Contact: MJ Loveland /Perry Klein
Printed Name N J Loveland Title: Well Integrity Project Supervisor
Signature ��/ , i Phone: Date
Commission Use O
Sundry Number, �,. �( 9
Conditions of approval: Notify Commission so that a representative may witness U
Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r
/ ,/ /
1 1 1 54C% E E'
Other: 1r1� Lc� Oa 4 oLu .� v�ci0.. a / leti.0
Subsequent Form Required: 'dy Goy
k APPROVED BY
Approved by: COMMISSIONER THE COMMISSION Date: C�
S �.-
Form 10 -403 Revised 1/2010 DEC O I Submit in Duplicate
0 IGIFf R s
�/
y
o �
ConocoPhillips Alaska, Inc.
Kuparuk Well 1C -133 (PTD 201 -077)
SUNDRY NOTICE 10 -403 APPROVAL REQUEST
November 21, 2010
This application for Sundry approval for Kuparuk (WestSak) well 1C -133 is for the repair of the surface
casing near surface. This well is a single casing horizontal undulating injector (I UI) that was drilled in
2001.On 07/09/10 a surface casing leak was confirmed and reported to the AOGCC.
ConocoPhillips would like to permanently repair the well with a welded patch.
With approval, repair of the surface casing will require the following general steps:
1. Safe -out the well as needed with a tubing tail plug.
2. Remove the floor grate, well house, flow lines, and other equipment from around the wellhead. '
3. Excavate wellhead location to a depth of — 26'.
4. Remove the previous sealant treatment from the conductor.
5. Install nitrogen purge equipment for the conductor (and IA if needed) so that hot work may be
conducted in a safe manner.
6. Cut windows in the conductor casing and remove cement from the outside of the surface casing for
inspection. Then start removing conductor to find damage to surface casing Notify A OGCC -�
Inspector for opp ortunity to inspect. i
7. CPAI Mechanical Engineers will determine if patch or repair is needed to return the casing to
operational integrity.
8. If a patch is required, QA/QC will verify the repair for a final integrity check.
9. Install anti - corrosion coating as specified by CPAI Corrosion Engineer.
10. Replace the conductor and fill the void with cement and top off with sealant.
11. Backfill as needed with gravel around the wellhead.
12. Remove plugs and return the well to service.
13. File 10 -404 with the AOGCC post repair.
Well Integrity Project Supervisor 11/20/2010
~~
WELL LOG TRANSMITTAL
To: Alaska Oil and Gas Conservation Comm.
Attn.: Christine Shartzer
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
RE: Plug Setting Record: 1C-133
Run Date: 7/22/2010
August 5, 2010
The technical data listed below is being submitted herewith. Please address any problems or
concerns to the attention o£
Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518
1C-133
Digital Data in LAS format, Digital Log Image file 1 CD Rom
50-029-23013-00
f J
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE
TRANSMITTAL LETTER TO THE ATTENTION OF:
~~
8
~~ ~ ~~'~
J ~°~
klinton.
Date: AUG 1 i 2010
41i ~ ~ Cam. Comnnissb~
Anchsx~~
Signed:
~~~ ~~E.
~~~~~~~
To: AOGCC
Christine ~ '~j G>,a~ -~ z o ~
333 West 7th Avenue
Suite 100
Anchorage, Alaska 99501
(907) 659-5102
RE : Cased Hale/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTT)
The technical data listed below is being submitted herewith. Please acknowledge receipt by returning
a signed copy of this transmittal letter to the following
ProActive Diagnostic Services, Inc.
Attn: Robert A. Richey
130 West International Airport Road
Anchorage, AK 99518 ~~'~::'~''~ °~ u ~" ~' ~ I (}~~J
Fax: (907) 245-8952
1) MTT Report
2)
O6,1u1-10
UT C ~b ~ - off'}
•
1 Report 50-029-23013-00
1 C-133
~~~~~
Signed : 1..
Print Name:
,JUI. 2 ~ 201¢
Date
{~N . C
PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518
PHONE: (907)245-8951 FAX: (907)245-88952
E-MAIL : ~dsanchcarag~mernorvlog.com WEBSITE : www.memoryioa.com
C:~DocumenLs and Settings\Diane Wiltiams~DesktoplTransmit_Conoco.docx
•
Memory Magnetic Thickness Toot
Log Results Summary
Company: ConocoPhillipsAlaska, Inc. Well: 1C-133
Log Date: July 6, 2010 Field: West Sak
Log No.: 7429 State: Alaska
Run No.: 4 (2"d MTT) API No.: 50-029-23013-00
Pipet Desc.: 3.5" 9.3 Ib L-80 EUE 8RD Top Log Intvl.: Surface
Pipet Use: Tubing Bot. Log Intvl.: 222 Ft. (MD)
Pipet Desc.: 5.5" 15.5 Ib L-80 BTC-MOD Top Log Intvl.: Surface
Pipet Use: Production Casing Bot. Log Intvl.: 222 Ft. (MD)
Pipe3 Dese.: 16" 62.58 Ib. H-40 Welded Top Log Intvl.: Surface
Pipe3 Use: Conductor Pipe Bot. Log Intvl.: 181 Ft. (MD}
Inspection Type : Corrosive & Mechanical Damage Inspection
COMMENTS
This MTT data is tied into the Mandrel Hanger @ 0'.
This is the second time this well has been logged with the 12 Arm Magnetic Thickness Tool (MTT). The
Magnetic Thickness Tool responds to the total thickness of metal of the 3.5" tubing and 5.5" production
casing, with some influence from the 16" conductor pipe. Passes at 5Hz, 8Hz and 10Hz were made at 20
fpm.
COMPARISON TO PREVIOUS MTT LOG RESULTS
A comparison of the current 10Hz pass to the previous 10Hz pass (December 12, 2006) indicates no
significant change in metal thickness during the time between logs. A slower and steadier logging speed (20
fpm) is observed in the current log compared to the previous log, providing a more stable and less noisy tool
response to the metal volume surrounding it.
In the 2006 log, a single calibration taken within the conductor pipe was applied to the entire log interval.
This resulted in an indication of less metal below the conductor, relative to the interval including the
conductor. The 2010 data set was processed using calibrations from both zones, eliminating the
appearance of metal loss below the conductor pipe. To enhance comparability between the 2010 and 2006
data sets, the 2006 data set in this report has been compensated to no longer indicate metal loss in the log
zone below the bottom of the conductor relative to the interval including the conductor.
INTERPRETATION OF MTT LOG RESULTS
The MTT fog results cover the interval surface to 222'. Changes in metal volume are relative to the
calibration points at 100' and 200', where the readings are assumed to represent undamaged pipe. All other
readings are relative to these reference points, which include influences from the 3.5" tubing, 5.5" production
casing and 16" conductor pipe.
A log plot overlay of the average overall metal thickness recorded by the 5Hz, 8Hz and 10Hz passes is
included in this report. This plot indicates minor metal loss over the intervals 4' -10' and 210' - 222' in all
three passes. Log plots of the entire 5Hz passes and an expanded log plot of -top 30' of the 5Hz pass are
included in this report.
A maximum ^'4% circumferential metal loss is recorded in the interval between 4' - 10' in the 5Hz pass.
A maximum -3% circumferential metal loss is recorded in the interval between 210' - 222' in the 5Hz pass,
which appears to be associated with a casing joint that may be manufactured with a slightly thinner wall or a
slightly different material.
ProActive Diagnostic Services, Inc. ,' P,~. Box 1369, Stafford, TX ??49?
Phone: (281j or (888) 565-9085 Fax: (281j 565-1369 E-mail: PDS~c~memaryiog.com
Prudhoe Bay Field Jffice Phone; (907j 659-230? Fax: (907j 659-2314
ao~-a~~
u~c ~
' • •
The percent circumferential metal loss expressed in this report is a percentage of the total metal that the
' MTT tool is responding to, which includes influences from the 3.5", 5.5" and 16" pipe. If all of the metal loss
is specific to the 5.5" production casing, the percent metal lass from that pipe alone is probably higher than
the numbers expressed. Some of the metal loss indicated could be from either the 3.5" tubing or 16"
' conductor.
i~
i~
C
L
i~
'I
' Field Engineer: Wm. McCrossan Analyst: HY. Yang Witness: B. Boehme
ProActive Diagnostic Services, Inc. J P.O. Bax 1369, Stafford, TX 77497
Phone: {281) or (888) 565-9085 Fax: {281) 565-1369 E-mail; PDSra~memoryiag.com
Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: {907) 659-2314
i~
Q~O`~~ relLSAFc,9 Compar~ - Current 10Hz to Previous 10Hz ~a Metal Thickness Overlay
w
~ €' ~N 1C-133
~~,. .r
PnaAcTive ~inynosTic SEnviccs July 6, 2010 and December 12, 2006
Database File: d:l4varriorldatal1c-133\comp.db
Dataset Patluiame: c~nip
Presentation Format: comps
Dataset Creation: Thu Jul 08 11:29:20 2010
Charted by: Depth in Feet scaled 1:150
-50 Delta Metal Thickness 2006 (10Hz) 50
-50 Delta Metal Thickness 2010 (10Hz) (%) 50
a
Metal Thickness 2006
20
Metal Thickness 2010
10Hz)
40
60
80
100
A
Q`ti~,wE"s 5Hz, ~z and 10Hz Delta Metal Thi~iess Passes Overlay
4- Fns.
s
1 C-133 July 6, 2010
Pf1°1~CTIYE ~IhfjM0571C SERVICES
Database File: d:\warriorldata\1c-133\overlay.db
Dataset Pathname: overlay
Presentation Format: overlay
Dataset Creation: Thu Jul 08 09:00:17 2010
Charted by: Depth in Feet scaled 1:150
-50 Delta Metal Thickness 2010 (1 OHz) (%) 50
-50 Delta Metal Thickness 2010 (8Hz) (°1°} 50
-50 Delta Metal Thickness 2010 (5Hz) (%} 50
0
20
10Hz Delta Metal
40
60
5Hz Delta Metal Thickness
Delta Metal
80
100
Bottom of 16"
120
140
160
180
Delta Metal
Delta Metal Thicknes
200
Delta Metal
220
-50 Delta Metal Thickness 2010 (10Hz) (%)
-50 Delta Metal Thickness 2010 ($Hz) (%)
-50 Delta Metal Thickness 2010 (5Hz} (%)
50
50
50
A
Q`E`"~E"s R~rded Magnetic Thickness L.~ Data - 5Hz Pass
~ ~ F~s~
~ '~ 1 C-133 July 6, 2010
' P11°QCTIVE DIAE~M°STIC SERVICES
Database File: d:lwarriorldatal1c-13315hzpass.db
Dataset Pathname: SHzPass
Presentation Format: mtt_20
Dataset Creation: Wed Jul 07 1722:34 2010
Charted by: Depth in Feet scaled 1:150
-50 Delta Metal Thickness (°lo) 50 1.5
0 Line Speed (ft/min} -200 -16.1
Line S ee Tree -~
p
.Hanger.
3.5" Collars
j 4°I° Metal Loss
i-
' Delta Metal Thickness
' Tubing Jt. 1
3.5" Collar
~--
i
' S.5" Collar
' Tubing Jt. 2
50
' 3.5" Collar ~
1
Tubing Jt. 3
5.5" Collar
- -- - ~
' 3.5" Collar - ~ _
MTTP01 (rad} 21.5
MTTP12 (rad) 3.9
`~~,wE"sA~ E~anded 5Hz Pass Magnetic ~kness Log Data
Q~~ 09
F~ to
1 C-133 July 6, 2010
P11RI~CTIYE ~IAQN°STIC SERVICES
Database File: d:\warrior\datal1c-1331extended 5hzpass.db
Dataset Pathname: SHzPass
Presentation Format: 14
Dataset Creation: Thu Jul 0$10:40:27 2010
Charted by: Depth in Feet scaled 1:60
-50 Delta Metal Thickness (%} 50 1.4 MTT Phase Shift -Sensor 01 (5 Hz) (rad} 11.4
0 LSPD (ft/min) -200 -7.4 MTT Phase Shift -Sensor 12 (5Hz) (rad) 2.6
I ' T I - - - -
ree _
Lin e S peed ~Hanger~
Pup
-
1
, -
~
I-
~ -
_. _
3
5 " Co llar _ _
.
4% Meta l Lo ss
S
1 ~'
~ ,~ - - --
10
De lta Met al Th ickness
e
~.
Tubing Jt. 1
w y
'
I I
>y ~
} ~ >
`
20
i
, ;
}
3a F
5
~
°,
.~
3.5" Col lar ~ -
-_
-50 Delta Metal Thickness (%) 50 1.4 MTT Phase Shift -Sensor 01 (5 Hz)I(rad) 11.4
0 LSPD (ft/min) -200 -7.4 MTT Phase Shift -Sensor 12 (5Hz) (rad) 2.6
~ 1 C-133
ConocoPl'lillips II Attributes An le 8 MD TD
AI`I, M1.,i,l ellbore APl/UWI Field Name Well Status Inc! (°) MD (itl(B) Act Btm (RNB)
500292301300 WEST SAK INJECTING 36.43 2,149.02 4,615.0
Comment
SSSV: NONE H2S (ppm)
0 Dare
6/18!2006 Annotation E
Last WO: ntl Date KBGrtl (R)
46
59 Riy Release Date
6!3/2001
Well Conti -1C-133 ]1612999 1:4]:51 PM .
chemaEC-AGUaI Annotation DepM (RKB) End Date Annotation Last Motl By End Date
Last Tag: SLM 4.130.0 7/5/2009 Rev Reason: TAG FILL SLM triples' 7/6/2009
Casin Strin s
String OD String ID Set Depth Set Depth (TVD) String Wt String
Casing Deccription (in) (in) Top (/tKg) (RKB) (Rl(B) (Ibs/R) Grade String Top Thra
CONDUCTOR 1 6 15.062 46.6 161.0 181.0 62.58 -40 ELD
PRODUCTION 5 t/ 2 4.950 0.0 3,952.0 3,669.5 15.50 -80 TC-h10D
LINER 31/ 2 2.992 3.952.0 4.602.0 4.318.8 9.30 ~0 UEBRD
Tubin Strin s
String OD String ID Set Depth Sat Oepth (ND) String Wt String
Tubing Description (inl (inl Top (RKB) (TtKB) (RKB) (Ibs/R) Grade String Top Thrd
coNnucroR, TUBING 31/ 2 2.992 O.D 3,952.0 3,669.5 9.30 -80 UEBRD
181 Other In Hole A ll Jewel :Tubi n Run 8 Retrievable, Fish, etc.
Top Depth
(TVD) Top Inc!
Gns uFT Top (itl(B) (itl(B) (°I Dascdption Commont Run Date ( )
,
3,666 3,866 3,584.0 6.33 G AS LIFT AMCO/KBG2-9/1/DMY/NT/// Comment: STA 1 /7/2001 2.900
3,910 3,627.6 5.40 N IPPLE AMCO'DS' NIPPLE w/2.812 NO GO Profile %//2001 2.812
3,949 3,666.5 4.57 S EAL BAKER SEAL ASSEMBLY /7!2001 3.000
3.951 3.668.5 4 53 S BE BAKER 12' SBE 77/2001 4.000
'
NIPPLE, 3,91U 4.150 3.86/.2 2.82 P LUG RP SET 4/20/2003 /20/2003 0.000
4.601 4.31ZR O.RR S HOE LINER SHOE f7/2001 2992
Perforations 8 Slots
snot
rop (rvD) Ban (rvD)
s
NO GO SUe Top (ftKB) Btm (ftKB) (7tKB) (flKB) Zone Data sh. Typa Comment
.
3s4e
4,050
4,080
3,767.2
3,7972
WS D, 1C-133
/23/2001
4.0
PERF
.5" HSD DP, 60 deg ph, 31J UJ HMX
4.110 4,140 3,827.2 3,857.2 S B, iC-133 23/2001 4.0 PERF .5" HSD DP, 60 deg ph, 31J UJ HMX
SEAL, 3,949 4,154 4,176 3,871.2 3.693.1 S A4, iC-133 !23/2001 4.0 PERF .5" HSD DP, 60 deg ph, 31J UJ HMX
4.196 4.206 3.913.1 3.923.1 S A3, 1C-133 /23/2001 4.0 PERF .5" HSD DP. 60 deg ph. 31J UJ HMX
seE
3
9s1 4,212 4,226 3,929.1 3,943.0 WS A3, 1C-133 /22/2001 4.0 PERF .5" HSD DP, 60 deg ph
,
,
PRODUCTION 4,230 4.242 3,947.D 3,959.0 WS A3. 1Gt33 /22/2001 4.0 PERF .5" HSD DP, 60 deg ph
,
sz
~
i
4,260
4,330
3,976.9
4,046.9
WS A2. 1C-133
/22/2001
4.0
PERF
.5" HSD DP, 60 deg ph
(PERF,
4,050-0,060
IPERF,
0.119-0,140
PLUG, 4,159
(PERF,
4,150.+1,1]6
IPERF,
4,19fi-0,206
IPERF,
9,212-0.22fi r
i
IPERF,
4,2364,242
IPERF,
4.2664,330
SROE, 4,601
LINER, 4,6D2
Tp, 4,615
CASING DETAIL
3-1/2" Monobore tniector
West Sak 1 C-133
DATE: 06!02/01
PHILLIPS Alaska Inc. 1 of 1 PAGES
# ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH
TOPS
Nabors Ri 245E RT to LDS 38.20 38.20
38.2
Vetco Gra Han er w/ Pu 4.73 38.20
't # 124 3-1/2" 9.3# L-80 EUE 8rd-Mod t 4.5" OD 2.992" ID 31.33 42.93
3-1/2" 9.3# L-80 EUE 8rd-Mod SPACE OUT PUP'S None Ran 74.26
't # 3-123 3-1/2" 9.3# L-80 EUE 8rd-Mod t 4.5" OD 2.992" lD 3786.11 74.26
3-1I2" 9.3# L-80 EUE 8rd-Mod u 4.5" OD 2.992" ID 5.68 3860.37
3-1I2" x 1" Camco KBG-2-9 w/ DK-1 latch 4.725" OD 2.9" ID 6.65 3866.05
3-112" 9.3# L-80 EUE 8rd-Mod u 4.5" OD 2.992" ID 5.50 3872.70
't # 2 3-1/2" 9.3# L-80 EUE 8rd-Mod tbg 4.5" OD 2.992" ID 31.35 3878.20
3-1 /2" 9.3# L-80 EUE 8rd-Mod collar 4.5" OD 2.992" ID .49 3909.55
3-1/2" Camco 'DS' ni le wf 2.812" No-Go Profile, 3.78" OD .72 3910.04
~t # 1 3-1/2" 9.3# L-80 EUE 8rd-Mod tbg 4.5" OD 2.992" ID 31.33 3910.76
3-1/2" 9.3# L-80 EUE 8rd-Mod u 4.5" OD 2.992" ID 6.06 3942.09
Baker No-Go Sub 4.5" OD 3" tD .78 3948.15
LANDED 1.41' FROM LOCATOR SHOULDER 1.41 3948.93
5 1/2" Baker XO cou lin w/ locator shoulder, 5-1/2" BTC x SBE 3950.34
Baker seal ass 4" OD 3" ID 11.94 3948.93
LANDED 2.00' FROM FULLY INSERTED 2.00 3960.87
BOTTOM OF BAKER SBE 3962.87
Remarks: String Weights with Blocks: 100K# Uo. 95K# Dn.75K# Blocks. Ran 124 joints of tubi ng
Drifted casing, & hanger with 2.867" plastic rabbit. Used Arctic Grade API Modified No Lead thread
compound on all connections. Tubing is non-coated. All tubing is new.
Nabors Rig 245E Drilling Supervisor. Granville Rizek
Page 1 of 1
Maunder, Thomas E (DOA)
From: NSK Problem Well Supv [n1617@conocophillips.com]
Sent: Sunday, July 04, 2010 10:52 AM
To: Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Regg, James B (DOA)
Cc: NSK Problem Well Supv
Subject: 1C-133 (PTD#201-077) Report Of Failed MITIA
Tom, Jim, Guy
Initial diagnostics indicate the well has a SC with the depth unknown at this point. Further diagnostics will be
performed to locate the depth of the leak. Pending the depth of the leak, repair options will be evaluated. Once a
repair method is decided upon, the appropriate paperwork will be submitted. The well has already been added to
the monthly report.
Please let me know if you have any questions.
Brent Rogers/Martin Walters
Problem Wells Supervisor
ConocoPhillips Alaska, Inc.
Desk Phone (907) 659-7224
Pager (907)-659-7000 pgr. 909
F NSK Problem Well Supv
Sent: day, May 25, 2010 8:21 AM
To: jim.re alaska.gov'; 'tom.maunder@alaska.gov'; Schwartz, Guy L (DOA)
Cc: NSK Well In itY Proj; NSK Problem Well Supv; CPFS Prod Engr; CPFi DS Lead Techs; Gangl, Meli ; Hollar, Eric Andrew; Pierson, Chris R
Subject: iC-133 201-077) Report Crt Failed MITIA
Jim/Tom/Guy,
West Sak injector 1 C-133 (PTD#2 77) failed a State Witnesse ITIA during a regularly scheduled 4 year
testing program. Slickline wi{I troublesh nd attempt to the r air as soon as reasonably possible. The well will
be shut in and freeze protected and will be a d to the mo ly report.
Attached is a 90 day TIO plot and wellbore schemati .
« File: 1 C-133 Wellbore Schematic.pdf » < ite: 1 C-133 T lot. pdf »
Please contact me at your convenienc ~ you have questions or comma
Martin
Martin Walters / Brent el
Problem Wells Supe ~ or
ConocoPhillips AI a Inc.
Office 907-6 - 224
Cell 90 43-1720 / 1999
Pager 7-659-7000 #909
8/7/2010
•
!/V~L~ ~~
~~~,~~~~
~,.
PROACTIVE DIAGNOSTIC SERVICES, INC.
•
To: AOGCC
Christine Mahnken
333 West 7th Avenue
Suite 100
Anchorage, Alaska 99501
(907] 659-5102
RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTT]
The technical data listed below is being submitted herewith. Please acknowledge receipt, by returning
a signed copy of this transmittal letter to the following
ProActive Diagnostic Services, Inc.
Attn: Robert A. Richey
130 West international Airport Road
Suite C ~~~,. ~$~i~~y ~~, i,J i.~ kE s!. ~ ~ ~ ~!
Anchorage, AK 99518
Fax: (907) 245-8952
-_ -~ `.
1 ] Caliper Report 03-Ju1-10 1 C-133 1 Report / EDE 50-029-23013-00
2J MTf Report 02-Ju1-10 1 C-104L1 1 Report
Boa-o~2
U~ ~o ~ - v3~ ~ ~ ~`~ ~
50-029-23076-60
_~ ~:._ _ _
Signed : Date
=~ . . ~~~
Print Name: `'
PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518
PHONE: (9071245-8951 FAX: (9071245-88952
E-MAIL : ~cis~~?chor~geCa~rnerTaor~lm .~~~ WEESITE : wr~+nnu.aT~PlTZOrlioct.~vrn
C:\Documen6 and Settvtgs~Diane Williams~Desktop\Transmit_Conoco.docx
•
Memory Mutti-Finger Caliper
Log Results Summary
Company: ConocoPhillipsAlaska, Inc. Well: 1C-133
Log Date: July 3, 2010 Field: West Sak
Lag No.: 7427 State: Alaska
Run No.: 2 (MIT) API No.: 50-029-23013-00
Pipet Desc.: 3.5" 9.31b. L-80 EUE 8RD Top Log Intvl1.: Surface
Pipet Use: Tubing and Liner Bot. Log Intvl1.: 4,136 Ft. (MD)
Inspection Type : Corrosive & Mechanical Damage Inspection
COMMENTS
This caliper data is tied into the DS Nipple @ 3,910' (Driller's Depth).
This log was run to assess the condition of the 3.5" tubing and liner with respect to corrosive and mechanical
damage. The caliper recordings indicate the 3.5" tubing and liner logged appear to be in good to poor
condition with a maximum wall penetration of 43% in joint 45 (1,444'}. Waif penetrations ranging from 20°l0
to 43% wall thickness are recorded in 92 of the 135 joints logged. The damage appears in the form of a line
of pits from -580' to 4,136' (EOL). No significant areas of cross-sectional wall loss or I.D. restrictions are
recorded throughout the tubing and liner logged.
This is the second time a PDS caliper has been run in this well and the 3.5" tubing has been logged. A
comparison of the current and previous log (August 2, 2005) indicates an increase in corrosive damage
during the time between logs. A comparison graph illustrating the difference in maximum recorded
penetrations on a joint-by joint basis between logs is included in this report.
MAXIMUM RECORDED WALL PENETRATIONS:
Line of Pits (43%) Jt. 45 @ 1,444 Ft. (MD)
Line of Pits (42%) Jt. 49 @ 1,551 Ft. (MD)
Line of Pits (41%) Jt. 50 @ 1,597 Ft. (MD)
Line of Pis (39%) Jt. 34 @ 1,078 Ft. (MD)
Line of Pits (39%) Jt. 55 @ 1,742 Ft. (MD)
MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS
No significant areas of cross-sectional wall loss (> 7%} are recorded throughout the tubing and liner logged.
MAXIMUM RECORDED ID RESTRICTIONS
No significant I.D. restrictions are recorded throughout the tubing and finer logged.
Field Engineer: Wm. McCrossan Analyst: C. Lucasan Witness: J. Hansen
Prw~Gti~re Diagnostic Sen~ices, Inc. ( P,O. Box 1..65, StafforJ, TX 77497
Phone: {281) or {333) 565-9085 Fa:~c: {231} !i65-1365 E-mail: PDS amemorylog.com
Prudhoe Bay Fieid Office Phone; (507} 659-230? Fax; {507) 659-214
• •
Correlation of Recorded Damage to Borehole Profile
Pipe 1 3.5 in (40.2' - 4129.2') Well: 1 C-133
Field: West Sak
Company: ConocoPhillips ,4laska, Inc.
Country: USA
Survey Date: July 3, 2010
^ A pprox. Tool De viation ^ A pprox. Borehol e Profil e
44
326
639
951
1265
1580
O
1891 ~
2205 •~
s
v
~
2519
2 831
3142
3454
3767
GLM 1
4129
130
0 5 0 1 00
Da mage Pr ofile (°i ° wall) / Tool D eviatio n (degr ees}
Bottom of Survey = 130
1
10
'
20
30
I +.
40 `~
50
60
a~
E
Z 70
c
~
o
-' riU
90 ,
100 I
~
t7
110 ..
120
I
•
•
Well: 1 C-133
Field: West Sak
Company: ConocoPhillips Alaska, Inc
Country: USA
Maximum Recorded Penetration
Comparison To Previous
Survey Date: July 3, 2010
Prev. Date: August 2, 2005
Tool: UW MFC 24 No. 214320
Tubing: 3S" 9.3 Ib L-80 EUE 8RD
Overlay
Max. Rec. Pe
0 50 100 1'
0.1 -
to
20
30
40
50
60
.g
E
0
z
~o
'S
80
90
100
110
120
124.2
i. (mi
~0 2(
I
I
I
~I
Is)
~0 2'
~0
^July 3, 2010 ^August 2, 2005
Difference
Diff. in Max. Pen. (mils)
-100 -50 0 50 100
d
a
E
0
z
'o
1 ~
I
-20 -10 0 10 20
Approx. Corrosion Rate (mpy)
•
•
PDS Report Overview
~~ 5... Body Region Analysis
Well: 1 C-133 Survey Date: July 3, 2010
Field: West Sak Tool Type: UW MFC 24 No. 214320
Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69
Country: USA No. of Fingers: 24
Anal st: C. Lucasan
Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len.
