Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout197-183MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Friday, January 16, 2026
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Kam StJohn
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
ConocoPhillips Alaska, Inc.
1D-130
KUPARUK RIV U WSAK 1D-130
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 01/16/2026
1D-130
50-029-22815-00-00
197-183-0
W
SPT
3568
1971830 1500
860 870 860 870
200 280 280 280
OTHER P
Kam StJohn
12/9/2025
MIT-IA post patch per Sundry 325-612
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 1D-130
Inspection Date:
Tubing
OA
Packer Depth
1600 2300 2265 2260IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitKPS251209131824
BBL Pumped:0.2 BBL Returned:0.2
Friday, January 16, 2026 Page 1 of 1
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1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown
Suspend Perforate Other Stimulate Pull Tubing Change Approved Program
Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Pull and reset patch
2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number:
Exploratory Development
3. Address:Stratigraphic Service
6. API Number:
7. If perforating: 8. Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool?N/A
Yes No
9. Property Designation (Lease Number): 10. Field:
West Sak Oil Pool
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD):
4778 4675 None
Casing Collapse
Structural
Conductor N/A
Surface N/A
Intermediate
Production N/A
Liner
Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft):
12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work:
Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service
14. Estimated Date for 15. Well Status after proposed work:
Commencing Operations: OIL WINJ WDSPL Suspended
16. Verbal Approval: Date: GAS WAG GSTOR SPLUG
AOGCC Representative: GINJ Op Shutdown Abandoned
Contact Name:
Contact Email:
Contact Phone:
Authorized Title:
Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number:
Plug Integrity BOP Test Mechanical Integrity Test Location Clearance
Other Conditions of Approval:
Post Initial Injection MIT Req'd? Yes No
APPROVED BY
Approved by: COMMISSIONER THE AOGCC Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
907-265-6678
KRU 1D-130
4257 4154 NoneN/A
jan.byrne@conocophillips.com
Jan Byrne
Length Size
Subsequent Form Required:
Suspension Expiration Date:
Will perfs require a spacing exception due to property boundaries?
Current Pools:
MPSP (psi): Plugs (MD):
17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval.
Authorized Name and
Digital Signature with Date:
Tubing Size:
PRESENT WELL CONDITION SUMMARY
AOGCC USE ONLY
Tubing Grade: Tubing MD (ft):
4092 MD/ 3573 TVD & None
Perforation Depth TVD (ft):
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL0025650 KRU
197-183
P.O. Box 1000360, Anchorage, Alaska 99510 50-029-22815-00-00
ConocoPhillips Alaska, Inc
Proposed Pools:
L-80
TVD Burst
3586
N/A
MD
N/A
N/A
121
2240
121
2529
42475.5
16
7.625
84
2492
4768
Perforation Depth MD (ft):
4108-4596
4731
3589-4075
Staff Intervention Engineer
12/1/2025
2.875
Packer: Backer locater seal assembly
SSSV: None
m
n
P
1
6
5
6
t
N
Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
Digitally signed by Jan Byrne
DN: OU=Wells Group, O=ConocoPhillips, CN=Jan Byrne, E=jan.byrne@
conocophillips.com
Reason: I have reviewed this document
Location: Anchorage tower
Date: 2025.10.08 05:56:42-08'00'
Foxit PDF Editor Version: 13.1.6
Jan Byrne
325-612
By Grace Christianson at 8:17 am, Oct 08, 2025
A.Dewhurst 24OCT25
10-404
J.Lau 10/30/25
AOGCC witnessed MITIA post-stabilized injection.
X
JLC 10/30/2025
10/31/25
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
October 8, 2025
Commissioner Jessie Chmielowski
Alaska Oil & Gas Commission
333 West 7th Avenue, Suite 100
Anchorage, AK 99501
Dear Commissioner Chmielowski,
Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips
Alaska, Inc. well KRU 1D-130 (PTD 197-183) to pull and reset a retrievable tubing patch
to allow for a compliance subsidence drift.
If you need additional information, please contact us at 265-6678.
Sincerely,
Jan Byrne
Well Intervention Engineer
ConocoPhillips Alaska, Inc.
Well Work Jus ca on & Objec ves (and date required if appropriate):
1D-130 is coming due for a subsidence dri 12/4/25. The shallow tubing patch will need to be
pulled to complete the subsidence dri and reset once the dri is complete.
Risks/Job Concerns:
Need Approved 10-403 from AOGCC required prior to pulling and rese ng patch.
Tubing patch set at 196' - 227' RKB over tubing leak at 216' RKB on 1/10/25
2019 Caliper reported other areas of tubing with 60% + isolated pi ng and lined pi ng.
Needs SW MITIA post patch re-set and post injec on
No issues last me it was dri ed. 12/28/2024
Steps:
Relay or Slickline/Eline
1. RIH to dri tubing down to top of patch at 196' RKB'.
2. Pull patch at 196' RKB. 31.86' upper assembly, 3.55' lower
3. Dri 2.25" dummy CA-2 plug down to D nipple at 4053' RKB.
4. Note any ght spots, weight swings or other anomalies on 24 hour summary of WSR.
5. Brush and ush patch set area around 150'-250' RKB.
6. Set lower 2.29" P2P at 227' (same as previous) correlate with LDL/Caliper ran 2019 (See
tabs).
7. S ng into P2P with test tool and perform CMIT TxIA to 2500 psi.
8. Run upper 2.29" P2P, spacer pipe, and anchor latch to s ng into lower P2P. Patch should
be 31' from element to element placing the upper P2P mid element at 196' (same as
previous).
9. Perform MITIA to 2500 psi. Record TIOs.
10. RDMO, turn well over to Opera ons to BOI.
11. Will require SW MITIA, no fy DHD Field Supervisor.
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag: RKB 4,389.0 1D-130 2/1/2018 pproven
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Set Upper Patch Assembly 1D-130 1/10/2025 rogerba
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 37.4 121.0 121.0 62.50 H-40 WELDED
SURFACE 7 5/8 6.87 37.4 2,529.3 2,239.7 29.70 L-80 ABM-BTC
PRODUCTION
5.5"x3.5"@4091'
5 1/2 4.95 37.1 4,768.1 4,247.2 15.50 L-80 BTC
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
41.4
Set Depth
4,104.7
Set Depth
3,585.8
String Max No
2 7/8
Tubing Description
TUBING WO
Wt (lb/ft)
6.50
Grade
L-80
Top Connection
EUE8rdAB
MOD
ID (in)
2.44
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)
41.4 41.4 0.00 HANGER 6.000 Tubing Hanger T&C
Upset
2.441
519.4 519.4 0.36 NIPPLE 3.680 Camco "DS" Nipple 2.312" T&C
Upset
2.312
4,003.9 3,485.6 7.08 GAS LIFT 4.750 Camco Mandrel KBMG-M CAMCO KBMG-
M
2.347
4,052.9 3,534.3 6.04 NIPPLE 3.680 Camco "D" Nipple 2.250" 2.250
4,091.7 3,572.8 5.78 SEAL ASSY 4.500 Baker 3-1/2" Locator Seal Assembly 3.000
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top (ftKB)
Top (TVD)
(ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in)
194.9 194.9 0.09 PACKER -
PATCH - UPR
2 7/8" PIIP Upper Patch
Pacher set mid-element @
197' - Part of Upper Patch
Assembly (OAL of Upper
Assembly = 30')
TTS PIIP CPP2
87085
1/10/2025 1.375
198.1 198.1 0.09 ANCHOR
LATCH ON
SPACER
PIPE
2 1/16" P110 SPACER PIPE
AND ANCHOR LATCH - Part
of the Upper Patch Assembly
with the Upper packer
CPAL
28702
1
1/10/2025 1.375
216.0 216.0 0.11 LEAK -
TUBING
LEAK @216' 7/2/2019
224.9 224.9 0.12 PACKER -
PATCH - LWR
LOWER 2.29" P2P MID-
ELEMENT AT 227' RKB
(2400LB RELEASE) (3.55'
OAL)
TTS PIIP CPP2
87051
1/8/2025 1.375
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)
4,003.9 3,485.6 7.08 1 Gas Lift DMY BK 1 0.0 6/23/2008 0.000
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
4,108.0 4,110.0 3,589.1 3,591.1 11/11/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,128.0 4,130.0 3,609.0 3,611.0 11/11/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,152.0 4,154.0 3,632.9 3,634.9 WS D, 1D-130 11/11/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,164.0 4,180.0 3,644.8 3,660.7 WS D, 1D-130 1/19/1998 4.0 IPERF 180° ph; 90° Orient; 2.5"HSD
4,192.0 4,194.0 3,672.7 3,674.7 WS C, 1D-130 11/11/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,207.0 4,241.0 3,687.6 3,721.5 WS B, 1D-130 1/19/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,210.0 4,212.0 3,690.6 3,692.6 WS B, 1D-130 11/11/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,212.0 4,241.0 3,692.6 3,721.5 WS B, 1D-130 1/19/1998 4.0 IPERF 180° ph, 2.5" HSD DP
4,246.0 4,248.0 3,726.5 3,728.5 WS A4, 1D-130 11/11/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,251.0 4,256.0 3,731.5 3,736.5 WS A4, 1D-130 1/19/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,256.0 4,276.0 3,736.5 3,756.4 WS A4, 1D-130 1/17/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,262.0 4,264.0 3,742.4 3,744.4 WS A4, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,278.0 4,280.0 3,758.4 3,760.4 WS A4, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,295.0 4,301.0 3,775.3 3,781.3 WS A3, 1D-130 1/17/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,298.0 4,300.0 3,778.3 3,780.3 WS A3, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,300.0 4,301.0 3,780.3 3,781.3 WS A3, 1D-130 1/17/1997 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,310.0 4,342.0 3,790.3 3,822.2 WS A3, 1D-130 1/17/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,354.0 4,356.0 3,834.1 3,836.1 WS A3, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,365.0 4,370.0 3,845.1 3,850.1 WS A2, 1D-130 1/17/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,380.0 4,420.0 3,860.0 3,899.9 WS A2, 1D-130 1/17/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,392.0 4,394.0 3,872.0 3,874.0 WS A2, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,402.0 4,404.0 3,882.0 3,884.0 WS A2, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
1D-130, 1/11/2025 10:16:30 AM
Vertical schematic (actual)
PRODUCTION
5.5"x3.5"@4091'; 37.1-4,768.1
IPERF; 4,594.0-4,596.0
IPERF; 4,490.0-4,492.0
IPERF; 4,462.0-4,464.0
APERF; 4,440.0-4,452.0
IPERF; 4,430.0-4,432.0
IPERF; 4,402.0-4,404.0
IPERF; 4,380.0-4,420.0
IPERF; 4,392.0-4,394.0
IPERF; 4,365.0-4,370.0
IPERF; 4,354.0-4,356.0
IPERF; 4,310.0-4,342.0
IPERF; 4,300.0-4,301.0
IPERF; 4,298.0-4,300.0
IPERF; 4,295.0-4,301.0
IPERF; 4,278.0-4,280.0
IPERF; 4,256.0-4,276.0
IPERF; 4,262.0-4,264.0
IPERF; 4,251.0-4,256.0
IPERF; 4,246.0-4,248.0
IPERF; 4,212.0-4,241.0
IPERF; 4,207.0-4,241.0
IPERF; 4,210.0-4,212.0
IPERF; 4,192.0-4,194.0
IPERF; 4,164.0-4,180.0
IPERF; 4,152.0-4,154.0
IPERF; 4,128.0-4,130.0
IPERF; 4,108.0-4,110.0
GAS LIFT; 4,004.0
SURFACE; 37.4-2,529.3
NIPPLE; 519.4
PACKER - PATCH - LWR; 224.9
LEAK - TUBING; 216.0
ANCHOR LATCH ON SPACER
PIPE; 198.1
PACKER - PATCH - UPR; 194.9
CONDUCTOR; 37.4-121.0
KUP INJ
KB-Grd (ft) RR Date
11/8/1997
Other Elev
1D-130
...
TD
Act Btm (ftKB)
4,778.0
Well Attributes
Field Name
WEST SAK
Wellbore API/UWI
500292281500
Wellbore Status
INJ
Max Angle & MD
Incl (°)
42.54
MD (ftKB)
2,896.15
WELLNAME WELLBORE1D-130
Annotation
Last WO:
End Date
6/16/2008
H2S (ppm) DateComment
SSSV: NIPPLE
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
4,430.0 4,432.0 3,909.9 3,911.9 WS A2, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,440.0 4,452.0 3,919.9 3,931.8 WS A2, 1D-130 1/17/1998 4.0 APERF 180°ph; 90° Orient; 2.5"HSD
4,462.0 4,464.0 3,941.8 3,943.8 WS A2, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,490.0 4,492.0 3,969.7 3,971.7 WS A2, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,594.0 4,596.0 4,073.4 4,075.4 WS A1, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
1D-130, 1/11/2025 10:16:30 AM
Vertical schematic (actual)
PRODUCTION
5.5"x3.5"@4091'; 37.1-4,768.1
IPERF; 4,594.0-4,596.0
IPERF; 4,490.0-4,492.0
IPERF; 4,462.0-4,464.0
APERF; 4,440.0-4,452.0
IPERF; 4,430.0-4,432.0
IPERF; 4,402.0-4,404.0
IPERF; 4,380.0-4,420.0
IPERF; 4,392.0-4,394.0
IPERF; 4,365.0-4,370.0
IPERF; 4,354.0-4,356.0
IPERF; 4,310.0-4,342.0
IPERF; 4,300.0-4,301.0
IPERF; 4,298.0-4,300.0
IPERF; 4,295.0-4,301.0
IPERF; 4,278.0-4,280.0
IPERF; 4,256.0-4,276.0
IPERF; 4,262.0-4,264.0
IPERF; 4,251.0-4,256.0
IPERF; 4,246.0-4,248.0
IPERF; 4,212.0-4,241.0
IPERF; 4,207.0-4,241.0
IPERF; 4,210.0-4,212.0
IPERF; 4,192.0-4,194.0
IPERF; 4,164.0-4,180.0
IPERF; 4,152.0-4,154.0
IPERF; 4,128.0-4,130.0
IPERF; 4,108.0-4,110.0
GAS LIFT; 4,004.0
SURFACE; 37.4-2,529.3
NIPPLE; 519.4
PACKER - PATCH - LWR; 224.9
LEAK - TUBING; 216.0
ANCHOR LATCH ON SPACER
PIPE; 198.1
PACKER - PATCH - UPR; 194.9
CONDUCTOR; 37.4-121.0
KUP INJ 1D-130
...
WELLNAME WELLBORE1D-130
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Wednesday, May 14, 2025
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Bob Noble
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
ConocoPhillips Alaska, Inc.
1D-130
KUPARUK RIV U WSAK 1D-130
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 05/14/2025
1D-130
50-029-22815-00-00
197-183-0
W
SPT
3568
1971830 1500
810 810 810 810
210 390 390 390
OTHER P
Bob Noble
4/7/2025
MITIA post patch per Sundry #324-643
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 1D-130
Inspection Date:
Tubing
OA
Packer Depth
200 2000 1970 1970IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitRCN250410153644
BBL Pumped:0.7 BBL Returned:0.7
Wednesday, May 14, 2025 Page 1 of 1
9
9
9
9
9
9 9
9
999
9 9
99
9
9
James B. Regg Digitally signed by James B. Regg
Date: 2025.05.14 10:45:21 -08'00'
ORIGINATED
TRANSMITTAL
DATE: 1/27/2025
ALASKA E-LINE SERVICES
TRANSMITTAL
#: 5238
42260 Kenai Spur Hwy
PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk
PH: (907) 283-7374 FAX: (907) 283-7378
DELIVERABLE DESCRIPTION
TICKET # WELL # API #
LOG
DESCRIPTION
DATE OF
LOG
5238 1D-130 50029228150000 Packer Setting Record 8-Jan-2025
RECIPIENTS
Conoco
DIGITAL FILES PRINTS CD'S
1 FTP Transfer 0 0 USPS
Attn: NSK-69
Richard.E.Elgarico@conocophillips.com 700 G Street
Anchorage, AK 99503
Received
By: Received By:
Signature Signature
AOGCC
DIGITAL FILES PRINTS CD'S
1 ShareFile 0 0 USPS
Attn: Natural Resources Technician II
abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision
aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501
Received
By: Received By:
Signature Signature
197-183
T40017
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2025.01.28 09:46:04 -09'00'
DNR
DIGITAL FILES PRINTS CD'S
1 SharePoint
Link 0 0 USPS
Attn: Natural Resource Tech II
DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501
Delivery Method: USPS
Received
By: Received By:
Signature Signature
Please return via e-mail a copy to both:
AR@ake-
line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com
1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown
Suspend Perforate Other Stimulate Pull Tubing Change Approved Program
Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Pull and reset patch
2.Operator Name:4. Current Well Class: 5. Permit to Drill Number:
Exploratory Development
3. Address:Stratigraphic Service
6.API Number:
7. If perforating:8. Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool?N/A
Yes No
9. Property Designation (Lease Number):10. Field:
West Sak Oil Pool
11.
Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD):
4778 4257 4675 4154 NA None None
Casing Collapse
Structural
Conductor NA
Surface NA
Intermediate
Production NA
Liner
Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft):
12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work:
Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service
14. Estimated Date for 15. Well Status after proposed work:
Commencing Operations:OIL WINJ WDSPL Suspended
16. Verbal Approval:Date: GAS WAG GSTOR SPLUG
AOGCC Representative: GINJ Op Shutdown Abandoned
Contact Name:Shelby Sumrall
Contact Email:
Contact Phone: 907-265-6678
Authorized Title: Well Integrity Specialist
Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number:
Plug Integrity BOP Test Mechanical Integrity Test Location Clearance
Other Conditions of Approval:
Post Initial Injection MIT Req'd? Yes No
APPROVED BY
Approved by: COMMISSIONER THE AOGCC Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
12/1/2024
2.875
Packer: Baker locater seal assembly
SSSV: None
Perforation Depth MD (ft):
L-80
2492
4108-4596
4731
3589-4075
5.5
Perforation Depth TVD (ft):
121
2529
42474768
16
7.625
84
3586
NA
MD
NA
NA
121
2240
ConocoPhillips Alaska, Inc
Size
Proposed Pools:
PRESENT WELL CONDITION SUMMARY
TVD Burst
Shelby.Sumrall@conocophillips.com
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL0025650 KRU
197-183
P.O. Box 1000360, Anchorage, Alaska 99510 50-029-22815-00-00
Length
AOGCC USE ONLY
Tubing Grade:Tubing MD (ft):
4092 MD/ 3573 TVD & None
KRU 1D-130
Subsequent Form Required:
Suspension Expiration Date:
Will perfs require a spacing exception due to property boundaries?
Current Pools:
MPSP (psi):Plugs (MD):
17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval.
Authorized Name and
Digital Signature with Date:
Tubing Size:
m
n
P
1
6
5
6
t
N
Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
Digitally signed by Shelby Sumrall
DN: OU=Alaska, O=Conocophillips, CN=Shelby Sumrall, E=
Shelby.Sumrall@conocophillips.com
Reason: I am the author of this document
Location: Anchorage Alaska
Date: 2024.11.08 17:06:12-09'00'
Foxit PDF Editor Version: 13.0.0
Shelby Sumrall
By Grace Christianson at 7:51 am, Nov 12, 2024
324-643
10-404
x
Post injection witnessed MITIA
DSR-11/20/24JJL 11/13/24
x
A.Dewhurst 21NOV24*&:
Jessie L. Chmielowski
Digitally signed by Jessie L.
Chmielowski
Date: 2024.11.22 08:48:38 -08'00'11/22/24
RBDMS JSB 112524
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
November 8, 2024
Commissioner Jessie Chmielowski
Alaska Oil & Gas Commission
333 West 7th Avenue, Suite 100
Anchorage, AK 99501
Dear Commissioner Chmielowski,
Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips
Alaska, Inc. well KRU 1D-130 (PTD 197-183) to pull and reset a retrievable tubing patch
to allow for a compliance drift.
If you need additional information, please contact us at 265-6678.
Sincerely,
Shelby Sumrall
Well Integrity Specialist
ConocoPhillips Alaska, Inc.
Digitally signed by Shelby Sumrall
DN: OU=Alaska, O=Conocophillips, CN=
Shelby Sumrall, E=Shelby.Sumrall@
conocophillips.com
Reason: I am the author of this document
Location: Anchorage Alaska
Date: 2024.11.08 17:05:52-09'00'
Foxit PDF Editor Version: 13.0.0
Shelby
Sumrall
Well Work JusƟĮcaƟon & ObjecƟves (and date required if appropriate):
1D-130 is coming due for a subsidence driŌ 12/4/24. The shallow tubing patch will need to be
pulled to complete the subsidence driŌ and reset once the driŌ is complete.
Risks/Job Concerns:
Need Approved 10-403 from AOGCC required prior to pulling and reseƫng patch.
Tubing patch set at 199' - 229' RKB over tubing leak at 216' RKB on 12/5/23
2019 Caliper reported other areas of tubing with 60% + isolated piƫng and lined piƫng.
Patch packers have been set @ 208'-238', 205'-235', 204'-234' and 199'-229' RKB
Steps:
Relay or Slickline/Eline
1. RIH to driŌ tubing down to top of patch at 199' RKB'.
2. Pull patch at 199' RKB.
3. DriŌ 2.25" dummy CA-2 plug down to D nipple at 4053' RKB.
4. Note any Ɵght spots, weight swings or other anomalies on 24 hour summary of WSR.
5. Brush and Ňush patch set area around 150'-250' RKB.
6. Set lower 2.29" P2P at 227' (2' higher than previous) correlate with LDL/Caliper ran
2019.
7. SƟng into P2P with test tool and perform CMIT TxIA to 2500 psi.
8. Run upper 2.29" P2P, spacer pipe, and anchor latch to sƟng into lower P2P. Patch should
be 30' from element to element placing the upper P2P mid element at 197' (2' higher
than previous).
9. Perform MITIA to 2500 psi. Record TIOs.
10. RDMO, turn well over to OperaƟons to BOI.
11. Will require SW MITIA, noƟfy DHD Field Supervisor.
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag: RKB 4,389.0 1D-130 2/1/2018 pproven
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Pulled & replaced patch. 1D-130 12/5/2023 fergusp
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 37.4 121.0 121.0 62.50 H-40 WELDED
SURFACE 7 5/8 6.87 37.4 2,529.3 2,239.7 29.70 L-80 ABM-BTC
PRODUCTION
5.5"x3.5"@4091'
5 1/2 4.95 37.1 4,768.1 4,247.2 15.50 L-80 BTC
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
41.4
Set Depth …
4,104.7
Set Depth …
3,585.8
String Max No…
2 7/8
Tubing Description
TUBING WO
Wt (lb/ft)
6.50
Grade
L-80
Top Connection
EUE8rdAB
MOD
ID (in)
2.44
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)
41.4 41.4 0.00 HANGER 6.000 Tubing Hanger T&C
Upset
2.441
519.4 519.4 0.36 NIPPLE 3.680 Camco "DS" Nipple 2.312" T&C
Upset
2.312
4,003.9 3,485.6 7.08 GAS LIFT 4.750 Camco Mandrel KBMG-M w/1" DCK-
2 SOV 1500 psi
CAMCO KBMG-
M
2.347
4,052.9 3,534.3 6.04 NIPPLE 3.680 Camco "D" Nipple 2.250" 2.250
4,091.7 3,572.8 5.78 SEAL ASSY 4.500 Baker 3-1/2" Locator Seal Assembly 3.000
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top (ftKB)
Top (TVD)
(ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in)
199.0 199.0 0.09 PACKER -
PATCH - UPR
UPPER 2.29" P2P (2400LB
RELEASE), SPACER PIPE, &
ANCHOR LATCH (30.5' OAL)
CPP2
87075
12/5/2023 1.375
203.0 203.0 0.10 ANCHOR
LATCH ON
SPACER
PIPE
2 1/16" P110 SPACER PIPE
AND ANCHOR LATCH
CPAL
28702
1
12/5/2023 1.375
216.0 216.0 0.11 LEAK -
TUBING
LEAK @216' 7/2/2019
229.0 229.0 0.13 PACKER -
PATCH - LWR
LOWER 2.29" P2P MID-
ELEMENT AT 229' RKB
(2400LB RELEASE) (3.55'
OAL)
CPP2
87087
12/4/2023 1.375
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)
4,003.9 3,485.6 7.08 1 Gas Lift DMY BK 1 0.0 6/23/2008 0.000
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
4,108.0 4,110.0 3,589.1 3,591.1 11/11/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,128.0 4,130.0 3,609.0 3,611.0 11/11/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,152.0 4,154.0 3,632.9 3,634.9 WS D, 1D-130 11/11/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,164.0 4,180.0 3,644.8 3,660.7 WS D, 1D-130 1/19/1998 4.0 IPERF 180° ph; 90° Orient; 2.5"HSD
4,192.0 4,194.0 3,672.7 3,674.7 WS C, 1D-130 11/11/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,207.0 4,241.0 3,687.6 3,721.5 WS B, 1D-130 1/19/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,210.0 4,212.0 3,690.6 3,692.6 WS B, 1D-130 11/11/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,212.0 4,241.0 3,692.6 3,721.5 WS B, 1D-130 1/19/1998 4.0 IPERF 180° ph, 2.5" HSD DP
4,246.0 4,248.0 3,726.5 3,728.5 WS A4, 1D-130 11/11/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,251.0 4,256.0 3,731.5 3,736.5 WS A4, 1D-130 1/19/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,256.0 4,276.0 3,736.5 3,756.4 WS A4, 1D-130 1/17/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,262.0 4,264.0 3,742.4 3,744.4 WS A4, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,278.0 4,280.0 3,758.4 3,760.4 WS A4, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,295.0 4,301.0 3,775.3 3,781.3 WS A3, 1D-130 1/17/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,298.0 4,300.0 3,778.3 3,780.3 WS A3, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,300.0 4,301.0 3,780.3 3,781.3 WS A3, 1D-130 1/17/1997 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,310.0 4,342.0 3,790.3 3,822.2 WS A3, 1D-130 1/17/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,354.0 4,356.0 3,834.1 3,836.1 WS A3, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,365.0 4,370.0 3,845.1 3,850.1 WS A2, 1D-130 1/17/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,380.0 4,420.0 3,860.0 3,899.9 WS A2, 1D-130 1/17/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,392.0 4,394.0 3,872.0 3,874.0 WS A2, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,402.0 4,404.0 3,882.0 3,884.0 WS A2, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,430.0 4,432.0 3,909.9 3,911.9 WS A2, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
1D-130, 12/6/2023 8:24:58 AM
Vertical schematic (actual)
PRODUCTION
5.5"x3.5"@4091'; 37.1-4,768.1
IPERF; 4,594.0-4,596.0
IPERF; 4,490.0-4,492.0
IPERF; 4,462.0-4,464.0
APERF; 4,440.0-4,452.0
IPERF; 4,430.0-4,432.0
IPERF; 4,402.0-4,404.0
IPERF; 4,380.0-4,420.0
IPERF; 4,392.0-4,394.0
IPERF; 4,365.0-4,370.0
IPERF; 4,354.0-4,356.0
IPERF; 4,310.0-4,342.0
IPERF; 4,300.0-4,301.0
IPERF; 4,298.0-4,300.0
IPERF; 4,295.0-4,301.0
IPERF; 4,278.0-4,280.0
IPERF; 4,256.0-4,276.0
IPERF; 4,262.0-4,264.0
IPERF; 4,251.0-4,256.0
IPERF; 4,246.0-4,248.0
IPERF; 4,212.0-4,241.0
IPERF; 4,207.0-4,241.0
IPERF; 4,210.0-4,212.0
IPERF; 4,192.0-4,194.0
IPERF; 4,164.0-4,180.0
IPERF; 4,152.0-4,154.0
IPERF; 4,128.0-4,130.0
IPERF; 4,108.0-4,110.0
GAS LIFT; 4,004.0
SURFACE; 37.4-2,529.3
NIPPLE; 519.4
PACKER - PATCH - LWR; 229.0
LEAK - TUBING; 216.0
ANCHOR LATCH ON SPACER
PIPE; 203.0
PACKER - PATCH - UPR; 199.0
CONDUCTOR; 37.4-121.0
KUP INJ
KB-Grd (ft) RR Date
11/8/1997
Other Elev…
1D-130
...
TD
Act Btm (ftKB)
4,778.0
Well Attributes
Field Name
WEST SAK
Wellbore API/UWI
500292281500
Wellbore Status
INJ
Max Angle & MD
Incl (°)
42.54
MD (ftKB)
2,896.15
WELLNAME WELLBORE1D-130
Annotation
Last WO:
End Date
6/16/2008
H2S (ppm) DateComment
SSSV: NIPPLE
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
4,440.0 4,452.0 3,919.9 3,931.8 WS A2, 1D-130 1/17/1998 4.0 APERF 180°ph; 90° Orient; 2.5"HSD
4,462.0 4,464.0 3,941.8 3,943.8 WS A2, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,490.0 4,492.0 3,969.7 3,971.7 WS A2, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,594.0 4,596.0 4,073.4 4,075.4 WS A1, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
1D-130, 12/6/2023 8:24:58 AM
Vertical schematic (actual)
PRODUCTION
5.5"x3.5"@4091'; 37.1-4,768.1
IPERF; 4,594.0-4,596.0
IPERF; 4,490.0-4,492.0
IPERF; 4,462.0-4,464.0
APERF; 4,440.0-4,452.0
IPERF; 4,430.0-4,432.0
IPERF; 4,402.0-4,404.0
IPERF; 4,380.0-4,420.0
IPERF; 4,392.0-4,394.0
IPERF; 4,365.0-4,370.0
IPERF; 4,354.0-4,356.0
IPERF; 4,310.0-4,342.0
IPERF; 4,300.0-4,301.0
IPERF; 4,298.0-4,300.0
IPERF; 4,295.0-4,301.0
IPERF; 4,278.0-4,280.0
IPERF; 4,256.0-4,276.0
IPERF; 4,262.0-4,264.0
IPERF; 4,251.0-4,256.0
IPERF; 4,246.0-4,248.0
IPERF; 4,212.0-4,241.0
IPERF; 4,207.0-4,241.0
IPERF; 4,210.0-4,212.0
IPERF; 4,192.0-4,194.0
IPERF; 4,164.0-4,180.0
IPERF; 4,152.0-4,154.0
IPERF; 4,128.0-4,130.0
IPERF; 4,108.0-4,110.0
GAS LIFT; 4,004.0
SURFACE; 37.4-2,529.3
NIPPLE; 519.4
PACKER - PATCH - LWR; 229.0
LEAK - TUBING; 216.0
ANCHOR LATCH ON SPACER
PIPE; 203.0
PACKER - PATCH - UPR; 199.0
CONDUCTOR; 37.4-121.0
KUP INJ 1D-130
...
WELLNAME WELLBORE1D-130
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83
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Friday, January 26, 2024
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Sully Sullivan
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
ConocoPhillips Alaska, Inc.
1D-130
KUPARUK RIV U WSAK 1D-130
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 01/26/2024
1D-130
50-029-22815-00-00
197-183-0
W
SPT
3568
1971830 1500
930 930 935 935
160 340 300 300
OTHER P
Sully Sullivan
12/20/2023
Post patch MIT per Sundry 323-118
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 1D-130
Inspection Date:
Tubing
OA
Packer Depth
240 2010 1950 1925IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitSTS231220134959
BBL Pumped:0.6 BBL Returned:0.6
Friday, January 26, 2024 Page 1 of 1
9
9
9
9
9
9
9
9 9 9
9
9
Post patch MIT
James B. Regg Digitally signed by James B. Regg
Date: 2024.01.26 09:26:08 -09'00'
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: Pull/ Replace Tubing Patch
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 4778'feet None feet
true vertical 4257'feet None feet
Effective Depth measured 4389'feet 199', 229'feet
true vertical 3869'feet 199', 229'feet
Perforation depth Measured depth
True Vertical depth
Tubing (size, grade, measured and true vertical depth) 2-7/8" L-80 4105' MD 3586' TVD
Packers and SSSV (type, measured and true vertical depth) 199' MD
229' MD
N/A
199' TVD
229' TVD
N/A
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure: N/A
13a.
Prior to well operation:
Subsequent to operation:
13b. Pools active after work: West Sak Oil Pool
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:
2529' 2240'
Burst Collapse
Production
Liner
4731'
Casing
4247'4768'
2492'
121'Conductor
Surface
Intermediate
16"
7-5/8"
84'
measured
TVD
5-1/2" x 3-1/2"
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
197-183
50-029-22815-00-00
P.O. Box 100360
Anchorage, AK 99510
3. Address:
ConocoPhillips Alaska, Inc.
N/A
5. Permit to Drill Number:2. Operator Name
N
4. Well Class Before Work:
ADL0025650
Kuparuk River Field/ West Sak Oil Pool
KRU 1D-130
Plugs
Junk measured
Length
measured
true vertical
Packer
Representative Daily Average Production or Injection Data
Casing Pressure Tubing Pressure
14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283)
~
Gas-Mcf
MD
~
Size
121'
~~~
INJECTOR ~~
~
323-118
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.
N/A
Packer: P2P Patch Packer
Packer: P2P Patch Packer
SSSV: None
Allen Eschete
allen.eschete@conocophillips.com
(907) 265-6558Interventions Engineer
4108-4596'
3589-4075'
Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov
By Grace Christianson at 2:07 pm, Jan 02, 2024
Digitally signed by Allen Eschete
DN: CN=Allen Eschete, E=Allen.Eschete@
ConocoPhillips.com
Reason: I am the author of this document
Location:
Date: 2024.01.02 13:21:22-09'00'
Foxit PDF Editor Version: 13.0.0
Allen Eschete
DSR-1/26/24
RBDMS JSB 010324
DTTMSTART JOBTYP SUMMARYOPS
12/4/2023 ACQUIRE DATA PULLED UPPER P2P PACKER & SPACER PIPE @ 204' RKB.
PULLED LOWER P2P PACKER @ 234' RKB. DRIFTED TBG W/
DMY CA2 PLUG DRIFT TO D-NIP @ 4053' RKB WITHOUT ANY
ISSUES. BRUSHED PATCH SETTING AREA, SET LOWER 2.29"
P2P MID ELEMENT @ 229' RKB, IN PROGRESS
12/5/2023 ACQUIRE DATA CMIT TBG x IA W/ TEST TOOL IN LOWER PACKER @ 229'
RKB, 2500 PSI(PASS). SET UPPER 2.29" P2P PATCH
ASSEMBLY @ 199' RKB (CE) (OAL 30.8' / SN:CPP287075 /
CPAL287021), MIT IA 2500 PSI (PASS). JOB COMPLETE.
12/20/2023 ACQUIRE DATA (SW) STATE WITNESSED (SULLY SULLIVAN) MITIA (PASS) @
2010 PSI
1D-130 Pull/ Replace Tubing Patch
Summary of Operations
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag: RKB 4,389.0 1D-130 2/1/2018 pproven
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Pulled & replaced patch. 1D-130 12/5/2023 fergusp
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 37.4 121.0 121.0 62.50 H-40 WELDED
SURFACE 7 5/8 6.87 37.4 2,529.3 2,239.7 29.70 L-80 ABM-BTC
PRODUCTION
5.5"x3.5"@4091'
5 1/2 4.95 37.1 4,768.1 4,247.2 15.50 L-80 BTC
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
41.4
Set Depth …
4,104.7
Set Depth …
3,585.8
String Max No…
2 7/8
Tubing Description
TUBING WO
Wt (lb/ft)
6.50
Grade
L-80
Top Connection
EUE8rdAB
MOD
ID (in)
2.44
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)
41.4 41.4 0.00 HANGER 6.000 Tubing Hanger T&C
Upset
2.441
519.4 519.4 0.36 NIPPLE 3.680 Camco "DS" Nipple 2.312" T&C
Upset
2.312
4,003.9 3,485.6 7.08 GAS LIFT 4.750 Camco Mandrel KBMG-M w/1" DCK-
2 SOV 1500 psi
CAMCO KBMG-
M
2.347
4,052.9 3,534.3 6.04 NIPPLE 3.680 Camco "D" Nipple 2.250" 2.250
4,091.7 3,572.8 5.78 SEAL ASSY 4.500 Baker 3-1/2" Locator Seal Assembly 3.000
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top (ftKB)
Top (TVD)
(ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in)
199.0 199.0 0.09 PACKER -
PATCH - UPR
UPPER 2.29" P2P (2400LB
RELEASE), SPACER PIPE, &
ANCHOR LATCH (30.5' OAL)
CPP2
87075
12/5/2023 1.375
203.0 203.0 0.10 ANCHOR
LATCH ON
SPACER
PIPE
2 1/16" P110 SPACER PIPE
AND ANCHOR LATCH
CPAL
28702
1
12/5/2023 1.375
216.0 216.0 0.11 LEAK -
TUBING
LEAK @216' 7/2/2019
229.0 229.0 0.13 PACKER -
PATCH - LWR
LOWER 2.29" P2P MID-
ELEMENT AT 229' RKB
(2400LB RELEASE) (3.55'
OAL)
CPP2
87087
12/4/2023 1.375
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)
4,003.9 3,485.6 7.08 1 Gas Lift DMY BK 1 0.0 6/23/2008 0.000
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
4,108.0 4,110.0 3,589.1 3,591.1 11/11/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,128.0 4,130.0 3,609.0 3,611.0 11/11/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,152.0 4,154.0 3,632.9 3,634.9 WS D, 1D-130 11/11/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,164.0 4,180.0 3,644.8 3,660.7 WS D, 1D-130 1/19/1998 4.0 IPERF 180° ph; 90° Orient; 2.5"HSD
4,192.0 4,194.0 3,672.7 3,674.7 WS C, 1D-130 11/11/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,207.0 4,241.0 3,687.6 3,721.5 WS B, 1D-130 1/19/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,210.0 4,212.0 3,690.6 3,692.6 WS B, 1D-130 11/11/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,212.0 4,241.0 3,692.6 3,721.5 WS B, 1D-130 1/19/1998 4.0 IPERF 180° ph, 2.5" HSD DP
4,246.0 4,248.0 3,726.5 3,728.5 WS A4, 1D-130 11/11/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,251.0 4,256.0 3,731.5 3,736.5 WS A4, 1D-130 1/19/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,256.0 4,276.0 3,736.5 3,756.4 WS A4, 1D-130 1/17/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,262.0 4,264.0 3,742.4 3,744.4 WS A4, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,278.0 4,280.0 3,758.4 3,760.4 WS A4, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,295.0 4,301.0 3,775.3 3,781.3 WS A3, 1D-130 1/17/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,298.0 4,300.0 3,778.3 3,780.3 WS A3, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,300.0 4,301.0 3,780.3 3,781.3 WS A3, 1D-130 1/17/1997 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,310.0 4,342.0 3,790.3 3,822.2 WS A3, 1D-130 1/17/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,354.0 4,356.0 3,834.1 3,836.1 WS A3, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,365.0 4,370.0 3,845.1 3,850.1 WS A2, 1D-130 1/17/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,380.0 4,420.0 3,860.0 3,899.9 WS A2, 1D-130 1/17/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,392.0 4,394.0 3,872.0 3,874.0 WS A2, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,402.0 4,404.0 3,882.0 3,884.0 WS A2, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,430.0 4,432.0 3,909.9 3,911.9 WS A2, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
1D-130, 12/27/2023 9:19:21 AM
Vertical schematic (actual)
PRODUCTION
5.5"x3.5"@4091'; 37.1-4,768.1
IPERF; 4,594.0-4,596.0
IPERF; 4,490.0-4,492.0
IPERF; 4,462.0-4,464.0
APERF; 4,440.0-4,452.0
IPERF; 4,430.0-4,432.0
IPERF; 4,402.0-4,404.0
IPERF; 4,380.0-4,420.0
IPERF; 4,392.0-4,394.0
IPERF; 4,365.0-4,370.0
IPERF; 4,354.0-4,356.0
IPERF; 4,310.0-4,342.0
IPERF; 4,300.0-4,301.0
IPERF; 4,298.0-4,300.0
IPERF; 4,295.0-4,301.0
IPERF; 4,278.0-4,280.0
IPERF; 4,256.0-4,276.0
IPERF; 4,262.0-4,264.0
IPERF; 4,251.0-4,256.0
IPERF; 4,246.0-4,248.0
IPERF; 4,212.0-4,241.0
IPERF; 4,207.0-4,241.0
IPERF; 4,210.0-4,212.0
IPERF; 4,192.0-4,194.0
IPERF; 4,164.0-4,180.0
IPERF; 4,152.0-4,154.0
IPERF; 4,128.0-4,130.0
IPERF; 4,108.0-4,110.0
GAS LIFT; 4,004.0
SURFACE; 37.4-2,529.3
NIPPLE; 519.4
PACKER - PATCH - LWR; 229.0
LEAK - TUBING; 216.0
ANCHOR LATCH ON SPACER
PIPE; 203.0
PACKER - PATCH - UPR; 199.0
CONDUCTOR; 37.4-121.0
KUP INJ
KB-Grd (ft) RR Date
11/8/1997
Other Elev…
1D-130
...
TD
Act Btm (ftKB)
4,778.0
Well Attributes
Field Name
WEST SAK
Wellbore API/UWI
500292281500
Wellbore Status
INJ
Max Angle & MD
Incl (°)
42.54
MD (ftKB)
2,896.15
WELLNAME WELLBORE1D-130
Annotation
Last WO:
End Date
6/16/2008
H2S (ppm) DateComment
SSSV: NIPPLE
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
4,440.0 4,452.0 3,919.9 3,931.8 WS A2, 1D-130 1/17/1998 4.0 APERF 180°ph; 90° Orient; 2.5"HSD
4,462.0 4,464.0 3,941.8 3,943.8 WS A2, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,490.0 4,492.0 3,969.7 3,971.7 WS A2, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,594.0 4,596.0 4,073.4 4,075.4 WS A1, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
1D-130, 12/27/2023 9:19:22 AM
Vertical schematic (actual)
PRODUCTION
5.5"x3.5"@4091'; 37.1-4,768.1
IPERF; 4,594.0-4,596.0
IPERF; 4,490.0-4,492.0
IPERF; 4,462.0-4,464.0
APERF; 4,440.0-4,452.0
IPERF; 4,430.0-4,432.0
IPERF; 4,402.0-4,404.0
IPERF; 4,380.0-4,420.0
IPERF; 4,392.0-4,394.0
IPERF; 4,365.0-4,370.0
IPERF; 4,354.0-4,356.0
IPERF; 4,310.0-4,342.0
IPERF; 4,300.0-4,301.0
IPERF; 4,298.0-4,300.0
IPERF; 4,295.0-4,301.0
IPERF; 4,278.0-4,280.0
IPERF; 4,256.0-4,276.0
IPERF; 4,262.0-4,264.0
IPERF; 4,251.0-4,256.0
IPERF; 4,246.0-4,248.0
IPERF; 4,212.0-4,241.0
IPERF; 4,207.0-4,241.0
IPERF; 4,210.0-4,212.0
IPERF; 4,192.0-4,194.0
IPERF; 4,164.0-4,180.0
IPERF; 4,152.0-4,154.0
IPERF; 4,128.0-4,130.0
IPERF; 4,108.0-4,110.0
GAS LIFT; 4,004.0
SURFACE; 37.4-2,529.3
NIPPLE; 519.4
PACKER - PATCH - LWR; 229.0
LEAK - TUBING; 216.0
ANCHOR LATCH ON SPACER
PIPE; 203.0
PACKER - PATCH - UPR; 199.0
CONDUCTOR; 37.4-121.0
KUP INJ 1D-130
...
