Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout200-1831. 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 Patch for Drift
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 6100'feet None feet
true vertical 4254' feet None feet
Effective Depth measured 5578'feet 133', 174'feet
true vertical 3762' feet 132', 174' feet
Perforation depth Measured depth
True Vertical depth
Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 5442' MD 3639' TVD
Packers and SSSV (type, measured and true vertical depth) 133' MD
174' MD
N/A
132' TVD
174' 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:
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:
325-280
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: PIIP Patch Packer
Packer: PIIP Patch Packer
SSSV: None
Shelby Sumrall
shelby.sumrall@conocophillips.com
(907) 265-6678Well Integrity Specialist
5504-5544', 5574-5614', 5622-5650', 5668-5684', 5692-5728', 5750-5800'
3694-3731', 3785-3795', 3803-3829', 3846-3861', 3868-3902', 3923-3970'
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
118'
~~~
INJECTOR ~~
~
measured
TVD
5-1/2" x 3-1/2"
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
200-183
50-029-22986-00-00
P.O. Box 100360
Anchorage, AK 99510
3. Address:
ConocoPhillips Alaska, Inc.
N/A
5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work:
ADL0025650
Kuparuk River Field/ West Sak Oil Pool
KRU 1D-101
Plugs
Junk measured
Length
Production
Liner
6048'
Casing
4233'6079'
469'
118'Conductor
Surface
Intermediate
16"
10-3/4"
871'
499' 499'
Burst Collapse
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 12:59 pm, Aug 01, 2025
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: 2025.07.31 11:45:09-08'00'
Foxit PDF Editor Version: 13.1.6
Shelby
Sumrall
RBDMS JSB 080725
DSR-9/10/25JJL 8/12/25
DTTMSTART JOBTYP SUMMARYOPS
6/17/2025 DATA
ACQUISITION
DRIFTED TBG 2.79" TO TOP OF PATCH @ 136' RKB. MADE
MULTIPLE ATTEMPTS TO PULL UPPER PATCH PACKER
ASSEMBLY WITHOUT SUCCESS. PULLED TTS PULLING TOOL,
HAND OVER WELL BACK TO OPS TO BRING BACK ONLINE. JOB
SUSPENDED DUE TO UNIT MAINTENANCE AND HIGHER PRIORITY
WORK.
6/23/2025 DATA
ACQUISITION
PLANT 3.5" TTS PULLING TOOL ON TOP OF PATCH. MADE 2
ATTEMPTS TO PULL PATCH @ 100' UNABLE TO GET PATCH FREE.
PULLED 3.5" TTS PULLING TOOLS. HAND WELL BACK OVER TO
OPS. DECISION MADE TO HAVE COIL PULL SHALLOW PATCH DUE
TO TOOLSTRING PROXIMITY TO WELLHEAD.
6/29/2025 DATA
ACQUISITION
7/6/2025 DATA
ACQUISITION
TRAVEL FROM 3T TO 1D. SPOT UP / RIG UP CTU#4. RIH WITH
PULLING ASSEMBLY. TAG UPPER PATCH PACKER @ 115' CTMD.
UNABLE TO LATCH WITH BAITED PULLING TOOL. RECONFIGURE
WITH HYDRAULIC SPEAR. RIH ENGAGE UPPER PATCH PACKER,
PULL PATCH WITH 20 K LBS STRAIGHT PULL. LAY DOWN TOOLS
UPPER PACKER AND BLANK PIPE. RIH AND PULL LOWER
PACKER WITH 10 K LBS STRAIGHT PULL. RIH WITH EXP JET
NOZZLE, WASH PATCH AREA, GLM#1 AND DS NIPPLE. TAG 5758'
CTMD. PUH WASHING DS NIPPLE & GLM #1. FREEZE PROTECT
FROM 2,500' TO SURFACE. JOB IN PROGRESS. READY FOR
RELAY.
BRUSH & FLUSHED TUBING & 2.81'' DS NIPPLE 5389' RKB, DRIFT
DMY 2.81'' CA-2 PLUG TO D- NIPPLE 5389' RKB (CLEAN), DRIFT
2.72'' X 42' DMY PATCH TO 239' RKB (CLEAN), SET 2.72'' LWR P2P
PACKER MID ELEMENT 176' RKB (CPP35225) W/ PASSING CMIT- T
X IA TO 2500 PSI, SET 2.72'' X 40.5' UPPER PATCH ASSEMBLY W/
PASSING 2500 PSI MIT-IA (CPP35085, CPAL35139).
**JOB IS READY FOR STATE WITNESSED MIT-IA ONCE BOL &
STABILIZED.
7/15/2025 DATA
ACQUISITION
(SW) STATE WITNESSED (KAM STJOHN) MITIA (PASS) @ 1800 PSI
1D-101 Pull/Replace Patch
Summary of Operations
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag: SLM 5,578.0 1D-101 1/3/2020 fergusp
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Added new patch 1D-101 7/6/2025 Jconne
Notes: General & Safety
Annotation End Date Last Mod By
NOTE:8/18/2010 pproven
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 31.0 118.0 118.0 62.58 H-40 WELDED
SURFACE 10 3/4 10.05 30.4 499.3 499.2 40.50 J-55 BTC
PRODUCTION
5.5"x3.5"
5 1/2 4.95 30.4 6,078.6 4,233.5 15.50 L-80 BTC-MOD
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
28.9
Set Depth …
5,442.2
Set Depth …
3,638.6
String Max No…
3 1/2
Tubing Description
TUBING
Wt (lb/ft)
9.30
Grade
L-80
Top Connection
EUE8RDMOD
ID (in)
2.99
Completion Details: excludes tubing, pup, space out, thread, RKB...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal
ID (in)
28.9 28.9 0.17 HANGER 8.000 VETCO GRAY TUBING HANGER 3.500
5,345.4 3,554.2 31.36 GAS LIFT 4.725 CAMCO KBG 2-9 2.900
5,389.0 3,591.7 29.71 NIPPLE 4.540 CAMCO DS NIPPLE w/ 2.812" NO
GO PROFILE
2.812
5,427.5 3,625.5 27.73 NO GO 4.500 BAKER NO GO SUB 3.000
5,428.3 3,626.2 27.69 SEAL ASSY 4.000 BAKER 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)
132.6 132.5 0.78 PACKER -
PATCH - UPR
2.725" PIIP UPPER PACKER,
MOE = 135' RKB, OAL = 4.1'
TO PULL: PACKER +
SPACER PIPE + ANCHOR
LATCH = 40.85
TTS PIIP CPP3
5085
7/6/2025 1.625
136.6 136.6 0.80 ANCHOR
LATCH ON
SPACER
PIPE
SPACER PIPE & ANCHOR
LATCH
CPAL
35139
7/6/2025 1.590
163.0 163.0 0.94 LEAK -
TUBING
TUBING LEAK 163' 1/29/2018 0.000
173.6 173.5 0.99 PACKER -
PATCH - LWR
2.725" PIIP LOWER PACKER,
MOE = 176' RKB, OAL = 4.01
TTS PIIP CPP3
5225
5/29/2025 1.625
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)
5,345.4 3,554.2 31.36 1 GAS LIFT DMY BK 1 0.0 3/19/2018 0.000
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
5,504.0 5,544.0 3,694.3 3,730.9 WS D, 1D-101 12/28/2000 4.0 IPERF 2.5" HSD, 60 deg phase
5,574.0 5,594.0 3,758.5 3,777.0 WS B, 1D-101 12/28/2000 4.0 IPERF 2.5" HSD, 60 deg phase
5,594.0 5,614.0 3,777.0 3,795.5 WS B, WS A-4,
1D-101
12/27/2000 4.0 IPERF 2.5" HSD, 60 deg phase
5,622.0 5,650.0 3,803.0 3,829.1 WS A4, 1D-101 12/27/2000 4.0 IPERF 2.5" HSD, 60 deg phase
5,668.0 5,684.0 3,845.9 3,860.9 WS A3, 1D-101 12/27/2000 4.0 IPERF 2.5" HSD, 60 deg phase
5,692.0 5,728.0 3,868.5 3,902.3 WS A3, 1D-101 12/26/2000 4.0 IPERF 2.5" HSD, 60 deg phase
5,750.0 5,800.0 3,923.0 3,970.1 WS A2, 1D-101 12/26/2000 4.0 IPERF 2.5" HSD, 60 deg phase
Cement Squeezes
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Des Com
Pump Start
Date
39.6 499.0 39.6 498.9 Primary – Full
Bore
Single Stage 77 bbl 11 ppg LiteCreet ... Pump 20
bbl Preflush. PT lines to 1000 psi. Mix & pump 110
sxs (77 bbl slurry) LiteCRETE @ 11.0 ppg. Drop plug
and displ w/H2O. Bump plug - floats held. Cmt
returns to surface 20-25 bbl. ^^Csg OD=10.75
5,431.0 6,079.0 3,628.6 4,233.9 Primary – Full
Bore
Lead 460 sx 10.7 ppg Arctic Set III + Tail 340 sx 15.8
ppg Class G... PT lines to 3500 psi. Pump 20 bbl
ARCO Wash @ 8.3 ppg; 40 bbl MudPushXL @ 10.0
ppg. Mix & pump 460 sxs ASIII Lite @ 10.7 ppg;
follow w/340 sxs Class G @ 15.8 ppg. Displ w/134
bbl mud @ 6 bpm - bumped plug - floats held. Full
circ thru out job. Recovered 160 bbl cmt. ^^Csg
OD=3.5 x 5.5
1D-101, 7/31/2025 10:03:41 AM
Vertical schematic (actual)
PRODUCTION 5.5"x3.5"; 30.4-
6,078.6
IPERF; 5,750.0-5,800.0
Primary – Full Bore; 5,431.0
ftKB
IPERF; 5,692.0-5,728.0
IPERF; 5,668.0-5,684.0
IPERF; 5,622.0-5,650.0
IPERF; 5,594.0-5,614.0
IPERF; 5,574.0-5,594.0
IPERF; 5,504.0-5,544.0
GAS LIFT; 5,345.4
SURFACE; 30.4-499.3
Primary – Full Bore; 39.6 ftKB
PACKER - PATCH - LWR; 173.6
LEAK - TUBING; 163.0
ANCHOR LATCH ON SPACER
PIPE; 136.6
PACKER - PATCH - UPR; 132.6
CONDUCTOR; 31.0-118.0
KUP INJ
KB-Grd (ft)
39.56
RR Date
11/27/200
0
Other Elev…
1D-101
...
TD
Act Btm (ftKB)
6,100.0
Well Attributes
Field Name
WEST SAK
Wellbore API/UWI
500292298600
Wellbore Status
INJ
Max Angle & MD
Incl (°)
68.43
MD (ftKB)
3,832.87
WELLNAME WELLBORE1D-101
Annotation
Last WO:
End DateH2S (ppm) DateComment
SSSV: NONE
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Friday, August 22, 2025
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Kam StJohn
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
ConocoPhillips Alaska, Inc.
1D-101
KUPARUK RIV U WSAK 1D-101
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 08/22/2025
1D-101
50-029-22986-00-00
200-183-0
W
SPT
3626
2001830 1500
974 973 974 974
OTHER P
Kam StJohn
7/15/2025
As Per Sundry 325-280 Post patch installation. Mono Bore
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-101
Inspection Date:
Tubing
OA
Packer Depth
190 1815 1770 1765IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitKPS250715132734
BBL Pumped:0.5 BBL Returned:0.4
Friday, August 22, 2025 Page 1 of 1
Originated: Delivered to:8-Jul-25Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPEDATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 1B-04 50-029-20595-00 910151309 Kuparuk River Plug Setting Record Field- Final 30-Jun-25 0 12 1B-05 50-029-20237-00 910106098 Kuparuk River Multi Finger Caliper Field & Processed 19-Jun-25 0 13 1B-05 50-029-20237-00 910106098 Kuparuk River Plug Setting Record Field- Final 21-Jun-25 0 14 1B-11 50-029-20657-00 910151309 Kuparuk River Multi Finger Caliper Field & Processed 1-Jul-25 0 15 1B-11 50-029-20657-00 910149873 Kuparuk River Plug Setting Record Field- Final 1-Jul-25 0 16 1B-15A 50-029-22465-01 910106169 Kuparuk River Plug Setting Record Field- Final 20-Jun-25 0 17 1D-101 50-029-22988-00 910151308 Kuparuk River Packer Setting Record Field- Final 6-Jul-25 0 18 1H-103 50-029-23593-00 910082841 Kuparuk River Multi Finger Caliper Field & Processed 21-Jun-25 0 19 1L-24 50-029-22170-00 910151023 Kuparuk River Packer Setting Record Field- Final 28-Jun-25 0 110 2A-16 50-103-20042-00 910150862 Kuparuk River Plug Setting Record Field- Final 27-Jun-25 0 1PLEASE 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 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:181-065177-001181-136204-256200-183218-003191-066185-147T40642T40643T40643T40644T40644T40645T40646T40647T40648T406497/9/202571D-10150-029-22988-00910151308Kuparuk RiverPacker Setting RecordField- Final6-Jul-2501Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.07.09 09:29:07 -08'00'
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 & Reset tubing 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
11.
Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD):
6100 None None
Casing Collapse
Structural N/A
Conductor N/A
Surface N/A
Intermediate N/A
Production N/A
Liner N/A
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:n1617@conocophillips.com
Contact Phone: 265-6678
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
4254 5686 3846 N/A
Subsequent Form Required:
Suspension Expiration Date:
N/A
N/A
N/A
118
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
Length Size
AOGCC USE ONLY
N/A
Tubing Grade:Tubing MD (ft):
PRK: 5428 / 3626 SSSV: N/A
Perforation Depth TVD (ft):
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL0025650 Kuparuk River
200-183
P.O. Box 100630, Anchorage, Alaska 99508 50-029-22986-0000
ConocoPhillips Alaska, Inc.
L-80
TVD Burst
5428
N/A
MD
N/A
4233
499
5.5x3.5 6079
Proposed Pools:
N/A N/A
N/A
469 499
N/A
118
5504 - 5800
6048
N/A
3694 - 3970
N/A N/A
16
10.75
87
N/A
Well Integrity Specialist
KRU 1D-101
6/6/2025
N/AN/A
3.5
N/A
PKR: Baker seal assembly SSSV: None
Perforation Depth MD (ft):
N/A
m
n
P
66
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: 2025.05.06 13:34:55-08'00'
Foxit PDF Editor Version: 13.1.6
Shelby Sumrall
325-280
By Grace Christianson at 3:31 pm, May 06, 2025
DSR-5/6/25JJL 5/6/25
10-404
A.Dewhurst 02JUN25*&:
Jessie L. Chmielowski
Digitally signed by Jessie L.
Chmielowski
Date: 2025.06.02 13:30:54 -08'00'06/02/25
RBDMS JSB 060225
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
May 6, 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-101 (PTD 200-183) to pull and reset a retrievable tubing patch
to allow access for a subsidence surveillance 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: 2025.05.06 13:33:50-08'00'
Foxit PDF Editor Version: 13.1.6
Shelby
Sumrall
Well Work Justification & Objectives (and date required if appropriate):
1D-101 is coming due for a subsidence compliance drift on 6/6/2025. The tubing patch at 136' needs
to be pulled to allow for the subsidence compliance drift and then reset after. The patch packer
depths may be adjusted slightly based on wellbore conditions.
Risk/Job Concerns:
• P2P tubing patch set from 136' to 177'.
• Tubing leak located at 163', possible additional tubing leak within patch setting interval
• Caliper shows ~20-40% tubing wall loss from 1000' down
• Subsidence surveillance- Sub flowchart location I-B End
• Need approved 10-403 prior to pulling and resetting tubing patch
Steps:
Relay
1. RIH, drift to top of patch at 136'.
2. RIH to pull upper P2P, spacer pipe, and anchor latch assembly at 136' (OAL 40.43').
3. RIH to pull lower P2P at 177' (OAL 4.01')
4. Brush and flush tubing to DS nipple at 5389'.
5. RIH w/ dummy plug drift to DS nipple at 5389'.
6. Pump 20 bbls 100*F diesel down tubing to preheat.
7. RIH w/ lower P2P, set at ~176'.
8. RIH w/ test tool to lower P2P at 176'.
9. Perform CMIT-TxIA to 2500 psi. Record pre, initial, 15 min & 30 min TIO's
10. RIH w/ upper P2P & spacer pipe assembly, sting into lower P2P at 176'. Patch should be 41'
element to element setting the upper P2P at 135'.
11. Perform MIT-IA to 2500 psi. Record pre, initial, 15 min & 30 min TIO's.
12. RDMO. Return well to Ops.
13. DHD to perform state witnessed MITIA once BOI and stabilized.
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag: SLM 5,578.0 1D-101 1/3/2020 fergusp
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Added new patch 1D-101 7/9/2024 jconne
Notes: General & Safety
Annotation End Date Last Mod By
NOTE:8/18/2010 pproven
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 31.0 118.0 118.0 62.58 H-40 WELDED
SURFACE 10 3/4 10.05 30.4 499.3 499.2 40.50 J-55 BTC
PRODUCTION
5.5"x3.5"
5 1/2 4.95 30.4 6,078.6 4,233.5 15.50 L-80 BTC-MOD
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
28.9
Set Depth …
5,442.2
Set Depth …
3,638.6
String Max No…
3 1/2
Tubing Description
TUBING
Wt (lb/ft)
9.30
Grade
L-80
Top Connection
EUE8RDMOD
ID (in)
2.99
Completion Details: excludes tubing, pup, space out, thread, RKB...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal
ID (in)
28.9 28.9 0.17 HANGER 8.000 VETCO GRAY TUBING HANGER 3.500
5,345.4 3,554.2 31.36 GAS LIFT 4.725 CAMCO KBG 2-9 2.900
5,389.0 3,591.7 29.71 NIPPLE 4.540 CAMCO DS NIPPLE w/ 2.812" NO
GO PROFILE
2.812
5,427.5 3,625.5 27.73 NO GO 4.500 BAKER NO GO SUB 3.000
5,428.3 3,626.2 27.69 SEAL ASSY 4.000 BAKER 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)
136.1 136.1 0.80 PACKER -
PATCH - UPR
2.725" PIIP UPPER PATCH
ASSEMBLY (MOE = 139'),
XO, SPACER PIPE, ANCHOR
LATCH (OAL 40.43)
TTS PIIP CPP3
5313
7/8/2024 1.625
140.2 140.2 0.82 ANCHOR
LATCH ON
SPACER
PIPE
SPACER PIPE CPAI 7/8/2024 1.590
163.0 163.0 0.94 LEAK -
TUBING
TUBING LEAK 163' 1/29/2018 0.000
177.5 177.5 1.01 PACKER -
PATCH - LWR
2.725" PIIP PACKER, OAL =
4.01', MOE = 180' RKB
TTS PIIP CPP3
5234,
CPAL
35182
7/8/2024 1.625
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)
5,345.4 3,554.2 31.36 1 GAS LIFT DMY BK 1 0.0 3/19/2018 0.000
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
5,504.0 5,544.0 3,694.3 3,730.9 WS D, 1D-101 12/28/2000 4.0 IPERF 2.5" HSD, 60 deg phase
5,574.0 5,594.0 3,758.5 3,777.0 WS B, 1D-101 12/28/2000 4.0 IPERF 2.5" HSD, 60 deg phase
5,594.0 5,614.0 3,777.0 3,795.5 WS B, WS A-4,
1D-101
12/27/2000 4.0 IPERF 2.5" HSD, 60 deg phase
5,622.0 5,650.0 3,803.0 3,829.1 WS A4, 1D-101 12/27/2000 4.0 IPERF 2.5" HSD, 60 deg phase
5,668.0 5,684.0 3,845.9 3,860.9 WS A3, 1D-101 12/27/2000 4.0 IPERF 2.5" HSD, 60 deg phase
5,692.0 5,728.0 3,868.5 3,902.3 WS A3, 1D-101 12/26/2000 4.0 IPERF 2.5" HSD, 60 deg phase
5,750.0 5,800.0 3,923.0 3,970.1 WS A2, 1D-101 12/26/2000 4.0 IPERF 2.5" HSD, 60 deg phase
1D-101, 7/9/2024 5:05:46 PM
Vertical schematic (actual)
PRODUCTION 5.5"x3.5"; 30.4-
6,078.6
FLOAT SHOE; 6,077.3-6,078.6
FLOAT COLLAR; 6,014.3-
6,015.5
IPERF; 5,750.0-5,800.0
IPERF; 5,692.0-5,728.0
IPERF; 5,668.0-5,684.0
IPERF; 5,622.0-5,650.0
IPERF; 5,594.0-5,614.0
IPERF; 5,574.0-5,594.0
IPERF; 5,504.0-5,544.0
SEAL ASSY; 5,428.3
SBE; 5,429.2-5,441.1
NIPPLE; 5,389.0
GAS LIFT; 5,345.4
PORT COLLAR; 613.9-616.6
SURFACE; 30.4-499.3
FLOAT SHOE; 498.1-499.3
PACKER - PATCH - LWR; 177.5
LEAK - TUBING; 163.0
ANCHOR LATCH ON SPACER
PIPE; 140.2
PACKER - PATCH - UPR; 136.1
CONDUCTOR; 31.0-118.0
HANGER; 30.4-34.1
HANGER; 30.4-33.8
HANGER; 28.9
KUP INJ
KB-Grd (ft)
39.56
RR Date
11/27/200
0
Other Elev…
1D-101
...
TD
Act Btm (ftKB)
6,100.0
Well Attributes
Field Name
WEST SAK
Wellbore API/UWI
500292298600
Wellbore Status
INJ
Max Angle & MD
Incl (°)
68.43
MD (ftKB)
3,832.87
WELLNAME WELLBORE1D-101
Annotation
Last WO:
End DateH2S (ppm) DateComment
SSSV: NONE
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Friday, August 30, 2024
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Kam StJohn
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
ConocoPhillips Alaska, Inc.
1D-101
KUPARUK RIV U WSAK 1D-101
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 08/30/2024
1D-101
50-029-22986-00-00
200-183-0
W
SPT
3626
2001830 1500
912 912 912 912
OTHER P
Kam StJohn
7/24/2024
MITIA post patch repair per Sundry # 324-319
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-101
Inspection Date:
Tubing
OA
Packer Depth
370 2020 1975 1970IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitKPS240724183323
BBL Pumped:0.7 BBL Returned:0.7
Friday, August 30, 2024 Page 1 of 1
9
À
9
9
9
9
9 9
9 9 9
9
9
9 9
9post patch repair
James B. Regg Digitally signed by James B. Regg
Date: 2024.08.30 15:34:21 -08'00'
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 Patch for Drift
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 6100 feet None feet
true vertical 4254 feet None feet
Effective Depth measured 5578'feet 136', 177'feet
true vertical 3762' feet 136', 177' feet
Perforation depth Measured depth
True Vertical depth
Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 5442' MD 3639' TVD
Packers and SSSV (type, measured and true vertical depth)
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:
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:
499' 499'
Burst Collapse
Production
Liner
6048'
Casing
4233'6079'
469'
118'Conductor
Surface
Intermediate
16"
10-3/4"
871'
measured
TVD
5-1/2" x 3-1/2"
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
200-183
50-029-22986-00-00
P.O. Box 100360
Anchorage, AK 99510
3. Address:
ConocoPhillips Alaska, Inc.