3.5 ins 9.3 f L-80 CUC 8RD '2.992 ins 3.5 ins 6.0 ins 6.0 ins
Penetration and Metal Loss (% wall)
~ penetration body .~ metal loss body
120
100
80
60
40
20
0 0 to 1 to 10 to 20 to 40 to over
1 °/ 10 % 20% 40% 85% 85%
Number of'oints anal sed total = 135
pene. 0 7 46 75 7 0
loss 35 100 0 0 0 0
Damage Configuration (body )
150
I
10O
5ti
0
isolated general line ring hole / poss
pitting corrosion corrosion corrosion ible hole
Number of ~oints dama ed total = 128
128 0 0 0 0
Damage Profile (% wall)
~ penetration body _..: rnetal loss body
0 50 100
n
GLM 1
Bottom of Survey = 130
Analysis Overview page 2
PDS REPORT JOINT TABI,
Pipe: 3.5 in 9.3 ppf L-80 EUE 8KD Well:
Body Wall: 0.254 in Field:
Upset Wall: 0.254 in Company:
Nominal I.D.: 2.992 in Country:
Survey Date:
•
'CATION SHEET
1 C-133
West Sak
ConocoPhillips Alaska, Inc
USA
July 3, 2010
Joint
No. lt. Depth
(Ft.) PE~n.
IJp,~~l
(Ins.) Pen.
Body
(Ins.) Pen.
°4, Mei.[I
loss
44, Min.
LD•
(Ins.)
Comments Damage Profile
(%wall)
0 50 100
.1 40 t) 0.01 5 I 2.96 PUP
1 44 0 0.01 4 ' 2.95
2 76 [? 0.01 4 1 2.95
3 107 [? 0.03 10 f 2.95
4 137 U 0.04 17 I 2.96 Shallow ittin
5 169 [ i 0.01 2 I 2.94
6 200 [> 0.06 22 2.96 Isolated ittin .
7 231 O 0.03 13 2.94 Shallow ittin .
8 263 t? 0.04 14 I 2.95 Shallow ittin .
9 294 U 0.04 1 ~1 I 2.95 Shallow ittin .
10 326 [~ 0.04 15 1 2.96 Shallow ittin .
11 357 i? Q05 _'t) 1 2.93 Shallow ittin .
12 388 t? 0.04 14 1 2.95 Shallow ittin .
13 420 [? 0.02 ~) 1 2.95
14 451 O 0.04 15 1 2.95 Shallow ~ittin .
15 482 (t 0.04 14 I 2.95 Shallow ittin .
16 514 t) 0.04 17 2.95 Shallow ittin .
17 545 i? 0.04 17 I 2.93 Shallow ittin .
18 576 [) 0.05 2O I 2.93 Shallow line of its.
19 607 [? 0.04 1 i 2.96 Shallow line of its.
20 639 l? 0.05 2U 2.95 Line of its.
21 669 ~! 0.05 1 ~) i 2.93 Shallow line of its.
22 700 [I 0.06 2 > 2.96 Line of its.
23 731 !? 0.06 22 1 2.95 Line of its.
24 763 i? 0.06 Z4 ~ 2.95 Line of its.
25 794 [? 0.07 ~7 '~ 2.96 Line of its.
26 825 [? 0.07 26 4 2.97 Line of its.
27 857 !~ 0.07 20 ~' 2.94 Line of its.
28 888 ! ` 0.06 Z' 2.96 Line of its.
29 920 [? 0.08 ~> 2.95 Line of its.
30 951 [? 0.06 24 5 2.96 Line of its.
31 983 [? 0.05 19 ? 2.95 Shallow line of its.
32 1014 ti 0.06 13 ~ 2.94 Line of its.
33 1045 (t 0.06 24 5 2.96 Line of its.
34 1077 [! 0.10 i9 2 2.95 Line of its.
35 1108 [1 0.07 28 3 2.96 Line of its.
36 1 140 [) 0.10 38 3 2.96 Line of -its.
37 1171 [? 0.07 27 ? 2.96 Line of its.
38 1203 [? 0.07 27 _' 2.93 Line of its.
39 1234 U 0.08 30 2.96 Line of its.
40
1265
l?
0.09
'r7
?
2.93
Line of its. _
41 1297 ±! 0.07 '7 2.95 Line of its.
42 1328 [) 0.07 24 ~' 2.94 Line of its.
43 1359 [? 0.07 28 2.95 Line of its. -
44 1391 U 0.08 32 ~ 2.94 Line of its. -
45 1422 O 0.11 43 S 2.96 Line of its.
46 1454 U 0.07 ~9 6 2.96 Line of its.
47 1485 U 0.08 31 b 2.96 Line of its. -
48 1517 [! 0.06 25 ? 2.96 Line of its. '
49 1548 n 0.1 1 42 ' 2.95 Line of its.
_ Penetration Body
Metal Loss Body
Page I
•
PDS REPORT JOINT TABI.
Pipe: 3.5 in 9.3 ppf I -80 EUE 8RD Well:
Body Wall: 0.254 in Field:
Upset Wall: 0.254 in Company:
Nominal LD.: 2.992 in Country:
Survey Date:
ELATION SHEET
1 G133
West Sak
ConocoPhillips ,Alaska, Inc
USA
July 3, 2010
Joint
No. Jt. Depth
(Ft) I':~n.
UI~;~~I
ili~~.) Pen.
Body
(Ins.) Pen.
% Met,,l
Loss
",4> Min.
LD•
(Ins.)
Comments Damage Profile
(%wall)
0 50 100
50 1580 a 0.10 41 2.96 Line of pits.
51 1611 t? 0.07 29 2.94 Line of its.
52 1643 11 0.09 3(> 2.95 Line of .its.
53 1674 !~ 0.08 3~ s 2.95 Line of its.
54 1704 ~! 0.07 ~t~ 2.95 Line of its.
55 1736 Il 0.10 ~'> 2.96 Line of its.
56 1767 i> 0.06 '-1 2.96 Line of its.
57 1797 ~~ 0.07 ZF3 2.94 Line of its.
58 1829 ~? 0.06 23 2.96 Line of its.
59 1860 a 0.05 ZU 2.95 Shallow line of its_
60 1891 t~ 0.05 ZO 2.94 Line of its.
61 1923 a 0.05 ZO 2.96 Line of its.
62 1954 ~! 0.05 i t3 1 2.95 Shallow line of its.
G3 1985 ~! 0.06 22 4 2.96 Line of its.
64 2017 U 0.05 1 t3 2.96 Shallow line of its.
65 2048 i~ Q05 19 2.96 Shallow line of its.
66 2080 !? 0.06 ~ ~ ' 2.95 Line of its.
67 2111 t! 0.05 20 ? 2.94 Line of its.
68 2143 I i 0.04 1 ~ 1 2.96 Shallow line of its.
69 2173 i1 0.04 16 -( 2.96 Shallow line of its.
70 2205 t? 0.04 17 1 2.94 Shallow line of its.
71 2236 U 0.04 1 7 4 2.96 Shallow line of its.
72 2267 i) 0.05 2U 1 2.94 Shallow line of its.
73 2299 c! 0.04 1' 2.96 Shallow line of its.
74 2330 U 0.08 ~Z 2.93 Line of its. -
75 2362 tr 0.07 !~, ~ 2.94 Line of its.
76 2393 e) 0.06 2.94 Line of its.
77 2424 ! ~ 0.06 13 1 2.94 Line of its.
78 2456 ~'~ 0.04 16 I 2.96 Shallow line of its.
79 2487 ~~ 0.06 2Z - 2.95 Line of its.
80 2519 n 0.05 1 ti 2.94 Shallow line of its.
81 2550 I! 0.06 23 2.95 Line of its.
82 2581 t! 0.05 18 I 2.95 Shallow line of its.
83 2612 t1 0.04 15 I 2.95 Shallow line of its.
84 2644 a 0.06 Z ~ I 2.95 Line of its.
85 2675 t! 0.05 1 I 1 2.94 Line of its.
86 2707 ~.r 0.06 z > ,' 2.94 Line of pits.
87 2738 I! 0.04 17 2.95 Shallow line of its.
88 2768 ~) 0.08 SU _' 2.94 Line of its.
89 2800 ~'~ 0.07 Z~ 2.96 Line of its.
90 2831 i) 0.04 1 7 ? 2.95 Shallow line of its.
91 2862 ~ i 0.06 ~' "1 I 2.96 Line of its.
92 2894 ~? 0.06 2-1 _' 2.94 Line of its.
93 2925 U 0.03 I ~ .? 2.93 Shallow line of its.
94 2956 I! 0.04 I b I 2.93 Shallow line of its.
95 2988 I! 0.06 2"~ I 2.96 Line of its.
96 3019 U 0.04 17 2.95 Shallow line of pits.
97 3050 ! t 0.05 1 f, 2.95 Shallow line of its.
98 3081 a 0.04 17 I 2.95 Shallow line of its.
99 3112 i! 0.04 1 7 2.95 Shallow line of its.
_ Penetration Body
Metal Loss Body
Page 2
•
PDS REPORT JOINT TABI
Pipe: 3.5 in 9.3 ppf L-80 EUE 8RD Well:
Body Wall: 0.254 in Field:
Upset Wall: 0.254 in Company:
Nominal LD.: 2.992 in Country:
Survey Date,
1LATION SHEET
1 C-133
West Sak
ConocoPhillips Alaska, Inc
USA
July 3, 2010
Joint
No. Jt. Depth
(Ft.} PE•n.
OI>.tic~l
{lips.) Pen.
Body
(Ins.) Pen.
~%~ Mci,rl
loss
`~ Min.
LD•
(Ins.)
Comments Damage Profile
(%wall}
0 50 100
100 3142 (? 0.05 2t~ 2.93 Line of pits.
101 3173 (? 0.05 19 .' 2.95 Shallow line of its.
102 3204 a 0.06 23 2.95 Line of its.
103 3235 !? 0.06 24 2.95 Line of its.
104 3266 !? 0.06 23 2.96 Line of its.
105 3297 (1 0.07 28 2.96 Line of its.
106 3329 a 0.06 ;' ~ - 2.96 Line of its.
107 3360 (~ 0.07 'u ~ 2.96 Line of its.
108 3392 0.06 Zit -' 295 Line of its.
109 3423 r.? 0.07 Zt3 2.96 Line of its. -
110 3454 (? 0.05 2t? -! 2.95 Shallow line of its. Lt. De osits. -
111 3484 (? 0.09 ~(~ 296 Line of its.
112 3516 i! 0.07 Zt~ 2.96 Line of its.
113 3547 r? 0.06 _'~ 2.94 Line of its.
114 3578 U 0.09 S5 ~' 2.95 Line of its. -
115 3610 U 0.07 Z'? i 2.95 Line of its. -
116 3641 i_1 0.06 ~'-1 -t 2.96 Line of its. -
117 3673 O 0.09 3.1 2.96 Line of its.
118 3704 ~? 0.08 i 1 _' 2.95 Line of its.
119 3735 U 0.09 35 2.95 Line of its.
120 3767 U 0.08 31 _' 2.94 Line of its.
121 3798 (? 0.07 30 :? 2.95 Linc of its.
122 3829 tt 0.07 ~t3 ~ 2.95 Line of its.
122.1 3861 (? 0.07 ~'t3 _' 2.93 PUP Line of its.
122.2 3866 (> 0 r) r? Z90 GLM 1 Latch (~ 5:30
122.3 3872 ~~ 0.02 ~; 2.93 PUP
123 3879 i! 0.09 >6 _' 2.94 Line of its.
123.1 3910 (! 0 U O 2.81 Camco DS Ni le
124 3912 (! 0.09 ib Z 2.95 Line of its.
124.1 3942 U 0.04 1 5 I 2.95 PUP Shallow ittin .
124.2 3948 (? 0 (? i1 3.00 Baker Seal Assembl
124.3 3961 U 0 n i? 4.00 Baker 12' SBE
124.4 3963 U 0.04 16 1 295 PUP Shallow line of its.
125 3972 (~ 0.10 3~i _' 2.93 Line of its.
126 4003 (? 0.08 ;i) ~' 2.95 Line of its.
127 4035 U 0.11 -t4 1 2.93 Perforations. Lt. De osits. -
128 4066 O.i!t~ 0.16 h4 - 293 Perforations. Lt. De osits. -
129 4098 O 0.14 i(, _' 2.91 Perforations. Sli ht Bucklin
130 4129 Li.(lt3 0."14 i i ~ 293 Perforations. Sli ht Bucklin .
_ Penetration Bodv
Metal Loss Body
Page 3
S PDS Report Cross Sections
'~4
Well: 1 C-133 Survey Date: July 3, 2010
Field: West Sak Tool Type: UW MFC 24 No. 214320
Cornpany: ConocoPhillips Alaska, Inc. Tool Size: 1.69
Country: USA No. of Fingers: 24
Tubing: 3.5 ins 9.3 ppf L-80 EUF 8RD Analyst: C. Lucasan
Cross Section for Joint 45 at depth 1444.417 ft
Tool speed = 44
Nominal ID = 2.992
Nominal OD = 3.500
Remaining wall area = 98 °%
Tool deviation = 14 "
Finger 18 Penetration = 0.108 ins
Line of pits 0.1 1 ins = 43% Wall Penetration HIGH SIDE = UP
Cross Sections page 1
PDS Report Cross Sections
~, s „
Well: 1 C-133 Survey Date: July 3, 2010
Field: West Sak Tool Type: UW MFC 24 No. 214320
Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69
Country: USA No. of Fingers: 24
Tubin 3.5 ins 9.3 f L-80 EUE 8RD Anal st: C. Lucasan
Cross Section for Joint 49 at depth 1551 ft
Tool speed = 43
Nominal ID = 2.992
Nominal OD = 3.500
Remaining wall area = 97 %
Tool deviation = 15 "
Finger 5 Penetration = 0.106 ins
Line of pits 0.1 1 ins = 42% Wall Penetration HIGH SIDE = UP
Cross Sections page 2
~~~ KUP 1 C-133
~OflOCO~"11~~IP5 ~ WeII Attributes Max An Ie 8 MD TD
.I.y,_,-y t
~
/ wellhx o-rl~uwl
I II Fl~ld rr<, ,e
7: E~ 'AK wvu smtt~ Incl I°I
IV_E[.TING ~r,4 Mo InKSI
t. +C2 n 1 ec mKe)
1 ~
-:
- .
~
~
~ -.c t
Sa J~:~NE - --- HIS pP „1
I,, C.,le Annotat~Dn EnA Data
,. I: ~;C Las[:: ~. r. KR-~_;r[I lttl
dr. Ri LIR I -CiTIB-
+~l,Jl
.~
~~i
" ` Annvl4hJn Depth lltK61 Ertl DUte
_a! Tag:: ~_M 4.'33.C ^:1C09 Annot~i[!on
R.,~: Reawl:: - - =ILL SLY1 Lint MVd BY
:rhvj Exf Date
7:6i2C0
Csain Strin s
I: ^SInO De3CIiDtion i Shing OD i Sttlnp ID
Iln) Ilnl
TCH, 1}tKBI Set Depth
ittKBl Set Depln INDj
IIiK6) String Wt
(Ih5:it1 Sirlhn
VI'Jtl¢
SDtIxI TDD ihltl
PP _ D u..T IC1N F _ 9_.3 I'J J l ! ,a. I ~ I r"I ~T -t.5;)C)
_INER 3 ,.,_ _.=~2J _~2.J e1g.Y ?.?l L-aJ E_:EB RD
Tuhtn Srinn s
I
Ttihn Deatf fion
. Gnrng IlD Gir nD In
lin) Ilnl
Tc ftKbl
4
rl 1 11ri
(ttKRl
car na1Kn iNn1
fItK6)
Kt ~"U lRR
111 5:1[1 .,
r~r~U
l+'Jfle
Su'il To Thrtl
.:~o:.c-oF. T)131Nr' 3 • '_ 352 n;l ~ ~ ;7 ~ r ;, r .~ -1c
_ I :~ .ECRG
_
o?_
F
~ Other I
Trip InKR) n Hole (
rov DePn,
(TVD)
(fIKB) All Jew
Top ItMI
t`) elry: Tubin
DovnpNn t~ Run & Ret rievable, Fltih, ste.)
~rnln rarr
lue nJm '
Cf lh,l
y~
'3 q-F
3_5. ~ 5
8J.0 i
5.3_ 4
C4.: _IF- .. ~ _ ETA 1
C:Ab1C _C'KBr_.q-5•I!DFr1Y~~NTti. t
' _ .2001 ?.570
3.5'.6 _.627 5 5 40 V iPPLE CAN CO'D9 NIPPLE ~s. r2 fi'2 NO ~tD P~
~I. ~n '!2C01 2.C~1~
- 35.15 3bf-F5 457 9EAL RAKER 9FgL AS8Eh13LY Fr?~2C~~1 ?.GCC
3.55'1 3. f.B:~.S 45.1 S3E BAKER lG'tiEE E?:2CC1 4.OJC
1.156 3.EIi7.2 26~ a_UG YdRP SET 1:2J l2C~C3 4~'~•?JC i. CACr
d,~71 n.317.8 7.88 SHOE LINER SrOE e'?rC01 _...
PerfOratlOne /t, SlOts
-
TOp (ftK61
BSfn IfIK6)
urolrvD)
IftKB)
Rrn,rrvDl
InK B)
ZrJ118
DJtc nx
t?~ns
(~~~•
TVpO
COnxnCIM1[
1+~-
, ~ -.._ 4.~3f ?70. - 3.757:." :S D. IC-t i3 E:'2:3i[COl ~.J I?CRF 2.5"H~-I UP.E ueg ph 3~. '_.J h+MX
.c.-i
s [_' _
~-
-II -. i 10
-. ~ =
G 4.146
i.l i 6 3 ?27~^_
3 871.= 3.907 2
}.353.'1 'r WS ~.G133
JS A4, iC- 133 -:2~~2 C01
5i2?i1001 = J
'.3 I%ERF
I'-ERF " ," H3D DP. FC cey ph iIJ '_:J HMY
`.5" H56 DP. oC tlu'g Ph. 31J UJ h+1r1:5
. ~ ~ =. 14 4236 3.13_'1 _?3 1 . 1'S A_a. 1C- 133 Oi23:2C01 ± J I^^-EnF 2S"HSD DP 60 deg Ph 31J 4.'J Hfdk'
-.212 1.22r. 3 425.1 3.?_"s.C Y VS q3. IG 133 n;2si2^u01 ~.] 1^ERF i.5"HSD UP. sC ceg ph
3BE.3 Gi-' _ ~ - d,~d~ 1 Fi-i? G 3.y55 C L VS /1.3. 1C 133 6'22i1Cp7 <.~ PERF 2.5" HSJ DP. SC ccy ph
FaooL'c 3orJ, _2r~] 4336 3+7r.v 4.3055 W4 A2 'I C-133 F~2?:2GJ1 50 Ia ERF 2S"H3D DP 6C deg Ph
P_oaa ~o
a,l nF+F.i
Y
PEF=.
.~y CE.4 n,-,~ -
T~.i CIS
Page 1 of 1
Maunder, Thomas E (DOA)
From: NSK Problem Well Supv [n1617@conocophillips.com]
Sent: Monday, June 14, 2010 9:06 AM
To: Brooks, Phoebe L (DOA); Maunder, Thomas E (DOA); Regg, James B (DOA); DOA AOGCC
Prudhoe Bay
Cc: NSK Problem Well Supv
Subject: RE: MIT Kuparuk River 1C-133 & 1C-10 05-21-10
Phoebe,
On well 1 C-133, both tests were a failure. It is not typical to report both when the result was the same on both.
The first test on 1C-10 was not reported due to it being invalid. The results from the second are the only
pressures that have validity towards the compliance testing.
Please let me know if you have any questions.
Brent Rogers/Martin Walters
Problem Wells Supervisor
ConocaPhillips Alaska, Inc.
Desk Phone (907) 659-7224
Pager (907) 659-7000 pgr. 909
From: Brooks, Phoebe L (DOA) [mailto:phoebe.brooks@alaska.gov]
Sent: Wednesday, June 09, 2010 9:44 AM
To: NSK Problem Well Supv
Cc: Regg, James B (DOA)
Subject: MIT Kuparuk River iC-133 & iC-10 05-21-10
Martin/Brent,
John Crisp submitted two test reports for well 1C-133 however, we only received one report from you. Please
submit the retest report for 1C-133 (I've attached the inspector's copy). There were also two MITIA test reports
for well 1C-10. Apparently, the first test was not tested at the right pressure amount and was retested using the
correct test pressure. We received the second test report but, not the first. Please submit this report as well
(inspector's copy attached).
Thank you,
Phoebe
Phoebe Brooks
Statistical Technician II
Alaska Oil and Gas Conservation Commission
Phone: 907-793-1242
Fax:907-276-7542
8/7/2010
Page 1 of 1
Maunder, Thomas E (DOA)
From: NSK Problem Well Supv [n1617@conocophillips.com]
Sent: Tuesday, May 25, 2010 $:21 AM
To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA)
Cc: NSK Well Integrity Proj; NSK Problem Well Supv; CPF1 Prod Engr; CPF1 DS Lead Techs;
Gangl, Melissa A; Hollar, Eric Andrew; Pierson, Chris R
Subject: 1 C-133 (PTD#201-077) Report Of Failed MITIA
Attachments: 1C-133 Wellbore Schematic.pdf; 1C-133 TIO Plot.pdf
Jim/Tom/Guy,
West Sak injector 1C-133 (PTD#201-077) failed a State Witnessed MITIA during a regularly scheduled 4 year
testing program. Stickline will troubleshoot and attempt to the repair as soon as reasonably possible. The well will
be shut in and freeze protected and will be added to the monthly report.
Attached is a 90 day TIO plot and wellbore schematic.
Please contact me at your convenience if you have questions or comments.
Martin
Martin Walters / Brent Rogers
Problem Wells Supervisor
ConocoPhillips Alaska Inc.
Office 907-659-7224
Cell 907-943-1720 / 1999
Pager 907-659-7000 #909
8/7/2010
Well Name 1 C-133 Notes: Repart Of Fail~c# ~~+~1 MITIA
End Date 6/1/2010
Days 120
Start Date 2'1 '2010
Annular Communication Surveillance
1600 ___..® ____ -- - -._ _.... ..._ - •- __.~___.-..----._ _~_ __ -_._ .__-~ 160
WHP
IAP
OAP - 140
1400 -
W HT _ _
- 120
1200
- - - 100
1000 _ _
LL
.Q 800 - - - - - - 80 ~
600 -- - - - - 60
- 40
400 ~
~ - - 20
200 -- --
0
0
Jan-10 Feb-10 Mar-10 Apr-10 May-10
aoo
~DGI
350
~MGI
300
o ~PWI
a 250
m
~SWI
LL zoo ~BLPD
-
~
~ ~ so I
ioo }
k
so
n - - f
MEMORANDUM
To: Jim Regg ~ / /Z~
P.I. Supervisor VI
FROM: John Crisp
Petroleum Inspector
State of Alaska
Alaska Oil and Gas Conservation Commission
DATE: Tuesday, May 25, 2010
SUBJECT: Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA INC
1C-133
KUPARUK RIV U WSAK IC-133
Src: Inspector
NON-CONFIDENTIAL
LJ
Reviewed Bye
P.I. Suprv ~.-15'2
Comm
Well Name: KUPARUK RIV U WSAK 1C-133 API Well Number: 50-029-23013-00-00 Inspector Name: John Crisp
Insp Num: mitJCr100523165511 Permit Number: 201-077-0 Inspection Date: 5/21/2010
Rel Insp Num:
Pretest Initial
Packer Depth 15 Min. 30 Min. 45 Min. 60 Min.
Wel~ 1C-133 Type Inj. ~TVD 3666 / IA _ ~~~
~ 2240 ~ 1780 /
P.T.D zolo770 ;TypeTest SPT Test psi ]soo ~ OA
IllterV814YRTST P~F F r Tubing 931 933 930 I
Notes: 1.1 bbl pumped for this failed MIT on monobore injector.
~~~
Tuesday, May 25, 2010 Page 1 of 1
i
MEMORANDUM
To: Jim Regg r
P.I. Supervisor ~ ~~~~ 1 ~O
FROM: John Crisp
Petroleum Inspector
•
State of Alaska
Alaska Oil and Gas Conservation Commission
DATE: Tuesday, May 25, 2010
SUBJECT: Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA INC
1 C-133
KUPARUK RIV U WSAK 1C-133
Src: Inspector
NON-CONFIDENTIAL
Reviewed By:
P.I. Suprv ~~
Comm
Well Name: KUPARUK RIV U WSAK 1C-133 API Well Number: 50-029-23013-00-00
Insp Num: mitJCr100523165121 Permit Number: 201-077-0
Rel Insp Num: Inspector Name: John Crisp
Inspection Date: 5/21/2010
Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
Well 1C-133 Type Inj. W TVD 3666 jA 1780 2240 ~ 1700
P.T.DI zo1o77o',TypeTest sPT Test psi ~~ lsoo pA ~
Interval a~TST p/F F Tubing 930 931 91a
Notes:. l bbl pumped for this MIT retest. Failed to pass MIT.
~~~ Z
tens ' .. r
Tuesday, May 25, 2010 Page 1 of 1
.
.
~
ConocoPhillips
Alaska
,JUL I) 3 2007
&
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
July 2,2007
Mr. Tom Maunder
Alaska Oil & Gas Commission
333 West ih Avenue, Suite 100
Anchorage, AK 99501
d-()\~ 011
5CANNED JUL 0 5 2007
Dear Mr. Maunder:
Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRD). 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.
4¡~
M.J. Loveland
ConocoPhillips Well Integrity Supervisor
c-------/-
.
.
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 PTD# cement pumped cement date inhibitor sealant date
ft bbls ft na gal
1 C-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
1C-133 201-077 16" none 16" na 8.5 7/1/2007
1C-190 ~ 203-003, 27" none 27" na 11I11I10 6/24/2007
[}'}Wbb} ~
3K-12 186-165 6" none 6" na 3
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
.
.
WELL LOG
TRANSMITTAL
ProActive Diagnostic Services, Inc.
To:
AOGCC
Howard Okland
333 West 7th Avenue
Suite 1 00
Anchorage, Alaska 99501
(907) 659-5102
t't", A~..'~,r)
~v,~··:¡J:I¡'i~
1 f~
.J,. t"""
RE : Cased Hole/Open Hole/Mechanical Logs and / or Tubing Inspection(Caliper / MTT)
The technical data listed below is being submitted herewith. Please acknowledge receipt by
returning a signed copy of this transmittal letter to the attention of :
ProActive Diagnostic Services, Inc.
Attn: Robert A. Richey
130 West International Airport Road
Suite C
Anchorage, AI< 99518
Fax: (907) 245-8952
.<'- ~)
()H ;1 Cons.
1) 1 Report
2) 1 Report
3) 1 Report
4) 1 Report
5) 1 Report
6) 1 Report
7)
Signed :
Print Name:
1C - 111 MTT Log
1C - 117 MTT Log
1 C - 127 MTT Log
1C - 133 MTT Log
10 - 114 MTT Log
10-117 MTT Log
10- Dec ~6 U"1 C- õìol - 1c9"Õ"
11- Dec ~6 UTe.. :JOI-I$ I
11- Dec ~6 U ..lC-.9ö l-II~/
12- Dec 06 t):r c.. 86 l - ó-=ï":)
08- Dec ~6 U1' c... tct ~ - tSC)
09- Dec ~6 U:rc... \DO ~
C.jj~
~/h r;~ ~O~ /YIf} ?1 v1 Ý'-l?1/1
Date: If:) / IS'!OG,.
PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518
PHONE: (907)245-8951 FAX: (907)245-8952
E-MAIL: ~":S_'_NG:-:Q:v,G=(ði;!i:}.'E:J?:·_-___)G_G:!:'jl
WEBSITE: 'Hi'PN.'JiEiJ1C?fI'-C<J.,:<>\1
D,OO _ PDSA'I C-2006\Z _ W ordlDistributionlTransmíttal_ Sheeis\Transmít. Origina!.doc
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Memory Magnetic Thickness Tool
Log Results Summary
Company: ConocoPhillips Alaska, Inc. Well: 1C-133
Log Date: December 12, 2006 Field: Kuparuk
Log No. : 8082 State: Alaska
Run No.: 1 API No.: 50-029-23013-00
Pipe1 Desc.: 3.5" 9.3 Ib L-80 EUE 8RD Top Log Intvl.: Surface
Pipe1 Use: Tubing Bot. Log IntvL: 191 Ft. (MD)
Pipe2 Desc.: 5.5" 15.5 Ib L-80 BTCM Top Log Intvl.: Surface
Pipe2 Use: Production Casing Bot. Log Intvl.: 191 Ft. (MD)
Pipe3 Desc.: 16" 62.58 lb. H-40 Welded Top Log Intvl.: Surface
Pipe3 Use: Conductor Pipe Bot. Log IntvL: 181 Ft. (MD)
Inspection Type: Assess External Corrosive Damage (Metal Loss) to Production Casing.
COMMENTS:
This MTT data is tied into the Mandrel Hanger @ 0' Depth.
This is the first log of this well with the 12 Arm Magnetic Thickness Tool (MTT). The Magnetic Thickness
Tool responds to the total thickness of metal of the 3.5" tubing and 5.5" production casing, with some
influence from the 16" conductor pipe.
Due to the concentric pipe strings in the log interval, the MTT response is qualitative - indicating an overall
increase or decrease in metal surrounding the tool, but not distinguishing in which pipe string the change in
metal thickness occurs. In this log, the MTT was calibrated down hole (70'), where the readings are
assumed to represent undamaged tubing and casing. All other readings are relative tp this reference point,
which include influences from the 3.5" tubing, 5.5" casing, and 16" conductor pipe.
INTERPRETATION OF MTT LOG RESULTS:
The MTT log results cover the interval from surface to 191'. A log plot of the entire pass, plus a detailed
section of any interval showing damage is included in this report. The Delta Metal Thickness (%) curve in
these plots refers to total metal surrounding the MTT tool.
A maximum 5% circumferential metal loss is recorded in the interval between 1.5' - 9'.
A 3% circumferential metal loss is recorded in the interval between 49' - 56'.
A 2% circumferential metal loss is recorded in the intervals between 22' - 32' and 35' - 37'.
A 15% isolated metal loss is recorded at 22'.
A 12% isolated metal loss is recorded at 31'.
The 10HZ recordings are slightly noisier than normal. However, the isolated metal loss features are
recorded in all three passes made in the interval logged. The percent circumferential metal loss expressed
in this report is a percentage of the total metal that the MTT tool is responding to, which includes influences
from the 3.5", 5.5" and 16" pipe. If all of the metal loss is specific to the 5.5" production casing, the percent
metal loss from that pipe alone is probably higher than the numbers expressed. Some of the metal loss
indicated could be from either the 3.5" tubing or 16" conductor.
I Field Engineer: R. Richey
Witness: C. Fitzpatrick I
Analyst: M. Tahtouh & J. Burton
PíQ/.\.ctive Seni!ŒS, Tile.
Phone: or (888) 565-9085 Fax:
Prudhoe Bay Field ()ffice Phone:
659-231",
u:r:~ gol-09"1
I cia
)5 Magnetic Thickness Tool (10Hz Pass)
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PROAcTIvE OiAq""""'¡C SERvicES, INC.
Database File: d\warrior\data\1c-133\1c-133.db
I Dataset Pathname: 10hz. 1
Presentation Format: 2.2 scale
Dataset Creation: Wed Dee 1309:36:552006 by Calc Sondex Warrior V70
Charted by: Depth in Feet scaled 1150
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Dataset Pathname: 10hz.1
Presentation Format: 2.2 scale
Dataset Creation: Wed Dee 13 09:36:55 2006 by Calc Sondex Warrior V7. 0
Charted by: Depth in Feet scaled 150
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Database File: d\warrior\data\1c-133 top 3 metalloss\1c-133.db
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1C-133
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11C-133
API: 500292301300
SSSV Type: None
TUBING
(0-3952,
00>3.500,
10:2.992)
Well Type: INJ
Orig 6/3/2001
Completion:
Last W/O:
Ref Log Date:
Angle @ TS: deg @
Angle @ TD: 1 deg @ 4615
I
Annular Fluid:
Reference
Loç¡:
Last T aç¡: 4153' RKB
Last Tag 10/18/2006
Date:
I·Çª$ n~i~t ' l'lg:~AI..I..:::,¡):.
Description
CONDUCTOR
PRODUCTION
PROD LINER
Rev Reason: TAG
Last Update: 1 0/28/2006
) RODUCTION
(0-3952,
OD5.500,
Wt:1550)
TD: 4615 ftKB
Max Hole 36 deg @ 2149
Angle:
I
Size
16.000
5.500
3.500
Top
o
o
3952
Bottom
181
3952
4602
TVO
181
3669
4319
wt
62.58
15.50
9.30
Grade
H~40
L-80
L-80
I
Thread
WELD
BTC-MOD
EUE8RD
NIP
(3910-3911,
003.780)
'::~:':
Size , Top I Bottom I TVO I wt I Grade I
3.500 0 I 3952 I 3669 I 9.30 , L-80 I
I
Thread
EUE8RD
Interval TVD
4050 - 4080 3767 - 3797
Zone
WSD
Status
Ft SPF Date 19 Comment
30 4 ~/23/2001 IP!=KF 2.5" HSD DP, 60 deg
ph 31J UJ HMX
4 6/23/2001IPERF 2.5" HSD DP, 60 deg
ph, 31J UJ HMX
4 6/23/2001 ¡PERF 2.5" HSD DP, 60 deg
ph, 31J UJ HMX
4 6/23/2001 /PERF 2.5" HSD DP, 60 deg
I ph, 31J UJ HMX
4 3/22/2001/PERF 2.5" HSD DP, 60 d~ ph
4 3/22/2001/PERF 2.5" HSD DP, 60 deg ph
4 j/22/2001/PERF 12.5" HSD DP, 60 deg ph
I
4110 - 4140 3827 - 3857
WSB
30
4154 - 4176 3871 - 3893
NIP
(3948-3949,
00:4.500)
WSA4
22
I
4196 - 4206 3913 - 3923
WSA3
10
4212 - 4226
4230 - 4242
4260 - 4330
1 GåS'i
St I MD TVD Man Man Type V Mfr I V Type I VOD LatCh I Port I TRO I Date I Vlv
Mfr Run Cmnt
1 13866 3584 CAMCO KBG-2-9 CAMCO I DMY 1 1.0 1 ¡NT 10.000 I 0 16/7/20011
I Other ...... "
Depth TVO Type
3910 3628 NIP
3948 3665 NI P
3949 3666 SEAL
3951 3668 SSE
4150 3867 PLUG
4599 4316 SHOE
3929 - 3943 WS A3
3947 - 3959 WS A3
3977 - 4047 WS A2
14
12
70
I
SEAl.
(3949-3951,
00:4000)
SBE
(3951-3952,
OD:5.000)
I
Perf
(4050-4080)
-.-
--
--
--
-
-
-
--
Description
CAMCO 'DS' NIPPLE w/2.812 NO GO Profile
BAKER NO GO SUB
BAKER SEAL ASSEMBLY
BAKER 12' SBE
WRP SET 4/20/2003
ID
2.812
3.000
3.000
4.000
0.000
2.992
-
I
-
-
Perf
(4110-4140)
-
--
-.-
I
I
PROD LINER
(3952-4602,
003500,
W(930)
Perf -'- 1--
(4154-4176) -'- 1--'--
-- I---
- f=
Perf -
(4196-4206) -- r-----
- -
'- -
Perf -- -
(4212-4226) - -"-
- --
- -
Perf - -
(4230-4242) - -.
-- -
Perf - -
= -
(4260-4330) ~..
-.- -
.....
I
I
I
I
I
I
12/06/06
Scbhlmberger
NO. 4061
Schlumberger -DCS
2525 Gambell Street, Suite 400
Anchorage, AK 99503-2838
A TTN: Beth
(~ÞA. !UIU~ífì
\.... 1..'. "'l;\1:~CL.,
n c 2I'>u·ni;
,0 ~d
Company: Alaska Oil & Gas Cons Comm
Attn: Christine Mahnken
333 West 7th Ave, Suite 100
Anchorage. AK 99501
u,.r~ dOl -077
Field:
Kuparuk
.
Well
Job#
Log Description
Date
BL
Color
CD
1G-16 11486083 INJECTION PROFILE 11/26/06 1
1C-133 11486084 INJECTION PROFILE 11/27/06 1
1 R-20 11486085 LDL 11/28/06 1
10-05 11486086 INJECTION PROFILE 11/29/06 1
1 D-03 N/A SBHP 11/25/06 1
1 D-09 N/A SBHP 11/25/06 1
2T-18 11477636 INJECTION PROFILE 12/01/06 1
1 R-03A 11483497 INJECTION PROFILE 11/30/06 1
2X-03 11483499 INJECTION PROFILE 12/02/06 1
1 E-04 11477639 INJECTION PROFILE 12/04/06 1
.
Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you.
MEMORANDUM
e
State of Alaska
e
Alaska Oil and Gas Conservation Commission
TO:
Jim Regg ?1, /' ,~/.~..,
P.I. Supervisor I ì~l"{ .J,c...;/'ì.1..r.)
DATE: Monday, May 22, 2006
SUBJECT: Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA INC
IC-133
KUPARUKRIVUWSAK IC-133
dJJ~-o77
FROM:
Jeff Jones
Petroleum Inspector
Src: Inspector
Reviewed By:
P.I. Suprv:7ßr2--
Comm
NON-CONFIDENTIAL
Well Name: KUPARUK RIV U WSAK IC-133 API Well Number 50-029-23013-00-00
Insp Num: mitJJ060508183705 Permit Number: 201-077-0
Rei Insp Num
Inspector Name: Jeff Jones
Inspection Date: 5/8/2006
Packer
Well : IC-133 ¡Type Inj. I W I TVD
P.T. ! 2010770 ,TypeTest i SPT i Tes!J)si¡
Interval 4YRTST P/F P
Depth
3666
Pretest
Initial
1500
I IA ~
lOA
, I
Tubing'
o
2100
15 Min. 30 Min. 45 Min.
I 2090 2075 2070
i
60 Min.
--
--
1170
1170
1168
1168
1164
_.L
Notes 0.8 bbls diesel pumped. Monobore injector. I well house inspected; no exceptions noted.
°iGANi\lEY, ,)
{' ~
Monday, May 22, 2006
Page I of I
e
e
ConocoPhillips Alaska, Inc. KRU 1 C-133
TUBING 1C-133
API: 500292301300 Well Tvee: INJ Anole @ TS: dea@
(O-J952, SSSV Type: None Orig 6/3/2001 Angle @ TD: 1 deg @ 4615
00:3.500, Comeletion:
10:2.992) Annular Fluid: Last W/O: Rev Reason: Set WRP
~OOUCTION I Reference Lon: RefLoa Date: Last Undate: 4/21/2003
(0-3952, Last Tan: 4463 TD: 4615 ftKB
00:5.500, Last Tan Date: 11/5/2001 Max Hole Anale: 36 dea tâ) 2149
WI: 15.50) Casina Strina . ALL STRINGS
DescriDtion Size Too Bottom TVD Wt Grade Thread
CONDUCTOR 16.000 0 181 181 62.58 H-40 WELD
PRODUCTION 5.500 0 3952 3669 15.50 L-80 BTC-MOD
PROD LINER 3.500 3952 4602 4319 9.30 L-80 EUE8RD
Tubina Strina . TUBING
Size 1 Top I Bottom I TVD I Wt 1 Grade I Thread
NIP 3.500 1 0 I 3952 I 3669 I 9.30 I L-80 T EUE8RD
(3910-3911, I - Peñorations Summarv
00:3.780) Interval TVD Zone Status Ft SPF Date Tvae Comment
4050 - 4080 3767 - 3797 WSD 30 4 6/23/2001 IPERF 2.5" HSD DP, 60 deg ph,
31J UJ HMX
4110 - 4140 3827 - 3857 WSB 30 4 6/23/2001 IPERF 2.5" HSD DP, 60 deg ph,
31J UJ HMX
4154 - 4176 3871 - 3893 WSA4 22 4 6/23/2001 IPERF 2.5" HSD DP, 60 deg ph,
31J UJ HMX
4196 - 4206 3913 - 3923 WSA3 10 4 6/23/2001 ¡PERF 2.5" HSD DP, 60 deg ph,
NIP 31J UJ HMX
4212 - 4226 3929 - 3943 WSA3 14 4 6/22/2001 IPERF 2.5" HSD DP, 60 dea eh
(3948-3949, 4230 - 4242 3947 - 3959 WSA3 12 4 6/22/2001 IPERF 2.5" HSD DP, 60 dea eh
00:4.500) 4260 - 4330 3977 - 4047 WSA2 70 4 6/22/2001 IPERF 2.5" HSD DP, 60 dea eh
Gas Lift MandrelsNalves
St I MD I TVD I ~~~ Man I V Mfr I V Type I V OD I Latch 1 Port I TRO I ~:~ I C~~t
SEAL Type
1 ì 3866T 35841 CAMCO KBG-2-9 I CAMCO I DMY I 1.0 liNT I 0.000 T 0 16/7/2001 I
(3949-3951, Other luas, eauiD., etc. . JEWELRY
00:4.000) Death TVD Type Descriation ID
SBE 3910 3628 NIP CAMCO 'DS' NIPPLE w/2.812 NO GO Profile 2.812
(3951-3952, 3948 3665 NIP BAKER NO GO SUB 3.000
00:5.000) 3949 3666 SEAL BAKER SEAL ASSEMBLY 3.000
Perf - - 3951 3668 SBE BAKER 12' SBE 4.000
(4050-4080) - - 4150 3867 PLUG WRP SET 4/20/2003 0.000
- - 4599 4316 SHOE 2.992
- -
Perf - -
(4110-4140) - -
- -
PROO
LINER
(3952-4602,
00:3.500,
Wt:9.30)
Perf - -
(4154-4176) - -
- -
- -
Perf - -
(41964206) - -
- -
- -
Perf - -
(4212-4226) - -
- -
- -
Perf - -
(4230-4242) - -
- -
- -
Perf - -
(4260-4330) - -
- -
-- --
e
e
MICROFILMED
07/25/06
DO NOT PLACE
ANY NEW MATERIAL
UNDER THIS PAGE
F:\LaserFìch~\CvrPgs _ Inserts\Microfihn _ Marker. doc
)
)
MEMORANDUM
State of Alaska
Alaska Oil and Gas Conservation Commission
TO:
Jim Regg
P.I. Supervisor
,"';"}
\<;;, a~ '1 f¡ b(ù 5"
DATE: Friday, September 16,2005
SUBJECT: Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA mc
I C-133
KUPARUK RIV U WSAK IC-133
.,/'
01 '
{JJJ \~
FROM:
John Spaulding
Petroleum Inspector
Src: Inspector
Reviewed By:
P.I. Suprv ..::::1Ei2-
Comm
NON-CONFIDENTIAL
Well Name: KUPARUK RIV U WSAK lC-l33 API Well Number 50-029-23013-00-00
Insp Num: mitJS050915202309 Permit Number: 201-077-0
Rei Insp Num
Inspector Name: John Spaulding
Inspection Date: 9/12/2005
Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
Well I IC-133 Type Ini:- N TVD -I 3666 IA 700 700 700 ~----I--- I
P.T. I 2010770 ITypeTest SPT Test psi I 916.5 OA 60 1730 1670 1660 i
I ---+-
Interval INITAL P/F P Tubing i i
Notes Monobore
5CANNEt NO'ß Ü ~ 2005,
Friday, September 16,2005
Page 1 of 1
)
)
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
Mechanical Integrity Test
OPERATOR:
FIELD I UNIT I PAD:
DATE:
OPERATOR REP:
AOaCC REP:
ConocoPhillips Alaska Inc.
West Sak I KRU/1 C
07127/05
Rodgers - AES
I"
rí '17ì ,0,)
~q d
~~j--rrJ?l
Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us
Packer Depth Pretest Initial 15 Min. 30 Min.
Well 1C-131 Type Inj. N TVD 3,705' Tubing 0 2050 1850 Interval 0
P.T.D.2011850 Type test P Test psi 1500 Casing 0 0 0 0 P/F F
Notes: Mono-Annulus Integrity Verification MITT with plug in tbg.
We1l1C-131 Type Inj. N TVD 3,705' Tubing 1850 2000 1960 1950 Interval 0
P.T.D. 2011850 Type test P T est psi 1500 Casing 0 0 0 0 P/F P
Notes: Mono-Annulus Integrity Verification MITT 2nd bump up test with plug in tbg.
We1l1C-131 Type Inj. N TVD 3,705' Tubing 1800 2000 2000 2000 Interval 0
P.T.D. 2011850 Type test P T est psi 1500 Casing 0 2500 2450 2440 P/F P
Notes: Mono-Annulus Integrity Verification MITIA with plug in tbg.
Well 1 C-133 Type Inj. N TVD 3,666' Tubing 0 2060 2010 2010 Interval 0
P.T.D. 2010770 Type test P Test psi 1500 Casing 0 0 0 0 P/F P
Notes: Mono-Annulus Integrity Verification MITT with plug in tbg.
We1l1C-133 Type Inj. N TVD 3,666' Tubing 1900 2130 2125 2100 Interval 0
P.T.D. 2010770 Type test P Test psi 1500 Casing 0 2550 2475 2460 P/F P
Notes: Mono-Annulus Integrity Verification MITIA with plug in tbg.
Test Details:
SCA~.\H\!E[) AUG 0 9 2.00~)
TYPE INJ Codes
F = Fresh Water Inj
G = Gas Inj
S = Salt Water Inj
N = Not Injecting
TYPE TEST Codes
M = Annulus Monitoring
P = Standard Pressure Test
R = Internal Radioactive Tracer Survey
A = Temperature Anomaly Survey
D = Differential Temperature Test
INTERVAL Codes
I = Initial Test
4 = Four Year Cycle
V = Required by Variance
T = Test during Workover
0= Other (describe in notes)
MIT Report Form
Revised: 06/19/02
2005-0727 _MIT _KRU_1 C-133_MITT.xls
)
)
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
Mechanical Integrity Test
Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us
OPERATOR:
FIELD I UNIT I PAD:
DATE:
OPERATOR REP:
AOGCC REP:
ConocoPhillips Alaska Inc.
West SakI KRU/1C
07127/05
Rodgers - AES
¡y, "'!1~""1>;
, "..,ii&!, ' '¡¡!Ii'" f i
l),~~t,-'
;;~ 1l~7Iò)
Packer Depth Pretest Initial 15 Min. 30 Min.
Well 1C-131 Type Inj. N TVD 3,705' Tubing 0 2050 1850 Interval 0
P.T.D. 2011850 Type test P T est psi 1500 Casing 0 0 0 0 P/F F
Notes: Mono-Annulus Integrity Verification MITT with plug in tbg.
Well 1 C-131 Type Inj. N TVD 3,705' Tubing 1850 2000 1960 1950 Interval 0
P.T.D. 2011850 Type test P T est psi 1500 Casing 0 0 0 0 P/F P
Notes: Mono-Annulus Integrity Verification MITT 2nd bump up test with plug in tbg.
Well 1C-131 Type Inj. N TVD 3,705' Tubing 1800 2000 2000 2000 Interval 0
P.T.D. 2011850 Type test P T est psi 1500 Casing 0 2500 2450 2440 P/F P
Notes: Mono-Annulus Integrity Verification MITIA with plug in tbg.
Well 1 C-133 Type Inj. N TVD 3,666' Tubing 0 2060 2010 2010 Interval 0
P.T.D. 2010770 Type test P T est psi 1500 Casing 0 0 0 0 P/F P
Notes: Mono-Annulus Integrity Verification MITT with plug in tbg.
Well 1 C-133 Type Inj. N TVD 3,666' Tubing 1900 2130 2125 2100 Interval 0
~ P.T.D. 2010770 Type test P T est psi 1500 Casing 0 2550 2475 2460 P/F P
Notes: Mono-Annulus Integrity Verification MITIA with plug in tbg.
Test Details:
TYPE INJ Codes
F = Fresh Water Inj
G = Gas Inj
S = Salt Water Inj
N = Not Injecting
TYPE TEST Codes
M = Annulus Monitoring
P = Standard Pressure Test
R = Internal Radioactive Tracer Survey
A = Temperature Anomaly Survey
D = Differential Temperature Test
MIT Report Form
Revised: 06/19/02
2005-0727 _MIT _KRU_1 C-133_MITT.xls
INTERVAL Codes
I = Initial Test
4 = Four Year Cycle
V = Required by Variance
T = Test during Workover
o = Other (describe in notes)
)) J~.,^> ~ô(~)
DATA SUBMITTAL COMPLIANCE REPORT
5/12/2004
.spu-¿ ~J~ À.U~ l
Permit to Drill 2010770
Well Name/No. KUPARUK RIV U WSAK 1C-133
Operator CONOCOPHILLlPS ALASKA INC
MD 4615--
Completion Date 6/22/2001 ~
Completion Status 1WINJ
WD 4332---
------
REQUIRED INFORMATION
Mud Log No
Samples No
--,-----~--
DATA INFORMATION
Types Electric or Other Logs Run:
Well Log Information:
Log/ Electr
Data Digital Dataset
Type rJled/Fnnt Number Name
~T ~8
i
! Log Gamma Ray
! Log Temperature
! ~ ~asing collar locator
!~ ~sure
I
i ¡Log ~~a TVD Log
.4-
I
¡ Log
~-
~
Log Log Run
Scale Media No
",JDjeétion Profile
25 Blu
1 Blu
5 BS
5 BS
~/ FINAL
5 BS 1
Blu
Blu
1
1
Expressl DEN/ CNL ~5
1
FINAL
Por
Current Status 1WINJ
API No. 50-029-23013-00-00
Q
Directional Survey ~
(data taken from Logs Portion of Master Well Data Maint)
Interval OHI --.,.../
Start Stop CH Received Comments
158 4602 Open 7/13/2001 158-4602
161 4615 Open 6/24/2002
3850 4141 Case 7/26/2002
¡,,){) 0 4375 Case 5/17/2002
400 4375 Case 5/17/2002
158 4602 Case 7/11/2001 ~-4602.5 BL, Sepia
~ 4375 Case 5/17/2002
3850 4141" Case 7/26/2002
3850 4141 Case 7/26/2002
3350 4591 Case 7/13/2001 3350-4591.6 BL, Sepia
¡ Log Induction/Resistivity 25 Blu 1 161 4615 Open 6/24/2002
I
! Log Cement Bond Log/PSP/SCMT 5 FINAL 3773 4474 Case 7/13/2001 3773-4474 Color Print -----
iLkÓg c-e--amma Ray 5 BS 1 CAt)0 4375 Case 5/17/2002
!~" ~binable Magnetic 5: . - FINAL ~- 4567 Case 7/13/2001 3350-4567 BL, Sepia
esonance
~ Platform Express Array Inducti ~ FINAL 158 4602 Case 7/13/2001 158-4602.5 BL, Sepia
¡Log CMR/ NEU/ DEN 1 FINAL 3290 4580 Case 6/15/2001 3290-4580 BL, Sepia
i
I 4t605 See Notes
I~ 161 4615 Open 6/24/2002 LDWG - LIS TIF file and
! graphic image files
i Log Gamma Ray 25 Blu 161 4615 Open 6/24/2002
f " Cio-táå
~ FINAL 158 4602 Open 7/13/2001 158-4602, Digital Data
! Log Induction/Resistivity 25 Blu 161 4615 Open 6/24/2002
I -
0-(og "-=r'emperature 5 BS U-OO 4375 Case 5/17/2002
~_. .-- - .--- - -----
DATA SUBMITTAL COMPLIANCE REPORT
5/12/2004
Permit to Drill 2010770
Well Name/No. KUPARUK RIV U WSAK 1C-133
Operator CONOCOPHILLlPS ALASKA INC
MO 4615
TVO 4332
Well Cores/Samples Information:
Name
ADDITIONAL INFORM~ION
Well Cored? Y ~
Chips Received? ,- Y I N ~
Analysis
Received?
..J..LN--
Comments:
Compliance Reviewed By:
Completion Date 6/22/2001
Completion Status 1WINJ
1~
Interval
Start Stop
Sent
Received
Daily History Received?
Formation Tops
Current Status 1WINJ
Sample
Set
Number Comments
<0:N
~/N
Date:
API No. 50-029-23013-00-00
UIC Y
--'
l:3 ~ ~LoA1
"~
Field:
Date BL Sepia
07/08/02 1
07/05/02 1
07/07/02 1
07/03/02 1
07/01/02 1
07/09/02 1
07/02/02 1
06/30/02 1
07/04/02 1
07/07102 1
06/08102
Schlumberger
Schlumberger Technology Corporation, by and through is Geoquest Division
3940 Arctic Blvd, Suite 300
Anchorage, AK 99503-5711
A TTN: Beth
~
Well
Job#
Log Description
1 C-131 ~Ö '-1 ~S INJECTION PROFILE
1C-133 PlOl- OiÎ INJECTION PROFILE
1F-02 fiG-d.JI SBHP
1Q-15 1 ~5-ot,J{¡, SBHP
2G-03 I <ß'Lf- ~q INJECTION PROFILE
2H-15 J c:zrl.J - O~ lo INJECTION PROFILE
2K-08 I ~9 -0 ~ ~ PRODUCTION PROFILE
2K-27 .;?O /- liD ~ GLS
2X-13 /'ìf4,../Î4 PRODUCTION PROFILE
3C-15 1 ~ 5,..ò\oo SBHP
1D-103 ~o~-o'1ln 22319 USIT
-
5IGN~7~ ~ ~
DATE:
07/23/02
NO. 2255
Company: Alaska Oil & Gas Cons Comm
Attn: Lisa Weepie
333 West 7th Ave, Suite 100
Anchorage, AK 99501
Kuparuk
CD
Color
RECEIVED
JUL 2 6 2002
Alaska OJ-¡ & Gas Cons. Commission
Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. Anchorage
05/16/02
Scblum_erger
Well
NO. 2082
Company: Alaska Oil & Gas Cons Comm
AUn: Lisa Weepie
333 West 7th Ave, Suite 100
Anchorage, AK 99501
Field: Kuparuk
Date BL Sepia CD Color
04/14/02 1 1
04/14/02 1 1
04/14/02 1 1
04/11/02 1 1
04/11/02 1 1
04/18/02 1 1
04/18/02 1 1
04/21/02 1 1
04/16/02 1 1
04/19/02 1 1
04/23/02 1 1
04/15/02 1 1
04/13/02 1 1
Schlumberger Technology Corporation, by and through is Geoquest Division
3940 Arctic Blvd, Suite 300
Anchorage, AK 99503-5711
ATTN: Beth
"..-
1 C-119
1 C-133
1 C- 133
1 D-1 09
1 D-119
1 D-132
1 D- 132
1 R-35
2D-02
2P-431
2T-39
3B-14
3C-15
~.