WELLNAME WELLBORE1D-130
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 1D-130 (PTD 197-183) Update and return to normal status
Date:Tuesday, March 28, 2023 1:50:00 PM
Attachments:AnnComm Surveillance TIO for 1D-130.pdf
MIT KRU 1D-130 diagnostic MITIA 3-2-23.xlsx
From: Byrne, Jan <Jan.Byrne@conocophillips.com>
Sent: Tuesday, March 28, 2023 1:46 PM
To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>
Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>
Subject: KRU 1D-130 (PTD 197-183) Update and return to normal status
Chris,
KRU 1D-130 (PTD 197-183) was reported last month after TIO trend review had revealed that the IA
pressure had a precipitous drop last December. Subsequent the report DHD performed a passing
MITIA and pack off tests after which the IA pressure was left elevated for the monitor period.
Throughout the monitor period the IA pressure has exhibited no signs of pressure fall off or other
anomalies. CPAI intends to return this well to its ‘normal’ status at this time. A 90 day TIO trend and
10-426 for the diagnostic MITIA are attached.
Please let me know if you disagree with 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
1D-130 90-Day Bleed History
WELL DATE STR-PRES END-PRES DIF-PRES CASING
1D-130 2023-02-05 42 5 -37 IA
1D-130 2023-03-11 588 263 -325 IA
Last Tag
Annotation Depth (ftKB) End Date Wellbore Last Mod By
Last Tag: RKB 4,389.0 2/1/2018 1D-130 pproven
Last Rev Reason
Annotation End Date Wellbore Last Mod By
Rev Reason: Set Upper Section of Patch 7/28/2022 1D-130 zembaej
Casing Strings
Top (ftKB)
37.4
Set Depth …
121.0
OD (in)
16
Casing Description
CONDUCTOR
Set Depth (ft…
121.0
Wt/Len (lb/ft)
62.50
Grade
H-40
Top Connection
WELDED
ID (in)
15.06
Top (ftKB)
37.4
Set Depth …
2,239.7
OD (in)
7 5/8
Casing Description
SURFACE
Set Depth (ft…
2,529.3
Wt/Len (lb/ft)
29.70
Grade
L-80
Top Connection
ABM-BTC
ID (in)
6.87
Top (ftKB)
37.1
Set Depth …
4,247.2
OD (in)
5 1/2
Casing Description
PRODUCTION
5.5"x3.5"@4091'
Set Depth (ft…
4,768.1
Wt/Len (lb/ft)
15.50
Grade
L-80
Top Connection
BTC
ID (in)
4.95
Tubing Strings: string max indicates LONGEST segment of string
Top (ftKB)
41.4
Set Depth …
3,585.8
String Ma…
2 7/8
Tubing Description
TUBING WO
Set Depth (ftKB)
4,104.7
Wt (lb/ft)
6.50
Grade
L-80
Top Connection
EUE8rdAB MOD
ID (in)
2.44
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)
41.4 41.4 0.00 HANGER 6.000 Tubing Hanger T&C
Upset
2.441
519.4 519.4 0.36 NIPPLE 3.680 Camco "DS" Nipple 2.312" T&C
Upset
2.312
4,003.9 3,485.6 7.08 GAS LIFT 4.750 Camco Mandrel KBMG-M w/1" DCK-
2 SOV 1500 psi
CAMCO KBMG-
M
2.347
4,052.9 3,534.3 6.04 NIPPLE 3.680 Camco "D" Nipple 2.250" 2.250
4,091.7 3,572.8 5.78 SEAL ASSY 4.500 Baker 3-1/2" Locator Seal Assembly 3.000
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top (ftKB)
Top (TVD)
(ftKB) Top Incl (°) Des Com Make Model SN ID (in)
203.8 203.8 0.10 PACKER -
PATCH - UPR
UPPER 2.29" P2P (2400LB
RELEASE), SPACER PIPE, &
ANCHOR LATCH (30.5' OAL)
CPP28
7086
1.375
207.0 207.0 0.10 ANCHOR
LATCH ON
SPACER PIPE
2 1/16" P110 SPACER PIPE AND
ANCHOR LATCH
CPAL2
87046
1.375
216.0 216.0 0.11 LEAK - TUBING LEAK @216'
233.9 233.9 0.14 PACKER -
PATCH - LWR
LOWER 2.29" P2P MID-
ELEMENT AT 236' RKB (2400LB
RELEASE) (3.55' OAL)
CPP28
7046
1.375
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)
4,003.9 3,485.6 7.08 1 Gas Lift DMY BK 1 0.0 6/23/2008 0.000
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
4,108.0 4,110.0 3,589.1 3,591.1 11/11/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,128.0 4,130.0 3,609.0 3,611.0 11/11/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,152.0 4,154.0 3,632.9 3,634.9 WS D, 1D-130 11/11/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,164.0 4,180.0 3,644.8 3,660.7 WS D, 1D-130 1/19/1998 4.0 IPERF 180° ph; 90° Orient; 2.5"HSD
4,192.0 4,194.0 3,672.7 3,674.7 WS C, 1D-130 11/11/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,207.0 4,241.0 3,687.6 3,721.5 WS B, 1D-130 1/19/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,210.0 4,212.0 3,690.6 3,692.6 WS B, 1D-130 11/11/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,212.0 4,241.0 3,692.6 3,721.5 WS B, 1D-130 1/19/1998 4.0 IPERF 180° ph, 2.5" HSD DP
4,246.0 4,248.0 3,726.5 3,728.5 WS A4, 1D-130 11/11/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,251.0 4,256.0 3,731.5 3,736.5 WS A4, 1D-130 1/19/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,256.0 4,276.0 3,736.5 3,756.4 WS A4, 1D-130 1/17/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,262.0 4,264.0 3,742.4 3,744.4 WS A4, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,278.0 4,280.0 3,758.4 3,760.4 WS A4, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,295.0 4,301.0 3,775.3 3,781.3 WS A3, 1D-130 1/17/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,298.0 4,300.0 3,778.3 3,780.3 WS A3, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,300.0 4,301.0 3,780.3 3,781.3 WS A3, 1D-130 1/17/1997 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,310.0 4,342.0 3,790.3 3,822.2 WS A3, 1D-130 1/17/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,354.0 4,356.0 3,834.1 3,836.1 WS A3, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,365.0 4,370.0 3,845.1 3,850.1 WS A2, 1D-130 1/17/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,380.0 4,420.0 3,860.0 3,899.9 WS A2, 1D-130 1/17/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,392.0 4,394.0 3,872.0 3,874.0 WS A2, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,402.0 4,404.0 3,882.0 3,884.0 WS A2, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,430.0 4,432.0 3,909.9 3,911.9 WS A2, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,440.0 4,452.0 3,919.9 3,931.8 WS A2, 1D-130 1/17/1998 4.0 APERF 180°ph; 90° Orient; 2.5"HSD
4,462.0 4,464.0 3,941.8 3,943.8 WS A2, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
1D-130, 7/29/2022 8:04:19 AM
Vertical schematic (actual)
PRODUCTION
5.5"x3.5"@4091'; 37.1-4,768.1
IPERF; 4,594.0-4,596.0
IPERF; 4,490.0-4,492.0
IPERF; 4,462.0-4,464.0
APERF; 4,440.0-4,452.0
IPERF; 4,430.0-4,432.0
IPERF; 4,402.0-4,404.0
IPERF; 4,380.0-4,420.0
IPERF; 4,392.0-4,394.0
IPERF; 4,365.0-4,370.0
IPERF; 4,354.0-4,356.0
IPERF; 4,310.0-4,342.0
IPERF; 4,300.0-4,301.0
IPERF; 4,298.0-4,300.0
IPERF; 4,295.0-4,301.0
IPERF; 4,278.0-4,280.0
IPERF; 4,256.0-4,276.0
IPERF; 4,262.0-4,264.0
IPERF; 4,251.0-4,256.0
IPERF; 4,246.0-4,248.0
IPERF; 4,212.0-4,241.0
IPERF; 4,207.0-4,241.0
IPERF; 4,210.0-4,212.0
IPERF; 4,192.0-4,194.0
IPERF; 4,164.0-4,180.0
IPERF; 4,152.0-4,154.0
IPERF; 4,128.0-4,130.0
IPERF; 4,108.0-4,110.0
SEAL ASSY; 4,091.7
NIPPLE; 4,052.9
GAS LIFT; 4,004.0
SURFACE; 37.4-2,529.3
NIPPLE; 519.4
PACKER - PATCH - LWR; 233.9
ANCHOR LATCH ON SPACER
PIPE; 207.0
LEAK - TUBING; 216.0
PACKER - PATCH - UPR; 203.8
CONDUCTOR; 37.4-121.0
HANGER; 41.4
KUP INJ
KB-Grd (ft) RR Date
11/8/1997
Other Elev…
1D-130
...
TD
Act Btm (ftKB)
4,778.0
Well Attributes
Field Name
WEST SAK
Wellbore API/UWI
500292281500
Wellbore Status
INJ
Max Angle & MD
Incl (°)
42.54
MD (ftKB)
2,896.15
WELLNAME WELLBORE1D-130
Annotation
Last WO:
End Date
6/16/2008
H2S (ppm) DateComment
SSSV: NIPPLE
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
4,490.0 4,492.0 3,969.7 3,971.7 WS A2, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,594.0 4,596.0 4,073.4 4,075.4 WS A1, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
1D-130, 7/29/2022 8:04:20 AM
Vertical schematic (actual)
PRODUCTION
5.5"x3.5"@4091'; 37.1-4,768.1
IPERF; 4,594.0-4,596.0
IPERF; 4,490.0-4,492.0
IPERF; 4,462.0-4,464.0
APERF; 4,440.0-4,452.0
IPERF; 4,430.0-4,432.0
IPERF; 4,402.0-4,404.0
IPERF; 4,380.0-4,420.0
IPERF; 4,392.0-4,394.0
IPERF; 4,365.0-4,370.0
IPERF; 4,354.0-4,356.0
IPERF; 4,310.0-4,342.0
IPERF; 4,300.0-4,301.0
IPERF; 4,298.0-4,300.0
IPERF; 4,295.0-4,301.0
IPERF; 4,278.0-4,280.0
IPERF; 4,256.0-4,276.0
IPERF; 4,262.0-4,264.0
IPERF; 4,251.0-4,256.0
IPERF; 4,246.0-4,248.0
IPERF; 4,212.0-4,241.0
IPERF; 4,207.0-4,241.0
IPERF; 4,210.0-4,212.0
IPERF; 4,192.0-4,194.0
IPERF; 4,164.0-4,180.0
IPERF; 4,152.0-4,154.0
IPERF; 4,128.0-4,130.0
IPERF; 4,108.0-4,110.0
SEAL ASSY; 4,091.7
NIPPLE; 4,052.9
GAS LIFT; 4,004.0
SURFACE; 37.4-2,529.3
NIPPLE; 519.4
PACKER - PATCH - LWR; 233.9
ANCHOR LATCH ON SPACER
PIPE; 207.0
LEAK - TUBING; 216.0
PACKER - PATCH - UPR; 203.8
CONDUCTOR; 37.4-121.0
HANGER; 41.4
KUP INJ 1D-130
...
WELLNAME WELLBORE1D-130
Submit to:
OPERATOR:
FIELD / UNIT / PAD:
DATE:
OPERATOR REP:
AOGCC REP:
Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min.
PTD 1971830 Type Inj W Tubing 930 930 930 930 Type Test P
Packer TVD 3573 BBL Pump 1.0 IA 23 3000 2880 2860 Interval O
Test psi 1500 BBL Return OA 140 410 410 370 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 / 1D Pad
VanCamp
03/02/23
Notes:Diagnostic MITIA
Notes:
1D-130
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 1D-130 diagnostic MITIA 3-2-23 (002)
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Do not click links or open attachments unless you recognize the sender and know
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From:Wallace, Chris D (OGC)
To:AOGCC Records (CED sponsored)
Subject:FW: KRU 1D-130 (PTD 197-183) Report of suspect IA pressure fall off
Date:Wednesday, March 1, 2023 11:08:14 AM
Attachments:AnnComm Surveillance TIO for 1D-130.pdf
From: Byrne, Jan <Jan.Byrne@conocophillips.com>
Sent: Wednesday, March 1, 2023 9:46 AM
To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>
Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>
Subject: KRU 1D-130 (PTD 197-183) Report of suspect IA pressure fall off
Chris,
KRU 1D-130 (PTD 197-183) During review of TIO trends it was noted that 1D-130’s IA pressure had a
precipitous drop off around December 25, 2022. DHD will be mobilized to perform initial testing to
include an MITIA, pack off tests and adjust the IA pressure for a 30 day monitor. Any required
paperwork for continued injection or corrective action will be submitted once a plan 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, Inc.
Office phone: (907) 659-7224
Cell phone: (808) 345-6886
1D-130 90-Day Bleed History
WELL DATE STR-PRES END-PRES DIF-PRES CASING
1D-130 2023-02-05 42 5 -37 IA
Last Tag
Annotation Depth (ftKB) End Date Wellbore Last Mod By
Last Tag: RKB 4,389.0 2/1/2018 1D-130 pproven
Last Rev Reason
Annotation End Date Wellbore Last Mod By
Rev Reason: Set Upper Section of Patch 7/28/2022 1D-130 zembaej
Casing Strings
Top (ftKB)
37.4
Set Depth …
121.0
OD (in)
16
Casing Description
CONDUCTOR
Set Depth (ft…
121.0
Wt/Len (lb/ft)
62.50
Grade
H-40
Top Connection
WELDED
ID (in)
15.06
Top (ftKB)
37.4
Set Depth …
2,239.7
OD (in)
7 5/8
Casing Description
SURFACE
Set Depth (ft…
2,529.3
Wt/Len (lb/ft)
29.70
Grade
L-80
Top Connection
ABM-BTC
ID (in)
6.87
Top (ftKB)
37.1
Set Depth …
4,247.2
OD (in)
5 1/2
Casing Description
PRODUCTION
5.5"x3.5"@4091'
Set Depth (ft…
4,768.1
Wt/Len (lb/ft)
15.50
Grade
L-80
Top Connection
BTC
ID (in)
4.95
Tubing Strings: string max indicates LONGEST segment of string
Top (ftKB)
41.4
Set Depth …
3,585.8
String Ma…
2 7/8
Tubing Description
TUBING WO
Set Depth (ftKB)
4,104.7
Wt (lb/ft)
6.50
Grade
L-80
Top Connection
EUE8rdAB MOD
ID (in)
2.44
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)
41.4 41.4 0.00 HANGER 6.000 Tubing Hanger T&C
Upset
2.441
519.4 519.4 0.36 NIPPLE 3.680 Camco "DS" Nipple 2.312" T&C
Upset
2.312
4,003.9 3,485.6 7.08 GAS LIFT 4.750 Camco Mandrel KBMG-M w/1" DCK-
2 SOV 1500 psi
CAMCO KBMG-
M
2.347
4,052.9 3,534.3 6.04 NIPPLE 3.680 Camco "D" Nipple 2.250" 2.250
4,091.7 3,572.8 5.78 SEAL ASSY 4.500 Baker 3-1/2" Locator Seal Assembly 3.000
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top (ftKB)
Top (TVD)
(ftKB) Top Incl (°) Des Com Make Model SN ID (in)
203.8 203.8 0.10 PACKER -
PATCH - UPR
UPPER 2.29" P2P (2400LB
RELEASE), SPACER PIPE, &
ANCHOR LATCH (30.5' OAL)
CPP28
7086
1.375
207.0 207.0 0.10 ANCHOR
LATCH ON
SPACER PIPE
2 1/16" P110 SPACER PIPE AND
ANCHOR LATCH
CPAL2
87046
1.375
216.0 216.0 0.11 LEAK - TUBING LEAK @216'
233.9 233.9 0.14 PACKER -
PATCH - LWR
LOWER 2.29" P2P MID-
ELEMENT AT 236' RKB (2400LB
RELEASE) (3.55' OAL)
CPP28
7046
1.375
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)
4,003.9 3,485.6 7.08 1 Gas Lift DMY BK 1 0.0 6/23/2008 0.000
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
4,108.0 4,110.0 3,589.1 3,591.1 11/11/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,128.0 4,130.0 3,609.0 3,611.0 11/11/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,152.0 4,154.0 3,632.9 3,634.9 WS D, 1D-130 11/11/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,164.0 4,180.0 3,644.8 3,660.7 WS D, 1D-130 1/19/1998 4.0 IPERF 180° ph; 90° Orient; 2.5"HSD
4,192.0 4,194.0 3,672.7 3,674.7 WS C, 1D-130 11/11/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,207.0 4,241.0 3,687.6 3,721.5 WS B, 1D-130 1/19/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,210.0 4,212.0 3,690.6 3,692.6 WS B, 1D-130 11/11/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,212.0 4,241.0 3,692.6 3,721.5 WS B, 1D-130 1/19/1998 4.0 IPERF 180° ph, 2.5" HSD DP
4,246.0 4,248.0 3,726.5 3,728.5 WS A4, 1D-130 11/11/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,251.0 4,256.0 3,731.5 3,736.5 WS A4, 1D-130 1/19/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,256.0 4,276.0 3,736.5 3,756.4 WS A4, 1D-130 1/17/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,262.0 4,264.0 3,742.4 3,744.4 WS A4, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,278.0 4,280.0 3,758.4 3,760.4 WS A4, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,295.0 4,301.0 3,775.3 3,781.3 WS A3, 1D-130 1/17/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,298.0 4,300.0 3,778.3 3,780.3 WS A3, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,300.0 4,301.0 3,780.3 3,781.3 WS A3, 1D-130 1/17/1997 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,310.0 4,342.0 3,790.3 3,822.2 WS A3, 1D-130 1/17/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,354.0 4,356.0 3,834.1 3,836.1 WS A3, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,365.0 4,370.0 3,845.1 3,850.1 WS A2, 1D-130 1/17/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,380.0 4,420.0 3,860.0 3,899.9 WS A2, 1D-130 1/17/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,392.0 4,394.0 3,872.0 3,874.0 WS A2, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,402.0 4,404.0 3,882.0 3,884.0 WS A2, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,430.0 4,432.0 3,909.9 3,911.9 WS A2, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,440.0 4,452.0 3,919.9 3,931.8 WS A2, 1D-130 1/17/1998 4.0 APERF 180°ph; 90° Orient; 2.5"HSD
4,462.0 4,464.0 3,941.8 3,943.8 WS A2, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
1D-130, 7/29/2022 8:04:19 AM
Vertical schematic (actual)
PRODUCTION
5.5"x3.5"@4091'; 37.1-4,768.1
IPERF; 4,594.0-4,596.0
IPERF; 4,490.0-4,492.0
IPERF; 4,462.0-4,464.0
APERF; 4,440.0-4,452.0
IPERF; 4,430.0-4,432.0
IPERF; 4,402.0-4,404.0
IPERF; 4,380.0-4,420.0
IPERF; 4,392.0-4,394.0
IPERF; 4,365.0-4,370.0
IPERF; 4,354.0-4,356.0
IPERF; 4,310.0-4,342.0
IPERF; 4,300.0-4,301.0
IPERF; 4,298.0-4,300.0
IPERF; 4,295.0-4,301.0
IPERF; 4,278.0-4,280.0
IPERF; 4,256.0-4,276.0
IPERF; 4,262.0-4,264.0
IPERF; 4,251.0-4,256.0
IPERF; 4,246.0-4,248.0
IPERF; 4,212.0-4,241.0
IPERF; 4,207.0-4,241.0
IPERF; 4,210.0-4,212.0
IPERF; 4,192.0-4,194.0
IPERF; 4,164.0-4,180.0
IPERF; 4,152.0-4,154.0
IPERF; 4,128.0-4,130.0
IPERF; 4,108.0-4,110.0
SEAL ASSY; 4,091.7
NIPPLE; 4,052.9
GAS LIFT; 4,004.0
SURFACE; 37.4-2,529.3
NIPPLE; 519.4
PACKER - PATCH - LWR; 233.9
ANCHOR LATCH ON SPACER
PIPE; 207.0
LEAK - TUBING; 216.0
PACKER - PATCH - UPR; 203.8
CONDUCTOR; 37.4-121.0
HANGER; 41.4
KUP INJ
KB-Grd (ft) RR Date
11/8/1997
Other Elev…
1D-130
...
TD
Act Btm (ftKB)
4,778.0
Well Attributes
Field Name
WEST SAK
Wellbore API/UWI
500292281500
Wellbore Status
INJ
Max Angle & MD
Incl (°)
42.54
MD (ftKB)
2,896.15
WELLNAME WELLBORE1D-130
Annotation
Last WO:
End Date
6/16/2008
H2S (ppm) DateComment
SSSV: NIPPLE
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
4,490.0 4,492.0 3,969.7 3,971.7 WS A2, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,594.0 4,596.0 4,073.4 4,075.4 WS A1, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
1D-130, 7/29/2022 8:04:20 AM
Vertical schematic (actual)
PRODUCTION
5.5"x3.5"@4091'; 37.1-4,768.1
IPERF; 4,594.0-4,596.0
IPERF; 4,490.0-4,492.0
IPERF; 4,462.0-4,464.0
APERF; 4,440.0-4,452.0
IPERF; 4,430.0-4,432.0
IPERF; 4,402.0-4,404.0
IPERF; 4,380.0-4,420.0
IPERF; 4,392.0-4,394.0
IPERF; 4,365.0-4,370.0
IPERF; 4,354.0-4,356.0
IPERF; 4,310.0-4,342.0
IPERF; 4,300.0-4,301.0
IPERF; 4,298.0-4,300.0
IPERF; 4,295.0-4,301.0
IPERF; 4,278.0-4,280.0
IPERF; 4,256.0-4,276.0
IPERF; 4,262.0-4,264.0
IPERF; 4,251.0-4,256.0
IPERF; 4,246.0-4,248.0
IPERF; 4,212.0-4,241.0
IPERF; 4,207.0-4,241.0
IPERF; 4,210.0-4,212.0
IPERF; 4,192.0-4,194.0
IPERF; 4,164.0-4,180.0
IPERF; 4,152.0-4,154.0
IPERF; 4,128.0-4,130.0
IPERF; 4,108.0-4,110.0
SEAL ASSY; 4,091.7
NIPPLE; 4,052.9
GAS LIFT; 4,004.0
SURFACE; 37.4-2,529.3
NIPPLE; 519.4
PACKER - PATCH - LWR; 233.9
ANCHOR LATCH ON SPACER
PIPE; 207.0
LEAK - TUBING; 216.0
PACKER - PATCH - UPR; 203.8
CONDUCTOR; 37.4-121.0
HANGER; 41.4
KUP INJ 1D-130
...
WELLNAME WELLBORE1D-130
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Thursday, September 1, 2022
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Lou Laubenstein
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
ConocoPhillips Alaska, Inc.
1D-130
KUPARUK RIV U WSAK 1D-130
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 09/01/2022
1D-130
50-029-22815-00-00
197-183-0
W
SPT
3568
1971830 1500
880 880 880 880
140 210 170 150
OTHER P
Lou Laubenstein
8/9/2022
MIT-IA per Sundry # 322-058, test will also complete 4-year test
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 1D-130
Inspection Date:
Tubing
OA
Packer Depth
1305 2215 2150 2140IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitLOL220810094231
BBL Pumped:0.3 BBL Returned:0.3
Thursday, September 1, 2022 Page 1 of 1
9
9
9
9
9
9
99
9 9 9
9
Sundry # 322-058,
James B. Regg Digitally signed by James B. Regg
Date: 2022.09.01 14:46:41 -08'00'
Operations shutdownRepair WellFracture StimulatePlug PerforationsAbandon1. Type of Request:
Change Approved ProgramPull TubingOther StimulatePerforateSuspend
Perforate New Pool Re-enter Susp Well Other: Pull/ Replace Tubing PatchAlter CasingPlug for Redrill
5. Permit to Drill Number:4. Current Well Class:2. Operator Name:
DevelopmentExploratory
3. Address:ServiceStratigraphic 6. API Number:
8. Well Name and Number:7. If perforating:
What Regulation or Conservation Order governs well spacing in this pool?
NoWill planned perforations require a spacing exception? Yes
Current Pools:10. Field:9. Property Designation (Lease Number):
11.
Junk (MD):Plugs (MD):MPSP (psi):Effective Depth TVD:Effective Depth MD:Total Depth TVD (ft):Total Depth MD (ft):
None4778'
CollapseCasing
Structural
Conductor
Surface
Intermediate
Production
Liner
Packers and SSSV MD (ft) and TVD (ft):Packers and SSSV Type:
13. Well Class after proposed work:12. Attachments: Proposal Summary Wellbore schematic
ServiceDevelopmentExploratory StratigraphicDetailed Operations Program BOP Sketch
15. Well Status after proposed work:14. Estimated Date for
WDSPLWINJOILCommencing Operations:Suspended
WAGGASDate:16. Verbal Approval:SPLUGGSTOR
AOGCC Representative: GINJ AbandonedOp Shutdown
Contact Name:
Contact Email:
Contact Phone:
Authorized Title:
Sundry Number:Conditions of approval: Notify AOGCC so that a representative may witness
Location ClearanceMechanical Integrity TestBOP TestPlug Integrity
Other:
Post Initial Injection MIT Req'd? NoYes
Spacing Exception Required? Subsequent Form Required:NoYes
APPROVED BY
Date:COMMISSIONERApproved by:THE AOGCC
Sr Res EngSr Pet GeoSr Pet EngComm.Comm.
4108-4596'
4731'
2-7/8"3589-4075'
5-1/2 x 3-1/2"
16"
7-5/8"
84'
2492'
Perforation Depth MD (ft):
MD
121'
2240'
121'
2529'
4247'4768'
SizeLength
Proposed Pools:
BurstTVD
PRESENT WELL CONDITION SUMMARY
None4389'4257'
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL0025650
197-183
P.O. Box 100360, Anchorage, AK 99510 50-029-22815-00-00
ConocoPhillips Alaska, Inc.
KRU 1D-130
West Sak Oil PoolWest Sak Oil PoolKuparuk River Field
N/A
Tubing Grade:
204' MD and 204' TVD
234' MD and 234' TVD
N/A
Tubing Size:Perforation Depth TVD (ft):
L-80
3/10/2023
Packer: P2P Patch Packer
Packer: P2P Patch Packer
SSV: None
17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval.
Authorized Name and
Digital Signature with Date:
AOGCC USE ONLY
Allen Eschete
allen.eschete@conocophillips.com
(907) 265-6558
Intervention Engineer
Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
3869'
Tubing MD (ft):
4105'
By Samantha Carlisle at 11:35 am, Feb 23, 2023
323-118
Digitally signed by Allen Eschete
DN: CN=Allen Eschete, E=Allen.Eschete@ConocoPhillips.com
Reason: I have reviewed this document
Location:
Date: 2023.02.23 07:22:49-09'00'
Foxit PDF Editor Version: 12.0.1
Allen Eschete
SFD 3/1/2023 DSR-2/23/23
X
VTL 03/08/23
10-404
X
GCW 03/08/23
JLC 3/8/2023
3/9/23
Brett W. Huber,
Sr.
Digitally signed by Brett W.
Huber, Sr.
Date: 2023.03.09 10:16:34
-09'00'
RBDMS JSB 030923
KRU 1D-130
Well Work Justification & Objectives (and date required if appropriate):
1D-130 is coming due for a subsidence drift 3/10/23. The shallow tubing patch will need to be pulled to
complete the subsidence drift and reset once the drift is complete.
Risk/Job Concerns:
• Approved 10-403 from AOGCC required prior to pulling and reseting patch.
• Tubing patch set at 204' - 234' over tubing leak at 216'.
• 2019 Caliper reported other areas of tubing with 60% + isolated pitting and linned pitting.
• Patch packers have been set @ 238'/208', 235'/205', and 234'/204' RKB
Steps:
Relay or Slickline/Eline
1. Drift tubing down to top of patch at 204'.
2. Pull patch at 204'.
3. Drift dummy plug down to 2.25" D nipple at 4053' RKB.
1. If unable to drift, contact Well Integrity Specialist for path forward.
4. Brush and flush patch set area around 150'-250'.
5. Pump 20 bbls 100*F diesel down tubing to preheat.
6. Set lower 2.29" P2P at 229' (5' higher than previous) correlate with LDL run 7/2/2019.
7. Sting into P2P with test tool and perform CMIT TxIA to 2500 psi.
8. Run upper 2.29" P2P, spacer pipe, and anchor latch to sting into lower P2P.
1. Patch should be 30' from element to element placing the upper P2P mid element at 199'
(5' higher than previous).
9. Perform MITIA to 2500 psi. Record TIOs.
10. RDMO, turn well over to Operations to BOI.
11. Will require SW MITIA, notify DHD Field Supervisor.
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag: RKB 4,389.0 1D-130 2/1/2018 pproven
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Set Upper Section of Patch 1D-130 7/28/2022 zembaej
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 37.4 121.0 121.0 62.50 H-40 WELDED
SURFACE 7 5/8 6.87 37.4 2,529.3 2,239.7 29.70 L-80 ABM-BTC
PRODUCTION
5.5"x3.5"@4091'
5 1/2 4.95 37.1 4,768.1 4,247.2 15.50 L-80 BTC
Tubing Strings: string max indicates LONGEST segment of string
Top (ftKB)
41.4
Set Depth …
4,104.7
Set Depth …
3,585.8
String Ma…
2 7/8
Tubing Description
TUBING WO
Wt (lb/ft)
6.50
Grade
L-80
Top Connection
EUE8rdAB
MOD
ID (in)
2.44
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)
41.4 41.4 0.00 HANGER 6.000 Tubing Hanger T&C
Upset
2.441
519.4 519.4 0.36 NIPPLE 3.680 Camco "DS" Nipple 2.312" T&C
Upset
2.312
4,003.9 3,485.6 7.08 GAS LIFT 4.750 Camco Mandrel KBMG-M w/1" DCK-
2 SOV 1500 psi
CAMCO KBMG-
M
2.347
4,052.9 3,534.3 6.04 NIPPLE 3.680 Camco "D" Nipple 2.250" 2.250
4,091.7 3,572.8 5.78 SEAL ASSY 4.500 Baker 3-1/2" Locator Seal Assembly 3.000
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top (ftKB)
Top (TVD)
(ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in)
203.8 203.8 0.10 PACKER -
PATCH - UPR
UPPER 2.29" P2P (2400LB
RELEASE), SPACER PIPE, &
ANCHOR LATCH (30.5' OAL)
CPP2
87086
7/28/2022 1.375
207.0 207.0 0.10 ANCHOR
LATCH ON
SPACER
PIPE
2 1/16" P110 SPACER PIPE
AND ANCHOR LATCH
CPAL
28704
6
7/28/2022 1.375
216.0 216.0 0.11 LEAK -
TUBING
LEAK @216' 7/2/2019
233.9 233.9 0.14 PACKER -
PATCH - LWR
LOWER 2.29" P2P MID-
ELEMENT AT 236' RKB
(2400LB RELEASE) (3.55'
OAL)
CPP2
87046
7/27/2022 1.375
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)
4,003.9 3,485.6 7.08 1 Gas Lift DMY BK 1 0.0 6/23/2008 0.000
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
4,108.0 4,110.0 3,589.1 3,591.1 11/11/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,128.0 4,130.0 3,609.0 3,611.0 11/11/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,152.0 4,154.0 3,632.9 3,634.9 WS D, 1D-130 11/11/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,164.0 4,180.0 3,644.8 3,660.7 WS D, 1D-130 1/19/1998 4.0 IPERF 180° ph; 90° Orient; 2.5"HSD
4,192.0 4,194.0 3,672.7 3,674.7 WS C, 1D-130 11/11/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,207.0 4,241.0 3,687.6 3,721.5 WS B, 1D-130 1/19/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,210.0 4,212.0 3,690.6 3,692.6 WS B, 1D-130 11/11/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,212.0 4,241.0 3,692.6 3,721.5 WS B, 1D-130 1/19/1998 4.0 IPERF 180° ph, 2.5" HSD DP
4,246.0 4,248.0 3,726.5 3,728.5 WS A4, 1D-130 11/11/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,251.0 4,256.0 3,731.5 3,736.5 WS A4, 1D-130 1/19/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,256.0 4,276.0 3,736.5 3,756.4 WS A4, 1D-130 1/17/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,262.0 4,264.0 3,742.4 3,744.4 WS A4, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,278.0 4,280.0 3,758.4 3,760.4 WS A4, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,295.0 4,301.0 3,775.3 3,781.3 WS A3, 1D-130 1/17/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,298.0 4,300.0 3,778.3 3,780.3 WS A3, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,300.0 4,301.0 3,780.3 3,781.3 WS A3, 1D-130 1/17/1997 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,310.0 4,342.0 3,790.3 3,822.2 WS A3, 1D-130 1/17/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,354.0 4,356.0 3,834.1 3,836.1 WS A3, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,365.0 4,370.0 3,845.1 3,850.1 WS A2, 1D-130 1/17/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,380.0 4,420.0 3,860.0 3,899.9 WS A2, 1D-130 1/17/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,392.0 4,394.0 3,872.0 3,874.0 WS A2, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,402.0 4,404.0 3,882.0 3,884.0 WS A2, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,430.0 4,432.0 3,909.9 3,911.9 WS A2, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
1D-130, 2/9/2023 4:58:19 PM
Vertical schematic (actual)
PRODUCTION
5.5"x3.5"@4091'; 37.1-4,768.1
IPERF; 4,594.0-4,596.0
IPERF; 4,490.0-4,492.0
IPERF; 4,462.0-4,464.0
APERF; 4,440.0-4,452.0
IPERF; 4,430.0-4,432.0
IPERF; 4,402.0-4,404.0
IPERF; 4,380.0-4,420.0
IPERF; 4,392.0-4,394.0
IPERF; 4,365.0-4,370.0
IPERF; 4,354.0-4,356.0
IPERF; 4,310.0-4,342.0
IPERF; 4,300.0-4,301.0
IPERF; 4,298.0-4,300.0
IPERF; 4,295.0-4,301.0
IPERF; 4,278.0-4,280.0
IPERF; 4,256.0-4,276.0
IPERF; 4,262.0-4,264.0
IPERF; 4,251.0-4,256.0
IPERF; 4,246.0-4,248.0
IPERF; 4,212.0-4,241.0
IPERF; 4,207.0-4,241.0
IPERF; 4,210.0-4,212.0
IPERF; 4,192.0-4,194.0
IPERF; 4,164.0-4,180.0
IPERF; 4,152.0-4,154.0
IPERF; 4,128.0-4,130.0
IPERF; 4,108.0-4,110.0
GAS LIFT; 4,004.0
SURFACE; 37.4-2,529.3
NIPPLE; 519.4
PACKER - PATCH - LWR; 233.9
ANCHOR LATCH ON SPACER
PIPE; 207.0
LEAK - TUBING; 216.0
PACKER - PATCH - UPR; 203.8
CONDUCTOR; 37.4-121.0
KUP INJ
KB-Grd (ft) RR Date
11/8/1997
Other Elev…
1D-130
...
TD
Act Btm (ftKB)
4,778.0
Well Attributes
Field Name
WEST SAK
Wellbore API/UWI
500292281500
Wellbore Status
INJ
Max Angle & MD
Incl (°)
42.54
MD (ftKB)
2,896.15
WELLNAME WELLBORE1D-130
Annotation
Last WO:
End Date
6/16/2008
H2S (ppm) DateComment
SSSV: NIPPLE
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
4,440.0 4,452.0 3,919.9 3,931.8 WS A2, 1D-130 1/17/1998 4.0 APERF 180°ph; 90° Orient; 2.5"HSD
4,462.0 4,464.0 3,941.8 3,943.8 WS A2, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,490.0 4,492.0 3,969.7 3,971.7 WS A2, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,594.0 4,596.0 4,073.4 4,075.4 WS A1, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
1D-130, 2/9/2023 4:58:19 PM
Vertical schematic (actual)
PRODUCTION
5.5"x3.5"@4091'; 37.1-4,768.1
IPERF; 4,594.0-4,596.0
IPERF; 4,490.0-4,492.0
IPERF; 4,462.0-4,464.0
APERF; 4,440.0-4,452.0
IPERF; 4,430.0-4,432.0
IPERF; 4,402.0-4,404.0
IPERF; 4,380.0-4,420.0
IPERF; 4,392.0-4,394.0
IPERF; 4,365.0-4,370.0
IPERF; 4,354.0-4,356.0
IPERF; 4,310.0-4,342.0
IPERF; 4,300.0-4,301.0
IPERF; 4,298.0-4,300.0
IPERF; 4,295.0-4,301.0
IPERF; 4,278.0-4,280.0
IPERF; 4,256.0-4,276.0
IPERF; 4,262.0-4,264.0
IPERF; 4,251.0-4,256.0
IPERF; 4,246.0-4,248.0
IPERF; 4,212.0-4,241.0
IPERF; 4,207.0-4,241.0
IPERF; 4,210.0-4,212.0
IPERF; 4,192.0-4,194.0
IPERF; 4,164.0-4,180.0
IPERF; 4,152.0-4,154.0
IPERF; 4,128.0-4,130.0
IPERF; 4,108.0-4,110.0
GAS LIFT; 4,004.0
SURFACE; 37.4-2,529.3
NIPPLE; 519.4
PACKER - PATCH - LWR; 233.9
ANCHOR LATCH ON SPACER
PIPE; 207.0
LEAK - TUBING; 216.0
PACKER - PATCH - UPR; 203.8
CONDUCTOR; 37.4-121.0
KUP INJ 1D-130
...
WELLNAME WELLBORE1D-130
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Originated:Delivered to:6-Apr-21
Halliburton Alaska Oil and Gas Conservation Comm.
Wireline & Perforating Attn.: Natural Resource Technician
Attn: Fanny Haroun 333 West 7th Avenue, Suite 100
6900 Arctic Blvd.Anchorage, Alaska 99501
Anchorage, Alaska 99518
Office: 907-275-2605
FRS_ANC@halliburton.com
The technical data listed below is being submitted herewith. Please address any problems or
concerns to the attention of the sender above
WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL #
1 1A-23 50-029-22131-00 906975765 Kuparuk River Multi Finger Caliper Field & Processed 12-Feb-21 0 1
2 1B-11 50-029-20657-00 907041775 Kuparuk River Multi Finger Caliper Field & Processed 20-Mar-21 0 1
3 1D-101 50-029-22986-00 n/a West Sak Packer Setting Record Field- Final 14-Mar-21 0 1
4 1D-130 50-029-22815-00 907025874 West Sak Packer Setting Record Field- Final 13-Mar-21 0 1
5 1F-19 50-029-22660-00 906994361 Kuparuk River Packer Setting Record Field- Final 24-Feb-21 0 1
6 1G-02 50-029-20813-00 906996811 Kuparuk River Multi Finger Caliper Field & Processed 24-Feb-21 0 1
7 1L-11 50-029-22034-00 906914692 Kuparuk River Leak Detect Log Field- Final 15-Jan-21 0 1
8 1Q-10 50-029-21215-00 907035266 Kuparuk River Packer Setting Record Field- Final 18-Mar-21 0 1
9 2H-09 50-103-20050-00 907042522 Kuparuk River Packer Setting Record Field- Final 19-Mar-21 0 1
10 3H-21 50-103-20094-00 907045708 Kuparuk River Packer Setting Record Field- Final 22-Mar-21 0 1
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:
Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518
FRS_ANC@halliburton.com
Date:Signed:
Transmittal Date:
Received by the AOGCC 04/07/2021
PTD: 1971830
E-Set: 34904
04/07/2021
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Jim Regg �n� DATE: Wednesday, March 31, 2021
P.I. Supervisor ' l `]fl�4 "^�I SUBJECT: Mechanical Integrity Tests
111 ConocoPhillips Alaska, Inc.
ID -130
FROM: Brian Bixby KUPARUK RIV U WSAK ID -130
Petroleum Inspector
Src: Inspector
Reviewed By:
P.I. Supry
NON -CONFIDENTIAL Lamm
Well Name KUPARUK RIV U WSAK ID -130 API Well Number 50-029-22815-00-00
Inspector Name: Brian Bixby
Insp Num: mitBDB210328060121 Permit Number: 197-183-0
Inspection Date: 3/27/2021
Rel Insp Num:
Packer Depth
Pretest Initial
15 Min 30 Min 45 Min 60 Min
a13o
Type Inj W iVD ayes -Tubing
vso Sao
980 9so�-
P
92Ia3o
Type Test sPr Test psi ,oa IA
ao sw
use -
u4o
umped:
0.4 - BBL Returned: 04 - OA
120 - 220 -X160
wo -
Interval
��—.
OTHER P/F P
-
— _L-
Notes: Required per SUNDRY 321_184 Post Patch
Wednesday, March 31, 2021 Page I of I
1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown
Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program
Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Pull & reset tubing patch
ConocoPhillips Alaska, Inc.Development Exploratory
3. Address: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 4778 feet None feet
true vertical 4257 feet None feet
Effective Depth measured 4675 feet 4092 feet
true vertical 4154 feet 3573 feet
Perforation depth Measured depth 4108 - 4596 feet
True Vertical depth 3589 - 4075 feet
Tubing (size, grade, measured and true vertical depth)2.875 L-80 3586 3081
Packers and SSSV (type, measured and true vertical depth)Baker locater seal assem4092 / 3573 None None
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure:
13.
Prior to well operation:
Subsequent to operation:
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:
Contact Name:
Authorized Title:
Contact Email:
3/29/2021 Contact Phone:
321-084
Authorized Name:
Authorized Signature with date:
Senior Engineer:Senior Res. Engineer:
14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283
WINJ WAG
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Jan Byrne
n1617@conocophillips.com
659-7224
Well Integrity & Compliance Specialist
-----
-----
N/A
Representative Daily Average Production or Injection Data
Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure
Conductor 84 16 121 121
Production 4731 5.5 4768 4247
Surface 2492 7.625 2529 2240
Packer measured
true vertical
Casing Length Size MD TVD
N/A Kuparuk River Field / West Sak Oil Pool
Plugs measured
Junk measured
Burst Collapse
197-183
50029228150000'
ADL0025650 KRU 1D-130
P.O. Box 100630, Anchorage, Alaska 99508
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
2. Operator Name 4. Well Class Before Work:5. Permit to Drill Number:
t
Fra
O
197
6. A
G
L
PG
R
Form 10-404 Revised 3/2020 Submit Within 30 days of Operations
By Samantha Carlisle at 8:48 am, Mar 30, 2021
宇宬宪宬宷室宯宯宼季家宬宪宱宨宧季宥宼季宍室宱季宅宼宵宱宨
宇宑孽季宆宑宀宍室宱季宅宼宵宱宨孯季守宀宭室宱孱宥宼宵宱宨它宦宲宱宲宦宲害宫宬宯宯宬害家孱宦宲宰
宕宨室家宲宱孽季完季室宰季宷宫宨季室宸宷宫宲宵季宲宩季宷宫宬家季宧宲宦宸宰宨宱宷
宏宲宦室宷宬宲宱孽季宄宱宦宫宲宵室宪宨孯季宄宯室家宮室
宇室宷宨孽季孵孳孵孴孱孳孶孱孵孼季孴孳孽孷孺孽孶孳孰孳孻孪孳孳孪
安宲宻宬宷季宓宫室宱宷宲宰宓宇安季宙宨宵家宬宲宱孽季孴孳孱孴孱孳
Jan Byrne
SFD 4/1/2021DSR-4/1/21
RBDMS HEW 3/30/2021
VTL 5/5/21
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
March 29, 2021
Commissioner Jessie Chmielowski
Alaska Oil & Gas Commission
333 West 7th Avenue, Suite 100
Anchorage, AK 99501
Dear Commissioner Chmielowski,
Enclosed please find the 10-404 report for Sundry 321-084 well operations from
ConocoPhillips Alaska, Inc. for pulling and resetting a retrievable tubing patch to allow
access for a subsidence surveillance drift in well KRU 1D-130 (PTD 197-183).