N/A
5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work:
ADL0025650
Kuparuk River Field/ West Sak Oil Pool
KRU 1D-101
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
118'
~ ~~
INJECTOR ~~
~
324-319
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
Shelby Sumrall
shelby.sumrall@conocophillips.com
(907) 265-6678Well Integrity Specialist
5504-5544', 5574-5614', 5622-5650', 5668-5684', 5692-5728', 5750-5800'
3694-3731', 3785-3795', 3803-3829', 3846-3861', 3868-3902', 3923-3970'
Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov
Packer: PIIP Patch Packer
Packer: PIIP Patch Packer
Packer: Seal Assembly
SSSV: None
136' MD
177' MD
5428' MD
N/A
136' TVD
177' TVD
3626' TVD
N/A
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: 2024.07.30 13:17:21-08'00'
Foxit PDF Editor Version: 13.0.0
Shelby
Sumrall
By Grace Christianson at 1:51 pm, Jul 30, 2024
DTTMSTART JOBTYP SUMMARYOPS
7/8/2024 ANNCOMM PULLED UPPER P2P AND SPACER @ 136' RKB, PULLED LOWER P2P @ 177'
RKB, RAN DMY 2.81" CA-2 DRIFT TO D NIPPLE @ 5389' RKB. JOB IN
PROGRESS
7/9/2024 ANNCOMM SET LOWER 2.72" P2P MID ELEMENT @ 180' RKB, PASSING 2500 PSI CMIT,
SET UPPER P2P MID ELEMENT @ 139' RKB, PASSING 2500 PSI MIT-IA (ser#
CPP35234), (ser# CPP35313, CPAL35182)...JOB COMPLETE
7/24/2024 ACQUIRE
DATA
(SW) STATE WITNESSED (KAM St.JOHN) MITIA (PASS) @ 2020 PSI
1D-101 Pull/Replace Tubing Patch
Summary of Operations
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag: SLM 5,578.0 1D-101 1/3/2020 fergusp
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Added new patch 1D-101 7/9/2024 jconne
Notes: General & Safety
Annotation End Date Last Mod By
NOTE: 8/18/2010 pproven
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 31.0 118.0 118.0 62.58 H-40 WELDED
SURFACE 10 3/4 10.05 30.4 499.3 499.2 40.50 J-55 BTC
PRODUCTION
5.5"x3.5"
5 1/2 4.95 30.4 6,078.6 4,233.5 15.50 L-80 BTC-MOD
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
28.9
Set Depth
5,442.2
Set Depth
3,638.6
String Max No
3 1/2
Tubing Description
TUBING
Wt (lb/ft)
9.30
Grade
L-80
Top Connection
EUE8RDMOD
ID (in)
2.99
Completion Details: excludes tubing, pup, space out, thread, RKB...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal
ID (in)
28.9 28.9 0.17 HANGER 8.000 VETCO GRAY TUBING HANGER 3.500
5,345.4 3,554.2 31.36 GAS LIFT 4.725 CAMCO KBG 2-9 2.900
5,389.0 3,591.7 29.71 NIPPLE 4.540 CAMCO DS NIPPLE w/ 2.812" NO
GO PROFILE
2.812
5,427.5 3,625.5 27.73 NO GO 4.500 BAKER NO GO SUB 3.000
5,428.3 3,626.2 27.69 SEAL ASSY 4.000 BAKER 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)
136.1 136.1 0.80 PACKER -
PATCH - UPR
2.725" PIIP UPPER PATCH
ASSEMBLY (MOE = 139'),
XO, SPACER PIPE, ANCHOR
LATCH (OAL 40.43)
TTS PIIP CPP3
5313
7/8/2024 1.625
140.2 140.2 0.82 ANCHOR
LATCH ON
SPACER
PIPE
SPACER PIPE CPAI 7/8/2024 1.590
163.0 163.0 0.94 LEAK -
TUBING
TUBING LEAK 163' 1/29/2018 0.000
177.5 177.5 1.01 PACKER -
PATCH - LWR
2.725" PIIP PACKER, OAL =
4.01', MOE = 180' RKB
TTS PIIP CPP3
5234,
CPAL
35182
7/8/2024 1.625
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)
5,345.4 3,554.2 31.36 1 GAS LIFT DMY BK 1 0.0 3/19/2018 0.000
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
5,504.0 5,544.0 3,694.3 3,730.9 WS D, 1D-101 12/28/2000 4.0 IPERF 2.5" HSD, 60 deg phase
5,574.0 5,594.0 3,758.5 3,777.0 WS B, 1D-101 12/28/2000 4.0 IPERF 2.5" HSD, 60 deg phase
5,594.0 5,614.0 3,777.0 3,795.5 WS B, WS A-4,
1D-101
12/27/2000 4.0 IPERF 2.5" HSD, 60 deg phase
5,622.0 5,650.0 3,803.0 3,829.1 WS A4, 1D-101 12/27/2000 4.0 IPERF 2.5" HSD, 60 deg phase
5,668.0 5,684.0 3,845.9 3,860.9 WS A3, 1D-101 12/27/2000 4.0 IPERF 2.5" HSD, 60 deg phase
5,692.0 5,728.0 3,868.5 3,902.3 WS A3, 1D-101 12/26/2000 4.0 IPERF 2.5" HSD, 60 deg phase
5,750.0 5,800.0 3,923.0 3,970.1 WS A2, 1D-101 12/26/2000 4.0 IPERF 2.5" HSD, 60 deg phase
1D-101, 7/29/2024 4:56:27 PM
Vertical schematic (actual)
PRODUCTION 5.5"x3.5"; 30.4-
6,078.6
FLOAT SHOE; 6,077.3-6,078.6
FLOAT COLLAR; 6,014.3-
6,015.5
IPERF; 5,750.0-5,800.0
IPERF; 5,692.0-5,728.0
IPERF; 5,668.0-5,684.0
IPERF; 5,622.0-5,650.0
IPERF; 5,594.0-5,614.0
IPERF; 5,574.0-5,594.0
IPERF; 5,504.0-5,544.0
SEAL ASSY; 5,428.3
SBE; 5,429.2-5,441.1
NIPPLE; 5,389.0
GAS LIFT; 5,345.4
PORT COLLAR; 613.9-616.6
SURFACE; 30.4-499.3
FLOAT SHOE; 498.1-499.3
PACKER - PATCH - LWR; 177.5
LEAK - TUBING; 163.0
ANCHOR LATCH ON SPACER
PIPE; 140.2
PACKER - PATCH - UPR; 136.1
CONDUCTOR; 31.0-118.0
HANGER; 30.4-34.1
HANGER; 30.4-33.8
HANGER; 28.9
KUP INJ
KB-Grd (ft)
39.56
RR Date
11/27/200
0
Other Elev
1D-101
...
TD
Act Btm (ftKB)
6,100.0
Well Attributes
Field Name
WEST SAK
Wellbore API/UWI
500292298600
Wellbore Status
INJ
Max Angle & MD
Incl (°)
68.43
MD (ftKB)
3,832.87
WELLNAME WELLBORE1D-101
Annotation
Last WO:
End DateH2S (ppm) DateComment
SSSV: NONE
Originated: Delivered to:13-Aug-24
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 # E SET#
1 1A-26 50-029-22115-00 909422974 Kuparuk River Leak Detect Log Field- Final 18-Jul-24 0 1
2 1A-26 50-029-22115-00 909422974 Kuparuk River Multi Finger Caliper Field & Processed 18-Jul-24 0 1
3 1D-12 50-029-22948-00 909422973 Kuparuk River Leak Detect Log Field- Final 15-Jul-24 0 1
4 1D-12 50-029-22948-00 909422973 Kuparuk River Multi Finger Caliper Field & Processed 15-Jul-24 0 1
5 1D-101 50-029-22988-00 909422480 Kuparuk River Patch Setting Record Field- Final 9-Jul-24 0 1
6 1F-03A 50-029-20853-01 909423152 Kuparuk River Packer Setting Record Field- Final 20-Jul-24 0 1
7 1G-01 50-029-20805-00 909469740 Kuparuk River Multi Finger Caliper Field & Processed 31-Jul-24 0 1
8 1G-01 50-029-20805-00 909469740 Kuparuk River Packer Setting Record Field- Final 30-Jul-24 0 1
9 1G-07A 50-029-20872-01 909383029 Kuparuk River Leak Detect Log Field- Final 2-Jul-24 0 1
10 1G-07A 50-029-20872-01 909383029 Kuparuk River Multi Finger Caliper Field & Processed 11-Jul-24 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:
T39431
T39431
T39432
T39432
T39433
T39434
T39435
T39435
T39436
T39436
190-166
199-084
200-183
196-096
182-130
218-051
8-14-2024
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2024.08.14 08:29:49 -08'00'
5 1D-101 50-029-22988-00 909422480 Kuparuk River Patch Setting Record Field- Final 9-Jul-24 0 1
200-183
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 & Reset tubing 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
11.
Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD):
6100 None None
Casing Collapse
Structural N/A
Conductor N/A
Surface N/A
Intermediate N/A
Production N/A
Liner N/A
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:Jan Byrne
Contact Email:n1617@conocophillips.com
Contact Phone: 265-6471
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
4254 5686 3846 N/A
Subsequent Form Required:
Suspension Expiration Date:
N/A
N/A
N/A
118
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
Length Size
AOGCC USE ONLY
N/A
Tubing Grade:Tubing MD (ft):
PRK: 5428 / 3626 SSSV: N/A
Perforation Depth TVD (ft):
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL0025650 Kuparuk River
200-183
P.O. Box 100630, Anchorage, Alaska 99508 50-029-22986-0000
ConocoPhillips Alaska, Inc.
L-80
TVD Burst
5428
N/A
MD
N/A
42335.5x3.5 6079
Proposed Pools:
N/A N/A
N/A
469 499
N/A
118
499
5504 - 5800
6048
N/A
3694 - 3970
N/A N/A
16
10.75
87
N/A
Well Integrity Specialist
KRU 1D-101
6/6/2024
N/AN/A
3.5
N/A
PKR: Baker seal assembly SSSV: None
Perforation Depth MD (ft):
N/A
m
n
P
s
66
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: 2024.05.30 11:30:59-08'00'
Foxit PDF Editor Version: 13.0.0
Jan Byrne
324-319
By Grace Christianson at 11:53 am, May 30, 2024
10-404
SFD 5/30/2024 DSR-5/30/24
X
X
VTL 6/24/2024*&:JLC 6/24/2024
Brett W. Huber, Sr.
Digitally signed by Brett W.
Huber, Sr.
Date: 2024.06.24 15:22:02 -08'00'06/24/24
RBDMS JSB 062624
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
May 29, 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-101 (PTD 200-183) to pull and reset a retrievable tubing patch
to allow access for a subsidence surveillance drift.
If you need additional information, please contact us at 265-6471.
Sincerely,
Jan Byrne
Well Integrity Specialist
ConocoPhillips Alaska, Inc.
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: 2024.05.30 11:32:03-08'00'
Foxit PDF Editor Version: 13.0.0
Jan Byrne
Well Work Justification & Objectives (and date required if appropriate):
1D-101 is coming due for a subsidence compliance drift on 6/6/2024. The tubing patch at 138' needs
to be pulled to allow for the subsidence compliance drift and then reset after. The patch packer
depths may be adjusted slightly based on wellbore conditions.
Risk/Job Concerns:
• P2P tubing patch set from 138' to 179'.
• Tubing leak located at 163', possible additional tubing leak within patch setting interval
• Caliper shows ~20-40% tubing wall loss from 1000' down
• Subsidence surveillance- Sub flowchart location I-B End
• Need approved 10-403 prior to pulling and resetting tubing patch
Steps:
Relay
1. RIH, drift to top of patch at 138'.
2. RIH to pull upper P2P, spacer pipe, and anchor latch assembly at 138' (OAL 40.83').
3. RIH to pull lower P2P at 179' (OAL 4.01')
4. Brush and flush tubing to DS nipple at 5389'.
5. RIH w/ dummy plug drift to DS nipple at 5389'.
6. Pump 20 bbls 100*F diesel down tubing to preheat.
7. RIH w/ lower P2P, set at ~179'.
8. RIH w/ test tool to lower P2P at 179'.
9. Perform CMIT-TxIA to 2500 psi. Record pre, initial, 15 min & 30 min TIO's
10. RIH w/ upper P2P & spacer pipe assembly, sting into lower P2P at 179'. Patch should be 41'
element to element setting the upper P2P at 138'.
11. Perform MIT-IA to 2500 psi. Record pre, initial, 15 min & 30 min TIO's.
12. RDMO. Return well to Ops.
13. DHD to perform state witnessed MITIA once BOI and stabilized.
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag: SLM 5,578.0 1D-101 1/3/2020 fergusp
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Set patch.1D-101 6/6/2023 fergusp
Notes: General & Safety
Annotation End Date Last Mod By
NOTE:8/18/2010 pproven
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 31.0 118.0 118.0 62.58 H-40 WELDED
SURFACE 10 3/4 10.05 30.4 499.3 499.2 40.50 J-55 BTC
PRODUCTION
5.5"x3.5"
5 1/2 4.95 30.4 6,078.6 4,233.5 15.50 L-80 BTC-MOD
Tubing Strings: string max indicates LONGEST segment of string
Top (ftKB)
28.9
Set Depth …
5,442.2
Set Depth …
3,638.6
String Ma…
3 1/2
Tubing Description
TUBING
Wt (lb/ft)
9.30
Grade
L-80
Top Connection
EUE8RDMOD
ID (in)
2.99
Completion Details: excludes tubing, pup, space out, thread, RKB...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal
ID (in)
28.9 28.9 0.17 HANGER 8.000 VETCO GRAY TUBING HANGER 3.500
5,345.4 3,554.2 31.36 GAS LIFT 4.725 CAMCO KBG 2-9 2.900
5,389.0 3,591.7 29.71 NIPPLE 4.540 CAMCO DS NIPPLE w/ 2.812" NO
GO PROFILE
2.812
5,427.5 3,625.5 27.73 NO GO 4.500 BAKER NO GO SUB 3.000
5,428.3 3,626.2 27.69 SEAL ASSY 4.000 BAKER 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)
138.0 138.0 0.81 PACKER -
PATCH - UPR
Upper patch assembly 2.72"
P2P, xo, spacer pipe, anchor
latch (OAL 40.86')
CPP3
5361/
CPAL
35208
6/6/2023 1.600
142.0 142.0 0.83 SPACER
PIPE
Spacer pipe CPAI 6/6/2023 1.600
163.0 163.0 0.94 LEAK -
TUBING
TUBING LEAK 163' 1/29/2018 0.000
179.0 179.0 1.02 PACKER -
PATCH - LWR
2.72" P2P, 1.625" ID, 3.68'
OAL
CPP3
5358
6/6/2023 1.625
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)
5,345.4 3,554.2 31.36 1 GAS LIFT DMY BK 1 0.0 3/19/2018 0.000
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
5,504.0 5,544.0 3,694.3 3,730.9 WS D, 1D-101 12/28/2000 4.0 IPERF 2.5" HSD, 60 deg phase
5,574.0 5,594.0 3,758.5 3,777.0 WS B, 1D-101 12/28/2000 4.0 IPERF 2.5" HSD, 60 deg phase
5,594.0 5,614.0 3,777.0 3,795.5 WS B, WS A-4,
1D-101
12/27/2000 4.0 IPERF 2.5" HSD, 60 deg phase
5,622.0 5,650.0 3,803.0 3,829.1 WS A4, 1D-101 12/27/2000 4.0 IPERF 2.5" HSD, 60 deg phase
5,668.0 5,684.0 3,845.9 3,860.9 WS A3, 1D-101 12/27/2000 4.0 IPERF 2.5" HSD, 60 deg phase
5,692.0 5,728.0 3,868.5 3,902.3 WS A3, 1D-101 12/26/2000 4.0 IPERF 2.5" HSD, 60 deg phase
5,750.0 5,800.0 3,923.0 3,970.1 WS A2, 1D-101 12/26/2000 4.0 IPERF 2.5" HSD, 60 deg phase
1D-101, 6/7/2023 11:16:29 AM
Vertical schematic (actual)
PRODUCTION 5.5"x3.5"; 30.4-
6,078.6
IPERF; 5,750.0-5,800.0
IPERF; 5,692.0-5,728.0
IPERF; 5,668.0-5,684.0
IPERF; 5,622.0-5,650.0
IPERF; 5,594.0-5,614.0
IPERF; 5,574.0-5,594.0
IPERF; 5,504.0-5,544.0
GAS LIFT; 5,345.4
SURFACE; 30.4-499.3
PACKER - PATCH - LWR; 179.0
LEAK - TUBING; 163.0
SPACER PIPE; 142.0
PACKER - PATCH - UPR; 138.0
CONDUCTOR; 31.0-118.0
KUP INJ
KB-Grd (ft)
39.56
RR Date
11/27/200
0
Other Elev…
1D-101
...
TD
Act Btm (ftKB)
6,100.0
Well Attributes
Field Name
WEST SAK
Wellbore API/UWI
500292298600
Wellbore Status
INJ
Max Angle & MD
Incl (°)
68.43
MD (ftKB)
3,832.87
WELLNAME WELLBORE1D-101
Annotation
Last WO:
End DateH2S (ppm) DateComment
SSSV: NONE
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Thursday, July 27, 2023
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Austin McLeod
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
ConocoPhillips Alaska, Inc.
1D-101
KUPARUK RIV U WSAK 1D-101
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 07/27/2023
1D-101
50-029-22986-00-00
200-183-0
W
SPT
3626
2001830 1500
620 623 620 620
OTHER P
Austin McLeod
6/16/2023
MITIA post patch. Sundry 323-172. Monobore.
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-101
Inspection Date:
Tubing
OA
Packer Depth
1450 2310 2260 2250IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitSAM230617184425
BBL Pumped:0.3 BBL Returned:0.3
Thursday, July 27, 2023 Page 1 of 1
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post patch. Sundry 323-172.
James B. Regg Digitally signed by James B. Regg
Date: 2023.07.31 11:16:26 -08'00'
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 feet None feet
true vertical feet None feet
Effective Depth measured feet 138', 179'feet
true vertical feet 138', 179'feet
Perforation depth Measured depth
True Vertical depth
Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 5442' MD 3639' TVD
Packers and SSSV (type, measured and true vertical depth) 138' MD
179' MD
N/A
138' MD
179' MD
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:
323-172
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) 265-6558Intervention Engineer
5504-5554', 5574-5614', 5622-5650', 5668-5684', 5692-5728', 5750-5800'
3694-3731', 3758-3795', 3803-3829', 3846-3861', 3868-3902', 3923-3970'
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
118'
~ ~~
INJECTOR ~~
~
measured
TVD
5-1/2" x 3-1/2"
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
200-183
50-029-22986-00-00
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-101
Plugs
Junk measured
Length
Production
Liner
6048'
Casing
4233'6079'
469'
118'Conductor
Surface
Intermediate
16"
10-3/4"
87'
499' 499'
Burst Collapse
Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov
6100'
4254'
5578'
3762'
By Grace Christianson at 3:31 pm, Jun 27, 2023
Digitally signed by Allen Eschete
DN: CN=Allen Eschete, E=Allen.Eschete@ConocoPhillips.com
Reason: I have reviewed this document
Location:
Date: 2023.06.27 13:14:47-08'00'
Foxit PDF Editor Version: 12.1.2
Allen Eschete
DTTMSTART JOBTYP SUMMARYOPS
6/5/2023 ANNCOMM PULLED 2.72" x 42' UPPER PATCH ASSEMBLY @ 134' RKB, PULLED
2.72" LOWER P2P @ 175' RKB. IN PROGRESS.
6/6/2023 ANNCOMM BRUSH & FLUSH TUBING & RAN 2.81" PLUG DRIFT TO DS-NIP @ 5389'
RKB SET P2P LOWER PACKER @ 179' RKB MID ELEMENT, RAN TTS
TEST TOOL TO LOWER PACKER AND PERFORMED CMIT-TxIA @
2500psi, PASSED, SET PATCH & UPPER PACKER @ 138' RKB MID
ELEMENT, PERFORMED MIT-IA @ 2500psi, PASSED, JOB COMPLETE
CPP35361/CPAL35208/CPP35358
KRU 1D-101 Tubing Patch
Summary of Operations
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag: SLM 5,578.0 1D-101 1/3/2020 fergusp
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Set patch. 1D-101 6/6/2023 fergusp
Notes: General & Safety
Annotation End Date Last Mod By
NOTE: 8/18/2010 pproven
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 31.0 118.0 118.0 62.58 H-40 WELDED
SURFACE 10 3/4 10.05 30.4 499.3 499.2 40.50 J-55 BTC
PRODUCTION
5.5"x3.5"
5 1/2 4.95 30.4 6,078.6 4,233.5 15.50 L-80 BTC-MOD
Tubing Strings: string max indicates LONGEST segment of string
Top (ftKB)
28.9
Set Depth
5,442.2
Set Depth
3,638.6
String Ma
3 1/2
Tubing Description
TUBING
Wt (lb/ft)
9.30
Grade
L-80
Top Connection
EUE8RDMOD
ID (in)
2.99
Completion Details: excludes tubing, pup, space out, thread, RKB...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal
ID (in)
28.9 28.9 0.17 HANGER 8.000 VETCO GRAY TUBING HANGER 3.500
5,345.4 3,554.2 31.36 GAS LIFT 4.725 CAMCO KBG 2-9 2.900
5,389.0 3,591.7 29.71 NIPPLE 4.540 CAMCO DS NIPPLE w/ 2.812" NO
GO PROFILE
2.812
5,427.5 3,625.5 27.73 NO GO 4.500 BAKER NO GO SUB 3.000
5,428.3 3,626.2 27.69 SEAL ASSY 4.000 BAKER 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)
138.0 138.0 0.81 PACKER -
PATCH - UPR
Upper patch assembly 2.72"
P2P, xo, spacer pipe, anchor
latch (OAL 40.86')
CPP3
5361/
CPAL
35208
6/6/2023 1.600
142.0 142.0 0.83 SPACER
PIPE
Spacer pipe CPAI 6/6/2023 1.600
163.0 163.0 0.94 LEAK -
TUBING
TUBING LEAK 163' 1/29/2018 0.000
179.0 179.0 1.02 PACKER -
PATCH - LWR
2.72" P2P, 1.625" ID, 3.68'
OAL
CPP3
5358
6/6/2023 1.625
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)
5,345.4 3,554.2 31.36 1 GAS LIFT DMY BK 1 0.0 3/19/2018 0.000
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
5,504.0 5,544.0 3,694.3 3,730.9 WS D, 1D-101 12/28/2000 4.0 IPERF 2.5" HSD, 60 deg phase
5,574.0 5,594.0 3,758.5 3,777.0 WS B, 1D-101 12/28/2000 4.0 IPERF 2.5" HSD, 60 deg phase
5,594.0 5,614.0 3,777.0 3,795.5 WS B, WS A-4,
1D-101
12/27/2000 4.0 IPERF 2.5" HSD, 60 deg phase
5,622.0 5,650.0 3,803.0 3,829.1 WS A4, 1D-101 12/27/2000 4.0 IPERF 2.5" HSD, 60 deg phase
5,668.0 5,684.0 3,845.9 3,860.9 WS A3, 1D-101 12/27/2000 4.0 IPERF 2.5" HSD, 60 deg phase
5,692.0 5,728.0 3,868.5 3,902.3 WS A3, 1D-101 12/26/2000 4.0 IPERF 2.5" HSD, 60 deg phase
5,750.0 5,800.0 3,923.0 3,970.1 WS A2, 1D-101 12/26/2000 4.0 IPERF 2.5" HSD, 60 deg phase
1D-101, 6/21/2023 7:31:35 AM
Vertical schematic (actual)
PRODUCTION 5.5"x3.5"; 30.4-
6,078.6
IPERF; 5,750.0-5,800.0
IPERF; 5,692.0-5,728.0
IPERF; 5,668.0-5,684.0
IPERF; 5,622.0-5,650.0
IPERF; 5,594.0-5,614.0
IPERF; 5,574.0-5,594.0
IPERF; 5,504.0-5,544.0
GAS LIFT; 5,345.4
SURFACE; 30.4-499.3
PACKER - PATCH - LWR; 179.0
LEAK - TUBING; 163.0
SPACER PIPE; 142.0
PACKER - PATCH - UPR; 138.0
CONDUCTOR; 31.0-118.0
KUP INJ
KB-Grd (ft)
39.56
RR Date
11/27/200
0
Other Elev
1D-101
...
TD
Act Btm (ftKB)
6,100.0
Well Attributes
Field Name
WEST SAK
Wellbore API/UWI
500292298600
Wellbore Status
INJ
Max Angle & MD
Incl (°)
68.43
MD (ftKB)
3,832.87
WELLNAME WELLBORE1D-101
Annotation
Last WO:
End DateH2S (ppm) DateComment
SSSV: NONE
VTL 4/13/23
DSR-3/22/23
X
MDG 3/29/2023
X
10-404
GCW 04/13/23JLC 4/13/2023
04/13/2023
Brett W.
Huber, Sr.
Digitally signed by Brett W.
Huber, Sr.
Date: 2023.04.13 15:04:23
-08'00'
RBDMS JSB 041423
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-101
KUPARUK RIV U WSAK 1D-101
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 09/01/2022
1D-101
50-029-22986-00-00
200-183-0
W
SPT
3626
2001830 1500
335 335 335 335
4YRTST P
Lou Laubenstein
8/9/2022
4-Year test, monobore well
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-101
Inspection Date:
Tubing
OA
Packer Depth
940 1800 1760 1760IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitLOL220810094033
BBL Pumped:0.2 BBL Returned:0.2
Thursday, September 1, 2022 Page 1 of 1
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monobore well
James B. Regg Digitally signed by James B. Regg
Date: 2022.09.01 14:44:22 -08'00'
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Submit to:
OOPERATOR:
FIEL DD // UNITT // PAD:
DATE:
OPERATORR REP:
AOGCCC REP:
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD 2001900 Type Inj N Tubing 580 585 585 585 Type Test P
Packer TVD 5977 BBL Pump 2.1 IA 145 1800 1770 1770 Interval 4
Test psi 1500 BBL Return 2.1 OA 43 54 54 54 Result P
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD 2001830 Type Inj N Tubing 150 160 160 160 Type Test P
Packer TVD 3626 BBL Pump 0.3 IA 380 1800 1750 1750 Interval 4
Test psi 1500 BBL Return 0.3 OA Result P
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD 1972400 Type Inj N Tubing 100 1800 1740 1730 Type Test P
Packer TVD 3621 BBL Pump 1.7 IA 25 1800 1740 1730 Interval 4
Test psi 1500 BBL Return 1.6 OA Result P
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD 2000470 Type Inj N Tubing 500 505 505 505 Type Test P
Packer TVD 3526 BBL Pump 0.8 IA 140 1800 1700 1690 Interval 4
Test psi 1500 BBL Return 0.5 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
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
Galle / Borge
07/14/22
Notes:
Notes:
1D-40A
1D-101
1D-137
Notes:Single casing well
1D-106
Notes:Single casing well. Tubing plug at 4444' MD. Open Pocket at 4286' MD. CMIT T x IA.