Job#
Log Description
~() -/~q DRIFT & TAG
~J-O 71 PRESSURE/TEMP LOG
.j., INJECTION PROFILE
Jq 7-~:<~ STATIC BOTTOM HOLE PRESSURE
aDJ-r~ q STATIC BOTTOM HOLE PRESSURE
Jq? - J ;:). 1 TEMPERATURE WARMBACKS
.v INJECTION PROFILE
aD) - rl'O PRESSURE TEMPERATURE
J'?l/-/'SJ PRESSURE-TEMP STATIONS
aDd -o~ ?- PERF RECORD/STATIC SURVEY
rlDJ-/R'..~ PRODUCTION PROFILE
J9s-oat./ PRESSURE/TEMP LOG
/ <g'5"'~Dl'\ PRESSURE/TEMP
RC;t:IVED
SIGN~ {J. (1(lýx:J
,',1 ~.y 1 -; 2002
1'"""\' I
AJaskaOU& Gas Cons.Commisston
Anchorage
DATE:
Please sign and return one copy of this transmittal to Sherrie at the åbove address or fax to (907) 561-8317. Thank you.
)
~PHILLlPS Alaska, Inc.
~ A Subsidiar.y of PHILLIPS PETROLEUM COMPANY
)
Post Office Box 100360
Anchorage, Alaska 99510-0360
C. Mallary
Phone (907) 265-6434
Fax: (907) 265-6224
December 17, 2001
Commissioner Cammy Oechsli Taylor
State of Alaska
Alaska Oil & Gas Conservation Commission
333 West ih Avenue Suite 100
Anchorage, Alaska 99501
Subject: Completion Report for 1C-133 (201-077)
Dear Commissioner:
Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the West
Sak well1C-133.
If you have any questions regarding this matter, please contact Steve McKeever at 265-6826.
/~'¿{gJ! %A/[Mf
C. Mallary 7
Drilling Engineering Supervisor
P AI Drilling
CMlskad
RECEIVED
nEn 1 " zon1
!~i : l, t u
,~ìaska Oil & Gas Cons. Commission
:~nchorage
OR\G\NAL
) STATE OF ALASKA )
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
Oil 0 Gas 0 Suspended D Abandoned D Service 0 i1«A~;T
2. Name of Operator ~ 'l/ftnft&Ð
3. ::~:~ Alaska, Inc. ~ s.~.. ." ~
P. O. Box 100360, Anchorage, AK 99510-0360 WQ.t,,-~~., .r
~1'1IfIIIN'ft1rf'i:o"!
4. Location of well at surface .:::,o:;e8¡;;'.~
1690' FNL, 997' FWL, Sec. 12, T11 N, R10E, UM (ASP: 562005, 5968547);1).k:'-;~ ..' , ,j
At Top Producing Interval ~. .k..,."-?::~:.~~1 ~
2434' FSL, 1028' FWL, Sec. 12, T11 N, R10E, UM (ASP: 562047, 5967391)j\ '~'~':;::T~DJ ';¡
At Total Depth ~ "_.A'£"_.,,,~..,..1
2421' FSL, 1027' FWL, Sec. 12, T11 N, R10E, UM (ASP: 562046, 5967378)~'
5. Elevation in feet (indicate KB, OF, etc.) 6. Lease Designation and Serial No.
RKB 41.2', 102' AMSL ADL 25649 ALK 467
12. Date Spudded 13. Date T.D. Reached 14. Date Comp.z.~sp. Or Ab~nd.
May 25, 2001 May 28, 2001 June;r,--2001 ~~
17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey
4615' MD / 4332' TVD 4500' MD /4217' TVD YES 0 No D
22. Type Electric Dr Other Logs Run
AIT/Den/Neu/CMR, SCMT
23.
1. Status of well
CASING SIZE
16"
5.5"
3.5"
WT. PER FT.
62.5#
15.5#
9.3#
GRADE
H-40
L-80
L-80
Classification of Service Well
Water Injector
7. Permit Number
201-077/
8. API Number
50-029-23013-00
9. Unit or Lease Name
Kuparuk River Unit,
10. Well Number
1 C-133
11. Field and Pool
West Sak Oil Pool
Kuparuk River Field
15. Water Depth, if offshore 16. No. of Completions
N/ A feet MSL 1
20. Depth where SSSV set 21. Thickness of Permafrost
N/A feet MD 1813'
CASING, LINER AND CEMENTING RECORD
SETTING DEPTH MD
TOP BOTTOM
Surface 158'
Surface 3951'
3951' 4600'
HOLE SIZE
CEMENTING RECORD
332 sx AS 1
450 sx AS IIIL, 330 sx Class G
included above
AMOUNT PULLED
24"
7.875"
7.875"
24. Perforations open to Production (MD + TVD of Top and Bottom and
interval, size and number)
4212' - 4226' MD
4230' - 4242' MD
4260' - 4330' MD
4196' - 4206' MD
4154' - 4176' MD
4110' - 4140' MD
4050' - 4080' MD
3929' - 3943' TVD
3947' - 3959' TVD
3977' - 4047' TVD
3913' - 3923' TVD
3871' - 3893' TVD
3827' - 3857' TVD
3767' - 3797' TVD
Date First Production
Date of Test
Hours Tested
Flow Tubing
Casing Pressure
28.
25.
SIZE
TUBING RECORD
DEPTH SET (MD)
3963'
PACKER SET (MD)
N/A
3.5"
4 spf
4 spf
4 spf
4 spf
4 spf
4 spf
4 spf
26.
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED
NIA
PRODUCTION TEST
Method of Operation (Flowing, gas lift, etc.)
Injector
Production for OIL-BBL
Test Period>
Calculated
GAS-MCF
W A TER-BBL
CHOKE SIZE
GAS-OIL RATIO
OIL -BBL
GAS-MCF
W A TER-BBL
OIL GRAVITY - API (corr)
24-Hour Rate>
Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips.
CORE DATA
N/A
Form 10-407 Rev. 7-1-80
R,ECEIV~ED
nE-(~ 1" Q ?nn1
.., \.,. \..' L U l. ¡
Alaska OJ¡ & Gas Con~. Commission
.{\.nchorage
CONTINUED ON REVERSE SIDE
Submit in duplicate
0 R \ G \ N A LBBDMS BFl
DEC 2 ì 2001
0~
29.
)
30.
)
GEOLOGIC MARKERS
FORMATION TESTS
NAME
MEAS.DEPTH
TRUE VERT. DEPTH
Include interval tested, pressure data, all fluids recovered and gravity.
GOR, and time of each phase.
Ugnu C
Top West Sak D
Base West Sak
3444'
4048'
4466'
3175'
3765'
4183'
Annulus left open - freeze protected with diesel.
31. LIST OF ATTACHMENTS
Summary of Daily Operations, Directional Survey
32. hat the following is and correct to the best of my knowledge.
f{,. ¡1t¿./&.¡
Title Drillinq Enqineerinq Supervisor
Questions? Call Steve McKeever 265-6826
Signed
Date
J;L/¡7hJ
C. Mallary
Prepared by Steve McKeever
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. RECEiVED
Item 28: If no cores taken, indicate "none-.
DEC 1 8 2001
Fonn 10-407
OR\G\NAL
¡~iaska Oil & Gas Cons. Gommissicm
Anchorage
)
)
Legal Well Name: 1 C-133
Common Well Name: 1 C-133 Spud Date: 5/25/2001
Event Name: ROT - DRILLING Start: 5/15/2001 End:
Contractor Name: Nabors Rig Release: Group:
Rig Name: Nabors 245 Rig Number: 245
Date From;.To Houts Code sUb . Description pf pþerati()ns
Code
5/15/2001 00:00 - 12:00 12.00 MOVE MOB MOBMIR Raise & secure stomper, Move Drilling module & utility module off mats.
Install king pin plates. Move drilling module towards 1 C pad.
12:00 - 00:00 12.00 MOVE MOB MOBMIR Fuel & service Lampsons. Move drill module from 1 J towards. Fix
hydraulic leak @ 1 D. Allow traffic to pass rig. Fix anti freeze leak @
spine road. Replace oil cooler on #2 Lampson, right track engine.
Repair air leak on #1 Lampson.
5/16/2001 00:00 - 12:00 12.00 MOVE MOB MOBMIR PJSM on rig move. Move drill Module to KOC. Service & fuel
Lampson's. Let traffic by @ KOC. Continue move to 1 C. Replace teflon
pad on crib block #1 Lampson. Drill module @ 1C @ 1200 hrs.
12:00 - 00:00 12.00 MOVE MOB MOBMIR Fuel Camp, cpm, drill module.PJSM on moving rig. Move utility module
f/1 J pad towards 1 C. Moved 3.8 miles @ midnight.
5/17/2001 00:00 - 12:00 12.00 MOVE MOB MOBMIR Move Utility Module to KOC, Turn around at KOC, Allow traffic to pass
rig, Service Lampson's, Replace keeper pins in primary chain, Replace
keeper in track pin. Move to 1 C. On pad @ 10:00 hrs (8.4 miles total).
Pull king pins plates Parallel module & place on mats. Pull king pin
plates on Drill module, parallel module on mats & spot over hole.
12:00 - 00:00 12.00 MOVE MOB MOBMIR Finish spotting rig over hole. Lock stomper into place, drop cellar Jack
rig onto cantilever. Center rig over well with plumb bob. Set down
drilling module, Mate up utility module wI Drill module, set down utility
module. Hook up interconnects, service lines ect.
5/18/2001 00:00 - 12:00 12.00 MOVE RURD MOBMIR Hook up service lines & steam to utility module. Assemble mud ends on
mud pumps. Hook up flow line, fill up line between modules. Prep lifting
eyes for MPI inspection. Hook up choke line, Hi press mud line, cement
line. adjust V-door ramp. Raise cellar & hang on safety lines. Build
ramp for load test. Load test bridge crane in cellar. Remove ramp,
reinstall seals for cellar.
12:00 - 00:00 12.00 MOVE RURD MOBMIR Set down cellar & adjust same for level. Magnaflux padeyes under
rotary table. Hook up hydraulics to BOP lifting system, pull test BOP
lifting system. Hook up gylcol between floor & subHook up hydraulic
lines to stabbing board. Hook up kill & choke lines & blind flange same.
Wire up Top dDrive electrical service loop. Dress Brandt shakers. Instal
rollers on block dolly.
5/19/2001 00:00 - 12:00 12.00 MOVE RURD MOBMIR Finish installing rollers on block dolly. Rig up & test kill line, fix unibolt,
4" Oteco valve, (2) National ball valves, Test line to 250 & 5000 psi. Rig
down test equipment blow down lines. Hook up hydraulics to Top Drive.
Continue wiring up Top Drive control power. Move equipment to rig
floor, clear out pipe shed. Clean rig.
12:00 - 00:00 12.00 MOVE RURD MOBMIR Install shims on roller for block cradle. Finish wiring up control power for
Top Drive. Check all functions on top drive. Connect hydraulic hoses for
power tongs, Load pipeshed wI DP. Work on #2 boiler (wash out scale)
Remove auto fill shut off on water tank. Clean rig
5/20/2001 00:00 - 12:00 12.00 MOVE RURD MOBMIR PJSM. Finish installing shims in Top Drive rails. Rig up break out tongs
wI load cell. Check Top Drive torque output (OK). Make up upper IBOP,
double pin sub to 50k ftIIbs. Install upper IBOP actuator & function test
same. Clean threads & rabbit DP. Install 2, explosion proof boxes on
bridge crane for controls. Work on suction manifold for mud pumps.
Install locking ring on upper IBOP. Start installing Clamps on Top Drive.
12:00 - 00:00 12.00 MOVE RURD MOBMIR PJSM. Finish installing clamps on Top Drive. Check wear on #1 disc-flo
pump. Check suction lines on disc-flo manifold for blockage. Continue
rabbiting DP. TUrn stand pipe towards C section for kelly hose
clearance. Safety check on derrick. General housekeeping.
5/21/2001 00:00 - 12:00 12.00 MOVE RURD MOBMIR PJSM. Dress iron ruffneck to 3-1/12" Inspect derrick lights & install
Printed: 6/28/2001 3:43:43 PM
')
-)
Legal Well Name: 1 C-133
Common Well Name: 1 C-133 Spud Date: 5/25/2001
Event Name: ROT - DRILLING Start: 5/15/2001 End:
Contractor Name: Nabors Rig Release: Group:
Rig Name: Nabors 245 Rig Number: 245
Date From-To. - -Hours Cöde- Sub . phase . DesÞriptionofQperatiöns.
Code
5/21/2001 00:00 - 12:00 12.00 MOVE RURD MOBMIR safety cables where needed. Prep 21-1/4" annular for installation, install
3" cellar pump, hook up lines to cellar. Work on commissioning Top
Drive. Inspect & hook up geronimo line. Install 4" ball valves & fittings
on conductor. General housekeeping.
12:00 - 00:00 12.00 MOVE RURD MOBMIR PJSM. String up geolograph line. Help electrician & mechanic
troubleshoot RPM gauge on Top Drive, hook up purge air to Top Drive.
Rig up Baker MWD screens. Install safety line on board. Change out 4"
Baylon valve on Discflo manifold. Put #2 boiler together after visual
inspection by motorman. Dress 4-3/4" DC slips. Install kelly hose on
TOp Drive. General housekeeping.
5/22/2001 00:00 - 12:00 12.00 MOVE RURD MOBMIR PJSM. Rig up to test IBOP's, kelly hose, standpipe manifold, floor
safety valves. Test IBOP's, Floor safety valves to 250 psi & 5000 psi
(upper IBOP failed). Begin removing IBOP & actuators. Blow down Top
Drive & RID test equipment. Stack DSA, diverter spool, 21-1/4" annular
on speed head. Mix spud mud. Rig up new pull back line for V-door.
Note; held diverter drill wI crew
12:00 - 00:00 12.00 MOVE RURD MOBMIR PJSM. Install air actuators on IBOP. Test IBOP to 250 psi & 5000 psi
OK. Test Standpipe, kelly hose, mud line to 300 psi & 5000 psi, change
out Oteco valve on standpipe manifold & retest same OK. Mix spud
mud, rig up injection line.
5/23/2001 00:00 - 04:30 4.50 MOVE RURD MOBMIR Finish tightening flanges on diverter stack. Finish nippling up same.
Rebuild 4" Oteco valve on stand pipe manifold. Test same to 250 psi I
5000psi. Test kelly hose breaks. Work on swivel packing.
04:30 - 07:30 3.00 MOVE RURD MOBMIR P/U 5-1/2" landing joint, Casing hanger, land hanger on load shoulder in
well head. Test diverter, perform accumulator test. Test witnessed by
AOGCC rep. John Spaulding.
07:30 - 08:00 0.50 MOVE RURD MOBMIR Fill stack wI mud to check for leaks. Knife valve leaking.
08:00 - 10:30 2.50 MOVE RURD MOBMIR Work on knife valve & lay down machine
10:30 - 18:00 7.50 MOVE RURD MOBMIR Rig to P/U 3-1/2" DP. P/U 3-1/2" Dp & set back in derrick.
18:00 - 20:00 2.00 MOVE RURD MOBMIR Cut drilling line 90' (bad spot on line).
20:00 - 20:30 0.50 MOVE RURD MOBMIR Calibrate BHI depth tracking tracking system.
20:30 - 23:30 3.00 MOVE RURD MOBMIR Fill diverter stack & circ across surface equipment to check for leaks
(OK).
23:30 - 00:00 0.50 MOVE RURD MOBMIR P/U tools & clean floor; Note gas detector system is inoperable at this
time.
5/24/2001 00:00 - 12:00 12.00 RIGMNT RGRP MOBMIR PJSM. Trouble shoot gas detector system. Weatherize rig, Service Top
Drive, Iron Ruffneck, Rig Maintenance, Housekeeping
12:00 - 20:00 8.00 RIGMNT RGRP MOBMIR PJSM. Trace Wires, trouble shoot gas detector system. Rig
maintenance. General housekeeping.
20:00 - 22:00 2.00 RIGMNT OTHR SURFAC Test all gas detectors, testing witnessed by AOGCC rep. John
Spaulding
22:00 - 23:00 1.00 DRILL PULD SURFAC P/U Jars, Flex collars & stand back in derrick.
23:00 - 00:00 1.00 DRILL PULD SURFAC P/U BHA, Navidrill, subs, XO's.
5/25/2001 00:00 - 04:30 4.50 DRILL PULD SURFAC PJSM. P/U BHA #1, load & program LWD, MWD tools. Note; held
prespud meeting with crew while programing tools. Held Diverter drill.
04:30 - 06:00 1.50 DRILL DEQT SURFAC Test MWD tools.
06:00 - 10:30 4.50 DRILL DRLG SURFAC Clean out conductor fl 147' to 161'. Drilling 7-7/8" hole fl 161' to 322'
ADT = 4 hrs. Plugged flow line with gravel.
10:30 - 12:00 1.50 DRILL OTHR SURFAC Plugged flow line with gravel, clean out same. work & recip pipe wI
cleaning out flowline. Hole becoming tight.
12:00 - 14:00 2.00 DRILL DRLG SURFAC Work pipe thru tight hole. Unable to circulate. Rotate & work pipe
14:00 - 14:30 0.50 DRILL TRIP SURFAC POOH to bit. Drill string plugged with gravel. Clean out bit & navidrill.
14:30 - 15:30 1.00 DRILL TRIP SURFAC Orient MWD & Navidrill.
Printed: 6/28/2001 3:43:43 PM
)
)
Legal Well Name: 1 C-133
Common Well Name: 1 C-133
Event Name: ROT - DRILLING
Contractor Name: Nabors
Rig Name: Nabors 245
. Sub ..
Date From- To Hours. Code Code
5/25/2001 15:30 - 16:30 1.00 DRILL REAM SURFAC
16:30 - 00:00 7.50 DRILL DRLG SURFAC
5/26/2001 00:00 - 06:00 6.00 DRILL DRLG SURFAC
06:00 - 07:00 1.00 DRILL CIRC SURFAC
07:00 - 1 0:30 3.50 DRILL DRLG SURFAC
10:30 - 11 :00 0.50 DRILL CIRC SURFAC
11 :00 - 13:00 2.00 DRILL DRLG SURFAC
13:00 - 15:30 2.50 DRILL CIRC SURFAC
15:30 - 20:30 5.00 DRILL DRLG SURFAC
20:30 - 21 :00 0.50 DRILL CIRC SURFAC
21 :00 - 21 :30 0.50 DRILL DRLG SURFAC
21 :30 - 22:00 0.50 DRILL CIRC SURFAC
22:00 - 00:00 2.00 DRILL TRIP SURFAC
5/27/2001 00:00 - 01 :30 1.50 DRILL TRIP SURFAC
01 :30 - 02:30 1.00 DRILL TRIP SURFAC
02:30 - 04:00 1.50 DRILL CIRC SURFAC
04:00 - 12:00 8.00 DRILL DRLG SURFAC
12:00 - 12:30 0.50 RIGMNT RSRV SURFAC
12:30 - 00:00 11.50 DRILL DRLG SURFAC
5/28/2001 00:00 - 07:30 7.50 DRILL DRLG SURFAC
07:30 - 09:00 1.50 DRILL CIRC SURFAC
09:00 . 13:00 4.00 DRILL WIPR SURFAC
13:00 - 13:30 0.50 DRILL CIRC SURFAC
13:30 - 14:00 0.50 RIGMNT RSRV SURFAC
14:00 . 00:00 10.00 DRILL DRLG SURFAC
5/29/2001 00:00 - 02:00 2.00 DRILL CIRC SURFAC
02:00 - 07:00 5.00 DRILL WIPR SURFAC
07:00 - 09:00 2.00 DRILL CIRC SURFAC
09:00 - 12:00 3.00 DRILL TRIP SURFAC
12:00 - 15:30 3.50 DRILL PULD SURFAC
15:30 - 16:30 1.00 LOG RURD SURFAC
16:30 - 00:00 7.50 LOG ELOG SURFAC
5/30/2001 00:00 - 05:30 5.50 LOG ELOG SURFAC
05:30 - 06:00 0.50 LOG RURD SURFAC
06:00 - 09:00 3.00 DRILL URM SURFAC
09:00 - 11 :00 2.00 DRILL URM SURFAC
11 :00 - 15:30 4.50 DRILL TRIP SURFAC
15:30 - 16:30 1.00 CASE RURD SURFAC
16:30 - 18:30 2.00 CASE RUNC SURFAC
18:30 - 19:30 1.00 CASE RUNC SURFAC
19:30 - CASE SURFAC
Start:
Rig Release:
Rig Number: 245
Spud Date: 5/25/2001
End:
Group:
5/15/2001
RIH, Wash & ream 100' to bottom.
Drilling 7-7/8" hole fl 322' to 774' AST =1.13 hours ART =5.2 hours
Drilling 7-7/8" hole f/774' to 1182'
BHI MWD/LWD computer system failed. Change out computer. Circ &
recip pipe
Drilling 7-7/8" hole fl 1182' to 1349'
BHI computer system down, restart system. Trouble shoot system. Circ
& recip pipe
Drilling 7-7/8" hole fl 1349' to 1554'
BHI computer system down, Work on same. Circ & recip pipe
Drilling 7-7/8" hole fl 1554' to 1969'
BHI computer sytem down, work on same. Circ & recip pipe.
Drilling 7-7/8" hole fl 1969' to 2031'
BHI computer system failed. Circ & recip pipe. Decision made to trip for
bit while a new computer was being brought to rig.
Monitor well for flow (OK). POOH for bit.
PJSM. POOH, change bit
Download LWD info, reprogram tools.
Circ Bottoms up. Break circ slowly.
Drilling 7-7/8" hole fl 2031' to 2787'. AST=.5 hrs ART=4.5 hrs
Service Rig & Top Drive
Drilling 7-7/8" hole fl 2787' to 3636' AST=2 hrs. ART=5.5 hrs
Drilling 7-7/8" hole f/3636' to 4015' ART=2 hrs AST=3hrs
Circ & Cond, Pump Hi density sweep. Monitor well for flow (OK). Pump
Dry job, Blow down Top Drive.
Wiper Trip to 2129', POOH 'slow', RIH 'slow', No fill.
Break circ slowly, Circ Bottoms up.
Serivce Rig & Top Drive wI circ.
Drilling 7-7/8" hole fl 4015' to 4615' ART=6 hrs AST=1 hr.
Circ HD sweep and clean hole.
Monitor well, pump dry job, BD TO, POOH to HW DP @ 1274' Monitor
well. and RIH to 4495' washed and reamed to 4615' TD, no fill.
Circulate HD sweep & clean hole.
Monitor well, pump dry job, BD TO, POOH, SLM, Monitor well @ BHA.
No problems.
LD flex collars, MWD, Logging tools, Mud Motor. Download MWD tools,
Clean rig floor.
PJSM wI Schlumberger. Rig up for open hole logs.
RIH wI AIT/Neutron Density/CMR. WL TD 4612'.
RIH wI AITINeutron Densityl CMR. Loggers TO 4612' WLM. Succesful
logging surface hole.
PJSM. RID Sclumberger logging tools.
PU & MU 77/8" hole opener. TIH to 3530' tagged up nOK.RIH to 4510'.
Wash from 4510' to 4615'. Circ HD sweep and condition mud for
casing.
Monitor well, Pump dry job, BD TD. POOH. Monitor @ HWDP. LD Hole
opener.
PJSM. Rig up to run 31/2" x 51/2" casing. PJSM wI Rig supervisor and
tool pusher.
Run 31/2" x 5 1/2" tapered string. 20 joints run, PU Baker SBE. Set on
tight spot @ 630'
Work casing by possible boulder. Pushing ahead of casing.
Make up Frank's fill up tool. RIH total of 13 joints 5 1/2" casing with
~
Printed: 6/28/2001 3:43:43 PM
')
)
PHILLIPSA~A$KA ING.
. .
. . . .. .. . .
. ()þC!rätions!Sytnmåry Report
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1 C-133
1 C-133
ROT - DRILLING
Nabors
Nabors 245
. Sub.
Hours' Code. Code Phase.
CASE SURFAC
1.50 CASE RUNC SURFAC
0.50 CASE CIRC SURFAC
3.50 CASE RUNC SURFAC
3.50 CEMENTCIRC SURFAC
3.00 CEMENT PUMP SURFAC
5/30/2001
5/31/2001
19:30 -
00:00 - 01 :30
01 :30 - 02:00
02:00 - 05:30
05:30 - 09:00
09:00 - 12:00
12:00 - 13:00 1.00 CEMENT DISP SURFAC
13:00 - 14:00 1.00 CEMENTOTHR SURFAC
14:00 - 15:00 1.00 CMPL TN NUND SURFAC
15:00 - 22:00 7.00 CMPL TN NUND SURFAC
6/1/2001
22:00 - 23:00 1.00 CMPL TN NUND SURFAC
23:00 - 00:00 1.00 CMPL TN NUND SURFAC
00:00 - 02:30 2.50 CMPL TN NUND SURFAC
02:30 - 04:30 2.00 CMPL TN NUND SURFAC
04:30 - 10:30 6.00 CMPL TN NUND SURFAC
10:30 - 12:30 2.00 CMPL TN NUND SURFAC
12:30 - 13:30 1.00 CMPL TN NUND SURFAC
13:30 - 18:00 4.50 CMPL TN NUND SURFAC
18:00 - 19:00 1.00 CMPL TN NUND SURFAC
19:00 - 22:00 3.00 CMPL TN NUND SURFAC
22:00 - 00:00 2.00 CMPL TN NUND SURFAC
00:00 - 03:00 3.00 CMPL TN NUND SURFAC
03:00 - 04:30 1.50 CMPL TN NUND SURFAC
04:30 - 05:30 1.00 WELCTL NUND SURFAC
05:30 - 15:00 9.50 WELCTL BOPE SURFAC
15:00 - 15:30 0.50 WELCTL BOPE SURFAC
15:30 - 17:30 2.00 CMPL TN RUNT SURFAC
17:30 - 19:00 1.50 CMPL TN RUNT SURFAC
19:00 - 00:00 5.00 CMPL TN RUNT SURFAC
00:00 - 00:30 0.50 CMPL TN SOHO SURFAC
00:30 - 05:00 4.50 CMPL TN FRZP SURFAC
05:00 - 06:30 1.50 CMPLTN DEQT SURFAC
6/2/2001
6/3/2001
5/15/2001
Spud Date: 5/25/2001
End:
Group:
Start:
Rig Release:
Rig Number: 245
. Desçriþtion of Op~ra.tions
accesories.
Continue to run 5 1/2" casing.
Circulate bottoms up @ 2315'.
Continue to run 51/2" casing to 4604'.
Cirulate and condition mud for cement job. PJSM with Co. Rep and TP.
RU Shlumberger. Pressure test lines to 4000 psi. Cement per well plan.
Recipicaating pipe while cementing. Note:Pipe stuck off bottom. 11"
above landing ring with hanger.
Rig displace cement with seawater. Bump plug with 2500 psi. Check
floats. OK. Circulated 51 bbls good cement to surface.
Pulled 325 k on weight indicator. (4.6' above landing ring with hanger).
Rinse diverter system & flowline with water.
Pull mouse hole. Remove turnbuckles and flowline attached to riser in
cellar. Preparing to set emergency slips.
Nipple down diverter system. Remove flowline. Rig up cylinders to pick
up diverter system.Center pipe & set emergency slips on 51/2" casing
with 220 k on slips. (weight indicator 290 k)
Rough cut on 51/2" casing, remove collar from joint # 92.. LD landing
joint and hangerand collar.
RD diverter system.
PJSM. Remove 20" Hydril f/ Cellar. Set back spacer spool & knife valve
on stump in cellar.
Dress off rough cut. Preheat, weld quick connect weld on head adapter,
postheat and wrap with insulation to cool slowly.