Please contact us at 659-7244 if you have any questions.
Sincerely,
Jan Byrne
Well Integrity Specialist
ConocoPhillips Alaska, Inc.
宇宬宪宬宷室宯宯宼季家宬宪宱宨宧季宥宼季宍室宱季宅宼宵宱宨
宇宑孽季宆宑宀宍室宱季宅宼宵宱宨孯季
守宀宭室宱孱宥宼宵宱宨它宦宲宱宲宦宲害宫宬宯宯宬害家孱宦宲宰
宕宨室家宲宱孽季完季室宰季宷宫宨季室宸宷宫宲宵季宲宩季宷宫宬家季
宧宲宦宸宰宨宱宷
宏宲宦室宷宬宲宱孽季宄宱宦宫宲宵室宪宨孯季宄宯室家宮室
宇室宷宨孽季孵孳孵孴孱孳孶孱孵孼季孴孳孽孷孺孽孳孼孰孳孻孪孳孳孪
安宲宻宬宷季宓宫室宱宷宲宰宓宇安季宙宨宵家宬宲宱孽季孴孳孱孴孱孳
Jan
Byrne
Date Event Summary
Executive
Summary
Pulled and reset tubing patch to allow for subsidence surveillance drift as per sundry 321-084. Well
work copied below.
03/13/21
((DELAYED START DUE TO OPERATIONS)); ((SUBSIDENCE SURVEILLANCE)) PULLED 2.28" P2P PATCH ASSEMBLY
@ 208' RKB (ALL PARTS RECOVERED); DRIFT 2.25" DMY CA-2 PLUG W/ BRUSH WHILE PUMPING 100°F DIESEL
DOWN TO D-NIPPLE @ 4053' RKB (NO ANOMALIES) & BRUSH PATCH INTERVAL ON WAY OOH; SET 2.28"
LOWER P2P W/ MID ELEMENT @ 237' RKB (3.56' OAL / CPP287043); W/ TTS TEST TOOL IN LOWER P2P CMIT
TBG X IA TO 2500 PSI (PASS); SET UPPER 2.285" P2P, SPACER PIPE, & ANCHOR LATCH W/ MID ELEMENT @
206.98' (30.82' OAL / CPP287017 / CPAL287036); MITIA TO 2500 PSI (PASS). JOB COMPLETE.
PRE CMIT T/I/O= 900/875/120, PRESSURE UP (.75) T/I/O= 2500/2500/240, 15 MIN T/I/O= 2400/2400/150, 30
MIN T/I/O= 2375/2375/130
MIT IA WHILE RIGGING DOWN PRE T/I/O= 850/850/130, (.5 BBLS) TO PRESSURE UP T/I/O= 900/2525/240, 15
MIN T/I/O= 875/2425/150, 30 MIN T/I/O= 875/2420/145
Last Tag
Annotation Depth (ftKB) End Date Wellbore Last Mod By
Last Tag: RKB 4,389.0 2/1/2018 1D-130 pproven
Last Rev Reason
Annotation End Date Wellbore Last Mod By
Rev Reason: Replaced Tbg Patch 3/13/2021 1D-130 zembaej
Casing Strings
Casing Description
CONDUCTOR
OD (in)
16
ID (in)
15.06
Top (ftKB)
37.4
Set Depth (ftKB)
121.0
Set Depth (TVD) …
121.0
Wt/Len (l…
62.50
Grade
H-40
Top Thread
WELDED
Casing Description
SURFACE
OD (in)
7 5/8
ID (in)
6.87
Top (ftKB)
37.4
Set Depth (ftKB)
2,529.3
Set Depth (TVD) …
2,239.7
Wt/Len (l…
29.70
Grade
L-80
Top Thread
ABM-BTC
Casing Description
PRODUCTION
5.5"x3.5"@4091'
OD (in)
5 1/2
ID (in)
4.95
Top (ftKB)
37.1
Set Depth (ftKB)
4,768.1
Set Depth (TVD) …
4,247.2
Wt/Len (l…
15.50
Grade
L-80
Top Thread
BTC
Tubing Strings
Tubing Description
TUBING WO
String Ma…
2 7/8
ID (in)
2.44
Top (ftKB)
41.4
Set Depth (ft…
4,104.7
Set Depth (TVD) (…
3,585.8
Wt (lb/ft)
6.50
Grade
L-80
Top Connection
EUE8rdAB MOD
Completion Details
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des Com
Nominal
ID (in)
41.4 41.4 0.00 HANGER Tubing Hanger 2.441
519.4 519.4 0.36 NIPPLE Camco "DS" Nipple 2.312" 2.312
4,052.9 3,534.3 6.04 NIPPLE Camco "D" Nipple 2.250" 2.250
4,091.7 3,572.8 5.78 SEAL ASSY Baker 3-1/2" Locator Seal Assembly 3.000
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top
(ftKB)
Top
(TVD)
(ftKB)
Top Incl
(°) Des Com Run Date ID (in) SN
205.0 205.0 0.10 PACKER -
PATCH - UPR
UPPER 2.285" P2P (4800LB RELEASE),
SPACER PIPE, & ANCHOR LATCH (30.82'
OAL)
3/13/2021 1.380 CPP287017
209.0 209.0 0.11 SPACER PIPE &
ANCHOR LATCH
2 1/16" P110 SPACER PIPE AND ANCHOR
LATCH
3/13/2021 1.380 CPAL287036
216.0 216.0 0.11 LEAK - TUBING LEAK @216' 7/2/2019
235.0 235.0 0.14 PACKER -
PATCH - LWR
LOWER 2.285" P2P (4800LB RELEASE) (4'
OAL)
3/13/2021 1.380 CPP287043
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft
)Type Com
4,108.0 4,110.0 3,589.1 3,591.1 11/11/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,128.0 4,130.0 3,609.0 3,611.0 11/11/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,152.0 4,154.0 3,632.9 3,634.9 WS D, 1D-130 11/11/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,164.0 4,180.0 3,644.8 3,660.7 WS D, 1D-130 1/19/1998 4.0 IPERF 180° ph; 90° Orient;
2.5"HSD
4,192.0 4,194.0 3,672.7 3,674.7 WS C, 1D-130 11/11/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,207.0 4,241.0 3,687.6 3,721.5 WS B, 1D-130 1/19/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,210.0 4,212.0 3,690.6 3,692.6 WS B, 1D-130 11/11/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,212.0 4,241.0 3,692.6 3,721.5 WS B, 1D-130 1/19/1998 4.0 IPERF 180° ph, 2.5" HSD DP
4,246.0 4,248.0 3,726.5 3,728.5 WS A4, 1D-130 11/11/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,251.0 4,256.0 3,731.5 3,736.5 WS A4, 1D-130 1/19/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,256.0 4,276.0 3,736.5 3,756.4 WS A4, 1D-130 1/17/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,262.0 4,264.0 3,742.4 3,744.4 WS A4, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,278.0 4,280.0 3,758.4 3,760.4 WS A4, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,295.0 4,301.0 3,775.3 3,781.3 WS A3, 1D-130 1/17/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,298.0 4,300.0 3,778.3 3,780.3 WS A3, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,300.0 4,301.0 3,780.3 3,781.3 WS A3, 1D-130 1/17/1997 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,310.0 4,342.0 3,790.3 3,822.2 WS A3, 1D-130 1/17/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,354.0 4,356.0 3,834.1 3,836.1 WS A3, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,365.0 4,370.0 3,845.1 3,850.1 WS A2, 1D-130 1/17/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,380.0 4,420.0 3,860.0 3,899.9 WS A2, 1D-130 1/17/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,392.0 4,394.0 3,872.0 3,874.0 WS A2, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,402.0 4,404.0 3,882.0 3,884.0 WS A2, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,430.0 4,432.0 3,909.9 3,911.9 WS A2, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,440.0 4,452.0 3,919.9 3,931.8 WS A2, 1D-130 1/17/1998 4.0 APERF 180°ph; 90° Orient; 2.5"HSD
4,462.0 4,464.0 3,941.8 3,943.8 WS A2, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,490.0 4,492.0 3,969.7 3,971.7 WS A2, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
4,594.0 4,596.0 4,073.4 4,075.4 WS A1, 1D-130 11/10/1997 4.0 IPERF 180° ph, 2.5" HSD DP
Mandrel Inserts
St
ati
on
N
o/Top (ftKB)
Top (TVD)
(ftKB) Make Model OD (in) Serv
Valve
Type
Latch
Type
Port Size
(in)
TRO Run
(psi) Run Date Com
1 4,003.9 3,485.6 CAMCO KBMG-
M
1 Gas Lift DMY BK 0.000 0.0 6/23/2008
1D-130, 3/14/2021 6:45:28 PM
Vertical schematic (actual)
PRODUCTION
5.5"x3.5"@4091'; 37.1-4,768.1
IPERF; 4,594.0-4,596.0
IPERF; 4,490.0-4,492.0
IPERF; 4,462.0-4,464.0
APERF; 4,440.0-4,452.0
IPERF; 4,430.0-4,432.0
IPERF; 4,402.0-4,404.0
IPERF; 4,380.0-4,420.0
IPERF; 4,392.0-4,394.0
IPERF; 4,365.0-4,370.0
IPERF; 4,354.0-4,356.0
IPERF; 4,310.0-4,342.0
IPERF; 4,300.0-4,301.0
IPERF; 4,298.0-4,300.0
IPERF; 4,295.0-4,301.0
IPERF; 4,278.0-4,280.0
IPERF; 4,256.0-4,276.0
IPERF; 4,262.0-4,264.0
IPERF; 4,251.0-4,256.0
IPERF; 4,246.0-4,248.0
IPERF; 4,212.0-4,241.0
IPERF; 4,207.0-4,241.0
IPERF; 4,210.0-4,212.0
IPERF; 4,192.0-4,194.0
IPERF; 4,164.0-4,180.0
IPERF; 4,152.0-4,154.0
IPERF; 4,128.0-4,130.0
IPERF; 4,108.0-4,110.0
SEAL ASSY; 4,091.7
NIPPLE; 4,052.9
GAS LIFT; 4,004.0
SURFACE; 37.4-2,529.3
NIPPLE; 519.4
PACKER - PATCH - LWR; 235.0
SPACER PIPE & ANCHOR
LATCH; 209.0
LEAK - TUBING; 216.0
PACKER - PATCH - UPR; 205.0
CONDUCTOR; 37.4-121.0
HANGER; 41.4
KUP INJ
KB-Grd (ft) Rig Release Date
11/8/1997
1D-130
...
TD
Act Btm (ftKB)
4,778.0
Well Attributes
Field Name
WEST SAK
Wellbore API/UWI
500292281500
Wellbore Status
INJ
Max Angle & MD
Incl (°)
42.54
MD (ftKB)
2,896.15
WELLNAME WELLBORE1D-130
Annotation
Last WO:
End Date
6/16/2008
H2S (ppm) DateComment
SSSV: NIPPLE
Submit to:
OOPERATOR:
FIELD /UNIT /PA D:
DATE:
OPERATOR REP:
AOGCC REP:
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD 1971830 Type Inj W Tubing 980 980 980 980 Type Test P
Packer TVD 3573 BBL Pump 0.4 IA 280 1810 1750 1740 Interval O
Test psi 1500 BBL Return 0.4 OA 120 220 160 140 Result P
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD 2001830 Type Inj W Tubing 514 518 514 514 Type Test P
Packer TVD 3626 BBL Pump 0.2 IA 1260 1810 1790 1780 Interval O
Test psi 1500 BBL Return 0.2 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
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
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
MMec h an i c al Int egr i t y Tes t
jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov
Notes:MITIA post patch pull and set per Sundry # 321-084
Notes:
1D-130
1D-101
Notes:MITIA post patch pull and reset per Sundry # 321-104 ***Single casing well***
Notes:
Notes:
ConocoPhillips Alaska Inc,
Kuparuk / KRU / 1D Pad
Brian Bixby
Hembree / VanCamp
03/27/21
Form 10-426 (Revised 01/2017)MIT KRU 1D-130 & 1D-101 03-27-21.xlsx
1.Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown
Suspend Perforate Other Stimulate Pull Tubing Change Approved Program
Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Pull and reset patch
2.Operator Name:4.Current Well Class:5.Permit to Drill Number:
Exploratory Development
3.Address: Stratigraphic Service 6.API Number:
7.If perforating:8.Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool?N/A
Will planned perforations require a spacing exception?Yes No
9.Property Designation (Lease Number):10. Field/Pool(s):
11.
Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD):
4778 NA None
Casing Collapse
Conductor NA
Surface NA
Production NA
Packers and SSSV Type:PKR:Packers and SSSV MD (ft) and TVD (ft):PKR:
SSSV:SSSV:
12. Attachments:Proposal Summary Wellbore schematic 13.Well Class after proposed work:
Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service
14.Estimated Date for 15.Well Status after proposed work:
Commencing Operations:OIL WINJ WDSPL Suspended
16.Verbal Approval:Date:GAS WAG GSTOR SPLUG
Commission Representative: GINJ Op Shutdown Abandoned
Contact Name:
Contact Email:
Contact Phone:
Date:2/16/2021
Conditions of approval: Notify Commission so that a representative may witness Sundry Number:
Plug Integrity BOP Test Mechanical Integrity Test Location Clearance
Other:
Post Initial Injection MIT Req'd? Yes No
Spacing Exception Required? Yes No Subsequent Form Required:
APPROVED BY
Approved by: COMMISSIONER THE COMMISSION Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
659-7224
Baker locater seal assembly
None
4092 / 3573
None
Size
Authorized Signature:
3/1/2021
2.875
Perforation Depth MD (ft):
L-80
COMMISSION USE ONLY
Authorized Name:
Tubing Grade:Tubing MD (ft):
3589 - 4075
Perforation Depth TVD (ft):Tubing Size:
4108 - 4596
Authorized Title:
17.I hereby certify that the foregoing is true and the procedure approved herein will not
be deviated from without prior written approval.
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL0025650
197-183
P.O. Box 100630, Anchorage, Alaska 99508 50029228150000'
ConocoPhillips Alaska, Inc.
KRU 1D-130
Kuparuk River Field / West Sak Oil Pool
4257 4675
PRESENT WELL CONDITION SUMMARY
4154 None
Length TVD Burst
3586
MD
NA
NA
NA
2240
4247
2529
4731
121 121
4768
84 16
7.625
5.5
2492
Well Integrity & Compliance Specialist
Jan Byrne / Dusty Freeborn
n1617@conocophillips.com
m
n
P
66
t
Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval.
By Samantha Carlisle at 8:56 am, Feb 16, 2021
321-084
宇宬宪宬宷室宯宯宼季家宬宪宱宨宧季宥宼季宍室宱季宅宼宵宱宨
宇宑孽季宆宑宀宍室宱季宅宼宵宱宨孯季守宀宭室宱孱宥宼宵宱宨它宦宲宱宲宦宲害宫宬宯宯宬害家孱宦宲宰
宕宨室家宲宱孽季完季室宰季宷宫宨季室宸宷宫宲宵季宲宩季宷宫宬家季宧宲宦宸宰宨宱宷
宏宲宦室宷宬宲宱孽季宄宱宦宫宲宵室宪宨孯季宄宯室家宮室
宇室宷宨孽季孵孳孵孴孱孳孵孱孴孹季孳孺孽孶孺孽孷孷孰孳孼孪孳孳孪
安宲宻宬宷季宓宫室宱宷宲宰宓宇安季宙宨宵家宬宲宱孽季孴孳孱孴孱孳
Jan Byrne
X
DSR-2/16/21
X 10-404
VTL 2/24/21
50-029-22815-00-00
X
DLB 02/16/2021Comm
2/24/21
dts 2/24/2021
JLC 2/24/2021
RBDMS HEW 2/25/2021
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
February 15, 2021
Commissioner Jessie Chmielowski
Alaska Oil & Gas Commission
333 West 7th Avenue, Suite 100
Anchorage, AK 99501
Dear Commissioner Chmielowski,
Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips
Alaska, Inc. well KRU 1D-130 (PTD 197-183) to pull and reset a retrievable tubing patch
to allow for a compliance drift.
Please contact us at 659-7244 if you have any questions.
Sincerely,
Jan Byrne
Well Integrity Specialist
ConocoPhillips Alaska, Inc.
宇宬宪宬宷室宯宯宼季家宬宪宱宨宧季宥宼季宍室宱季宅宼宵宱宨
宇宑孽季宆宑宀宍室宱季宅宼宵宱宨孯季
守宀宭室宱孱宥宼宵宱宨它宦宲宱宲宦宲害宫宬宯宯宬害家孱宦宲宰
宕宨室家宲宱孽季完季室宰季宷宫宨季室宸宷宫宲宵季宲宩季宷宫宬家季
宧宲宦宸宰宨宱宷
宏宲宦室宷宬宲宱孽季宄宱宦宫宲宵室宪宨孯季宄宯室家宮室
宇室宷宨孽季孵孳孵孴孱孳孵孱孴孹季孳孺孽孶孺孽孴孹孰孳孼孪孳孳孪
安宲宻宬宷季宓宫室宱宷宲宰宓宇安季宙宨宵家宬宲宱孽季孴孳孱孴孱孳
Jan
Byrne
Well Work Justification & Objectives (and date required if appropriate):
1D-130 is coming due for a subsidence compliance drift 3/10/21. The shallow tubing patch will need
to be pulled to complete the subsidence compliance drift and reset once the drift is complete.
Risk/Job Concerns:
• Approved 10-403 from AOGCC required prior to pulling and reseting patch.
• Tubing patch set at 208' - 238' over tubing leak at 216'.
• 2019 Caliper reported other areas of tubing with 60% + isolated pitting and linned pitting.
Steps:
Relay or Slickline/Eline
1. Drift tubing down to top of patch at 208'.
2. Pull patch at 208'.
3. Drift dummy plug down to 2.25" D nipple at 4053’.
4. Brush and flush patch set area around 200'-250'.
5. Set lower 2.29" P2P at 237' (one foot higher than previous) correlate with LDL run 7/2/2019.
6. Sting into P2P with test tool and perform CMIT TxIA to 2500 psi.
7. Run upper 2.29" P2P, spacer pipe, and anchor latch to sting into lower P2P.
- Patch should be 30' from element to element placing the upper P2P mid element at 207' (one
foot higher than previous).
8. Perform MITIA to 2500 psi. Record TIOs.
9. RDMO, turn well over to Operations to BOI.
10. Will require SW MITIA, notify DHD Field Supervisor.
Will require SW MITIA, notify DHD Field Supervisor.
24 hour notice to AOGCC Inspector to witness MIT-IA
Last Tag
Annotation Depth (ftKB) End Date Wellbore Last Mod By
Last Tag: RKB 4,389.0 2/1/2018 1D-130 pproven
Last Rev Reason
Annotation End Date Wellbore Last Mod By
Rev Reason: Added LEAKS & ENHANCED PATCHES 7/3/2020 1D-130 pproven
Casing Strings
Casing Description
CONDUCTOR
OD (in)
16
ID (in)
15.06
Top (ftKB)
37.4
Set Depth (ftKB)
121.0
Set Depth (TVD) …
121.0
Wt/Len (l…
62.50
Grade
H-40
Top Thread
WELDED
Casing Description
SURFACE
OD (in)
7 5/8
ID (in)
6.87
Top (ftKB)
37.4
Set Depth (ftKB)
2,529.3
Set Depth (TVD) …
2,239.7
Wt/Len (l…
29.70
Grade
L-80
Top Thread
ABM-BTC
Casing Description
PRODUCTION
5.5"x3.5"@4091'
OD (in)
5 1/2
ID (in)
4.95
Top (ftKB)
37.1
Set Depth (ftKB)
4,768.1
Set Depth (TVD) …
4,247.2
Wt/Len (l…
15.50
Grade
L-80
Top Thread
BTC
Tubing Strings
Tubing Description
TUBING WO
String Ma…
2 7/8
ID (in)
2.44
Top (ftKB)
41.4
Set Depth (ft…
4,104.7
Set Depth (TVD) (…
3,585.8
Wt (lb/ft)
6.50
Grade
L-80
Top Connection
EUE8rdAB MOD
Completion Details
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des Com
Nominal
ID (in)
41.4 41.4 0.00 HANGER Tubing Hanger 2.441
519.4 519.4 0.36 NIPPLE Camco "DS" Nipple 2.312" 2.312
4,052.9 3,534.3 6.04 NIPPLE Camco "D" Nipple 2.250" 2.250
4,091.7 3,572.8 5.78 SEAL ASSY Baker 3-1/2" Locator Seal Assembly 3.000
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top
(ftKB)
Top
(TVD)
(ftKB)
Top Incl
(°) Des Com Run Date ID (in) SN
208.0 208.0 0.10 PACKER -
PATCH - UPR
2.285 P2P, OAL 4' MAX OD 2.285" 3/10/2020 1.375 CPP287058
212.0 212.0 0.11 SPACER,
ANCHOR LATCH
ASSY
2 1/16" P110 SPACER PIPE (26' OF
SPACER PIPE AND ANCHOR LATCH)
3/10/2020 1.370 CPAL287030
216.0 216.0 0.11 LEAK - TUBING LEAK FOUND AROUND 216'. PERFORM
STATIONS OVER LEAK.
7/2/2019
238.0 238.0 0.14 PACKER -
PATCH - LWR
2.285 P2P, OAL 4' MAX OD 2.285" 3/10/2020 1.375 CPP287059
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft
)Type Com
4,108.0 4,110.0 3,589.1 3,591.1 11/11/1997 4.0 IPERF 180 deg ph, 2.5" HSD DP
4,128.0 4,130.0 3,609.0 3,611.0 11/11/1997 4.0 IPERF 180 deg ph, 2.5" HSD DP
4,152.0 4,154.0 3,632.9 3,634.9 WS D, 1D-130 11/11/1997 4.0 IPERF 180 deg ph, 2.5" HSD DP
4,164.0 4,180.0 3,644.8 3,660.7 WS D, 1D-130 1/19/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,192.0 4,194.0 3,672.7 3,674.7 WS C, 1D-130 11/11/1997 4.0 IPERF 180 deg ph, 2.5" HSD DP
4,207.0 4,241.0 3,687.6 3,721.5 WS B, 1D-130 1/19/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,210.0 4,212.0 3,690.6 3,692.6 WS B, 1D-130 11/11/1997 4.0 IPERF 180 deg ph, 2.5" HSD DP
4,212.0 4,241.0 3,692.6 3,721.5 WS B, 1D-130 1/19/1998 4.0 IPERF 180 deg ph, 2.5" HSD DP
4,246.0 4,248.0 3,726.5 3,728.5 WS A4, 1D-130 11/11/1997 4.0 IPERF 180 deg ph, 2.5" HSD DP
4,251.0 4,256.0 3,731.5 3,736.5 WS A4, 1D-130 1/19/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,256.0 4,276.0 3,736.5 3,756.4 WS A4, 1D-130 1/17/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,262.0 4,264.0 3,742.4 3,744.4 WS A4, 1D-130 11/10/1997 4.0 IPERF 180 deg ph, 2.5" HSD DP
4,278.0 4,280.0 3,758.4 3,760.4 WS A4, 1D-130 11/10/1997 4.0 IPERF 180 deg ph, 2.5" HSD DP
4,295.0 4,301.0 3,775.3 3,781.3 WS A3, 1D-130 1/17/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,298.0 4,300.0 3,778.3 3,780.3 WS A3, 1D-130 11/10/1997 4.0 IPERF 180 deg ph, 2.5" HSD DP
4,300.0 4,301.0 3,780.3 3,781.3 WS A3, 1D-130 1/17/1997 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,310.0 4,342.0 3,790.3 3,822.2 WS A3, 1D-130 1/17/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,354.0 4,356.0 3,834.1 3,836.1 WS A3, 1D-130 11/10/1997 4.0 IPERF 180 deg ph, 2.5" HSD DP
4,365.0 4,370.0 3,845.1 3,850.1 WS A2, 1D-130 1/17/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,380.0 4,420.0 3,860.0 3,899.9 WS A2, 1D-130 1/17/1998 4.0 IPERF 180°ph; 90° Orient; 2.5"HSD
4,392.0 4,394.0 3,872.0 3,874.0 WS A2, 1D-130 11/10/1997 4.0 IPERF 180 deg ph, 2.5" HSD DP
4,402.0 4,404.0 3,882.0 3,884.0 WS A2, 1D-130 11/10/1997 4.0 IPERF 180 deg ph, 2.5" HSD DP
4,430.0 4,432.0 3,909.9 3,911.9 WS A2, 1D-130 11/10/1997 4.0 IPERF 180 deg ph, 2.5" HSD DP
4,440.0 4,452.0 3,919.9 3,931.8 WS A2, 1D-130 1/17/1998 4.0 APERF 180°ph; 90° Orient; 2.5"HSD
4,462.0 4,464.0 3,941.8 3,943.8 WS A2, 1D-130 11/10/1997 4.0 IPERF 180 deg ph, 2.5" HSD DP
4,490.0 4,492.0 3,969.7 3,971.7 WS A2, 1D-130 11/10/1997 4.0 IPERF 180 deg ph, 2.5" HSD DP
4,594.0 4,596.0 4,073.4 4,075.4 WS A1, 1D-130 11/10/1997 4.0 IPERF 180 deg ph, 2.5" HSD DP
Mandrel Inserts
St
ati
on
N
o/Top (ftKB)
Top (TVD)
(ftKB) Make Model OD (in) Serv
Valve
Type
Latch
Type
Port Size
(in)
TRO Run
(psi) Run Date Com
1 4,003.9 3,485.6 CAMCO KBMG-
M
1 Gas Lift DMY BK 0.000 0.0 6/23/2008
1D-130, 7/3/2020 1:56:11 AM
Vertical schematic (actual)
PRODUCTION
5.5"x3.5"@4091'; 37.1-4,768.1
IPERF; 4,594.0-4,596.0
IPERF; 4,490.0-4,492.0
IPERF; 4,462.0-4,464.0
APERF; 4,440.0-4,452.0
IPERF; 4,430.0-4,432.0
IPERF; 4,402.0-4,404.0
IPERF; 4,380.0-4,420.0
IPERF; 4,392.0-4,394.0
IPERF; 4,365.0-4,370.0
IPERF; 4,354.0-4,356.0
IPERF; 4,310.0-4,342.0
IPERF; 4,300.0-4,301.0
IPERF; 4,298.0-4,300.0
IPERF; 4,295.0-4,301.0
IPERF; 4,278.0-4,280.0
IPERF; 4,256.0-4,276.0
IPERF; 4,262.0-4,264.0
IPERF; 4,251.0-4,256.0
IPERF; 4,246.0-4,248.0
IPERF; 4,212.0-4,241.0
IPERF; 4,207.0-4,241.0
IPERF; 4,210.0-4,212.0
IPERF; 4,192.0-4,194.0
IPERF; 4,164.0-4,180.0
IPERF; 4,152.0-4,154.0
IPERF; 4,128.0-4,130.0
IPERF; 4,108.0-4,110.0
GAS LIFT; 4,004.0
SURFACE; 37.4-2,529.3
NIPPLE; 519.4
PACKER - PATCH - LWR; 238.0
SPACER, ANCHOR LATCH
ASSY; 212.0
LEAK - TUBING; 216.0
PACKER - PATCH - UPR; 208.0
CONDUCTOR; 37.4-121.0
KUP INJ
KB-Grd (ft) Rig Release Date
11/8/1997
1D-130
...
TD
Act Btm (ftKB)
4,778.0
Well Attributes
Field Name
WEST SAK
Wellbore API/UWI
500292281500
Wellbore Status
INJ
Max Angle & MD
Incl (°)
42.54
MD (ftKB)
2,896.15
WELLNAME WELLBORE1D-130
Annotation
Last WO:
End Date
6/16/2008
H2S (ppm) DateComment
SSSV: NIPPLE
MEMORANDUM
TO: Jim Regg J �- 4jZ�jZ61Z<>
P.I. Supervisor
FROM: Guy Cook
Petroleum Inspector
NON -CONFIDENTIAL
State of Alaska
Alaska Oil and Gas Conservation Commission
DATE: Monday, April 20, 2020
SUBJECT: Mechanical Integrity Tests
ConocoPlullips Alaska, Inc.
ID -130
KUPARUK RIV U WSAK ID -130
See: Inspector
Reviewed By:
�'
P.I. Supry -
Comm
Well Name KUPARUK RIV U WSAK ID -130 API Well Number 50-029-22815-00-00 Inspector Name: Guy Cook
Insp Num: mitGDC200419174317 Permit Number: 197-183-0 Inspection Date: 4/1912020
Rel Insp Num:
Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min
Well 1x130 Type Ini JW 3565 - Tubing s3o 840 - 520 830
PTD 1971830 • Type Test I SPT Test psi 1500 - IA 1410 2110 - 2070 - 2065
BBL Pumped: 0.3 - BBL Returned: 03 OA iso iso - 180• lax
Interval oTliElt P/F I P
Notes: MIT -IA post patch per Sundry 320-030. The job was done with a Little Red Services pump truck and calibrated gauges.
Monday, April 20, 2020 Page I of I
Originated:
Halliburton
Wireline & Perforating
Attn: Fanny Sari
6900 Arctic Blvd.
Anchorage, Alaska 99518
Office: 907-275-2605
FRS—ANC@halliburton.com
Delivered to:
Alaska Oil and Gas Conservation Comm.
Attn.: Natural Resource Technician
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
The technical data listed below is being submitted herewith. Please address any problems or
concerns to the attention of the sender above
Transmittal Date:
RECEIVED
APR 2 3 2020
AOGCC
19'x183
32793
13 -Mar -20
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:
Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518
FRS _ANC@ha Iliburton.com
Date:tl
Signed:
NAME
API #
SERVICE ORDER #
FIELD NAME
JOB TYPE
DATA TYPE
LOGGING DATE
PRINTS #
CD #
V27
50-103-20178-00
50-029-20429-00
50-029-20590-00
50-029-20711-00
50-029-22102-00
906173399
906174414
906236618
906270889
906333945
906221237
Kuparuk
Kuparuk
Kuparuk
Kuparuk
Kuparuk
Kuparuk
Plug Setting Record
Packer Setting Record
Packer Setting Record
Packer Setting Record
Packer Setting Record
Packer Setting Record
Final -Field
Final -Field
Final -Field
Final -Field
Final -Field
Final -Field
14 -Dec -19
16 -Dec -19
24 -Jan -20
26 -Jan -20
21 -Feb -2050-029-20595-00
4 -Jan -20
0
0
0
0
08
1
1
1
1
-Jan -20
0
50-029-22815-00
50-029-22816-00
906340407
906236619
West Sak
West Sak
Packer Setting Record
Packer Setting Record
Final -Field
Final -Field
10 -Mar -20
14 -Jan -20
05
0
1
15 -tan -20
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:
Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518
FRS _ANC@ha Iliburton.com
Date:tl
Signed:
1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown
Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program
Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Tubing patch
ConcoPhillips Alaska, Inc.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 4778 feet feet
true vertical 4257 feet feet
Effective Depth measured 4333 feet 4092 feet
true vertical 3699 feet 3573 feet
Perforation depth Measured depth 4108 - 4596 feet
True Vertical depth 3589 - 4075 feet
Tubing (size, grade, measured and true vertical depth)3.5 L-80 4105 3586
Packers and SSSV (type, measured and true vertical depth)Baker 3.5 Locator Seal Assembly 4092 3573
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure:
13.
Prior to well operation:
Subsequent to operation:
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:
Contact Name: Jan Byrne / Dusty Freeborn
Authorized Title: Well Integrity Compliance Specialist
Contact Email:N1617@conocophillips.com
Contact Phone:907-659-7224
WINJ WAG
Water-Bbl
MD
121
2529
TVD
Oil-Bbl
measured
true vertical
Packer
5.5x3.5 4768
P. O. Box 100360, Anchorage, Alaska 995103. Address:
4. Well Class Before Work:
Representative Daily Average Production or Injection Data
Casing Pressure Tubing Pressure
KRU 1D-130
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
197-183
500292281500
Plugs
Junk measured
ADL0025650
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
320-030
Size
14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283)
Gas-Mcf
Authorized Signature with date:
Authorized Name: Jan Byrne
Liner
5. Permit to Drill Number:
Kuparuk River Field / West Sak Oil Pool
measured
4731
Conductor
Surface
Intermediate
Production
Casing
Structural
16
7.625
Length
84
2492
Burst
2. Operator Name
Senior Engineer:Senior Res. Engineer:
Collapse
t
Fra
O
6. A
G
L
PG
,
R
h
Form 10-404 Revised 3/2020 Submit Within 30 days of Operations
Digitally signed by jan.byrne@conocophillips.com
DN: CN=jan.byrne@conocophillips.com
Reason: I am the author of this document
Location: Working remotely from home
Date: 2020-04-20 20:10:05
Foxit PhantomPDF Version: 9.7.0
jan.byrne@conocophilli
ps.com
By Samantha Carlisle at 8:12 am, Apr 21, 2020
DSR-4/21/2020
RBDMS HEW 4/21/2020
SFD 4/23/2020VTL 4/28/20
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
April 20, 2020
Commissioner Jessie Chmielowski
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, AK 99501
Commissioner Chmielowski,
Enclosed please find the 10-404 Report for Sundry (320-030) Well Operations for
ConocoPhillips Alaska, Inc. well KRU 1D-130 (PTD 197-183) for tubing patch installation.
Please contact Dusty Freeborn or me at 659-7224 if you have any questions.
Sincerely,
Jan Byrne
Well Integrity & Compliance Specialist
ConocoPhillips Alaska, Inc.
Digitally signed by jan.byrne@conocophillips.com
DN: CN=jan.byrne@conocophillips.com
Reason: I am the author of this document
Location: Working remotely from home
Date: 2020-04-20 20:09:26
Foxit PhantomPDF Version: 9.7.0
jan.byrne@con
ocophillips.com
Submit to:
OOPERATOR:
FIELD /UNIT /PA D:
DATE:
OPERATOR REP:
AOGCC REP:
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD 1971830 Type Inj W Tubing 830 840 820 830 Type Test P
Packer TVD 3573 BBL Pump 0.3 IA 1410 2110 2070 2065 Interval O
Test psi 1500 BBL Return 0.3 OA 150 180 180 180 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
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
MMec h an i c al Int egr i t y Tes t
jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov
Notes:MITIA post patch per Sundry # 320-030
Notes:
1D-130
Notes:
Notes:
Notes:
ConocoPhillips Alaska Inc,
Kuparuk / KRU / 1D Pad
Guy Cook
Hembree / Miller
04/19/20
Form 10-426 (Revised 01/2017)MIT KRU 1D-130 04-19-20.xlsx
Last Tag
Annotation Depth (ftKB) End Date Last Mod By Wellbore
Last Tag: RKB 4,389.0 2/1/2018 pproven 1D-130
Last Rev Reason
Annotation End Date Last Mod By Wellbore
Rev Reason: Pull CA-2, set patch 3/10/2020 famaj 1D-130
Casing Strings
Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB)
Set Depth (TVD)
(ftKB)
Wt/Len
(lb/ft) Grade Top Thread Wellbore
CONDUCTOR 16 15.06 37.4 121.0 121.0 62.50 H-40 WELDED 1D-130
SURFACE 7 5/8 6.87 37.4 2,529.3 2,239.7 29.70 L-80 ABM-BTC 1D-130
PRODUCTION
5.5"x3.5"@4091'
5 1/2 4.95 37.1 4,768.1 4,247.2 15.50 L-80 BTC 1D-130
Tubing Strings
Des
String
Max
Nominal
OD (in)ID (in) Top (ftKB)
Set Depth
(ftKB)
Set Depth (TVD)
(ftKB) Wt (lb/ft) Grade Top Thread Wellbore
TUBING WO 2 7/8 2.44 41.4 4,104.7 3,585.8 6.50 L-80 EUE8rdAB
MOD
1D-130
Completion Details
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des Com
Nominal
ID (in) Wellbore
41.4 41.4 0.00 HANGER Tubing Hanger 2.441 1D-130
519.4 519.4 0.36 NIPPLE Camco "DS" Nipple 2.312" 2.312 1D-130
4,052.9 3,534.3 6.04 NIPPLE Camco "D" Nipple 2.250" 2.250 1D-130
4,091.7 3,572.8 5.78 SEAL ASSY Baker 3-1/2" Locator Seal Assembly 3.000 1D-130
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top (ftKB)
Top (TVD)
(ftKB) Top Incl (°) Des Com Run Date ID (in) Wellbore
208.0 208.0 0.10 Patch PKR 2.285" P2P (CPP287058) W/ 26' OF
SPACER PIPE AND ANCHOR LATCH
(CPAL287030) OAL 30' MAX OD 2.285"
3/10/2020 1.375 1D-130
212.0 212.0 0.11 Spacer Pipe 2 1/16" P110 SPACER PIPE 3/10/2020 1.370 1D-130
238.0 238.0 0.14 Patch PKR 2.285 P2P (CPP287059) OAL 4' MAX OD
2.285"
3/10/2020 1.375 1D-130
Liner Details
Top (ftKB)
Top (TVD)
(ftKB) Top Incl (°) Item Des Com
Nominal ID
(in) Wellbore
37.1 37.1 0.00 HANGER 4.950 1D-130
37.4 37.4 0.00 HANGER 6.875 1D-130
37.4 37.4 0.00 CONDUCTOR 15.062 1D-130
1,688.6 1,598.0 39.29 CEMENTER 6.875 1D-130
4,091.8 3,572.9 5.78 PBR 4.000 1D-130
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft
)Type Com Wellbore
4,108.0 4,110.0 3,589.1 3,591.1 11/11/1997 4.0 IPERF 180 deg ph, 2.5" HSD DP 1D-130
4,128.0 4,130.0 3,609.0 3,611.0 11/11/1997 4.0 IPERF 180 deg ph, 2.5" HSD DP 1D-130
4,152.0 4,154.0 3,632.9 3,634.9 WS D, 1D-130 11/11/1997 4.0 IPERF 180 deg ph, 2.5" HSD DP 1D-130
4,164.0 4,180.0 3,644.8 3,660.7 WS D, 1D-130 1/19/1998 4.0 IPERF 180 deg ph; 90 deg Orient;
2.5"HSD
1D-130
4,192.0 4,194.0 3,672.7 3,674.7 WS C, 1D-130 11/11/1997 4.0 IPERF 180 deg ph, 2.5" HSD DP 1D-130
4,207.0 4,241.0 3,687.6 3,721.5 WS B, 1D-130 1/19/1998 4.0 IPERF 180 deg ph; 90 deg Orient;
2.5"HSD
1D-130
4,210.0 4,212.0 3,690.6 3,692.6 WS B, 1D-130 11/11/1997 4.0 IPERF 180 deg ph, 2.5" HSD DP 1D-130
4,212.0 4,241.0 3,692.6 3,721.5 WS B, 1D-130 1/19/1998 4.0 IPERF 180 deg ph, 2.5" HSD DP 1D-130
4,246.0 4,248.0 3,726.5 3,728.5 WS A4, 1D-130 11/11/1997 4.0 IPERF 180 deg ph, 2.5" HSD DP 1D-130
4,251.0 4,256.0 3,731.5 3,736.5 WS A4, 1D-130 1/19/1998 4.0 IPERF 180 deg ph; 90 deg Orient;
2.5"HSD
1D-130
4,256.0 4,276.0 3,736.5 3,756.4 WS A4, 1D-130 1/17/1998 4.0 IPERF 180 deg ph; 90 deg Orient;
2.5"HSD
1D-130
4,262.0 4,264.0 3,742.4 3,744.4 WS A4, 1D-130 11/10/1997 4.0 IPERF 180 deg ph, 2.5" HSD DP 1D-130
4,278.0 4,280.0 3,758.4 3,760.4 WS A4, 1D-130 11/10/1997 4.0 IPERF 180 deg ph, 2.5" HSD DP 1D-130
4,295.0 4,301.0 3,775.3 3,781.3 WS A3, 1D-130 1/17/1998 4.0 IPERF 180 deg ph; 90 deg Orient;
2.5"HSD
1D-130
4,298.0 4,300.0 3,778.3 3,780.3 WS A3, 1D-130 11/10/1997 4.0 IPERF 180 deg ph, 2.5" HSD DP 1D-130
4,300.0 4,301.0 3,780.3 3,781.3 WS A3, 1D-130 1/17/1997 4.0 IPERF 180 deg ph; 90 deg Orient;
2.5"HSD
1D-130
4,310.0 4,342.0 3,790.3 3,822.2 WS A3, 1D-130 1/17/1998 4.0 IPERF 180 deg ph; 90 deg Orient;
2.5"HSD
1D-130
4,354.0 4,356.0 3,834.1 3,836.1 WS A3, 1D-130 11/10/1997 4.0 IPERF 180 deg ph, 2.5" HSD DP 1D-130
4,365.0 4,370.0 3,845.1 3,850.1 WS A2, 1D-130 1/17/1998 4.0 IPERF 180 deg ph; 90 deg Orient;
2.5"HSD
1D-130
4,380.0 4,420.0 3,860.0 3,899.9 WS A2, 1D-130 1/17/1998 4.0 IPERF 180 deg ph; 90 deg Orient;
2.5"HSD
1D-130
4,392.0 4,394.0 3,872.0 3,874.0 WS A2, 1D-130 11/10/1997 4.0 IPERF 180 deg ph, 2.5" HSD DP 1D-130
4,402.0 4,404.0 3,882.0 3,884.0 WS A2, 1D-130 11/10/1997 4.0 IPERF 180 deg ph, 2.5" HSD DP 1D-130
4,430.0 4,432.0 3,909.9 3,911.9 WS A2, 1D-130 11/10/1997 4.0 IPERF 180 deg ph, 2.5" HSD DP 1D-130
4,440.0 4,452.0 3,919.9 3,931.8 WS A2, 1D-130 1/17/1998 4.0 APERF 180 deg ph; 90 deg Orient;
2.5"HSD
1D-130
4,462.0 4,464.0 3,941.8 3,943.8 WS A2, 1D-130 11/10/1997 4.0 IPERF 180 deg ph, 2.5" HSD DP 1D-130
4,490.0 4,492.0 3,969.7 3,971.7 WS A2, 1D-130 11/10/1997 4.0 IPERF 180 deg ph, 2.5" HSD DP 1D-130
4,594.0 4,596.0 4,073.4 4,075.4 WS A1, 1D-130 11/10/1997 4.0 IPERF 180 deg ph, 2.5" HSD DP 1D-130
Comment
SSSV: NIPPLE
1D-130, 3/13/2020 2:05:42 PM
Vertical schematic (actual)
PRODUCTION
5.5"x3.5"@4091'; 37.1-
4,768.1
IPERF; 4,594.0-4,596.0
IPERF; 4,490.0-4,492.0
IPERF; 4,462.0-4,464.0
APERF; 4,440.0-4,452.0
IPERF; 4,430.0-4,432.0
IPERF; 4,402.0-4,404.0
IPERF; 4,380.0-4,420.0
IPERF; 4,392.0-4,394.0
IPERF; 4,365.0-4,370.0
IPERF; 4,354.0-4,356.0
IPERF; 4,310.0-4,342.0
IPERF; 4,300.0-4,301.0
IPERF; 4,298.0-4,300.0
IPERF; 4,295.0-4,301.0
IPERF; 4,278.0-4,280.0
IPERF; 4,256.0-4,276.0
IPERF; 4,262.0-4,264.0
IPERF; 4,251.0-4,256.0
IPERF; 4,246.0-4,248.0
IPERF; 4,212.0-4,241.0
IPERF; 4,207.0-4,241.0
IPERF; 4,210.0-4,212.0
IPERF; 4,192.0-4,194.0
IPERF; 4,164.0-4,180.0
IPERF; 4,152.0-4,154.0
IPERF; 4,128.0-4,130.0
IPERF; 4,108.0-4,110.0
SEAL ASSY; 4,091.7
NIPPLE; 4,052.9
GAS LIFT; 4,004.0
SURFACE; 37.4-2,529.3
NIPPLE; 519.4
Patch PKR; 238.0
Spacer Pipe; 212.0
Patch PKR; 208.0
CONDUCTOR; 37.4-
121.0
HANGER; 41.4
KUP INJ
KB-Grd (ft) Rig Release Date
11/8/1997
Annotation
Last WO:
End Date
6/16/2008
H2S (ppm) Date...