Notes:Single casing well
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
MMec h an i c all In t eg r ityy Tes t
jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov
Form 10-426 (Revised 01/2017)2022-0714_MIT_KRU_1D-pad_4wells
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By Samantha Carlisle at 11:36 am, Mar 10, 2022
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10-404
X
SFD
West Sak Oil
SFD 3/10/2022
X
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VTL 3/18/22
Jeremy Price Digitally signed by Jeremy Price
Date: 2022.03.18 15:15:21 -08'00'
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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
04/07/2021
PTD: 2001830
E-Set: 34903
MEMORANDUM
TO: Jim Regg 7e� 4j zoji�
P.I. Supervisor
FROM: Brian Bixby
Petroleum Inspector
NON -CONFIDENTIAL
State of Alaska
Alaska Oil and Gas Conservation Commission
DATE: Wednesday, March 31, 2021
SUBJECT: Mechanical Integrity Tests
ConocoPhillips Alaska, Inc.
1D-101
KUPARUK RIV U WSAK ID -101
Src: Inspector
Reviewed By:
-IF
�n
P.I. Supry J0 -
Comm
Well Name KUPARUK RIV U WSAK ID -101 API Well Number 50-029-22986-00-00 Inspector Name: Brian Bixby
Permit Number: 200-183-0 Inspection Date: 3/27/2021
Insp Num: mitBDB210328055746
Rel Insp Num:
Packer
Well ID -101 Typelnj W TVD
PTD 2001830 Type Test SPT Test psi
BBL Pumped: 0.2 IBBL Returned:
OTHER _ P/F
Interva(
ch ✓
Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min
3626 Tubing 514 518 514 514
1500 IA 1260 1810 - 1790 1780 ��,- -
02 OA
P
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 7760 feet None feet
true vertical 4254 feet None feet
Effective Depth measured 5686 feet 5428 feet
true vertical 3846 feet 3526 feet
Perforation depth Measured depth 5504 - 5800 feet
True Vertical depth 3694 - 3970 feet
Tubing (size, grade, measured and true vertical depth)3.5 L-80 5442 3639
Packers and SSSV (type, measured and true vertical depth)Baker seal assembly 5428 / 3526 None NA
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:
321-104
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 87 16 118 118
Production 6048 5.5x3.5 6079 4233
Surface 469 10.75 499 499
Packer measured
true vertical
Casing Length Size MD TVD
N/A Kuparuk River Field / West Sak Oil Pool
Plugs measured
Junk measured
Burst Collapse
200-183
50-029-22986-0000
ADL0025650 KRU 1D-101
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
Ot
200
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孶孳孽孶孶孰孳孻孪孳孳孪
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
VTL 5/5/21 SFD 4/1/2021DSR-4/1/21
6100
RBDMS HEW 3/30/2021
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 321-104 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-101 (PTD 200-183).
If you need additional information, please contact us at 659-7224.
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孶孳孽孳孷孰孳孻孪孳孳孪
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 patch to acquire subsidence surveillance drift as per approved sundry 321-104.
Wellwork is copied below.
03/14/21
((SUBSIDENCE SURVEILLANCE)); PULLED 2.72" P2P PATCH ASSEMBLY @ 137' RKB; DRIFT W/ 2.812" DMY CA-2
PLUG BRUSH ASSEMBLY DOWN TO DS NIPPLE @ 5389' RKB (NO ANOMALIES) & BRUSH PATCH INTERVAL W/
100° DIESEL; ((UTILIZING EDPU)) SET LOWER 2.72" P2P W/ MID ELEMENT (4.01' OAL / CPP35290) @ 178' RKB;
W/ TEST TTS TEST TOOL IN LOWER PACKER CMIT TBG X IA T O2500 PSI (PASS); ((UTILIZING DPU)) SET UPPER
2.72" P2P, SPACER PIPE, & ANCHOR LATCH (41.73' OAL / CPP35224 / CPAL35139) W/ MID ELEMENT @ 137.11'
RKB. MIT IA TO 2500 PSI (PASS). JOB COMPLETE.
MITIA 2500 PRE MIT IA T/I= 475/550 PRESSURE UP (.75 BBLS) T/I= 450/2525, 15 MIN T/I= 450/2460, 30 MIN
T/I= 450/2450
Last Tag
Annotation Depth (ftKB) End Date Wellbore Last Mod By
Last Tag: SLM 5,578.0 1/3/2020 1D-101 fergusp
Last Rev Reason
Annotation End Date Wellbore Last Mod By
Rev Reason: Replaced Tbg Patch 3/14/2021 1D-101 zembaej
Casing Strings
Casing Description
CONDUCTOR
OD (in)
16
ID (in)
15.06
Top (ftKB)
31.0
Set Depth (ftKB)
118.0
Set Depth (TVD) …
118.0
Wt/Len (l…
62.58
Grade
H-40
Top Thread
WELDED
Casing Description
SURFACE
OD (in)
10 3/4
ID (in)
10.05
Top (ftKB)
30.4
Set Depth (ftKB)
499.3
Set Depth (TVD) …
499.2
Wt/Len (l…
40.50
Grade
J-55
Top Thread
BTC
Casing Description
PRODUCTION 5.5"x3.5"
OD (in)
5 1/2
ID (in)
4.95
Top (ftKB)
30.4
Set Depth (ftKB)
6,078.6
Set Depth (TVD) …
4,233.5
Wt/Len (l…
15.50
Grade
L-80
Top Thread
BTC-MOD
Tubing Strings
Tubing Description
TUBING
String Ma…
3 1/2
ID (in)
2.99
Top (ftKB)
28.9
Set Depth (ft…
5,442.2
Set Depth (TVD) (…
3,638.6
Wt (lb/ft)
9.30
Grade
L-80
Top Connection
EUE8RDMOD
Completion Details
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des Com
Nominal
ID (in)
28.9 28.9 0.17 HANGER VETCO GRAY TUBING HANGER 3.500
5,389.0 3,591.7 29.71 NIPPLE CAMCO DS NIPPLE w/ 2.812" NO GO PROFILE2.812
5,427.5 3,625.5 27.73 NO GO BAKER NO GO SUB 3.000
5,428.3 3,626.2 27.69 SEAL ASSY BAKER 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
137.0 137.0 0.81 PACKER-PATCH
-UPPER
2.72" P2P PINNED TO RELEASE @
2400LBS (PACKER,SPACER PIPE, &
ANCHOR LATCH OAL=41.73')
3/14/2021 1.625 CPP35244
141.0 141.0 0.83 SPACER PIPE &
ANCHOR LATCH
2-1/16", P110 SPACER PIPE & ANCHOR
LATCH ASSEMBLY
3/14/2021 1.597 CPAL35139
163.0 163.0 0.94 LEAK - TUBING TUBING LEAK 163' 1/29/2018 0.000
176.0 176.0 1.00 PACKER-PACH-
LOWER
2.72" P2P PINNED TO RELEASE @
2400LBS (4.01' OAL)
3/14/2021 1.625 CPP35290
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft
)Type Com
5,504.0 5,544.0 3,694.3 3,730.9 WS D, 1D-101 12/28/2000 4.0 IPERF 2.5" HSD, 60 deg phase
5,574.0 5,594.0 3,758.5 3,777.0 WS B, 1D-101 12/28/2000 4.0 IPERF 2.5" HSD, 60 deg phase
5,594.0 5,614.0 3,777.0 3,795.5 WS B, WS A-4,
1D-101
12/27/2000 4.0 IPERF 2.5" HSD, 60 deg phase
5,622.0 5,650.0 3,803.0 3,829.1 WS A4, 1D-101 12/27/2000 4.0 IPERF 2.5" HSD, 60 deg phase
5,668.0 5,684.0 3,845.9 3,860.9 WS A3, 1D-101 12/27/2000 4.0 IPERF 2.5" HSD, 60 deg phase
5,692.0 5,728.0 3,868.5 3,902.3 WS A3, 1D-101 12/26/2000 4.0 IPERF 2.5" HSD, 60 deg phase
5,750.0 5,800.0 3,923.0 3,970.1 WS A2, 1D-101 12/26/2000 4.0 IPERF 2.5" HSD, 60 deg phase
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 5,345.4 3,554.2 CAMCO KBG 2-
9
1 GAS LIFT DMY BK 0.000 0.0 3/19/2018
Notes: General & Safety
End Date Annotation
8/18/2010 NOTE:
1D-101, 3/15/2021 8:43:24 AM
Vertical schematic (actual)
PRODUCTION 5.5"x3.5"; 30.4-
6,078.6
IPERF; 5,750.0-5,800.0
IPERF; 5,692.0-5,728.0
IPERF; 5,668.0-5,684.0
IPERF; 5,622.0-5,650.0
IPERF; 5,594.0-5,614.0
IPERF; 5,574.0-5,594.0
IPERF; 5,504.0-5,544.0
SEAL ASSY; 5,428.3
NIPPLE; 5,389.0
GAS LIFT; 5,345.4
SURFACE; 30.4-499.3
PACKER-PACH-LOWER; 176.0
LEAK - TUBING; 163.0
SPACER PIPE & ANCHOR
LATCH; 141.0
PACKER-PATCH-UPPER; 137.0
CONDUCTOR; 31.0-118.0
HANGER; 28.9
KUP INJ
KB-Grd (ft)
39.56
Rig Release Date
11/27/2000
1D-101
...
TD
Act Btm (ftKB)
6,100.0
Well Attributes
Field Name
WEST SAK
Wellbore API/UWI
500292298600
Wellbore Status
INJ
Max Angle & MD
Incl (°)
68.43
MD (ftKB)
3,832.87
WELLNAME WELLBORE1D-101
Annotation
Last WO:
End DateH2S (ppm) DateComment
SSSV: NONE
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 & Reset tubing 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):
7760 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:3/2/2021
Conditions of approval: Notify Commission so that a representative may witness Sundry Number:
Plug Integrity BOP Test Mechanical Integrity Test Location Clearance
Other:
Post Initial Injection MIT Req'd? Yes No
Spacing Exception Required? Yes No Subsequent Form Required:
APPROVED BY
Approved by: COMMISSIONER THE COMMISSION Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
Well Integrity Specialist
Jan Byrne
n1617@conocophillips.com
6048
118 118
6079
87 16
10.75
5.5x3.5
469
Length TVD Burst
5428
MD
NA
NA
NA
499
4233
499
4254 5686
PRESENT WELL CONDITION SUMMARY
3846 None
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL0025650
200-183
P.O. Box 100630, Anchorage, Alaska 99508 50-029-22986-0000
ConocoPhillips Alaska, Inc.
KRU 1D-101
Kuparuk River Field / West Sak Oil Pool
COMMISSION USE ONLY
Authorized Name:
Tubing Grade:Tubing MD (ft):
3694 - 3970
Perforation Depth TVD (ft):Tubing Size:
5504 - 5800
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.
659-7224
Baker seal assembly
None
5428 / 3526
NA
Size
Authorized Signature:
3/21/2021
3.5
Perforation Depth MD (ft):
L-80
m
n
P
O
66
t
Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval.
By Samantha Carlisle at 10:51 am, Mar 02, 2021
321-104
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孳孵季孴孳孽孵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
10-404
VTL 3/2/21 DSR-3/2/21
X
6100 DLB
X
X
DLB 03/02/2021Comm
3/3/21
dts 3/3/2021 JLC 3/3/2021
RBDMS HEW 3/3/2021
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
March 2, 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-101 (PTD 200-183) to pull and reset a retrievable tubing patch
to allow access for a subsidence surveillance drift.
If you need additional information, please contact us at 659-7224.
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孳孵季孴孳孽孵孷孽孶孼孰孳孼孪孳孳孪
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-101 is coming due for a subsidence compliance drift on 4/2/2021. The tubing patch at 137' needs
to be pulled to allow for the subsidence compliance drift and then reset after. The patch packer
depths may be adjusted slightly based on wellbore conditions.
Risk/Job Concerns:
• P2P tubing patch set from 137' to 177'.
• Tubing leak located at 163', possible additional tubing leak within patch setting interval
• Caliper shows ~20-40% tubing wall loss from 1000' down
• Subsidence surveillance- Sub flowchart location I-B End
• Need approved 10-403 prior to pulling and resetting tubing patch
Steps:
Relay
1. RIH, drift to top of patch at 137'
2. RIH to pull upper P2P, spacer pipe, and anchor latch assembly at 137' (OAL 40.83').
3. RIH to pull lower P2P at 177' (OAL 4.01')
4. Brush and flush tubing to DS nipple at 5389'.
5. RIH w/ dummy plug drift to DS nipple at 5389'.
6. Pump 20 bbls 100*F diesel down tubing to preheat.
7. RIH w/ lower P2P, set at ~178'.
8. RIH w/ test tool to lower P2P at 178'.
9. Perform CMIT-TxIA to 2500 psi. Record pre, initial, 15 min & 30 min TIO's
10. RIH w/ upper P2P & spacer pipe assembly, sting into lower P2P at 178'. Patch should be 41'
element to element setting the upper P2P at 137'.
11. Perform MIT-IA to 2500 psi. Record pre, initial, 15 min & 30 min TIO's.
12. RDMO. Return well to Ops.
13. DHD to perform state witnessed MITIA once BOI and stabilized.
Last Tag
Annotation Depth (ftKB) End Date Wellbore Last Mod By
Last Tag: SLM 5,578.0 1/3/2020 1D-101 fergusp
Last Rev Reason
Annotation End Date Wellbore Last Mod By
Rev Reason: UPDATED LEAK & PATCH INFO 7/1/2020 1D-101 pproven
Casing Strings
Casing Description
CONDUCTOR
OD (in)
16
ID (in)
15.06
Top (ftKB)
31.0
Set Depth (ftKB)
118.0
Set Depth (TVD) …
118.0
Wt/Len (l…
62.58
Grade
H-40
Top Thread
WELDED
Casing Description
SURFACE
OD (in)
10 3/4
ID (in)
10.05
Top (ftKB)
30.4
Set Depth (ftKB)
499.3
Set Depth (TVD) …
499.2
Wt/Len (l…
40.50
Grade
J-55
Top Thread
BTC
Casing Description
PRODUCTION 5.5"x3.5"
OD (in)
5 1/2
ID (in)
4.95
Top (ftKB)
30.4
Set Depth (ftKB)
6,078.6
Set Depth (TVD) …
4,233.5
Wt/Len (l…
15.50
Grade
L-80
Top Thread
BTC-MOD
Tubing Strings
Tubing Description
TUBING
String Ma…
3 1/2
ID (in)
2.99
Top (ftKB)
28.9
Set Depth (ft…
5,442.2
Set Depth (TVD) (…
3,638.6
Wt (lb/ft)
9.30
Grade
L-80
Top Connection
EUE8RDMOD
Completion Details
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des Com
Nominal
ID (in)
28.9 28.9 0.17 HANGER VETCO GRAY TUBING HANGER 3.500
5,389.0 3,591.7 29.71 NIPPLE CAMCO DS NIPPLE w/ 2.812" NO GO PROFILE 2.812
5,427.5 3,625.5 27.73 NO GO BAKER NO GO SUB 3.000
5,428.3 3,626.2 27.69 SEAL ASSY BAKER 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
137.0 137.0 0.81 PACKER -
PATCH - UPR
2.72" P2P 4/9/2020 1.630 CPP35113
141.0 141.0 0.83 SPACER,
ANCHOR LATCH
2-1/16", P110 SPACER PIPE, LATCH SEAL
ASSEMBLY, OAL = 35.87'
4/9/2020 1.600 CPAL35146
163.0 163.0 0.94 LEAK - Tubing LRS TBG LEAK 1/29/2018 0.000
177.0 177.0 1.01 PACKER -
PATCH - LWR
2.72" P2P, 1.625" ID, 4.01' OAL 4/9/2020 1.625 CPP35210
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft
)Type Com
5,504.0 5,544.0 3,694.3 3,730.9 WS D, 1D-101 12/28/2000 4.0 IPERF 2.5" HSD, 60 deg phase
5,574.0 5,594.0 3,758.5 3,777.0 WS B, 1D-101 12/28/2000 4.0 IPERF 2.5" HSD, 60 deg phase
5,594.0 5,614.0 3,777.0 3,795.5 WS B, WS A-4,
1D-101
12/27/2000 4.0 IPERF 2.5" HSD, 60 deg phase
5,622.0 5,650.0 3,803.0 3,829.1 WS A4, 1D-101 12/27/2000 4.0 IPERF 2.5" HSD, 60 deg phase
5,668.0 5,684.0 3,845.9 3,860.9 WS A3, 1D-101 12/27/2000 4.0 IPERF 2.5" HSD, 60 deg phase
5,692.0 5,728.0 3,868.5 3,902.3 WS A3, 1D-101 12/26/2000 4.0 IPERF 2.5" HSD, 60 deg phase
5,750.0 5,800.0 3,923.0 3,970.1 WS A2, 1D-101 12/26/2000 4.0 IPERF 2.5" HSD, 60 deg phase
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 5,345.4 3,554.2 CAMCO KBG 2-
9
1 GAS LIFT DMY BK 0.000 0.0 3/19/2018
Notes: General & Safety
End Date Annotation
8/18/2010 NOTE:
1D-101, 7/3/2020 1:54:20 AM
Vertical schematic (actual)
PRODUCTION 5.5"x3.5"; 30.4-
6,078.6
IPERF; 5,750.0-5,800.0
IPERF; 5,692.0-5,728.0
IPERF; 5,668.0-5,684.0
IPERF; 5,622.0-5,650.0
IPERF; 5,594.0-5,614.0
IPERF; 5,574.0-5,594.0
IPERF; 5,504.0-5,544.0
GAS LIFT; 5,345.4
SURFACE; 30.4-499.3
PACKER - PATCH - LWR; 177.0
LEAK - Tubing; 163.0
SPACER, ANCHOR LATCH;
141.0
PACKER - PATCH - UPR; 137.0
CONDUCTOR; 31.0-118.0
KUP INJ
KB-Grd (ft)
39.56
Rig Release Date
11/27/2000
1D-101
...
TD
Act Btm (ftKB)
6,100.0
Well Attributes
Field Name
WEST SAK
Wellbore API/UWI
500292298600
Wellbore Status
INJ
Max Angle & MD
Incl (°)
68.43
MD (ftKB)
3,832.87
WELLNAME WELLBORE1D-101
Annotation
Last WO:
End DateH2S (ppm) DateComment
SSSV: NONE
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 and reset tubing patch
ConocoPhillips 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 7760 feet feet
true vertical 4254 feet feet
Effective Depth measured 5686 feet 5428 feet
true vertical 3846 feet 3626 feet
Perforation depth Measured depth 5504 - 5800 feet
True Vertical depth 3694 - 3970 feet
Tubing (size, grade, measured and true vertical depth)3.5 L-80 5428 3626
Packers and SSSV (type, measured and true vertical depth)Backer Seal Assembly 5428 3626
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
2. Operator Name
Senior Engineer:Senior Res. Engineer:
CollapseBurst
118
499
4233
Casing
Structural
16
10.75
Length
87
469
6048
Conductor
Surface
Intermediate
Production
Authorized Signature with date:
Authorized Name: Jan Byrne
Liner
5. Permit to Drill Number:
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
320-103
Size
Kuparuk River Field / West Sak River Oil Pool
14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283)
Gas-Mcf
measuredPlugs
Junk measured
ADL0025650 KRU 1D-101
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
200-183
50-029-22986-0000
P.O. Box 100360, Anchorage, Alaska 995103. Address:
4. Well Class Before Work:
Representative Daily Average Production or Injection Data
Casing Pressure Tubing PressureOil-Bbl
measured
true vertical
Packer
5.5 6079
WINJ WAG
Water-Bbl
MD
118
499
TVD
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 19:07:17
Foxit PhantomPDF Version: 9.7.0
jan.byrne@conocophillip
s.com
By Samantha Carlisle at 8:13 am, Apr 21, 2020
DSR-4/21/2020 RBDMS HEW 4/21/2020
VTL 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 (320-103) Well Operations for
ConocoPhillips Alaska, Inc. well KRU 1D-101 (PTD 200-183 ) for tubing patch pull and
replacement.
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 19:06:42
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 2001830 Type Inj W Tubing 640 640 640 660 Type Test P
Packer TVD 3626 BBL Pump 0.9 IA 100 1800 1760 1760 Interval O
Test psi 1500 BBL Return 0.9 OA Result P
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
TYPE INJ Codes TYPE TEST Codes
INTERVAL Codes Result Codes
W = Water P = Pressure Test I = Initial Test P = Pass
G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail
S = Slurry V = Required by Variance I = Inconclusive
I = Industrial Wastewater O = Other (describe in notes)
N = Not Injecting
ConocoPhillips Alaska Inc,
Kuparuk / KRU / 1D Pad
Guy Cook
Hembree / Miller
04/19/20
Notes:MITIA post patch per Sundry # 320-103
Notes:
1D-101
Notes:
Notes:
Notes:
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
Form 10-426 (Revised 01/2017)MIT KRU 1D-101 04-19-20.xlsx
Last Tag
Annotation Depth (ftKB) End Date Wellbore Last Mod By
Last Tag: SLM 5,578.0 1/3/2020 1D-101 fergusp
Last Rev Reason
Annotation End Date Wellbore Last Mod By
Rev Reason: SET PATCH 4/9/2020 1D-101 condijw
Casing Strings
Casing Description
CONDUCTOR
OD (in)
16
ID (in)
15.06
Top (ftKB)
31.0
Set Depth (ftKB)
118.0
Set Depth (TVD) …
118.0
Wt/Len (l…
62.58
Grade
H-40
Top Thread
WELDED
Casing Description
SURFACE
OD (in)
10 3/4
ID (in)
10.05
Top (ftKB)
30.4
Set Depth (ftKB)
499.3
Set Depth (TVD) …
499.2
Wt/Len (l…
40.50
Grade
J-55
Top Thread
BTC
Casing Description
PRODUCTION 5.5"x3.5"
OD (in)
5 1/2
ID (in)
4.95
Top (ftKB)
30.4
Set Depth (ftKB)
6,078.6
Set Depth (TVD) …
4,233.5
Wt/Len (l…
15.50
Grade
L-80
Top Thread
BTC-MOD
Tubing Strings
Tubing Description
TUBING
String Ma…
3 1/2
ID (in)
2.99
Top (ftKB)
28.9
Set Depth (ft…
5,442.2
Set Depth (TVD) (…
3,638.6
Wt (lb/ft)
9.30
Grade
L-80
Top Connection
EUE8RDMOD
Completion Details
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des Com
Nominal
ID (in)
28.9 28.9 0.17 HANGER VETCO GRAY TUBING HANGER 3.500
5,389.0 3,591.7 29.71 NIPPLE CAMCO DS NIPPLE w/ 2.812" NO GO PROFILE 2.812
5,427.5 3,625.5 27.73 NO GO BAKER NO GO SUB 3.000
5,428.3 3,626.2 27.69 SEAL ASSY BAKER 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)
137.0 137.0 0.81 PATCH - UPR
PKR (ME)
2.72" P2P, SPACER & ANCHOR LATCH, OAL 40.83',
SN: CPP35113, CPAL35146
4/9/2020 1.630
141.0 141.0 0.83 SPACER PIPE 2-1/16", P110 SPACER PIPE, LATCH SEAL
ASSEMBLY, OAL = 35.87'
4/9/2020 1.600
163.0 163.0 0.94 Tbg Leak TBG LEAK 3/20/2018 0.000
177.0 177.0 1.01 PATCH - LWR
PKR
2.72" P2P, CPP35210, 1.625" ID, 4.01' OAL 4/9/2020 1.630
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft
)Type Com
5,504.0 5,544.0 3,694.3 3,730.9 WS D, 1D-101 12/28/2000 4.0 IPERF 2.5" HSD, 60 deg phase
5,574.0 5,594.0 3,758.5 3,777.0 WS B, 1D-101 12/28/2000 4.0 IPERF 2.5" HSD, 60 deg phase
5,594.0 5,614.0 3,777.0 3,795.5 WS B, WS A-4,
1D-101
12/27/2000 4.0 IPERF 2.5" HSD, 60 deg phase
5,622.0 5,650.0 3,803.0 3,829.1 WS A4, 1D-101 12/27/2000 4.0 IPERF 2.5" HSD, 60 deg phase
5,668.0 5,684.0 3,845.9 3,860.9 WS A3, 1D-101 12/27/2000 4.0 IPERF 2.5" HSD, 60 deg phase
5,692.0 5,728.0 3,868.5 3,902.3 WS A3, 1D-101 12/26/2000 4.0 IPERF 2.5" HSD, 60 deg phase
5,750.0 5,800.0 3,923.0 3,970.1 WS A2, 1D-101 12/26/2000 4.0 IPERF 2.5" HSD, 60 deg phase
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 5,345.4 3,554.2 CAMCO KBG 2-
9
1 GAS LIFT DMY BK 0.000 0.0 3/19/2018
Notes: General & Safety
End Date Annotation
8/18/2010 NOTE: View Schematic w/ Alaska Schematic9.0
1D-101, 4/10/2020 5:36:03 AM
Vertical schematic (actual)
PRODUCTION 5.5"x3.5"; 30.4-
6,078.6
IPERF; 5,750.0-5,800.0
IPERF; 5,692.0-5,728.0
IPERF; 5,668.0-5,684.0
IPERF; 5,622.0-5,650.0
IPERF; 5,594.0-5,614.0
IPERF; 5,574.0-5,594.0
IPERF; 5,504.0-5,544.0
GAS LIFT; 5,345.4
SURFACE; 30.4-499.3
PATCH - LWR PKR; 177.0
Tbg Leak; 163.0
SPACER PIPE; 141.0
PATCH - UPR PKR (ME); 137.0
CONDUCTOR; 31.0-118.0
KUP INJ
KB-Grd (ft)
39.56
Rig Release Date
11/27/2000
1D-101
...