While head cooling--Make up DSA to riser spool in pipe shed. Rig up rig
floor. Clean pits.
Rig up to test weld on adapter and test same. Test failed. Re-weld
adapter, let cool & test @ 3950 psi OK.
Install 7" 5m tubing spool and orient same. Test tubing head to 1000
psi. OK
PJSM. Nipple up BOPE.
Re- orient DSA to riser for two hole of BOP stack, to align BOP stack in
cellar.
NU BOP stack on riser. Hook up Koomey hoses. Check for leaks.
Change pipe rams to 31/2" X 6" variables in top pipe rams. Install 3
1/2" rams in bottom pipe rams. Open doors on blind rams and check
same-OK.
Tap out bolt holes on top pipe ram door bonnet.
Install flowline riser, hook up flowline and fill up line.
RU to test BOPE.
Test BOPE. Test witnessed by AOGCC rep. Chuck Sheeve. Nabors
commisioning BOPE.
RID Test equipment. Blow down choke, kill line, and top drive.
RlU casing running equip. PJSM. Run 3 1/2" tubing.
Camco D.S. Nipple pin end threads did not make up. Backed
out--galled threads. Aquire another D.S. Nipple.
Run 3 1/2" completion. 124 jts in hole.
Finish running 31/2" tubing. RU to pump to verify sting in of seal
assembly space out. Lay down 2 joints of 31/2" tubing. Make up
hanger.
RU and pump 50 bbls diesel into annulus with pipe rams closed. Let u
tube to tubing.
Sting into seal bore extension, run in lockdown screws on hanger.
Printed: 6/28/2001 3:43:43 PM
)
)
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1 C-133
1 C-133
ROT - DRILLING
Nabors
Nabors 245
Start:
Rig Release:
Rig Number: 245
5/15/2001
Spud Date: 5/25/2001
End:
Group:
'H:' """ C" :d" Sub
. Date ' From-To, . ours , ,:~, e Code
. .. . .
. . ..
.D~scriþtiön()f'Qp~rations '
6/3/2001
05:00 - 06:30
06:30 - 08:00
1.50 CMPL TN DEaT SURFAC
1.50 CMPL TN DEaT SURFAC
Pressure test tubing for 30 min. OK. 3000 psi test- 80 psi lost.
RU & pressure test 5 1/2" x 31/2" annulus. Pressure test annulus for 30
min. OK. 3000 psi test-35 psi lost.
Blow down all mud lines.
PJSM. ND BOPE.
NU tree. Test tbg and tubing hanger @ 250 psi and 5000 psi for 15 min
each. Pull 2 way check. Install BPV. Prepare to PU cellar.
08:00 - 08:30
08:30 - 11 :00
11 :00 - 13:00
0.50 CMPL TN OTHR SURFAC
2.50 CMPL TN NUND SURFAC
2.00 CMPL TN NUND SURFAC
Printed: 6/28/2001 3:43:43 PM
Date
06/10/01
06/18/01
06/22/01
06/23/01
)
")
1 C-133 Event H ¡story
Comment
DRIFTED TBG W/ 23.5' OF 2.65" DUMMY GUN'S & TAGGED MUD @ 4488' RKB [TAG]
OBTAINED SCMT LOG SHOWING GOOD CEMENT FROM 4474' TO 3950' WITH A FEW SHORT VOID
AREAS
PERFORATED: 4212-4226 FT / 4230-4242 FT / 4260-4330 FT WITH 2.5" HSD @ 4 SPF - 31 J UJ, HMX
CHARGES.
PERF INTERVALS = 4196-4206 FT / 4154-4176 FT / 4110 - 4140 FT / 4050-4080 FT (TOTAL 6 RUNS)
Page 1 of 1
12/612001
---------- .... ~ ~ - - -
= SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00083 Sidetrack No. Page of 3
Company PHILLIPS ALASKA, INC. Rig Contractor & No. Nabors AK Drilling -245E Field KUPARUK RIVER UNIT
--
Well Name & No. PAD 1 C/133 Survey Section Name Definitive Survey BHI Rep. T WRIGHT
INTECI WELL DATA
Target TVD (81 Target Coord. NIS Slot Coord. N/S -1690.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL 0 SSD
--
Target Description Target Coord. E/W Slot Coord. E/W 997.00 Magn. Declination 26.240 Calculation Method MINIMUM CURVATURE
Target Direction (DO) Build\Walk\DL per: 100ft~ 30mO 10mO Vert. Sec. Azim. 177.40 Magn.to Map Corr. 26.240 Map North to: OTHER
SURVEY DATA
Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate
Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) I W(-) DL Build (+) Right (+) Comment
Type (FT) (DD) (DO) (81 (81 {81 (81 (Per 10081 Drop (-) Left (-)
0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT
25-MA Y-01 MWD 161.00 0.00 0.00 161 .00 161.00 0.00 0.00 0.00 0.00 0.00 .~
25-MAY-01 MWD 205.00 0.88 353.98 44.00 205.00 -0.34 0.34 -0.04 2.00 2.00
25-MAY-01 MWD 294.00 0.88 357.50 89.00 293.99 -1.70 1.70 -0.14 0.06 0.00
25-MA Y-01 MWD 385.00 1.32 353.63 91.00 384.97 -3.45 3.44 -0.28 0.49 0.48
25-MA Y-01 MWD 476.00 1.05 343.79 91.00 475.95 -5.30 5.28 -0.63 0.37 -0.30
25-MA Y-01 MWD 566.00 0.53 284.37 90.00 565.94 -6.23 6.18 -1.27 1.00 -0.58
25-MA Y-01 MWD 656.00 1.85 231.64 90.00 655.92 -5.50 5.38 -2.81 1.76 1.47
25-MA Y-01 MWD 747.00 4.13 222.85 91.00 746.79 -2.34 2.06 -6.19 2.55 2.51
26-MAY-01 MWD 838.00 5.98 219.69 91.00 837.44 3.46 -3.99 -11.45 2.06 2.03 -3.47
26-MAY-01 MWD 928.00 7.29 218.98 90.00 926.83 11.20 -12.03 -18.03 1.46 1.46 -0.79
26-MA Y-01 MWD 1019.00 8.63 218.28 91.00 1016.95 20.69 -21 .88 -25.89 1.48 1.47 -0.77
26-MA Y-01 MWD 1109.00 11.25 221 .09 90.00 1105.60 32.14 -33.80;' -35.85 2.96 2.91 3.12
26-MAY-01 MWD 1201 .00 11.51 221.09 92.00 1195.79 45.27 -47.48 -47.78 0.28 0.28 0.00 '-"
26-MA Y-01 MWD 1295.00 11.16 217.23 94.00 1287.95 59.03 -61.79 -59.45 0.89 -0.37 -4.11
26-MA Y-01 MWD 1390.00 11.95 205.27 95.00 1381.04 74.79 -78.01 -69.21 2.65 0.83 -12.59
26-MA Y-01 MWD 1485.00 14.06 193.32 95.00 1473.62 94.59 -98.14 -76.07 3.59 2.22 -12.58
26-MA Y-01 MWD 1581.00 16.00 186.99 96.00 1566.33 118.85 -122.62 -80.37 2.64 2.02 -6.59
26-MAY-01 MWD 1675.00 18.46 179.26 94.00 1656.12 146.51 -150.37 -81.75 3.57 2.62 -8.22
26-MAY-01 MWD 1770.00 21.62 175.04 95.00 1745.36 .179.04 -182.86 -80.04 3.66 3.33 ~4.44
26-MAY-01 MWD 1866.00 24.52 176.80 96.00 1833.68 216.64 -220.37 -77.40 3.10 3.02 1.83
27-MAY-01 MWD 1962.00 29.44 177.85 96.00 1919.20 260.17 -263.87 -75.40 5.15 5.13 1.09
-----------
27-MAY-01 MWD. 2055.00 33.93 176.44 93.00 1998.32 309.01 -312.64 -72.93 4.89 .4.83 -1.52
---
27-MAY-01 MWD 2149.00 36.43 176.09 94.00 2075.15 363.15 -366.67 ~69.40 2.67 2.66 -0.37
I
- --
~ Company PHilLIPS ALASKA, ~INC.
Well Name & No. PAD 1 C/133
,NTEQ
- -
SURVEY CALCULATION AND FIELD WORKSHEET
Target ìVD --"
Target Description
(Fl)
Target Direction
(DO)
-
-
-
-
-
WELL DATA
Target Coord. NIS Slot Coord. NIS
Target Coord. E/W Slot Coord. E/W
Build\Walk\DL per: 100ft~ 30mO 10mO Vert. Sec. Azim.
Date
Survey Survey Inc!. Hole
Tool Depth Angle Direction
Type (Fl) (OD) (DO)
27-MAY-01 MWD 2243.00 36.04 176.79
27-MAY-01 MWD 2338.00 35.86
27-MAY-01 MWD 2433.00 35.33
27-MAY-01 MWD 2528.00 34.89
27-MAY-01 MWD 2623.00 33.84
27-MAY-01 MWD 2718.00 33.57
27-MAY-01 MWD 2812.00 33.40
27-MAY-01 MWD 2907.00 33.40
27-MAY-01 MWD 3000.00 30.32
27-MAY-01 MWD 3098.00 28.30
27-MAY-01 MWD 3287.00 25.49
27-MAY-01 MWD 3380.00 22.59
27-MAY-01 MWD 3474.00 20.30
27-MAY-01 MWD 3570.00 17.40
28-MA Y -01 MWD 3666.00 13.54
28-MA Y-01 MWD 3762.00
28-MA Y-01 MWD 3855.00
28-MAY-01 MWD 3949.00
28-MA Y-01 MWD 4040.00
28-MAY-01 MWD 4135.00
28-MAY-01 MWD 4231.00
28-MAY-01 MWD 4326.00
28-MAY-01 MWD 4421.00
28-MAY-01 MWD I 4514.00
175.39
173.28
172.22
172.57
174.33
173.63
173.28
173.28
172.93
171.87
169.40
168.00
166.60
164.49
9.05
6.94
164.84
169.76
4.57
2.64
176.44
185.23
2.55
191 .21
178.90
4.31
1.93
184.88
0.97
0.79
193.32
195.43
Course
Length
(Fl)
94.00
95.00
95.00
95.00
95.00
95.00
94.00
95.00
93.00
98.00
189.00
93.00
94.00
96.00
96.00
96.00
93.00
94.00
91.00
95.00
96.00
95.00
95.00
93.00
ìVD
(Fl)
2150.97
2227.87
2305.13
2382.84
2461 .26
2540.29
2618.69
2698.00
2776.98 -
2862.43
3030.97
3115.90
3203.38
3294.23
3386.73
3480.85
3572.94
3666.46
3757.28
3852.18
3948.01
4042.86
4137.83
4230.82
-
-
-
Job No. 0450-00083
Rig Contractor &No. Nabors AK Drilling - 245E
Survey Section Name Definitive Survey
SURVEY DATA
Vertical
Section
418.70
474.46
529.67
584.12
637.54
690.13
741.90
794.07
843.03
890.86
976.03
1013.64
1047.61
1078.15
1103.21
1121.54
1134.25
1143.63
1149.33
1153.55
1159.23
1164.38
1166.74
1168.11
-1690.00
997.00
177.40
Total Coordinate
N(+) I S(-)
(Fl)
-422.13
-477.77
-532.79
-586.99
-640.14
-692.51
-744.08
-796.04
-844.78
"892.41
~977.15
-1014.52
-1048.22
-1078.48
-1103.28
-1121.41
-1134.00
-1143.33
-1149.03
-1153.28
-1158.99
-1164.15
-1166.53
-1167.91
E(+) I W(-)
(Fl)
-65.95
-62.15
-56.70
-49.80
-42.70
-36.69
-31 .25
-25.29
-19.55
-13.79
-2.52
3.59
10.31
17.10
23.43
28.41
31.32
32.57
32.60
31.99
31.64
31.58
31.26
30.90
Grid Correction
Magn. Declination
Magn. to Map Corr.
DL
(Per 100 Fl)
0.60
0.89
1.41
0.79
1.12
1.07
0.45
0.20
3.31
2.07
1.51
3.30
2.50
3.06
4.06
4.68
2.38
2.62
2.20
- '0.30
1.98
2.53
1.03
0.20
0.000
26.240
Build Rate
Build (+)
Drop (-)
-0.41
-0.19
-0.56
-0.46
-1.11
-0.28
-0.18
0.00
-3.31
-2.06
-1 .49
-3.12
-2.44
-3.02
-4.02
-4.68
-2.27
-2.52
-2.12
-0.09
1.83
-2.51
-1.01
-0.19
Sidetrack No.
Page ~ of 3
Field KUPARUK RIVER UNIT
BHI Rep. T WRIGHT
26.240
Depths Measured From: RKB ~ MSLOSSO
Calculation Method MINIMUM CURVATURE
Map North to: OTHER
Walk Rate
Right (+)
Left (-)
0.74
-1.47
Comment
--/
-2.22
-1.12
0.37
1.85
-0.74
-0.37
0.00
-0.36
-0.56
-2.66
- -1.49
-1 .46
~
-2.20
0.36
5.29
.
.
=
,NTEQ.
Target TVD
Target Description
Target Direction
- ------
SURVEY CALCULATION AND FIELD WORKSHEET
Job No. 0450-00083
26.240
- -
Sidetrack No.
- --
Page -~ of 3
Company PHILLIPS ALASKA, INC.
Well Name & No. PAD 1 C/133
Rig Contractor & No. Nabors AK Drill~g - 245E .
Survey Section Name Definitive Survey
Field KUPARUK RIVER UNIT
BHI Rep. T WRIGHT
Depths Measured From: RKB ~ MSLO SSO
Calculation Method MINIMUM CURVATURE
Map North to: OTHER
Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate
Date Tool Depth Angle Direction Length 1VD Section N{+) I S{-) E{+) I W{-) DL Build (+) Right (+)
Type (Fl) (DO) (00) (Fl) (FT) (Fl) (Fl) (Per 100 Fl) Drop (-) Left (-)
28-MAY-01 MWD 4546.00 0.88 192.61 32.00 4262.81 1168.56 -1168.36 30.79 0.31 0.28
28-MAY-01 MWD 4615.00 0.88 192.61 69.00 4331 .80 1169.58 -1169.40 30.56 0.00 0.00
WELL DATA
(FT)
Target Coord. N/S Slot Coord. N/S
Target Coord. Ef\N Slot Coord. Ef\N
Build\Walk\DL per: 1 OOft~ 30mO 10mO Vert. Sec. Azim.
SURVEY DATA
177 .40
Magn. to Map Corr.
-1690.00
. 997.00
Grid Correction
Magn. Declination
.0.000
26.240
(DO)
Comment
Projected Data - NO SURVEY
-~
~-
ft.
aD }-()1-;
)
)
Phillips Alaska, Inc.
Pad 1C
133
slot #133
Kuparuk River Unit
North Slope, Alaska
SUR V E Y LIS TIN G
by
Baker Hughes INTEQ
Your ref: MWD <0-4615'>
OUr ref: svy6535
License:
Date printed: 11-Jul-2001
Date created: 27-May-200l
Last revised: 5-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 28.551,w149 29 50.024
Slot Grid coordinates are N 5968546.449, E 562004.248
Slot local coordinates are 1690.00 S 997.00 E
Projection type: alaska - Zone 4, Spheroid: Clarke - 1866
Reference North is True North
)
Phillips Alaska, Inc.
Pad lC,133
Kuparuk River Unit,North 5lope, Alaska
Measured Inclin A%~uth True Vert
Depth Degrees Degrees Depth
0.00
161. 00
205.00
294.00
385.00
476.00
566.00
656.00
747.00
838.00
928.00
1019.00
1109.00
1201.00
1295.00
1390.00
1485.00
1581.00
1675.00
1770.00
1866.00
1962.00
2055.00
2149.00
2243.00
2338.00
2433.00
2528.00
2623.00
2718.00
2812.00
2907.00
3000.00
3098.00
3287.00
3380.00
3474.00
3570.00
3666.00
3762.00
3855.00
3949.00
4040.00
4135.00
4231.00
4326.00
4421.00
4514.00
4546.00
4615.00
7.29
8.63
11. 25
11. 51
11.16
11.95
14.06
16.00
18.46
21.62
24.52
29.44
33.93
36.43
36.04
35.86
35.33
34.89
33.84
33.57
33.40
33.40
30.32
28.30
25.49
22.59
20.30
17.40
13.54
9.05
0.00
0.00
0.88
0.88
1.32
0.00
0.00
353.98
357.50
353.63
0.00
161. 00
205.00
293.99
384.97
475.95
565.94
655.92
746.79
837.44
926.83
1016.95
1105.60
1195.79
1287.95
1381.04
1473.62
1566.33
1656.12
1745.36
1833.68
1919.20
1998.32
2075.15
2150.97
2227.87
2305.13
2382.84
2461. 26
2540.29
2618.69
2698.00
2776.98
2862.43
3030.97
3115.90
3203.38
3294.23
3386.73
3480.85
3572.94
3666.46
3757.28
3852.18
3948.01
4042.86
4137.83
4230.82
4262.81
4331.80
\
)
5URVEY LI5TING Page 1
Your ref: MWD <0-4615'>
Last revised: 5-Jun-2001
R E C TAN G U L A R Dogleg Vert
COO R DIN ATE 5 Deg/100ft 5ect
O.OON
O.OON
0.34N
1.70N
3.44N
5.28N
6.18N
5.38N
2.06N
3.995
12.035
21.885
33.805
47.485
61. 795
78.015
98.145
122.625
150.375
182.865
220.375
263.875
312.645
366.675
422.135
477.775
532.795
586.995
640.145
692.515
744.085
796.045
844.785
892.415
977 . 155
1014 . 525
1048.225
1078.485
1103.285
1121.415
1134.005
1143.335
1149.035
1153.285
1158.995
1164.155
1166.535
1167.915
1168.365
1169.405
O.OOE
O.OOE
0.04W
0.14W
0.28W
0.63W
1.27W
2.81W
6.19W
11.45W
18.03W
25.89W
35.85W
47.78W
59.45W
69.21W
76.07W
80.37W
81. 75W
80.04W
77 . 40W
75.40W
72 . 93W
69.40W
65.95W
62.15W
56.70W
49.80W
42.70W
36.69W
31.25W
25.29W
19.55W
13.79W
2.52W
3.59E
10.31E
17.10E
23.43E
28.41E
31. 32E
32.57E
32.60E
31.99E
31.64E
31.58E
31. 26E
30.90E
30.79E
30.56E
0.00
0.00
2.00
0.06
0.49
0.00
0.00
-0.34
-1. 70
-3.45
GRID COORD5
Easting Northing
562004.25
562004.25
562004.21
562004.10
562003.94
562003.57
562002.93
562001.40
561998.04
561992.84
561986.32
561978.54
561968.68
561956.86
561945.31
561935.68
561928.99
561924.89
561923.73
561925.70
561928.65
561931.00
561933.87
561937.84
561941.74
561945.99
561951.89
561959.22
561966.75
561973.19
561979.05
561985.43
561991.57
561997.71
562009.67
562016.09
562023.07
562030.11
562036.64
562041.77
562044.79
562046.10
562046.19
562045.61
562045.31
562045.28
562044.98
562044.64
562044.53
562044.31
5968546.45
5968546.45
5968546.79
5968548.15
5968549.88
5968551.72
5968552.61
5968551.80
5968548.46
5968542.37
5968534.27
5968524.36
5968512.36
5968498.58
5968484.18
5968467.89
5968447.70
5968423.19
5968395.43
5968362.97
5968325.47
5968282.00
5968233.26
5968179.26
5968123.84
5968068.24
5968013.27
5967959.13
5967906.05
5967853.73
5967802.21
5967750.31
5967701.62
5967654.04
5967569.41
5967532.09
5967498.45
5967468.25
5967443.50
5967425.42
5967412.85
5967403.53
5967397.83
5967393.57
5967387.87
5967382.71
5967380.33
5967378.94
5967378.49
5967377 . 45
All data in feet unless otherwise stated. Calculation uses minimum curvature method.
Coordinates from slot #133 and TVD from RKB 102' (N-245E) (102.00 Ft above mean sea level).
Bottom hole distance is 1169.80 on azimuth 178.50 degrees from wellhead.
Vertical section is from wellhead on azimuth 177.40 degrees.
Grid is alaska - Zone 4.
Grid coordinates in FEET and computed using the Clarke - 1866 spheroid
Presented by Baker Hughes INTEQ
1.05
0.53
1.85
4.13
5.98
343.79
284.37
231.64
222.85
219.69
218.98
218.28
221. 09
221. 09
217.23
205.27
193.32
186.99
179.26
175.04
176.80
177 . 85
176.44
176.09
176.79
175.39
173.28
172 . 22
172.57
174 . 33
173.63
173.28
173.28
172.93
171. 87
169.40
168.00
166.60
164.49
164.84
6.94
4.57
2.64
2.55
4.31
169.76
176.44
185.23
191.21
178.90
1. 93
0.97
0.79
0.88
0.88
184.88
193.32
195.43
192 . 61
192.61
0.37
1.00
1. 76
2.55
2.06
-5.30
-6.23
-5.50
-2.34
3.47
1.46
1.48
2.96
0.28
0.89
11.21
20.69
32.14
45.27
59.04
2.65
3.59
2.64
3.57
3.66
74.80
94.59
118.86
146.51
179.04
3.10
5.15
4.89
2.67
0.60
216.64
260.18
309.01
363.15
418.71
0.89
1.41
0.79
1.12
1.07
474.46
529.67
584.13
637.55
690.13
0.45
0.20
3.31
2.07
1. 51
741.90
794.07
843.03
890.87
976.03
3.30
2.50
3.06
4.06
4.68
1013.64
1047.61
1078.15
1103.21
1121.54
2.38
2.62
2.20
0.30
1. 98
1134.25
1143.63
1149.33
1153.55
1159.23
2.53
1.03
0.20
0.31
0.00
1164.39
1166.75
1168.11
1168.56
1169.58
)
)
Phillips Alaska, Inc.
Pad 1C,133
Kuparuk River Unit,North Slope, Alaska
SURVEY LISTING Page 2
Your ref: MWD <0-4615'>
Last revised: 5-Jun-2001
Measured Inclin Azimuth True Vert
Depth Degrees Degrees Depth
R E C TAN G U L A R Dogleg Vert
COO R DIN ATE S Deg/100ft Sect
G RID COO R D S
Easting Northing
All data in feet unless otherwise stated. Calculation uses min~um curvature method.
Coordinates from slot #133 and TVD from RKB 102' (N-245E) (102.00 Ft above mean sea level) .
Bottom hole distance is 1169.80 on az~uth 178.50 degrees from wellhead.
Vertical section is from wellhead on az~uth 177.40 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,133
Kuparuk River Unit,North Slope, Alaska
SURVEY LISTING Page 3
Your ref: MWD <0-4615'>
Last revised: 5-Jun-2001
Comments in wellpath
--------------------
---------
Me
'l'VD
Rectangular Coords.
Comment
-----------------------------------------------------------------------------------------------------------
4615.00 4331.80
1169.40S
30.56E Projected Data - NO SURVEY
Casing positions in string 'A'
==--~----------====----------=
Top Me Top 'l'VD
Rectangular Coords.
Bot Me Bot 'l'VD
Rectangular Coords.
Casing
-----------------------------------------------------------------------------------------------------------
0.00
0.00
O.OON
O.OOE 4603.00 4319.81
1169.225
30.60E 5 1/2
Targets associated with this wellpath
------~-----~-------------===========
Target name
Geographic Location
T.V.D.
Rectangular Coordinates
Revised
-----------------------------------------------------------------------------------------------------------
W5 1C K6 (5-DEC-00) 562066.000,5967392.000,0.0000 3909.00
1155.025
52.37E
8-Jan-2001
0
Se_l.bellger
NO. 1277
Schlumberger Technology Corporation, by and through is Geoquest Division
3940 Arctic Blvd, Suite 300
Anchorage, AK 99503-5711
A TIN: Sherrie
7/11/2001
Company: Alaska Oil & Gas Cons Comm
Attn: Lisa Wee pie
333 W. 7th Ave. Suite 100
Anchorage, AK 99501
Field:
/-
Well Job# Log Description Date BL Sepia
~1 1C-133 21268 PEX-AIT OS/29/01 1 1
1 C-133 21268 PEX-DEN-CNL POROSITY OS/29/01 1 1
l,t> 1 C-133 21268 SSTVD OS/29/01 1 1
1J> 1 C-133 21268 CMR OS/29/01 1 1
1 C-133 21268 PEX,AIT,CMR (PDC) OS/29/01
---
SIGNE¡(' ~ lJ.Op
---
DATE:
Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you.
Kuparuk
CD
1
RECEIVED
'JUL 13 2001
Alaska Oil & Gas Cons. Commi88ion
AndIoI1ge
7/9/2001
Sc~lullbePDep
NO. 1267
Schlumberger Technology Corporation, by and through is Geoquest Division
3940 Arctic Blvd, Suite 300
Anchorage, AK 99503-5711
ATTN: Sherrie
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 C-133 2D!-o11 21312 SCMT 06/18/01 1
1J-09 lot - OI/¥ 21311 SCMT 06/05/01 1
1J-10 1,0(.01/ 21306 SCMT 06/12/01 1
3H-11/ ftl-12~ 21314 US IT 06/14/01 1
3H-11 Ifl1'1'- 21314 USIT 06/14/01 1
3K-20 'ZÞI'" (8 21313 SCMT 06/18/01 1
,--,
~ED: ~ -, ~Ol¿~ ~
/'
DATE:
RECEIVED
'JUL 13 2001
Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you.
AIa8ka 00 & Gas Cons. Commi8eion
Andlorage
~~~~E
)
: F !Æ~l,~~~Á,
)
AlASKA OIL AND GAS
CONSERVATION COMMISSION
TONY KNOWLES, GOVERNOR
333 W. 7fH AVENUE, SUITE 100
ANCHORAGE, ALASKA99501-3539
PHONE (907) 279-1433
FAX (907) 276-7542
J ames Trantham
Drilling Engineering Supervisor
Phillips Alaska, Inc.
. P.O. Box 100360
Anchorage AK 99510
Re:
Kuparuk River Unit 1C-133
Phillips Alaska, Inc.
Pennit No: 201-077
Sur. Loc. 1690' FNL, 997' FWL, Sec. 12, T11N, RI0E, UM
Btmhole Loc. 2433' FSL, 1048' FWL, Sec. 12, T11N, R10E, UM
Dear Mr. Trantham:
Enclosed is the approved application for pennit to drill the above referenced well.
The pennit to drill does not exempt you from obtaining additional pennits required by law from
other governmental agencies, and does not authorize conducting drilling operations until all other
required pennitting detenninations are made.
The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035;
and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC
25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test
before operation, and of the BOPE test perfonned before drilling below the surface casing shoe,
must be given so that a representative of the Commission may witness the tests. Notice may be
given by contacting the Commission petroleum field inspector on the North Slope pager at
659-3607.
Sincerely,
~M.,~
Julie M. Heusser
Commissioner
BY ORDER OJ¡ THE COMMISSION
DATED thisK day of May 2001.
jjcÆnclosures
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
20 AAC 25.005
1b. Type of well. - Explo~atory (j Stratigraphic Test LJ
Service ø Development Gas 0 Single Zone 0
5. Datum elevation (OF or KB)
RKB = 102 feet AMSL
1 a. Type of work: Drill b!J Redrill U
Re-entry 0 Deepen 0
2. Name of Operator
Phillips Alaska, Inc.