TD
Act Btm (ftKB)
4,778.0
Well Attributes
Field Name
WEST SAK
Wellbore API/UWI
500292281500
Wellbore Status
INJ
Max Angle & MD
Incl (°)
42.54
MD (ftKB)
2,896.15
Legal Wellname 1D-130 Common Wellname1D-130
AK All Wellbores Schem
Mandrel Inserts
St
ati
on
No
/S Top (ftKB)
Top (TVD)
(ftKB) Make Model OD (in) Serv
Valve
Type
Latch
Type
Port
Size
(in)
TRO Run
(psi) Run Date Com Wellbore
1 4,003.9 3,485.6 CAMCO KBMG-M 1 Gas Lift DMY BK 0.000 0.0 6/23/2008 1D-130
1D-130, 3/13/2020 2:05:42 PM
Vertical schematic (actual)
PRODUCTION
5.5"x3.5"@4091'; 37.1-
4,768.1
IPERF; 4,594.0-4,596.0
IPERF; 4,490.0-4,492.0
IPERF; 4,462.0-4,464.0
APERF; 4,440.0-4,452.0
IPERF; 4,430.0-4,432.0
IPERF; 4,402.0-4,404.0
IPERF; 4,380.0-4,420.0
IPERF; 4,392.0-4,394.0
IPERF; 4,365.0-4,370.0
IPERF; 4,354.0-4,356.0
IPERF; 4,310.0-4,342.0
IPERF; 4,300.0-4,301.0
IPERF; 4,298.0-4,300.0
IPERF; 4,295.0-4,301.0
IPERF; 4,278.0-4,280.0
IPERF; 4,256.0-4,276.0
IPERF; 4,262.0-4,264.0
IPERF; 4,251.0-4,256.0
IPERF; 4,246.0-4,248.0
IPERF; 4,212.0-4,241.0
IPERF; 4,207.0-4,241.0
IPERF; 4,210.0-4,212.0
IPERF; 4,192.0-4,194.0
IPERF; 4,164.0-4,180.0
IPERF; 4,152.0-4,154.0
IPERF; 4,128.0-4,130.0
IPERF; 4,108.0-4,110.0
SEAL ASSY; 4,091.7
NIPPLE; 4,052.9
GAS LIFT; 4,004.0
SURFACE; 37.4-2,529.3
NIPPLE; 519.4
Patch PKR; 238.0
Spacer Pipe; 212.0
Patch PKR; 208.0
CONDUCTOR; 37.4-
121.0
HANGER; 41.4
KUP INJ
...
Legal Wellname 1D-130 Common Wellname1D-130
AK All Wellbores Schem
THE STATE
°fALASKA
GOVERNOR MIKE DUNLEAVY
Jan Byrne
Well Integrity Compliance Specialist
ConocoPhillips Alaska, Inc.
PO Box 100360
Anchorage, AK 99510
Re: Kuparuk River Field, West Sak Oil Pool, KRU 1D-130
Permit to Drill Number: 197-183
Sundry Number: 320-030
Dear Mr. Byrne:
Alaska Oil and Gas
Conservation Commission
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.cogcc.olaska.gov
Enclosed is the approved application for the 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 AOGCC grants for good cause shown, a person affected by it may file with the AOGCC
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,
J ek1cc
C
DATED thisL4of January, 2020.
4BDMSLL� JAN 312020
RECEIVED
STATE OF ALASKA JAN 2 1 202
ALASKA OIL AND GAS CONSERVATION COMMISSION Il_16 7 2 0
APPLICATION FOR SUNDRY APPROVALS AO
20 AAC 25280
1. Type of Request: Abandon LJ Plug Perforations ❑ Fracture Stimulate Li Repair Well 0 Operations shutdown LJ
Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑
Plug far Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Tubing patch❑
2. Operator Name:
4. Current Well Class:
5. Permit to Drill Number:
ConocoPhilli s Alaska Inc.
Exploratory ❑ Development ❑
Stratigraphic ❑ Service Q ,
197-183
3. Address:
6. API Number:
P. O. Box 100360, Anchorage, Alaska 99510
50029228150000 re
7. If perforating:
8. Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool? NA
Will planned perforations require a spacing exception? Yes ❑ No O
KRU ID -130 -
9. Property Designation (Lease Number):
10. Field/Pool(s):
ADL0025650 '
I Kuparuk River Field /West Sak Oil Pool
11. PRESENT WELL CONDITION SUMMARY
Total Depth MD (H): Total Depth TVD (H): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD):
4,778' 4,257' 4,053' 3,534'
Casing Length Size MD TVD Burst Collapse
Structural
Conductor 84' 16" 121' -
Surface 2,492' 10" 2,529'
Intermediate
Production 4,731' 8" 4,768'
Liner
Perforation Depth MD (H):
Perforation Depth TVD (H):
Tubing Size:
Tubing Grade:
Tubing MD (it):4108'
- 4596'
3589'- 4075'
3.500"
L-80
4,100'
Packers and SSSV Type:
Packers and SSSV MD (ft) and TVD (ft):
12. Attachments: Proposal Summary Q Wellbore schematic ❑
13. Well Class after proposed work:
Detailed Operations Program ❑ BOP Sketch ❑
Exploratory ❑ Stratigraphic ❑ Development ❑ Service ❑�
14. Estimated Date for
15. Well Status after proposed work:
2/1/2020
Commencing Operations
❑ WINJ ❑� WDSPL ❑ Suspended El:
OIL
GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑
16. Verbal Approval: Date:
Commission Representative:
GINJ ❑ Op Shutdown ❑ Abandoned ❑
17. 1 hereby certify that the foregoing is true and the procedure approved herein will not
be deviated from without prior written approval.
Authorized Name: Jan Byrne Contact Name: Jan Byrne / Dusty Freeborn
Authorized Title: Well Integrity Compliance Specialist Contact Email: N1617@conocophillips.com
Contact Phone: 907-659-7224
Authorized Signature: Date: 1/19/20
COMMISSION USE ONLY
Conditions of approval: Notify Commission so that a representative may witness Sundry Number: n
Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test u Location Clearance ❑
Other:
3BDMS �� .IAN 3 1 ZOZO
Post Initial Injection MIT Req'd? Yes ,.,� {/ No ❑
,/
Spacing Exception Required? Yes No Subsequent Form Required: /a— -fd
APPROVED BY /J n
Approved by: COMMISSIONER THE COMMISSION Date.
V U
�� ���w
Form -403 Revisedl/201
M i/zg/zel
// Submit Form and
Approved application is valid for 12 months from the date of a _ G I ISI !' A[t"ents in Duplicate
ID -130
DESCRIPTION SUMMARY
OF PROPOSAL
1D-130 was reported to the AOGCC and shut in and secured on 3/4/19 after failing an MITIA. Diagnostics
culminated in an acoustic LDL locating a tubing leak at 216'. The well was left secured due to not meeting
metrics, but the DPE has now determined the well to meet metrics and warrant patching. CPAI intends to set a
2.290", -30' OAL, Paragon 2 Packer, retrievable patch over the tubing leak to regain integrity and return the
well to injection.
Work Steps
1. Pull plug and prep patch set area.
2. Set patch at -208' to 238'.
3. Perform MITIA.
4. Bring well on injection.
5. Perform SW MITIA./
6. Submit 10-404. �t b✓� �vLe 5u C/ /01-T
Z4 nm -[L ��
KUP INJ WELLNAME 1D-130 WELLBORE 1D-130
ConocomillipsWell Attributes Max Angle SMD TD
Welll re PPIRIWI Well Core 3lalus 11) MpORI(BI Ac1BIm (EKE)
Alaska, Inc. IWESTSAK 1500=81500 11
CONMCTON: 3]4.121 O—
NIPPLE: 5194
SURFACE, 3 ,kZM.3—
GAS LIPI 4,W40—
NIPPLE. 4,W 9
IFERF', 4,1WL. .110.0
PERF. 41M&4 DO 0-
14.10 4,154.0
IFERF, 4.1 U1 4.1000
IFERF. 4, LEE CL41%O.
IFERF:421064,3130L
IPERF: 42M.642410
ERF, 4.2120.4.2410
IPERF. 4246.04245.0
IPERF', 4.251 M.2 ,,O�
IPERF: 42] S. 04.MO—
IPERF, 4,3W,04,301.0
IPERF: 4.31064,3420
I14, 35444355.0
IPERF. 4,3E 643]0.0
IPERF. 4 W0L4AM 0�
MERE 4440 N,4S2C�
IPERF: 4,4S264164.0�
IPERF, 44044492.0
IPERF: 4,MN,4 . O5
3]l
FR4..1
. 114.]60,1 ��
MOO
R.a1 oe.
S1
^I
N
Top IiVO)
M. Ln[eM1
PONSIae
TRO Run
Top (IIKB)
(IIKB)
Make
Model
o6 po)
&ary
Type type
(in)
(psi)
0.un Oale
Com
1 4,003.9
3,485.fi
CAMCO
KBM1IG-
1
Gas LIR
DMI BK
0.000
LE
fi2W2008
M
I
I
ConocoPhillips
Alaska
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
January 19, 2020
Commissioner Jessie Chmielowski
Alaska Oil & Gas Commission
333 West 7h Avenue, Suite 100
Anchorage, AK 99501
Dear Commissioner Chmielowski,
Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips
Alaska, Inc. well KRU 1D-130 (PTD 197-183) to set a retrievable tubing patch to repair a
tubing leak.
Please contact Dusty Freeborn or me at 659-7244 if you have any questions.
Sincerely,
Jan Byrne
Well Integrity & Compliance Specialist
ConocoPhillips Alaska, Inc.
=_ CASED
HOLE
Well Log Transmittal
To: AOGCC
Natural Resources Technician
333 West 7th Avenue
Suite 100
Anchorage, Alaska 99501
(907)793-1225
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 :
1) Caliper Report
2)
Signed
Print Name:
19 7 183
31150
READ Cased Hole, Inc. RECEIVED
Attn: Diane Williams
130 West International Airport Road AUG 2 9 2019
Suite C
Anchorage, AK 99518 AOGCC
Dianw.Williams(cDreadcasedhole com
02 -Jul -19 1D-130 1 Report / CD 50-029-22815-00
Date: 0 j[q
PROACTIVE DIAGNOSTIC SERVICES, INC., 130W, INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518
PHONE: (907)245-8951 FAX: (907)246-8952
E-MAIL: PDSANCHORAGEO.MEMORVLOGCOM WEBSITE: MMMEMORVLOG.COM
https//readcasedhvlamy.ahazepoivccvMpersoneVdiene_williama reedcesedhvle_corNDommevta/Desk[vp/ConocvPhillips_]Yevsmicdvcrt
CASED
HOLE
137183
31150
Memory Multi -Finger Caliper
Log Results Summary
Company:
ConocoPhillips Alaska, Inc.
Well:
1D-130
Log Date:
July 2, 2019
Field:
West Sak
Log No.:
15691
State:
Alaska
Run No.:
2
API No.
50-029-22815-00
Pipe Description:
2.875 inch 6.5 Ib. L-80 EUE 8RD ABMOD
Top Log Interval:
Surface
Pipe Use:
Tubing
Bottom Log Interval:
4,050 Ft. (MD)
Inspection Type : Corrosive & Mechanical Damage Inspection
COMMENTS:
This caliper data is tied into the top of the Camco DS Nipple at 519.4 feet (Driller's Depth).
This log was run to assess the condition of the tubing with respect to internal corrosive and mechanical
damage, particularly around a known leak at 219 feet. The caliper recordings indicate a possible hole at 217
feet. A 3-D log plot of the caliper recordings across the possible hole is included in this report.
The caliper recordings indicate the remainder of the 2.875 inch tubing appears to range from good to poor
condition with respect to internal corrosive and mechanical damage. Additional wall penetrations between
20% and 67% wall thickness are recorded in 77 of the 131 joints logged. Recorded damage appears as
deep isolated pitting and a line of pits. No significant areas of cross-sectional wall loss or I.D. restrictions are
recorded throughout the tubing logged.
This is the second time a READ caliper has been run in this well, and the first time this 2.875 inch tubing has
been logged since the RWO dated June 16, 2008.
MAXIMUM RECORDED WALL PENETRATIONS:
Possible Hole
85
5
217 Ft. (MD)
Isolated Pitting
67
1.2
90 Ft. (MD)
Line of Pits
63
125
4,026 Ft. (MD)
Line of Pits
62
124
3,990 Ft. (MD)
Isolated Pitting
56
121
3,397 Ft. (MD)
MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS:
No significant areas of cross-sectional wall loss (> 12%) are recorded throughout the tubing logged.
MAXIMUM RECORDED ID RESTRICTIONS:
No significant I.D. restrictions are recorded throughout the tubing logged.
B. Suhanek & A. Power C. Waldrop J. Fama
P.EAD Cased Hole Inc. / P.O. Box 1369, Stafford, TX 774.^.7
Phone: (281) 431-7100 or (898) 565-9085 Fax: (281) 431-7125 E-mail: ANSA-NorthAmerica(alreadcasedhole com
Prudhoe Bay Field Office Phone: (907) 659-2307 Fey,
�_- HOLE° Multifinger Caliper 3D Log Plot
Company: ConocoPhillips Alaska, Inc. Field: West Sak
Well: 1D-130 Date: July 2, 2019
Description: Detail of Caliper Recordings Across Possible Hole in 2.875 Inch Tubing.
Comments Depth Maximum Penetration Nominal I.D. 3-D Log Image Map
.......—............ .._. _�
111:240ft 0 % 100 2 Inches 3 82° 0° 90° 180° 270° 0'
Maximum I.D.
2 inches 3
Minimum I.D.
2 Inches 3
I _
150
Joint
-.--.
160
170
180
Joint 4
190
I
!I
__
200
I_
210
Joint 5
_
Possible Hole
- ---
-
- -
—
85% Wall
226--
—
Penetration
—7t77--
-230
230
-- ..
240
g
Joint
250
_
Correlation of Recorded Damage to Borehole Profile
Pipe 1 2.875 in (47.4'- 4,050.4') Well: ID -130
Field: West Sak
Company: ConocoPhilips Alaska, Inc
Country: USA
Survey Date: July 2, 2019
■ Approx. Tool Deviation . Approx. Borehole Profile
1 49
10 360
20 681
30 997
40 1,311
50 1,624
Ul
60 1,937 c
Z s
7
c p-
702,250 O
80 2,565
90 2,884
100 3,202
110 3,519
120 3,834
GLM 1
125 4,019
0 50 100
Damage Profile (% wall) / Tool Deviation (degrees)
Bottom of Survey = 125
CASED
HOLE Body Region Analysis
Well: i D-130 Survey Date: July 2, 2019
Field: West Sak Tool Type: UW MFC 24 No. 214320
Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches
Country: USA No. of Fingers: 24
Pipe 2.875 in. 6.5ppf L-80 EUE 8RD ABMOD Analyst: Waldro
Pipe Nom.OD Weight Grade & Thread Nom.ID Top Depth Bottom Depth
2.875 in. 6.5 ppf L-80 EUE 8RD ABMOD 2.441 in. 47 ft. a nsn e
MR
40
20
Damage Configuration (body)
0
Isolated General Line Other Hole/
Fitting Corrosion Corrosion Damage Pos. Hole
Damage Profile (% wall)
Penetration body Metal loss body
0 50 100
GLM 1
Bottom of Survey = 125
_= I CASED
- _-� HOLE Joint Tabulation Sheet
Well: 1 D-130 Survey Date: July 2, 2019
Field: West Sak Analyst: Waldrop
Company: ConocoPhiflips Alaska, Inc.
Pipe
Description Nom. ID Body Wall Top Depth
2.875 in. 6.5 ppf L-80 EUE 8RD ABMOD Tubing 2.441 in. 7 in. 47 ft
Bottom Depth
4,050 ft.
Joint
No.
Jt. Depth Pen.
(Ft.) Upset
(in.)
Pen.
Body
(in.)
Pen.
%
Metal
Loss
%
Min.
I.D.
(in.)
_0_.21
Comments
Damage Profile
(% wall)
0 50 100
0.1
47
0
0.03
12
2
2.42
Pun�-
1
49
0
Q.02
11
3
2_.39
1.1
79
0
0.03
16
5
2.36
Pup Shallow Pittin Lt Deposits.
1.2
89
0
0.15
67
6
13k__
Pup Isolated Pittine. Lt Deposits.
1.3
99
0
0.02
11
3
2.35
Pup Lt Deposits
2
107
0
0.04
17
5
2.37
_
Shallow Pittin . Lt. Deposits.
3
139
T 0
0.03
12
2
2.39
4
170
0
0.03
12
3
2.39
5
201
0
0.18
85
5
2.39
Possible Holel
6
232
0
0.04
18
6
2.38
Shallow Pitting.
7
265
0
0.02
11
3
2.40
8
296
0
0.04
18
6
2.37
Shallow Pittin . Lt. Deposits.
9
328
0
0. 4
18
6
2.37
Shallow Line of Pits. Lt Deposits,
10
360
0
0.07
31
5
2.3
Isolated Pitting
11
392
0
0 04
19
8
2.39
Shallow Line of Pits.
12
424
0
0.05
22
6
2.39
Isolated Pittin
13
455
0
0.04
18
7
2.39
Shallow Line of Pits.
14
487
0
0.06
25
9
2.39
isolated Pittin
14.1
519
0
0
0
0
2.30
_
Camco DS Nipple
15
520
0_
0.04
17
6
2.38
Shallow Line of Pits. Lt. D o its.
_16
553
0
0.07
30
5
2.38
Isolated Pittiny. Lt. De osits.
17
585
0
0.04
19
6
2.38
Shallow Pitting,
18
617
0
0.04
19
7
2.39
Shallow Pittine
19
649
0
0.05
21
6
2.39
_
Isolated Pittin
20
681
0
0.04
17
6
2.40
Shallow Line of Pits.
21
713
0.04
0.06
25
7
2.38
Isolated PittingLt. Deposits.
22
745
n
0.05
22
i
2.41
Isolated Pi in
23
777
0
0.03
13
6
2.38
24
809
0 1
0.04
17
4
2.37
Shallow Pitting. Lt Deposits.
25
840
0
0.04
20
5
2.38
Isolated Pittin
26
871
0
0.04
18
2
2.40
S all w Pitting.
27
902
0
0.03
15
6
2.39
Line of Pits.
28
933
0
0.04
17
8
-Shallow
2.39
Shallow Filling.
29
965
0
0.07
32
6
2.38
Isolated Pitting Lt Deposits.
30 1
997
0
0.04
18
8
2.39
_
Shallow Pitting.
31 1
1028
0
0.04
19 J
6
2.39
Shallow Pitting.
32 1
1060
0
0.04
18
3
2.38
_
Shallow Pitting. Lt, Deposits.
33 1
1090
0
0.05
22
7
139
Line of Pits.
34 1
1122
0
0.02
10
6
2.38
_
35
1154
_ 0
0.03
13
6
2.40
36
1186
0
0.03
12
5
2,39
_
37
1218
0
0.04
19
6
2.39
Shallow Line of Pits.
3
1249
0
0.02
8
2
2 9
9
1280
0
0.05
24
5
2.38
Isolated Pittin
40
1311
- 0
0.08
35
6
2.38
Isolated Pittinp Lt. Deposits.
41
1343
0
0.04
16
6
2.39
Shallow Line of Pits.
42
1374
0
0.02 1
10 1
5 J
2.38
43
1406
0
.02
9
4
2.38
44
1437
0
0.04
17
5
2.37
Shallow Line of Pits. Lt Deposits.
45
1469
0
0.0_
15
3
2.38
Shallow Pittine. Lt Deposits.
Penetration Body
Metal Loss Body
Page 1
Well:
Field:
Company:
aft I CASED
HOLE
ID -130
WestSak
ConocoPhilips Alaska, Inc.
Joint Tabulation Sheet
Survey Date: July 2, 2019
Analyst: Waldrop
Pipe
Description Nom. ID Body Wall Top Depth
2.875 in, 6.5 ppf L-80 EUE 8RD ABMOD Tubing 2.441 in. 0.217 in. 47 ft
Bottom Depth
4,050 ft.
Joint
No.
It. Depth Pen.
(Ft.) Upset
(in.)
Pen,
Body
(in.)
Pen.
%
Metal
Loss
I %
Min.
I.D.
(in.)
Comments
Damage Profile
(% wall)
0 50 100
1499
0
0.03
14
3
2.38
Lt. De posits.
L48
1531
0 _
0.04
18
2
2. 8
Shallow Pitfine
1561
0
03
1
2.38
_
Lt. De osits.
1592
0
0.05
25
6
2.39
Isolated Pittin
1624
0
0.07
31
7
2.39
Isolated Plainly,
51
1656
0
0.04
17
6
2.38
Shallow Fitting.
52
1687
0
0.05
_E03
22
4
2.39
Line of Pits.
53
1719
0
14
9
2.38
Lt. De osits.
54
1748
0
0.04
20
3
2.39
Isolated Pitting,
55
1779
0
0.02
11
3
2.39
56
1810
0
0.05
24
6
2.37
Line of Pit . Lt 7Neposits.
57
1842
0
0.05
25
2
2.37
Isolated Pittinp, Lt, De osits.
58
1874
0
0.05
21
5
2.38
Isolated Pittin
59
1906
0
0.06
28
4
239
Line of Pit .
60.
1937
0.04
007
31
12
2,37
Line of Pits. it De osits.
61
1968
0
O.Q7
30
4
2. 9
Line of Pits.
62
2000
0
007
31
6
2.38
Is lated Pi in It De osits.
63
2031
0
0.06
26
6
2.38
_
Line of Pits.
64
2062
0
005
22
6
2. 0
Line of Pits.
65
2094
0
0.06
28
4
2.38
Line of Pits Lt. 1--- -
66
67
2125
2156
0
0
0.07
004
34
18
6
5
2.38
2.39
Line of Pits.
Shallow Line of Pits
68
2187
0
0,05
25
4
2.38
_
Line of Pits.
69
2218
0
0.07
32
6
2.40
Isolated Pittin
70
2250
0
0.05
25
6
2.39
Line of Pits.
71
2282
0
0.05
24
6
2.38
Line of Pits
72
2313
0
0.06
29
6
2.38
Line of Pits. Lt Deposits.
73
234
0
0.09
40
6
2.38
Line of Pits.
74
2376
0
0.04
17
6
2.38
Shallow Pitting. Lt. Deposits.
75
2408
0
0.03
12
6
2.37
Lt Deposits,
76
2439
0
.05
22
6
2.38
Isolated Pitting,
77
2470
0
0.04
18
3
2.36
Shallow Pitting. Lt. Deposits.
78
2502
0
005
21
6
2.39
Isolated Pittin
79
2533
0
0.0
19
6
2.38
Shallow Pitfin .
80
2565
0
006
29
6
2.39
Line of Pits.
81
2597
0
0.07
32
6
2.37
_
Line of Pits. Lt. Deposits.
82
2629
0
0.06
28
6
2.39
Isolated Pitting.
83
2661
0
0.07
34
6
2,38
Line of Pits,
84
2693
0 1
0.05
24
6
2. 8
IWIated Pitting Lt De sits.
85
2725
0
003
16
6
2.38
Shallow Pitting.
86
2756
0
0.05
22
6
2.37
Line of Pits. Lt. Deposits.
87
2788
0
0.08
37
5
2.37
Line of Pits. Lt De osits.
88
2820
0
0.02
10
3
2.36
Lt. Deposits,
89
2852
0
0.06
29
6
2.39
Line of Pits.
90
2884
0
0.05
25
6
2.37
Line of Pits. Lt. De osits.
91
2916
0
0.03
16
6
2.38
Shallow Pitting, Lt. Deposits.
92
2948
0
0.06
29
6
2.40
Line of Pits.
93
2980
0
0.06
27
6
2.38
Line of Pits. Lt. De osits.
94
3012
0
0.0521
6
2. 8
Line of Pits_Lt, Denosits.
95
3044.
0
002.
9
2
2A0
'Penetration Body
Metal Loss Body
Page 2
-�
Well:
Field:
Company:
CASED
HOLE
ID-130
West Sak
ConocoPhillips Alaska, Inc.
Joint Tabulation Sheet
Survey Date: July 2, 2019
Analyst: Waldrop
Pipe
Description Nom. ID Body Wall Top Depth
2.875 in. 6.5 ppf L-80 EUE BIRD ABMOD Tubing 2.441 in. 0.217 in. 47 ft
--77
Bottom Depth
4,050 ft. J
Joint
No.
Jt. Depth Pen.
(Ft.) Upset
(in.)
Pen.
Body
(in.)
Pen.
%
Metal
Loss
%
Min.
I,D.
(i n.)
Comments
Damage Profile
(% wall)
0 50 100
96
3075
0
0.03
12
3
2.38
Lt Deows.
97
3106
_ 0
0.07
32
11
2.38
_
Isolated Pittin
98
3138
00.07
31
7
_2.38
Line of Pits Lt. Deposits.
99
3170
0
0.05
24
5
2.38
Line of Pits.
100
3202
0
0.06
27
6
2.38
Isolated Pitting
101
3234
1 0-k-0.05
21
7
239
Line of Pits.
102
3266
1 0 1
0.10
45
5
2.39
Line of Pits.
1033297
0
0.09
41
7
2.38
Isolated Pittin
104
3329
0
0.07
33
5
2.39
Line of Pits.
105
3361
0
0.08
36
5
2.39
Line of Pits.
106
33930
0.12
56
6
2.37
Isolated Pitting. Lt. Deposits.
107
3425
0
0.08
37
6
2.39
Line of Pits.
108
3456
0
0.07
31
7
2.38
Line of Pits.
109
3487
0
0.0
41
6
2.39
Line of Pits.
110351
9
0
0.08
36
8
2.37
Line of Pits. Lt. Deposits,
111
3551
0
0.06
26
6
38
Line of Pits. Lt. Deposits,
112
3583
0
0.09
42
6
2.37
Line of Pits. Lt. De o its.
113
3615
0
0.06
29
3
2.39
Line of Pits.
114
3645
0
0.08
38
4
2.40
Line of Pits.
115
3676
0
0.09
43
5
2.37
Line of Pits. Lt. De osits.
116
3708
0
0.09
42
4
2.39Line
of Pits.
117
3739
0
0.10
47
3
2.39
Line of Pits.
118
3770
0
0.10
46fi
2 37
Isolated Pi tin Lt. Deposits.
119
3802
0
0.11
49
1 6
2.38
Line of Pits.
120
3834
0
0.10
47
6
2.38
Line of Pits. Lt. De osits.
121
3865
0
0.11
51
6
2.39
Line of Pits.
122
3897
0
0.11
51
7
2.38
Line of Pits.
3928
0
0.10
46
6
2.39
Line of Pits.
3960
0
0.1362
6
2.38
Line of Pits.
3992
0
003
12
6
2.36
Pu Lt. De osits.
E124
400
0
0
0
0
2.34
LM 1 No D viation
4009
0
003
12
6
2.36
Pu Lt D osits.
4019
0
0.14
63
6
2.39
1 Line of Pits.
MOEN
Penetration Body
Metal Loss Body
Page 3
Cross-sectional Illustration
Survey Date:
ICASED
Tool Type:
=_ff%
11
HOLE
Well:
ID -130
Field:
West Sak
Company:
ConocoPhillips Alaska, Inc.
Country:
USA
Tubing:
2.875 in. 6.5
ppf L-80 €UF 8RD
Cross-sectional Illustration
Survey Date:
July 2, 2019
Tool Type:
UW MFC 24 No. 214320
Tool Size:
1.69 inches
No. of Fingers:
24
Cross Section for Joint 5 at depth 216.550 ft.
Tool speed = 49
Nominal ID = 2.441
Nominal OD = 2.875
Remaining wall area = 95%
Tool deviation - 2°
Finger = 3 Penetration = 0.184 in.
Possible Hole 0.18 in. = 85% Wall Penetration
HIGH SIDE = UP
A===% I CASED
HOLE
Well:
ID -130
Field:
West Sak
Company:
ConocoPhillips Alaska, Inc.
Country:
USA
Tubing:
2.875 in. 6.5 DDf L-80 EUE
Cross-sectional Illustration
Survey Date:
July 2, 2019
Tool Type:
UW MFC 24 No. 214320
Tool Size:
1.69 inches
No. of Fingers:
24
Cross Section for Joint 1.2 at depth 89.730 ft.
Tool speed = 30
Nominal ID = 2.441
Nominal OD = 2.875
Remaining wall area = 97%
Tool deviation = 2°
Finger = 15 Penetration= 0.145 in.
Isolated Pitting 0.15 in. = 67% Wall Penetration HIGH SIDE = UP
Wallace, Chris D (DOA)
From:
NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com>
Sent:
Monday, March 4, 2019 3:58 PM
To:
Wallace, Chris D (DOA)
Cc:
CPA Wells Supt; NSK Well Integrity Supv CPF1 and 2
Subject:
KRU 1 D-130 (PTD 197-183) Report of failed MITIA
Attachments:
1 D-130.pdf,, 1 D-130 90 day TIO trend 3.4.19.JPG
Chris,
KRU water Injector 1D-130 (PTD 197-183) Reviewing the TIO trend this morning revealed that the IA pressure had
equalized with the tubing pressure. DHD was mobilized to the well and a diagnostic MITIA failed. The well is to be shut
in and freeze protected as soon as possible. The immediate plan is to secure the well and continue diagnostics. Once a
path forward has been determined the proper paperwork for continued injection or corrective action will be
submitted. A wellbore schematic and TIO trend are attached.
Please let us know if you disagree or have any questions with this plan.
Regards,
Jan Byrne / Kelly Lyons
Well Integrity Supervisor
ConocoPhillips Alaska, Inc.
Office phone: (907) 659-7224
LJ
MEMORANDUM
To: Jim Regg
P.I. Supervisor ~~~ ~~ j2(-,~ t0
FROM: Bob Noble
Petroleum Inspector
•
State of Alaska
Alaska Oil and Gas Conservation Commission
DATE: Thursday, July 22, 2010
SUBJECT: Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA INC
1 D-130
KUPARUK RIV U WSAK iD-130
Src: Inspector
NON-CONFIDENTIAL
Reviewed By:
P.I. Suprv ~~
Comm
Well Name: KUPARUK RIV U WSAK 1D-130
Insp Num: mitRCN100718143450
Rel Insp Num: API Well Number: 50-029-22815-00-00
Permit Number: 197-183-0 Inspector Name: Bob Noble
Inspection Date: 7/16/2010
Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
Well I I 31D o Type Inj. N • TVD 3568 ~ IA 10 1750 - 1650 1630
P.T.D 1971830 TypeTest SPT Test psi l~so OA ]~0 2ao ]so ]so
Interval 4~TST p/F P ~ Tubing soo soo alo alo
Notes: ~~~ rL~q ~l}- ~S~F- 1bT~~~S~`
Thursday, July 22, 2010 Page 1 of 1
~~~~~~
Schlumberger -DCS
2525 Gambell Street, Suite 400
Anchorage, AK 99503-2838
ATTN: Beth
,:,a ~ a ~..,,~
Log Description
~'
~~~I `e _~ ~ ~~~~~~
f,,, .
~~:~ ~ ~
NO. 5125 ;., ~._
Company: Alaska Oil & Gas Cons Comm
Attn: Christine Mahnken
333 West 7th Ave, Suite 100
Anchorage, AK 99501
Field: Kuparuk
Date BL Color CD
03/03/09
Well Job #
3H-33 604C-00006 USIT _ 02/09/09 1 1
1 D-130 ANHY-00049 INJECTION PROFILE J ~- 02/12/09 1 1
2A-26 ANHY-00053 PERF/SBHP SURVEY L l~ (p 02/16/09 1 1
3H-33 AYS4-00039 SFRT - 02/23/09 1 1
3C-06 B14B-00005 GLS ~! ~i 02/23/09 1 1
2N-318 6148-00006 SBHP SURVEY _ ~' _ / U 02/24/09 1 1
3H-33 804C-00006 SONIC SCANNER ~'
a 02/09/09 1 1
3J-06 6148-00008 PRODUCTION PROFILE 02/27/09 1 1
1 D-119 AYS4-00044 INJECTION PROFILE ~ _. ~ ~ 02/28/09 1 1
3G-03 AYS4-00043 PRODUCTION PROFILE - ~' ~ 02/27/09 1 1
%'_ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907j 561-8317: Thank you.
±J
i
1~E~I®~NDUl9~ •
Toy Jim Regg "~
P.I. Supervisor ~ ~~~'. Iti(;7
FROM: Bob Noble
Petroleum Inspector
State of Alaska •
Alaska Oil and Gas Conservation Commission
DATE: Wednesday, July 30, 2008
SUBJECT: Mechanical [ntegrity Tests
CONOCOPHILLIPS ALASKA INC
1 D-130
KUPARUK RIV U WSAK ID-130
Src: Inspector
NON-CONFIDENTIAL
Reviewed By:
P.I. Suprv ~-~ .~.'=
Comm
Well Name• KUPARUK RIV U WSAK 1 D-130 API Well Number 50-029-22815-00-00 Inspector Name: Bob Noble
Insp Num: mitRCN080730090558 Permit Number 197-183-0 / Inspection Date• ~/27i20os
Rel Insp Num:
Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
Well 1D-130 Type Inj. W TVD 3573 IA 1600 2320 2310 2310
p•T• 19na3° TypeTest ~ SPT Test psi ~ 2320 OA I 60 ~o ~ ~o ~o
Interval ~T^I- ~ P/F P .~ Tubing aoo soo soo soo ~
Notes:
.L1tY~ ;~~-~G~~~I,-W~ I~rJF~
~'~~'~~~~ raUG ~ ~1 2008
Wednesday, July 30, 2008 Page l of 1
Page 1 of 1
• •
Maunder, Thomas E (DOA)
From: Maunder, Thomas E (DOA)
Sent: Monday, July 21, 2008 8:59 AM
To: 'Lauer, Cody'; Allsup-Drake, Sharon K
Subject: 197197 KRU_1 D-130_308-201.pdf
Attachments: 197-183 KRU 1D-130_308-201.pdf
'~/, - -
Cody and Sharon,
I am reviewing the 404 recently submitted for work on this well. I have attached a copy of the 404.
It is noted that there is "no packer" and that is technically correct, however there is a seal bore at the 5-1/2" x 3-
1/2" XO that is the functional equivalent. Where tapered production strings have been employed such as here, a
note similar to what I have done on the 404 should be included.
Catl or message with any questions.
Tom Maunder, PE
AOGCC
~/N~~v JUL ~ ~ 2008
7/21 /2008
• STATE OF ALASKA •
JU! ~ 2Q0~
ALASKA OiL AND GAS CONSERVATION COMMISSION ~PS~~a ~'~ i;~~•4-> ~, ~ t n
REPORT OF SUNDRY WELL OPERATIONS ~1.,..,ti ~Os~is'3~SitJn
A~n
1. operations Performed: Abandon ^ Repair Well ^~ ~ Plug Perforations ^ Stimulate ^ Other Patch
Alter Casing ^ Pull Tubing ~ ~ Pertorate New Pool ^ Waiver ^ Time Extension ^
Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^
2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number:
ConoCOPhillips Alaska, InC. Development ^ Exploratory ^ 197-183 /
3. Address: SVatigraphic ^ Service ~ • 6. API Number:
P. O. Box 100360, Anchora e, Alaska 99510 50-029-22815-00
7. KB Elevation (tt): 9. Well Name and Number:
RKB 41', Pad 71' 1 D-130 '
8. Property Designation: 10. Field/Pool(s):
ADL 25650 ~ Kuparuk River Field /West Sak Oil Pool .
11. Present Well Condition Summary:
Total Depth measured 4778' feet
true vertical 4257' . feet Piugs (measured)
Effective Depth measured 4304' feet Junk (measured)
true vertical feet
Casing Length Size MD TVD Burst Collapse
Structural
CONDUCTOR 80' 16" 121' 121'
SURFACE 2486' 7-5/8" 2527' 2238'
PRODUCTION 4051' 5-1/2" 4092' 3573'
PRODUCTION 676' 3-1/2" 4768' 4247'
Perforation depth: Measured depth: see attached schematic
true vertical depth:
Tubing (size, grade, and measured depth) 2-7/8", L-80, 4105' MD.
l~ \_ c-~ r
Packers &SSSV (type & measured depth) no packer t W ~~~ C v`~ ~CrJ ~~ ~~4~ Pt'~C'fc ~ v ~{b b~ ~"~U `~
~ e
no SSSV
12. Stimulation or cement squeeze summary: ~~
Intervals treated (measured) not applicable
Treatment descriptions including volumes used and final pressure :
13. Representative Daily Average Production or Injection Data
Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure
Prior to well operation SI
Subsequent to operation 284 -
14. Attachments 15. Well Class after work:
Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ^~
Daily Report of Well Operations _X 16. Well Status after work:
Oil^ Gas^ WAG^ GINJ^ WINJ Q' WDSPL^
17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt:
308-201
Contact Cody Gauer @ 263-4802
Printed Name C Title
Ph
263
4802 Wells Engineer
~ l S~j
D
t
Signature __ one:
- a
e
Pre h n Allsu Drake 63-461
~{ J
Form 10-404 Revised 04//2006
~_ ,j~i~ ~ ~ 2Q0~
~~ 7~ l8. off'
Submit Original S~lrriy ~~'
•
•
ConocoPl~i~ips Time Log & Summary
Wel7vfaw YYeb RePardng ~ \e p o
Well Name:. 1 D-130 Rig Name: NORDIC 3
Job Type: RECOMPLETION Rig Accept: 6/14/2008 2:00:00 PM
Rig Release:
--- -
Time Lo s
9____
--- _ __ -
__
-
Date From To Dur S De th E Depth Phase Code Subcode T Comment
6/14/2008 zahrsummarv
Nordic Rig 3 released from 1 D-122 on 6-14-08 @ 12:30. Rigged down and moved to 1 D-130. Nordic Rig 3
accepted on 1 D-130 on 6-14-08 @ 14:00. Pull BPV and Reverse circ. displace well w/ 9.6 ppg brine. Set
TWC and ND Tree. Witness of BOPE Test waived b Bob Noble 17:00 hrs on 6-14-08.
12:30 14:00 1.50 MIRU MOVE MOB P Moving Nordic Rig 3 from 1 D-122 to
1 D-130 S of ri ,level and berm u .
14:00 16:00 2.00 COMPZ RPCOM OTHR P Nordic Rig 3 accepted 6-14-08 @
1_4:00 on 1 D-130 Spot rig
equipment. Bring in lubricator. Load
pits w/ 9.4 ppg brine and wt up to 9.6
brine.
16:00 17:00 1.00 COMPZ RPCOM OTHR P L bricate out BPV and la .down
lubricator.
17:00 18:00 1.00 COMPZ RPCOM OWFF P PT lines to 3,000 psi. Open up well
320 si tb , 320 si IA, 120 si OA.
18:00 19:00 1.00 COMPZ RPCOM OTHR P Continue to load pits w/ 9.6 ppg
brine.
19:00 20:00 1.00 COMPZ RPCOM CIRC P Reverse circulate 9.6 ppg brine @ 4
bpm @ 610 psi to tiger tank w/ 110
bbfs. Shut down and change over to
take returns in house. @ 4 bpm @
720 si. for 50 bbls.
20:00 21:00 1.00 COMPZ RPCOM OWFF P Monitor well - on slight vac. BD and
RD lines and a ui ment.
21:00 21:30 0.50 COMPZ RPCOM OTHR P Set TWC.
21:30 23:00 1.50 COMPZ RPCOM NUND P PJSM, ND Tree.
23:00 00:00 1.00 COMRZ RPCOM NUND P PJSM, NU BOPE.
6/15/2008
Continue to NU BOPE and Test BOPE @ 250/3000 psi. Pull test plug and TWC. Monitor well. BOLDS and
pull seal assy from SBE and Hanger to rig floor. Reverse circ 2 BU. Pooh laying down 3 1/2 completion.
Change LPR's. Test @ 250/3,000 psi. PU and Rih w/ 2 7/8 completion string space out and land:
14 bbls lost toda .
00:00 03:00 3.00 COMPZ RPCOM NUND P Continue to NU BOPE.
03:00 08:00 5.00 COMPZ WELCTI BOPE P Begin testing BOPE 250/3,000
si
08:00 09:30 1.50 COMPZ RPCOM OTHR P Pull BPV and test plug. MU landing
joint and BOLD. Tubing jumped up
-1.5 ft after the last LDS was backed
out. Pull tubing out of PBR with
95K#, ull u hole at 75K#. Lb
landin 'oint and tubin han er.
09:30 10:30 1.00. COMPZ RPCOM CIRC P RU to reverse circulate. Reverse 75
bbl of 9.2 2 tubin volume).
Page 9 of 2
Time Logs
Subcode T Comment
Date
From To D
ur
e th E De th Phase Code
5-
D
--
_ 10:30 16:00 _
_
5.50 _
_ COMPZ _
RPCOM _
PULD P -
Pump dry job. PULD 3-1/2
com letion. External corrsion evident
on the 3-1/2" tubing starting on joint
69.
16:00 17:00 1.00 COMPZ RPCOM OTHR P Set Test plug. Change out LPR's f/ 3
1/2 to 2 7/8.
17:00 18:30 1.50 COMPZ WELCTL BOPE P Test Lower Pipe rams @ 250/3,000
si. RD test a ui and ull test lu .
18:30 22:00 3.50 0 4,092 COMPZ RPCOM PULD P PU and Rih w/seal assy and 2 7/8
tb to 4,092'
22:00 22:30 0.50 4,092 4,107 COMPZ RPCOM OTHR P Veri seals are in SBE and no o.
PT IA 250 si.
22:30 23:00 0.50 4,107 COMPZ RPCOM HOSO P Space out and MU hanger, pupjt,
and X-O Sub. MU Landin 't.
23:00 23:30 0.50 COMPZ RPCOM CIRC P Reverse circ. w/ 50 bbls of corrosion
inhibited brine w/ 1 % by vol. CRW
132 followed by 5 bbls 9.6 ppg brine
4 b m 500 si..