TD
Act Btm (ftKB)
6,100.0
Well Attributes
Field Name
WEST SAK
Wellbore API/UWI
500292298600
Wellbore Status
INJ
Max Angle & MD
Incl (°)
68.43
MD (ftKB)
3,832.87
WELLNAME WELLBORE1D-101
Annotation
Last WO:
End DateH2S (ppm) DateComment
SSSV: NONE
MEMORANDUM
Tot Jim Regg
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
ConocoPhillips Alaska, Inc.
IDA01
KUPARUK RIV U WSAK IDA01
See: Inspector
Reviewed By:
P.1. Supry J301—
Comm
" 1Comm
Well Name KUPARUK RIV U WSAK ID -101 API Well Number 50-029-22986-00-00 Inspector Name: Gig' Cook
IBSp Num: mi[GDC200419173519 Permit Number: 200-183-0 Inspection Date: 4/19/2020 -
Rel Insp Num:
Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min
Well ID -101 Typelnj W -TVD 3626 Tubing 640 640 - 640 660 -
PTD 2001830 ' Type Test I SPr Test psi 1500 IA too 1800 - 1760 - 1760 -
BBL Pumped: 1 0.9 BBL Returned: 0.9 OA
Interval OTHER PIF P
Notes: MTC -IA post patch per Sundry 320-103. The job was done with a Little Red Services pump truck and calibrated gauges.
Monday, April 20, 2020 Page I o1 I
THE STATE
°fALASKA
GOVERNOR MIKE DUNLEAVY
Paul Duffy
Sr. Wells Engineer
ConocoPhillips Alaska, Inc.
PO Box 100360
Anchorage, AK 99510
Re: Kuparuk River Field, West Sak Oil Pool, KRU ID -101
Permit to Drill Number: 200-183
Sundry Number: 320-103
Dear Mr. Duffy:
Alaska Oil and Gas
Conservation Commission
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
w .aogcc.alaska.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
C
DATED this -6 day of March, 2020.
ABDMS! `� MAR 0 9 2020
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC: 25 280
RECEIVED
MAR 5 2020
AOGCC
1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑� Operations shutdown ❑
Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program El
Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Buse Well ❑ Alter Casing ❑ Other: Pull and reset tubing patch ❑�
2. Operator Name:
4. Current Well Class:
5. Permit to Drill Number:
ConocoPhillips Alaska, Inc.
Exploratory ❑ Development ❑
Stratigraphic ❑ Service 0
200-183
3. Address:
6. API Number:
P.O. Box 100360, Anchcorage, Alaska 99510
50-029-229860000
7. If perforating:
8. Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool? NIA
KRU ID -101 +
Will planned perforations require a spacing exception? Yes ❑ No 2
9. Property Designation (Lease Number):
10. FieldlPool(s):
ADL0025650 '
Kuparuk River Field / West Sak River Oil Pool `
11. PRESENT WELL CONDITION SUMMARY
Total Depth MD (ft):
Total Depth TVD (ft):
Effective Depth MD: Effective Depth ND:
MPSP (psi):
Plugs (MD): Junk (MD):
7760
4,254'
5,686' 3,846'
1,930
Casing
Length
Size MD
TVD
Burst Collapse
Conductor
87'
16" 118'
118'
Surface
469'
10.75" 499'
499'
Production
6,048'
5.5"x3.5" 6,079'
4,233'
Perforation Depth MD (ft):
Perforation Depth TVD (ft):
Tubing Size:
Tubing Grade:
Tubing MD (ft):
5,504'-5,800'
3,694'-3,970'
3.500"
L-80
5,428'
Packers and SSSV Type:
Packers and SSSV MD (ft) and TVD (ft):
Baker Seal assembly
MD= 5,428'; TVD= 3,626'
12. Attachments: Proposal Summary ❑✓ Wellbore schematic Q
13. Well Class after proposed work:
Detailed Operations Program ❑ BOP Sketch ❑
Exploratory ❑ Strati ra hic
g p ❑ Development ❑ Service ❑✓
14. Estimated Date for . 3/19/2020
15. Well Status after proposed work:
Commencing Operations:
OIL ❑ WINJ Q • WDSPL ❑ Suspended ❑
GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑
16. Verbal Approval: Date:
Commission Representative: N/A
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: Paul Duffy Contact Name: Paul Duffy/Jan Byrne/Dusty Freeborn
Authorized Title: Well Integn!ya Compliance Specialist Contact Email: N1$170cpnoc0phl11IVs,CgM
Contact Phone: 659-7224
Authorized Signature: Date: 3/3/2020
COMMISSION USE ONLY
Conditions of approval: Notify Commission so that a representative may witness Sundry Number:
Plug Integrity ❑ SOP Test ❑ Mechanical Integrity Test L_I Location Clearance ❑
Other:
Post Initial Injection MIT Req'd? Yes K"No ❑ 1BDMSffc-' MAR 0 9
Spacing Exception Required? Yes ❑ No Subsequent Form Required: L�Zo
APPROVED_BY 2 ��
Approved by: COMMISSIONER THE COMMISSION Date:
_a,
i
3 �� �rQcl n3�s,
�p,/�$n6mk Form and
Form 10-403 Revisedbi7 proved applica io a d 1 t r m the date of a roval.
PP Attachments in Duplicate
ConocoPhillips
Alaska
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
March 3`a, 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-101 (PTD 200-183) to pull and replace a leaking retrievable
tubing patch and to allow access below the patch for a subsidence surveillance drift.
If you need additional information, please contact myself or Jan Byme at 659-7224.
Sincerely,
-04.-
Paul Duffy
Well Integrity & Compliance Specialist
ConocoPhillips Alaska, Inc.
I D-101
DESCRIPTION SUMMARY
OF PROPOSAL
ID -101 had a 3.5" –37' retrievable tubing patch installed over a tubing leak at 163' on April 1st,
2019. The well passed a state witnessed MITIA to 1820 psi post patch set. On August 4th,
2019, it was reported to the AOGCC for signs of IA re -pressurization. Diagnostics, which
included a leak detect, determined that the source of IA pressurization is the retrievable patch.
Internal subsidence compliance requires drifting the well for secure annually, which requires j
pulling of the patch. This request is to pull the patch, drift the tubing, and reset the patch to �/
regain tubing integrity.
1. Pull 3.5" –37' tubing patch.
2. Drift tubing with dummy plug for secure.
3. Re -set 3.5" – 38' patch over tubing leak at 163'.
4. Perform MITIA.
5. Bring well on injection for stabilization.
6. Perform state witnessed MITIA. �-
7. Submit 10-404.
Wallace, Chris D (CED)
From: Well Integrity Compliance Specialist CPH & 2 <n1617@conocophillips.com>
Sent: Sunday, August 4, 2019 5:01 PM
To: Wallace, Chris D (CED)
Cc: CPA Wells Supt
Subject: West Salk Injector 1D-101 (PTD 200-183) has displayed signs of IA re -pressurization.
Attachments: 1D-101.pdf; 1D-101 90 Day TIO plot.JPG
Chris -
West Salk Injector 1D-101 (PTD 200-183) has displayed signs of IA re -pressurization. The IA was initially bled after a
change of injection rate. The rate has since stabilized, and the IA has continued to increase in pressure. It is CPAI's
intentions to leave the well on injection and perform the initial set of diagnostics. Depending on the results of the tests
the well will be monitored for 30 days to monitor for IA pressure stabilization. If at any point the IA indicates that it has
lost integrity the well will be shut in and the proper paperwork for continued injection or repair will be
submitted. Please let me know if you have any questions or disagree with the plan.
Attached are copies of the well bore schematic and a 90 Day TO plot.
Dusty Freeborn/Jan Byrne
Wells Integrity & Compliance Specialist
ConocoPhillips Alaska, Inc.
Office phone: (907) 659-7224
Cell phone: (907) 830-9777
WELLS TEAM
Cpwc"Mps
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
JUN 17 2G19
1. Operations Abandon ❑ Plug Perforations ❑
Fracture Stimulate ❑
Pull Tubing ❑ AOGGn h tdown ❑
Performed: Suspend ❑ Perforate ❑
Other Stimulate ❑
Alter Casing ❑ Change Approved Program ❑
Plug for Redrill ❑ arforate New Pool ❑
Repair Well ❑
Re-enter Susp Well ❑ Other: Extend and re -install patch ❑�
2. Operator
ConocoPhillips Alaska, Inc.
4. Well Class Before Work:
5. Permit to Drill Number:
Name:
Development ❑
Stratigraphic ❑
Exploratory ❑
Service ❑'
200-183
3. Address: P. 0. BOX 100360, Anchorage, Alaska
6. API Number:
99510
50-029-22986-00
7. Property Designation (Lease Number):
8. Well Name and Number: KRU 1D-101
ADL0025650
9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s):
Ku aruk River Field / West Sak Oil Pool
11. Present Well Condition Summary:
Total Depth measured 6,100 feet
Plugs
measured None feet
true vertical 4,254 feet
Junk
measured None feet
Effective Depth measured 5,686 feet
Packer
measured 5,428 feet
true vertical 3,861 feet
true vertical 3,625 feet
Casing Length Size
MD
TVD Burst Collapse
CONDUCTOR 87 feet 16
118' MD
118' TVD
SURFACE 469 feet 10 3/4 "
499' MD
499' TVD
PRODUCTION 6,048 feet 5 1/2 "
6,079' MD
4234' TVD
Perforation depth Measured depth 5504'5800' feet
True Vertical depth 3694'-3970 feet
Tubing (size, grade, measured and true vertical depth)
3.5 "
L-80 5,442' MD 3,639' TVD
Packers and SSSV (type, measured and true vertical depth) SEAL ASSY -BAKER SEAL ASSEMBL' 5,428' MD 3,626' TVD
12. Stimulation or cement squeeze summary:
Intervals treated (measured): N/A
Treatment descriptions including volumes used and final pressure:
N/A
13.
Representative Daily Average Production or Injection Data
Oil -Bbl
Gas-Mcf
Water -Bbl Casing Pressure Tubing Pressure
Prior to well operation: I N/A
N/A N/A
N/A N/A
Subsequent to operation: I N/A
N/A N/A
N/A N/A
14. Attachments (required Per 20 MC 25.070, 25.071. s 25.283)
15. Well Class after work:
Daily Report of Well Operations ❑
Exploratory ❑
Development ❑ Service Q Stratigraphic ❑
Copies of Logs and Surveys Run ❑
16. Well Status after work:
Oil ❑ Gas ❑ WDSPL ❑
Printed and Electronic Fracture Stimulation Data ❑
GSTOR ❑ WINJ
0 WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑
17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge.
Sundry Number or N/A if C.O. Exempt:
319-107
contact Name: Dusty Freeborn/Jan Byrne
Authorized Name: Dusty Freeborn
Contact Email: N1617@conocophillips.com
Authorized Title: Well Integrity Supervisor
Contact Phone: 907-659-7224
Authorized Signature:
Date: 12 June 19
v r4- ('/70/ley
Form 10-404 Revised 4/2017
� 00/1
-3BDMS 6v JUN 1 8 2019 Submit Original Only
ConocoPhillips
Alaska
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
June 12th, 2019
Commissioner Jessie Chmielowski
Alaska Oil & Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, AK 99501
Commissioner Chmielowski:
Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips
Alaska, Inc. well KRU 1D-101(PTD 200-183) for tubing patch extension and re -set.
If you need additional information, please contact us at your convenience.
Sincerely,
Dusty Freeborn/Jan Byrne
Well Integrity Supervisor
ConocoPhillips Alaska, Inc.
Office phone: (907) 659-7224
WELLS TEAM
/J',\ KUP ]NJ WELLNAME 10-101 WELLBORE 1D-101
ConoeoPhillips
Attributes Max Angie&MD
reels Ynme WeI1COrn APIIUWI Wdlbore 6[alus
1,66
hall`)
RTD
MD (XK9 c[91m InNB1
Alaska. Inc
NEST SAK 500292298600 INJ
843
3,8320] 6.100.0
tr2=IPpmI Dak Annotallon End Dale KBGrd(11) RiB Release Date
SBBV NONE Leat WO: 39.56 11 2]12000
1a1p1.arzrpla T:um AM
Last Tag
raluhmalic lan.ap
MnMatlon eapm(like) I End DNe wSlSRs Biel Mod By
Last Tag:RKB 5,686.0122]/201] 16101 1pproven
--- - -
Last Rev Reason
Annol&bn
I End D. WNB..
Last MM By
Rev Reason'. Pull patch,and. noses tlower patch hiddetl atltllional patch
4cor2019 16101
bworlM
r'sounbly)
Casing Strings
crime description OD 'in'mgn) Top IXKDI sol Oep"mrca) bel per BrMig wuLen ll_. craae
Tnp Threw
CONDUCTOR ifi 15.06 31.0 1180 118.0 82.58 740
WELDED
Casing DescriptionOD(in) ID lin) Top IXK91 let Degh(XKBj Sol cal nVig WtlLen g._erade
Top Thrss
wwwww
SURFACE 10314 10.05 304 499.3 499.2 40.50 J-55
I
BTC
n..www
CONIXeei. a1 D11a. 0
Gating Oescripllon OD(n) IDpn) Top 11NB Sel Depth result bet Depth (I VU), Will-el11... Gmde
PRODUCTION 55'k55" 51/2 4.95 304 6,0786 4,233.5 1550 L-80
Top ihrvJ
BTC -MOD
Tubing Strings
Iejy.rd.E'Y*0
Tubing ttscnpllon since Ma... ID lint Top(.Ks) eel Dep1n ur. Sel Depth (TVD)1... Wl ldtttl Grade Topco;B-. on
spacer Plpelap
TUBING 3112 2.99 289 5,442.2 36386 9.30 L-80 EUEBRDMOO
Completion Details
T.plrvDl rop ma Alan l
TOP( --i IXKid 1'1 hem Des Com lalinj
Middle Paber(mo. leas
289 28.9 0.17 HANGER VETCO GRAY TUBING HANGER 3500
spacermceasl.a
q aktRO
5,3890 3,591,) 29.71 NIPPLE CAMCO OS NIPPLE el 2.012'NO GO PROFILE 2.812
5,427.5 3.625.5 2].]3 NO GO BAKER NO GO SUB 3.000
5.4283 3.626.2 27.59 SUEASSY BAKER SEAL ASSEMBLY 3000
Lew<r Fslmr(MElnps.p
Other In Hole ireline rehievable plugs, valves, pumps, fish, etc.)
Top lrvD) Top and
Top(1MB) (XKaI 1') Des Com Run On. ID (in)
130.0 1380 Det Upper Packer UPPER PACKER, 2]2" P2P SN'. CPPZ6113, GAL= 4/1/2019 1.630
sullorl ala-
(ME) 4.1"
140.0 1400 0.82 SpacelPipe SPACER PIPE, 2-1/16" S IATCH SEAL ASSEMBLY 31312019 1.600
SN: CPAL35109 OAL =8.42'
148,5 148.5 0.86 Middle Parker UPPER PACKER, 2.72' P2P SIN CPP35207, UAL = 7312019 L630
(ME) 4.V
151.0 151.0 0.88 Spacer Pipe SPACER PIPE, 31116" E IATCH SEAL ASSEMBLY W3112019 1.600
SN: CPAL35064 CAL =26 BP
case UFT. 5ae5<
163.0 1830 0.94 Tag Leak TBG LEAK 7272018 0000
1750 1] 50 1.00 Lower Packer LOWER PACKER, 2.]2"P2P (kCPP352ID,1625"ID. 3/3012019 1630
(ME) 4,01'CALL
Perforations & Slots
nl r.E 51.c
shol
Den
To.1. (Tv.) Isnolnn
MKBI ( Linked IDna Dab 1 Type Com
Top (me) Dim(ftKIh XKa)
5,504.0 5,54403 3.]30.9 WS D.10.ID1 12/282000 d0 PERK 2.5"HS0. 60 tleg phase
0 369
369
5,5740 5,594.0 3,]58.5 3.777.0 758. 1D-101 10282000 40 (PERE 2.5" HSD. 60 deg phase
5.5940 5,614.0 3.777.0 Vill AS B. MA4, 1212712000 40 1PERF 25" HBO, 69 deg phase
1D-101
5,8220 5,650.0 3.003.0 3,829.1 MA4, 10.101 12272000 4.0 (PERF 25 "MSR 60 deg phase
5,6580 1.684.0 3,8459 3,860.9 MR M. IDA 01 12272000 4.0 PERE 25" HSD, 60 tla0 phase
SE/4Assoo5.e2aa
5.692.0 5.728.0 3,688b 3,9023 Mrs M. 10.101 12262000 4.0 ISERE 25" HSD, 60 deo phase
5,7500 5.800.0 3,9230 1 3,970.1 V10A21ol 12/262000 4.0 IPERF 2.5" HED. 60 deg phase
Mandrel Inserts
st
aX
HI Tap(XKB)
Tep(1VD)
IXNBI Make
Mwbl
ODlln)
sery
Vabe
type
lei<M1
Type
Pm131ze
fns
TRO flan
(psg
Run DMe Com
1 5,3454
3,554.2 CAVI
KBG2-
1
ussio T
OMY BN
0000
OD 311912018
1
1
9
I
I
I
IPERF,5.50165.SIea�
Notes: General &Safety
Dme
8/10/2010
NOTE View SchemaIn, w/Alaska S[hemasic90
(PERF: 5.5)4all .0
IPEFF:S.�1658140-
(PERF; s,6d 05,0].0
IPERF5.89ea5.si
(PERF; S.essi.W sial
IPERF: S]W 0.5.BM0-
PRDD.BTNw5dsd.5:R6
BN08
Date Event Summary
03/30/19
03/31/19
04101/19
06/10/19
1D-101
DESCRIPTION OF WORK COMPLETED
SUMMARY
PULLED 2.72" UPPER P2P SPACER ANCHOR ASSEMBLY @ 154' RKB, PULLED 2.72"
LOWER P2P @ 174' RKB, DRIFT TBG W/ 2.81 DUMMY CA -2 PLUG TO 5389' RKB CLEAN
DRIFT, SET LOWER 2.72 P2P @ 175' RKB (SN: CPP35210), SET UPPER 2.72 P2P SPACER
ANCHOR LATCH @ 155' RKB (CAL 24.84'/ SN: CPP35115 / CPAL35073), MIT IA 2500 PSI
FAILED 4 TIMES. RETEST IN AM. IN PROGRESS.
LRS MIT IA 7 TIMES GETTING BETTER EACH TIME ALL TEST'S FAILED, PULLED 2.72"
UPPER P2P SPACER & ANCHOR ASSEMBLY @ 151' RKB (ME) ELEMENTS & ANCHOR
GOOD, RAN 3 1/2 TTS TOOL TO LOWER 2.72" P2P @ 175' RKB CMIT PASS, SET 2.72" P2P
PACKER SPACER ANCHOR ASSEMBLY @ 148.42' RKB (ME) (CPP35207 / CPAL35064),
MIT IA FAILED, SET 3 1/2 TTS TEST TOOL IN UPPER 2.72" P2P @ 148.42' RKB MITT
FAILED, RAN 3 1/2 SLIP STOP HOLE FINDER UNABLE TO MIT TBG LAST TEST @ 132'
RKB FAILED, CMIT TBG x IA 2500, FAILED ON TBG & PASSED ON IA, PULLED 3 1/2 TTS
TEST TOOL FROM 2.72 P2P @ 148.42' RKB. IN PROGRESS.
CMIT T/1= 600/611 (.7) T/I= 2500/2550, 15 MIN T/1= 2450/2482, 30 MIN T/1= 2440/2467
RAN SPINNER TEMP LDL LOG FROM 145' TO SURFACE UNABLE TO FIND LEAK W/
SPINNER A BPM LLR, PUMPED 17 BBLS DIESEL @ 30 DEG. DOWN IA & 10 BBLS @ 90
DEG. DIESEL ATTEMPTING TO FIND TEMP SWING. SET 3 1/2 TTS TEST TOOL IN 2.72
P2P @ 148' RKB, CMIT TBG x IA PASS, PULLED 3 1/2 TTS TEST TOOL @ SAME, SET 2.72"
P2P (CPP35113 / CPAL35109) PACKER SPACER ANCHOR ASSEMBLY @ 138' RKB (ME).
MIT IA 2500 PASS. COMPLETE.
CMIT TxIA: T/1= 2600/2500, 15 MIN T/1= 2500/2480, (100/20), 30 MIN T/1= 2460/2476 (40/4)
MITIA: PRE MIT T/1= 1050/1318, PRESSURE UP (.2) T/1= 1050/2530,15 MIN T/1= 1050/2483,
(47) 30 MIN T/1= 1050/2477
Initial T/I = 844/540 IA FL @ Surface
Pressured up the IA to 1820 psi with 0.5 bbl of diesel
Start T/I = 844/1820
15 min T/I = 844/1770 (-50 psi)
30 min T/I = 844/1760 (-10 psi)
Bled the IA to 540 psi with 0.5 bbl of diesel back.
Continued to bleed the IA to 250 psi.
Final T/I = 844/250
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Jim Regg o/q DATE: Wednesday, June 26, 2019
P.I. Supervisor / 1�5 Iq SUBJECT: Mechanical Integrity Tests
h ConocoPhillips Alaska, Inc.
ID -101
FROM: Lou LaubenStein KUPARUK RIV U WSAK ID -101
Petroleum Inspector
Sre: Inspector
Reviewed By:
P.I. Supry — 1z—p
NON -CONFIDENTIAL Comm
Well Name KUPARUK RIV U WSAK ID -101 API Well Number 50-029-22986-00-00 Inspector Name: Lou Laubenstein
Permit Number: 200-183-0 Inspection Date: 6/10/2019
Insp Num: mi[LOL190611090026
Rel Insp Num:
Packer Depth
Well 11
ID -101 Typelnj 'TVD 3626 'Tubing
PTD 2001830 ' Type Test s"' Test psi 1500 - IA
BBL Pumped: 0.5 BBL Returned: os OA
Interval _ OTHER P/F P
Notes: MIT -IA Post patch and reset per Sundry #319-107
Pretest Initial 15 Min 30 Min 45 Min 60 Min
81: Sit 844 R I I -
540 1820 1770 1760 - 1
Wednesday, June 26, 2019 I'a^c I "I I
WELL LOG TRANSMITTAL #905559665
To: Alaska Oil and Gas Conservation Comm.
Atm.: Natural Resource Technician
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
RE: Leak Detect Log and Packer Setting Record: 1D-101
Run Date: 03/30/2019 and 04/01/2019
200183
June 26, 2019
KLi .;LW ;
JUN 2 7 2010
The technical data listed below is being submitted herewith. Please address any problems or
concerns to the attention of.-
Fanny
£
Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518
FRS ANC@halliburton.com
1D-101
Digital Data in LAS format, Digital Log file
50-029-22986-00
1 CD Rom
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE
TRANSMITTAL LETTER TO THE ATTENTION OF:
Halliburton
Wireline & Perforating
Attn: Fanny Sari
6900 Arctic Blvd.
Anchorage, Alaska 99518
Office: 907-275-2605
FRS_ANC @halliburton. com
Date: 0L 2 C `% Signed:
THE STATE
01ALASKA
GOVERNOR MIKE DUNLEAVY
Jan Byrne
Well Integrity Supervisor
ConocoPhillips Alaska, Inc.