3. Address
P.O. Box 100360 Anchorage, AK 99510-0361
4. Location of well at surface
1690' FNL, 997' FWL, Sec. 12, T11N, R10E, UM
At top of productive interval
2437' FSL, 1047' FWL, Sec. 12, T11 N, R10E, UM
At total depth
2433' FSL, 1048' FWL, Sec. 12, T11 N, R10E, UM
12. Distance to nearest property line I 13. Distance to nearest well
2284' @ TD feet 1 C-03 64'
16. To be completed for deviated wells
'Kickoff depth: 600 M D
18. Casing program
size
Maximum hole angle
Hole Casing Weight
24" 16" 62.5#
7.875" 5.5" 15.5#
7.875" 3.5" 9.3#
5.5" Csg 3.5" 9.3#
Specifications
Grade Coupling
H-40 Weld
L-80 STCM
L-80 EUE 8rd M
L-80 EUE 8rd M
Length
120'
3911'
670'
3952'
19. To be completed for Redrill, Re-entry, and Deepen Operations.
Present well condition summary
Total Depth:
measured
true vertical
feet
feet
Effective Depth:
feet
feet
measured
true vertical
Casing
Conductor
Surface
0
Size Cemented
Length
Perforation depth:
measured
true vertical
6. Property Designation
ADL 25649 ALK 467
7. Unit or property Name
Kuparuk River Unit
8. Well number
1 C-133
9. Approximate spud date
May 10, 2001
14. Number of acres in property
2448
17. Anticipated pressure (see 20 AAC 25.035 (e)(2))
Maximum surface 1460 psig At total depth (TVD) 1919 psig
Setting Depth
feet
36
)
kS7¡"
Development Oil 0
Multiple Zone 0
10. Field and Pool
Kuparuk River Field
West Sak Oil Pool
11. Type Bond (see 20 AAC 25.0251)
Statewide
Number
#59-52-180
Amount
$200,000
15. Proposed depth (MD and TVD)
4622 ' MD / 4337 ' TVD
Top Bottom Quantity of Cement
MD TVD MD TVD (include stage data)
41.2' 41.2' 161' 161' 225 cf AS 1
41.2' 41.2' 3952' 3667' 390 sx AS III L & 330 sx Class G
3952' 3667' 4622' 4337' Tapered String -Cemented above
41.2' 41.2' 3952' 3667' (Tubing String)
Title: Drilling Engineering SupeNisor
Commissioner
the commission
Plugs (measured)
Junk (measured)
Measured depth
True Vertical depth
RECEIVED
APR 2 7 2001
Alaska Oil & Gas Con
A~-- S. CommiSSion
'''-'' fUr-age
20. Attachments Filing fee ø Property Plat 0 BOP Sketch ø Diverter Sketch ø Drilling programø
Drilling fluid program ø Time vs depth plot 0 Refraction analysis 0 Seabed report 0 20 AAC 25.050 requirements ø
21. I hereby certl y that the foregoing is true and correct to the best of my knowledge Questions? Call Steve McKeever 265-682f
Signed ~ a~.S \ (ú.~~
James Trantham
Date ~ 0 fbo.1- <-Løo \
Prenarp.rl hv Sfp.ve McKp.p.vp.r
Commission Use Onl~
Permit Number API number I Approval date 5 J<) /) I I See cover letter
20/ - 0 ="7 50- 0 2.. <1 - .2 3 d J.3 . ó. for other requirements
Conditions of approval Samples required 0 Yes §I No Mud log required 0 Yes 2 No
Hydrogen sulfide measures 0 Yes g No Directional survey required JBI Yes 0 No
Required working pressure for BOPE 0 2M; 0 3M; 0 5M; 0 10M;D 0
Other: c..Q""'t~-o\--q\)~\\~'1 \,.~~~ \-\\, \ ~ ~(:)~ "Ct.Qt.,....~~ ;)..s~ ~~"I ~Û~~-\-~..:,~\)~
by order of
OR~GINAL SIGNED BY
.J. M. t leu~r
Approved by
Form 10-401 Rev. 12/1/85.
_IIML
Date 6" (K .0 I
Submit in triplicate
)
Applir ..~. n for Permit to Drill, We1l1C-133
} Revision No.O
. Saved: 26-Apr-01
Permit It - West Sak Well #1 C-133
Application for Permit to Drill Document
MoximizE
We-II VolUI;
Table of Contents
1. Well Name.......... ............................................ ................... ... .....................................2
Requirements of 20 AAC 25.005 (f).......................... ......... ...... ................. ........................... ................... 2
2. Location Su m mary ................. ...................... ....... ..................................................... 2
Requirements of 20 AAC 25.005(c)(2) ................................................................................................... 2
Requirements of 20 AAC 25. 050(b) ........... ........................ ............... ........ ............ ... ..... .................. ........3
3. Blowout Prevention Equipment Information .........................................................3
Requirements of 20 AAC 25.005(c)(3) . ..................................... ............................................................. 3
4. Dri II i ng Hazards I nformati on ................................................................................... 3
Requirements of 20 AAC 25.005 (c)(4) ..................................................................................................3
5. Procedure for Conducting Formation Integrity Tests ........................................... 3
Requirements of 20 AAC 25.005 (c)(5) ................................................................................... ...............3
6. Casi ng and Cementing Program .............................................................................4
Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 4
7. Diverter System Information ....... ............. ..... ..................................... ................. ....4
Requirements of 20 AAC 25. 005( c)(7) ................................................................................................... 4
8. Dri II i ng FI uid prog ram ......... ...................... .............................................................. 4
Requirements of 20 AAC 25.005(c)(B) ................................................................................................... 4
9. Abnormally Pressured Formation Information ...................................................... 5
Requirements of 20 AAC 25.005 (c)(9) .. ......... ................ ...................................... ................................. 5
10. Seism ic Analysis.............. ... .................................................................... ...... ........ ...5
Requirements of 20 AAC 25.005 (c)(1 0) ................................................................................................ 5
11. Seabed Condition Analysis .....................................................................................5
Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 5
12. Evidence of Bondi ng................................... ... ............................................ ..............5
Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 5
OR G HAL
1C-133 PERMIT ITDOC
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13. Proposed Dri II i ng Program ........................................ .... ...... .... ......................... ....... 5
Requirements of 20 AAC 25.005 (c)(13) ................................................................................................5
14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 6
Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 6
15. Attach ments .................. ....... ..... .................... .................... ....... ....... ......................... 7
Attachment 1 Directional Plan......................... ............................................................. .......................... 7
Attachment 2 Diagram and Description of the Blowout Prevention Equipment, Nabors Rig 245e ....... 7
Attachment 3 Drilling Hazards Summary..... ....... .................................. ................. ................................ 7
Attachment 4 Formation Integrity Test Procedure.................................................................................7
Attachment 5 Cement Loads and CemCADE Summary. ...................................................................... 7
Attachment 6 Diagram and Description of the Diverter System, Nabors Rig 245e............................... 7
Attachment 7 Diagram of the Mud System, Nabors Rig 245e............................................................... 7
Attachment 8 Well Schematic. . ........................... ....... ... ...................................... ................................... 7
1. Well Name
Requirements of 20 AAC 25.005 (f)
Each well must be identified by a unique name des~qnated by the operator and a unique API number as.':¡igned by the commission
under 20 AAC 25: 040(b). For a well wdh multliJle well branches, each bli;¡ncl7 must similarly be identified by a unique name and API
number by adding a svfl7x to the name de5ignated for the well by the operator and to the number assigned to the well by the
evmmis...;,ion.
The well for which this Application is submitted will be designated as lC-133.
2. Location Summary
Requirements of 20 AAC 25.005(c)(2)
An applicatìon for a Permit to Drìll mU8t be accompanied by each ol the following item~ except lor an item already on file witf7 the
commì::,"Eiion and Identified in the applkê-1tion:
(2) a plat identifylÌ7g the property and the propelty's owners and showing
(A)the coordinates of the proposed location of the well at the ,':ívrface, at the top or each objective formation, and at total depth,
referenced to governmental section lìnes.
(8) the cvordinates or the propOS'ed location or the well at the sudace, rererenced to the state plane coordìnate system fvr this
state as maintained by the National Geodelic Survey ìn the National Oceanic and Atmospheric Administration;
(C) the proposed depth ol the well at the top of" each objective formation and at total depth;
11690' FNL, 997' FWL, See 12, TllN, Rl0E, UM
RKB Elevation
Pad Elevation
Location at Surface
NGS Coordinates
Northings: 5,968.547.38 Eastings: 562,005.48
Location at Top of
Productive Interval
(West Sak "D" Sand)
NGS Coordinates
Northings: 5,967,396
2437' FSL, 1047' FWL, See 12, TllN, Rl0E, UM
Eastings: 562,065
Measured Depth, RKB:
Total Vertical Depth, RKB:
Total Vertical Depth, 55:
Location at Total Depth 12433' FSL, 1048' FWL,
NGS Coordinates
Northings: 5,967,392 Eastings: 562,066
See 12, TI1N, Rl0E, UM
Measured Depth, RKB:
Total Vertical Depth, RKB:
Total Vertical Depth, 55:
and
ORIGINAL
102.0' AMSL
60.8' AMSL
4052
3767
3665
4622
4337
4235
1C-133 PERMIT IT.DOC
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(D) other information required by 20 MC 25:050(b);
Requirements of 20 AAC 25. 050 (b)
.It" a well is to be intentionally deviate4 the application for a Pennit to Dn!1 (Form .1 0-40.1) must
(1) include a platl drawn to a 5vitable scale¡ showing the path at the proposed wellbore¡ inc:iuding all adjacent well bores within lOO
feet of any portion at the proposed well;
Please see Attachment 1: Directional Plan
and
(2) for all wells within 200 feet of the proposed wellbore
(A) kit the names of'tl7e operators of those well:;,~ to the extent that those names are known or discoverz~ble in public record$,
and !:;tJow that each named operator has been furm:<;,17ed a copy of the application by certified ma/~' or
(8) state that the applicant is the only affected owner.
The Applicant is the only affected owner.
3. Blowout Prevention Equipment Information
Requirements of 20 AAC 25.005(c)(3)
An application tÖr a Permit to 01111 must be accompanied by eactJ of the following item5~ except (or an item already on tHe with the
¿:vmmissio(l and Identified in the application:
(3) a diagram and des{,¡iption olthe blowout prevention equipment (BOPE) as required by 20 AAC 25.03~ 20 MC 25.036~ or 20
MC 25.03~ asapplicabkj
Please see Attachment 2: Diagram and Description of the Blowout Prevention Equipment for Nabors Rig
245e.
4. Drilling Hazards Information
Requirements of 20 AAC 25.005 (c)(4)
An application ('Or a Permit t'O Drill must be accompanied by each of the following item':J~ except tbr an item already on file with the
commis..c,ion and identllìed in the application:
(4) infO/mation on drilling hazards~ ineluding
(A) the maximum downhole pre!:;'sure that may be encounterec!, cntelia used to detenmi7e it and maxlinum potential surlace
prðS'ure based on a methane gradient;
The expected reservoir pressures in the West Sak sands in the lC pad area vary from 0.43 to 0.46 pSi/ft,
or 8.2 to 8.8 ppg EMW (equivalent mud weight). These are pressures obtained from actual well test data
from the nearby WS1-0l 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/ft)
=1459 psi
(8) data on potential gas zones;
The well bore is not expected to penetrate any gas zones.
and
(C) data conæming potential causes of lIole problems such as abnormally geo-pres:.c:;ured strata, lost ckculation zones¡ and zones
that have a propensity for differential sticking;
Please see Attachment 3: Drilling Hazards Summary.
5. Procedure for Conducting Formation Integrity Tests
Requirements of 20 AAC 25.005 (c)(5)
An application for a Permit to Drill must be accompanied by each of the following items¡ except for an item already on tfie wltll tile
commission and Identified in the application:
(.5) a description of tIle procedure for condudJi7g formation integrity tests¡ as required under 20 AAC 25.0JO(f};
OR 'G -N 1C-133 PERMIT IT. DOC
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l Revision No.O
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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 LOT / FIT procedure found in Attachment 4.
6. Casing and Cementing Program
Requirements of 20 AAC 25.005(c)(6)
An application for a PermIt to Drill must be accompanied by each of the following items, except for an item already on file with the
commission and identified in the application:
(6) a complete proposed casing and cementing program as required by 20 AAC 25, 030, and a desaiption of any siotted line/~ pre-
petforated linet; or screen to be installed-'
Casing and Cementing Program
Hole Top Btm
Csg/Tbg Size Weight Length MD/TVD MD/TVD
00 (in) (in) (Iblft) Grade Connection (ft) (ft) (ft) Cement Program
16 24 62.5 H-40 Welded 120 41/41 161 / 161 Cemented to
surface with 9
cy High Early
5-1/2 7-7/8 15.5 L-80 BTC,AB 3911 41/41 3952 / 3667 Cemented to
Modified Surface with
3-1/2 7-7/8 9.3 L-80 EUE 8rd, 670 3952/3667 4622 / 4337 390 sx ASLite
AB Lead, 330 sx
Modified Class G Tail
See also Attachment 4: Cement Loads and CemCADE Summary.
7. Diverter System Information
Requirements of 20 AAC 25.005(c)(7)
An application for a Permit to Drill must be accompanied by each of the fvllowing items~ except for an item already 0/7 tìle with the
commission and identified in the application:
(7) a diagram and desaiption of'the diverter system as required by 20 AAC 25.035; unless tl7is requirement is waived by the
wmmissiofJ under 20 MC 25.035(h)(2);
Please see Attachment 5: Diagram And Description of the Diverter System For Nabors Rig 245e.
8. Drilling Fluid Program
Requirements of 20 AAC 25.005(c)(B)
An application for a Permit to Dn/l must be accompanied by each of the follow/f7g Items, except for an/tem already on tHe with the
commt:'ision and identified in tile application:
(8) a drilling fluid program, including a diagram c7nd description of the dnll1Í7g flwd system, c'JS required by 20 MC 25:033/
Drilling will be done with a bentonite slurry having the following properites over the listed intervals:
Spud to Base of Permafrost Base of Permafros to Total Depth
Initial Value Final Value Initial Value Final Value
8.5 9.4 - 9.6* 9.4 9.4
150-200 150-200 150 75
Density (ppg)
Funnel Viscosity
(seconds)
Yield Point
(cP)
Plastic Viscostiy
(lb1100 sf)
10 second Gel
Strength (lb1100 sf)
10 minute Gel
Strength (lb1100 sf)
pH
API Filtrate(cc)
Solids (%)
30-60 30-60 25-45 25-45
8-15 11- 22 11-22 11-22
15-30 10-25 15-30 15- 30
25-55 25-55 25-55 25-55
8-9 8-9
8-15 6 5-6 5-6
5-8 5-8 5-8 6-11
1C-133 PERMIT IT. DOC
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Appl,i 'Qn for Permit to Drill, Well 1 C-133
l Revision No.O
Saved: 26-Apr-01
*9.8 ppg if hydrates are encountered
Please see Attachment 6: Diagram of Mud System, Nabors Rig 245e.
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 Flo-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.
Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033.
9. Abnormally Pressured Formation Information
Requirements of 20 AAC 25.005 (c)(9)
An applic:-ation fiJr a Permit to Drill must be accompanied by each of'the f'ollowing item~ except for an item already 0/7 fìle with the
comml!.,-sion and Identified 1i7 the application:
(9) for an exploratory or stratigraphic t¿~::;t well a tabulation setting out the depths olpredicted abnormally geo.pressured strE:lta as
required by 20 AAC 25.033(f);
Not applicable: Application is not for an exploratory or stratigraphic test well.
10. Seismic Analysis
Requirements of 20 AAC 25.005 (c)(10)
An application for a PermIt to Dnll mtJst be accompanied by each of the (ollowing Items, except (or an item already on file with the
commiss1"on and identified in the application:
(10) tÒr an exploratVlY or stratžqraphic l-e!J"t we/I, a seisrnic refraction or reflection analY5is a!J" required by 20 MC 25~06.l(a)/
Not applicable: Application is not for an exploratory or stratigraphic test well.
11. Seabed Condition Analysis
Requirements of 20 AAC 25.005 (c)(11)
An application lor a Pel7l71t to Dnll must be accompanied by each of the fiJI/owing Item5~ eXi..è::pt fòr an item already on file with the
commission and identIfied in the application:
(11) lor a well drilled from an offshore platform, mobile bottom.founded structure, jack.up rig or floatJi7g dri/lli7g vessel an analyst:'i
of seabed conditions as required by 20 MC 25:06.1(b);
Not applicable: Application is not for an offshore well.
12. Evidence of Bonding
Requirements of 20 AAC 25.005 (c)(12)
An application for a Permit to Drill must be accompanied by each of the following items~ except for an item already on file with the
commi!i..sion and identified in the application:
(12) evidence showing that the requirements of 20 MC 25.025 {Bonding}lïave 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 Drill must be accompanied by each of the following items, except for an item already on file with the
commission and Identified li7 the application:
The proposed drilling program is listed below. Please refer as well to Attachment 7, Well Schematic.
1. Excavate cellar, install cellar box, set and cement 16" conductor. Weld landing ring on conductor.
2. MIRU Nabors Rig 245e. Install diverter and function test same.
3. Spud and directionally drill 7-7/8" hole to desired targets through West Sak interval. Run
MWD/LWD logging tools in drill string as required for directional monitoring and formation data
gathering.
ORIGINAL
1C-133 PERMIT IT. DOC
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Applit ".í?n for Permit to Drill, Well 1 C-133
! Revision No.O
, Saved: 26-Apr-01
4. Circulate and condition hole to run open hole logs. POOH.
5. Run Schlumberger Platform Express logging suite: AIT 1 GRI N 1 D 1 CMR.
6. RIH. Circulate and condition hole to run casing.
7. Run and cement 5-1/2" 15.5# L-80 BTCM x 3-1/2" 9.3# L-80 EUE 8rd tapered casing string to
surface. Displace cement with mud and perform stage job or top job if required.
Note: 5-1/2" Port Collar to be installed @ +/- 1/000' TVD.
8. Nipple down diverter and install wellhead. Nipple up BOP stack and pressure test to 5,000 psi.
9. PU and RIH with 3-1/2" tubing to just above seal bore extension and displace well to clean
seawater.
10. Sting into seal bore extension and space out.
11. Unsting seal assembly, and freeze protect well with diesel.
12. Sting back into seal bore extension and land tubing.
13. Using diesel, pressure test tubing and annulus to 3,000 psi. Record results. Install back pressure
valve.
14. Nipple down BOP stack. Install production tree and pressure test same.
15. Secure well and release Nabors Rig 245e.
A cement bond log will be run after the rig has moved off the well.
14. Discussion of Mud and Cuttings Disposal and Annular Disposal
Requirements of 20 AAC 25.005 (c)(14)
An application for a Permit to On!1 mustc be accompanied by each of the following item.'i¡ except for an Item already 017 file with the
c:vmmi!,"sion and Identified 1i7 the application:
(14) a general description of how the operator plans to dispœ,--e of drilling mud and cuttings and a statement of whether the
operal'Or intends to request authorization under 20 AAC 25.080 ('Or an annular disposal operation in the well.,:
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 II 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.
Phillips Alaska does not intend to request authorization for the use of this well for annular disposal
operations. \"'"'ó\- ~~;\ \) \~ I ~1Do.." ~\j\ ~
15. Attachments
Attachment 1 Directional Plan
Attachment 2 Diagram and Description of the Blowout Prevention Equipment, Nabors Rig 245e
Attachment 3 Drilling Hazards Summary
Attachment 4 Formation Integrity Test Procedure
Attachment 5 Cement Loads and CemCADE Summary.
Attachment 6 Diagram and Description of the Diverter System, Nabors Rig 245e
Attachment 7 Diagram of the Mud System, Nabors Rig 245e
Attachment 8 Well Schematic.
OR G. NAL
1C-133 PERMIT IT. DOC
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210 -
420 -
630 -
840 -
1050 -
1260 -
1470 -
,.-....
-I-
Q) 1680-
Q)
'+-
'--"
..c 1890-
-I-
c..
Q)
0
2100-
0
Ü
:¡:: 2310-
!....
Q)
>
Q) 2520 -
::J
!....
I-
I 2730-
V
2940 -
3150 -
3360 -
)
ì:,
!
~HI~Lfp5'~
r¡T¡¡
~
Created by finch For: S McKeever
Dote ploUed : 29-Mor-2001
Plot Reference i. 1 JJ Version #J.
Coordinates ore in feet reference slot # 1 JJ,
True Vertical Depth. ore reference Est. RKB 91',
1I,,1i
IIfØ.s
Phillips Alaska, Inc.
Structure: Pad 1 C
Well: 133
;.
-~
0 - ð EST. RKB ELEVATION: 91'
Field: Kuparuk River Unit Location: North Slope. Alaska
177.41 AZIMUTH
1157' (TO TARGET)
***Plane of Proposal***
INTII,Q
East (feet) - >
320
160
80
160
240
KOP
.. 2.00
.. 4.00
.. 6.00
.. 8.00
DLS: 2.00 deg per 100 ft
240
80
Begin Turn
10.98
12.60
3570 -
ESTIMATED
SURFACE LOCATION:
1689' FNL, 997' FWL
SEC. 12. T11N, R10E
~~
! m T,m
14.66 DLS: 3.00 deg per 100 ft
16.99
19.51
22.14
24.85 Bose Permafrost
27.62
30,43
33.26
EOC
Top K-15
Begin Drop
35.00
32.50
30.00
27,50
25.00
22.50
20,00
17.50
3780- TARGET ANGLE
VERTICAL
3990 -
4200 -
4410 -
0
210
420
630
840
.. Bose Permafrost
MAXIMUM ANGLE
35.97 DEG
DLS: 2.50 deg per 100 ft
Vertical Section (feet) ->
Top Ugnu C
..
"
"
15.00
12.50 Top Ugnu B
10.00 Top Ugnu A
7.50 K13
5 0 Casing X/O pt
. 0 Top W Sak D
2.50 ~
A4
Target A3/EOC
A2
Top Ugnu B
Top Ugnu A
Target A3/EOC
TO - Casing Pt
u
..
A 1 Bose Pay
Bose W Sak
~l
TO - Casing pt
1050
1260
Azimuth 177.41 with reference 0.00 N. 0.00 E from slot # 133
TARGET/TO LOCATION:
2434' FSL. 1047' FWL
SEC. 12, T11N. R10E
OR.'GNAL
320
- 80
- 0
- 80
- 160
- 240
- 320
- 400
- 480
(J)
0
- 560 C
-
:::r
,.-....
- 640 -
CD
CD
-+
'--"
- 720 I
V
- 800
- 880
- 960
- 1040
-1120
- 1200
- 1280
- 1360
)
Phillips Alaska, Inc.
Pad 1C
133
slot #133
Kuparuk River Unit
North Slope, Alaska
PRO P 0 S ALL 1ST I N G
by
Baker Hughes INTEQ
Your ref: 133 Version #3
Our ref: prop1915
License:
Date printed: 26-Mar-2001
Date created: 25-0ct-1996
Last revised: 26-Mar-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 28.561,w149 29 50.024
Slot Grid coordinates are N 5968547.449, E 562004.240
Slot local coordinates are 1689.00 S 997.00 E
Projection type: alaska - Zone 4, Spheroid: Clarke - 1866
Reference North is True North
OR G NAL
Grid Report
Page 1 of 3
")
)
Phillips Alaska, Inc. PROP08AL LI8TING Page 1
Pad 1C,133 Your ref : 133 Version #3
Kuparuk River Unit,North 8lope, Alaska Last revised : 26-Mar-2001
Measured Inc lin Azimuth True Vert R E C TAN G U L A R G RID COO R D 8 G E 0 G R A PHI C
Depth Degrees Degrees Depth COO R DIN ATE 8 Easting Northing COO R D I N ATE 8
0.00 0.00 236.00 0.00 O.OON O.OOE 562004.24 5968547.45 n70 19 28.56 w149 29 50.02
500.00 0.00 236.00 500.00 O.OON O.OOE 562004.24 5968547.45 n70 19 28.56 w149 29 50.02
600.00 0.00 236.00 600.00 O.OON O.OOE 562004.24 5968547.45 n70 19 28.56 w149 29 50.02
700.00 2.00 236.00 699.98 0.988 1. 45W 562002.80 5968546.46 n70 19 28.55 w149 29 50.07
800.00 4.00 236.00 799.84 3.908 5.79W 561998.49 5968543.50 n70 19 28.52 w149 29 50.19
900.00 6.00 236.00 899.45 8.788 13 .01W 561991.30 5968538.57 n70 19 28.47 w149 29 50.40
1000.00 8.00 236.00 998.70 15.598 23.11W 561981.26 5968531.67 n70 19 28.41 w149 29 50.70
1l00.00 10.00 236.00 1097.47 24.348 36.08W 561968.36 5968522.82 n70 19 28.32 w149 29 51.08
1200.00 10.98 220.35 1195.81 36.458 49.45W 561955.10 5968510.60 n70 19 28.20 w149 29 51. 47
1300.00 12.60 207.95 1293.72 53.348 60.73W 561943.96 5968493.62 n70 19 28.04 w149 29 51. 80
1400.00 14.66 198.66 1390.91 74.978 69.89W 561934.97 5968471.92 n70 19 27.82 w149 29 52.06
1500.00 16.99 191.73 1487.12 101. 278 76. 91W 561928.16 5968445.56 n70 19 27.57 w149 29 52.27
1600.00 19.51 186.49 1582.09 132.188 81.77W 561923.56 5968414.62 n70 19 27.26 w149 29 52.41
1700.00 22.14 182.43 1675.55 167.608 84.45W 561921.16 5968379.18 n70 19 26.91 w149 29 52.49
1800.00 24.85 179.20 1767.26 207.458 84.96W 561920.98 5968339.34 n70 19 26.52 w149 29 52.50
1844.02 26.06 177.98 1807.00 226.368 84.49W 561921.60 5968320.43 n70 19 26.34 w149 29 52.49
1900.00 27.62 176.57 1856.95 251.618 83.28W 561923.02 5968295.20 n70 19 26.09 w149 29 52.46
2000.00 30.43 174.40 1944.39 299.968 79. 42W 561927.27 5968246.89 n70 19 25.61 w149 29 52.34
2100.00 33.26 172.56 2029.33 352.368 73.39W 561933.72 5968194.54 n70 19 25.10 w149 29 52.17
2194.48 35.97 171.06 2107.08 405.488 65. 72W 561941.82 5968141.49 n70 19 24.57 w149 29 51.94
2409.37 35.97 171.06 2281.00 530.168 46 . lOW 561962.45 5968016.98 n70 19 23.35 w149 29 51. 37
2500.00 35.97 171.06 2354.35 582.748 37.83W 561971.15 5967964.48 n70 19 22.83 w149 29 51.13
2744.10 35.97 171.06 2551. 91 724.378 15.55W 561994.58 5967823.05 n70 19 21.44 w149 29 50.48
2782.85 35.00 171.06 2583.46 746.598 12.05W 561998.26 5967800.86 n70 19 21. 22 w149 29 50.38
2882.85 32.50 171.06 2666.60 801.478 3.42W 562007.34 5967746.06 n70 19 20.68 w149 29 50.13
2982.85 30.00 171. 06 2752.08 852.718 4.65E 562015.82 5967694.89 n70 19 20.17 w149 29 49.89
3082.85 27.50 171.06 2839.75 900.228 12.12E 562023.68 5967647.44 n70 19 19.71 w149 29 49.67
3182.85 25.00 171.06 2929.43 943.918 18.99E 562030.91 5967603.82 n70 19 19.28 w149 29 49.47
3282.85 22.50 171. 06 3020.95 983.698 25.25E 562037.49 5967564.09 n70 19 18.89 w149 29 49.29
3382.85 20.00 171. 06 3114.15 1019.498 30.89E 562043.41 5967528.34 n70 19 18.53 w149 29 49.13
3439.91 18.57 171.06 3168.00 1038.118 33.82E 562046.49 5967509.75 n70 19 18.35 w149 29 49.04
3482.85 17.50 171.06 3208.83 1051. 248 35.88E 562048.66 5967496.64 n70 19 18.22 w149 29 48.98
3582.85 15.00 171.06 3304.83 1078.888 40.23E 562053.24 5967469.03 n70 19 17.95 w149 29 48.85
3682.85 12.50 171.06 3401.96 1102.368 43.93E 562057.12 5967445.59 n70 19 17.72 w149 29 48.75
3720.73 11.55 171. 06 3439.00 1110.158 45.15E 562058.41 5967437.80 n70 19 17.64 w149 29 48.71
3779.78 10.08 171.06 3497.00 1121.108 46.87E 562060.22 5967426.88 n70 19 17.54 w149 29 48.66
3782.85 10.00 171. 06 3500.03 1121.638 46.96E 562060.31 5967426.35 n70 19 17.53 w149 29 48.66
3882.85 7.50 171. 06 3598.86 1136.668 49.32E 562062.80 5967411.34 n70 19 17.38 w149 29 48.59
3916.25 6.67 171.06 3632.00 1140.728 49.96E 562063.47 5967407.28 n70 19 17.34 w149 29 48.57
3940.76 6.05 171.06 3656.36 1143.408 50.38E 562063.91 5967404.60 n70 19 17.32 w149 29 48.56
"toO ~~S")
3982.85 5.00 171.06 3698.25 1147.418 51. OlE 562064.57 5967400.60 n70 19 17.28 w149 29 48.54
4040.76 3.55 171.06 3756.00 1151.678 51.68E 562065.28 5967396.34 n70 19 17.23 w149 29 48.52
4075.81 2.68 171.06 3791.00 1153.568 51.98E 562065.59 5967394.47 n70 19 17.22 w149 29 48.51
4082.85 2.50 171.06 3798.03 1153.878 52.03E 562065.64 5967394.15 n70 19 17.21 w149 29 48.51
4102.84 2.00 171.06 3818.00 1154.648 52.15E 562065.77 5967393.38 n70 19 17.21 w149 29 48.51
4136.85 1.15 171.06 3852.00 1155. 578 52.30E 562065.92 5967392.46 n70 19 17.20 w149 29 48.50
4182.85 0.00 171. 06 3898.00 1156.028 52.37E 562066.00 5967392.00 n70 19 17.19 w149 29 48.50
4253.85 0.00 171. 06 3969.00 1156.028 52.37E 562066.00 5967392.00 n70 19 17.19 w149 29 48.50
4360.85 0.00 171.06 4076.00 1156.028 52.37E 562066.00 5967392.00 n70 19 17.19 w149 29 48.50
4455.85 0.00 171. 06 4171.00 1156.028 52.37E 562066.00 5967392.00 n70 19 17.19 w149 29 48.50
OR G NAL
Grid Report
Page 2 of 3
)
All data in feet unless otherwise stated. Calculation uses minimum curvature method.