23:30 00:00 0.50 COMPZ RPCOM OTHR P Land completion w/mule shoe @
4,104' 57k up wt, 50k do wt. and
35k block wt.
6/16/2008
Test tbg and. IA and shear out SOV. Set BPV and ND BOPE. NU tree and test to 5000 psi. Set BPV.
Nordic Ri 3 released from 1 D-130 on 6-16-08 12:00 noon.
00:00 01:00 1.00 COMPZ RPCOM OTHR P RU Lines and PT @ 300 psi for TBG
and IA PT.
01:00 02:30 1.50 COMPZ RPCOM DHEQ P PT Tbg @ 2;500 psi and hold for 15
minutes and chart. Bleed down.
1,750 psi. PT ~ 2.000 psi. Hold
and chart for 30 minutes dum tb
and shear out SOV 750 si.
02:30 03:00 0.50 COMPZ RPCOM OTHR P Set TWC
03:00 06:30 3.50 COMPZ RPCOM NUND P ND BOPE and change out 2 7/8
rams to 3 1/2.
06:30 08:30 2.00 COMPZ RPCOM NUND P PJSM, NU tree, test packoff and tree
to 5000 si.
08:30 11:00 2.50 COMPZ RPCOM FRZP P PJSM. RU Little red, pump 70 bbl
down the IA taking returns up the
tubin . U-tubr for 1 hr.
11:00 12:00 1.00 COMPZ RPCOM OTHR P 300 psi on the tubing. RU lubricator
and set BPV.
Nordic Rig 3 released from 1 D-130
on 6-16-08 12:00 noon.
---
Page 2 of'Z
- KUP
1.~h~~~~r~~~~5 ( ~ Well Attributes ~ 1 D-130
~;;. ~-. n. ~ API I UWI Feld Name Well slaws aal mum InGmalron (') Total DeptA (hKb)
I 5002922815 WEST SAK INJ 42.54 4,768.0
Comment H2S (ppm) Date AnnotaR... End Date KB-Ground Distance (Iq Rig RNeue Date
Last WO: 6/16/2008 1 tl8/1997
..Mi, X19 f;.t ~) 'Ci". !.=.~a~i~l.l
L,,,~,I
-Annotation Depth (RKB) Entl Drte Anrrotrtion
End Drte
HANGER, 47
CONDUCTOR,
x121
SURFACE,
42,s27
cns urT,
4,009
PRODUCTION, ~
44.092
IPERF,
4,108>, 170 ~...........
IPERF,
4,1284,130
IPERF,
4,152-4,159 _
IPERF,
4,1844,180
IPERF,
4,1924,199
IPERF,
4,21D4, ztz
IPERF,
a,zm4,z41
IPERF,
4,2124,241
IPERF,
4,2964,298
IPERF, ,
4,2514,258
IPERF,
4,2824,284 ~•...
IPERF, --
4,2564,27fi
IPERF, --
4,2784, 260 ~':;-..
IPERF,
4,2954,301 ~~-
IPERF,
4,29&4,300
IPERF,
IPERF,
4,3704,342
IPERF, -
4,359-4.35fi
IPERF,
4,365<, 370
IPERF,
4,3924,394
IPERF,
4,3844.420 '
IPERF, .
4.9024.404
IPERF,
4.9344.432 -...........
APERF,
4,9944,952
IPERF,
4,4824,984 .._ _
IPERF,
0,4944,492
IPERF,
4,5944,598 _-
PRODUCTION,
4,osz-x,766
TD, 4,768
Last Tag: 4,304.0 5Y292008 Rev Reason: WORKOVER 7112/2008
Casing Strings
Gesing Desulpuon OD p0) fD (,n) lop (AKB) Sai Depth (tt.. Set Depih (ND) (K.. Wi (lbs/... Grade lop Gonne.:tro0
CONDUCTOR 16 15.062 0.0 121.0 121.0 62.50 H-40
Casing Ducriptlon OD (in) ID (in) Top (RKB) Set Depth (ft.. Set Depth (ND) (R.. Wt (ItuU... Grade Top Connection
SURFACE 75/8 7.625 0.0 2,527.0 2,234.7 29.70 L-80
Casing Description OD pn) ID pn) Top (RKB) Set Depth (ft.. Set Depth (ND) (R.. VYt (Ibs/... Grade Top Connecton
PRODUCTION 5112 4.767 0.0 4,092.0 3,573.2 15.50 L-80
Casing Oesedptlan OD (in) ID (in) Top (RKB) Set Depth (R.. Set Depth (ND) (ft. . Yyt (Ibs/... Grade Top Connection
PRODI_ICTION 3112 2.441 1 4,p920 4.76Rq 4.247.1 0.30 L-RO
Tubin Strin s
Tubing Description OD (in) ID (in) Top (R.. Set Depth (RK... Set Depth (ND) (RKB) Wt (Ibs/It) Grade Top Connection
TUBING 2 7/8" 3.668 2.441 -0.1 4,104.7 3,585.8 6.50 L-80 EUE 8R0
AB-rrlod~ed
Perforations
Notes: General & Safety
j Mandr®I Oeta its:
Set Depm Pon
Top fND) Valve Latch Size TRO Run
S61 (RKB) (RKB) Make Model OD IMI Type Type IIRI (psi) Run Date Commem
S~~r,~ ~ ~ Oi~ ~~~ l~`~~~Gl / ~..~~,~o~.,~
OII/ ~ ~
C01~5i' R~tA'rIO1~T CO1rII~iISSIOIQ 333 W. 7th AVENUE, SUITE 100
ANCHORAGE, ALASKA 99501-3539
PHONE (907) 279-1433
FAX (907) 276-7542
Cody Gauer
Wells Engineer
ConocoPhillips Alaska Inc.
PO Box 100360 ~~~NE~ JUN ~ ~ 2008
Anchorage, AK 99510
Re: Kuparuk River Field, West Sak Oil Pool, 1D-130 ~ ~ g 3
Sundry Number: 308-201 ~,
Dear Mr. Gauer:
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.
When providing notice for a representative of the Commission to witness any
required test, contact the Commission's petroleum field inspector at (907)
659-3607 (pager).
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 rehearing. A request for rehearing 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. A person may not appeal
a Commission decision to Superior Court unless rehearing has been
requested.
Sincerely,
~~
Daniel T. Seamount, Jr.
~~ Chair
DATED this ~?- day of June, 2008
Encl.
ConocoPh ~ I I ~ ps
Alaska
P.0. BOX 100360
ANCHORAGE, ALASKA 99510-0360
June 3, 2008
Commissioner
State of Alaska
Alaska Oil & Gas Conservation Commission
333 West 7'h Avenue Suite 100
Anchorage, Alaska 99501
Dear Commissioner:
~~:~.
'~JiJ~
,~''v s~
p~lasKa Gig ~ Gas Cc~s~~c~3r~~ss~c~
Arach4r 9
ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the
West Sak Well 1 D-130 (PTD# 197-183).
Injecting well 1D-130 was drilled and completed in 1997. The well operated on water injection
until August 2007 when it failed an MITIA. Tubing by Inner Annulus communication was
suspected and a caliper survey was run to identify leaks. A caliper PDS log was run showing wall
penetrations in excess of 40% in all tubing below 1,450', approximately 88 of 133 joints. Based
on this, the tubing will be replaced with smaller diameter tubing for more effective corrosion
control.
The purpose of the proposed workover will be to pull the existing 3-1/2" tubing string and replace
it with a new 2-7/8" tubing. Attached is a proposed schematic along with a general workover
procedure.
If you have any questions or require any further information, please contact me at 263-4802
Regar ,
Gauer
Wells Engineer
CPAI Drilling and Wells
~ ~ • ~°~ '~
,Ivy • STATE OF ALASKA ,~ ~'
~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~ ~~/1/ Q
APPLICATION FOR SUNDRY APPROV ~4i/~ 2~0~
20 AAC 25.280 a ~'~ One „
1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver O/'ag~ ~ ~I
Alter casing ^ Repair well Q Plug Perforations ^ Stimulate ^ Time Extension ^
Change approved program ^ Pull Tubing Q ~ Perforate New Pool ^ Re-enter Suspended Well ^
2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number:
ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 197-183
3. Address: Stratigraphic ^ Service Q 6. API Number:
P. O. Box 100360, Anchorage, Alaska 99510 50-029-22815-00
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 Requires? Y@S NO ~ - 1D-130
9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s):
ADL 25650 - RKB 41', Pad 71' Kuparuk River Field /West Sak Oil Pool ,
12. PRESENT WELL CONDITI ON SUMMARY
Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ff): Effective Depth TVD (ft): Plugs (measured): Junk (measured):
4778' 4257 4290' 3770' 4044'
Casing Length Size MD TVD Burst Collapse
CONDUCTOR g0' 16" 121' 121'
SURFACE 2486' 7-5/8" 2527' 2238'
PRODUCTION 4051' 5-1/2" 4092' 3573'
PRODUCTION 676' 3-1/2" 4768' 4247'
Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft):
see attached schematic 3-1/2" i_-$0 4100'
Packers and SSSV Type: Packers and SSSV MD (ft)
no packer
no SSSV
13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work:
Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service Q
15. Estimated Date for 16. Well Status after proposed work:
Commencing Operat June 19, 2008 Oil ^ Gas ^ Plugged ^ Abandoned ^
17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^~ ~ WDSPL ^
Commission Representative:
18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Cody Gauer @ 263-4802
Printed Name Uel' Title: Wells Engineer
Signature Phone 263-4802 Date p6 oy a~
Commission Use Onl
Sundry Number:
Conditions of approval: Notify Commission so that a representative may witness ~d ~ ~-/,; /
Plug Integrity. BOP Test ~ Me
chanical Integrity Test ~ Location Clearance ^
'
Other: ~ ~ V ~ p Sc ` ~~ \ T~ c7
Subsequent Form Required: ~O~c
1
~~~
oRi^iNA~
~ APPROVED BY ~ Z
Approved by: COMMISSIONER THE COMMISSION Date:
~~
Form 10-403 Revi ed 0 /2006 .1~ ~ ~`~ ~~r" ~ ~/~ Submit in Duplicate
.,,~ .2~=-. ~r r/~ /S~ l''~0 X08
West Sak 1 D-130 •
General Workover Procedure
June 4, 2008
Pre Rig Work:
1. Apply for Sundry
2. Tag Fill. Obtain SBHP & Caliper log
3. Pull DV @ 3,985'
4. Set BPV
Rig Workover:
Verify Sundry Approval
1. MIRU Nordic 3.
2. Pull BPV Circulate 9.6 ppg kill weight fluid ~~~ P~ ~~d~ ~~
3. ND tree, NU & test 11" SM BOPE w/ 3.5" rams to 250/si. ~~
4. Pull and Lay down tubing G.~L~~~
5. Run in w/ new completion. Sting into existing PBR. Space out.
6. Spot corrosion inhibitor. Land tubing. Pressure test IA to 2000 psi
7. ND BOPE. NU existing tree. Freeze protect well.
8. RDMO Nordic 3.
Post Rig Work:
MIRU CTU. FCO well.
1. RDMO CTU
2. MIRU SL. Pull SOV & Run GLV's
3. RDMO SL
• West Sak 1 D-130
General Workover Procedure
June 4, 2008
Pre Rig Work:
1. Apply for Sundry
2. Fill. Obtain SBHP & Caliper log
3. Pull V @ 3,985'
4. Set BP
Rig Workover:
Verify Sundry Appro 1
1. MIRU Nordic 3.
2. Pull BPV Circulate kill eight fluid
3. ND tree, NU & test BOPE
4. Pull and Lay down tubing ~
i
5. Run in w/ new completion. Sting i t
6. Spot corrosion inhibitor. Land tubing
7. ND BOPE. NU existing tree. Freeze
8. RDMO Nordic 3.
~~~~~~
~.
existing PBR. Space out.
ressure test IA to 1500 psi
ro ct well.
Post Rig Work:
MIRU CTU. FCO well.
1. RDMO CTU
2. MIRU SL. Pull SOV & Run GLV's
3. RDMO SL
i
~~.
Conc~c4Phillips Ataska, Inc..
i D-130 "' ---
API:
I SSSV T e: I
I~, SURFACE Annular Fluid:
j (0-2527,
' OD:7 625 Referertce Lo
i Wt:29.70) LastTa : ~
i ~a~ r~~ n~~o• e
TUBING
(0-4100,
OD:3.500,
ID:2.438)
~ROOUCnoN
(o-aosz,
OD:5.500,
Wt:15.50)
SEALASSY
(4087-4099,
OD:3.500)
PBR
(4092-4104,
OD:5.500)
TTL
(4100-4101,
OD:3.500)
Perf
(4108-4110)
PRODUCTION
(4092768,
OD:3.500,
Wt:9.30)
Perf
(4152x1154)
Perf
(4164-0180)
Perf
(4210x1212)
Pert
(4207241)
Perf
(4246x1248)
Pert
(4251256)
Perf
(4354.4356)
Perf
(4365-4370)
Pert
(4380x1420)
Perf
(4402-4404)
Perf
(4430-0432)
Pert
(4440-0452)
Perf
(4462-4464)
Perf
(4594-4596)
ng_String -ALL
e: INJ
ion: 11/
xrw
KRU 1 D-130
An k: ~ TD: 3 de ~ 4778
Rev Reason: GLV C/O, SET PLUG,
TAG FOUNDLEAK
Last U date: 4/13/2008
~St MD TVD Man Mfr
.. Man Type V Mfr V Type V OD Latch Port TRU ,Date Run L VN~
Cmnt
1 i4@. ;. Sly 2,~T AaT DMY I.0 T-1 (fin-K) i 4 10. ~ .,
Other mugs, equip., etc.} -JEWELRY
- _ __
,
De h TVD T e Descri tion ID
4044 3525 NIP Camco'W-1' Bore 2.813
4044 3525 PLUG 2.81" MA-2 PLUG set 4/10/2008 0.000
4087 3568 SEAL ASSY Baker S0d0 GBH-22 LOCATOR SEAL ASSEMBLY STABBING INTO PROD CSG PBR 3.000
4092 3573 PBR 3.5" PROD CSG POLISHED BORE RECEPTACLE CEMENTED IN TO RECEIVE 3.5"TUBING 4.000
4100 7581 TTL 2.441_
General Notes
Det e Note
4!11/2 008 NOTE: LEAK FOUND 4002' WLM
e
Tubing String -TUBING
~~
Maunder, Thomas E (DOA)
From: Gauer, Cody [Cody.Gauer@conocophillips.com]
Sent: Wednesday, June 11, 2008 2:13 PM
To: Maunder, Thomas E (DOA)
Cc: Ennis, J J
Subject: RE: 1 D-130 (197-183)
Attachments: 1D-130 Sundry Procedure revised 6-11-08.doc
Tom,
My apologies. Below are some answers to your questions.
• Page 1 of 2
1) We conducted a SIBHP test on 5/29/08 and determined the BHP at mid perf to be 1819 psi. From this the KWF
was determined to be 9.6 ppg. Sorry for not including that.
2) The 11" 5M BOPE w/ 3.5" rams will be tested to 250/2500 psi.
3) Following a conversation with Brett, he pointed out to me that the initial MITIA was to 2000 psi. I changed the
IA test pressure to 2000 psi. But I believe that the Sundry procedure was submitted prior to that conversation.
I have attached a revised copy of the procedure with needed correction. Please let me know if you have any other
questions for me.
Thanks,
Cody Gauer
From: Ennis, J J
Sent: Wednesday, June 11, 2008 1:16 PM
To: Gauer, Cody
Cc: 'Maunder, Thomas E (DOA)'
Subject: FW: 1D-130 (197-183)
Cody,
Message from Tom Maunder below.
Jim Ennis
j j.ennis@conocophillips.com
(907)265-1544 (VV)
(907) 632-7281 (C)
From: Maunder, Thomas E (DOA,_,~tna~-e--.
Sent: W ,es , 2008 1:13 PM
6/12/2008
~~
Maunder, Thomas E (DOA)
From: Maunder, Thomas E (DOA)
Sent: Wednesday, June 11, 2008 1:13 PM
To: 'Ennis, J J'
Cc: 'Gober, Howard'
Subject: 1 D-130 (197-183)
Jim,
Would you forward to Cody. I don't have his eddress.
Cody,
I am reviewing the sundry for 1 D-130 and have a couple of questions ...
Page 1 of 1
1. Do you have an estimate of the BMP and KW fluid?
2. What is the proposed BOP test?
3. You propose to only test the IA to 1500 psi. For the last MIT performed in
July 2006, the initial pressure was 2000 psi.
Call or message with any questions.
Tom Maunder, PE
AOGCC
Ell 1/2008
_ __ _ ESL LOG
~ _, / ~4L
._-,
ProActive Diagnostic Services, Inc.
To: ACGCC
Christine Mahnken
333 West 7th Avenue
Suite 100
Anchorage, Alaska 99501
(907J 659-5102
u
RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTTJ
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 ~~~~~~ ~U~ ZQQ$
Suite C
Anchorage, AK 99518
Fax (907j 245-8952
L1) Caliper Report
/2j Caliper Report
23-May-08
29-May-08
2Q06B 1 Report / EDE 50-029-21168-02
1x130
v~.c ~9~ _r~3 r ~3~~~
~Y ,
Signed : Y
Print Name: C~~~~~n,~c>. 1 Vt~tw w{Q,~,
1 Report / EDE 50-029-22815-00
Date
PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518
PHONE: (907)245-8951 FAx: (907)245-88952
E-MAIL _ ~..;c- ~ - WEBSITE . ,_-- -_- - ..:z'J
C:\Document5 and Settings\Owner\Desktop\Transmit_Conoco.doc
• •
Memory Mufti-Finger Caliper
j Log Results Summary
Company: _-
ConocoPhillips Alaska, Inc.
Well:
1D-130
Log Date: May 29, 2008 Field: Kuparuk
Log No.: 7236 State: Alaska
Run No.: 1 API No.: 50-029-22815-00
Pipet Desc.: 3.5" 9.3 Ib. L-80 EUE-MOD Top Log Intvl: Surface
Pipet Use: Tubing Bot. Log Intvl: 4,100 Ft. (MD)
Pipet Desc.: 3.5" 9.3 Ib. L-80 Top Log Intvl: 4,092 Ft. (MD)
Pipet Use: Liner Bot. Log Intvl: 4,292 Ft. (MD)
Inspection Type : Corrosive ~ Mechanical-Damage Inspection
COMMENTS
This caliper data is tied into the Tubing Tail (4,100).
This is the first time a PDS caliper has been run in this well. This log was run to assess the tubing for
corrosive and mechanical damage. The caliper recordings indicate the 3.5"tubing is in good to poor
condition with respect to corrosive damage. Maximum recorded penetrations are in excess of 40% in every
joint below _1,450', with a maximum wall penetration of 85% recorded in joint 125.3 (3,996'). The damage
appears in the form of a deep line of pits and corrosion from -1,300' to the bottom of the tubing, with areas of
Less severe general corrosion, and isolated pitting recorded above 1,300'. No sign cant areas of cross-
sectional wall loss (> 12%) are recorded. Deposits restrict the I.D. to 2.74" in joint 127 (4,071'}.
The caliper recordings indicate the 3.5" liner logged is in poor condition with respect to corrosive damage.
The caliper recordings indica#e a maximum wall penetration of 76% in joint 128 (4,123') throughout the liner
logged. The damage appears in the form of scattered pits. No significant areas of cross-sectional wall loss (>
11°~) or I.D. restrictions are recorded (< 2.73")throughout the liner logged.
3.5" TUBING -MAXIMUM RECORDED WALL PENETRATIONS
Line Corrosion (85%) Jt. 125.3 ~ 3,996 Ft. (MD)
Line Corrosion (84%} Jt. 117 @ 3,689 Ft. (MD)
Line Corrosion (83%) Jt. 119 @ 3,776 Ft. (MD)
Line Corrosion (80%) Jt. 127 @ 4,054 Ft. (MD)
Line Corrosion (76%) Jt. 123 @ 3,901 Ft. (MD)
3.5" TUBING -MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS
No significant areas of cross-sectional wall loss (> 12%) are recorded.
3.5" TUBING -MAXIMUM RECORDED ID RESTRICTIONS
Deposits Minimum LD. = 2.74" Jt. 127 @
No other significant I.D. restrictions are recorded.
~~~~~ JU~I ~ 2008
4,071 Ft. (MD)
ProActive Diagnostic Services, Inc. / P.p. Box 1369~_Stdfford, TX 77497
Phone: (281) or (888) 565-9085 Fax: (281`) 5~5-1369 E-mail: PDS@memoryfog.com
Prudhoe Bay Field Office Phone: (907) 559-2307 Fax: (907) 659-2314
(~G t q~-- r~3 ~ /(e3~ea
• •
3.5" LINER -MAXIMUM RECORDED WALL PENETRATIONS
Scattered Pits (76%) Jt. 128 @ 4,123 Ft. (MD)
Scattered Pits { 72%) Jt. 129 ~ 4,142 Ft. (MD)
Scattered Pits (67%) Jt. 132 @ 4,256 Ft. (MD)
Scattered Pits (65°~) Jt. 130 ~ 4,173 Ft. (MD)
Scattered Pits (59%) Jt. 131 @ 4,204 Ft. (MD)
3.5" LINER -MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS
No significant areas of cross-sectional wall loss (> 11%) are recorded throughout the liner logged
3.5" LINER -MAXIMUM RECORDED ID RESTRICTIONS
No significant I.D. restrictions (< 2.73") are recorded throughout the liner logged.
Field Engineer: W. McCrossan Analyst: C. Waldrop Witness: R. Ober
ProACtive Diagnostic Services, Inc. J P.O. Box 1369, Stafford, TX 77497
Phane: (281) or (888) 565-9085 Fax: (Z81) 565-1369 E-mail: PDS@memorylog.com
Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314
• •
Correlation of Recorded Damage to Borehole Profile
Pipe 1 3.5 in (23.0' - 4263.9') Well: 1 D-130
Field: Kuparuk
Company: ConocoPhillips Alaska, Inc.
Country: USA
Survey Date: May 29, 2008
A pprox. Tool D eviation ^ A pprox. Boreho le Profil e
28
335
650
965
12 78
1588
1902 ~
c
2214
a
a~
~
2529
2839
3153
3467
3781
GLM 1
41 70
133 4264
0 5 0 1 00
Dam age Pr ofile (% wall) / Tool D eviatio n (degr ees)
Bottom of Survey = 133
1
10
20
30
40
50
60 ~~
~
z 70
c
0
80
90
100
110
120
130
• •
PDS Report Overview
~---~..-_-~~. Body Region Analysis
Well: 1 D-130 Survey Date: May 29, 2008
Field: Kuparuk Tool Type: UW MFC 24 No. 21 1387
Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69
Country: USA No. of I-fingers: 24
__ Analyst: C. Waldrop
Tubing: Norn.OD Weight Grade & thread Nom.ID Nom. Upset Upper ten. Lower ten.
3.5 ins 9.3 f L-80 EUE-MOD 2.992 ins 3.5 ins 6.0 ins 6.0 ins
Penetration and Metal Loss (% wall)
p~- penetration body metal loss body
150
1100
50
0
U to 1 to 1 U to ZU to 40 to over
1% 10% 20% 40% 85% 85%
umber of joints analysed (total = 144)
pene. 0 11 17 23 93 0
loss 3 138 3 0 0 0
Damage Configuration (body )
100
80
60
4i1
20
0
isolated general line ring hole / poss
pitting corrosion corrosion corrosion ible hole
Number of ~oints dama ed total = 130
33 7 90 0 0
Damage Profile (% wall)
~ penetration body metal loss body
0 50 100
n
GLM 1
Bottom of Survey = 133
Analysis Overview page Z
•
PDS REPORT JOINT TABI
Pipe: 3.5 in 9.3 ppf L-80 EUE-MOD Well:
Body Wall: 0.254 in Field:
Upset Wall: 0.254 in Company:
Nominal I.D.: 2.992 in Country:
Survey Date
•
JLATION SHEET
1 D-13 0
Kuparuk
ConocoPhillips Alaska, Inc.
USA
May 29, 2008
Joint
No. Jt. Depth
(Ft.) Pen.
Ul~sc•I
(Ins.l Pen.
Body
(Ins.) I'en.
`%> Mc~ial
I utis
~, Min.
LD.
(Ins.)
Cornrnents Damage Profile
(% wall)
0 50 100
.1 23 a 0.01 t~ 2.89 PUP
1 28 ~I 0.01 b 2.92
1.1 59 l) 0.01 (> i ~ 2.89 PUP
1.2 62 ~~ 0.01 ~~ ~ 2.88 PUP
1.3 64 ~ I 0.02 1 2.93 PUP
1.4 74 t ~ 0.02 ~ -I 2.92 PUP
2 84 n 0.02 ~, 2.91
3 116 t) 0.04 ld ~ 2.93 Shallow ittin
4 147 t~ 0.02 9 ? 2.92
5 17 8 (~ 0.02 ~) 2.92
6 210 +~ 0.03 11 2.92
7 241 ~~ 0.03 i _' 2.93 Shallow ittin
8 272 ll 0.04 14 2.92 Shallow ittin
9 303 ~) 0.02 8 2.93
10 335 (~ 0.03 11 _' 2.93
11 366 ~ ~ 0.03 13 _' 2.92 Shallow ittin
12 398 ~ ~ 0.02 c~ 2 2.92
13 429 ! ~ 0.03 1 i _' 2.91 Shallow Corrosion.
14 461 U 0.03 1 ~ _' 2.92 Shallow ittin
15 492 tl 0.04 15 ~ 2.93 Shallow ittin
16 524 U 0.03 13 2.93 Shallow ittin
17 555 c~ 0.04 15 ? 2.92 Shallow ittin
18 587 U 0.04 15 _' 2.93 Shallow ittin
19 618 l) 0.04 I i _' 2.93 Shallow ittin
20 650 ~~ 0.05 l~l _' 2.93 Shallow ittin
21 682 c1 0.05 '~~ _' 2.93 Shallow ittin
22 71 3 (~ 0.05 ~ I 2 2.92 Isolated ittin .
23 745 ~~ 0.06 _'<' 3 2.92 Corrosion.
24 776 (~ 0.06 1~1 2 2.91 Isolated ittin .
25 808 l) 0.07 _'c> 292 Isolated ittin .
26 839 (~ 0.06 24 ~ 2.93 Isol d it in .
27 871 U 0.07 _'13 2.91 Isolated ittin .
28 902 U 0.06 ' ~ 2.9 Iso to itti
29 934 O 0.09 ~(> -! 2.91 Isolated ittin .
30 965 U 0.08 ~U .91 Isolate itti
31 996 a 0.09 35 2.93 Corrosion.
32 1028 ~~.~~~~ 0.10 39 ~ 92 Iso ed ittin .
33 1059 U 0.08 3Z -~ 2.93 Corrosion.
34 1091 ~~ 0.09 37 ~ 2.92 I la ed ittin .
35 1123 ~~.r1~, 0.10 ;7 2.95 Isolated ittin .
36 1154 tI 0.1 S') rr sion.
37 1185 a 0.10 4t1 2.90 Corrosion. -
3 1216 (~ .11 ~tl ~ 91 I o e itti
39 1246 (1.1)h 0.09 . i ~l 2.91 Isolated ittin .
1 78 U 0.09 t~l 4 2.91 ine orro ion Lt. D sit .
41 1310 i) 0.14 i-1 (, 2.93 Line Corrosion.
4 1341 i~ 0.1 i ~ 3 ine C r ion. -
43 1371 it 0.09 >~> 2.93 line Corrosion.
44 1400 U.l~'r .10 111 I .95 ine Corrosion.
45 1431 i ~ 0.09 2.91 Linc Corrosion.
Penetration Body
Metal Loss Body
Page 1
PDS REPORTJOINTTABULATION SHEET
Pipe: 3.5 in 9.3 ppf L-80 EUE-MOD Well: 1 D-130
Body Wall: 0.254 in Eield: Kuparuk
Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc.
Nominal I.D.: 2.992 in Country: USA
Survey Date: May 29, 2008
Joint
No. Jt. Depth
(Ft) Pen.
UI~Set
(Ins.) Pen.
Body
(Ins.) I'en.
°i~ Metal
I~~ss
°~~~ Min.
LD•
(Ins.)
Comments Damage Profile
(%wall)
0 50 100
46 1462 t) 0.11 43 i 2.92 Line Corrosion.
47 1494 t) 0.13 50 6 2.93 Line Corrosion. -
48 1524 t~.tu, 0.12 47 4 2.90 Line Corrosion. Lt. De osits.
49 1556 U 0.13 5U (, 2.92 Line Corrosion.
50 1588 t).u? 0.11 -ta ~ 2.94 Line Corrosion.
51 1619 U 0.12 ~8 `~ 2.93 Line Corrosion.
52 1651 O.1 t) 0.11 44 t> 2.93 Line Corrosion.
53 1682 U.lu> 0.13 i 3 5 2.93 Line Corrosion.
54 1714 i ).1 U 0.11 45 (, 2.93 Line Corrosion.
55 1745 i).U6 0.11 -14 (, 2.9 Line Corrosion. Lt. De sits. -
56 1777 U.t)t3 0.12 =18 i~ 2.96 Line Corrosion.
57 1808 l) 0.14 54 f, 2.93 Line Corrosion.
58 1839 ~L~)b 0.12 ~~) i> 2.92 Line Corrosion.
59 1871 l).t)~) 0.13 53 i 2.93 Line Corrosion.
60 1902 U 0.17 E,f3 t, 2.92 Line Corrosion.
61 1932 t) 0.16 62 t, 2.93 Line Corrosion.
62 1964 t).1~7 0.14 54 (, 2.93 Line Corrosion.
63 1995 i) tt`) 0.15 5t3 - 2.96 Line Corrosion.
64 2026 O.U6 0.13 ~1 t~ 2.94 Line Corrosion.
65 2058 U.t)b 0.14 5~1 6 2.94 Line Corrosion.
66 2089 U.t)5 0.14 56 ~ 2.95 Line Corrosion.
67 2121 U.ttt3 0.12 ~~) t, 2.93 Line Corrosion.
68 2152 U.t)~) 0.14 i-1 t, 2.94 Line Corrosion.
69 2183 U.1)3 0.12 -1~) - 2.96 Line Corrosion.
70 2214 U 0.18 '._' ~~ 2.92 Line Corrosion. t. De sits.
71 2246 t).U- 0.12 4E, t~ 2.96 Line Corrosion.
72 2277 U.t); 0.12 4~) r, 2.96 Line Corrosion.
73 2309 c) 0.14 5;' !, 2.91 Line Corrosion. Lt. De osits.
74 2341 O.U6 0.13 5Z i, 2.96 Line Corrosion.
75 2371 l).U~? 0.13 iu t, 2.94 Line Corrosion.
76 240 .U8 0.14 55 t, .93 Lin Corrosi
77 2434 U.t)tt 0.15 5i 2.96 Line Corrosion.
78 246 U.t15 0.1 a~i - 2 93 Lin orr Sion. Lt. e osits.
79 2497 l) 0.12 d% i~ 2.96 Line Corrosion.
80 25 9 U.l)Ei 0.12 -tt~ t, 2.94 Line Corrosion.
81 2559 U. I Z 0.14 5~ t, 2.92 Line Corrosion. -
82 2590 l).1)t3 0. 5 5th t, 2.9 Line C rrosio .
83 2622 t) 0.13 53 t, 2.95 Line Corrosion.
84 2652 U.t)t3 0.16 t,l t, .93 Line Corrosion.
85 2684 t).t)ti 0.14 i4 h 2.91 Line Corrosion. -
86 2715 l) 0.13 5U ~t Lin orros'on. --
87 2746 U 0.15 bU 2.93 Line Corrosion. Lt. De osits.
88 2777 t).Utj 0 14 55 7 .94 ~ e C rr sio .
89 2808 ().Ill 0.15 `i') 2.96 Line Corrosion.
90 2839 U 0.14 '>-t - 2.93 i e Corrosion. Lt. De os~ts.
91 2871 l).U- 0.13 ~~_' !, 2.95 Line Corrosion.
9 2903 O.Ufi 0.13 i2 i, 2.95 Line rr si n.
93 2934 !) 0.11 41 - 2.93 Line Corrosion. -
94 2965 ! ~ ~~) ~ .13 5~ ~, 2.92 Line Corros on. - -
95 2996 + ~~ ; ~~ ~ 0.15 !,t) 2.92 Linc Corrosion. ~ `'
_ Penetration Body
Metal Loss Body
Page 2
• •
PDS REPORT JOINT TABULATION SHEET
Pipe: 3.5 in 9.3 ppf L-80 EUE-MOD Well: 1 D-130
Body Wall: 0.254 in Field: Kuparuk
Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc.
Nominal I.D.: 2.992 in Country: USA
Survey Date: May 29, 2008
Joint
No. Jt. Depth
(FL) I'~~n.
(!I„~~!
f,lns.i Pen.
Body
(Ins.) Pen.
% Mt~t.il
Iosti
",'~, Min.
LD•
(Ins.)
Comments Damage Profile
(%wall)
0 50 100
96 3028 (i.n0 0.17 66 (~ 2.95 Line Corrosion.
97 3059 ti.n 0.15 58 (, 2.93 Line Corrosion.
98 3090 (t.t); 0.18 69 b 2.93 Line Corrosion. Lt De sits.
99 3122 t).1 U 0.15 57 ~ 2.94 Line Corrosion.
100 3153 U.1 1 0.15 6U +, 2.93 Line Corrosion. -
101 3185 O.l)£S 0.14 5~ !, 2.95 Line Corrosion.
102 3215 t) 0.13 5Z - 2.93 Line Corrosion. -
103 3247 U.(i9 0.15 57 ~) 2.94 Line Corrosion. -
104 32 79 U. l ~' 0.16 (i 1 ~ 2.92 Line Corrosion.
105 3310 t) 0.14 5i C, 2.93 Line Corrosion. Lt. De sits. -
106 3342 U.t)Y> 0.15 5£3 7 2.92 Line Corrosion.
107 3373 tl.!) 0.18 ~ 1 £~ 2.94 Line Corrosion.
108 3404 u.l I 0.13 5'I £; 2.93 Line Corrosion. -
109 3436 11.1) 0.15 5' 2.93 Line Corrosion.
110 3467 l).l 3 0.15 i`I 2.93 Line Corrosion. -
111 3499 U.tl: 0.17 ~!~ '~ 2.93 Line Corrosion. -
112 3530 U.!1~ 0.19 74 9 2.91 Line Corrosion. Lt. De osits. -
113 3561 U.11b 0.17 6ti ti 2.92 Line Corrosion.
114 3593 t1 0.18 ~ 1 I_ 2.92 Line Corrosion.
115 3625 U.O'1 0.17 66 ~i 2.95 Line Corrosion.
116 3656 t1. I ' 0.19 74 8 2.92 Line Corrosion. Lt De osits. -
117 3687 !~ 0.21 £34 7 2.92 Line Corrosion. Lt. De sits. -
118 3718 11.t)£i 0.18 70 2.94 Line Corrosion.
119 3749 U 0.21 83 £3 2.93 Line Corrosion. Lt. De sits.
120 3781 t~.t)~) .18 ?t) £~ 2. 6 Line C rrosion. -
121 3812 ! ~ 0.18 ; ~> ') 2.91 ine Corrosion.
122 3844 i? 0.17 69 7 2.93 Line Corrosion.
123 3875 u.Ub 0.19 ?V £3 2.93 Line Corrosion.
124 3907 U 0.18 ^2 '! 2.95 Line Corrosion.
125 3938 O 0.18 ;'t) 2.93 Line Corrosion. Lt. De sits.
125.1 970 U 0.18 69 £; .95 PUP ine Corrosion.
125.2 3985 U 0 U U N A GLM 1 Latch @ 12:30
25. 399 (1.119 0.22 £;5 ~1 .9 L'ne o rosin L D osits. r
126 4007 U 0.17 1,') 2.92 Line Corrosion. Lt De osits.
26 1 4038 U 0.03 1 t 1 2.9 U
126.2 4044 U 0 l! !) 2.81 Ni e
126.3 4046 t).13 0.12 4E~ -£ 90 PUP i e rro io Lt. e sits.
127 4050 t1 0.20 80 lu 2.74 line Corrosion. De sits.
127.1 4081 c1. I t~ 06 23 I 92 UP I olated ~t i Lt. De si s.
127.2 4087 !~ 0 t) U 4.00 PBR
1 7.3 4100 t1 .05 lt3 _' 2.9 P allow it in t. De sits
128 4107 tLt?- 0.19 '(> (, 2.87 Liner Perforations. Scatd. Pits.
1 9 4 8 t1.1 I 0.18 i1 i 2.91 L' r Perforations. Scatd. Pi
130 4170 a 0.17 +, ~ ~, 2.89 Liner Perforations. Scatd. Pits.
131 4 01 U.Ut~ 0. 5 i~+ - 2. 8 Liner Perforations. Scatd. Pits. -
132 4232 t1.t)- 0.17 ~„~ ~ I 2.76 Liner Perforations. Scatd. Pits. -
13 4264 !1.n4 0.14 5-1 I I 2.7 finer Perf rations. Scatd. Pits.
_ Penetration Body
Metal Loss Body
Page 3
~, ~„ PDS Report Cross Sections
t ---
Well: 1 D-130 Survey Date: May 29, 2008
Field: Kuparuk Tool Type; UW MFC 24 No. 211387
Company: Conoco Phillips Alaska, Inc. Tool Size: 1.69
Country: USA No. of Fingers; 24
Tubin 3.5 ins 9.3 f L-80 EUE-MOD ___ Analyst; C. Waldron
Cross Section for Joint 125.3 at depth 3996.233 ft
Tool speed = 43
Nominal ID = 2.992
Nominal OD = 3.500
Remaining wall area = 90
Tool deviation = 7 °
Finger 12 Penetration = 0.215 ins
Line Corrosion 0.22 ins = 85% Wall Penetration HIGH SIDE = UP
•
Cross Sections page 1
~~ ,~~ PDS Report Cross Sections
Well: 1 D-130 Survey Date: May 29, 2008
Field: Kuparuk Tool Type: UW MFC 24 No. 211387
Company: Conoco Phillips Alaska, Inc. Tool Size: 1.69
Country: USA No. of Fingers: 24
Lubin 3.5 ins 9.3 f L-80 EUE-MOD _ __ _ Analvst: C. Waldron
Cross Section for Joint 117 at depth 3689.153 ft
Tool speed = 43
Nominal ID = 2.992
Nominal OD = 3.500
Remaining wall area = 94
Tool deviation = 25 °
Finger 9 Penetration = 0.214 ins
Line Corrosion 0.21 ins = 84% Wall Penetration HIGH SIDE = UP
•
•
Cross Sections page 2
~~ ~~ PDS Report Cross Sections
Well: 1 D-130 Survey Date: May 29, 2008
Field: Kuparuk Tool Type: UW MFC 24 No. 211387
Company: Conoco Phillips Alaska, Inc. Tool Size: 1.69
Country: USA No. of Fingers: 24
Tubin 3.5 ins 9.3 f L-80 EUE-MOD Anal st: C. Waldro
Cross Section for Joint 127 at depth 4070.613 ft
Tool speed = 43
Nominal ID = 2.992
Nominal OD = 3.500
Remaining wall area = 100
Tool deviation = 9 °
Finger 9 Projection = -0.228 ins
Deposits Minimum I.D. = 2.74 ins HIGH SIDE = UP
•
Cross Sections page 3
ConocoPhillips Alaska, Inc.
• KRU 1D-130
10-130
API: 500292281500 Well T INJ An le TS: d
SURFACE
(0.2527 SSSV T
Annular Fluid: NONE Ori Com lotion:
Last W/O: 11/8 /1997 An le TD:
Rev Reason: 3 d 4778
GLV ClO, SET PLUG,
TAG FOUND LEAK
,
00:7.625 Reference L Ref L Date: Last U date: 4/13/2008
,
Wt:29.70) Last Ta : 4290' TD: 4778 ftK6
Last Ta Date: 4192008 Mex Hde An le: 43 d 2896
Cesin Stri - ALL ST RINGS
TUBING Descri lion Size To Bottom TVD Wt Grade Thread
(0.4100, CONDUCTOR 16.000 0 121 121 62.50 H-00
00:3.500, SURFACE 7.625 0 2527 2238 29.70 L~0
10:2.438) r _ PRODUCTION 5.500 0 4092 3573 15.50 L$0
- I PRODUCTION 3.500 4092 4768 4247 9.30 L$0
J Tubin Strin - TUBING
Size To Bo ttom TVD Wt G rade Thread
3.500 0 4100 3581 9.30 L-80 EVE MOD
' Pertorations S ummer
RODUCTION
(o-ao92 Interval TVD Zone Status Ft SPF Date T e Comment
,
00:5
500 4108 - 4110 3589 - 3591 2 4 11/11/1997 I PERF 180 d 2.5" HSD DP
.