P.O Box 100360
Anchorage, AK 99510-0360
Re: Kuparuk River Field, West Sak Oil Pool, KRU 1 D-101
Permit to Drill Number: 200-183
Sundry Number: 319-107
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
wvsov. aogcc.al aska.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,
Daniel T. Seamount, Jr.
Commissioner
DATED this 7 day of March, 2019.
6oMS1��MP� a � +ip1a
R
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 21 260
ED,
MAR 0 6) 01g
A vC
1. Type of Request: Abandon LJ Plug Perforations Li Fracture Stimulate Ll Repair Well U Operations shutdown LJ
Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑
Plug for Rednll ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Pull and reset tubing patch❑
2. Operator Name:
4. Current Well Class:
. Permit to Drill Number:
ConocoPhllll s Alaska Inc.
Exploratory El El
Strati ra hic
g p El Service ❑�
200-183
3. Address:
API Number:
[6.
P. O. Box 100360, Anchorage, Alaska 99510
500292298600
7. If perforating:
8. Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool? NA
KRU 1D-101 -
Will planned perforations require a spacing exception? Yes ❑ No 2
9. Property Designation (Lease Number):
10. Field/Pool(s):
ADL0025650
Kuparuk River Field /West Sak Oil Pool -
11. PRESENT WELL CONDITION SUMMARY
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD):
6,100' 4,254' 5686' 3846'
Casing Length Size MD TVD Burst Collapse
Structural
Conductor 87' 16" 118'
Surface 469' 10-3/4" 499'
Intermediate
Production 6,048' 5.6'x3.5" 6,079'
Liner
Perforation Depth MD (ft):
Perforation Depth TVD (ft):
Tubing Size:
Tubing Grade:
Tubing MD (ft)'.
5504'-5800'
3694'-3970'
3.500"
L-80
5,428'
Packers and SSSV Type:
Packers and SSSV MD (ft) and TVD (ft):
Baker seal assembly
MD= 5428' TVD= 3626'
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 3/15/2019
15, Well Status after proposed work:
Commencing Operations:
OIL ❑ WINJ ❑� . WDSPL ❑ Suspended ❑
GAS ❑ WAG ❑ GSTOR [I 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 / Kelly Lyons
Authorized Title: Well Integrity Supervisor Contact Email: 1,11617@conocophillips.com
Contact Phone: 907-659-7224
Authorized Signature: ��. Date. 3/4/19
COMMISSION USE ONLY
Conditions of approval: Notify Commission so that a representative may witness Sundry Number:
Plug Integrity ❑ BOP Test E]Mechanical Integrity Test El/ Location Clearance ❑
Other:
Post Initial Injection MIT Req'd? Yes No
1
Spacing Exception Required? Yes El No Subsequent Form Required: 1 o — 4 o z7
APPROVED BY{
Approved by COMMISSIONER THE COMMISSION Date: l
/
IS,
If I\Arm 10-403 Revised 4/2017
U N i�+ v h L RBDMSI9 W 012019
Submit Form and
Approved application is valid for 12 months from the date of approval. 2 �.�Attachmom, In Duplicate j.
ConocoPhillips
Alaska
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
March 3, 2019
Commissioner Hollis S. French
Alaska Oil & Gas Conservation Commission
333 West 7�h Avenue, Suite 100
Anchorage, AK 99501
Commissioner French,
Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips
Alaska, Inc. well 1D-101 (PTD 200-183). The request is for approval to pull and reset a
tubing patch to allow for drifting the tubing below the patch.
If you need additional information, please contact myself or Kelly Lyons at 659-7224.
Regards,
Jan By
Well Integrity Supervisor
1D-101
DESCRIPTION SUMMARY
OF PROPOSAL
1D-101 had a 3.5" -20' retrievable tubing patch installed over a tubing leak at 163' on March 20, 2018. Internal
subsidence compliance requires drifting the well for secure annually, as such, the patch needs to be pulled to
facilitate drifting the tubing. This request is to pull the patch, drift the tubing, and reset the patch.
1. Pull 3.5" -20' patch from tubing.
2. Drift tubing with dummy plug for secure.
3. Reinstall 3.5" -20' patch over tubing leak at 163'.
4. Perform MITIA.
5. Bring well online for stablization.
6. Perform SW MITIA. SfQ ty W fn r 5 sPd
7. Submit 10-404.
KUP INJ
1D-101
IA�tOCOF'AbskapS
1 yKanou es Maxrr) Angle 8 MD TD
Mgle&f
Alaska.11lo.
W¢Ad,PAPIIUWI FIeIO Neme WellboreSWlui Act Line InKD)
500292298600 WEST BAK INJ 68.43 3,832.0] 6.1000
CSZ-V L N2b (ppm) Dab Mnoedtlan Eno daft KDGra (DI ply ages'..BSSV: NONE Last WO: 39.56 1112]12000
10-101, L.a M86:1J:II1M
1
Last Tag
Last Tag. RNB De?I (leh Ens Ogre LaaeMoa Dy
Last Tag 5,8860 12/2]1201] PProye0
Last Rev Reason
Annolatlost En40ale Lasl Motl ay
Rev Reason'. Circ ONt. poll plUg, install patch 323/2016 co0mjw
Casing Strings
caang Oe:cnpimn OD pn) lOpn) rnv 111Ne) sHOepm (nNe1 sal Depm (rv01... wuLen l... Oratle TOv in am CONDUCTOR i6 15.062 31.0 1180 1180 6258 H40 WELDED
C aslny DeiGrlpllOn trianl fl) (in) Top tpKDl s¢I Oepm (IIKDI SN Oepm (Typl._WULm 1... Gme TDp]n(am
SURFACE 10 We 10.050 30.4 499.3 489.2 00.50 J-55 BTC
CONOUCTOR13t 011e0
I
Casing Daecnptlon 00 (In) 10 (In) TOp IflKDI Sel Oeplh (M1K01 Sel Oepm (NOL... WIILen D.. Graae Top roman
PRODUCTION 5.5x35" 5112 4.950 30.4 6,0]86 4,2335 15. SO 1.80 BTC -MOO
Tubing
Vpcenc�Yerasa0
-arn-n
nbm9065enpllon smog mz_. 10 (ml rop (uNe1 sal Oepm lrz_$eroepm lrvol (... wlRmnl ratio rep connttnon
TUBING 31/2 2.992 28.9 5,4422 3636.6 930 L-80 EVE6RDMDD
Completion Details
rep L..x:1a1.D
IDP am Top mel Nominal
I., (.A, (neer fl Tem Des core ID ONI
28.9 28.9 017 HANGER VETCO GRAY TUBING HANGER 3.500
-Pacer Plea+. -I Lehnl
5,389.0 3,591] 29.71 NIPPLE CASCO DS NIPPLE wl2.812'NO GO PROFILE2.812
Isco
5427.5 3,625.5 2773 NO GO BAKER NO GO SUS 3000
Lo»<r Paabr;,T4D
54283 3626.2 27.69 SEALASSY BAKER SEAL ABSEMBLY 3000
Other In N431e:I1Nirelitle retrievable plugs, valves, pumps, Fish, etc.)
Top ITVDI Train.,
TOP(PaIn (it I CI Dn Com RUNOaIe ID pan
154.0 1560 0.89 Upper Packer UPPER PACKER. 2.72 P2P SN: CPP35028, CAL= 3202018 1630
SURFACE, JOp 4999
B LATCH REAL ASSEMBLY 3202018 1800
1580 158.0 0.91 Spacer Pipe+ SPACERPIPE,) CALL
Snap latch SN: CPAL9508d )OAL=2096'
1630 1630 D.9d Tdg Leak TBG LEAK3/202010 0.000
1740 1]4.0 099 Lower Packer LOWER PACKER. 2. P2P sal AGGRESSIVE SLIPS 3202018 1030
pCPP35156.1.62510, 4 01' CAL)
Perforations & Slots -
shm
GAs 111. s.94s4
j
Top (WD) 6hn(rv0) (il..I'D
Top des, arm atela (RKD) (We, Zane D ) Type Co.
5,506.0 5,544.0 3.694.3 3,730.9 WSD.16101 12/282000 4.0 /PERF 2.5"HBO. 60 deg phace
55740 5,594.0 3,758.5 3]77.0 MB. 10,101 12/282000 d.0 PERF2.5" HSD. 60 deg phase
NIPPLE. 5,3090
5.594.0 5,614.0 3,7770 3,]95.5645 B. WB AA. 12I, I2pD0 4O/PERF 2.5' I-II.. 60 deg phase
16101
5,622.0 5,650.0 3,803.0 3,029.1 WS A6, 16101 122]/2000 An rE., 2.5" HSD, BE deg phase
5,E68.0 5,6840 3,845.9 3,8609 WS A3. 16101 12/2'112000 4.D IP RE 2.5' HSD. 60 deg phase
5,692.0 5,728.0 3.868.5 3,902.3 WSA3. 161D1 12126/2000 6.0 !PERF 2.5"HS D, 60 deg phase
5.7500 5,8000 3,9 SO 3,970.1 V¢SA2, 16101 11282000 a0 I (PERF ZA H6D,60aegpnase
Mandrel Inserts
At
an
an
N Top Inner
TOP IMD)
(IIKDIECA;CO
MMI
OOgn)
Sery
vNee
Typ¢
LMM
Type
POn slae
(In)
mo pun
(pF0
punOx
CDm
5.345A
3556.2
KBG 2-
1
GAS LIFT
DMY
BK
0.000
D.0
3/19/2018
9
SEPLR93V; 5,4]8]
Notes: General&Safety
EnOOale
AnnObaon
81182010
!NOTE '.Wew BCM1emalicwl Plaska Schemalic9.0
PIPP;5Sc4O5544.0
IPERr 55)40 -SW 0
IPERF', 5,59405.8140
/PERF', 5.833050500
IPEPF:596B4O5.0a40
/PERP 5.6Lf 0 5,7Z8D
IPERF:5.7500.54000
RODUCTPEN55,37 50.4.
.:a'. a-
RECEIVED
STATE OF ALASKA
IlikSKA OIL AND GAS CONSERVATION C SSION APR 1 1 2018
REPORT OF SUNDRY WELL OPERATIONS
1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ ADGGG ❑
Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑
Plug for Redrill ❑ perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Patch Q
2.Operator 4.Well Class Before Work: 5.Permit to Drill Number:
Name: ConocoPhillips Alaska, Inc.
Development ❑ Exploratory ❑ 200-183
3.Address: P. 0. Box 100360,Anchorage,Alaska Stratigraphic❑ Service 0 6.API Number:
99510 50-029-22986-00
7.Property Designation(Lease Number): 8.Well Name and Number: KRU 10-101
ADL0025650
9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s):
Kuparuk River Field/West Sak Oil Pool
11.Present Well Condition Summary:
Total Depth measured 6,100 feet Plugs measured None feet
true vertical 4,254 feet Junk measured None feet
Effective Depth measured 5,389 feet Packer measured 154, 174, 5428 feet
true vertical 3,592 feet true vertical 154, 174, 3626 feet
Casing Length Size MD TVD Burst Collapse
CONDUCTOR 87 feet 15 " 118' MD
SURFACE 469 feet 12 " 499' MD
PRODUCTION 6,048 feet 7 " 6,079' MD K
JEWELERY TYPI MD apth MD&TVD feet Composite
Tubing(size,grade,measured and true vertical depth) 3.5" L-80 5,428' MD 3,626'TVD
Packers and SSSV(type,measured and true vertical depth) UPPER PACKER- UPPER PACKER, 2 154' MD 154'TVD
LOWER PACKER- LOWER PACKER, ; 174' MD 174'TVD
SEAL ASSY- BAKER SEAL ASSEMBL' 5,428' MD 3,626'TVD
12.Stimulation or cement squeeze summary:
Intervals treated(measured):
Treatment descriptions including volumes used and final pressure:
13. Representative Daily Average Production or Injection Data
Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure
Prior to well operation:
Subsequent to operation:
14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work:
Daily Report of Well Operations ❑I Exploratory ❑ Development ❑ Service 0 Stratigraphic ❑
Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL ❑
Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 0 WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑
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:
318-065
Contact Name: Jan Byrne/Kelly Lyons
Authorized Name:Jan Byrne
Contact Email: N1617@conocophillips.com
Authorized Title:Well integrity Supervisor
Contact Phone: 907-659-7224
Authorized Signature: �„ G Date:4/6/2018
V7-1- 4/27-/18
RBDMS.._ APR 1 12018
Form 10-404 Revised 4/2017 Submit Original Only
• •
• •
ConocoPhillips
Alaska
P.O. BOX 100360
ANCHORAGE,ALASKA 99510-0360
April 6th, 2018
Commissioner Hollis S. French
Alaska Oil & Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, AK 99501
Commissioner French:
Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips
Alaska, Inc. well KRU 1D-101 (PTD 200-183) for tubing patch repair.
If you need additional information,please contact us at your convenience.
Sincerely,
Jan Byr e/Kelly Lyons
Well I egrity Supervisor
ConocoPhillips Alaska, Inc.
Office phone: (907) 659-7224
WELLS TEAM
• ID-101 •
DESCRIPTION OF WORK COMPLETED
SUMMARY
Date Event Summary
West Sak water injector 1D-101 experienced an unexplained IA pressure anomaly and was
reported on 12/24/17. The well was SI and diagnostics culminated in identifying a tubing leak at
163' MD. A 20' OAL, 2.72" retrievable patch was set over the leak after which the well was
brought on injection and once stabilized the well passed a state witnessed MIT-IA. Pertinent
work is copied below.
01/29/18 PERFORM BASLINE TEMPERATURE PASS FROM SURFACE TO TOP OF PLUG AT 5389'.
LRS BEGIN PUMPING DOWN IA AT 0.5 BBL/MIN. LOG UP LOOKING FOR LEAK. LEAK
FOUND AT 163'. PERFORMED STATION SURVEYS @ 175'/ 170'/ 165'/ 160'/ 155'. READY
FOR CALIPER.
03/20/18
BRUSHED & FLUSHED/GAUGED TBG TO 2.75" DOWN TO SEAL ASSY @ 5428' RKB,
EXTRA BRUSHING FROM 91'TO 291' RKB. DRIFTED 2.73"x 24.25' DMY PATCH TO 300'
RKB. SET LOWER 2.72" PIIP PACKER (AGGRESSIVE SLIPS ) MID ELEMENT 174' RKB.
CMIT AGAINST TEST TOOL IN LOWER PACKER TO 2500 PSI ( PASS ) SET 26' UPPER
2.72" PIIP PATCH ASSEMBLY MID ELEMENT @ 154' RKB. MIT x IA 2500 PSI.
INITIAL T/I/FL = 890/950/2133 LRS PT TBG/IA TO 2500 PSI W/.6 BBLS START=
2635/2690/2133 15 MINS =2560/2625/2133 30 MINS = 2540/2605/2133
RU LRS TO IA. INITIAL T/I/FL = 890/950/2133 LRS PT IA TO 2500 PSI W/.6 BBLS START=
1000/2550/2133 15 MINS = 1000/2500/2133 30 MINS = 1000/2480/2133
04/05/18 State witnessed (Brian Bixby) MIT-IA Passed to 2000 psi.
Initial T/I = 846/340. IA FL @ surface.
Pressured IA to 2000 psi w/0.8 bbls diesel.
Starting T/I = 846/2000.
15 min T/I = 844/1950. (-50).
30 min T/I = 843/1950. (0). Bled IA to 340 psi (bled back 0.6 bbls), continued to bleed IA to 200
psi.
Final T/I = 842/200.
• 1D-101
DESCRIPTION OF WORK COMPLETED
SUMMARY
KUP INJ • 1D-101
Max Angle&MD TD
ConocoPhiIIips 00. Well AttributesWellbore API/UWI Field Name Wellbore Status MD(ftKB) Act Btm(ftKB)
AlHSkB,Inc. . 500292298600 WEST SAK INJ 68.43 3,832.87 6,100.0
''OPt+III_P: Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date
... SSSV:NONE Last WO: 39.56 11/27/2000
1D-101,3/252018 6:33:13 PM Last Tag
Vertical schematic(actual)
Annotation Depth(ftKB) End Date Last Mod By
Last Tag:RKB 5,686.0 12/27/2017 pproven
Last Rev Reason
' 1 ; '� Annotation End Date Last Mod By
I ,i Rev Reason:Circ out,pull plug,install patch 3/23/2018 condijw
HANGER;28.9 ( ,,i ) Casing Strings
Casing'
Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(I...Grade Top Thread
CONDUCTOR 16 15.062 31.0 118.0 118.0 62.58 H-40 WELDED
Casing Description OD(in) ID(in) Top(ftKB) Set Depth(RKB) Set Depth(ND)....Wt/Len(1...Grade Top Thread
SURFACE 10 3/4 10.050 30.4 499.3 499.2 40.50 J-55 BTC
Casing Description OD in ID in TopRKB Set Depth RKB Set Depth.4 pi ( ) ( ) ( ) p (ftKB) p (TVD)...Wt/Len(I...Grade Top Thread
,�PRODUCTION 5.5"x3.5" 5 1/2 4.950 30.4 6,078.6 4,233.5 15.50 L-80 BTC-MOD
CONDUCTOR;31.0-110.0 t ' Tubing Strings
Tubing Description String Ma...ID(in) Top(ft613) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection
TUBING 31/2 2.992 28.9 5,442.2 3,638.6 9.30 L-S0 EUE8RDMOD
Upper Packer;154'0 Completion Details
Top(ND) Top Incl Nominal
Top(ftKB) (ftKB) C) Item Des Com ID(in)
28.9 28.9 0.17 HANGER VETCO GRAY TUBING HANGER 3.500
Tbg Leak;163.0
Spacer Pipe+Snap Latch; 5,389.0 3,591.7 29.71 NIPPLE CAMCO DS NIPPLE w/2.812"NO GO PROFILE 2.812
158.0 5,427.5 3,625.5 27.73 NO GO BAKER NO GO SUB 3.000
><. 5,428.3 3,626.2 27.69 SEAL ASSY BAKER SEAL ASSEMBLY 3.000
Lover Packer;174.0 0..
u•: Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.)
Top(ND) Top Incl
•
Top(ftKB) (RKB) I I Des Com Run Date ID p81
154.0 154.0 0.89 Upper Packer UPPER PACKER,2.72"P2P SN:CPP35028,OAL= 3/20/2018 1.630
SURFACE;30.4.499.3-+ ^ 158.0 158.0 0.91 Spacer Pipe+ SPACER PIPE,2-1/16"&LATCH SEAL ASSEMBLY 3/20/2018 1.600
Snap Latch SN:CPAL35064)DAL=20.74'
163.0 163.0 0.94 Tbg Leak TBG LEAK 3/20/2018 0.000
174.0 174.0 0.99 Lower Packer LOWER PACKER,2.72"P2P w/AGGRESSIVE SLIPS 3/20/2018 1.630
(#CPP35156,1.625"ID,4.01'OAL)
Perforations&Slots
Shot
Dens
GAS LIFT;5,345.4 Top(ND) Btm(ND) (shots/ft
Top(RKB) Btm(ftKB) (RKB) (ftKB) Zone Date I Type Com
5,504.0 5,544.0 3,694.3 3,730.9 WS D,1D-101 12/28/2000 4.0 IPERF 2.5"HSD,60 deg phase
L-- 5,574.0 5,594.0 3,758.5 3,777.0 WS B,1D-101 12/28/2000 4.0 IPERF 2.5"HSD,60 deg phase
5,594.0 5,614.0 3,777.0- 3,795.5 WS B,WS A-4, 12/27/2000 4.0 IPERF 2.5"HSD,60 deg phase
NIPPLE;5,389.0 r1D-101
5,622.0 5,650.0 3,803.0 3,829.1 WS A4,1D-101 12/27/2000 4.0 IPERF 2.5"HSD,60 deg phase
5,668.0 5,684.0 3,845.9 3,860.9 WS A3,1D-101 12/27/2000 4.0 IPERF 2.5"HSD,60 deg phase
5,692.0 5,728.0 3,868.5 3,902.3 WS A3,1D-101 12/26/2000 4.0 IPERF 2.5"HSD,60 deg phase
5,750.0 5,800.0 3,923.0 3,970.1 WS A2,1D-101 12/26/2000 4.0 (PERF 2.5"HSD,60 deg phase
Mandrel Inserts
St
ati
N Top(ND) Valve Latch Port Size TRO Run
Top(RKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com
lg1 5,345.4 3,554.2 CAMCO KBG 2- 1 GAS LIFT DMY BK 0.000 0.0 3/19/2018
si Mk9
SEAL ASSY;5,428.3 Notes:General&Safety
as
is End Date Annotation
a 8/18/2010 NOTE:View Schematic w/Alaska Schematic9.0
•
IPERF;5,504.0-5.544.0
(PERF;5,574.0.5,594.0
IPERF;5,594.0-5,6140
IPERF;5,622.0-5,650.0
IPERF;5,668.0-5,684.0
IPERF;5,692.0-5,728.0
IPERF;5,750.0-5,800.0
PRODUCTION 5.Sx3.5"60784-
;30., .6
• •
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
Mechanical Integrity Test
Submit to: jim.regqaalaska.gov. AOGCC.InspectorsCa)alaska.gov phoebe.brooks@alaska.gov chris.wallace(a�alaska.gov
OPERATOR: ConocoPhillips Alaska Inc,
FIELD/UNIT/PAD: Kuparuk/KRU/1D Pad
DATE: 04/05/18
OPERATOR REP: Miller/Beck
AOGCC REP: Brian Bixby
Well 1D-101 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD 2001830 Type Inj W Tubing 846 846 844 843 Type Test P
Packer TVD 3626 BBL Pump 0.8 IA 340 2000 1950 1950 Interval 0
Test psi 1500 BBL Return 0.6 OA Result P
Notes: Post Patch MITIA per Sundry#318-065 *"`Single casing well*
Well 1D-122 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD 1981490 Type Inj W Tubing 950 950 951 951 Type Test P
Packer TVD 3519 BBL Pump 0.7 IA 360 2000 1910 1900 Interval 0
Test psi 1500 BBL Return 0.6 OA Result P
Notes: Post Patch MITIA per Sundry#318-064 **Single casing well'*`
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
Notes:
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD Type Inj 1 Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
Notes:
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
Notes:
TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes
W=Water P=Pressure Test I=Initial Test P=Pass
G=Gas 0=Other(describe in Notes) 4=Four Year Cycle F=Fail
S=Slurry V=Required by Variance I=Inconclusive
I=Industrial Wastewater 0=Other(describe in notes)
N=Not Injecting
Form 10-426(Revised 01/2017) MIT KRU 10-101 and 122 04-05-18.xlsx
MEMORANDUM • tate of Alaska
Alaska Oil and Gas Conservation Commission
TO: Jim Regg K,C 41c1(1'& DATE: Monday,April 09,2018
P.I.Supervisor (l SUBJECT: Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA,INC.
ID-101
FROM: Brian Bixby KUPARUK RIV U WSAK 1D-101
Petroleum Inspector
Src: Inspector
Reviewed By:
P.I.Supry,)1e=
NON-CONFIDENTIAL Comm
Well Name KUPARUK RIV U WSAK 1D-101 API Well Number 50-029-22986-00-00 Inspector Name: Brian Bixby
Permit Number: 200-183-0 Inspection Date: 4/5/2018
Insp Num: mitBDB180405122336
Rel Insp Num:
Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min
Well ID-101 Type Inj W' TVD 3626 . Tubing 846 846 844 - 843
PTD , 2001830 'Type Test SPT-Test psi 1500 IA 340 - 2000 ' 1950 _ 1950
BBL Pumped: j 0.8 - BBL Returned: 0.6 OA
Interval OTHER P/F P
- - -.- --— ----- ,,
Notes: This is a monobore well so there is no OA.Test was conducted per Sundry#318-065 post tubing patch.
r--
SCANNED
Monday,April 09,2018 Page 1 of 1
THE STATE
ofALAV KA
GOVERNOR BILL WALKER
Jan Byrne
Well Integrity Supervisor
ConocoPhillips Alaska, Inc.
PO Box 100360
Anchorage, AK 99510
Re: Kuparuk River Field, West Sak Oil Pool, KRU 1D-101
Permit to Drill Number: 200-183
Sundry Number: 318-065
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.00gcc.claska.gov
Enclosed is the approved application for sundry approval relating to the above referenced well.
Please note the conditions of approval set out in the enclosed form.
As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further
time as the 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,
Hollis S. French
Chair
41,
DATED this2 y -day of February, 2018.
RBDMS I-'- FEB 2 7 2C18
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
FECEIVED
FEB 2 0 2 1g
z�zs/� �
AOGCC
G7
1. Type of Request: Abandon LJ Plug Perforations LJ Fracture Stimulate Ll Repair Well Operations shutdown
Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑
Plug for Reddll ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Patch Other: 0'
2. Operator Name:
4. Current Well Class:
5. Permit to Drill Number:
ConocoPhilli s Alaska Inc.