Coordinates from slot #133 and TVD from Est. RKB 91' (91.00 Ft above mean sea level).
Bottom hole distance is 1157.21 on azimuth 177.41 degrees from wellhead.
Total Dogleg for wel1path is 78.80 degrees.
Vertical section is from wellhead on azimuth 177.41 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. PROP08AL LI8TING Page 2
Pad 1C,133 Your ref : 133 Version #3
Kuparuk River Unit,North 8lope, Alaska Last revised : 26-Mar-2001
Measured Inclin Azimuth True Vert R E C TANGU L A R G RID COO R D 8 G E 0 G R A PHI C
Depth Degrees Degrees Depth COO R DIN A T E 8 Easting Northing COO R D I N ATE 8
4500.00 0.00 171.06 4215.15 1156.028 52.37E 562066.00 5967392.00 n70 19 17.19 w149 29 48.50
4610.85 0.00 171. 06 4326.00 1156.028 52.37E 562066.00 5967392.00 n70 19 17.19 w149 29 48.50
All data in feet unless otherwise stated. Calculation uses minimum curvature method.
Coordinates from slot #133 and TVD from Est. RKB 91' (91.00 Ft above mean sea level).
Bottom hole distance is 1157.21 on azimuth 177.41 degrees from wellhead.
Total Dogleg for wellpath is 78.80 degrees.
Vertical section is from wellhead on azimuth 177.41 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,133
Kuparuk River Unit,North 8lope, Alaska
PROP08AL LI8TING Page 3
Your ref: 133 Version #3
Last revised: 26-Mar-2001
Comments in wellpath
--------------------
--------------------
MD
TVD
Rectangular Coords.
Comment
-----------------------------------------------------------------------------------------------------------
600.00 600.00 O.OON O.OOE KOP
1100.00 1097.47 24.348 36.08W Begin Turn
1844.02 1807.00 226.368 84.49W Base Permafrost
2194.48 2107.08 405.488 65. 72W EOC
2409.37 2281. 00 530.168 46 . lOW Top K-15
2744.10 2551.91 724.378 15.55W Begin Drop
3439.91 3168.00 1038.118 33.82E Top Ugnu C
3720.73 3439.00 1110.158 45.15E Top Ugnu B
3779.78 3497.00 1121.108 46.87E Top Ugnu A
3916.25 3632.00 1140.728 49.96E K13
3940.76 3656.36 1143.408 50.38E Casing x/a pt
4040.76 3756.00 1151.678 51.68E Top W 8ak D
4075.81 3791.00 1153.568 51.98E C
4102.84 3818.00 1154.648 52.15E B
4136.85 3852.00 1155.578 52.30E A4
4182.85 3898.00 1156.028 52.37E W8 1C K6 (5-DEC-00)
4253.85 3969.00 1156.028 52.37E A2
4360.85 4076.00 1156.028 52.37E A1 Base Pay
4455.85 4171.00 1156.028 52.37E Base W 8ak
4610.85 4326.00 1156.028 52.37E TD - Casing pt
Casing positions in string 'A'
------------------------------
------------------------------
Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing
-----------------------------------------------------------------------------------------------------------
0.00
0.00
O.OON
O.OOE 4610.85 4326.00
1156.028
52.37E 3 1/2 Casing
Targets associated with this wellpath
-------------------------------------
-------------------------------------
Target name
Geographic Location
T.V.D.
Rectangular Coordinates
Revised
-----------------------------------------------------------------------------------------------------------
WS lC K6 (5-DEC-00) 562066.000,5967392.000,0.0000 3898.00
1156.028
52.37E
8-Jan-2001
OR, G NA-
Grid Report
Page 3 of 3
Phillips Alaska, Inc.
Pad 1C
133
slot #133
Kuparuk River Unit
North Slope, Alaska
SUM MAR Y C LEA RAN C ERE P 0 R T
by
Baker Hughes INTEQ
Your ref: 133 Version #3
Our ref: prop1915
License:
Date printed: 26-Mar-2001
Date created: 25-0ct-1996
Last revised: 26-Mar-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 28.561,w149 29 50.024
Slot Grid coordinates are N 5968547.449, E 562004.240
Slot local coordinates are 1689.00 S 997.00 E
Projection type: alaska - Zone 4, Spheroid: Clarke - 1866
Object wellpath
GMS <0-7753'>, ,5,Pad 1C
GMS <0-10243'>,,6,Pad 1C
GMS <0-9784'>, ,7,Pad 1C
PGMS <0-9002'>,,10GI,Pad 1C
Unknown Data"WS1,Pad 1C
PMSS <0 - 10969'),,17,Pad 1C
PMSS <0-8677'>,,13,Pad 1C
PMSS <0 - 11918'>,,16,Pad 1C
MSS <0-7000'>,,9GI,Pad 1C
PMSS <0-6529'>,,23 PB1,Pad 1C
PMSS <1840-13975>,,23A,Pad lC
PMSS <0-10140'>,,25,Pad 1C
PMSS <0-13910'>,,27,Pad 1C
PMSS <0-14630'>, ,26,Pad 1C
PMSS <0 - 8095'>, ,18,Pad 1C
GMS <0-7780'>"l,Pad 1C
PMSS <0-9390'>,,15,Pad 1C
PMSS <0-10980'>, ,14,Pad 1C
GMS <0-7575'>, ,4,Pad 1C
MMS <6948-7570'>"WS#24,Pad lC
GMS <0-9600'>, ,8,Pad 1C
PMSS <0-11300'>, ,11,Pad 1C
PMSS <0-17089'>,,12,Pad 1C
GMS <0-7615'>, ,2,Pad 1C
GMS <0-9700'>, ,3,Pad 1C
Reference North is True North
Closest approach with 3-D
Last revised Distance
18-Dec-1998 242.9
18-Dec-1998 334.3
18-Dec-1998 439.4
18-Dec-1998 203.6
2-Nov-1998 7509.9
2-Dec-1998 524.2
1-Dec-1998 314.5
8-Jan-1999 291.3
2-Jan-1998 531.2
13-Jul-1999 281.5
8-Jun-1999 281.5
4-Jun-1999 327.6
1-Jan-1999 355.6
24-Aug-1999 342.2
22-Feb-1999 211.0
11-Mar-1999 368.1
17-Dec-1998 248.2
18-Mar-1998 187.8
18-Dec-1998 187.1
17-Dec-1997 10668.8
18-Dec-1998 551.8
19-Mar-1997 586.4
7-Jan-1998 571.0
18-Dec-1998 239.3
18-Dec-1998 63.9
Minimum Distance method
M.D. Diverging from M.D.
0.0 612.5
480.0 480.0
380.0 380.0
1611.1 1611.1
1144.4 1144.4
100.0 100.0
280.0 280.0
100.0 100.0
1200.0 1200.0
0.0 0.0
0.0 0.0
400.0 400.0
0.0 0.0
600.0 600.0
260.0 260.0
600.0 600.0
100.0 100.0
160.0 160.0
160.0 160.0
4610.9 4610.9
0.0 862.5
280.0 280.0
420.0 420.0
4280.0 4280.0
1633.3 1633.3
OR G I VA Lsummary Clearance Report
I , I Page 1 of 1
)
Created by finch For: S McKeever
Data plotted: 26-t.1or-2001
Plot Rorerence ie 133 Version 63.
Coordinatell Ofe i" fcet roforonce slot *133.
True Vortical Depths ore reference Est. RKB 91',
Structure: Pad 1 C
Well: 133
~
~
~
Phillips Alaska, Inc.
Field: Kuparuk River Unit Location: North Slope. Alaska
Im.B
~
INTF.Q
250
ð)
240
TRUE NORTH
~
340
350 ~
I
330
30
320
40
~310
¡If 300
60
70
280
80
270
90
260
100
11 0
120
230
130
190
~
Normal Plane
All depths shown are
\
\
\
\
\
\
200 \
\
\
140
150
160
180
170
Travelling Cylinder - Feet
Measured depths on Reference Well
OR 'G NA~
")
Phillips Alaska, Inc. ~
Created by finch For: S McKeever Structure: Pod 1 C Well: 133 rdi
Dote plotted: 26-Mar-2D01
Plot Referenco is 133 Version 113. Field: Kuporuk River Unit Locotion : North Slope. Alosko ~i
Coordinates are in feøt reference slot #133.
Truo Vortic:ol Dopths ore referonco Est. RKB 91',
Bii&1I
-=-
INTF.Q
<- West (feet)
200 180 160 140 120 100 80 60 40 20 0 20 40 60 80 100 120
I I
~ & &> <& - 40
40 - \'ì-":ì / / 800 / ..1'/600 \
/ -$-300
/ / -"700
20 - )II( 900
/ / / ... -$- 300 - 20
/ ... )1</800
/ / / /"'500
...
0 - /""1000 ... / / .. 600 800 ;r./@ 300
/ / / - 0
/ / )1</900 / / .;00 900..1'/
-&
/ / 1009... /
20 - / - 20
/ / 'II' 800 11°D,;./ /
/ /
/ / /
/ / 1200,1 /
/ I
40 - (fJ)/Ii 1000 /900 1 - 40
- ,-V I 1
I 1300".1
I
60 - / / - 60
/ /
/ /
.. 1000 I
80 - I 1400"
I I - 80
I I
I I
I I
100 - I - 100
I
I
........... I (j)
- J 1100
( ,) 120 - -120 0
( ,) I C
- I -
'-" I :y
...c 140 - I -140 /"""'.
- I ' -
:J I I CD
CD
0 I I -
If') 160 - I I - 160 '-"
I I I I
I I
V I ~ 1700 V
180 - ;/.1200 - 180
I I
I I
, I
200 - ' I - 200
I 1
, I
I
, I
220 - , J. 1800 -220
I I
I I
I I
240 - I I -240
I I
I I
, 1300 I
260 - I - 260
I
I
J. 1900
280 - I - 280
I
I
I
I
300 - I - 300
I
I
\
320 - I - 320
I
340 ~ ~ 340
200 180 160 140 120 100 80 60 40 20 20 40 60 80 100 120
<- West (feet)
OR 'GNA~
')
')
Phillips Alaska, Inc. ~
Croatod by finch For: S McKeever Structure: Pad 1 C Well: 133
Doto plottod : 26-Mor-200 1 CÐ
Plot Raforonce is , 33 Version *3. Field: Kuparuk River Unit Location: North Slope. Alaska ~
CODrdlnates ore in teet reference slot '133.
True Vortical Depths ora reference Est. RKB 91',
BíllI
Bf&'Iu
INTF.Q
<- West (feet)
640 560 480 400 320 240 160 80 80 160 240 320 400 480 560
80 ' ~Ø> '180'0 ~ I I I 80
1~09... ø ~600
/ / 11200
160 - / / / I I - 160
/ / /.. 1600 .¡ 1200,
/ /.1400
-$/ / I I I .. 2400
/ I ' .1800
240 - '" / I I I
I - 240
/ / I I I
/ I I
/ / I I
/ / I I .. 2600
320 - / I 0\. 2000
-@5 / , 1400 \
I
I I \
400 - I I \ .. 2800 - 400
I I \
I I I
I
I \ ~ 2200
480 - I I - 480
I I \
I I \ .. 3000
I I \
I
560 - I I \ - 560
I ~ 1600 \
I \
I I 0\. 2400
I I \
640 - I I \ .. 3200 - 640
I
I I \
-(f¡ I \
",-.., I \
Q) 720 - I \ - 720 (/)
I ~ 2600 0
Q) I C
'+- I \ .. 3400 -
"--" 800 - I \ - 800 :!"
...c: .1800 \ .........
-+- I \ -
::s I \ CD
0 880 - I \ 2800 - 880 CD
(f) I -
I \ .. 3600 -.-
I I \ I
V 960 - I \ V
I , 3000 - 960
I
I \
I \
1040 - .. 2000 \ 3200 .. 3800 - 1040
I
I \
I 0\. 3400
1120 - I \ - 1120
I . 3600
I g 3800
1.3.3 .. 4000
I
1200 - I - 1200
I
I
I
1280 - - 1280
.. 4200
1360 - - 1360
. 4400
1440 - - 1440
1520 - - 1520
. 4600
1600 ~ 1600
640 560 480 400 320 240 160 80 80 160 240 320 400 480 560
<- West (feet)
OR, 'G NA~
Diagram and Description of the Blowout ~revention
EquipJent, Nabors Rig 245e )
West Sak Injector Wells, Kuparuk River Unit
..---.S c:L
8
~ ~
~ Þ
7
~ Þ
~ 6 ~
~ ~
~ 5 Þ
[ ]
4
[ ]
3
(t ~[ ]
Top of Tubing Head:
Elevation is 33 inches 2
above pad level.
j' .'
I I
I I
I I
I I
I I
, ,
I ,
I ,
I I
5-1/2" Casing !! ~
16" Casing ~
KEY:
1. Landing Ring, 16" x 13-5/8", Vetco Gray, with 5-1/2" Casing
Landed, Vetco Gray.
2. Tubing Head, 10-3/4" Vetco Gray Quick Connect Bottom x API
7-1/16" 5000 psi Flange Up, Vetco Gray.
3. Double Studded Adapter I Spacer Spool, 7-1/16" x
13-5/8" 5000 psi, Nabors.
4. Spacer Spool, 13-5/8" 5000 psi x 13-5/8" 5000 psi, Nabors.
5. Single Ram BOP, 13-5/8" x 5000 psi, with pipe rams.., Nabors
6. Drilling Spool, 13-5/8" x 5000 psi, wI 2 Side Outlets, Nabors
7. Double Ram BOP,13-5/8" x 5000 psi, with Pipe Rams.. on
Top and Blind Rams on Bottom, Nabors
8. Annular BOP, 13-5/8" x 5000 psi, Hydril GK, Nabors
9. Choke Valve, Manual Operation, 4-1/16" x 5,000 psi, Nabors
10. Choke Valve, Hydraulically Operated, 4-1/16" x 5,000 psi, Nabors
11. Kill Line Valve, Manual Operation, 3-1/8" x 5,000 psi, Nabors
12. 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 low 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.
** Variable Bore Rams will accomodate 3-1/2" to 6" or 4-1/2" to 7"
pipe OD's as appropriate ..
OR 'G NA~
prepared by
Steve McKeever
4/26/01
)
lC-133 Drillinq Hazards Summary
)
(SEE WELL PLAN FOR DETAILED DISCUSSION OF THESE RISKS)
7-7/8" Open Hole / 5-1/2" x 3-1/2" Casina Interval
Hazard
Broach of Conductor
Risk Level I Mitigation Strategy
Moderate Monitor cellar continuously during interval.
Gas Hyd rates
Moderate
Running Sands and
Gravels
Moderate
Abnormal Reservoir
Pressure
Lost circulation
Hole swabbing on trips
Low
Low
Moderate
Control drill, Reduced pump rates, Reduced
drilling fluid temperatures, Additions of
d ri Itreat.
Maintain planned mud parameters,
Increase mud weight, use weighted
sweeps, run gravel isolation strinq.
Diverter drills, increased mud weight.
Reduced pump rates, mud rheology, LCM
Trip speeds, Proper hole filling, pumping
out
0 R G - NA [-133 Drilling Hazards Summary
prepared by Mark Chambers
2/18/01
)
PHilliPS AlasKa, Inc.
A Subsidiary of PHILLIPS PETROLEUM COMPANY
}
FORMATION INTEGRITY TEST PROCEDURE
Kuparuk River Unit Drilling Operations
1. After cementing casing and nippling up BOPE, RIH to top of cement and pressure test the
casing to the test pressure specified in the well plan (usually 3000 psi or 3500 psi) for 30
minutes and record on chart (AOGCC required casing integrity test). Record the information
on the PAl LOT form (you can locate on the drilling web page). Plot Casing Pressure Test
(volume vs. pressure and time holding pressure on casing). Verify that the test indicates a
linear line and that there is no air entrained in the mud. Repeat Casing pressure test if
needed.
2. Drill 20. to 50' of new hole below the casing shoe.
3. Circulate the hole to establish a uniform mud density throughout the system (required for a
good FIT or LOT). PU into the shoe.
4. Close the blowout preventer (ram or annular).
5. Pump down the drill stem at 1/4 to 1/2 bpm.
6. On the LOT form, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until the
formation begins to take fluid; at this point the pressure will continue to rise, but at a slower
rate.
Note: If 16.0 ppg EMW is reached, shut down and hold the pressure there. This
becomes the data for a formation integrity test (FIT) instead of a LOT
7. At leak off pump 3 bbls of mud into formation prior to shutting down the pump.
8. Shut down when the leak-off point is clearly seen and 3 bbls of mud has been pumped into the
formation. Record initial shut-in pressure. With the pump shut down monitor, record and
report the shut -in pressures for a minimum of 10 minutes or until the shut -in pressure
stabilizes. Record time vs. pressure in 1-minute intervals and plot information. Bleed the
pressure off and record the fluid volume recovered. Forward the data to the Drilling
Engineer in Anchorage. The Drilling Engineer will forward the information to the Agencies.
0: G NA-
PAl FIT LOT Procedure 042601.doc
Page 1 of 1
4/26/01
West Sak lC-133 Mono~,Je Injector, Cement Loads and Cem\...lDE Summary.
45 % Excess Below permafrost, 300 % Above.
7-7/8" Openhole. TD @ 4611' MD.
5-1/2" X 3-1/2" Tapered String. 5-1/2" X 3-1/2" Cross over @ 3941'MD.
Single Stage Design. Tail Slurry TOC @ 3441' MD. (500' above Cross Over)
Port collar for no cement to surface contingency. Port Collar @ 1000' MD
Base of permafrost @ 1844' MD.
Volume Cales:
Pump 40 bbls CW preflush, 40 bbls MudPUSH XL @ 10.2 ppg. Cement from TD to
3441' MD with Class G + adds @ 15.8 ppg, and from 3441' to surface with ASLite @
10.7 ppg.
Lead Slurry Requirements:
ASLite @ 10.7 ppg, Class G + 50% D124, 3.5% D44, 0.4% D46, 30% D53,
1.5% SI, 1.5% D79 - 4.44 ft3/sk
(3441' - 1844') x 0.1733 ft3/ft x 1.45 (45% excess)
1844' x 0.1733 x 4 (300% excess)
401.39 ft3 + 1278.26 ft3
1679.56 ft3/4.44 ft3/sk
= 401.30 ft3
= 1278.26 ft3
= 1679.56 ft3
= 378 sks
Round up to 390 sks
Tail Slurry Requirements:
Expanding Cement @ 15.8 ppg, Class G + 0.3% D65, 0.2% D800, 2.0 gps
D600G, 0.15% D35, 0.2% D47, 4.5% D174 - 1.22 ft3/sk
(4611' - 3941') x 0.2714 ft3/ft x 1.45 (45% excess)
(3941' - 3441') x 0.1733 ft3/ft x 1.45 (45% excess)
80' (shoe joints) x 0.0488 ft3/ft
263.66 ft3 + 125.64 ft3 + 3.90 ft3
393.20 ft3/l.22 ft3/sk
= 263.66 ft3
= 125.64 ft3
= 3.90 ft3
= 393.20 ft3
= 322 sks
Round up to 330 sks
CemCADE* Summary:
Fluid sequence: Establish circulation using FW. 40 bbl CW 1 00 preflush, Drop
Bottom Plug, 40 bbls 10.2 ppg MudPUSH XL spacer, 390 sks (308 bbls) ASLite
Lead, 330 sks (72 bbls) Class G + adds, Drop Top Plug. Displacement is
approximately 100 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.
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 < 20, Ty < 20, as thin and light as possible for effective mud
removal.
OR. 'G NA-
Diagram an )Description of the Di' )rter System,
Nabors Rig 245e
West Sak Wells, Kuparuk River Unit
~
~
~
L
<
---.J
Open
- -----------þ¡
t- - - - - - - ~ To Accumulator
I
Closed' -:-,
-+-------_J I '--I
I 1
I 1 From
: r- - - -. Accumulator
I 1
I 1
I 1
I I
I I
I I
I I
Closed I I
1 I
1 I
- --_J 1
1
D -----_..: Open
Maintenance & Operation
5
4
~
6
~
7 ~
1. Upon initial installation:
Close valve and fill preventer with water to
ensure no leaks
Close annular preventer. Verify that preventer
closes and and that the knife valve opens
immediately.
3
2. In the event of a kick, close annular preventer.
Knife valve will open automatically.
3" Threaded Outle~
with Ball Valv~"\
1
~ ~
Bottom of Lower Spool:
Elevation is 0.25 inches
...., BELOW pad level.
b3" Threaded Outlet
1 ~ith Ball Valve
DO NOT SHUT-IN DIVERTER
AND VALVE AT SAME TIME
UNDER ANY CIRCUMSTANCES
2
I
~
KEY:
1. Conductor Casing: 1611
2. Starting Head: 1611 2000 psi slip-on, weld-on bottom x 13-3/811 male overshot top - Vetco Gray
3. Lower Spool: 13-5/811 2000 psi female overshot bottom x 21-1/411 - 2,000 psi flange top - Nabors
4. Diverter Spool: Flanged 21-1/411 2000 psi bottom and top, with 1611 side outlet - Nabors
5. Annular Preventer: Hydril Model MSP, 21-1/411 x 2,000 psi, flanged bottom, studded top - Nabors
6. Knife Valve: 1611: The valve opens automatically upon closure of annular preventer - Nabors
7. Diverter Line: 1611 - Nabors
OR G NA-
prepared by
Steve McKeever
4/26/01
Well # 1C-133, AFE #AK0157
West Sak M bbore Injector
5-1/211 x 3-1/211 Tapered String
Planned Completion Schematic v1.0
Christmas Tree:
Vetco-Gray, API 5K 7-1/16" Flange
Bottom x API 5K 3-1/8" Valves, with
Otis 3-1/8" 5K Tree Top
Tubing Head:
Vetco-Gray, 10-3/4" Gray
Quick Connect Bottom x
API 5K 7-1/16" Flange Top
1611 Conductor
@ +1-161' MD
~l,
Port Collar @ 1000' MD:
TAM 5-1/2" BTC Box x Pin
--4
~
I¡
i
Production Tubing:
3-1/2" 9.3# L-80 EUE 8rd, AB
Modified.
...
Production Casing
5-1/2" 15.5# L-80 BTCM
XO / SBE to surface
Set XO / SBE +/- 100' above
top Perforation
,
.,------~
~..""a""w "0""
"".......,,,,,,,",,,,..,
...
Production Casing
3-1/2" 9.3# L-80 EUE 8RD-Mod
TO to XO / SBE
TD 7-7/811 Hole
4622' MD, 4337' TVD
~
)HILLIPS Alaska, Inc.
A Subsidiary of PHILLIPS PETROLEUM COMPANY
11
¡
il
Tubing Hanger:
3-1/2" Vetco-Gray w/ 3-1/2" pup (EUE
8rd, AB Mod pin) down x 3.725" MCA
box up .
Casmg Hanger:
5-1/2" Vetco-Gray w/ 5-1/2" pup
(BTCM pin) down x 7.790" MCA box
L up
Landing Ring:
Vetco-Gray, 16" Weld on Bottom
x 13-5/8" Male Overshot Top
Nabors Rig 245 RKB @ 0'
Eastings: 562,005.5
Northings: 5,968,547.4
Elevation: 101.6' AMSL
Gas Lift Mandrel:
3-1/2" x 1" Cameo 'KBG-2-9' w/ dummy valve, IBT special
clearance box up x IBT special clearance box down, with 6-
foot tubing handling pups (XO to EUE 8rd) installed on top
and bottom.
(1) Joint Tubing: 3-1/2", 9.3#, L-80, EUE 8rd AB Mod
Landing Nipple: 3-1/2" Cameo 'OS' w/ 2.812" No-Go Profile.
(1) Joint Tubing: 3-1/2",9.3#, L-80, EUE 8rd AB Mod
Locator Seal Assembly: 3-1/2" Baker GBH-22 '80-40' w/ 12' of
Seals and Locator, 3-1/2" x 6' L-80 Handling Pup installed on top.
EUE 8rd AB Mod Box up.
Casing Bore Receptacle Assembly @ +1- 3952' MD, 3667' TVD:
Baker 5-1/2" XO / Handling Pup, BTC x LTC
Baker XO Coupling w/ locator shoulder, LTC x SBE
Baker 5" 00 x 4" 10 Seal Bore Extension 12'
- Baker XO, SBE x 3-1/2" EUE 8rd
(x) Joints Tubing: 3-1/2",9.3#, L-80, EUE 8rd AB Mod, from
Landing Sleeve to Seal Bore Extension
Landing Sleeve: 3-1/2" Weatherford, installed in top of joint #3.