,
Wt:15
50) 4128 - 4130 3609 - 3611 2 4 11/11/1997 IPERF 180 2.5" HSD DP
. 4152 -4154 3633 - 3635 WS 0 Zone D 2 4 11/11/1997 I PERF 180 h 2.5" HSD DP
4164 - 4180 3645 - 3661 WS D Zone D 16 4 1/19/1998 IPERF 180 d h~ 90 d Orient 2.5"HSD
4192 - 4194 3673 - 3675 WS C Zone C 2 4 11/11/1997 IPERF 180 d h 2.5" HSD DP
4207 - 4210 3688 - 3691 WS B Zone B 3 4 1!19!1998 IPERF 180 h' 90 Orient 2.5°HSD
SEAL ASSV 4210 - 4212 3691 - 3693 WS B Zone B 2 8 1!19!1998 IPERF 180 h' 90 Orient 2.5"HSD
(4087 4099 4212 - 4241 3693 - 3722 WS B Zone B 29 4 1/19!1998 I PERF 180 ~ 90 Orient 2.5"HSD
00:3.500) 4246 - 4248 3727 - 3728 WSA4 Zone A4 2 4 11/11!1997 IPERF 180 2.5" HSD DP
4251 -4256 3731 -3736 WSA4 Zone A4 5 4 1/19!1998 I PERF 180 d h' 90 Orient 2.5"HSD
~~ 4256 - 4262 3736 - 3742 WSA4 Zone A4 6 4 1/17/1998 I PERF 180 d h' 90 d Orient 2.5"HSD
4262 - 4264 3742 - 3744 WSA4 Zone A4 2 8 1/17/1998 I PERF 180 d h' 90 d Orient 2.5"HSD
4264 - 4276 3744 - 3756 WSA4 Zone A4 12 4 1/17/1998 IPERF 180 d h' 90 Orient 2.5`HSD
PBR 4278 - 4280 3758 - 3760 WSA4 Zone A4 2 4 11/10/1997 IPERF 180 d h 2.5" HSD DP
(4092-4104, 4295 -4298 3775 - 3778 WS A3 Zone A3 3 4 1/17/1998 I PERF 180 h~ 90 d Orient 2.5"HSD
00:5.500) 4298 - 4300 3778 - 3780 W S A3 Zone A3 2 8 1/17/1998 I PERF 180 d ~ 90 Orient 2.5"HSD
4300-4301 3780-3781 WS A3 Zone A3 1 4 1/17/1998 I PERF 180 h~90d Orient 2.5"HSD
4310 - 4342 3790 -3822 WS A3 Zone A3 32 4 1/17/1998 I PERF 180 ~ 90 d Orient 2.5"HSD
4354 - 4356 3834 - 3836 W S A3 Zone A3 2 4 11/10/1997 IPERF 180 d h 2.5" HSD DP
TTL 4365 - 4370 3845 - 3850 WS A2 Zone A2 5 4 1/1711998 IPERF 180 d h' 90 Orient' 2.5"HSD
(4100-4101• 4380 - 4392 3860 - 3872 WS A2 Zone A2 12 4 1117/1998 IPERF 180 d h' 90 d Orieni~ 2.5'HSD
00:3.500) 4392 - 4394 3872 - 3874 WS A2 Zone A2 2 8 1/17/1998 IPERF 180 d h' 90 d Orient 2.5"HSD
4394 -4402 3874 - 3882 WS A2 Zone A2 8 4 1/17/1998 I PERF 180 ~ 90 d Orient 2.5"HSD
4402 -4404 3882 -3884 WS A2 Zone A2 2 8 1/17/1998 IPERF 180 d h' 90 Orient 2.5°HSD
Pert 4404 -4420 3884 - 3900 WS A2 Zone A2 16 4 1/17/1998 IPERF 180 d h' 90 d Orient 2.5"HSD
(4708-4110) 4430 -4432 3910 - 3912 WS A2 Zone A2 2 4 11/10/1997 IPERF 180 2.5" HSD DP
4440 -4452 3920 - 3932 WS A2 Zone A2 12 4 1!17!1998 A PERF 180 d h' 90 Orient 2.5"HSD
4462 -4464 3942 - 3944 WS A2 Zone A2 2 4 11/10/1997 I PERF 180 2.5° HSD DP
RODUCTICNJ 4490 -4492 3970 - 3972 WS Al Zone At 2 4 11/10/1997 IPERF 180 2.5" HSD DP
(4092-4768 4594 - 4596 4073 - 4075 2 4 11/10/1997 I PERF 180 2.5" HSD DP
,
oD:3.soo, Gas Lift Mendr elsNalve s
vt/ts.3o> St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv
Cmnt
Pert 1 3985 3467 BST AXT DMV 1.0 T-1 0.000 0 4/10/2008
(4152-4154) Other lu s ui .etc . -JEWE LRY
Pert
4164
4180 De th TVD T e Descri lion ID
(
-
) gOgq 3525 NIP Camco'W-1' Bore 2.813
4044 3525 PLUG 2.81" MA-2 PLUG set 4!102008 0.000
4087 3568 S EAL ASSY Baker 80-00 G BH-22 LOCATOR SEAL ASSEMBLY STABBING IN TO PR OD CS G PBR 3.000
4092 3573 PBR 3.5" PROD CS G POLISHED BORE REC EPTA CLE CEMENTED I N TO R ECEN E 3.5° TUBING 4.000
4100 3581 TTL 2.441
Pert General Notes
(4210-0212) Dale Note
Pert 4/11/2008 NOTE: LEAK FOUND 4002' WLM
(4207-4241)
Pert
(4246-4248)
Pert
(4251-4256)
Pert
(4354-4356)
Pert
(4365-4370)
Pert
(4380-4420)
Pert
(4402-4404)
Pert
(4430-4432)
Pert
(4440-4452)
Pert
(4462-4464)
Perf
(4594-4596)
-
~i~1~~G~fi~
Schlumberger -DC5
2525 Gambell Street, Suite 400
Anchorage, AK 99503-2838
ATTN: Beth
Well Job #
~~-
~~~:~~~~~ MAY ~ 2 200$
Log Description
-._
Date
NO.4678
Company: Alaska Oil & Gas Cons Comm.
Attn: Christine Mahnken
333 West 7th Ave, Suite 100
Anchorage, AK 99501
Field: Kuparuk
BL Color CD
04/30/08
3K-102 NA PRODUCTION PROFILE 04/08/08 1 1
1 E-04 11996622 LDL ~ ~_ p - C{ 04/16/08 1 1
2U-13 11996617 PRODUCTION PROFILE - a~ 04/10/08 1 1
2W-17 11996618 SFRT - 04/12/08 1 1
2L-330 11970662 PERF/SBHP V _ ~ 04!19!08 1 1
3F-18 11970666 LDL - C 04!23!08 1 1
iD-130 11964595 LDL -C ~- 04/23/08 1 1
iY-07 11964596 INJECTION PROFILE - ~ / ~ 04/24/08 1 1
2T-217A 11970667 INJECTION PROFILE ..p 6(0 (~ 04!24108 1 i
1 F-05 11964597 INJECTION PROFILE / ~nj ~ 04/25/08 1 1
3K-102 12021157 MEM PROD PROFILE j 04/26/08 1 1
1 L-09 11970669 PRODUCTION PROFILE t/ 04/26/08 1 1
Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you.
•
•
ID-130 (PTD 197-183} Report Of Suspected T X IA Communication • Page 1 of 1
Regg, James B (DOA) •
From: NSK Problem Well Supv [n1617@conocophillips.com]
Sent: Thursday, April 03, 2008 5:00 PM ~
To: Regg, James B (DOA); Maunder, Thomas E (DOA) ~~~~(~ ~ ~ ~ ~ ~
Cc: NSK Well Integrity Proj; NSK Problem Weli Supv; NSK West Sak Prod Engr
Subject: 1 D-130 (PTD 197-183) Report Of Suspected T X IA Communication
Attachments: 1 D-130 Wellbore Schematic.pdf; 1 D-130 TIO Plot.jpg
West Sak water injector 1 D-130 (PTD 197-183) was reported to have TxIA communication on 04/01/08. The Drillsite
Operator had to bleed the IA three times in the past week and the TXIA communication was confirmed on 04/03/08. The
TIO prior to the IA bleed was 933!1086/150. The immediate action taken was to bleed the IA down and shut the well in.
Further diagnostics will include an MITIA.
Pending the outcome of the initial diagnostics, it is ConocoPhillips intention to proceed with a 10-403 sundry for repair or
workover. The well will be also added to the monthly failed MIT report. --~
..-
Attached is a schematic and a 90 day TIO plot. "~
«1 D-130 Wellbore Schematic.pdf» «1 D-130 TIO Plot.jpg»
Please contact me at your convenience if you have any questions or comments.
Martin Walters / Brent Rogers
Problem Wells Supervisor
ConocoPhillips Alaska Inc.
Office 907-659-7224
Cell 907-943-1720 / 1999 ~ MAY ~ ~ 200$
Pager 907-659-7000 #909
4/24/2008
KRU 1 D-130
PTD 197-183
Tll/t~ Plat - '1 C~-~ ~0
1 OOt~
?S~~
~~~
~~~
200
~ -+-F-~
03-Jan-08
18-Jan-08 29-Jan-O$ 11-Feb-O$ 24-Feb-O$
Date
08-Mar-08 21-Mar-08
200
1~0
t~.7.
100 ~
L
~JO
•
KRU
Conacc~P~llips Alaska, ln~.
~D-130
'
API: bUUL92Y815UU v~il T e: INJ
b An le a~ TS: de
SSSV T e: NONE Ori Cpm letion: 11!811997 An le TD: 3 de
Annular Fluid: Last W/O: Rev Reason: Shov
SURFACE Reference Lo Ref l.o Date: Last U date: 5/21/
(0-2527, Last Ta : 4320 TD: 4778 ftK6
OD:7.625, Last Tag DatP~ ~ior?~~g Max Hole Annle: 43 degn 2896
wezs.7o> Casing String -ALL STRINGS
TUBING
(0-0100,
OD:3.500,
ID:2.438)
'RODUCTION
(0 3092,
OD:5.500,
Wt:15.50)
NIP
(404411045,
OD:3.500)
SEALASSY
(40873088,
OD:3.500)
TiL
(4100-4101,
OD:3.500)
'RODUCTION
(4092-4768,
OD:3.500,
Wt:9.30)
Pert
(4108-4110)
Perf
(4152-4154)
Pert
(41643180)
Pert
(42103212)
Pert
(4207-4241)
Ped
(43543356)
Perf
(4365-4370)
Pert
(4402-4404)
Perf
(438011420)
Descri lion Size To Bottom TVD Wt Grade Thread
CONDUCTOR 16.000 0 121 121 62.50 H-40
SURFACE 7.625 0 2527 2238 29.70 L-80
PRODUCTION 5.500 0 4092 3573 15.50 L-80
PRODI ICTInN 7 Fn0 dn92 d7RR d9d7 R 3n t _Rn
---
- Gas Lit MandrelsNalves
_. _ _ _. _
St I MD TVD Man Mfr Man Type I v Mfr I V Type V OD Latch I Port TRO Date Run Cmnt
~ 1 r 3985 3467. BST
Other (plugs, equip., etc
De th TVD T e AXT DMY 10_ T-1 0.000 0 11!7/1997
.) -JEWELRY
Descn lion -~
ID
_= = 4044 3525 NIP Camco'W-1' Bore 2.813
~~ 4087 3568 SEAL ASSY Baker 80-40 GBH-22 3.000
--
,.... 4100 3581 TTL 2.441
_
1 D-130
Perf
(4594-4596)
_ _
Tubin Strin -TUBING
_ _. _ _ -
Size To Bottom T`JD Wt Grade Thread
3.500 0 4100 .1 3t ~ ~ GLiE P:10D
Perforations Summary
.
.
Conoc;p.,illips
Alaska
RECEIVED
JUL 1 0 Z007
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
Alaska Oil & Gas Cons. Commission
Anchorage
July 6, 2007
Mr. Tom Maunder
Alaska Oil & Gas Commission
333 West 7th Avenue, Suite 100
Anchorage, AK 99501
sCANNED JUL 1 1 2007
\'03
,0\1"
Dear Mr. Maunder:
Enclosed please find a spreadsheet with a list of wells ftom the Kuparuk field (KRU). Some of
these wells were found to have a void in the conductor by surface casing annulus. The voids that
were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The
remaining volume of annular void subsequently was filled with a corrosion inhibiter engineered
to prevent water ftom 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 M.J. Loveland at 907-659-7043, if you have any questions.
.~~
M.%
ConocoPhillips Well Integrity Project Supervisor
__,c<
---
.
.
ConocoPhillips Alaska Inc.
Suñace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off
Corrosion
Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/
Well Name pro # cement pumped cement date inhibitor sealant date
ft bbls ft Qal
1 0-09 198-065 23" na 5 6/9/2007
10-101 200-183 2" na 3.2 6/9/2007
10-102 200-075 2" na 3.2 6/9/2007
10-103 202-096 5" na 8 6/9/2007
1O-105a 201-202 25" na 38 6/912007
10-106 197-240 2" na 3.2 6/9/2007
10-107 200-177 2" na 3.2 6/912007
10-108 198-187 8" na 12.8 61912007
10-113 198-178 2" na 1 6/912007
10-114 198-159 2" na 1 6/912007
10-115 197-232 2" na 1 6/912007
10-116 198-172 2" na 1 6/912007
10-117 197-237 2" na 1 6/912007
10-118 197-229 2" na 1 6/912007
10-119 197-222 2" na 1 6/912007
10-122 198-149 2" na 1 6/912007
10-123 198-170 2" na 1 6/912007
1O-125a 200-044 2" na 1 6/912007
10-126 198-108 2" na 1 6/9/2007
10-127 198-109 8" na 2.5 6/9/2007
10-128 198-133 2" na 1 6/912007
10-129 197-213 2" na 1 6/9/2007
10-130 197-183 23" na 5 619/2007
Kuparuk Field
June 9,2007
Company: Alaska Oil & Gas Cons Comm
Attn: Christine Mahnken
333 West 7th Ave, Suite 100
Anchorage, AK 99501
Field: Kuparuk
.
Date BL Color CD
RECEIVED
A,U 11 () \') 2006
08/01/06
Scblumbepgep
~ Oii & Gas Cons. Corr~
A.nchorage
Schlumberger -DCS
2525 Gambell Street, Suite 400
Anchorage, AK 99503-2838
ATTN: Beth
_,' '\-"~i !\1ìl': 1/1;
'St.;t\Ni\Ü:J", ,"IV ! .~
NO. 3899
()':¡: C- 1 c} '1- -{ i3
Well
Log Description
Job#
1J-101 (REDO) 40012836 MD & TVD VISION RESISTIVITY 12/20/05 2 1
1 D-125A (REDO) 11213778 INJECTION PROFILE 07/17/06 1
2K-24 (REDO) 11213781 INJECTION PROFILE 07/20/06 1
1 G-05 11249932 INJECTION PROFILE 07/28/06 1
3A-08 11249933 PROD PROFILE W/DEFT 07/29/06 1
1 D-117 11216305 INJECTION PROFILE 07/08/06 1
3F-18 11235384 SBHP SURVEY 07/25/06 1
3F-17 11235383 BHP SURVEY 07/25/06 1
1Y-32 11213707 SBHP LOG 07/25/06 1
3G-25X 11216313 PROD PROFILE W/DEFT 07/31/06 1
1Y-24A 11216315 GLS/FBHP SURVEY 08/01/06 1
1 R-36 11249931 LDL 07/27/06 1
2V-10 11216311 SBHP SURVEY 07/28/06 1
1 D-1 07 11216309 INJECTION PROFILE 07/12/06 1
1 D-130 11249928 INJECTION PROFILE 07/09/06 1
31-03 11213788 PROD PROFILE W/DEFT 07/26/06 1
1Y -05 11216310 LDL 07/27/06 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
e
State of Alaska
Alaska Oil and Gas Conservation Commission
TO:
J i
J R ./'7 A(" 1/"7,51" ,v,
im egg \ L.;?(¡¿1~ v, ""-,,
P.l. Supervisor ' ( :
DATE: Wednesday, July 12,2006
SUBJECT: Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA INC
1D-130
KUPARUK RIV U WSAK 10-130
,CöQ
\C\\'"
FROM:
Jeff Jones
Petroleum Inspector
Src: Inspector
Reviewed By:
P.I. Suprv-¡g~
Comm
NON-CONFIDENTIAL
Well Name: KUPARUK RIV U WSAK 10-130 API Well Number 50-029-22815-00-00 Inspector Name: Jeff Jones
Insp Num: mitlJ060711175756 Permit Number: 197-183-0 Inspection Date: 7/10/2006
Rei Insp Num
Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
-- IType Inj. I W ! TVD I I
Well I 1D-130 i 3568 IA 180 1990 i 1960 , 1960 i
ì ì
! 1971830 ¡TypeTest : SPT I Test psi ! ! i T ---+-
P.T. 1500 lOA i 140 180 180 175
, , I 950 -¡- I
4YRTST P / Tubing I 950 950 950 I
Interval P/F I i i
Notes 0.6 bbls diesel pumped. 1 well house inspected; no exceptions noted.
~!
Wednesday, July 12,2006
Page I of 1
~~'"<
kf.i?:~)PHllLIPS Alaska, Inc"
~~'$.- A S:.Jl~$ldi<'ü~i <)f' PHIL UPS PETHOLEVM CD~·1P.,)J·f(
TUBING ,·i 1D-130
(0-4100,
00:3.500,
102.438)
PRODUCTION
(0-4092,
00:5,500,
Wt15,50)
NIP
( 4044-4045,
003500)
e
e
KRU
1 D-130
~
:;0"
INJ
11/8/1997
ImO
2896
Wt
62,50
29,70
15,50
9,30
Grade' Thread
H-40
L-80 I
L-80
L-80
Thread
EUE MOD
SEAL ASSY
(4087-4088.
00:3.500)
WSB
TTL WSB
(4100-4101, 4246 - 4248
00:3500) 4251 - 4256
4256 - 4262
Perf 4262 - 4264
(4108-4110)
4264 - 4276
PRODUCTION 4278 - 4280 3758 - 3760
( 4092-4768, 4295 - 4298 3775 - 3778
00:3500,
Wt:930) 4298 - 4300 3778 - 3780
Perf 4300 - 4301 3780 - 3781 WSA3
(4152-4154)
Perf 4310 -4342 3790 - 3822 WSA3
(4164-4180) 4354 - 4356 3834 - 3836 WSA3
4365 - 4370 3845 - 3850 WSA2
4380 - 4392 3860 - 3872 WSA2
Perf 4392 - 4394 3872 - 3874
(4210-4212)
Perf ! 4394 - 4402 3874 - 3882
(4207-4241) 4402 - 4404 3882 - 3884
Perf
( 4246-4248) WSA2
Perf
(4251-4256) WSA2
Perf WSA2
( 4354-4356)
Perf WSA2
( 4365-4370) WSA1
Perf
( 4380-4420) Vlv
Cmnt
Perf
( 4402-4404) ID
Perf
( 4430-4432) I 2,813
3,000
Perf 2441
( 4440-4452)
Perf
( 4462-4464)
Perf
( 4594-4596)
MEMORANDUM
State of Alaska
Alaska Oil and Gas Conservation Commission
THRU: Tom Maunder
P.I. Supervisor
FROM: John Crisp
TO: Camille O. Taylor(~b~ DATE: July 11, 2002
Chair
~.~-
[, /' SUBJECT: Mechanical Integrity Tests
Phillips Alaska
{/3 y ~---~ - ~'~)-~ 1D Pad
1D-10,1D-119,1D-120,1D-130
Kuparuk River Field
Petroleum Inspector Kuparuk River Unit
NON- CONFIDENTIAL
Packer Depth Pretest Initial 15 Min. 30 Min.
We,,I ~D-~O I Type,nj.I s I T.V.D. 16180 I Tubingl 1850 11064 11866 I~ I Interval[ 4
P.T.O.I 1980490 ITypetestl P ITestpsil 1545 I Casingl 0 I 1822 I 17'89 I 1783 I P/F I P
Notes: Rosemount Digital Gauge observed fortest 1 1/2 bbls. Pumped for test pressure.
WellI 1D,t19 ITypelnj. I S I T.V.D. } 3564 I Tubingl 1850 I 1850 I 18'50 I 1850 IlnterVal} 4
P.T.D.I 1972220 ITypetestl P ITestpsil 1500 I Casingl 0 I 17251 1700 I 1690 I P/F I P
Notes: 2 bbls. Pumped for test pressure.
WellI 1D-120 [Typelnj.I N I T.V.D. [ 3590 [TubingI 920 1920 J 890 I 090 [IntervalI 4'
P.T.D.I 1972210 TypetestI P ITestpsil 1500 J CasingI 0 I 1800 I 1750 I 1750 I 'P/F IF,
Notes: 1 1/2 bbls. Pumped for test pressure.
.. Wel!l 1D-130 I Typelnj. I S I T.V.D. I 3568 I Tubingl 900 I 1000 I 1000 } 1000 }InterVal! 4
P.T:D.I 1971830 TypetestI P ITestpsiI 1500 I Casingl ,175 118651182511825. I
p/F IF,
Notes: 1 bbl. pumped for test pressure.
, WellJ [Type Inj.
P.T.D. I I Type test
Notes:
Type INJ. Fluid Codes
F = FRESH WATER INJ.
G = GAS IN J.
S = SALT WATER INJ.
N = NOT INJECTING
4 MIT's witnessed, no failures.
Type Test
M= Annulus Monitoring
P= Standard Pressure Test
R= Internal Radioactive Tracer Survey
A= Temperature Anomaly Survey
D= Differential Temperature Test
Test's Details
Interval
I= Initial Test
4= Four Year Cycle
V= Required by Variance
W= Test during Workover
O= Other (describe in notes)
M.I.T.'s performed: _4
Attachments:
Number of Failures: 0
Total Time during tests: 3 hrs,
cc:
SCANNED AUG 0 i 2002
MIT report form
5/12/00 L.G,
MIT PAl 1D 07-11-02jc.xls
7/24/2002
THE MATERIAL UNDER THIS COVER HAS BEEN
MICROFILMED
ON OR BEFORE
JANUARY 03 2001
P L
M ATE
THIS
W
IA L UNDER
M ARK ER
C:I.,OR]~,,~ILM.DOC
AOGCC Geological Materials Inventory
PER3/HT
97-183 ARCO
Log Data Sent Received
4 ARM CAL ~ 2527-3970 } I/(,/q"~ 2/23/1998 2/26/1998
8193 ~[3/' SPERRY MPT/GRfEWR4 12/10/1997 12/10/1997
CBL ~"'~"3880-4670 J///o?!~ 2/23/1998 2/26/1998
CBL ~ ~:'L/ 21904043 l,//7~77 1/20/1998 1/29/1998
DG~WR4-MD ~B/: 1224778 12/10/1997 12/10/1997
DG~EWR4-TVD ~' 121-4257 12/10/1997 12/10/1997
~ ~'4050-4510 :/'/~ ~ /~' ~3 7/9/1998 7/13/1998
MWD SRVY ~ SPE~Y 0-4778.00 2/13/1998 3/18/1998
MWD SRVY ~-SPE~Y 0-4778. 12/8/1997 12/10/1997
~0-407 Completion Date /1,/5/., :~? Daily well ops / 6/~.,/>/~ Z _ ¢~/f~;"
Are d~ ditch samples required? yes ~ no And received? -~,~~- no
yes 7 no ~alysis description received?
yes ...... no Received? ~~ no
Initial
Was the well cored?
Are tests required?
Well is in compliance
Comments
Box
-r~.~es ......... no
UIC
Wednesday, October 13, 1999 Page I of 1
GeoQuest
500 w. International Airport Road
Anchorage, AK 99518-1199
ATTN: Sherrie
NO. 11326
Company:
Alaska Oil & Gas Cons Comm
Attn: Lori Taylor
3001 Porcupine Drive
Anchorage, AK 99501
7/9/98
Field:
Kuparuk (Reservoir Analysis Logs)
Well Job # Log Description Date BL RF Sepia Floppy
Disk
1 A-20 PRODUCTION PROFILE 980531 I 1
1D-10 ~'CBT 98051 8 I 1
1 D- 124 FLOWING TEMP/PRESS 980524 I 1
1 D- 130 ~ \ (~ --INJECTION PROFILE 980423 I 1
1 D- 133 FLOWING TEMP/PRESS 980524 I 1
1 E-23 ~,\ ~ L.~ - INJECTION PROFILE 980523 I 1
2 A- 17 PRODUCTION PROFILE 98052 2 I 1
2 A- 19 PRODUCTION PROFILE 98051 0 I I
--
2 D- 14 Lk\ ~. _ WATER INJECTION PROFILE 980531 I 1
2 D- 16 Lk ~ C. -.. WATER INJECTION PROFILE 980530 I 1
2 F- 02 {,_k ~ ~ .-WATER INJECTION PROFILE 980528 I 1
2 F- 03 Iv~, ~ C - .WATER INJECTION PROFILE 98052 9 I 1
2 M- 23 TEMPERATURE SURVEY 980507 1 1
3 C- 04 PRODUCTION PROFILE 980505 I 1
3C-04 GAS LIFT SURVEY 980505 I 1
3F-06 GAS LIFT SURVEY 98051 2 I 1
3 F-06 PRODUCTION PROFILE 98051 2 I 1
3 F-14 PRODUCTION PROFILE 98051 4 I 1
3K-27 GAS LIFT SURVEY 980504 I 1
1D-09 ~ CBT 98051 7 I I
cI ~.
SIGNED: . ___
Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you.
DATE:
2/23/98
GeoQuest
500 w. International Airport Road
Anchorage, AK 99518-1199
ATTN: Sherrie
NO. 11853
Company:
Alaska Oil & Gas Cons Comm
Attn: Lori Taylor
3001 Porcupine Drive
Anchorage, AK 99501
Field:
West Sak (Reservoir Analysis Logs)
Well Job # Log Description Date BL
RF Sepia Floppy
Disk
1D-117 ~)- ;;;2~7 -- CEMENT MAP LOG 980126 1 1
1 B- 1 21 ~'~7 -/i~ ! ~ CEMENT MAP LOG 9 8 01 21 I 1
1 D-130 ~7 - ? ~' ~ FOUR ARM CALIPER W/FMS 971 1 05 I 1
,
1 D- 13 0 ~ CEMENT BOND LOG 9 8 01 1 0 1 I
SIGNED'
Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you.
1/20/98
GeoQuest
500 w. International Airport Road
Anchorage, AK 99518-1199
ATTN: Sherrie
NO. 11730
Company:
Alaska Oil & Gas Cons Comm
Attn: Lori Taylor
3001 Porcupine Drive
Anchorage, AK 99501
,Field:
Kuparuk (Reservoir Analysis Logs)
Well Job # Log Description Date BL RF Sepia LIS
Tape
1E-34 '/, "~ ~o,~ O~ 97571 TDTP 971 129, 1
1 E-34 / 97571 TDTP-DEPTH CORRECTED 971 1 29 I 1
1 E-34 / 97571 TDTP BORAX/SPINNER 971 1 29 I 1
1Q-0aA / ~ ~~ 98006 GR/CCL(PDC) 970728 1
3C-05 INJECTION PROFILE 971 21 3 I 1
3C-12 INJECTION PROFILE 9 8 01 0 6 I 1
3 F-01 PRODUCTION PROFILE 9 8 01 0 5 I 1
......
3 F-12 INJECTION PROFILE 971 2 02 I 1
3 F-15 INJECTION PROFILE 971 21 2 I 1
3 H-06 INJECTION PROFILE 971 2 0 5 I 1
'{- 1 5 INJECTION PROFILE 971 2 0 9 I 1
oO-11 , GAS LIFT SURVEY 971 027 I 1
WS 1D-130 ,/' CBT 971107 I I
-I1~
.o~$
,.L~L~
.C~
SIGNED: __ DATE:
Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you.
ARCO Alaska, Inc.
Post Office Box 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
February 13, 1998
Mr. David J. Johnston
Commissioner
State of Alaska
Alaska Oil & Gas Conservation Commission
3001 Porcupine Drive
Anchorage, Alaska 99501
Subject: 1D-130 (Permit No. 97-183) Well Completion Report
Dear Mr. Commissioner:
Enclosed is the well completion report for the completion on West Sak ID-130.
If there are any questions, please call 265-6890.
Sincerely,
T. W. Mc Kay
Senior Drilling Engineer
Kupamk Development
TWM/skad
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
I Status of Well Classification of Service Well ':":'" ? ' "
OIL r--] GAS E~ SUSPENDED r~ ABANDONED~ SERVICE [~ INJECTOR
2 Name of Operator 7 Permit Number
ARCO Alaska, I nc 97-183 ~ -,..., r.:,.: .... : ' '~;"'
3 Address 8 APl Number
P.O. Box 100360, Anchorage, AK 99510-0360 50-029~22815
4 Location of well at surface !:': i:'~i!.i;i..j i 9 Unit or Lease Name
406' FNL, 600' FEL, Sec. 23, T11N, R10E, UM ~,,,~_~..~ .! ~ Kuparuk River Unit
At Top Producing Interval 10 Well Number
1734' FNL, 1583' FEL, Sec. 23, T11N, R10E, UM ! ~;'--''~ i West Sak 1D-130
At Total Depth i · :..:~...~. ~-_~:: 11 Field and Pool
1767' FNL, 1614' FEL, Sec. 23, T11N, R10E, UM KUPARUK RIVER
5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. West Sak Oil Pool
RKB 41', Pad 71'J ADL 25650 ALK 468
12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 115 Water Depth, if offshore 16 No. of Completions
27-Oct-97 05-Nov-97 07-Nov-97I NA feet MSL 1
17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost
4778' MD & 4257' TVD 4703' MD & 4182' TVD YES XL~ NO U NA feet MD 1742' APPROX
22 Type Electdc or Other Logs Run
GR/Res, HSI, SLTJ
23 CASING, LINER AND CEMENTING RECORD
SETTING DEPTH MD I
CASING SIZE W-[ GRADE TOP BTM HOLE SIZE CEMENT RECORD
16' 62.58# H-40 SURF. 121' 24' 9 cu yds High Eady
7.625' 29.7# L-80 SURF. 2529' 9.875' 462 sx AS Lite, 293 sx Class G
5.5' 15.5# L-80 SURF. 4092' 6.75' 175 sx Class G
3.5' 9.3# L-80 4092' 4768' 6.75'
24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD
interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD)
3.5' 4100'
4144'-4180' MD 3626'-3661'TVD 4400'-4420' MD 3880'-3900'TVD
4207'-4241' MD 3688'-3722' TVD 4430'-4432' MD 3910'-3912' 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC
4251'-4256' MD 3731'-3736' TVD 4440'-4452' MD 3920'-3931' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED
4322'-4342' MD 3802'-3822' '['VD 4462'-4464' MD 3942'-3944' TVD
4354'-4356' MD 3834'-3836' 'rVD 4490'-4492' MD 3970'-3972' TVD
4365'-4370' MD 3845'-3850' TVD 4594'-4596' MD 4073'-4075' 'I-VD
4380'-4400' MD 3860'-3880' TVD 4 spf I
27 PRODUCT,ON TEST R I I k I A I
Date First Production Method of OperationiNJECToR(FIowing, gas lift, etc.) U I ~1~ I 1 ~1~ ~ L
Date of Test Hours Tested PRODUCTION FO OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE J GAS-OIL RATIO
I
TEST PERIOI:
Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr)
Press. 24-HOUR RATE: 20°
28 CORE DATA
Bdef description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips.
N/A
Form 10-407 Submit in duplicate
Rev, 7-1-80 CONTINUED ON REVERSE SIDE
29. 30.
GEOLOGIC MARKERS FORMATION TESTS
NAME Include interval tested, pressure data, all fluids recovered and gravity,
MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase.
Top West Sak Sand 4144' 3625'
Base West Sak Sand 4583' 4062'
Annulus left open - freeze protected with diesel.
p~.i'..?-..~:~':'¥-~' '''~'' '-~ :i~.~:' ~;~'I,~,?~'3~ ~' '" ..... -'
31. LIST OF ATrACHMENTS
Summary of Daily Drilling Reports, Directional Survey
32. 1 hereby ceftin that the foregoing is true and correct to the best of my knowledge.
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 only 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 cement-
ing and the location of the cementing tool.
Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In-
jection, Gas Injection, Shut-in, Other-explain.
Item 28: If no cores taken, indicate "none".
Form 10-407
Date: 1/26/98
ARCO ALASKA INC.
WELL SUMMARY REPORT
Page: 1
WELL:iD-130 RIG:PARKER 245
WELL_ID: AK9053 TYPE:
AFC: AK9053 AFC EST/UL:$ 1062M/ 1025M
STATE:ALASKA
AREA/CNTY: NORTH SLOPE EAST
FIELD: WEST SAK BLOCK:
SPUD:10/27/97 START COMP: FINAL:
WI: 0% SECURITY:0
API NUMBER: 50-029-22815-00
10/23/97 (Dt)
TD: 0'(
SUPV:DEB
10/24/97 (D2)
TD: 0'(
SUPV:DEB
10/25/97 (D3)
TD: 0'(
SUPV:DEB
o)
10/26/97 (D4)
TD: 0'(
SUPV:DEB
10/26/97.
o)
o)
o)
10/27/97 (D5)
TD: 712' (712)
SUPV:DEB
10/28/97 (D6)
TD: 2774' (2062)
SUPV:GRW
10/29/97 (D7)
TD: 2774'(
SUPV:GRW
o)
10/30/97 (DS)
TD: 2774'(
SUPV:GRW
o)
MW: 0.0 VISC: 0 PV/YP: 0/ 0
MOVING DRILLING MODULE
Move modules and camp to West Sak 1 pad.
APIWL: 0.0
MW: 0.0 VISC: 0 PV/YP: 0/ 0
MOVING
Move modules and camp to West Sak 1 pad.
APIWL: 0.0
MW: 0.0 VISC: 0 PV/YP: 0/ 0
MOVING
Move modules and camp to West Sak 1 pad.
APIWL: 0.0
MW: 0.0 VISC:
MOVING
Moving utility module.
0 PV/YP: 0/ 0 APIWL: 0.0
Accepted rig @ 2200 hrs.
MW: 8.9 VISC: 85 PV/YP: 22/26 APIWL: 7.8
DRILLING AT 1600'
Finish moving utility module to iD pad. Function test
diverter system. Spud at 121' at 1730 hrs and drill to 712'
MD.
MW: 9.8 VISC: 64 PV/YP: 23/25
RIH W/HOLE OPENER
Drill from 712' to 2774'
APIWL: 5.8
MW: 9.7 VISC: 110 PV/YP: 35/29 APIWL: 5.6
RIH W/7-5/8" CASING
Trip out from 451'. Hole packed off, could not rotate or
reciprocate. Worked pipe up to 275' and pipe came free.
Ream to 1675' Safety meeting. Run 7-5/8" casing.
MW: 9.5 VISC: 154 PV/YP: 35/38 APIWL: 4.8
POOH W/7-5/8" CASING
Run 7-5/8" casing from 1773' to 1840' - hole packed off.
Wash casing from 1840' to 1968' Unable to wash deeper.
Safety meeting. Pump pill and POOH w/7-5/8" casing to
1366'. Hole tight.
Date: 1/26/98
ARCO ALASKA INC.
WELL SUMMARY REPORT
Page: 2
10/31/97 (D9)
TD: 2774'(
SUPV:GRW
0)
11/01/97 (D10)
TD: 2774'( 0)
SUPV:GRW
11/02/97 (Dll)
TD: 2774'( 0)
SUPV:GRW
11/03/97 (D12)
TD: 2774'( 0)
SUPV:GRW
11/04/97 (D13)
TD: 3845' (1071)
SUPV:GRW
11/05/97 (D14)
TD: 4778'(933)
SUPV:GRW
11/06/97 (D15)
TD: 4778'( 0)
SUPV:GRW
11/07/97 (D16)
TD: 4778' ( 0)
SUPV:GRW
MW: 9.8 VISC: 308 PV/YP: 51/62
POOH
Wash ream to 1270' to 2774'
APIWL: 4.2
MW: 10.0 VISC: 284 PV/YP: 48/56 APIWL: 4.6
CEMENTING
Circ and raise mud weight to 9.6 ppg from 10.0 ppg. Safety
meeting. RIH w/7-5/8" casing to 2375'. Wash/reciprocate
casing to 2527' Hole packed off and taking fluid. Reduce
mud weight to 9.5 ppg.
MW: 9.3 VISC: 46 PV/YP: 16/12 APIWL: 14.6
COOLING SOW STARTING HEAD
Pump first stage cement. Displace while getting partial
returns. Cement 2nd stage. Got contaminated mud back to
surface. Perform top job. Had good returns at surface but
no cement to surface. Perform second top job.
MW: 9.0 VISC: 43 PV/YP: 14/10
DRILLING FLOAT EQUIPMENT
N/U BOPE. Test BOPE to 300/3000 psi.
APIWL: 18.2
MW: 9.2 VISC: 52 PV/YP: 12/15 APIWL: 8.0
DRILLING
Drill stage collar @ 1689' Drill cement and landing
collar. Cleanout cement from 2395' to 2530' Drill plug
catcher, float and shoe. Wash to 2584' Perform leakoff
test to 14.9 ppg EMW. Washout rathole 2584' to 2774' Drill
20' of new hole. Run LOT to 15.2 ppg EMW. Drill from 2794'
to 3845'
MW: 9.1 VISC: 58 PV/YP: 16/22
APIWL: 4.8
Drill from 3845' to 4778'. Drop single shot survey. RIH
w/4-arm caliper. Tagged bridge at 3974' Unable to work
past. Log up from 3974' to surface. Run HSI from 2774' to
surface.
MW: 9.2 VISC: 48 PV/YP: 11/ 9 APIWL: 7.2
NU BOPE
Finish running USI log. RIH and hit bridge at 3950'. Worked
to 3970' Safety meeting. Run 5.5" x 3.5" casing string to
4770'
MW: 9.2 VISC: 47 PV/YP: 11/10 APIWL: 7.4
SETTING BPV
Freeze protect 7-5/8" x 5.5" annulus. Run bond log. TOC @
3475' Run 3.5" tubing.
Date: 1/26/98
ARCO ALASKA INC.
WELL SUMMARY REPORT
Page: 3
11/08/97 (D17)
TD: 4778'( 0)
SUPV:GRW
MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0
RIG RELEASED
ND BOPE. NU Tree. Test packoff to 5000 psi for 5 min.
Released rig @ 1200 pm 11/08/97.
End of WellSummary for Well:AK9053
ARCO Alaska, Inc,
WELL JOB SCOPE
1 D-130 OTHER STIMULATION,OTH STIM SPT
DATE
11/1 O/97
DAY
1
KEY PERSON
KUPARUK RIVER UNIT
WELL SERVICE REPORT
K1 (1D-130(W4-6))
IJOB NUMBER
1108971726.6
UNIT NUMBER
SUPERVISOR
BLACK
DAILY WORK
OTHER STIMULATION,OTH STIM SPT
OPERATION COMPLETE I SUCCESSFUL
NO I YES
InitialTbgPress IFinalTbgPress IlnitiallnnerAnn
0 PSI 0 PSI 0 PSI
DALLY SUMMARY
SWS-JOHNSON
Final Inner Ann0 PSI I Initial Outer 0AnnpsI I
Final Outer Ann
0 PSI
MAKE CCL/GR TIE IN RUN. PERFORATE W/2.5" HSD DP @ 4 SPF & 180 DEG PHASED F/4594-4596' ELM, 4490-4492' ELM,
4462-4464' ELM, 4430-4432' ELM, 4392-4394' ELM, 4402-4404' ELM. IN PROGRESS. NOTE: SLTJ DID NOT ARRIVE FOR BOND
LOGGING.
TIME
18:30
19:30
21:30
00:00
LOG ENTRY
MIRU SWS (JOHNSON & CREW). NOTE: SLTJ DID NOT ARRIVE F/PRE PERF BOND LOGGING. MU 1-11/16"
TIE IN TOOL ASSEMBLY (CCL/GR/WT) TL-19'. TGSM & PT BOPE TO 3500 PSI.
RIH TO 4708' ELM & TAG BOTTOM. LOG UP & TIE IN TO 11/5/97 SPERRY DGR/EWR4/ROP. POOH F/INITIAL
GUN RUN. CONTACT PARKER & SECURITY F/PAD RADIO SILENCE. CHECK LOCATION FOR ACTIVITY.
MU GUN ASSEMBLY #1 (10' GUN/SWITCH/10' GUN/CCL) TL-27'. PT BOPE & RIH. TIE IN & MAKE TIE IN PASS F/
4679' ELM (4703' RKB) TO 3930' ELM. RIH & LOG INTO POSITION F/1ST SHOTS. PERFORATE F/4594-4596'
ELM W/2.5" HSD DP @ 4 SPF & 180 DEG, NO ORIENTATION. GOOD INDICATION. LOG UP & PERFORATE W/
SAME GUNS F/4490 - 4492' ELM. GOOD INDICATION. POOH.
AT SURFACE. ALL SHOTS FIRED. MU GA#2 (10' GUN/SWITCH/10' GUN/CCL) TL-27'. PT & RIH. TIE AND
PERFORATE W/SAME GUNS AS ABOVE F/4462-4464' ELM. GOOD INDICATIONS. LOG UP, ENSURE TIE IN &
PERFORATE W/SAME F/4430-4432' ELM. LOG OFF & POOH.
01:45 AT SURFACE. ALL SHOTS FIRED. MU GA#3 (20' GUN/CCL) TL-24'. PT & RIH. TIE IN & PERFORATE AS
BEFORE F/4392-4394' ELM & F/4402-4404' ELM. NO SURFACE INDICATION. LOG & POOH.
03:15
05:00
AT SURFACE. ALL SHOTS FIRED. MU GA#4 (5' GUN/SWITCH/5' GUN/SWITCH/5' GUN/CCLI.
PT & RIH. IN PROGRESS PAST REPORT TIME.
ARCO Alaska, Inc.
WELL
1 D-130
DATE
11/13/97
JOB SCOPE
OTHER STIMULATION,OTH STIM SPT
DAILY WORK
MICROFRACTURE
DAY OPERATION COMPLETE I SUCCESSFUL
4 NO I YES
,nitialTbgPress IFinalTbgPress Iln~tiallnnerAnn
35 PSI 30 PSI 0 PSI
DAILY SUMMARY
KUPARUK RIVER UNIT
WELL SERVICE REPORT
K1 (1D-130(W4-6))
JOB NUMBER
1108971726.6
UNIT NUMBER
UNIT #3
KEY PERSON SUPERVISOR
DS-ROCK ELLIS
Final Inner Ann I Initial Outer Ann Final Outer Ann
0 PSII 0 PSI 0 PSI
IISOLATED PERFS & PERFORMED INJECTIVITY/FALLOFF MICROFRACTURE TESTS INTO 6 SETS OF PERFS: 4354-4356', 4402-
4404', 4430-4432', 4462-4464', 4490-4492' & 4594-4596'.
TIME
07:00
07:30
08:00
09:00
11:00
11:45
13:00
LOG ENTRY
PRESSURE TESTED COILED TUBING, COIL CONNECTOR, HYDRAULIC DISCONNECT (15/16" BALL) & CIRC
SUB TO 4000 PSI.
MU 2-5/8" TAM STRADDLE PACKER W/PANEX GAUGES. ACTIVATED GAUGES @ 8:05 AM 11/13/97.
RIH W/STRADDLE PACKER TO 150'. ATTEMPTED TO SET & TEST STRADDLE PACKER. TOP ELEMENTS
APPEAR TO BE INFLATED & HOLDING PRESSURE, PUMPING BY LOWER ELEMENTS 0.25 BPM @ 1700 PSI.
RELEASED PACKER.
RIH TO PBD 4690' & TAGGED BP. PU & FLAGGED COIL TO CORRELATE W/PERFORATING LOG. CIRC HOLE
W/2 COIL VOLUMES OF DIESEL TO WARM ELEMENTS ON PACKER.
PU PACKER TO 4550' (BLANK PIPE BETWEEN PERFS). INFLATED STRADDLE PACKER & TESTED SAME TO
2000 PSI.
RELEASED PACKER & SPACED OUT ELEMENTS ACROSS PERFS 4594-4596'.
PERFORMED INJECTIVITY TESTS & FALLOFF TESTS INTO PERFS 4594-4596'FOR MICROFRACTURE STRESS
TEST.
15:00 RELEASED PACKER & RESET ACROSS PERFS 4490-4492'. PERFORMED INJECTIVITY & FALLOFF FOR
MICROFRACTURE STRESS TEST.
16:00 RELEASED PACKER & RESET ACROSS PERFS 4462-4464'. PERFORMED INJECTIVlTY & FALLOFF FOR
MICROFRACTURE STRESS TEST.
17:30 RELEASED PACKER & RESET ACROSS PERFS 4430-4432'. PERFORMED INJECTIVITY & FALLOFF FOR
MICROFRACTURE STRESS TEST.
19:00 RELEASED PACKER & RESET ACROSS PERFS 4402-4404'. PERFORMED INJECTIVlTY & FALLOFF FOR
MICROFRACTURE STRESS TEST.
20:15 RELEASED PACKER & RESET ACROSS PERFS 4392-4394'. ATTEMPTED TO PERFORM INJECTIVlTY
MICROFRACTURE STRESS TEST. PACKER EQUALIZED. ATTEMPTED TO RESET & PERFORM INJECTIVlTY
TEST. PACKER COMMUNICATING TO THE 1-3/4" X 3-1/2" ANNULUS & PACKER SLIPPING DOWN HOLE.
21:00 RELEASED PACKER & RESET ACROSS PERFS 4354-4356'. PERFORMED INJECTIVlTY & FALLOFF FOR
MICROFRACTURE STRESS TEST. AT COMPLETION OF TEST, PACKER FAILED.
22:00 POH W/STRADDLE PACKER.
23:00 SECURED WELL & SION.
ARCO Alaska, Inc.