Exploratory El ElEl
Stratigraphic ElService Q •
200-183 '
3. Address:
6. API Number:
P. O. Box 100360, Anchorage, Alaska 99510
500292298600 .
7. If perforating: -eA&
8. Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool? /UA-
Will planned perforations require a spacing exception? Yes ❑ No LiKRU
1 D-101
9. Property Designation (Lease Number):
10. Field/Pool(s):
ADL0025650
Kuparuk River Field / West Salk Oil Pool
11. PRESENT WELL CONDITION SUMMARY
Total Depth MD (ft): Total Depth TVD (ft):
Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD):
6,100' 4,254' .
5389' 3592' . 5389'
Casing Length
Size MD TVD Burst Collapse
Structural
Conductor 87'
16" 118'
Surface 469'
13" 499'
Intermediate
Production 6,048'
8.. 6,079'
Liner
Perforation Depth MD (ft):
Perforation Depth TVD (ft):
Tubing Size:
Tubing Grade:
Tubing MD (ft):
5504'- 5800'
3694'- 3970'
4.500"
L-80
5,428'
Packers and SSSV Type:
Packers and SSSV MD (ft) and TVD (ft):
12. Attachments: Proposal Summary Q Wellbore schematic O
13. Well Class after proposed work:
Detailed Operations Program ❑ BOP Sketch ❑
Exploratory ❑ Stratigraphic ❑ Development ❑ Service 0
14. Estimated Date for 2/26/2018
15. Well Status after proposed work:
Commencing Operations:
OIL ❑ WINJ El • WDSPL ❑ Suspended ❑
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: Kelly Lyons / Jan Byrne
Authorized Title: Well Integrity Supervisor Contact Email: N1617@conocophillips.com
Contact Phone: 907-659-7224
I&
Authorized Signature: L Date: 2/17/2018
COMMISSION USE ONLY
Conditions of approval: Notify Commission so that a representative may witness Sundry Number:
,tom
Plug Integrity ❑ BOP Test E] Mechanical Integrity Test [V Location Clearance ❑
Other:
Post Initial Injection MIT Req'd? Yes No ❑
Spacing Exception Required? Yes No Subsequent Form Required: �� l �j V RBDMS LL-- FEB .7 1G18
❑
APPROVED BY ,o
Approved by: l\ COMMISSIONER THE COMMISSION Date:
-alz-q241% 4.7111, 23// R I G I N A L
Submit Form and
Form 10-403 Revised 4/2017 Approved application, is valid for 12 months from the date of approval. Attachments in Duplicate
ConocoPhillips
Alaska
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
February 17, 2018
Commissioner Hollis S. French
Alaska Oil & Gas Conservation Commission
333 West 7u' Avenue, Suite 100
Anchorage, AK 99501
Commissioner French,
Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips
Alaska, Inc. well 1D-101 (PTD# 200-183). The request is for approval to set a tubing
patch to regain tubing integrity. d
If you need additional information, please contact myself or Kelly Lyons at 659-7224.
Regards,
e�
Jan yrne
Well Integrity Supervisor
1D-101
DESCRIPTION SUMMARY
OF PROPOSAL
1D-101
ID -101 was reported to the AOGCC on 12-24-17 for an unexplained IA pressure increase. The well was shut
in and secured after which diagnostics culminated in an Leak Detect Log locating a tubing leak at 163' MD.
This request is to install a 3.5", -24', retrievable patch over the leak to regain tubing integrity and return the well
to injection. I
1. Prep wellbore for patch.
2. Install 3.5" -24' retrievable tubing patch over the leak at 163' MD.
3. Perform MIT -IA.
4. Bring well online for stablization.
5. Perform SW MIT -IA.
6. Submit 10-404.
✓ '&-�\ KUP INJ
1D-101
ConOCoPhillips
Well Attributes Max Angle 8 MD TD
A 86kar 1110. p
Wellb92 APIs mei Name Welleo,e 5talus ncl l'1 MD XK61 Hct Btm ltll(B)
500292298600 WEST SPH INJ fi8.43 3,032.07 6,100.0
Comment X35 (pp.) Oh
SSSV: NONE
AnnaMion Ena Gale XBGM gl) RI9 Relm[e Dale
LasI NO: 39.56 11/2712000
t D.tm, Inden8352n 5 PM
Veniulx auntie aqui
Annotation pepin lXKet Eno OM Pnnot6bn tas[Med By Fne pate
Tag:RKB 5,886.0 1219/209 Rev Reason: TAG. aETPLUG ppmven 1/612018
asing Strings
eaam9 Deaenpnon DD liol ID01 Top I'm sm Depm lnKBl sm Depm lTVDI-. wvLe�ll_. Graae TOP Tn,ew
CONDUCTOR i6 15.062 31.0 118.0 11110 6258 If40 VJELDEO
.in,..P<lon OD no, I011nl Top I-. SH-m-ni" SH0. m IN01... oin-en ll... Gmtle Tep Th,�
XHNGEILMS
SURFACE 103/4 10.050 306 499.3 4982 40.50 J55 BTC
man, Description OD tint ID (lnl I -P k -B) Sq Depm IMKB) Sel Oeptn IN01... con -a g...Gmc. Top Tnrmtl
PRODUCTION 55"x35" 51/2 4.950 306 6,0]8.6 62335 1550 L-80 BTG -MOD
Tubing Strings
TUOing pe- Slung M. 1011n1 iop mu" Sa Oepm le.. Set Oepin (NOj 1... W11bX1) G,xle Top Connection
""d
TUBING J 1/2 2.992 28.9 5,442.2 36386 9.30 EUESROMOD
Completion Detalls
CONDUCTOR: 3101140
Nominal lD
Top IXN2 TOp(N01 (28,9 TopInpIPI
IGEOn Cam I3
017
20.9 20.9 0.1] HANGER VETCO GRAT TUBING HANGER 3500
5389.0 3,591.7 29.71 NIPPLECAMCO DS NIPPLE w/2812'NO GO PROFILE 2812
3URFHce, ao 4-aaa 3-
5,42].5 3625.5 2773 NOG. BAKER NO GO SDe 3000
5.428.3 3,626.2 2(69 6FALA6SV BAKER SEALASSEMBLY 3000
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Toc PVD' Topincl
Top XKB "KB1 I°I Des Com
Run Date
IDIin1
5,3890 3$91] 29]1 PLUG 261"CAQPLUGIOAL=26'}(2.31"F/N
12/P/201]
0.000
PRONG=1]5"F/N)
Perforations & Slots
snot
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Cees
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B11nXaIDI
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Top lrcNel
een (XKat
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Tree
Com
5,504.0
5,544.0
3,694.3
3730.9
VIS D. 10.101
12/2821100
4.0
1 IPERF
2.5" HSO. 60 deg phase
5,574.0
5,5940
3,758.5
3,777.0
VIS B, 10101
12/282000
4.0
IPERF
25" Han, 60 deg phase
Nock, 5.Me
5,584.0
5,6160
3,7770
3.795.5
WS B. VIS A-
122]/2000
4.0
[PERE
2.5" HSD, BO deg phase
PLUG: case
4, ID -10i
5,622.0
5,650)
31803.0
3,829.1
WS A4.1D-
122]2000
4.0
IPERF
2.5" HSD. 60 deg phase
101
5,668.0
5,684.0
3,545.9
3,8609
WS A3, 10.
12272000
4,0
PERE
2.5 Har. 60 deg phase
101
5,692.0
5,720.0
3,860.5
3,902.3
WS A3, 10.
12/26/2000
4.0
IPERF
2.5 HSD, 60 deg phase
01
5.]580
5.000.0
3923.0
3,970.1
WS Pill
12/26/2000
4.0
IPERF
2.5" HSO,BOdegpnase
101
Mandrel Inserts
by
NI
N Top I'pp
Top jNDl
(n,D*
MCael
G011n1
SLl
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Ipsp
Run Oale
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as
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KBG 2
1
GAS LIFT
OMY
DCR-1
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112]2000
SEAL Assva4ma
9
I
Notes: General & Safety
End Cat
W1812ot0 N.TE: uew Schematic w/Alaska achematic90
IPERF;5.500.Da.eN.
IPERF;5.5740.5$940
IPERF S.5940 Ski 40
IPERFS.M.VaGW.0
IPERF', 58.45,884.0
IPERF:5,8920-5.7ffi0
IPERF,5.7500S,8W0
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• A
Wallace, Chris D (DOA)
From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com>
Sent: Sunday, December 24, 2017 4:17 PM
To: Wallace, Chris D (DOA)
Cc: Senden, R.Tyler
Subject: Report of IA pressure anomaly 1D-101 (PTD 200-183) 12-24-17
Attachments: 1D-101 schematic.pdf; 1D-101 90 day TIO 12-24-17.JPG
Chris,
West Sak water injector 1D-101 (PTD 200-183) is experiencing an unexplained IA pressure anomaly. Attempts to bleed
the IA earlier this morning to establish a dP between the tubing and IA were unsuccessful. The tubing and IA pressures
are equalized at"880psi. The well will be shut in and freeze protected as soon as possible. Initial diagnostics with DHD
to include MIT/packoff testing will be pursued with follow-up well intervention work with slickline/Eline/coil as
appropriate. Prior to returning the well to injection, proper paperwork will be provided. Please let us know if you
disagree with the path forward.
Attached are the schematic and 90 day TIO plot.
Kelly Lyons/Jan Byrne
Well Integrity Supervisor
ConocoPhillips Alaska, Inc.
Desk Phone(907)659-7224
1
u
MEMORANDUM
Toy Jim Regg
P.I. Supervisor ~ ~~~ ~ ~2Z ~ ] ~
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
1D-101
KUPARUK RIV U WSAK 1D-101
Src: Inspector
NON-CONFIDENTIAL
Reviewed By:
P.I. Suprv r ~ =
Comm
Well Name: KUPARUK RIV U WSAK 1D-101
Insp Num: mitRCN100718161531
Rel Insp Num: API Well Number: 50-029-22986-00-00
Permit Number: 200-183-0 Inspector Name: Bob Noble
Inspection Date: 7/16/2010
Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
Well 1D-lo yT pe Inj. N ~ V 3626 IA 298 1722 1678 1670 r
P.T.Di zools3o ITypeTest SPT Test psi 1722 OA
Interval aYRTST p/F P Tubing looo lozs lots lozs
Notes: til; ~., ~C~ ~5~ ~ ~0 ~~;
~~ ~~.
Thursday, July 22, 2010 Page 1 of 1
I
WELL LOG TRANSMITTAL
To: Alaska Oil and Gas Conservation Comm. October 8, 2009
Attn.: Christine Mahnken
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
RE: Injection Profile: 1D-101
Run Date: 7/19/2009
The technical data listed below is being submitted herewith. Please address any problems or
concerns to the attention of:
Rafael Barreto, Halliburton Wireline Perforating, 6900 Arctic Blvd., Anchorage, AK 99518
1D -101
Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom
50 -029- 22986 -00
Injection Profile Log :itANNET, N0,1 s 7 2009 1 Color Log
50- 029 22986 -00
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE
TRANSMITTAL LETTER TO THE ATTENTION OF:
Halliburton
Wireline Perforating
Attn: Rafael Barreto 3
6900 Arctic Blvd. O a @DU
Anchorage, Alaska 99518 l `6 t 1 6
Office: 907 273 -3527
Fax: 907 273 -3535 T
rafael.barretoi (turar%c
NOV o 5 ?0U
Date: ,�,,�4� F� Signed:
yap. ^)°07Sic-
Tc~: AClGCC
Christine Mahnken
333 West 7th Avenue
Suite 100
Anchorage, Alaska 99501
(907) ~59-5102
RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing tnspection(Caliper / MTT)
The technical data listed below is being submitted herewith. Please acknowledge receipt by returning
a signed copy of this transmittal letter to the following :
PrcAct+ve Diagnostic Services, lnc.
Attn: Robert A. Richey
130 West International Airport Road
Suite C
Anchorage, Alf 99518
~ax: (907~ 245-8952
(1) Caliper Repor~ 28-Jun-09 1 D~101 1 Report / EDE 5Q-029-22986-00
2) Caliper Report 28-Jun-09 1 a103 1 Report / EDE 50-029-23086-00
~~~ ao~ -l~3 I~a~9
i>z-c- ao~ - D9 ~ ~~ aap ax~~~~~~~. ;L~;... :~; 2~C'.~
,
`y _ ,
Signed : Date :
Print Name:
PROACTNE DIliGNOSTIC SERVICES, ItdC., 130 FN. INTERNATIONAL ~IRPORT RD SUITE C, ANCHORAGE, AK 99518
PHONE: (9074245-8951 FAx: (907'245-88952
E-NIAIL : . " : _ :: ~/VEBStTE : _ `
~
C~`.Documenis and Settings\Oamer~Desk[op\Trnnsmit_Conoco.docx
~ ~
Memory Multi-Finger Calipe~r
s Log Resuit~ ~ummary
Company: ConocoPhillips Alaska, Inc. Well: 1 D-101
L.og Date: June 28, 2009 Field: West Sak
Log No. : 7337 5tate: Alaska
Run No.: 1 API No.: 50-029-22986-00
Pipe1 pesc.: 3.5" 9.3 ib. L-80 EUE 8RQ Top Log Intv11.: Surface
Pipe1 Use: Tubing and Liner Bot. Lc>g Intvtl.: 5,523 Ft. (MD)
Inspection Type : Buckling ~ Corrosive & MechanicaJ Damage inspection
COMMENTS :
This caliper data is fled lnto the DS-Nipp/e @ 5,389' (Dritier's Depth).
This log was run to assess the condition of fihe tubing and liner with respect to subsidence induced budcling
and corrosive and mechanical damage. The caliper recordings indicate the 3.5" tubing and liner iogg~d are
in good to poor condition, with a maximum reeorded wall penetration of 50°r6 recorded in a line of pits in joints
56 (1,770') and 151 (4,763'). Wall penetrations from 20~o to 49% wall thickness are recorded in 135 of the
179 joints logged. Recorded damage appears as a line of piis from -1,950' to 5,523' (EOL). No significant
areas of cross-sectionat wall loss or I.D. restrictions are recorded throughout the tubing and liner logged.
The caliper recordings indicate no significant buckiing throughout the 3.5° tubing and liner logged. A log plat
of the centered and off-center caliper recordings from surface to 1,000' is inctuded in this report.
3.5" TUBING ~ LINER - MAXIMUM RECORDED WALL PENETFtAT10NS:
Line of pits ( 50%) Jt. 56 @ 1,770 Ft. (MD)
Line of pits ( 50°r6) Jt. 151 ~ 4,763 Ft. {MD)
Line of pits ( 49°~) Jt. 148 ~ 4,598 Ft. (MD)
Line pf pits ( 48%) Jt. 141 @ 4,463 Ft. (MD)
Line of pits ( 43%) Jt. 58 ~ 1,833 Ft. (MR)
3.5" TUBING & LINER - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS :
No significant areas of cross-sectiona! wall ioss {> 7%) are recorded throughout the tubing and liner logged.
3.5" TUBING $ LINER - MAXIMUM RECORDED ID RESTRICT1t3NS :
No s~nificant I.D. restrictions are recorded throughout the tubing and li~er logged.
Field Engineer: Wm. McCrossan Analyst: C. Waldrop Witness: C. Fitzpatrick
ProAckive Diagnostic Servlces, inc. / P.O. Box 1369, Staffard, TX 7?49?
Phone: {2$i} or (&88} 565-9085 Fax: (281) 565-1369 E-mail; PDS~memorylag.com
Prudhoe Bay Field Office Phone: (907} 659-2307 Fax: (90?) 659-231~
U T.~ ao~ -~~53 l~s2 ~
' • •
~~ PDS Multifinger Caliper 3D Log Plot
' Company : ConocoPhillips Alaska, Inc. Field : West Sak
Well : 1 D-101 Date : June 28, 2009
' Description : Detail of Centered and Off-Center Caliper Recordings from Surface to 1,000'
Comments Depth Max ID (1/1000 in.) (Off-Center) Image Map (Centered) Image Map
1ft:750ft 2500 _ _ 3500 0° 90° 180^. 270° 0° 0° 90° 180° ~ 270° . U•
Min ID (t/1000 in.)
2500 3500
Nominal tD (1/1000 in.)
:.. ............................................................ .
2500 3500r
Tree ~
- ' I
_~ .
,
~
~ •
500 - .,,.~, ~.;~.: .
-
Joint 16 r
i- '
: ~
Joint 17
550
_. ' ~
; ' '~x ~
~ ,~
oint 18 _
, ; _ ... _~
- - ~
M
- K~
,,,~.~-. ...._..
~ ~'
~`~~~_ ='~. .
_
•
6~~
Joint 19 i
~
_ _ ,_ _ , -
; _
---
, - _-
~---.~+~~e+s..
~`
~ -.
Joint 20 ss~ - ~ ~
"
~'.
~
.. _
_ .
-,+~PNI
-
Joint 21 _ ~~
_ , ~ _ - __ _~.
--~ - - , -
'"
."'~""'"
~"._..
-
700 _ .
' ., . -~...
°.
~oint 22 ;. _,.~ '
~...
Joint 23
750 ~ °
'y'd
Joint 24 ,
;
~ M~
~
- --"=~+~ws~:
,~,:
Joint 25 $~~
_~~~
~
Joint 26 --7 --I
! -~
,';% ~ ~ ~
:
. ,
,`. '~ '~"~~..? :~~'
~
Joint 27 BrJ~ ~
-- m
t
-- ~"--~'_ "~'t~~' ",~~
'~
Joint 28 900 6 . ~
~,
,,,~„~.,
- -•,~.--
-
~'*~r
Joint 29 _ B~~N~~.._
950
.loint 30 ,
-- ~y `
-
: ---, _ .
Joint 31 .
i
, ~.
i--7- - I '
*~,
I
Nominal ID (1/1000 in.)
i ...............................................................
2500 3500+
Min ID (7/1000 in.)
2500 3500
Comments Depth Max ID (1/1000 in.) (Off-Center) Image Map (Centered) Image Map
1ft:750ft 2500 3500 0° 90° 180° 270° 0° 0° 90° 180° 270° 0°
~ ~
Correlation of Recorded Damage to Borehole Profile
^ Pipe 1 3.5 in (28. t' - 5512.4') Well: t D-101
Field: West Sak
Company: ConocoPhillips Alaska, Inc.
Country: USA
Survey Date: )une 28, 2009
~ A pprox. Tool De viation ^ A pprox. Boreho le Profil e
~ 32
25 784
5~~ a 1565
"i, ~
°~
7 ~ ~ 2352 ~
` ~
a
,
.n
E `~
~ ~
Z
s
0 10t1 3143 ~
~
12 ~ 3935
150 4718
GLM 1
_..
174 5512
0 5 0 1 00
Dam age Pr ofile (% wall) / Tool D eviatio n (degr ees)
Bottom of Survey = 174
• •
PDS Report Overview
~ ~~ Body Region Analysis
Weli: 1 D-101 Survey Date: June 28, 2009
field: West Sak Tool Type: UW MFC 24 No. 218370
Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69
Country: USA No. of Fingers: 24
Analyst: C. Waldrop
Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len.
3.5 ins 9.3 f L-80 EUF 8RD 2.992 ins 3.5 ins 6.0 ins 6.0 ins
Penetretion and Metal Loss (% wall)
~ penetration body ~~ metal loss body
200
150
100
SO
~ 0 to 1 to 10 to 20 to 40 to over
1% 10% 20% 40% 85% 85%
Number of 'oints anal s ed total = 179
pene. 0 11 31
loss 10 169 0 125 12 0
0 0 0
Damage Configuration ( body )
150
l0U
5U
~_
isolated general line ring hole / poss
pitting corrosion corroaon corrosion ible hole
Number of ~oints dama ed total = 143
143 0 0 0 0
Damage Profile (% wall)
~ penetration body ~ metal loss body
0 50 100
n
GLM 1
Bottom of Survey = 174
Analysis Overview page 2
•
PDS REPORT JOINT TABI.
Pipe: 3.5 in 93 ppf L-80 EUE 8RD Well:
Body Wall: 0.254 in Field:
Upset Wall: 0.254 in Company:
Nominal I.D.: 2.992 in Country:
Survey Date:
•
iLATION SHEET
1 D-101
West Sak
ConocoPhillips Alaska, inc.
USA
June 28, 2009
)oint
No. Jt. Depth
(Ft.) I'c~n.
~JF,~c~i
(Ins.) Pen.
Body
(Ins.) I'en.
°i~ ~~1c•~,il
Ic~,s
°~<~ Min.
I.D.
(Ins.)
Comments Damage Profile
(%wall)
0 50 100
.1 28 l) 0.03 i t I 2.92 PUP
1 32 ~) 0.02 7 ' 2.94
~ 65 ~) 0.03 11 4 2.93
3 96 t) .03 11 1 2.93
4 127 ~~ 0.02 ~~ i 2.92
5 159 U 0.01 ~ 2.93
6 190 ~) 0.03 1 ~ 7 ' 2.93
7 221 U 0.03 11 i 2.94
8 253 U 0.03 1O _' 2.92
9 283 U 0.03 1 1 ~~ 2.92
10 315 t) 0.02 '+ I 2.92
11 34 ~~ 0.03 I~ -I 2.92
12 377 ~~ 0.03 II ~ 2.94
13 409 ~~ Q.02 7 I 2.92
14 440 ~! 0.03 1 I I 2.92
15 470 U 0.02 9 2.94
16 502 U 0.03 12 -~ 2.94
V 533 ~~ 0.01 5 ~~ 2.93
18 564 ~~ 0.03 11 I 2.92
19 596 i~ 0.04 I-~ 2.94
20 627 U 0.02 ~~ -J 2.95
21 659 ~ ~ 0.03 I 1 2.93
22 690 U 0.03 I~~ ~ 2.93
23 721 t1 0.03 11 3 2.92
24 753 ~7 .02 '3 ~~ .91
25 784 c~ 0.03 12 ~1 2.94
26 815 t> 0.04 1(~ ~ 2.93
27 847 U 0.05 Zt) ~ 2.94 Isolated ittin .
28 875 ~~ 0.07 Zt3 ~ . 2 Isolated ittin .
29 906 c1 0.04 15 -3 2.94
30 937 ~~ 0.03 13 -t 2 94
31 969 ~~ 0.05 ~' 1 ' 2.93 Isolated ittin .
32 1000 ~~ 0.03 1! -t 2.95
33 1032 n 0.04 1 i ~ 2.93
34 1063 l) 0.03 13 5 2.95
35 1094 l1 0.04 1 i i 2.94
36 1126 ~> 0.04 14 _' 2.94
37 1157 ~~ 0.07 2tS ~ 2.92 Line of its.
8 1188 ~~ 0.05 1~) t~ 2.94 Lineof its.
39 1220 n 0.06 2l ~ 2.93 Line of its.
4D 1251 t1 0.07 ?8 ~ 2.94 Line of its.
41 1282 U 0.06 'S > 2.95 Line of its.
42 1314 t~.t>> 0.07 1(~ 2.94 Line of its.
43 1345 t~ 0.07 1ft 2.93 Line of its.
44 1377 U 0.07 ~~f5 ~4 2.94 Line of it .
45 1408 u 0.06 15 1 2.94 Line of its.
46 1439 ~) 0.07 ~~ 4 2.94 Line of its.
47 1 a71 U 0.08 iU 2 2.93 Line of its.
48 1502 l~ 0.06 2,' ~' 2.93 Line of its.
49 1533 U 0.07 26 ~~ 2.94 Line of its.
Penetration Body
Metal Loss Body
Page 1
•
PDS REPORT JOINT TABI,
Pipe: 3.5 in 9.3 ppf L-80 EUE 8RD Well:
Body Wall: 0.254 in Field:
Upset Wall: 0.254 in Company:
Nominal I.D.: 2.992 in Country:
Survey Date:
•
iLATfON SHEET
1 D-101
West Sak
ConocoPhillips Alaska, Inc
USA
June 28, 2009
)oint
No. )t. Depth
(Ft.) I'<•n.
Il~,;c•i
(In:.) Pen.
Body
(Ins.) Pen.
°i~> Mc~t,~l
Ic,s~
"~> Min.
I.D.
(Ins.)
Comments Damage Profile
(%wall)
0 50 100
50 1565 ~~ 0.09 ~:9 ~ 2.94 Line of its.
51 1596 U .06 ' i ; 2.96 Vne of its.
5 16 7 (~ 0.08 3 i ~t .93 Line of 't~.
53 1659 ~~ 0.08 ~3"~ 4 2.95 Line of its.
54 1690 t~ 0.08 ~2 ~1 .95 i of its.
55 1722 (? 0.10 4l) 5 2.93 Line of i.
56 1753 u 0. 3 5U ~ .93 Line of its.
7 1784 t~ 0.09 s(, .9 Line of its.
58 1816 l) 0.11 43 (~ 2.96 Line of its.