(1) Joint Tubing: 3-1/2",9.3#, L-80, EUE 8rd AB Mod
Float Collar: 3-1/2" Weatherford w/ 3-1/2" EUE 8rd Box x Pin.
(2) Joints Tubing: 3-1/2",9.3#, L-80, EUE 8rd AB Mod
Float Shoe: 3-1/2" Weatherford w/ 3-1/2" EUE 8rd Box Up.
OR GNA-
1C-133 Schematic v1.0
prepared by Steve McKeever
04/26/01
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DIMENSIDNS IN INCIÐ
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ES501 PART NUMBER I.D.
ESSDO GENERAL TILERANCES
ENGINEERING SPECIFICATmNS
PARKER TECHNDLDGY. INC.
LOW PRESSURE MUD MIXING AND
TRANSFER SYS - PROCESS FLOW DIA(
:t:E 1171\NRI PF -156-001
/PHilLIPS" PHILLIP''')Alaska, Inc.
T¡'1"fI A Subsidiary of PHILLIPS PETROLEUM COMPANY
~
Post Office Box 100360
Anchorage, Alaska 99510-0360
)
James Trantham
Phone (907) 265-6434
Fax: (907) 265-1535
Email: jtranth@ppco.com
April 26, 2001
Re: Application for Permit to Drill, West Sak Injector lC-133
RECEIVED
APR 2 7 2001
Alaska Oil & Gas Cons '.
An"s.-- . CommISSIon
VI rvrage
Daniel T. Seamount, Jr., Chairman
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue
Suite 100
Anchorage, Alaska 99501
(907) 279-1433
Dear Commissioner Seamount:
Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore service well, #lC-133, an injector well
to provide pressure support for West Sak production.
Please find attached for the review of the Commission Form 10-401 and the information required by 20
ACC 25.005.
Please note that with this permit application Phillips is providing information required that is specific to
the drilling rig Phillips will be using to drill this well. This rig is Nabors Drilling Rig 245e (formerly Parker
Drilling Rig 245). Phillips requests that this information be placed "on file" with the Commission so that it
can be referred to, rather than included with, future applications. This information is:
Attachment 2 Diagram and Description of the Blowout Prevention Equipment, Nabors Rig 245e
Attachment 4 Formation Integrity Test Procedure
Attachment 5 Diagram and Description of the Diverter System, Nabors Rig 245e
Attachment 6 Diagram of the Mud System, Nabors Rig 245e
If you have any questions or require any further information, please contact me at 263-6434 or Steve
McKeever at 265-6826.
Si 1cerely,
" Q ()A.£cS ,tr-C(., \í CUI... I.A.-~
~mes Trantham
Drilling Engineering Supervisor
r\ r' ¡ ,"" 'i
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Anlt!rican, Expresse Cash,'"Advance,', "Draft
. . ..............'/i...iDAIE....tllJf/Yi/.wr...... ....'.~~ì~'
~~t:Z:iE.....'....\j¥{¡;tð:;Q....~...........9f;t!~r;ìørA1ð~4v~/l(.t~J 1 CO'"C, ~""Ô"'."""""""""'."'","""""',1",
---O/lLt tu. i .t&-ÿ'7 ~, ~1/o"IÞ." ~ '", """",,, "','
-- ' 1/ '~"', "'DOLLARS
Issued by Integrated Payment system, Inc.
E"Blewood, Colorado JL.' NO VALlDFOP-AMOUNTOVElt$I()OO
payab" le,atN, orWestBan",k,""of""G, rari~Ju",l1ctio,"'. n.;Downtown.NA " ' ""..,, ,.'SaAR",' ",", O",~,.',', ,",""",,",',,,,',',' ',B""ll PJt:t, ,," "",'.",',,'..,i,','.,,,".",",',',"',.','.,'..,..',,' ",.,.. ',.,..,"',".,.,.,
Grand Junction. Colorado ' ", 1 /J' " " ," ' ' 'I
PERIOO.ENOING \c'~ I =-~ ." ~"'-- -- '7' {/
1:.0 2. DOL. 00 I: lSII,IO.? SOOOSlb 1I10.2?
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WELL PERMIT CHECKLIST COMPANY ¡6'1ï/,~5 WELL NAME /~- /}:¡ PROGRAM: exp - dev - redrll- serv ~ well bore seg _ann. disposal para req-
FIELD & POOL '/9ð¡ Co INITCLASS I"~.~ GEOLAREA 3?/J UNIT# /IJt:~ ON/OFFSHORE ~fl¿
ADMINISTRATION 1. Permittee attached. . . . . . . . . . . . . . . . . . . . . . . ~ N
2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N
3. Unique well name and number. .. . . . . . . . . . . . . . . . y. N
4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N
5. Well located proper distance from drilling unit boundary. . . . Y N
6. Well located proper distance from other wells.. . . . . . . . . Y N
7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N.
8. If deviated, is wellbore plat included.. . . . . . . . . . . ... . Y N
9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N
10. Operator has appropriate bond in force. . . . . . . . . . . . . Y, N
11. Permit can be issued without conservation order. . . . . . . . Y N
12. Permit can.be issued without administrative approval.. . . . . Y N
13. Can permit be approved before 15-day wait.. . . . . . . . . . ~ N
14. Conductor string provided. . . . . . . . . . . . . . . . . . . N
15. Surface casing protects all known USDWs. . . . . . . . . . . . N
16. CMT vol adequate to circulate on conductor & surf csg. . . . . Y N
17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . -¥-H' ~ þ.. s.~ ~~~,.....~ ~""""'\.'1
18. CMT will cover all known productive horizons. . . . . . . . . . ~ N
19. Casing designs adequate for C, T, B & permafrost. . . . . . . ' N
20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N Q.,,, ~'> \-\ ¥".~ ~ l I f"\C ~ <:k..~a:: \>'-~
21. If a re-drill, has a 10-403 for abandonment been approved. . . ~Þ.r ::>
22. Adequate wellbore separation proposed.. . . . . . . . . . . . N
23. If diverter required, does it meet regulations. . . . . . . . . . N
24. Drilling ,fluid program schematic & equip list adequate. . . . . N '
25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N" \ ~ ' \ .\ \.. ~. ~-
V~~A ~TI')E . 26. BOPE press rating appropriate; testto .;2~Ù psig. N ~Q~ e ~~..."'\\ c~ ~~~ ~tt~CA.~ . . ~,-\.'\tA\ 'coJ"\ Q:Ò ð\)..,~')\'-R~~
~v"I' I II 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N .
28. Work will occur without operation shutdöwn. . . . . . . . . . . N '~
29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y @ ~ ~ \~ ~"\.,\o:\,,,," ~\ ~\ ~<è.~~\~~~ out s.~c;.~~ ~ c:a.\().~c;.
30. Permit can be issued wlo hydrogen sulfide measure,s. . . . '. ßy N
31. Data presented on P.otential overpressure zones. . . . . .. ,. Y ., hi) LJ
32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . N j7(. ''7.
APPR ..,PATij 33. Seabed condition survey (if off-shore). . . . .. . . . . . . . ' Y N . ,
~ fÞ</ðJ 34. Contact name/phone for weekly progress reports [exploratory Iy] Y N
ANNULAR DISPOSAL35. With proper cementing records, this plan . ""'-.)~ ~ ~\À\~~-==- -\0 CA.?~~~ð o.~,,~\~~ ot:... <::...,~\.,~ \3;"
(A) will contain waste in a suitable receiving zone; . . . . .. . Y N
(8) 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 MC 25.412. Y N
GEOLOGY: ENGINEERING: UIC/Annular COMMISSION:
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Well H istol)' File
APPENDIX
Information of detailed nature that is not
particularly germane to the Well Pennilling Process
but is part of the history file.
To improve the readability of the Well History file and to
sim'plify fìnding infomlation, information of this
nature is accumulated at the end of the file under APPENDIX.
No special effort has been made to chronologically '.
organize this category of information.
c!ds
Company:
Log Date:
Log No. :
Run No.:
Pipe1 Desc.:
Pipe1 Use:
Inspection Type:
COMMENTS:
Me~ory Multi-Finger Calipe~
Log Results Summary
CONOCOPHILLlPS ALASKA, INC.
August 2, 2005
6519
1
3.5" 9.3Ib. L-80
Tubing
Well: 1C-133
Field: Kuparuk
State: Alaska
API No.: 50-029-23013-00
Top Log IntvI1.: Surface
Bot. Log IntvI1.: 4,005 Ft. (MD)
Corrosive & Mechanical Damage Inspection
This caliper data is tied into the DS Nipple @ 3,910' (Driller's Depth).
This log was run to assess the condition ofthe 3.5" tubing with respect to corrosive and mechanical
damages. The 3.5" tubing appears to be in good to fair condition with respect to corrosive damage, with a
maximum wall penetration of 36% in joint 121 (3,807'). Wall penetrations ranging between 20% and 36%
are recorded in 48 of the 131 of the joints logged. A line of pits is recorded in the interval between joints 34
and 125 (1,100' - 4,005'). The damage appears in the forms of isolated pitting, general corrosion, and lines
of pits. No significant areas of cross-sectional wall loss or I.D. restrictions are recorded throughout the tubing
logged.
Cross-sectional drawings of the most significant events recorded are included in this report. The distribution
of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report.
MAXIMUM RECORDED WAll PENETRATIONS:
Line of Pits
Line of Pits
Line of Pits
Isolated Pitting
Line of Pits
( 36%)
( 33%)
( 31%)
( 31 %)
( 30%)
121 @
120 @
117 @
123 @
114 @
3,807 Ft. (MD)
3,783 Ft. (MD)
3,700 Ft. (MD)
3,902 Ft. (MD)
3,608 Ft. (MD)
Jt.
Jt.
Jt.
Jt.
Jt.
MAXIMUM RECORDED CROSS-SECTIONAL METAL lOSS:
No significant areas of cross-sectional wall loss (> 8%) are recorded.
MAXIMUM RECORDED ID RESTRICTIONS:
No significant I.D. restrictions are recorded.
8(Gt~~\U~ED ,AUG 2 fj¡ 20Q:j
I Field Engineer: N.Kesseru Analyst: M. Tahtouh Witness: C. Fitzpatrick I
ProActive Diagnostic Services, rile. I P.O. Box 1369¡ Stafford¡ TIC 77497
Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memoryiog.com
Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314
>;¡o,t,\j 77
~,.
Well:
Field:
Company:
Coun try:
1 C-133
Kuparuk
CONOCOPHILLlPS ALASKA, INC.
USA
I Tubing:
Weight
9.3 ppf
Grade & Thread
L-80
Nom.OD
3.5 ins
Penetration and Metal Loss (% wall)
_ penetration body
150
11Mj metal loss body
100
50
o 0 to
1%
1 to
10%
1 0 to 20 to 40 to ove r
20% 40% 85% 85%
Number of joints analysed (total = 131)
pene. 0 1 82 48 0
loss 4 1 27 0 0 0
o
o
Damage Configuration ( body)
80
60
40
20
o
isolated general line ring hole / poss
pitting corrosion corrosion corrosion ible hole
Number of joints damaged (total = 130)
38 30 62 0 0
PDS Report Overview
Body Region Analysis
Survey Date:
Tool Type:
Tool Size:
No. of Fingers:
Analyst:
NomJD
2.992 ins
Nom. Upset
3.5 ins
August 2, 2005
MFC 24 No. 00387
1.69
24
M. T ahtouh
Upper len.
1.2 ins
Lower len.
1.2 ins
Damage Profile (% wall)
_ penetration body
o
o
GLM 1
Bottom of Survey = 126
Analysis Overview page 2
R1I! metal loss body
50
100
50
100E
.
¡,...-..
~
-
PDS~KEPORT JOINTTABULATION(::>HEET
Pipe: 3.5 in 9.3 ppf L-80 Well: 1 C-133
Body Wall: 0.254 in Field: Kuparuk
Upset Wall: 0.254 in Company: CONOCOPHILLlPS ALASKA, INC.
NominaII.D.: 2.992 in Country: USA
Survey Date: August 2, 2005
Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile
No. (Ft.) Upset Body % Loss I.D. Comments (% wall)
(Ins.) (Ins.) (Yo (Ins.) 0 50 100
.1 38 0 0.03 10 .1 2.84 PUP
1 43 0 0.04 14 4 2.92 Shallow pitting.
2 74 0 0.04 15 6 2.93 Shallow corrosion.
3 106 0 0.04 15 5 2.93 Shallow corrosion.
4 136 0 0.04 14 7 2.94 Shallow pitting.
5 167 0 0.04 17 5 2.93 Shallow corrosion.
6 199 0 0.04 15 6 2.94 Shallow corrosion.
7 230 0 0.03 12 3 2.93 Shallow pitting.
8 261 0 0.04 17 6 2.93 Shallow corrosion.
9 293 0 0.03 13 5 2.92 Shallow pitting.
10 324 0 0.04 14 6 2.93 Shallow pitting.
11 356 0 0.04 17 3 2.91 Shallow corrosion.
12 387 0 0.03 13 4 2.92 Shallow pitting.
13 418 0 0.04 15 4 2.93 Shallow corrosion.
14 450 0 0.03 13 5 2.93 Shallow corrosion.
15 481 0 0.04 15 5 2.94 Shallow corrosion.
16 512 0 0.04 14 4 2.94 Shallow corrosion.
17 543 0 0.04 15 6 2.93 Shallow pitting.
18 575 0 0.06 23 4 2.91 Line of pits.
19 606 0 0.04 17 6 2.90 Shallow pitting.
20 637 0 0.04 16 4 2.91 Shallow corrosion.
21 667 0 0.05 21 6 2.92 Corrosion.
22 699 0 0.03 13 6 2.93 Shallow corrosion.
23 730 0 0.04 17 8 2.93 Shallow corrosion.
24 761 0 0.04 15 3 2.93 Shallow pitting.
25 793 0 0.04 16 4 2.91 Shallow pitting.
26 824 0 0.05 20 3 2.94 Isolated pitting.
27 856 0 0.05 20 6 2.93 Isolated pitting.
28 887 0 0.04 15 6 2.94 Shallow corrosion.
29 918 0 0.04 15 6 2.94 Shallow corrosion.
30 950 0 0.04 15 1 2.95 Shallow pitting.
31 981 0 0.05 19 5 2.93 Shallow corrosion.
32 1013 0 0.06 24 5 2.92 Line of pits.
33 1044 0 0.04 17 2 2.94 Shallow pitting.
34 1076 0 0.06 25 7 2.94 Line of pits.
35 1107 0 0.04 17 5 2.93 Line of shallow pits.
36 1139 0 0.07 28 2 2.94 Line of pits
37 1170 0 0.05 20 6 2.94 Line of pits.
38 1201 0 0.04 17 4 2.92 Shallow pitting.
39 1233 0 0.04 17 5 2.92 Shallow pitting.
40 1264 0 0.05 18 3 2.91 Shallow pitting.
41 1295 0 0.05 19 4 2.92 Shallow pitting.
42 1327 0 0.06 24 7 2.93 Corrosion.
43 1358 0 0.05 20 5 2.92 Shallow corrosion.
44 1390 0 0.05 20 2 2.92 Shallow pitting.
45 1421 0 0.06 22 5 2.91 Line of pits
46 1453 0 0.05 18 1 2.94 Line of shallow pits.
47 1484 0 0.04 17 2 2.95 Shallow pitting.
48 1516 0 0.04 15 6 2.93 Shallow pitting.
49 1547 0 0.06 25 3 2.93 Corrosion.
I Penetration Body
t'~I: Metal Loss Body
Page 1
PDS~ KEPORT JOINT T ABULA TION~ ;)HEET
Pipe: 3.5 in 9.3 ppf L-80 Well: 1 C-l 33
Body Wall: 0.254 in Field: Kuparuk
Upset Wall: 0.254 in Company: CONOCOPHILLlPS ALASKA, INC.
N ominaII.D.: 2.992 in Country: USA
Survey Date: August 2, 2005
Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile
No. (Ft.) Upset Body % Loss I.D. Comments (% wall)
(Ins.) (Ins.) % (Ins.) 0 50 100
50 1579 0 0.07 27 6 2.93 Line of pits.
51 1610 0 0.05 20 2 2.93 Shallow pitting.
52 1642 0 0.06 23 4 2.93 Line of pits.
53 1673 0 0.06 24 6 2.92 Line of pits.
54 1704 0 0.06 22 6 2.93 Line of pits. Lt. Deposits.
55 1735 0 0.04 17 6 2.92 Line of shallow pits.
56 1766 0 0.05 20 6 2.92 Line of shallow pits.
57 1796 0 0.05 19 6 2.93 Line of shallow pits.
58 1828 0 0.05 19 6 2.94 Line of shallow pits.
59 1859 0 0.06 22 5 2.93 Line of pits.
60 1890 0 0.06 25 5 2.90 Line of pits.
61 1922 0 0.06 22 4 2.93 Line of pits.
62 1953 0 0.04 17 7 2.93 Line of shallow pits.
63 1985 0 0.04 17 4 2.93 Line of shallow pits.
64 2016 0 0.04 17 1 2.95 Shallow pitting.
65 2048 0 0.04 14 5 2.93 Line of shallow pits.
66 2079 0 0.05 21 5 2.94 Line of pits.
67 2111 0 0.05 20 6 2.93 Line of shallow pits.
68 2142 0 0.03 13 5 2.93 Shallow pitting.
69 2172 0 0.04 15 2 2.95 Shallow pitting.
70 2204 0 0.04 15 6 2.93 Line of shallow pits.
71 2235 0 0.04 16 2 2.91 Shallow pitting.
72 2267 0 0.04 17 2.90 Line of shallow pits.
73 2298 0 0.04 14 2 2.92 Line of shallow pits.
74 2330 0 0.06 22 2 2.92 Isolated pitting.
75 2361 0 0.05 19 6 2.91 Shallow corrosion.
76 2393 0 0.05 19 6 2.88 Shallow pitting.
77 2424 0 0.04 16 2 2.90 Line of shallow pits.
78 2455 0 0.05 20 5 2.91 Line of shallow pits.
79 2487 0 0.05 21 5 2.92 Corrosion.
80 2518 0 0.04 17 5 2.91 Line of shallow pits.
81 2549 0 0.05 19 3 2.93 Line of shallow pits.
82 2581 0 0.05 20 3 2.90 Corrosion.
83 2612 0 0.05 20 7 2.92 Line of pits.
84 2644 0 0.05 18 7 2.93 Shallow corrosion.
85 2675 0 0.07 26 6 2.91 Isolated pitting.
86 2706 0 0.07 26 3 2.91 Corrosion. Lt. Deposits.
87 2738 0 0.07 28 3 2.93 Line of pits.
88 2768 0 0.06 22 2 2.90 Line of pits.
89 2799 0 0.05 21 7 2.93 Line of pits.
90 2831 0 0.05 20 6 2.93 Line of pits. Lt. Deposits.
91 2862 0 0.06 24 5 2.93 Line of pits. Lt. Deposits.
92 2893 0 0.05 19 3 2.91 Shallow corrosion.
93 2925 0 0.04 18 4 2.92 Line of shallow pits.
94 2956 0 0.06 23 3 2.92 Line of pits.
95 2987 0 0.04 17 3 2.93 Shallow pitting.
96 3019 0 0.05 20 4 2.93 Line of shallow pits.
97 3050 0 0.05 18 4 2.92 Line of shallow pits.
98 3081 0 0.05 20 3 2.92 Line of pits.
99 3112 0 0.05 19 3 2.94 Shallow pitting.
I Penetration Body
i,~':f: Metal Loss Body
Page 2
PDS~ KEPORT JOINT TABULA TION{ :)HEET
Pipe: 3.5 in 9.3 ppf L-80 Well: 1 C-133
Body Wall: 0.254 in Field: Kuparuk
Upset Wall: 0.254 in Company: CONOCOPHILLlPS ALASKA, INC.
N ominall.D.: 2.992 in Country: USA
Survey Date: August 2, 2005
Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile
No. (Ft.) Upset Body 0/0 Loss I.D. Comments (% wall)
(Ins.) (Ins.) (X) (Ins.) 0 50 100
100 3142 0 0.06 25 3 2.91 Line of pits.
101 3173 0 0.06 23 6 2.92 Line of pits.
102 3204 0 0.06 23 6 2.93 Line of pits.
103 3235 0 0.05 20 :2 2.92 Line of pits.
104 3266 0 0.05 21 7 2.93 Line of pits.
105 3297 0 0.06 24 6 2.92 Line of pits.
106 3329 0 0.05 20 3 2.94 Shallow corrosion.
107 3360 0 0.07 30 3 2.93 Line of pits.
108 3392 0 0.06 25 4 2.94 Line of pits.
109 3423 0 0.05 19 4 2.91 Line of shallow pits.
110 3454 0 0.04 17 :2 2.93 Line of shallow pits. Lt. Deposits.
111 3484 0 0.07 26 5 2.92 Line of pits.
112 3516 0 0.06 24 2 2.92 Line of pits.'
113 3547 0 0.07 27 3 2.91 Line of pits. Lt. Deposits.
114 3578 0 0.08 30 5 2.94 Line of pits.
115 3610 0 0.06 24 5 2.92 Line of pits.
116 3641 0 0.07 26 :2 2.94 Line of pits.
117 3673 0 0.08 31 6 2.93 Line of pits.
118 3704 0 0.07 28 7 2.93 Line of pits.
119 3736 0 0.07 29 6 2.92 Isolated pitting.
120 3767 0 0.08 33 3 2.92 Line of pits.
121 3798 0 0.09 36 4 2.93 Line of pits.
122 3830 0 0.07 28 2 2.95 Line of pits.
122.1 3861 0 0.05 19 8 2.94 PUP Shallow pitting.
122.2 3867 0 0 0 0 N/A GLM (Latch @ 4:00)
122.3 3873 0 0.05 18 7 2.94 PUP Shallow pitting.
123 3879 0 0.08 31 5 2.93 Isolated pitting.
123.1 3910 0 0 0 0 2.81 DS Nipple
124 3911 0 0.06 24 3 2.93 Corrosion.
124.1 3943 0 0.08 30 2 2.94 PUP Isolated pitting.
124.2 3948 0 0 0 0 3.00 SEAL
124.3 3960 0 0 0 0 4.00 SBE
124.4 3963 0 0.Ú4 15 2 2.92 PUP Shallow pitting. ;,
125 3973 0 0.06 23 2 2.94 Isolated pitting.
126 4004 0 0,04 15 8 2.93 Shallow corrosion.
! Penetration Body
c}\~¡ Metal Loss Body
Page 3
· -- )....~--....-.-
~s
~ ·-1"
PDS Report Cross Sections
Well:
Field:
Company:
Country:
Tubing:
1 C-B3
Kuparuk
CONOCOPHILLlPS ALASKA, INC.
USA
3.5 ins 9.3 ppf L-80
Survey Date:
Tool Type:
Tool Size:
No. of Fingers:
Analyst:
August 2, 2005
MFC 24 No. 00387
1.69
24
M. Tahtouh
Cross Section for Joint 121 at depth 3807.05 ft
Tool speed = 49
NominallD = 2.992
Nominal OD = 3.500
Remaining wall area = 98 %
Tool deviation = 90
Finger 10 Penetration = 0.092 ins
Line of Pits
0.09 ins = 36% Wall Penetration
HIGH SIDE = UP
Cross Sections page 1
-J. "-_. ."-. -r·-..-.- -. J.- .---.....
- - )5
~ -10.
PDS Report Cross Sections
Well:
Field:
Company:
Country:
Tubing:
1 C133
Kuparuk
CONOCOPHILLlPS ALASKA, INC.
USA
3.5 ins 9.3 ppf L-80
Survey Date:
Tool Type:
Tool Size:
No. of Fingers:
Analyst:
August 2, 2005
MFC 24 No. 00387
1.69
24
M. Tahtouh
Cross Section for Joint 120 at depth 3782.76 ft
Tool speed = 48
Nominal 10 = 2.992
Nominal 00 = 3.500
Remaining wall area = 98 %
Tool deviation = 9 0
Finger 8 Penetration = 0.084 ins
Line of Pits
0.08 ins = 33% Wall Penetration
HIGH SIDE = UP
Cross Sections page 2
TUBING
(û-3952,
00:3.500,
10:2992)
~OOUCTION
(0-3952,
00:5.500,
Wt:15.50)
NIP
(391 0-3911,
00:3.780)
NIP
(394ß.3949,
00:4.5(0)
SEAL
(3949-3951,
00:4.0(0)
SBE
(3951-3952,
00:5.0(0)
Pert
( 4ŒO-408O)
Pert
(4110-4140)
PROO
LINER
(3952-4002,
00:3.500,
Wt:9.30)
Pert
(4154-4176)
Pert
(4196-4206)
Perf
(4212-4226)
Perf
(4230-4242)
Perf
(4260-4330)
\
ConocoPhillips Alaska, Inc.
1C-133
API: 500292301300
SSSV Type: None
Annular Fluid:
Reference Log:
Last Tag: 4463
Last Tag Date: 11/5/2001
Casing String - ALL STRINGS
Description Size
CONDUCTOR 16.000
PRODUCTION 5.500
PROD LINER 3.500
Tubing String - TUBING
Size I Top
3.500 0
Perforations Summary
Interval TVD
4050 - 4080 3767 - 3797
I Bottom
3952
Zone
WSD
4110 - 4140
3827 - 3857
WSB
4154-4176
3871 - 3893
WSA4
4196 - 4206
3913 - 3923
WSA3
4212 - 4226 3929 - 3943 WS A3
4230 - 4242 3947 - 3959 WS A3
4260 - 4330 3977 - 4047 WSA2
Gas Lift MandrelsNalves
st MD TVD Man Man
Mfr Type
1 3866 3584 CAMCO KBG-2-9 CAMCO
Other ()Iugs, equip., etc.) - JEWELRY
Depth TVD Type
3910 3628 NIP
3948 3665 NIP
3949 3666 SEAL
3951 3668 SBE
4150 3867 PLUG
4599 4316 SHOE
;j'
KRU
Well Type: INJ
Orig 6/3/2001
Completion:
Last w/o:
Ref Log Date:
TD: 4615 ftKB
Max Hole Angle: 36 deg @ 2149
Top Bottom TVD
0 181 181
0 3952 3669
3952 4602 4319
TVD Wt Grade
3669 9.30 L-80
Status Ft SPF Date Type
30 4 6/23/2001 IPERF
30 4 6/23/2001 IPERF
22 4 6/23/2001 IPERF
10 4 6/23/2001 IPERF
14 4 6/22/2001 IPERF
12 4 6/22/2001 IPERF
70 4 6/22/2001 IPERF
V Mfr
1 C-133
Angle @ TS: deg @
Angle @ TO: 1 deg @ 4615
Rev Reason: SetWRP
Last Update: 4/21/2003
Wt
62.58
15.50
9.30
Grade
H-40
L-80
L-80
Thread
WELD
BTC-MOD
EUE8RD
Th read
EUE8RD
Comment
2.5" HSD DP, 60 deg ph,
31J UJ HMX
2.5" HSD DP, 60 deg ph,
31J UJ HMX
2.5" HSD DP,60 deg ph,
31J UJ HMX
2.5" HSD DP, 60 deg ph,
31J UJ HMX
2.5" HSD DP, 60 deg ph
2.5" HSD DP, 60deg ph
2.5" HSD DP, 60 deg ph
DMY
INT
V Type V OD Latch Port TRO
o
1.0
Description
CAMCO 'DS' NIPPLE w/2.812 NO GO Profile
BAKER NO GO SUB
BAKER SEAL ASSEMBLY
BAKER 12' SBE
WRP SET 4/20/2003
0.000
Date
Run
6/7/2001
Vlv
Cmnt
ID
2.812
3.000
3.000
4.000
0.000
2.992