KUPARUK RIVER UNIT
WELL SERVICE REPORT
K1(1D-130(W4-6))
WELL JOB SCOPE JOB NUMBER
1 D-130 PERFORATE, PERF SUPPORT 0109980049.1
UNIT NUMBER
DATE DALLY WORK
01/17/98 PERFORATE, PERF SUPPORT
DAY OPERATION COMPLETE I SUCCESSFUL
2 NO I NO
Initial Tbg Press I Final Tbg Press I Initial Inner Ann
250 PSII 250 PSII 0 PSI
DAILY SUMMARY
KEY PERSON
SWS-BAILEY
Final Inner Ann I
I
0 PSI
SUPERVISOR
BLACK
Initial Outer Ann I Final Outer Ann
0 PSII 0 PSI
I
TIME LOG ENTRY
07:00 MI SWS (BAILEY & CREW). EVALUATE WELL CONDITION OF 1D-07 FOR INJECTION PROFILE. BECAUSE OF
WEATHER MOVE & BEGIN RU ON 1D-130. WAIT TO RU BASED ON SEVERE WIND CHILLS.
13:30 MU GUN ASSEMBLY #1 (20' 2-1/2 HSD (8' BLANKS) @ 4 SPF & DP'S/CCL). RIH TO 4300' ELM. COMPUTER
PROBLEMS. SD & DIAGNOSE PROBLEMS. CHANGE COMPONENTS & FINALLY GET TO WORK.
16:00 TIE IN TO 11/10/97 SWS GR/CCL & PERFORATE FROM 4440 - 4452' ELM W/2.5" HSD, DP'S @ 4 SPF ORIENTED
90 DEG F/LOW SIDE. SAW GOOD SURFACE INDICATIONS. POOH.
17:30 AT SURFACE. ALL SHOTS FIRED. MU GUN ASSEMBLY #2 (20' SAME GUNS - NO BLANKS). RIH TO 4550' ELM.
TIE IN & PERFORATE FROM 4400 - 4420' ELM W/SAME GUNS & ORIENTATION AS BEFORE. SAW GOOD
INDICATIONS. POOH
19:00 AT SURFACE. ALL SHOTS FIRED. MU GUN ASSEMBLY #3 (20' SAME GUNS - NO BLANKS). RIH TO 4500' ELM.
TIE IN & PERFORATE FROM 4380 - 4400' ELM W/SAME GUNS & ORIENTATION AS BEFORE. SAW GOOD
INDICATIONS. POOH.
21:30
AT SURFACE. ALL SHOTS FIRED. MU GUN ASSEMBLY #4 (5' SAME GUNS - NO BLANKS/SWITCH/10' SAME
GUNS (4' OF BLANKS)). RIH TO 4500' ELM. TIE IN & PERFORATE FROM 4365' -4370' ELM W/SAME AS
BEFORE. GOOD INDICATIONS. PULL UP, TIE IN & PERFORATE FROM 4295 - 4301' ELM W/SAME AS BEFORE.
POOH.
00:15 AT SURFACE. ALL SHOTS FIRED. MU GUN ASSEMBLY #5 (20 SAME GUNS - NO BLANKS). RIH TO 4500' ELM,
TIE IN & PERFORATE FROM 4322 - 4342' ELM. GOOD INDICATIONS. POOH
ARCO Alaska, Inc.
KUPARUK RIVER UNIT
WELL SERVICE REPORT
K1(1D-130(W4-6))
WELL
1 D-130
JOB SCOPE
PERFORATE, PERF SUPPORT
JOB NUMBER
0109980049.1
DATE DALLY WORK UNIT NUMBER
01/19/98 PERFORATE, PERF SUPPORT
DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR
3 YES I YES SWS-BAILEY BLACK
Final Tbg Press
250 PSI
Initial Inner Ann
0 PSI
Initial Tbg Press
25O PSI
Final Inner Ann I Initial Outer Ann I Final Outer Ann
0 PSII 0 PSII 0 PSI
DALLY SUMMARY
PERFORATE FROM 4221-4241', 4207-4221 ', 4164-4180', 4144-4164'& 4251-4256' ELM W/2.5" HSD DP'S @ 4 SPF, PHASED 180 I
DEG ORIENTED 90 DEG.
I
TIME LOG ENTRY
22:45
01:00
MIRU SWS (BAILEY & CREW). MU GUN ASSEMBLY #1 (20' 2.5" HSD - NO BLANKS/CCL). PT TO 2500 PSI.
RIH TO 4500' ELM TIE INTO 11/10/97 SWS GR/CCL & PERFORATE FROM 4221-4241' ELM W/2.5" HSD, DP'S @ 4
SPF ORIENTED 90 DEG. GOOD INDICATIONS. POOH.
02:30 AT SURFACE. ALL SHOTS FIRED. MU GUN ASSEMBLY #2 (20' 2.5" HSD - 6' OF BLANKS/CCL). PT & RIH TO
4500' ELM. TIE IN & PERFORATE FROM 4207-4221' ELM W/SAME GUNS AS ABOVE. GOOD INDICATIONS.
POOH.
04:30 AT SURFACE. ALL SHOTS FIRED. MU GUN ASSEMBLY #3 (20' 2.5" HSD - 4' OF BLANKS/CCL). PT & RIH TO
4500 ' ELM. TIE IN & PERFORATE FROM 4164 -4180' ELM W/SAME GUNS AS ABOVE. GOOD INDICATIONS.
POOH.
06:00 AT SURFACE. ALL SHOTS FIRED. SD FOR SEVERE WIND CHILLS.
12:00 MU GUN ASSEMBLY #4 (20' 2.5" HSD - NO BLANKS). PT & RIH TO 4500' ELM. TIE IN & PERFORATE FROM 4144
- 4164' ELM W/SAME GUNS AS ABOVE. GOOD INDICATIONS. POOH.
15:00 AT SURFACE. MU GUN ASSEMBLY #5 (5' 2.5" HSD - NO BLANKS). PT & RIH TO 4500' ELM. TIE IN &
PERFORATE FROM 4251 - 4256' ELM. GOOD INDICATIONS. POOH.
18:00 AT SURFACE. ALL SHOTS FIRED. BEGIN RD.
19:00 RD COMPLETE. TURN OVER TO PRODUCTION FOR INJECTION.
SPERRY-SUN DRILLING SERVICES
ANCHORAGE ALASKA
PAGE 1
ARCO ALASKA~ INC.
WEST SAK / iD-130
500292281500
NORTH SLOPE BOROUGH
COMPUTATION DATE: 12/ 1/97
DATE OF SURVEY: 110597
MWD SURVEY
JOB NUMBER: AKMM70309
KELLY BUSHING ELEV. = 111.50 FT.
OPERATOR: ARCO ALASKA INC
TRUE SUB-SEA
MEASD VERTICAL VERTICAL
DEPTH DEPTH DEPTH
COURS COURSE DLS TOTAL
INCLN DIRECTION RECTANGULAR COORDINATES VERT.
DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT.
.00 .00 -111.50
121.00 121 . 00 9.50
379.80 379.80 268.30
560.77 560.76 449.26
650.78 650 . 75 539.25
0 0 N .00 E .00 .00N .00E .00
0 0 N .00 E .00 .00N .00E .00
0 18 N 80.00 E .12 .12N .69E -.51
0 22 S 62.22 E .13 .07S 1.70E -.96
2 25 S 81.44 W 3.05 .50S .08E .35
742.26 742.00 630.50
833.02 832.11 720.61
923 . 47 921.0'9 809.59
1013 . 06 1007 . 63 896.13
1103.94 1093.61 982.11
5 26 S 81.62 W 3.30 1.42S 6.14W 4.80
8 13 S 71.27 W 3.33 4.13S 16.55W 13.18
12 25 S 58.24' W 5.29 11.33S 30.96W 27.55
17 26 S 51.30 W 5.93 24.81S 49.65W 49.51
20 21 S 48.82 W 3.33 43.74S 72.18W 78.14
1194.84 1177.85 1066.35
1291.69 1265.34 1153.84
1387.98 1350.13 1238.63
1483.70 1432.34 1320.84
1574.14 1507.45 1395.95
23 42 S 49.42 W 3.69 66.05S 97.97W 111.42
27 3 S 46.06 W 3.76 94.01S 128.63W 152.15
29 31 S 42.83 W 3.01 126.61S 160.54W 197.34
32 5 S 40.53 W 2.95 163.24S 193.10W 246.16
35 35 S 37.07 W 4.43 202.52S 224.59W 296.47
1672.57 1585.65 1474.15
1766.42 1658.05 1546.55
1954.86 1801.80 1690.30
214'4.31 1946.86 1835.36
2333.31 2091.08 1979.58
39 10 S 36.48 W 3.65 250.39S 260.35W 356.22
39 51 S 36.86 W .78 298.28S 296.01W 415.94
40 43 S 33.11 W 1.37 398.11S 365.83W 537.71
39 19 S 32.28 W .80 500.63S 431.65W 659.26
41 11 S 32.40 W .99 603.80S 496.97W 781.04
2523.24 2235.03 2123.53
2710.05 2377.15 2265.65
2896.15 2516.25 2404.75
3084.91 2658.10 2546.60
3180.13 2731.74 2620.24
40 15 S 31.54 W .58 708.90S 562.58W 904.53
40 42 S 36.22 W 1.64 809.51S 630.17W 102.5.60
42 32 S 36.60 W .99 908.98S 703.54W 1149.20
40 1 S 33.58 W 1.70 1010.80S 775.17W 1273.65
38 40 S 33.79 W 1.42 1061.02S 808.65W 1333.94
3275.28 2807.70 2696.20
3370.43 2887.52 2776.02
3464.39 2969.96 2858.46
3560.03 3056.83 2945.33
3653.30 3143.94 3032.44
35 22 S 34.62 W 3.51 1108.41S 840.83W 1391.17
30 31 S 31.85 W 5.33 1151.63S 869.25W 1442.81
26 46 S 32.09 W 3.99 1189.85S 893.10W 1487.71
22 37 S 33.18 W 4.38 1223.51S 914.62W 1527.57
19 13 S 34.'23 W 3.67 1251.22S 933.08W 1560.83
3748.89 3235.33 3123.83
3845.36 3329.19 3217.69
3940.89 3423.13 3311.63
4034.38 3515.80 3404.30
4224.60 3705.12 3593.62
14 46 S 31.85 W 4.71 1274.59S 948.37W 1588.70
11 55 S 29.84 W 2.99 1293.68S 959.82W 1610.86
8 57 S 33.61 W 3.18 1308.44S 968.84W 1628.09
6 10 S 36.40 W 3.01 1318.55S 975.86W 1640.39
4 52 S 40.18 W .71 1332.95S 987.13W 1658.67
OR I,G NAL
SPERRY-SUN DRILLING SERVICES
ANCHORAGE ALASKA
PAGE 2
ARCO ALASKAr INC.
WEST SAK / 1D-130
500292281500
NORTH SLOPE BOROUGH
COMPUTATION DATE: 12/ 1/97
DATE OF SURVEY: 110597
MWD SURVEY
JOB NUMBER: AKMM70309
KELLY BUSHING ELEV. = 111.50 FT.
OPERATOR: ARCO ALASKA INC
TRUE SUB-SEA COURS COURSE DLS TOTAL
MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT.
DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT.
4409.76 3889.66 3778.16 4 28 S 42.06 W .23 1344.32S 997.05W 1673.71
4599.39 4078.77 3967.27 4 0 S 37.00 W .32 1355.11S 1006.00W 1687.71
4712.50 4191.66 4080.16 3 9 S 35.18 W .76 1360.82S 1010.18W 1694.78
4778.00 4257.06 4145.56 3 9 S 35.18 W .00 1363.77S 1012.26W 1698.39
THE CALCULATION PROCEDURES ARE BASED ON THE USE OF
THREE-DIMENSION MINIMUM CURVATURE METHOD.
. .
HORIZONTAL DISPLACEMENT =' 1698.39 FEET
AT SOUTH 36 DEG. 35 MIN. WEST AT MD = 4778
VERTICAL SECTION RELATIVE TO WELL HEAD
VERTICAL SECTION COMPUTED ALONG 216.58 DEG.
TIE-IN SURVEY AT SURFACE 0.00' MD
PROJECTED SURVEY AT 4,778.00' MD
SPERRY-SUN DRILLING SERVICES
ANCHORAGE ALASKA.
PAGE 3
ARCO ALASKA~ iNC.
WEST SAK / !D-130
500292281500
NORTH SLOPE BOROUGH
COMPUTATION DATE: 12/ 1/97
DATE OF SURVEY: 110597
JOB NUMBER: AKMM70309
KELLY BUSHING ELEV. = 111.50 FT.
OPERATOR: ARCO ALASKA INC
INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH
TRUE SUB-SEA T~TAL
MEASD VERTICAL VERTICAL RECTANGULAR cooRDINATES MD-TVD VERTICAL
DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION
.00 .00 -111.50
1000.00 995.15 883.65
2000.00 1836.01 1724.51
3000.00 2593.62 2482.12
4000.00 3481.65 3370.15
.00 N .00 E .00
22.44 S 46.64 W 4.85 4.85
422.78 S 381.92 W 163.99 159.14
965.16 S 744.05 W 406.38 242.39
1315.30 S 973.52 W 518.35 111.97
4778.00 4257.'~6 4145.56 1363.77 S 1012.26 W
520.94 2.59
THE CALCULATION PROCEDURES ARE BASED ON THE USE OF
THREE-DIMENSION MINIMUM CURVATURE METHOD.
SPERRY-SUN DRILLING SERVICES
ANCHORAGE ALASKA.
PAGE
ARCO ALASKA, iNC.
WEST SAK / 1D-130
500292281500
NORTH SLOPE BOROUGH
COMPUTATION DATE: 12/ 1/97
DATE OF SURVEY: 110597
JOB NUMBER: AKMM70309
KELLY BUSHING ELEV. = 111.50 FT.
OPERATOR: ARCO ALASKA INC
INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH
TRUE SUB-SEA
MEASD VERTICAL VERTICAL
DEPTH DEPTH DEPTH
T~TAL
RECTANGULAR coORDINATES
NORTH/SOUTH EAST/WEST
MD-TVD VERTICAL
DIFFERENCE CORRECTION
.00 .00 -111.50
111.50 111.50 .00
211.50 211.50 100.00
311.50 311.50 200.00
411.50 411.50 300.0.0
.00 N .00 E
.00 N .00'E
.00 N .00 E
.06 N .33 E
.15 N .86 E
.00
.00 .00
.00 .00
.00 .00
.00 .00
511.50 511.50 400.00
611.51 611.50 500.00
711.64 711.50 600.00
812.21 811.50 700.00
913.67 911.50 800.00
· 08 N 1.41 E .00 .00
.28 S 1.29 E .01 .01
1.04 S 3.55 W .14 .14
3.27 S 13.85 W .71 .57
10.29 S 29.21 W 2.17 1.45
1017.12 1011.50 900.00
1123.08 1111.50 1000.00
1231.78 1211.50 1100.00
1343.84 1311.50 1200.00
1459.19 1411.50 1300.00
25.59 S 50.61 W
48.20 S 77.29 W
76.12 S 109.42 W
111.14 S 145.82 W
153.48 S 184.67 W
5.62 3.45
11.58 5.96
20.28 8.71
32.34 12.05
47.69 15.35
1579.13 1511.50 1400.00
1705.91 1611.50 1500.00
1836.21 1711.50 1600.00
1967.66 1811.50 1700.00
2098.60 1911.50 1800.00
204.85 S 226.34 W
267.32 S 272.87 W
334.52 S 322.48 W
405.11 S 370.39 W
476.14 S 416.18 W
67.63 19.94
94.41 26.79
124.71 30.29
156.16 31.45
187.10 30.94
2227.88 2011.50 1900.00
2360.44 2111.50 2000.00
2492.41- 2211.50 2100.00
2623.59 2311.50 2200.00
2755.36 2411.50 2300.00
545.41 S 459.93 W 216.38 29.28
618.89 S 506.55 W 248.94 32.57
691.92 S 552.16 W 280.91 31.97
763.51 S 597.79 W 312.09 31.18
833.35 S 647.63 W 343.86 31.76
2889.70 2511.50 2400.00
3023.69 2611.50 2500.00
3154.21 2711.50 2600.00
3279.94 2811.50 2700.00
3398.11 2911.50 2800.00
905.48 S 700.94 W 378.20 34.35
977.92 S 752.91 W 412.19 33.98
1047.57 S 799.64 W 442.71 30.53
1110.62 S 842.36 W 468.44 25.73
1163.36 S 876.55 W 486.61 18.17
3510.51 3011.50 2900.00
3618.81 3111.50 3000.00
3724.17 3211.50 3100.00
3827.26 3311.50 3200.00
1206.76 S 903.81 W 499.01 12.40
1241.51 S 926.52 W 507.31 8.30
1269.04 S 944.86 W 512.67 5.36
1290.36 S 957.88 W 515.76 3.09
SPERRY-SUN DRILLING SERVICES
ANCHORAGE ALASKA
PAGE 5
ARCO ALASKA, INC.
WEST SAK / 1D-130
500292281500
NORTH SLOPE BOROUGH
COMPUTATION DATE: 12/ 1/97
DATE OF SURVEY: 110597
JOB NUMBER: AKMM70309
KELLY BUSHING ELEV. = 111.50 FT.
OPERATOR: ARCO ALASKA INC
INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH
TRUE SUB-SEA TOTAL
MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL
DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION
3929.11 3411.50 3300.00
4030.06 3511.50 3400.00
4130.63 3611.50 3500.00
4231.00 3711.50 3600.00
4331.36 3811.50 3700.0.0
4431.66 3911.'50 3800.00
4531.95 4011.50 3900.00
4632.20 4111.50 4000.00
4732.37 4211.50 4100.00
4778.00 4257.06 4145.56
1306.85 S 967.81 W 517.61 1.85
1318.15 S 975.57 W 518.56 .95
1326.75 S 981.94 W 519.13 .57
1333.36 S 987.48 W 519.50 .37
1339.77 S 992.94 W 519.86 .35
1345.59 S 998.19 W 520.16 .31
1351.35 S 1003.16 W 520.45 .29
1356.95 S 1007.38 W 520.70 .24
1361.72 S 1010.81 W 520.87 .17
1363.77 S 1012.26 W 520.94 .07
THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN
THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS
CJ I~ I I--L- I IM ES S~I~/I C: ~ S
WELL LOG TRANSMITTAL
To:
State of Alaska
Alaska Oil and Gas Conservation Comm.
Atm.: Loft Taylor
3001 Porcupine Dr.
Anchorage, Alaska 99501
MWD Formation Evaluation Logs
December 10, 1997
1D-130, AK-MM-70309
The technical data listed below is being submitted herewith. Please address any problems or concems
to the attention of~
Jan Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518
1 LDWG formatted Disc with verification listing.
APl#: 50-029-22815-00
5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (907) 563-3256 · Fax (907) 563-7252
A Dresser Industries, Inc. Company
ri F1 I I_1_1 IM G SI=FIL/I C G S
WELL LOG TRANSMITTAL
To.-
State of Alaska
Alaska Oil and Gas Conservation Comm.
Attn.: Loft Taylor
3001 Porcupine Dr.
Anchorage, Alaska 99501
December 10, 1997
RE: MWD Formation Evaluation Logs 1D-130, AK-MM-70309
The technical data listed below is being submitted herewith. Please address any problems or concerns
to the attention of~
Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518
1D-130:
2" x 5" MD Resistivity & Gamma Ray Logs:
50-029-22815-00
2"x 5" TVD Resistivity & Gamma Ray Logs:
50-029-22815-00
1 Blueline
1 Folded Sepia
1 Blueline
1 Folded Sepia
5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252
A Dresser Industries, Inc. Company
December 8, 1997
AOGCC
Lori Taylor
3010 Porcupine Drive
Anchorage, Alaska 99501
Re: Distribution of Survey Data 1 D- 130
Dear Ms. Taylor:
Enclosed is two hard copy of the above mentioned file(s).
Well 1D-130
MWD survey tie-in point at 0.00 to a projected survey at 4,778.00'.
Please call me at 563-3256 if you have any questions or concerns.
Regards,
William T. Allen
Operations Support Engineer
Attachments
5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252
A Dresser Industries, Inc. Company
Nov. 5. i997 3'30PM ARCO.. ALASKA i]~C £~o, u~o! r, i/~ ~,~_/~
DATE:
TO:
FAX NUMBER:
FROM:
PHONE NUMBERS:
FAX NUMBERS:
E-MAIL:
NUMBER OF PAGES:
ARCO FAX COVER SHEET
1115197
Blair Wondzell - AOGCC
907-276-7542
Tom McKay
(907) 265-6890 (work)
(907) 244-5067 (cellular)
(907) 275-4704 (digital pager)
(907) 522-9218 (home)
(907) 265-6224 (work fax)
(907) 522-9398 (home fax)
tmckay@mail.arco.com.
(INCLUDING THIS COVER SHEET)
PLEASE DELIVER TO MR. WONDZELL AS SOON AS
POSSIBLE. THANKS
MESSAGE:
Blair, attached are the results of the three leakoff tests recently performed
below the 7-5/8" surface casin.g sho,e, on West Sak 1D-130 (H4). All three
tests indicate good cement Integnty at the shoe with leakoff values
calculated ranging from 12.6 to 13.5 ppg EMW, depending upon where you
define the break over point, which is highly subject to interpretation,
These are good leakoff values at this depth (TVD). Based on field
observations during the cement job, and the high volume of cement
pumped, plus two top jobs, we are confident we have a good quality
cement job to surface behind the 7-518" casing to enable annular injection,
Do you still want us to run a bond log on the surface casing in view of
these favorable leakoff test results? I'll talk to you later on today after
you've had a chance to review this information.
Best Regards,
Tom McKay
Nov,
AMCO ALAS~[A i~(J
~0, U~Oi
r, L/~
3000
2990
2800
27013
268D
2880
2300
2293
2100
2000--
1900
1700
7ffi
0
CASING AND LEAK-OFF FRACTURE TESTS
Well Name: 1D-130 Kuparuk
Supervisor: G.R. Whitlock
Date: 11/03/97
Test #'1
Casing Size and De. scrip 7-5/8", 29,70#, L-B0~_A._B_M_-B_T.C.. .................
Casing Setting Depth: 2529' TMD 2240' TVD
Mud Weight: 9.2 ppg EMW ~ Leak-off Pressure (PLO) + MW
0,052 x TVD
Lower Limit: EMW ~, 4,30 psi / (0.052 x 2240 ft) + 9.2 ppg
Upper Limit: EMW -' 500 psi / (0.052 x 2240 ft) + 9.2 ppg
Pumped 1.87 Bbl$.
EMW ~ 12.9 ppg
EMW =' 13.5 ppg
2 .4 6 8 10 12 1.4 16 18 20 22 24 26 28 30 32 34 36 31~ 40
STROKES
_C~,~G AND LEAK-OFF FRACTURE
Well Name: 1 D-130 Kuparuk
Supervisor: G,R. Whitlock
Date: 11/03/97
Test #2
Casing Size and Descrip 7-5/8", 29.70#, L-80, ABM-BTC
Casing Setting Depth: 2529' TMD 2240' TVD
Mud Weight: 9.2
ppg EMW-- Leak-off Pressure {PL+ MW
0.052 x TVD
Lower Limit: EMW = 430 psi / (0.052 x 2240 ft) + 9.2 ppg EMW = 12.9 ppg
Upper Limit: EMW = 500 psi / (0.052 x 2240 ft) + 9.2 ppg EMW -- 13.5 ppg
Pumped 2.38 Bbls.
3000
2900 --
2800
27o0
2(~30
2500 --
2400 --
2300
2:00
2000
1700
lO~ --
7OO
~0~
JOD
200
'00
0
o 2 4 6 (t
10 12
-o- CASING TEST
1 '~ 16 IB 20 22 24 26 28 30 32 34 36 38
STROKES
j'J!I~M AK~V ALAbRA !l'~b
C/t,~"',iG AND LEAK-OFF FRACTURE TE*'-~_
Well Name: 1D-130 Kuparuk Date: 11/03/97
Supervisor: G.R. Whitlock Test #3 TD @ 2794'
Casing Size and Descrip 7-5/8", 29.70#, L-80, ABM-BTC
Casing Setting Depth: 2529' TMD 2240' TVD
Mud Weight: 9.2 ppg EMW = Leak-off Pressure IPL + MW
0.052 x TVD
Lower Limit: EMW = 400 psi / (0.052 x 2240 ft) + 9.2 ppg EMW -- 12.6 ppg
Upper Limit: EMW -- 475 psi/(0.052 x 2240 ft) + 9.2 ppg EMW = 13.3 ppg
Pumped 2.55 Bb]s.
3o0o
2~)oo ~
2700 --
2,~o
26co
2,30o
23oo
22oo
21oo --
2000
1800
1700
1600--
1 ~30
1,~0
1300
12O0
1 lOO
1,~0 --
'~30
700
500
5o0
300--
200
100
0
o
2 4 6 8 lO 12
14 161~ 20 2224 26 28 30 32 34 36 3B 40
STROKES
ARCO
Alaska, Inc.
Kuparuk Drillsite Development
Post Office Box 100360
Anchorage, Alaska 99510
Telephone 907 265-6206
Michael Zanghi
Supervisor
October 27, 1997
Alaska Oil and Gas Conservation Commission
3001 Porcupine Drive
Anchorage, AK 99501
(907) 279-1433
Re:
Application for Permit to Drill, REVISION #2
West Sak 1D-130 (H4)
West Sak Phase lA Development Well, Kuparuk River Unit
Dear Sirs:
Please be advised that a minor design change has been made in the casing
program for the above referenced well. Pursuant to the verbal approval received
from Mr. Blair Wondzell of the AOGCC on October 25, 1997, the new setting
depth for the 7-5/8" surface casing will be 2,594' MD, which is 2,300' TVD. The
original setting depth was planned at 2,800' MD.
This change was necessary in order to minimize the possibility of circulating
production casing cement up into the surface casing annulus, the same annulus
to be used for annular pumping operations. A revised directional plat and
wellbore diagram are attached for your reference.
Please note that the anticipated spud date for this well is now October 27, 1997.
If you have any questions or require further information, please contact Tom
McKay at (907) 265-6890 or Tom Brockway at (907) 263-4135.
Sincerely,
Senior Drilling Engineer
Attachments
CC:
West Sak 1D-130 (H4) Well File
Tom Brockway ATO-1207
Mike Zanghi ATO-1276
Keith Lynch ATO-1228
Ike Bellaci ATO-1260
Cliff Crabtree NSK-6
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany
West Sak, ~)-130 (H4) Monobore .,~jector Well
Proposed Completion Diagram
With Annular Disposal Option
Tapered Monobore Injector
Isolate Injection Thief
Zones Using Patches
3-1/2" Tubing Tied Back to
Surface from Seal Bore/PBR
Annular Disposal Zone
Ugnu Sands
(3385' MD / 2913' TVD)
16" conductor Casing
7-5/8" DV Stage Collar
set approx. 200' TVD
below permafrost
7-5/8" Surface Casing
Cemented to Surface with
DV Stage Collar
+/- 2600' MD / +/- 2300' TVD)
Proposed Cement Top
(+/- 3200' MD / +/- 2766' TVD)
5-1/2" Production Casing
Seal Bore/PBR positioned +/-
100' above perfs
XO From 5-1/2" Casing
to 3-1/2" Casing
D Sands
B Sands
A Sands
3-1/2" Tapered Casing/Tubing
4722' MD / 4198' TVD
ARCO Alaska, Inc. TAB, 10/13/97, Rev.3
ARCO Alaska,
Structure · Pad 1D Well : H4
Field ' Kuparuk River Unit Location · North Slope, Alaska
2O0
400
600
80O
1000
1200
1400
(D 1600
(D
(- 1800
-i--
2000
2200
2400
I 2600
V
2800
3000
3200
3400
3600
3800
4000
4200
<- West (feet)
1200 1000 800 600 400 200 0
I I I I I I I I I I I I I
Surface 0.00N, 0.0/~ 0
200
KOP
.oo
Begin Turn to Torcjet /
7.17
~~ 2~.30 ~~ 1200
Bose Permofros~ ~ 1400
Stage Tool Set Depth
7 5/8 Casing ~~
Begin Angle Drop
~ 57.46
~p Ug~ ~n~ ~ 33 46
29.46
25.46
21.46 DLS: 4.00 de9 per 100 ft
17.46 . ,
1 3.46 '
9.46
Top West Sak Sands / EOD
TARGET - West Sok A3
Base West Sak Sands
5.46
TO - Casing Pt
i i i i i t i i i i i i i i i ii i i i
0 200 400 600 800 1000 1200 1400 1600 1800
Vertical Section (feet) ->
Azimuth 216.58 with reference 0.00 N, 0.00 E from slot #150
Created by jane8
Dote plotted : 27-0ct-97 I
Coordinates are in feet reference slot ~130,
/True Vc~ica, D~pth f R~B ( ...... ...... ...... 245).~
--- Baker Nughe~ INTEQ ---
TONY KNOWLE$, GOVERNOR
ALASKA OIL AND GAS
CONSERVATION COMMISSION
3001 PORCUPINE DRIVE
ANCHORAGE, ALASKA 99501-3192
PHONE: (907) 279-1433
FAX: (907) 276-7542
October 16, 1997
Thomas W. McKay, P.E.
Senior Drilling Engineer
ARCO Alaska. Inc.
P. O. Box 100360
Anchorage, AK 99510-0360
Re:
West Sak 1D-130(H4)
ARCO Alaska, Inc.
Permit No. 97- 183
Sur. Loc: 406'FNL, 600'FEL, Sec. 23. T1 iN, RI0E, UM
Btmhole Loc: 1790'FNL. 1626'FEL. Sec. 23, T1 IN, R10E. UM
Dear Mr. McKay:
Enclosed is the approved application for permit to drill the above referenced well.
The permit to drill does not exempt you from obtaining additional permits required by law from
other governmental agencies, and does not authorize conducting drilling operations until all other
required permitting determinations are made.
This approval includes annular disposal of drilling wastes and is contingent on obtaining
a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT) -
cementing records, FIT data, and any CQLs are to be submitted to the Commission prior
to the start of disposal operations.
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 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before
operation, and of the BOPE test performed 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
~ ~ctor on the North Slope pager at 659-3607.
David W. JbTi-fl'2m-m
Chairman ~.._~
BY ORDER OF THE COM~IISSION
dlf/Enclosure
cc;
Department of Fish & Game. Habitat Section w/o end.
Department of Environmental Conservation xv/o encl.
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
la. Type of Work Drill X Redrill
--
Re-Entry __ Deepen __
2O AAC 25.O05
i lb. Type of Well Exploratow___ Stratigraphic Test__
i Service X Development Gas Single Zone x
, -- --
Development Oil
--
Multiple Zone
--
2. Name of Operator
ARCO Alaska, Inc.
3. Address
P. O. Box 100360, Anchorage, AK 99510-0360
4. Location of well at surface
406' FNL, 600' FEL, Sec. 23, T11N, R10E, UM
At top of productive interval
1757' FNL, 1602' FEL, Sec. 23, T11N, R10E, UM
At total depth
1790' FNL, 1626' FEL, Sec 23, T11N, R10E, UM
12. Distance to nearest 13. Distance to nearest well
property line 1 D-06
1602' @ TD feet : 42' @ 440' feet
5.Datum Elevation (DF or KB)
RKB 41', Pad 71 feet
6. Property Designation
ADL 25650 ALK 468
7. Unit or property Name
Kuparuk River Unit
8. Well number
West Sak 1 D-130 (H4)
9. Approximate spud date
10/19/97
~ 14. Number of acres ~n property
12560
10. Field and Pool
Kuparuk River Field
West Sak Oil Pool
11. Type Bond (see 20 AAC 25.025)
Statewide
Number
#U630610
Amount
$200,000
15. Proposed depth (MD and TVD)
4722'MD
4198' TVD feet
16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2))
kickoff depth 600 feet Maximum hole angle 39.7°i Maximum surface 1400 psig At total depth (TVD) 1840 psig
18. Casing program
size
Hole Casing
24" ~ 16"
9.875"i 7.625"
8.5" ~ 5.5"
8.5" 3.5"
Specification
, Weight , Grade : Coupling ; Length:
;62.5# H-40 Weld ~ 77'
29.7# : L-80 ;BTC : 2759',
15.5~ : L-80 BTC-MOD 3970'
: ;
9.3# L-80 : 8RD : 711'
Setting Depth
Top
MD TVD
41' 41'
41' 41'
41' 41'.
4011'~ 3490',
Bo~om
MD ~ TVD
118' : 118'
2800'I 2458'~
4011' ~ 34~0'
4722'i 4198'
Quantity of cement
(include stage data)
200 CF
380 sx AS III & 235 sx Class G
215 sx Class G
19. To be completed for Redrill, Re-entry, and Deepen Operations.
Present well condition summary
Total depth: measured
true vertical
Effective depth: measured
true vertical feet
Casing
Structural
Conductor
Surface
Intermediate
Production
Liner
Length Size
Perforation depth: measured
true vertical
20. Attachments Filing fee ~ Property plat__
Drilling fluid program ~x Time vs depth plot__
feet Plugs (measured)
feet
feet Junk (measured
Cemented Measured depth
BOP Sketch x Diverter Sketch x
-- __
Refraction analysis__ Seabed report
ORIGINAL
True Vertical depth
~ :~ ~ :; ~ :,' ,-~ ~.~
i"~ :"' -'~'it ~ ',~ .', ~ ~; ~
21. I hereby certify that the foregoing ~s true and correct to the best of my knowledge
Signed Title ~~/~"//~ ~¢~/~/~///X6'"~ te
Comm~smon Use Only
Permit ~u~r j r~ ; ~_1~, ~] ~-- Approval date I~;/~o
Conditions of approval Samples required_Yes ~ No Mud log required ~ _
Hydrogen sulfide measures _ Yes/__~No Directional su~ey required ~ Yes ~ No
Required working pressure for BOPE ~2M; 3M; 5M; 10M; 15M
Other:
See cover letter for
other requirements
::/:hal Signed By by order of
Approved by }~vJd W, gohi~storl Commissioner the commission
Date
ARCO Alaska, Inc.
Kuparuk Drillsite Development
Post Office Box 100360
Anchorage, Alaska 99510
Telephone 907 265-6206
Michael Zanghi
Supervisor
September 18, 1997
Alaska Oil and Gas Conservation Commission
3001 Porcupine Drive
Anchorage, AK 99501
(907) 279-1433
Re- Application for Permit to Drill
West Sak 1D-130 (H4)
West Sak Phase lA Development Well, Kuparuk River Unit
Dear Sirs'
ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore development
well to the West Sak interval from 1D pad in the Kuparuk River Unit ("KRU").
The well is designed to penetrate and develop the production potential of the
West Sak sands in the vicinity of 1D pad.
The well is designed as a monobore injection well using a 5-1/2" x 3-1/2"
tapered casing string, with 3-1/2" tubing used as a tieback string.
Please find attached information as required by 20 AAC 25.005 (a) and (c) for
your review. Pertinent information attached to this application includes the
following'
1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a).
2)
Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c)
(1).
3)
A directional plat showing the surface and bottomhole locations
proposed for the well per 20 AAC 25.005 (c) (2). Note the 40 acre
spacing requirements detailed in ARCO's testimony for West Sak
Pool Rules governing the West Sak development project.
4)
Directional plots and proximity calculations in accordance with the
requirements of 20 AAC 25.050.
5)
Diagrams and descriptions of the BOP and diverter equipment to
be used as required by 20 AAC 25.035 (a) (1) and (b). Note that
due to the pressures expected in the West Sak sands, ARCO
proposes to test the 5000 psi BOP equipment to a maximum of
3000 psi, pending AOGCC approval per this letter and APD.
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany
6)
7)
8)
9)
10)
Please note that due to the large number of KRU wells which
have penetrated the West Sak sands in this area, ARCO has a
clear understanding of the formation pressures to be encountered.
As a result, no overpressured strata is expected in this area.
There are also no shallow hazards expected at WS 1D-130
(H4), such as shallow gas.
There have been eight (8) Kuparuk wells drilled from KRU 1D pad,
and no occurrences of shallow gas or other hazards have been
observed. There is a gas sand at approximately 2,100' TVD which
is present, but has not caused any past problems in the existing
wells which penetrated this sand using a diverter system only.
An exception to the requirements set out by 20 AAC 25.033 (e)
and 25.061 (a) are hereby requested for this APD because of this
regional experience. A prediction of the maximum downhole and
surface pressures which may be encountered however are
included in this APD per 20 AAC 25.035 (d) (2).
A complete proposed casing and cementing program is attached
as per 20 AAC 25.030. A wellbore schematic is also attached
visually depicting the proposed well and completion design.
The drilling fluid program, in addition to the requirements set forth
in 20 AAC 25.033 are attached in this APD package.
A copy of the proposed drilling program, including a request for
approval of annular pumping operations is attached. Please note
that ARCO requests permission to use two (2) well annuli which
are not located on KRU 1 D pad, and that ARCO requests that the
35,000 bbls disposal limitation be increased for these two annuli
in order to accommodate the predicted volume of waste to be
generated from the West Sak Phase lA development operation.
The Phase lA development includes the drilling of fourteen (14)
West Sak wells from the KRU 1 D pad. ARCO requests that the
WS1-01 and 1C-12 wells be permitted to receive 50,000 bbls of
waste each for the West Sak Phase lA project.
Also note that ARCO does not anticipate the presence of H2S in
the formations to be encountered in this well. However, there will
be H2S monitoring equipment functioning on the rigs as is the
standard operating procedure in the Kuparuk River Unit drilling
operation.
Please note that because of the large volume of regional
information available in this area, ARCO considers this well to be a
development well, and as such, no mudlogging operations such
as type log generation and sample catching are planned. An
exception to the requirements detailed in 20 AAC 25.005 (c) (8) is
thus requested. ~-~'.'~ ~!~ ~': ',-.,, ~ ~-..
;~'.~_~ ~ ~' ~--" ~., ,, · .....
Please note that the anticipated spud date for this well is October 19, 1997. If
you have any questions or require further information, please contact Tom
McKay at (907) 265-6890.
Sincerely,
Thomas W. McKay,U:'.E.
Senior Drilling Engineer
Attachments
CC:
West Sak 1D-130 (H4) Well
Tom Brockway ATO-1207
Mike Zanghi ATO-1276
Keith Lynch ATO-1228
Ike Bellaci ATO-1260
Cliff Crabtree NSK-6
File
ARCO
Alaska, Inc.
Kuparuk Drillsite Development
Post Office Box 100360
Anchorage, Alaska 99510
Telephone 907 265-6206
Michael Zanghi
Supervisor
October 16, 1997
Alaska Oil and Gas Conservation Commission
3001 Porcupine Drive 0~]-~ ] ~'~ 1997
Anchorage, AK 99501
(907) 279-1433
Re: Application for Permit to Drill, REVISION #1
West Sak 1D-'130 (H4)
INost Sak Phaso lA De¥olopment INell, Kuparuk RiYer ~9~ i 6 1N AL
Dear Sirs:
ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore development
well to the West Sak interval from 1D pad in the Kuparuk River Unit ("KRU").
The well is designed to penetrate and develop the production potential of the
West Sak sands in the vicinity of 1D pad.
The well is designed as a monobore injection well using a 5-1/2" x 3-1/2" tapered
casing string, with 3-1/2" tubing used as a tieback string. A separate surface'S.
casing string of 7-5/8" casing will be set and cemented to surface which will,(
provide a disposal annulus.
Please find attached information as required by 20 AAC 25.005 (a) and (c) for
your review. Pertinent information attached to this application includes the
following:
1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a).
2)
Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c)
('l).
3)
A directional plat showing the surface and bottomhole locations
proposed for the well per 20 AAC 25.005 (c) (2). Note the 40 acre
spacing requirements detailed in ARCO's testimony for West Sak
Pool Rules governing the West Sak development project.
4)
Directional plots and proximity calculations in accordance with the
requirements of 20 AAC 25.050.
5)
Diagrams and descriptions of the BOP and diverter equipment to
be used as required by 20 AAC 25.035 (a) (1) and (b). Note that
due to the pressures expected in the West Sak sands, ARCO
proposes to test the 5000 psi BOP equipment to a maximum of
3000 psi, pending AOGCC approval per this letter and APD.
Please note that due to the large number of KRU wells which have
penetrated the West Sak sands in this area, ARCO has a clear
understanding of the formation pressures to be encountered. As a
result, no overpressured strata is expected in this area. There are
also no shallow hazards expected at WS 1D-130 (H4), such as
shallow gas.
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCornpany
There have been eight (8) Kuparuk wells drilled from KRU 1D pad,
and no occurrences of shallow gas or other hazards have been
observed. There is a gas sand at approximately 2,100' TVD which
is present, but has not caused any past problems in the existing
wells which penetrated this sand using a diverter system only.
An exception to the requirements set out by 20 AAC 25.033 (e)
and 25.061 (a) are hereby requested for this APD because of this
regional experience. A prediction of the maximum downhole and
surface pressures which may be encountered however are
included in this APD per 20 AAC 25.035 (d) (2).
6)
A complete proposed casing and cementing program is attached
as per 20 AAC 25.030. A wellbore schematic is also attached
visually depicting the proposed well and completion design.
7) The drilling fluid program, in addition to the requirements set forth
in 20 AAC 25.033 are attached in this APD package.
8) A copy of the proposed drilling program, including a request for
approval of annular pumping operations is attached.
9)
Also note that ARCO does not anticipate the presence of H2S in
the formations to be encountered in this well. However, there will
be H2S monitoring equipment functioning on the rigs as is the
standard operating procedure in the Kuparuk River Unit drilling
operation.
10)
Please note that because of the large volume of regional
information available in this area, ARCO considers this well to be a
development well, and as such, no mudlogging operations such
as type log generation and sample catching are planned. An
exception to the requirements detailed in 20 AAC 25.005 (c) (8) is
thus requested.
Please note that the anticipated spud date for this well is October 23, 1997. If
you have any questions or require further information, please contact Tom
McKay at (907) 265-6890.
Sincerely, .-,~
Thomas W. McKay
Senior Drilling Engineer
Attachments
CC~
West Sak 1D-130 (H4) Well File
Tom Brockway ATO-1207
Mike Zanghi ATO-1276
Keith Lynch ATO-1228
Ike Bellaci ATO-1260
Cliff Crabtree NSK-6
Drill, Case and Completion Plan for West Sak 1D-130 (H4)
Monobore Injector with Disposal Annulus
General Procedure:
.
.
.
.
.
.
.
10.
11.
12.
13.
14.
15.
16.
Excavate cellar, install cellar box, set and cement 16" conductor to +/-
110' RKB. Weld landing ring on conductor.
Move in / rig up drilling rig. Install diverter & function test same.
Spud and directionally drill 9-7/8" hole to desired depth below permafrost
and above Ugnu interval. Planned casing setting depth is 2,800' MD.
Condition hole for casing, trip out.
Run and cement 7-5/8" 29.7# L80 BTC casing to surface, displace
cement with mud. Perform stage job and top job as required.
NOTE:
Stage (DV) tool to be installed +/- 20~.0_.~ TVD below the base
of permafrost interval.
Nipple down diverter and install wellhead. Nipple up BOP stack and
pressure test same to 3,000 psi.
Pick up 6-3/4" mill tooth bit with 3-1/2" drill pipe and collars. Trip in and
drill out stage collar. Clean out to float collar.
Shut in BOP's and pressure test casing to 3,000 psi for 30 minutes per
AOGCC regulations. Record results.