59 1848 u 0.10 4U 2.95 Line o i.
60 1879 ti.t~r, 0.09 37 ~i 2.96 Line of its.
61 1911 ~. i 0.10 -1U _' 2. 3 Line f i.
62 1942 u 0.11 a~ _' 2.95 Li n of i ts.
63 1974 ~~.~> ; .09 34 ~' 2.93 i of i
64 2005 u .07 2ts ~i .96 Line of its.
65 2037 u 0.08 31 (, 2.9 ~ne of its.
66 2067 u 0.10 -3u 7 .96 ine of its.
67 098 (~ 0.10 ~t3 a .96 Line of its.
68 2130 U 0.08 ;3 G .95 Lin of its. ' ~~ ~
69 2162 !~ 0.08 ~~' 2. 6 Line f i.
70 2194 t~ 008 ~~1 ~~ 2.96 Lineof ~ts.
71 2225 ~~ 0.06 ~-~ ~~ 2.94 ine of its.
72 257 t~ 0.09 ; i 5 .96 Line of its.
73 2289 ~) 0.06 ~'~1 i~ 2.96 Line of its.
7 1 !~ . 7 'ti 5 2. 6 i e f'
75 2352 u 0.06 ~ 5 _' 2.95 Vne of its.
76 2384 t~ 0 07 27 t~ 2.94 Line of its
77 2416 U 0.06 2~t ~~ 2.96 Line of its.
78 2447 ~~ 0.06 2 s i, 296 Line of its.
79 2479 ~~ 0.07 ~'(~ _' 2.95 Line of its.
80 51 1 u 0.08 ;1 t> 2.96 Une of its.
81 2542 U 0.07 1~ ~~ 2.94 Line of its.
82 257 ~~ 006 13 5 2.95 Lineof its.
83 2606 ~~ 0.07 2ti 5 2.96 Line of its.
84 2637 t1 0.07 27 ~ 2.95 Line of its.
85 2669 U.US 0.07 1b -~ 2.96 Line of its.
86 270 ~) 0.09 34 (> .9 i e o its.
87 2732 (1 0.07 2(~ 'i 2.95 Line of its.
88 2764 tt 0.07 ?t~ t~ 2.93 Line ( its.
89 2796 ~) 0.06 Z~; ~~ 2.95 Line of its.
90 2826 ~~ 006 ~'~ ~: 2.96 ineof its.
91 2858 ~~ 0.06 ~<=1 ~~ 2.96 Line of its.
9 2890 ~~ 0.06 ~' ; > .9 L'ne of its.
93 2922 ~1 0.05 21 5 2.95 Line of itr.
9 2953 ~) 0.05 ~(~ 5 2. 6 i of i
95 2985 u 0.04 16 (~ 2.95 Line of its.
96 3017 (~ 0.07 _'(~ ~~ 2.95 Line of its.
97 3048 ~~ 0.06 2 i 2.94 Line of its.
98 3 80 i~ 0.07 2(, 2.96 Line of its.
99 3112 u 0.06 14 2.96 L.ine of its.
Penetration Body
Metal Loss Body
Page 2
•
PDS REPORT JOINT TABI.
Pipe: 3.5 in 9.3 ppf L-80 EUE SRD Well:
Body Wall: 0.254 in Field:
Upset Wall: 0.254 in Company:
Nominal I.D.: 2.992 in Country:
Survey Date:
•
~ LATI ON SH EET
1 D-101
West Sak
ConocoPhillips Alaska, Inc
USA
)une 28, 2009
Joint
No. Jt Depth
(Ft) I'~~n.
( 1~,;~~t
(Im.) Pen.
13ody
(Ins.) Pen.
"r~ ~1c~t,~l
I oss
°~, Min.
I.D.
(Ins.)
Comments Damage Profile
(% wall)
0 50 100
100 3143 i~ 0.06 22 ~ 2.96 Line of its.
101 3175 ~~ 0.06 2~ ~i 2.95 Line f its.
10 3207 O 0.06 Z? t~ .96 Line of its.
103 3238 ~~ 0.05 1 t3 '~ .96 Line of its.
104 3270 ~~ 0.05 1U 5 2.96 Line of its.
105 3301 l1 0.07 ~9 (, 2.96 Line of its.
106 3333 ~~ 0.07 3U ~~ 2.95 Line of its.
107 3365 ~~ 0.06 ~~2 r, 2.96 Line of iLs.
108 3397 U 0.07 Z6 (, .95 Line of its.
109 3428 U 0.07 2E~ ~ 2.95 Line of its.
110 3460 i~ 0.05 1£9 i 2.96 Line of its.
111 3492 U 0.08 i:i ~ 2.96 ine of its.
112 3523 U 0.07 _'ti (, .95 Line of ~ts.
113 3555 ~~ 0.06 '_' i 2.95 Line of its.
114 3587 c~ 0.08 it 5 2.93 Line of its.
115 3619 u 0.05 _'u ~ 2.95 Line of its.
116 3650 ~~ 0.06 '-1 t, 2.95 Line of its.
17 3682 U 0.08 SU (~ 2.95 Line of its.
118 3714 ~~ 0.07 2i 6 .96 Line of its.
119 3745 ~~ 0 07 ~' !~ 2.96 Line of its.
120 3777 u 0.07 _'t~ !, 2.95 Line of its.
121 3809 ~~ 0.08 ,Z !~ 2.95 Line of its.
122 3840 ~~ 0.08 > 1 ~, 2.95 Line of its.
123 3872 U 0.08 ~i~t i~ 2.96 Line of its.
390 U.~~,-~ 0.0 ~'b ~ .9 in f~t .
125 3935 ~~ 0.09 35 ~ 2.96 Line of its.
12 3967 ~~ 0. 7 28 (, 2.96 Line of its.
127 3998 ~l 0.08 32 E~ 2.96 Line of its.
128 4030 ~> 0.07 ~'£3 (~ 2.95 Line o its.
129 4062 ~~ 0.06 ~'-1 -4 2.95 Line of its.
130 4093 ~? 0.06 ~~1 I 2.94 Line of its.
131 4124 u 0.07 2£i ~ 2.94 Line of its.
132 4156 ~~ 0.07 ~'~~ 2.94 Line o ils.
133 4187 U 0.06 .' 3 d 2.93 Line of its.
134 4218 U 0.08 ~3 ~ ~ 2.93 Line of i s.
135 4250 U 0.09 ~7 5 2.93 Line of its.
136 4281 t) 0.09 ~37 ~1 2.94 line of ifs.
137 4312 t) 0.09 t5 ~1 2.94 Line of its.
138 4344 ~~ 0.09 i5 ~ 2.95 Line of i.
139 4375 u 0.08 s~~ ~ 2.93 Linc of its.
140 6 ~~ 0.09 3(~ (~ 2.95 ine of ~ts.
141 4437 U 0.12 4ff b 2.96 1_ine of its.
142 4469 ~~ 0.10 ~l 1 ~, 2.96 Line of its.
143 4501 U 0.10 i9 6 2.96 Line of its.
144 4532 U 0.11 42 i .95 Line f its.
145 4564 U 0.08 i3 5 2.94 Line of its.
146 4595 (~ 0.12 =19 4 2.93 Line of its.
147 462 5 ~ 1 0.10 ~1t 1 4 2.94 Li ne of i ts.
148 4656 ~~ 0.11 4 3 -1 2.94 Line of its.
149 4688 t1 0. 8 ~3 t > 2.93 Line of its.
Penetration Body
` Metal Loss Body
Page 3
•
PDS REPORT JOINT TABI,
Pipe: 3.5 in 9.3 ppf L-SO EUE 8RD Weli:
Body Walf: 0.254 in Field:
Upset Wall: 0.254 in Cornpany:
Nominal I.D.: 2.992 in Country:
Survey Date:
•
~LATION SHEET
1 L~-101
West Sak
ConocoPhillips Alaska, Inc.
USA
June 28, 2009
Joint
No. Jt. Depth
(Ft) I'~~n.
~1F~~E~t
(In~J Pen.
13ody
(InsJ I'f~n.
",% 1~t~~t,~l
lu~~
"~~~, Min.
I.D.
(Ins.)
Comments Damage Profile
(%wall)
0 50 100
1 0 471 u 0.0 37 -~ 2.93 Li e of 'ts.
151 4749 t~ 0.13 5U 5 2.9 Line of its.
15 4780 U 0.07 '9 s .93 Line o its.
153 4812 t~ 0.08 ~~> ? 2.93 I.ine of its.
154 4843 U 0.08 t I 5 2.94 Line of its.
155 4874 (~ 0.07 ?~~ t 2 9 Line of its.
156 4906 ~~ 0.08 tt) ~3 .95 Line of its.
157 4937 ~1 0.07 ~'ti ' 2.93 Line of its.
158 4967 ~~ 0.10 i~) , 2.9 ine of its.
159 4998 ~~ 0.08 31 4 .93 Line of its.
160 5030 U.l~; 0.1 38 t 2.92 Line of itr.
61 5061 ~~ 0.09 3S _' 2.92 Line of its.
162 5092 ~~ 0.11 43 3 2.91 Line of its.
163 5124 (~ 0.09 35 , 2.93 Line of its.
164 5155 l~ .09 ;4 ~ 2.94 Lin of 'ts.
165 5786 U 0.11 -~Z J 2. 3 ine of its.
166 5217 ~?.l);' 0.11 -13 '~ 2.95 Line of its.
167 5249 l1 0.07 2~ ~ 2.95 'ne of its.
168 5279 l).t)(~ 0.08 3l1 -t 2.94 Line of its.
169 5310 U 0.08 iZ t 2.93 ine of its.
169.1 5340 tt 0.07 Z8 _' 2.92 PUP Line of its.
169.2 5346 (~ 0 U ~~ N A G M 1 Latch ~:00
169.3 5352 t~ 0.08 ; 3 ' 2.93 PUP Line of its.
170 5358 t1 0.08 ~ i -1 2.93 Line of its.
170 1 53 9 ~) 0 U ~~ 2.81 amco S-Ni e
171 5391 U 0.09 35 (, 2.93 Line of its.
171.1 5421 ti 0.08 >Z 2.94 PUP Line of its.
171.2 5427 U 0 (1 U 3.00 Baker Seal Assembl
171.3 5440 (1 0 U U 3.00 aker Seal Bore xtension
171.4 5442 (~ 0.09 34 Z 2.89 PUP Line of its.
172 5451 ~~ 0.09 ; 5 2 .93 To f 3.5" Li er. Line f its.
173 5482 (~ 0.10 i9 -1 2.91 Perforations. `~~
174 5512 O 0.09 3~ 4 2.91 erforations.
~ Penetration Body
Metal Loss Body
Page 4
PDS Report Cross Sections
~--~ ~~ „
u
Well: 1 D-101 5urvey Date: June 28, 2009
Field: ~'Vest Sak Tool Type: UW MFC 24 No. 218370
Company, ConocoPhillips Alaska, Inc. Tool Size: 1.69
Country: USA No. of Fingers: 24
Tubin : 3.5 ins 9.3 f L-80 EUE 8RD Anal sr. C. Waldro
Cross Section for Joint 56 at depth 1770.02 ft
Tool speed = 43
Nominal ID = 2.992
Nominal OD = 3.500
Remaining wall area = 97 °~
Tool deviation = 37 °
Finger 11 Penetration = 0.128 ins
Line of pits 0.13 ins = 50% Wall Penetration HIGH StDE = UP
i
•
Cross Sections page 1
~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~
PDS Report Cross Sections
.~ -'~ ,
u
Well: 1 D•101 Survey Date: June 28, 2009
Fieid: West Sak Tool Type: UW MFC 24 No. 218370
Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69
Country: USA No. of Fingers: 24
Tubing___ 3.5 ins__ 9.3 ppf L-80 EUE 8RD Analyst: C. Waldrop
Cross Section for Joint 151 at depth 4762.5 ft
Tool speed = 43
Nominal ID = 2.992
Nominal OD = 3.500
Remaining wall area = 98 %
Tooi deviation = 51 °
Finger 24 Penetradon = 0.126 ins
Line of pits 0.13 ins = 50% Wall Penetration HIGH SIDE = UP
~
~
Cross Sections page 2
~, ~~ KUP ~ 1 D-101
ConocoPhillip s Weil Attributes Max M Ie 8 Np TD
~~~~ ~~ ~ w nae
5002922 ru ea Name
98fi00 WESTSAK
INJ PJJI ~na 1°I 1
68.43 3,832.87 ~~ )
6,100.0
CommM
NO
~SV~
NE ) e n
0 7/1/2008 La
IWO g sa
39
66 iimnooo
ei
i asooaa .
~
lastTag:
SLM
5,725.0
72/112008 s
Rev Reasrn: TAG FILL : .
ae
1y1Z2008
Casin Strin s
casinp
n amgo
1~1 o smne
Pnl
Tou 1~Bi set
1~1
A~G 1 cnrgv~
Pbhq snr~g
~i'aae
iop mro
CONDUC TOR 1 6 15.062 0.0 118.0 1 18.0 151.53 X65 WELDED
Insulated
CONDUCTOR SURFAC 10 3 /4 10.050 0.0 499.0 4 98.9 40.50 J~i5 B
~^w~~,~~a PRODUC TION 51 /2 4.950 0.0 5,429.0 3,6 272 75.50 L~0 BTCMOD
UNFR 31 /2 2.992 5,429.0 6,078_0 42 32.9 9.30 L~0 EUE8FiD
S
RF
6 Tubi Strin
U
ACE.
DB
111iq D
ezalptlon
rln0
(„)
B~Mi91D
(M)
TuP (~g)
Set De
(~0)
Set
P~B)
~
rYg
(m~)
BtrMg
~~
StrYp Top MA
TU&NG 31 /2 2.992 0.0 5,428.0 3,6 26.3 9.30 L~0 EUESRD
Othar I n Nok A lt Jewe l . Tu Run ~ R etrisva Fish etc .
~ns ~iFi.
5.315
YO T°P oePtl~
(N~
1KKB1
Top YIN
1'1
Can~t
p~n Datf
D
5.345.0 3.554.3 31.97 G hS UFT CAMCO/KBG 2-9I11DMYIDCR-1/q Cortrnent: STA 1 ~ in~nooo 2.900
5.389.0 3,591.7 29J1 N IPPLE Cartico'DS' Nipple w/No-Go prolie 1/27/2000 2.812
5,428.0 3.626.3 27.70 S EAL Bake~Seal Assembly iimnaoo 3.000
6.077.0 4132.0 19_O6 S HOE Weatherford Fbat Sfae 17@7M000 2.992
NIPPLE. 5389 P~O~ ~~
T
ehn
Top~TVq
p~K6)
B6n(TVq
I~e)
Zuna
orte Sllaf
De~s
(sh...
~~
5,504.0 5,544.0 3,~4.8 3,731.0 V /S D, 10.101 12/28/200~ 4.0 IPER F 2.5' HSD. 60 deg phase
5.574.0 5.594.0 3.758.5 3, .0 WS B, 10.101 12f2&2000 4.0 IPER F 2.5' HSD, 60 deg phase
5,594.0 5,6U.0 3.777.0 3,795.6 WS B, WS A~d. 17J27/2000 4.0 IPER F 2.5' HSD, 60 deg pAase
spxe
s~u ~ o-~oi
. 5,6Y1.0 5,650.0 3,803.1 3,829.t WSA4,10.101 12f27f2000 4.O IPFA F 2.5'HSD,60degphaae
FROWCTION.
S,d79 S.GG$.O 5.684.0 3.84b.9 3.861.0 WSN, 1D701 12/27R000 4.O IP F 2.5'HSD.60de9phase
5,692.0 5.728.0 3,868.5 3,902.3 WS AS, 10.101 12126l2000 4.0 IPER F 2.6' HSD. 60 deg phase
5,750.0 5.800.0 3,923.0 3,970.1 WSA2,1O-101 1 4.O IP 2.5'HSD,80degplrese
IPERF
S.SOA5.56e
IPERF,
5.5115.591
IPERF,
5.594fi.614
IPERF.
5,627-5,650
IGERF.
5,888-5.6H4
IPERF,
5 E97~S.i.R
IPERF,
5,1505,800
SMOE, 6 077
LINER.6.018
TD,6.100
~
.
.
ConocÓÂ1i1lips
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
aeo-t ~3
SCANNE.D JUL 1 1 2007
Dear Mr. Maunder:
Enclosed please find a spreadsheet with a list of wells trom 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 trom 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.
ConocoPhillips Well Integrity Project Supervisor
.
.
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 oft Corrosion inhibitor/
Well Name PTD# cement DumDed cement date inhibitor sealant date
ft bbls ft !:I a I
1 D-09 198-065 23" na 5 6/912007
10-101 200-183 2" na 3.2 6/9/2007
10-102 200-075 2" na 3.2 6/912007
10-103 202-096 5" na 8 6/912007
1O-105a 201-202 25" na 38 6/912007
10-106 197-240 2" na 3.2 6/912007
10-107 200-177 2" na 3.2 6/912007
10-108 198-187 8" na 12.8 6/912007
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 6/9/2007
10-116 198-172 2" na 1 61912007
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 6/9/2007
10-122 198-149 2" na 1 6/912007
10-123 198-170 2" na 1 6/912007
1O-125a 200-044 2" na 1 619/2007
10-126 198-108 2" na 1 6/9/2007
10-127 198-109 8" na 2.5 6/912007
10-128 198-133 2" na 1 6/912007
10-129 197-213 2" na 1 619/2007
10-130 197-183 23" na 5 6/9/2007
Kuparuk Field
June 9,2007
Sc~lunIbepg8l'
NO. 3887
Schlumberger -DCS
2525 Gambell Street, Suite 400
Anchorage, AK 99503-2838
ATTN: Beth
{,",., Ì','tþtf~~)
..;¡\,.·n." (Ç¡¡¡.,'
?:. l~i:
Company: Alaska Oil & Gas Cons Comm
Attn: Christine Mahnken
333 West 7th Ave, Suite 100
Anchorage, AK 99501
()ûO - 1~3
UTe!-
Field:
Kuparuk
Well
BL
CD
Color
Job #
Log Description
Date
rW
-:/
1E-1Ð2 11211600 INJECTION PROFILE 06/23/06 1
1Y-12 (REVISED) 11235362 INJECTION PROFILE OS/20/06 1
1 E-1iJ5L 1 11213766 INJECTION PROFILE 06/20/06 1
1B-18 N/A PRODUCTION LOG W/DEFT 06/25/06 1
1J-164 11213765 INJECTION PROFILE 06/19/06 1
1 C-2S 1102601 SCMT 06/24/06 1
3M-22 11213770 PRODUCTION PROFILE W/DEFT 06/26/06 1
2M-12 11213771 PRODUCTION PROFILE W/DEFT 06/27/06 1
1Q-12 11285929 MEMORY INJECTION PROFILE 06/24106 1
1Y-07 11285928 MEMORY INJECTION PROFILE 06/23/06 1
1D-125A 11213778 INJECTION PROFILE 07/17/06 1
2K-14 11213777 PRODUCTION PROFILE W/DEFT 07/16/06 1
1C-20 11213775 FBHP SURVEY 07/14/06 1
1J-156 11216308 USIT 07/10/06 1
2K-06 11213773 INJECTION PROFILE 07/12106 1
2K-22 11249925 LDL 06/06/06 1
1 F-15 11249910 INJECTION PROFILE 06/05/06 1
1E-36 11235375 PRODUCTION PROFILE 07/13/06 1
2K-17 11249923 PRODUCTION PROFILE/DEFT 07/04/06 1
1 H-04' 11320991 INJECTION PROFILE 07/03/06 1
1D-101 N/A INJECTION PROFILE 06/27/06 1
2Z-13' 11249930 LDL 07/11/06 1
1D-106 N/A INJECTION PROFILE 06/26/06 1
2M-21 11320987 PRODUCTION PROFILE 06/29/06 1
2W-01 11320985 PRODUCTION PROFILE/DEFT 06/14106 1
1 E-28 11320986 PRODUCTION LOG 06/28/06 1
1J-101 40012836 MD & TVD VISION RESISTIVITY 12/20/05 2 1
Please sign and return one copy ofthis transmittal to Beth at the above address or fax to (907) 561-8317. Thank you.
07/24/06
e
e
MEMORANDUM
e
State of Alaska e
Alaska Oil and Gas Conservation Commission
TO:
Jim Regg
P.I. Supervisor
k)-t:{;j It-zS}O(;;
\.. '-
DATE: Wednesday, July 12,2006
SUBJECT: Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA INC
ID-101
KUPARUK RIV U WSAK 1D-101
a()O -- \ <3 3
FROM:
Jeff Jones
Petroleum Inspector
Src: Inspector
Reviewed By:
P.I. Suprv ,.:ffi¡2---
Comm
Well Name: KUPARUK RIV U WSAK 10-101 API Well Number 50-029-22986-00-00 Inspector Name: Jeff Jones
Insp Num: mitlJ060711172728 Permit Number: 200-183-0 Inspection Date: 7/10/2006
ReI Insp Num
Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
Well 1D-101 ¡Type Inj. ¡ W I TVD I 3626 I IA I 250 I 1810 1780 I 1780 I
i
P.T. i 2001830 ¡TypeTest! SPT i Test psi 1500 10A ! I I
I I
4YRTST P ./ Tubing! 1045 1045 1045 I 1045
Interval P/F ¡
Notes Monobore ipjector, 0.7 bbls diesel pumped. 1 well house inspected; no exceptions noted.
..../
NON-CONFIDENTIAL
Wednesday, July 12,2006
Page I of I
SURF
CASING
(Q-499,
OD:10.750,
Wt:40.50)
Gas Lift
mdrellDum m y
Valve 1
(5345-5346,
OD:4.725)
TUBING
(0-5428,
OD:3.500,
ID:2.992)
NIP
(5389-5390,
OD:3.500)
PROD
CASING
(0-5429,
OD:5 .500,
wt: 15.50)
SEAL
(5428-5429,
OD:4.000)
Perf
(5504-5544)
Perf
(5574-5594)
Perf
(5594-5614)
LINER
(5429-6078,
OD:3.500,
Wt:9.30)
Perf
(5622-5650)
Perf
(5668-5684)
Perf
(5750-5800)
e
KRU
1 D-101
I
¡
1=
MEMORANDUM
)
State of Alaska
)
Alaska Oil and Gas Conservation Commission
TO:
Jim Regg 0 ttU,.t1 bll;/{)~
P.I. Supervisor N (t Y'
DATE: Thursday, May 19,2005
SUBJECT: Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA INC
lD-IO I
KUPARUK RIV U WSAK lD-lOl
~o(¡)-1~3'
FROM:
Jeff Jones
Petroleum Inspector
Src: Inspector
Reviewed By:
P.I. Suprv ,jßí!
Comm
NON-CONFIDENTIAL
Well Name: KUPARUK RIV U WSAK 1D-101 API Well Number: 50-029-22986-00-00
Insp Num: mitJJ0505 I 8075723 Permit Number: 200-183-0
Rei Insp Num:
Inspector Name: Jeff Jones
Inspection Date: 5/17/2005
Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
Well lD-I0l Type Inj. W TVD 3626 IA 290 2010 I 1970 1970
P.T. 2001830 TypeTest SPT Test psi 906.5 OA
Interval 4YRTST P/F P Tubing 1300 1300 1300 1300
Notes: "Monobore" type injector. 1 well house inspected; no exceptions noted.
SCANNEDì AUG I) 920œi
Thursday, May 19,2005
Page 1 of 1
5622 - 5650 3803 - 3829
5668 - 5684 3846 - 3861
5750 - 5800 3923 - 3970
Gas Lift MandrelsNalves
St MD TVD Man Man
Mfr Type
1 5345 3554 CAMCO KBG 2-9 CAMCO
Other l:)lugs, equip., etc.: - JEWELRY
Depth TVD Type
5389 3592 NIP
5428 3626 SEAL
5618 3799 PLUG
6077 4232 SHOE
)
ConocoPhiUips,A,I:ask.a, Inc.
1D-101
SURF
CASING
(0-499,
00:10.750,
Wt:40.50)
API: 500292298600
SSSV Type' None
Gas Lift
mdrel/Oummy
Valve 1
(5345-5346,
00:4.725)
.-~,.~
-Ls·
Annular FlUid:
Reference Log:
Last Tag: 5927
Last Tag Date: ..V16/2002
Casing String - ALL
Description
CONDUCTOR
SURF CASING
PROD CASING
LINER
TübiiigStririg- TUBING;
Size I Top
3.500 0
Perforations. Summary
Interval TVD
5504 - 5544 3694 - 3731
5574.. 5594 3759 - 3777
5594 - 5614 3777.. 3796
NIP
(5389-5390.