Drill out float equipment and drill 10 feet of new hole below 7-5/8" casing
shoe.
Perform formation integrity test, taken to leak off if possible.
Directionally drill 6-3/4" hole to target depth through West Sak. Planned
casing setting depth is 4,722' MD.
Condition hole for casing, trip out.
Run and cement 3-1/2" 9.3# L80 8RD x 5-1/2" 15.5# L80 BTC tapered
casing string to surface, displace cement with mud. Sufficient cement will
be pumped to cover the Ugnu and West Sak sands. Clear 5-1/2" x 7-5/8"
disposal annulus with diesel after cementing operation.
Nipple up tubinghead. Nipple up BOP stack and pressure test same to
3,000 psi.
Pick up 4-3/4" mill tooth bit, 3-1/2" drill collars, and 2-7/8" drill pipe. Trip in
and clean out to top of 3-1/2" casing. Pressure casing to 3,000 psi for 30
minutes per AOGCC regulations. Record results.
Swap well over to non-freezing completion brine. Filter brine to desired
level. Trip out.
Page 1
17.
18.
19.
20.
21.
22.
23.
24.
Rig up and run 3-1/2" tubing tieback to surface for monobore injector.
Sting into seal bore and pressure test tubing and annulus to 3,000 psi.
Set tubing hanger. Install back pressure valve.
Nipple down BOP stack. Install production tree and pressure test same.
Secure well, release rig.
Rig up CTU and clean out 3-1/2" monobore tubing to PBTD. Circulate
well to clean brine. Secure well and release CTU.
Rig up E-line unit and RIH with CBL/CET, and run cement bond tools
across West Sak interval. Report results to office for remedial action if
necessary.
Rig up E-line unit and RIH with through-tubing perforating guns.
Perforate well overbalanced. POOH with perf guns. Repeat runs as
required to perforate all desired West Sak intervals. Rig down E-line unit.
Install back pressure valve, shut in and secure well.
TWM, 10/15/97
Page 2
DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS &
DRILLING AREA RISKS
West Sak 1D-130 (H4)
Drilling Fluid Type
Extended Bentonite Slurry
Drilling Fluid Properties:
Property
Density
Plastic Viscosity
Yield Point
Initial Gel
10 Minute Gel
APl Filtrate
pH
% Solids
Spud to TD
Surface Hole
8.8-9.0 ppg
8-15
15-45
5-20
10-30
8-15
8.0-10.0
4-6 %
Drill Out to TD
Production Hole
9.6-10.0 ppg
35
2O-35
5-15
10-35
5-10
8.0-9.5
8-12 %
Drilling Fluid System'
Tandem Brandt Scalping Shale Shakers
Triple Derrick Flow Line Cleaners
Solids Processing System to Minimize Drilling Waste
Desander, Mud Cleaner, Centrifuges, Degasser
Pit Level Indicator (Visual and Audio Alarm)
Trip Tank
Fluid Flow Sensor
Fluid Agitators
Mud Hoppers with Mixing Pumps
*Spud mud should be adjusted to a FV between 50-100 sec/qt to drill gravel beds.
Notes'
Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC
25.033.
This well will be drilled with a 9-7/8" surface hole followed by a 6-3/4" production hole. The
surface hole section will be drilled using a diverter system only for well control purposes and
a 7-5/8" casing string will be cemented to surface using a stage (DV) collar. The stage collar
will be placed approximately 200 feet TVD below the base of the permafrost interval. The
production hole will be drilled using a BOP stack as shown in the attached BOP Stack
Diagram. A tapered 5-1/2" x 3-1/2" production casing string will be run at total depth (TD).
This design will enable annular pumping operations to be performed on thi~.?elL,
MASP (Maximum Anticipated Surface Pressure):
Based on actual well test data from the nearby WS1-01 well, expected reservoir pressures in
the West Sak sands in the 1D pad area vary from 0.43 to 0.46 psi/fi, or 8.2 to 8.8 ppg EMW
(equivalent mud weight), depending on the -I-VD of the sand layer being evaluated.
Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a
required mud weight of 9.7 ppg can be predicted as a maximum mud weight required to
safely drill this formation, assuming a -I'VD of 3,590' MD/TVD.
Calculating MASP based on the highest recorded reservoir pressure from the WS1-01 well,
and assuming a gas gradient of 0.11 psi/fi from the West Sak base in the West Sak 1D-130
(H4} well to surface, the following MASP can be computed:
MASP
(3,999 ft)(0.46 - 0.11 psi/fi)
1400 psi
Experience in the area has proven that these zones can be safely drilled using the BOPE
system shown in the attached schematic. Following the cementing of the 7 5/8" 29.7# L80
BTC surface casing, the BOP stack will be installed and tested to 3000 psi. The 7 5~8"
29.7# L80 BTC casing to be used has a burst rating of 6890 psi; 70% of this burst rating
is 4823 psi. The stage collar will then be drilled out and the well cleaned out to the surface
casing shoe. At that time, the casing will be pressure tested for 30 minutes at a surface
pressure of 3,000 psi.
After testing the surface casing, the 6-3/4" production hole will be drilled to TD and a tapered
string of 5-1/2" x 3-1/2" production casing will be run. The 5-112" 15.5# LB0 BTC-MOD
casing to be used has a burst rating of 7000 psi; 70% of this burst rating is 4900 psi.
Following cementing operations, the well will be cleaned out to PBTD and the casing will be
pressure tested for 30 minutes at a surface pressure of 3000 psi. After testing, a 3-1/2"
tubing tieback string will be installed in the well to be used as the injection string.
Drilling Area Risks:
Drilling risks in the West Sak '1D-130 (H4) area are limited to lost circulation and potential
borehole instability in and below the permafrost formation. Lost circulation will be addressed
with lost circulation material (LCM) and reduced circulating rates as needed. Based on
previous Drill Site 1D drilling results, 10.0 ppg mud should be more than adequate to control
both the Ugnu and West Sak formation pressures without resulting in lost circulation.
ARCO has drilled through the West Sak formation many times in nearby Kuparuk wells. For
this reason, AAI requests that the requirements listed in 20 AAC 25.033 (e) and 20 AAC
25.061 (a) (pertaining to predicted overpressured strata and seismic refraction / reflection
analysis, respectively) be waived for the drilling of West Sak 1D-130 (H4).
Well Proximity Risks:
The nearest existing well to West Sak 1D-130 (H4) is KRU 1D-06. As designed, the
minimum distance between the two wells would be 42' at 440' MD.
Annular Pumping Activities:
Incidental fluids generated from drilling operations will be hauled to the nearest permitted
disposal well or will be pumped down the surface casing annulus of West Sak 1D-130 (H4).
That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in
pumping operations. In addition, the West Sak 1D-130 (H4) production tubing annulus will
be filled with diesel and/or non-freezing brine after setting the 3-112" tubing tieback string
and prior to the drilling rig moving off of the well.
TB/TVVM, 10/15/97
c~ot~ by ti.~. For: T MoKAY
Oste plo~ted : 18-5ep-97
Plot Reference is ~$ 1D-130/H4 Version ~4,
Coordinates are in feet reference slo[ ~130.
True Voice1 Depths ore reference RKB (Porker ~2~5.
250
500
750
lOOO
1250
500
1750
2000
2250
2500
I 2750
V
3000
5250
3500
5750
4000
4250
r Pod I1:H4
I Field : Kuparuk River Unit Location : North Slope, AlaskaI
1050 900 750
SURFACE LOCATION:
406' FNL, 600' FEL
SEC. 23, T11N, RIOE
<- West (feet)
600 450 300
RKB ELEVATION: 112'
216.58 AZIMUTH
1682' (TO TARGET)
***Plene of Proposal***
K0P TVI)=600 TMD=600 DEP=0
4.00
BEGIN TURN TO TARGET TVD=750 TMD=750 DEP=5
7.17
10.31
1.3.89
17.65
DLS: 4.00 deg per 100 ff.
21.49
25..39
29.30
,35.24
37'19E0C TVD=1584 TMD=166,3 DEP=536
B/ PERMAFROST TVD=1654 TMD=1729 DEP=378
Angle Drop
Ugnu Sends
Top West Sok Sands /EOD
I TARGET - West Sok A3
Bose West Sok Sends
FD - Cesing Pt
150 0 150
8?0 Az
Begin Turn to Tar(
Permofros(
TARGET LOCATION:
1757' FNL, 1602' FEL
SEC. 25, T11N, RIOE
TARGET
TVD=3728
TMD=4250
DEP=1682
SOUTH 1351
WEST 1002
150
150
300
450
600
750
900
1050
1200
1350
L 1500
MAXIMUM ANGLE
39.7 DEG
TD LOCATION:
1790' FNL, 1626' FEL
SEC. 23, T11N, RIOE
37.46
DLS: 4.00 dog per 100 ff.
BEGIN ANGLE DROP TVD=2800 TMD=3244 DEP=1345
33.46 T/ UGNU SNDS TVD=2913 TMD=.3`385 DEP=1430
29.46
25.46
21.46
17.46
13.46
9.46
5.46
TARGET ANGLE
5 DEG
T/ W SAK SNDS(EOD) WD=.3590 TMD=4111 DEP=1670
TARGET W SAK A3 TVD=3798 TMD=4250 DEP:1683
B/ W SAK SNDS WD=3999 TMD=4522 DEP=1706
TI) - CSG PT TVD=4198 TMD=47gg I)EP=iTg3
i I i i I i I I i I I i I I i
0 250 500 750 1000 1250 1500 1750
Vertical Section (feet) ->
Azimuth 216.58 with reference 0.00 N, 0.00 E from slot #130
I
v
Creeled by finch For: T McKAY
Dote plo~ed: 18-Sep-97
Prot Reference is WS 1D-130/H4 Version 24.
Coordinates ore ~n fe~ reference slat ~130.
True Ve~cal Depths ore ref~nce RKB (Porker ~245.
I,Aj C0 Alaskaw, Inc.
Structure : Pod lO Il : H4
ield : Kuperuk River Unit Location : North Slope, Alaska
80
40
40
8o
120
160
2O0
(D 240
~ 280
O
32O
I
v
360
400
440
48O
520
560
600
640
<- West (feet)
520 4-80 440 400 560 520 280 240 200 160 120 80 40 0 40 80
I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I
1800
1900
2000 ..........................
,, ,
lOOO ~9~6;''' ,'"
// ,'/.,"1500
//
1100..." ,/~400
/ /
tI iI
/ / iO0
/
/ 1700 /
1200 .," ,,"
# / 600
/ /
/ /
/ /
/ 1800
.' ,/
/
/ /
1300 ,' ,'
~' 1900 /
//
/
/ /
/
/2500
/
,
,' 4;~600
," '%1200
,/ k1300
2600 ~' . ....-~ ~ 1400
,/ 600,.,// __4;~700X
,/ // /. ..... ~ 1500
,,' 700/" #-~000 ~
/ /"" ./' ~. 1 600
2700f ,,' /1100 'k
/' 800/'" ,." ..--~ ~
," ,'"' ."~2OO ,/'600 ~ 1700
,,' ,./ .,' / 700 ~
2800// ,,,'" ,,,'" ,,,,' O0 X
'" ,' ~¢~. 12oo
,' 900 -_
2900?'," ~0 ........... ~
/~400 ,,
1~oo [
~1000
200 ]
~ 100
,
¢ 200
11300
,." 2000/'
,' /
.
~ "
/
/
/
/
/
/
[/2 5200
2100
4OO
4OO
1500
2100 i
, i
,' ~ 1600
I i I I i i I i I I I I I t i I i t I i I I i ~f~l) i I i I I [ I
520 480 4-40 400 ,360 ,320 280 24-0 200 160 120 80 40 0 40 80
<- West (feet)
80
4O
120
160
2OO
0
240
--4-
280 '-~
.-i-
520
I
v
360
400
440
480
52O
560
6O0
640
ARCO Alaska, Inc.
Pad 1D
H4
slot #130
Kuparuk River Unit
North Slope, Alaska
MINIMUM DISTANCE CLEARANCE
by
Baker Hughes INTEQ
REPORT
Your ref : WS 1D-130/H4 Version #4
Our ref : prop2192
License :
Date printed : 18-Sep-97
Date created : 16-Apr-97
Last revised : 18-Sep-97
Field is centred on n70 16 18.576,w150 2 ~.535
Structure is tenure= on n70 18 1.316,wi~9 30 i~.308
Slot location is nT0 17 57.323,w149 30 36.399
Slot ~rid coordinates are N 5959258.705, E 560490.261
Slot local coordinates are 406.00 S 600.00 W
Projection type= alaska - Zone 4, Spheroid= Clarke - 1866
Reference North is True North
Report is limited to clearances less ~=an 500 feet
DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4*
Object wellpath
P~ <0-8610'>,,6,Pad 1D
MSS <3311-8200'>,,7,Pad 1D
P(~S <O-8070'>,,3,Pad 1D
P~MS <0-T502'>,,4,Pad 1D
PGMS <O-8930'>,,5,Pad 1D
TOTCO Survey,,WS-8,Pad 1D
PGMS <0-9783'>,,2,Pad 1D
PG~S <0-8365'>,,1,Pad 1D
WS 1D-135/G7 Version #3,,GT,Pad 1D
WS 1D-133/JS Version #3,,JS,Pad 1D
WS 1D-129/J3 Version #2,,J3,Pad 1D
WS LD-124/G3 Version-#2,,G3,Pad 1D
WS 1D-121/G5 Version #2,,GS,Pad 1D
Closest approach with 3-D Minimum Distance method
Last revised Distance M.D. Diverging from M.D.
4-Aug-92 42.0 440.0 440.0
4-Aug-92 76.2 1860.0 1860.0
4-Aug-92 403.0 20.0 650.0
4-Aug-92 282.1 675.0 675.0
A-Aug-92 162.5 300.0 300.0
16-0ct-96 154.8 1300.0 1300.0
4-Aug-92 522.8 420.0 420.0
4-Aug-92 642.6 600.0 600.0
5-Sep-97 115.3 1000.0 1000.0
5-Sep-97 45.0 280.0 280.0
5-Sep-97 15.0 300.0 4722.0
5-Sep-97 135.0 600.0 600.0
5-Sep-97 225.0 600.0 600.0
West Sak -)-130 (H4) Monobore ..,jector Well
Proposed Completion Diagram
With Annular Disposal Option
Tapered Monobore Injector
Isolate Injection Thief
Zones Using Patches
3-1/2" Tubing Tied Back to
Surface from Seal Bore/PBR
Annular Disposal Zone
Ugnu Sands
(3385' MD / 2913' TVD)
16" conductor Casing
7-5/8" DV Stage Collar
set approx. 200' TVD
below permafrost
7-5/8" Surface Casing
Cemented to Surface
"' with DV Stage Collar
(2800' MD / 2458' TVD)
Proposed Cement Top
(3200' MD / 2766' TVD)
5-1/2" Production Casing
Seal Bore/PBR positioned +/-
100' above perfs
XO From 5-1/2" Casing
to 3-1/2" Casing
D Sands
B Sands
A Sands
3-1/2" Tapered Casing/Tubing
4722' MD / 4198' TVD
ARCO Alaska, Inc. TAB, 10/13/97
KUPARUK RIVER UNIT - WEST SAK OPERATIONS
,
20" DIVERTER SCHEMATIC
6
f4
5
3
DO NOT SHUT IN DIVERTER
AND VALVE AT SAME TIME
UNDER ANY CIRCUMSTANCES.
MAINTENAN(~E~ ~ OPERATION
UPON INITIAL INSTALLATION:
· CLOSE VALVE AND FILL PREVENTER WITH WATER TO
ENSURE NO LEAKS.
· CLOSE PREVENTER TO VERIFY OPERATION AND
THAT TH E VALVE OPENS IMMEDIATELY.
CLOSE ANNULAR PRE:/E;..TER Ih] THE =_.,,'E?-JT T~. 'AT Arq
INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED.
OPEN VALVE TO ACHIEVE DIVERSION.
ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS
DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b)
1. 16" CONDUCTOR.
2. SLIP-ON WELD STARTING HEAD.
3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE.
4. 20" - 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET.
5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON
CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN
PREVAILING WIND CONDITIONS.
6. 20"- 2000 PSI ANNULAR PREVENTER.
TWM, 9/1 ~97
J
J
8
7
6
5
J
13 5/8"
5000 PSI BOP STACK
West Sak Operations - Injector Wells
AC(;;;t,IMULATOR (;:;APA~ITY 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 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
FILL BOP STACK AND MANIFOLD WITH WATER.
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.
CLOSE ANNULAR PREVENTER AND 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 3000 PSI AND HOLD FOR 3 MINUTES.
BLEED TO ZERO PSI.
5. OPEN ANNU~.R PREVE!"!T,.~,~ AND L;A~;':~,- _ KiLL AND CHOKE LINE
VALVES.
6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES,
7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4.
CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI
LOW AND 3000 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 3000 PSI FOR 3 MINUTES.
9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE.
CLOSE BLIND RAMS AND TEST TO 3000 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 3000 PSI FOR 3 MINUTES.
12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP,
13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM.
SIGN AND SEND TO DRILLING SUPERVISOR.
14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY
OPERATE BOPE DAILY.
VBRS WILL ACCOMODATE 3-1/2" TO 6" OR 4-1/2" TO 7" PIPE ODS AS
APPROPRIATE.
1. 16" - STARTING HEAD
2_ 7-1/16" - 5000 PSI TUBING HEAD
3. 7-1/16" - 5000 PSI X 13-5/8" - 5000 PSI
DOUBLE STUDDED ADAPTER/SPACER SPOOL
4. 13-5/8" 5000 PS! X 13-5/8" 5000 PSI SPACER SPOOL
5. 13-5/8" - 5000 PSI PIPE RAMS
6. 13-5/8" - 5000 PSI DRLG SPOOL W/
CHOKE AND KILL LINES
7. 13-5/8" - 5000 PSI DOUBLE RAM W/
PIPE RAMS ON TOP, BLIND RAMS ON BTM
8. 13-5/8" - 5000 PSI ANNULAR
',~!;~;::,"-:~.:' :'!'.' iTWM, 9/18/97
NOTES , '~ ·
1. COORDINATES SHOWN ARE A.S.P. ZONE 4, N.A.D. 27. ._~ --. r-' ID.S.1B ~
ELEVA TIONS SHOWN ARE BRITISH PETROLEUM MEAN ~ ,C.P.F.1 ~---- ~~
SEA LEVEL. ALL OISTANCES SHOWN ARE TRUE.
2. BASIS OF LOCATIONS ANO ELEVATIONS ARE D.S. 1-0 PIT C ~--\ , i/' ~10 ':: ~,._/'~
. ,~ONUUENTS ~ER LHO ANO ASSOCIA~S. ", 9 L^REZ~'
.7. CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTIONS ~ PIT
4. DATE OF SURVEYS: 8/25, 29 & .70/97, FIELD BK L97-24,
6. SEE DRA~NG NEK-~.5-1 FOR AS-BUILT LOCA~ONS
..... !
..~ ~ClNI ~ MAP
~ ~ ~ LS-8055 z ~ ~
..................
A.5. P.~ 'X' ' ~A DTU~E L~NG/TUDE ' ~ ' ~'~
No.
i
S,~c. 14, T. 11 N., R. IOE. F.S.L.F.E.L.~
105 5,959,79&99 560,490.57 70' 18' 02.637' 149' 30' ~6.263' 134' 595' J 70.5'
106 5,959,76&9~ 560,490.67 70' 18' 02.341' 149' 30' 36.268' 104' 595'1 70.4' 62.3'
109 5,959,72189 560,490.60 [ 70' 18' 01.898' I49' 30' ~6.280' 59' 596'1 70.4'
S,~c. 23, T. 11 N., R. 10 E. CN.L.F. CL.:
115 5,959,60~.93 560,490.68 ' 70' 18' 00.718' 149' 30' ~6.306' 61' 597"
117 5,959,573.95 560,490.65 ~ 70' I8' 00.423' 149' 30' 36.314" 91' 59~*' 70.4'1
118 5,959,55&95 560,490.68 ~ 70' 18' 00.276' I49' 30' ~6.316" 106' 597"
~ 119 5,959,513.86 560,490.72 ~ 70' I7' 59.832' 149' 30' 36.526' ~5I" 598'= 70.~'1 6~.0'1
~ 120 5,959,499.0I 560,490.77'~ 70' 17' 59.686" 149' 30' 36.327" 166' 598' 70.~'1
, ,
121 5,959,483.89 560,490.67 ~ 70' 17' 59.5~8' 149' 30' 36.335" 18I' 598' 70.5' 6~.0
~24 5,959,393.96 560,490.70 70' 17' 58.653' I49' 30' ~6.355" 271' 599' 70.~''
129 5,959,27192 560,490.79 ~ 70' I7' 5X472" I49' 30' ~6.380" 391' 600' 70.~''
130 5,959,259.09 360,490.81 ' 70' 17' 5Z~26' 149' 30' 36.383' 4~' 600' 70.5' 6~2'~
I
133 5,959,21189 560,490.68 ' 70' 17' 56.882' 149' 30' ~6.397' 451' 600' 70.4': 69.0'~
135 5,959,139.02 560,490.80 ' 70' 17' 56.146' 149' 30' 36.412" 526" 601' 70.5" 69.4'
SUR~YOR'S CER~RCA ~
~ HEeEer CE~r ~r ~ ~ P~O~E~Lr
~NO UC~NSEO rO P~C~CE ~NO SUre,NC ;N ~E
ST~ OF ~L~SM~ ~NO m~r ~lS ~L~T RE, RESENTS ~:~ LOUNSBURY
A SURLY DONE BY UE OR UNOER MY O/REef~/~~/]~ k ASSOCIATES, INC.
SUPER~SION AND THAT ALL DIMENSIONS AND O~ER
DETAILS ARE CORRECT AS OF AUGUST 30. 1997, ~~-~m~ p~.~ suRv~o~
~EA' 1D ~ULE ' XX UNIT' D1
LK610410 9/02/97 CEA-D1DX-6104DIO 2 ¢ 2 1
SENT BY'AECO ,U.-~SKA ; 9-17-97 ; 3:19P~ ; KPS/~IS/CNST/P~OJ--' 907 265 6224;# 3/ 4
2. 9/17197 A~ rC ~ILT P~ ~1 ~2~
I
I ~ ...
. , ~ ~:~
' e ~ ,,~ ~~ ~ClNI~ MAP
~1 ~ ~ S~E: I' - I MILE
11e 4
119 ~
, 121 ,
,
, ' + ~ ,
LEGEND s~ SHE~ A 2 mR ~ ~0 L~ON INFOR~TiON
o ~x~s,~ co~c~ ~~ LOUNSBURY
· ~ c~uc~ ~.~~~ a ,ssocm~ss. INC.
i
' .... ~: 1D M~ ~ Uffil - 01
ARCO Alaska, Inc. J~ o.,~ ~ ~-o
~ ~T s~ PHA~ - ~ C~OUCT~S
AS-BUILT
~61~1o 9/o2/97 CEA-D1DX-610~IO 1 ~ 2 2
WELL PERMIT CHECKLIST COMPANY/,/'<:_<~
FIELD & POOL ? .~'<::::3/._~,,~ INIT CLASS
WELL NAME4/~/~,/~ /~) -.//_~,,'~.
GEOL AREA ' ~:>? d
PROGRAM: exp [] dev [] redrll [] serv~/wellbore seg [b ann. disposal para req,.~
UNIT# ~.///~/~--'~ ON/OFF SHORE o ~"
ADMINISTRATION
_DATE/
1. Permit fee attached .......................
2. Lease number appropriate ...................
3. Unique well name and number ..................
4. Well located in a defined pool ..................
5. Well located proper distance from drilling unit boundary ....
6. Well located proper distance from other wells ..........
7. Sufficient acreage available in drilling unit ............
8. If deviated, is wellbore plat included ...............
9. Operator only affected party ...................
10. Operator has appropriate bond in force .............
11. Permit can be issued without conservation order ........
12. Permit can be issued without administrative approval ......
13. Can permit be approved before 15-day wait ...........
Y N
N
N
N
N
N
N
ENGINEERING
GEOLOGY
REMARKS
14. Conductor string provided ................... L~ N
15. Surface casing protects all known USDWs ........... {~ N
16. CMT vol adequate to circulate on conductor & surf csg ..... ~ ~,,_.~..¢,~_~ _ ,_. / /^-- /'] ~ ~ ~~,~~ ¢-'c~-.~..
17. CMT vol adequate to tie-in long string to surf csg ...... ""z~'~/~///'"~" - ~C~' ' --
18. CMT will cover all known productive horizons ..........
19. Casing designs adequate for C, T, B & permafrost ......... N
20. Adequate tankage or reserve pit .................
21. If a re-drill, has a 10-403 for abandonment been approved... Y N
22. Adequate wellbore separation proposed ............. ~ N
23. If diverter required, does it meet regulations ..........
24· Drilling fluid program schematic & equip list adequate ..... N~ .--
25. BOPEs, do they meet regulation ...... ~_N ~¢c,'g~,~,,,-- g-';''~'~'i ~"-~/,~,%,v ..... ~,~
26. BOPE press rating appropriate; test to ~.,~/,~' ' ' .Psigl N / / ~ ~r
27. Choke manifold complies w/APl RP-53 (May 84) ........ N
28. Work will occur without operation shutdown ........... N
29. Is presence of H2S gas probable .................
30. Permit can be issued w/o hydrogen sulfide measures ..... Y Ix~/ / ,~
31. Data presented on potential overpressure zones .......
32. Seismic analysis of shallow gas zones ............. N - ' '
33. Seabed condition survey (if off-shore) .............
34. Contact name/phone for we,ekly,prog, ress repqrts ...... /.//
Y
N
· Y N
lexp~ora~ory omyj
GEOLOGY:
RPC..~?~~-
ENGINEERING'
COMMISSION:
JDH ~ R U C_,i(,~~
HOW/lit- A:\FORMS\cheklist rev 09/97
Well History File
APPENDIX
Information of detailed nature that is not
particularly germane to the Well Permitting Process
but is part of the history file.
To improve the readability of the Well History file and to
simplify finding information, information, of this
nature is accumulated at the end of the file under APPENDIX.
No special effort has been made to chronologically
organize this category of information.
Sperry-Sun Drilling Services
LIS Scan Utility
Wed Dec 03 09:41:53 1997
Reel Header
Service name ............. LISTPE
Date ..................... 97/12/03
Origin ................... STS
Reel Name ................ LrNKNOWN
Continuation Number ...... 01
Previous Reel Name ....... UNKNOWN
Comments ................. STS LIS Writing Library.
Technical Services
Tape Header
Service name ............. LISTPE
Date ..................... 97/12/03
Origin ................... STS
Tape Name ................ LrNKNOWN
Continuation Number ...... 01
Previous Tape Name ....... UNKNOWN
Comments ................. STS LIS Writing Library.
Technical Services
Scientific
Scientific
Physical EOF
Comment Record
TAPE HEADER
KUPARUK RIVER UNIT
MWD/MAD LOGS
WELL NAME:
API NUMBER:
OPERATOR:
LOGGING COMPANY:
TAPE CREATION DATE:
JOB DATA
JOB NUMBER:
LOGGING ENGINEER:
OPERATOR WITNESS:
SURFACE LOCATION
SECTION:
TOWNSHIP:
R3kNGE:
FNL:
FSL:
FEL:
FWL:
MWD RUN 1
AK-MM-70309
B. HEATNING SE
D. BREEDEN
ELEVATION (FT FROM MSL 0)
KELLY BUSHING:
DERRICK FLOOR:
GROUND LEVEL:
1D-130
500292281500
ARCO ALASKA, INC.
SPERRY-SUN DRILLING SERVICES
03-DEC-97
MWD RUN 2
AK-MM-70309
P. SMITH
G. WHITLOCK
23
liN
10E
406
6O0
111.50
111.50
70.50
WELL CASING RECORD
1ST STRING
2ND STRING
3RD STRING
PRODUCTION STRING
REMARKS:
OPEN HOLE CASING DRILLERS
BIT SIZE (IN) SIZE (IN) DEPTH (FT)
-9.875 7.625 2526.0
6.750 4778.0
1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE
NOTED.
2. ANNULAR HYDRAULICS ARE CALCULATED USING THE POWER
LAW MODEL.
3. MWD RUNS 1 AND 2 ARE DIRECTIONAL WITH DUAL GAMMA RAY
(DGR) AND
ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4).
4. THIS WELL REACHED A TOTAL DEPTH (TD) OF 4778'MD,
4257'TVD.
SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING.
SGRC = SMOOTHED GAMMA RAY COMBINED.
SEXP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (EXTRA
SHALLOW SPACING).
SESP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY
(SHALLOW SPACING).
SEMP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (MEDIUM
SPACING).
SEDP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (DEEP
SPACING).
SFXE = SMOOTHED FORMATION EXPOSURE TIME.
$
File Header
Service name ............. STSLIB.001
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 97/12/03
Maximum Physical Record..65535
File Type ................ LO
Previous File Name ....... STSLIB.000
Comment Record
FILE HEADER
FILE NUMBER: 1
EDITED MERGED MWD
Depth shifted and clipped curves; all bit runs merged.
.5000
DEPTH INCREMENT:
FILE SUMMARY
PBU TOOL CODE
FET
RPD
RPM
RPS
RPX
GR
ROP
$
START DEPTH
122.5
122 5
122 5
122 5
122 5
122 5
124 0
STOP DEPTH
4732 5
4732 5
4732 5
4732 5
4732 5
4725 5
4777 5
BASELINE CURVE FOR SHIFTS:
CURVE SHIFT DATA (MEASURED DEPTH)
EQUIVALENT UNSHIFTED DEPTH
BASELINE DEPTH
122.5
188
192
204
206
213
222
231
233
238
242
248
252
271
274
276
281
294
296
299
303
317
322
335
343
353
358
384
388
394
396
399
404
407
409
411
421
459
462
465
467
526
530
535
545
546
584
609
615
617
661
671
675
68O
686
690
693
697
703
.0
.5
.0
.5
.5
.0
.0
.5
.5
.5
.5
.0
.0
.5
.5
.5
.5
.5
.0
.5
.5
.0
.0
.0
.0
.0
.5
.0
.0
.0
.0
.0
.0
.5
.5
.0
.0
.0
.0
.0
.0
.0
.0
.0
.5
.0
.0
.5
.5
.0
.0
0
0
5
0
5
0
0
GR
121.0
186.5
191.0
203.0
205.5
213.0
221.0
230.0
232.5
238 5
241 5
248 0
251 5
272 0
274 0
277 0
282.0
294.0
297 0
299 0
302 5
318 0
321 5
334 0
343 0
353 0
357 5
382.0
388.0
394.5
396.0
398.0
404.0
406.5
408.5
410.0
421.0
458.5
460.5
464.0
466.5
524.0
528.0
532.5
544.0
545 0
584 0
609 0
615 5
617 0
661 0
672 5
675 0
680 5
686 0
690 5
693 0
696 5
702 5
705
713
719
722
724
727
761
768
775
776
801
807
831
834
873
875
877
898
902
972
1014
1019
1078
1098
1229
1314
1329
1332
1344
1347
1353
1402
1409
1411
1420
1476
1521
1528
1531
1556
1575
1584
1588
1591
1593
1596
1604
1607
1630
1638
1643
1646
1661
1752
1770
1772
1776
1798
1828
1836
.0
.5
.0
0
0
0
5
5
0
5
0
5
0
5
5
5
5
0
0
5
0
0
5
0
5
0
5
0
0
0
0
0
5
.--,
.0
.5
.5
.5
.5
.0
.0
.5
.0
.5
.0
.5
.0
.5
.5
.5
0
5
0
5
0
0
5
0
5
5
705.0
713.5
720.0
722.0
725.0
727.0
760.5
767.0
775.0
776.5
802.0
807.0
831.0
833.5
873.0
875.5
878.0
897.5
902.5
972.0
1014.0
1018.5
1078.5
1098.0
1229.5
1314.0
1330.5
1332.5
1345.0
1347.5
1353.0
1403.5
1410 5
1413 0
1420 0
1475 5
1522 5
1530 5
1532.5
1557.5
1579.5
1588.5
1591.0
1594.0
1595.5
1598.5
1605.0
1609.0
1630.5
1638'5
1644 5
1647 5
1662 0
1753 5
1770 5
1772 0
1776 5
1799 5
1826 5
1838 0
1856.0
1861.0
1864.5
1872.5
1875.5
1881.0
1884.5
1887.5
1891.5
1897.0
1921.0
1923.5
2002.0
2006.0
2011.0
2051.0
2057.0
2083.0
2085.5
2093.0
2109.0
2113.5
2117.0
2149.5
2157.5
2160.5
2166.5
2170.5
2176.0
2178.5
2185.5
2188.5
2191.0
2211.0
2298.0
2301.0
2307.5
2324.0
2329.5
2331.0
2333.0
2335.5
2360.0
2367.5
2380.5
2388 5
2391 5
2393 5
2396 5
2401 0
2414 5
2425 5
2427 5
2434 0
2438 5
2470 0
2475 0
2483 5
2487 0
2492 0
1857.0
1860.5
1865.5
1872.0
1876.0
18-80.0
1883.5
1888.0
1891.5
1897.0
1922.0
1923.0
2002.0
2008.0
2010.0
2055.0
2057.0
2083 5
2087 0
2093 5
2108 0
2116 0
2118 0
2150 5
2158 5
2161.0
2165.0
2170.5
2175.5
2178.5
2186.0
2189.5
2191.5
2210.5
2298.5
2301.5
2308.0
2321.5
2326.5
2330.0
2332.5
2336.5
2361 0
2370 0
2383 0
2390 5
2392 0
2393 5
2396.5
2402.5
2414.5
2426.0
2428.0
2436 0
2436 5
2472 0
2477 0
2484 0
2487 5
2493 0
2496
2498
2501
2504
2508
2513
2517
2518
4777
MERGED DATA SOURCE
PBU TOOL CODE
MWD
MWD
$
REMARKS:
2497.0
2500.5
2502.5
2504.5
2509.0
2514.0
2517.5
2519.0
4778.0
BIT RUN NO MERGE TOP MERGE BASE
1 122.0 2774.0
2 2774.0 4778.0
MERGED MAIN PASS.
$
Data Format Specification Record
Data Record Type .................. 0
Data Specification Block Type ..... 0
Logging Direction ................. Down
Optical log depth units ........... Feet
Data Reference Point .............. Undefined
Frame Spacing ..................... 60 .lin
Max frames per record ............. Undefined
Absent value ...................... -999.25
Depth Units .......................
Datum Specification Block sub-type...0
Name Service Order Units Size Nsam Rep
DEPT FT 4 1 68
ROP MWD FT/H 4 1 68
GR MWD AAPI 4 1 68
RPX MWD OHI~M 4 1 68
RPS MWD OHI~I~ 4 1 68
RPM MWD OHMM 4 1 68
RPD MWD O}{MM 4 1 68
FET MWD HOUR 4 1 68
Code Offset Channel
0 1
4 2
8 3
12 4
16 5
20 6
24 7
28 8
Name
DEPT
ROP
GR
RPX
RPS
RPM
RPD
FET
Min
122.5
9 7149
8 1345
0 5745
0 6154
0 4015
0 2178
0 0807
Max Mean Nsam
4777.5 2450 9311
881.567 252.749 9308
127. 173 58.7467 9207
570.088 38.8353 9221
535.127 41.2654 9221
2000 63.0795 9221
2000 118.646 9221
171. 046 2. 01087 9221
First
Reading
122.5
124
122.5
122.5
122.5
122.5
122.5
122.5
Last
Reading
4777 5
4777 5
4725 5
4732 5
4732 5
4732 5
4732 5
4732 5
First Reading For Entire File .......... 122.5
Last Reading For Entire File ........... 4777.5
File Trailer
Service name ............. STSLIB.001
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 97/12/03
Maximum Physical Record.. 65535
File Type ................ LO
Next File Name ........... STSLIB.002
Physical EOF
File Header
Service name ............. STSLIB.002
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 97/12/03
Maximum Physical Record..65535
File Type ................ LO
Previous File Name ....... STSLIB.001
Comment Record
FILE HEADER
FILE NUMBER: 2
RAW MWD
Curves and log header data for each bit run in separate files.
BIT RUN NUMBER: 1
DEPTH INCREMENT: .5000
FILE SUMMARY
VENDOR TOOL CODE START DEPTH STOP DEPTH
FET 121.0 2729.0
RPD 121.0 2729.0
RPM 121.0 2729.0
RPS 121.0 2729.0
RPX 121.0 2729.0
GR 121.0 2736.0
ROP 122.5 2773.5
$
LOG HEADER DATA
DATE LOGGED: 28-0CT-97
SOFTWARE
SURFACE SOFTWARE VERSION: ISC 5.06
DOWNHOLE SOFTWARE VERSION: CIM 5.46/SP4 5.03/DEP
II 2.17F
DATA TYPE (MEMORY OR REAL-TIME): MEMORY
TD DRILLER (FT) : 2774.0
TOP LOG INTERVAL (FT) : 122.0
BOTTOM LOG INTERVAL (FT) : 2774.0
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
MINIMUM ANGLE: .3
MAXIMUM ANGLE: 41.2
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE
DGR DUAL GAMMA RAY
EWR4 ELECTROMAG. RESIS. 4
TOOL NUMBER
P0866CRG6
P0866CRG6
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT):
BOREHOLE CONDITIONS MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S) :
MUD PH:
MUD CHLORIDES (PPM) :
FLUID LOSS (C3):
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TERMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
REMARKS:
$
Data Format Specification Record
Data Record Type .................. 0
Data Specification Block Type ..... 0
Logging Direction ................. Down
Optical log depth units ........... Feet
Data Reference Point .............. Undefined
Frame Spacing ..................... 60 .lin
Max frames per record ............. Undefined
Absent value ...................... -999.25
Depth Units .......................
Datum Specification Block sub-type...0
Name Service Order Units Size Nsam Rep
DEPT FT 4 1 68
GR MWD 1 AAPI 4 1 68
RPX MWD 1 OHMM 4 1 68
RPS MWD 1 OHP~4 4 1 68
RPM MWD 1 OPIMM 4 1 68
RPD MWD 1 OHl~4 4 1 68
ROP MWD 1 FT/H 4 1 68
FET MWD 1 HOUR 4 1 68
9.880
9.9
SPUD MUD
171.20
85.0
8.5
850
7.6
6.000
5.447
7.000
3.500
Code Offset Channel
0 1
4 2
8 3
12 4
16 5
20 6
24 7
28 8
26.7
Name Min Max Mean
DEPT 121 2773.5 1447.25
GR 8.1345 112.108 51.4542
RPX 0.5745 570.088 61.1938
RP$ 0.6154 535.127 65.6463
First Last
Nsam Reading Reading
5306 121 2773.5
5231 121 2736
5217 121 2729
5217 121 2729
RPM 0.5145 2000 105.037 5217
RPD 0.2178 2000 204.287 5217
ROP 38.465 881.567 272.226 5303
FET 0.0807 1.5547 0.32559 5217
121 2729
121 2729
122.5 2773.5
121 2729
First Reading For Entire File .......... 121
Last Reading For Entire File ........... 2773.5
File Trailer
Service name ............. STSLIB.002
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 97/12/03
Maximum Physical Record..65535
File Type ................ LO
Next File Name ........... STSLIB.003
Physical EOF
File Header
Service name ............. STSLIB.003
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 97/12/03
Maximum Physical Record..65535
File Type ................ LO
Previous File Name ....... STSLIB.002
Comment Record
FILE HEADER
FILE NUMBER: 3
RAW MWD
Curves and log header data for each bit run in separate files.
BIT RUN NUMBER: 2
DEPTH INCREMENT: .5000
FILE SUMMARY
VENDOR TOOL CODE START DEPTH STOP DEPTH
FET 2725 . 0 4733 . 0
RPD 2725 . 0 4733 . 0
RPM 2725 . 0 4733 . 0
RPS 2725 . 0 4733 . 0
RPX 2725 . 0 4733 . 0
GR 2730 . 0 4726 . 0
ROP 2770 . 0 4778 . 0
$
LOG HEADER DATA
DATE LOGGED: 05-NOV- 97
SOFTWARE
SURFACE SOFTWARE VERSION: ISC 5.06
DOWNHOLE SOFTWARE VERSION: CIM 5.46/SP4 5.03/DEP
II 2.17F
DATA TYPE (MEMORY OR REAL-TIME): MEMORY
TD DRILLER (FT) : 4778.0
TOP LOG INTERVAL (FT) : 2774.0
BOTTOM LOG INTERVAL (FT) :
BIT ROTATING SPEED (RPM) :
HOLE INCLINATION (DEG
MINIMUM ANGLE:
MAXIMUM ANGLE:
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE
DGR DUAL GAMMA RAY
EWR4 ELECTROMAG. RESIS. 4
$
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT):
BOREHOLE CONDITIONS MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S):
MUD PH:
MUD CHLORIDES (PPM) :
FLUID LOSS (C3):
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TERMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
REMARKS:
$
Data Format Specification Record
Data Record Type .................. 0
Data Specification Block Type ..... 0
Logging Direction ................. Down
Optical log depth units ........... Feet
Data Reference Point .............. Undefined
Frame Spacing ..................... 60 .lin
Max frames per record ............. Undefined
Absent value ...................... -999.25
Depth Units .......................
Datum Specification Block sub-type...0
4778.0
3.2
42.5
TOOL NUMBER
P0847SP4
P0847SP4
6.750
6.8
LSND
175.00
58.0
9.5
50O
4.8
4.000
3 .204
6.500
3 .000
35.2
.0
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1
GR MWD 2 AAP I 4 1 68 4 2
RPX MWD 2 OHMM 4 1 68 8 3
RPS MWD 2 OHNIM 4 1 68 12 4
RPM MWD 2 OHNIM 4 1 68 16 5
RPD MWD 2 OHMM 4 1 68 20 6
R0P MWD 2 FT/H 4 1 68 24 7
FET MWD 2 HOUR 4 1 68
28
Name Min Max Mean
DEPT 2725 4778 3751.5
GR 19.5618 127.173 68.2947
RPX 1.1015 113.389 9.59655
RPS 0.7325 79.1718 9.46071
RPM 0.4015 84.899 9.0432
RPD 0.4676 73.0477 8.95798
ROP 9.7149 665.849 227.05
FET 0.1057 171.046 4.5665
4107
3993
4017
4017
4017
4017
4017
4017
First
Reading
2725
2730
2725
2725
2725
2725
2770
2725
Last
Reading
4778
4726
4733
4733
4733
4733
4778
4733
First Reading For Entire File .......... 2725
Last Reading For Entire File ........... 4778
File Trailer
Service name ............. STSLIB.003
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 97/12/03
Maximum Physical Record..65535
File Type ................ LO
Next File Name ........... STSLIB.004
Physical EOF
Tape Trailer
Service name ............. LISTPE
Date ..................... 97/12/03
Origin ................... STS
Tape Name ................ UNKNOWN
Continuation Number ...... 01
Next Tape Name ........... UNKNOWN
Comments ................. STS LIS Writing Library.
Technical Services
Reel Trailer
Service name ............. LISTPE
Date ..................... 97/12/03
Origin ................... STS
Reel Name ................ ~OWN
Continuation Number ...... 01
Next Reel Name ........... UNKNOWN
Comments ................. STS LIS Writing Library.
Technical Services
Scientific
Scientific
Physical EOF
-Physical EOF
End Of LIS File