00:3.500)
TUBING
(0-5428,
00:3.500,
10:2.992) ~
SEAL
(5428-5429,
00:4.000)
Perf
(5504-5544)
Perf
(5574-5594)
LINER
(5429-6078,
00:3.500,
Wt9.30)
~
Perf
(5622-5650)
Perf
(5668-5684)
Perf
(5750-5800)
~
)
KRU
1 D-1 01
Well Type: INJ
Ong 11/27/2000
Completion:
Last WID:
Rei Log Date:
TO: 6100 FtKB
Max Hole Angle: 68 deg @ 3833
Angle @ TS deg @
Angle@TD: 19 deg @ 6100
Rev Reason: Set WRP
Last Update: 4/9/2003
Size
16.000
10.750
5.500
3.500
Top Bottom TVD Wt Grade Thread
0 118 118 151.53 X65 WELDED
0 499 499 40.50 J-55 BTC
0 5429 3627 15.50 L-80 BTC MOD
5429 6078 4233 9.30 L-80 EUE8RD
TVD Wt Grade Thread
3626 9.30 L-80 EUE8RD
Status Ft SPF Date Type Comment
40 4 12/28/2000 IPERF 2.5" HSD, 60 deg phase
20 4 12/28/2000 IPERF 2.5" HSD, 60 deg phase
20 4 12/27/2000 IPERF 2.5" HSD, 60 deg phase
Bottom
5428
Zone
WSD
WSB
WS B,WS
A4
WSA4
WSA3
WSA2
28
16
50
4 12/27/2000 IPERF 25' HSD. 60 deg phase
4 12/27/2000 IPERF 2.5" HSD. 60 deg phase
4 12/26/2000 IPERF 2.5" HSD. 60 deg phase
V Mfr
V Type
Port TRO
Date Vlv
Run Cmnt
11/27/200C
V aD Latch
DMY
DCR-1 0.000
o
1.0
Description
Cameo 'OS' Nipple wINo-Go profile
Baker Seal Assembly
WIRELlNE RETRIEVABLE PLUG SET 4/5/03
Weatherford Float Shoe
ID
2.812
3.000
0.000
2.992
~~'"~"'"
MICROFilMED
04/01/05
DO NOT PLACE
ANY NEW MATERIAL
UNDER THIS PAGE
F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc
Permit to Drill 2001830
DATA SUBMITTAL COMPLIANCE REPORT
111612003
Well Name/No. KUPARUK RIV U WSAK 1D-101 Operator CONOCOPHILLIPS ALASKA INC
APl No. 50-029-22986-00-00
MD 6100 ~' TVD 4254 J Completion Dat 12/26/2000 Completion Statu IWINJ Current Status IWINJ
UIC Y
REQUIRED INFORMATION .
Mud Log Nc) Sample Nc)
Directional Survey Nc)
DATA INFORMATION
Types Electric or Other Logs Run:
Well Log Information:
Log/
Data Digital
Type Media
Digital
Interval
Log Log Run OH I
Name Scale Media No Start Stop CH
(data taken from Logs Portion of Master Well Data Maint
Dataset
Received Number
Directional Survey FINAL 2/22/2001
Directional Survey FINAL 2/22/2001
Comments
Dir Survey'-P;'i3er-CoP~ ..... ~
Directional Survey FINAL 2/22/2001
GYRO
Dir Survey Digital Data
R ~-"~"- Directional Survey FINAL 2/22/2001
GYRO
L -~ ~" ~- ~el;l~[~ond Log 5 5275 5967 CH 1/10/2001
GYRO Dir Survey Digital
Data
L _~L..----'-~''- ~"~Profile 5 FINAL 4910 5906 OH 7/30/2001
C .~"'~' ~ FINAL 475 6050 oh 10/10/2001
D ~[3,.-~'' ~1~-73 FINAL 475 6050 OH 10/4/2001
R j LIS Verification FI NAL OH 10/4/2001
Lo .;~13j-~lnjection Profile 5 Blu I 5350 5610 Case 8~9~2002
Lo '~i~pinner 5 Blu 1 5350 5610 Case 8/9/2002
Lo .~,p..~-. Tem peratu re 5 Blu 1 5350 5610 Case 8/9~2002
Lo Pk.-"'l:~m;Sure 5 Blu I 5350 5610 Case 8/9~2002
GYRO Dir Survey Paper
Copy
5275-5967 Color Print
............... ~2987.7810-Color Print,
Sepia
49~10-5906 BL, Sepia
10357"~475-6050 Digital Dat~
10373 t.~-6050 Digital Data
LIS Verification Paper copy
Well Cores/Samples Information:
Interval Dataset
Name Start Stop Sent Received Number Comments
ADDITIONAL INFORMATION
Permit to Drill 2001830
DATA SUBMITTAL COMPLIANCE REPORT
1116~2003
Well Name/No. KUPARUK RIV U WSAK 1D-101
Operator CONOCOPHILLIPS ALASKA INC
MD 6100 TVD 4254
Well Cored? Y -~
Chips Received .e~*~''
Analysis
R ~.r~.iv~.d ?
Completion Dat 12/26/2000
Completion Statu 1WINJ Current Status
Daily History Received? ~ N
Formation Tops (~ N
1WINJ
APl No. 50-029-22986-00-00
UIC Y
Comments:
Compliance Reviewed By:
Date:
Schlumberger
Schlumberger Technology Corporation, by and through is Geoquest Division
3940 Arctic Blvd, Suite 300
Anchorage, AK 99503-5711
ATTN: Beth
NO. 2290
Company:
Alaska Oil & Gas Cons Comm
Attn: Lisa Weepie
333 West 7th Ave, Suite 100
Anchorage, AK 99501
Field: Kuparuk
Well Job # Log Description Date BL Sepia CD Color
2A-01A J ~(~--~'7 INJECTION PROFILE 07113102
1R-lS 1<~5-1~ INJECTION PROFILE 07110102
'lD-t25A ~O O-O ~q INJECTION PROFILE 07118102
2X-01 ! ~'5~D~c~ INJECTION PROFILE 07111102
ID-114 I c~'_j~c;} INJECTION PROFILE 07114102
ID-130 i c~ 7" ! ~,_~ INJECTION PROFILE 07/18/02
ID-101 ~O/~;)-I ~'~ INJECTION PROFILE 07/14102
1 D-122 I ~ ~°/~ ~ INJECTION PROFILE 07/17102
2D-05 J ~(1/-/c~o INJECTION PROFILE 07112/02
1D-140 ~00-/.~(,, 22291 RST-SIGMA 05107/02
08/06/02
DATE:
RECEIVED
AUG 0 9 2002
Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you.
_.
AJaska Oil & Gas Cons. Commission
Anch~age
WELL LOG TRANSMITTAL
To: State of Alaska October 3,2001
Alaska Oil and Gas Conservation Comm.
Attn.: Lisa Weepie
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
RE: MWD Formation Evaluation Logs: 1D-lO1, AK-MM-00273
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, 6900 Arctic Blvd., Anchorage, AK 99518
1D-101:
Digital Log Images: 1 CD Rom
RECEIVED
OCT 1 0 2001
0il & Gas Cons. ~n'~'~ssion
WELL LOG TRANSMITTAL
To:
State of Alaska
Alaska Oil and Gas Conservation Co.
Atm.: Lisa Weepie
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
September 28, 2001
MWD Formation Evaluation Logs 1D-101, AK-MM-00273
,~oo-~,~.
1 LDWG formatted Disc with verification listing.
API#: 50-029-22986-00
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY O1~ TI~ TRANSMITTAL
LETTER TO THE ATTENTION OF:
Sperry-Sun Drilling Service
Atto: Jim Galvin
6900 Arctic Blvd.
Anchorage, Alaska 99518
Date:
RECEIVED
OCT 0 4 200!
Ala~ Oil & Gas Coils. CommieaoD
7/19/2001
Schlumberger
NO. 1303
Schlumberger Technology Corporation, by and through is Geoquest Division
3940 Arctic Bird, Suite 300
Anchorage, AK 99503-5711
ATTN: Sherrie
Company:
Alaska Oil & Gas Cons Corem
Attn: Lisa Weepie
333 West 7th Ave, Suite 100
Anchorage, AK 99501
Field: Kuparuk
Well Job # Log Description Date BL Sepia CD Color
1J-03 Z_~.~ i),,~/,~ SBHP 06/27/0t I 1
ID-101 .Z~"',/~ INJECTION PROFILE 06/21101 I 1
ID-t07 _~.~]~-]'"r~ INJECTION PROFILE 06/24/01 I 1
1D-t'28 j~,,~ .../~ ~INJECTION PROFILE 07/06/01 I 1
IR-26 _/?/, O¢~, INJECTION PROFILE 06102/01 I 1
2A-19A ~,,~--o;,~ se,P STOPS o6/17/Ol I t
2F-08 IB~-_h~ ~ PRODUCTION PROFILE 06/25/01 I 1
2G-9 J~41/';'/0~ GAS LIFT SURVEY 07/03/01 I 1
2G-09 /~'/0~ PRODUCTION PROFILE 07/t4/01 I 1
2N-326 ~_1~ ,/~ PRESS & TEMP BASELINE 07102101 I 1
2N-326 7,/o~"~; WFL/RSTIPSP 07104/01
2V-03 I~"~' [~ WFURST-A 06109101 1
3H-31 ~- 0[~ INJECTION PROFILE 0613010t t
3a-07A ~1- ~ SBHP SURVEY
3M-01 ~'OlZ INJECTION PROFILE 06129101 I 1
=o-o= ~-o~ ~N~;CT~O, P.O~ 0~4/0~
30-10 /~- ~9 INJECTION PROFILE 07105101 1
3o-~9 Iq~- ~ RST BO~=LDL 06~04/0~
~-~ _~'""'"~" DATE:
RECEIVED
JUL 30 2001
Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 56t-83t7. Thank you.
PHILLIPS Alaska, Inc.
A Subsidiary of PHILLIPS PETROLEUM COMPANY
Post Office Box 100360
Anchorage, Alaska 99510-0360
J. Trantham
Phone (907) 265-6434
Fax: (907) 265-6224
January 15, 2001
Mr. Daniel T. Seamount, Jr.
Commissioner
State of Alaska
Alaska Oil & Gas Conservation Commission
333 West 7th Avenue Suite 100
Anchorage, Alaska 99501
Subject: Completion Report for 1D-101 and 1D-107 (200-183 & 200-177)
Dear Mr. Commissioner:
Phillips Alaska, Inc. submits the attached Completion Reports for the drilling.operations on West
Sak wells 1D-101 and 1D-107.
If you have any questions regarding, this matter, please contact me at 265-6434 or Steve McKeever
.at 265-6826.
S~ncerely,
J. Trantham
Drilling Engineering SuperviSor
PAI Drilling
JT/skad
RECEIVED
J,~N 1 6
Alaska Oil &A~' Cernrnission
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
1. Status of well Classification of Service Well
Oil ~1 Gas r'l suspended r-I Abandoned r"J Service [] ..... Injector-Water
2. Name of Operator ~'~~ '7. Permit Number
Phillips Alaska, Inc.
... ."~'A,~ 200-183 /
3. Address ~ 8. APl Number
P. O. Box 100360, Anchorage, AK 99510-0360,~,~ 50-029-22986-00
'4. Location of well at surface .......... 9. Unit or Lease Name
·
194' FSL, 595' FEL, Sec. 14, T11 N, R10E, UM (ASP:560490,5959859) Kuparuk River Unit
At Top Producing Interval
10.
Well
Number
1748' FNL, 1329' FEL, Sec. 14, T11N, R10E, UM (ASP 559726, 5963192)
1D-101
At Total Depth
11.
Field
and
Pool
1546' FNL, 1373' FEL, Sec. 14, T11 N, R10E, UM (ASP: 559680, 5963394) -"~'~"
~ ........ ., Kuparuk River Field
5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. West Sak Oil Pool
RKB 101' feetI ADL 25650 ALK 468
12. Date Spudded 13. Date T.D. Reached 14. Date.~omp., S.u~p,~. r Aband. 115. Water Depth, if offshore 16. No. of Completions
November 19, 2000 November 24, 2000 ?' I N/A ,o. Ms. 1
17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Suwey 120. Depth where SSSV set 21. Thickness of Permafrost
6100' MD / 4254' TVD 5983' MD / 4143' TVD YES r~] No DI N/A feet MD 1722'
22. Type Electric or Other Logs Run
GR/Res,' CBL
23. CASING, LINER AND CEMENTING RECORD
SE'I-rING DEPTH MD
CASING SIZE WT. PER FT. GRADE TOP Bo'rroM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED
16' 151.5# X-65 Surface 145' 24" 70 sx AS #1
10.75" 40.5# J-55 Surface 499' 12.25" 1 lO sx LiteCrete
5.5' X 15.5# L-80 Surface 5429' 7.875' 460 sx ASlII Lite & 340 sx Class G
3.5' 9.3# L-80 5429' 6079' 7.875' included above
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" 5442' N/A
5750'-5800' MD 3923'-3970' TVD 4 spf
5692'-5728' MD 3868'-3902' TVD 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
5668'-5684' MD 3846'-3861' TVD 4 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED
5622'-5650' MD 3803'-3829' TVD 4 spf N/A
5594'-5614' MD 3777'-3796' TVD 4 spf
5504'-5544' MD 3694'-3731' TVD 4 psf
5574'-5594' MD 3759'-3777' TVD 4 spf
27. PRODUCTION TEST
Date First Production Method of Operation (Flowing, gas lift, etc.)
Injector
Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO
I
Test Pedod >
Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr)
press, xx psi 24-Hour Rate >
28. CORE DATA
Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips.
N/A
Form 10-407 Rev. 7-1-80
CONTINUED ON REVERSE SIDE
Submit In ~luplicate
· GEOLOGIC MARKERS FORMATION TESTS
NAME Include interval tested, pressure data, all fluids recovereci and gravity.
MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase.
Top West Sak D 5499' 3690'
Base West Sak D 5544' 3731'
West Sak Base 5974' 4135'
Annulus left open - freeze protected with diesel.
31. LIST OF ATTACHMENTS
Summary of Daily Operations, Directional Survey
32. I hereby certify that the following Is true and correct to the best of my knowledge. Questions? Call Steve McKeever 265-6826
darn** Tren#~m
Prepared by Sharon AIIsup. Drai~e
INSTRUCTIONS
General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and
leases in Alaska.
Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water
supply for injection, observation, injection for in-situ combustion.
Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other
spaces on this form and in any attachments.
Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in
item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each
additional interval to be separately produced, showing the data pertinent to such interval.
Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.).
Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location
of the cementing tool.
Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection,
Shut-in, Other-explain.
RECEIVED
Item 28.' If no cores taken, indicate "none".
Form 10-407
JAN ]. 6 2001
Alaska Oil & Gas Cons. Commission
Anchorage
Date: 01/08/01
ARCO ALASKA INC.
WELL SUMMARY REPORT
Page: 1
WELL:iD-101
STATE:ALASKA
COUNTY: NORTH SLOPE EAST
FIELD: WEST SAK
SPUD:il/19/00 START COMP:
RIG:NORDIC 3
BLOCK:
FINAL:
WI: 0% SECURITY:0
API NUMBER: 50-029-22986-00
11/18/00 (D1)
TD/TVD: 0/0
SUPV:
MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0
0) HOVE RIG OFF ].O-1.07 P/U MATF; AND MOVE T¢} 1!~--1.01
Move rig off 1D-107.
11/19/00 (D2) MW: 8.8 VISC: 273 PV/YP: 45/82 APIWL: 5.4
TD/TVD: 455/455 (455) ON DIVERTER. DRLG 12 1/4" HOLE TO 520' SHORT TRIP & PO
SUPV:DONALD L. WESTER
Prepare 1D-101 for rig. Move rig spot over 1D-101. Accept
rig for operations 0300 hrs. 11/19/00. N/U diverter and
function test. Safety meeting prespud. Spud drill 145' to
455'
11/20/00 (D3) MW: 8.9 VISC: 118 PV/YP: 39/41 APIWL: 5.8
TD/TVD: 520/520 ( 65) DRILLING 7 7/8" HOLE @ 810'
SUPV:DONALD L. WESTER
Continue drilling 12.25" hole from 455' to 520' Circulate
and short trip into conductor @ 147' CBU. POOH to run
10.75" casing. Run 10.75" casing to 500'. Pump cement. Bump
plug. RIH tag ~ 492'. No firm cement. Drill out 10.75"
plugs and shoe @ 500'. Clean out to 520' with water. POOH.
11/21/00 (D4) MW: 9.4 VISC: 124 PV/YP: 34/43 APIWL: 5.8
TD/TVD: 1851/1742 (1331) DRLG. @ 2337'
SUPV:M.C. HEIM
RIH w/flex collars & shallow test MWD, RIH 3 stands hwdp,
RIH & tag, start drilling. Drilling from 520' to 1801'. MWD
failure. POH. Check bit. RIH, test MWD, finish RIH.
Drilling from 1801' to 1851'
11/22/00 (D5) MW: 9.4 VISC: 81 PV/YP: 30/29 APIWL: 4.8
TD/TVD: 3900/2680 (2049) POH FOR NEW BIT.
SUPV:M.C. HEIM
Drilling and surveys from 1851' to 3900', pump hi vis sweep
~ 3600'
Date: 01/08/01
ARCO ALASKA INC.
WELL SUMMARY REPORT
Page: 2
11/23/00 (D6) ~'~: 9.4 VISC: 82 PV/YP: 31/29
TD/TVD: 4932/3215 (1032) DRLG. & SURVEYS @ 5300'
SUPV:M.C. HEIM
APIWL: 3.8
Drilling from 3900' to 3984', survey and CBU. POH, hole
swabbing, pump out from 2800' to 1755' Download MWD,
change bit. RIH. Wash & ream 80' to bottom. Drilling and
surveys from 3984' to 4068' Rotate and reciprocate while
making mud swap, circ new mud in hole. Drilling and surveys
from 406R' to 4932'
11/24/00 (D7)
TD/TVD: 6100/425~
SUPV:M.C. HEIM
MW: 0.0 VISC: 82 PV/YP: 0/ 0
(1].68) MAKE UP
APIWL: 0.0
Drilling and surveys to TD @ 6100'. CBU, pump sweep. POH to
5300', hole swabbing, pump out to 4900', POH.
11/25/00 (D8)
TD/TVD: 6100/4254 (
SUPV:M.C. HEIM
MW: 9.4 VISC: 60 PV/YP: 26/25
0) RUNNING 5.5" X 3.5" CSG.
APIWL: 4.2
Continue pump out of hole from 4990' to 4480'. POH to 4000'
& pump dry job. POH. PJSM. Run in hole to 4330' Wash &
ream hole w/7-7/8" hole opener from 4330' to 6100', hole
in good condition. Circ & condition mud for running casing.
Pump sweep. POH. Rig up to run 5.5" x 3.5" casing string.
11/26/00 (D9) MW: 9.4 VISC: 49 PV/YP: 22/16 APIWL: 3.8
TD/TVD: 6100/4254 ( 0) RUNNING 3.5" COMPLETION.
SUPV:M.C. HEIM
PJSM. Run 3.5" casing. Run 5.5" casing. C].rc condition mud
for cementing PJSM. Pump cement. Bump plug, check flowers,
OK. N/D diverter, N/U tbg head spool and test packof£ to
1000%. NU BOPE and test.
11/27/00 (D10) MW: 0.0 VISC: 49 PV/YP: 0/ 0 APIWL: 0.0
TD/TVD: 6100/4254 ( 0) MOVING RIG F/ iD PAD TO iA PAD. (NOTE) RIG OFF ROAD
SUPV:M.C. HEIM
Test BOPE 250/30009. Rig up to run completion. PJSM. Run
3.5" completion. Freeze protect well. Nipple up tree, test
& packoff to 5000~. Test tree to 250/5000~. secure well.
Move rig off well. Rig released ~ 2400 hrs. 11/27/00.
Naska 0il & Gas Cons. commission
Anchorage
PHILLIPS Alaska, Inc('
KUPARUK RIVER UNIT
ELL SERVICE REPORT
1D-101(4-1))
WELL JOB SCOPE
1 D-101 DRILLING SUPPORT-CAPITAL
DATE
12/26/0O
DAY
1
JOB NUMBER
1221000908.1
DAILY WORK
PERFORATING
OPERATION COMPLETE I SUCCESSFUL I KEY PERSON
O Yes ~ No ~ Yes O No SWS-STEPHENSON
Initial Tbg IFinaITbg I Initial IA Final IA Initial '
0 PSII 0 PSII 0 PSI 0 PSI 0 PSI 0 PSII 3.500
UNIT NUMBER
SWS - 2145
SUPERVISOR
FERGUSON
2.812 " 5388 FT
DALLY SUMMARY
PERFORATED FROM 5750'- 5800' (3 RUNS) & 5692' - 5728' (2 RUNS) USING 2.5" HSD @ 4 SPF & 60 DEG
PHASING WITH 31 J UJ CHARGES [EHD = 0.29" & TTP = 17.32"] - 2.25 HOURS LOST TIME DUE TO MISFIRE
TIME LOG ENTRY
08:00 DEPART FOR KIC
08:20 DEPART FOR 1 D-101
08:40 ARRIVE ON LOCATION - SPOT EQUIPMENT
09:10 HOLD SAFETY MEETING
09:15 START RIG UP
10:20 PT TO 300#
10:25 PT TO 3000#
10:35 RIH WITH 20' 2.5" HSD & ROLLERS
11':20 LOG ,TIE IN PASS FROM 5900' TO 5350'
11:40 FLAG CABLE - LOG INTO SHOOTING POSITION & PERFORATE FROM 5780' - 5800'
11:50 POOH
1,2:30 RIG DOWN GUN 1 - MISFIRE
'13:30' RI,H WITHGUN 1"
14:05 CATCH FLAG - LOG INTO SHOOTING POSITION & PERFORATE FROM 5780' - 5800'
14:10 POSITIVE INDICATION- POOH
14:50. RIG DOWN GUN 1
15:05' RIG UP GUN 2
15:15 RIH WITH 20' 2.5" HSD
15:45 CATCH FLAG - LOG INTO SHOOTING POSITION & PERFORATE FROM 5760'- 5780'
15:50 POSITIVE INDICATION- POOH
16:15 RIG DOWN GUN 2
16:25' RIG UP GUN 3
16:35 RIH WITH 10' 2.5" HSD
17:15 CATCH FLAG - LOG INTO SHOOTING POSITION & PERFORATE FROM 5750' - 5760'
17:20 . POSITIVE INDICATION - POOH
17:50 RIG DOWN GUN 3
18:00 RIG UP GUN 4
18:10 RIH WITH 20' 2.5" HSD
18:45 CATCH FLAG - LOG INTO SHOOTING POSITION & PERFORATE FROM 5708' - 5728'
18:50 POSITIVE INDICATION - POOH
19:10 RIG DOWN GUN 4
19:20 RIG UP GUN 5
TIME LOG ENTRY '
19:30
20:15
20:20
21:00
~P'30
RIH WITH 16' 2.5" HSD GUN
CATCH FLAG- LOG INTO SHOOTING POSITION & PERFORATE FROM 5692' - 5708'
POSITIVE INDICATION- POOH
RIG DOWN
COMPLETE RIG DOWN
PHILLIPS Alaska, Inc('
WELL JOB SCOPe: JOB NUMBER
1 D-101 DRILLING SUPPORT-CAPITAL 1221000908.1
DATE
12/27/00
DAY
1
KUPARUK RIVER UNIT
ELL SERVICE REPORT
1D-101(4-1))
DAILY WORK
PERFORATING
OPERATION COMPLETE I SUCCESSFUL I KEY PERSON
~ Yes O No I (~'j Yes ('~., No ! SWS-STEPHENSON
iiJ,L~,.~, , J,,,.:::~ ' "~"'"' ~ ""'~1 i,.i.~,,,~, ,,., ~ .,,,..~, ,,~- ' ,,,~,,~.~ ,~.~, ~ ~ .,,,.4., ,~,,.., ~, ~ , L.. ,,.~.,,..
UNIT NUMBER
SWS-2128
SUPERVISOR
FERGUSON
DALLY SUMMARY
PERFORATED 5668' - 5684', 5622' - 5650' (2 RUNS) & 5594' - 5614' USING 2.5" HSD PERF GUNS @ 4 SPF AND
60 DEG PHASING WITH 31 J UJ CHARGES [EHD = 0.29" & TTP = 17.32"] TAGGED OBSTRUCTION @ 2330' - CAUSING
POSTPONEMENT OF FINAL THREE RUNS. RU PUMPS AND PUMP 200 BBLS DIESEL TO CLEANUP PRIOR TO NEXT RU WITH
E/L
. ,
TIME LOG ENTRy
07:00 DEPART KCC FOR 1D-101
07:1:5
07:25
08:30
ARRIVE ON LOCATION - HOLD SAFETY MEETING
!
START RIG UP
PT TO 300# '
08:35 PT TO 3000~
08:45 RIH WITH 16'. 2.5' HSD WITH ROLLERS (GUN #6 - GUNS 1 TO 5 SHOT ON DEC 26/2000)
09:40 LOG TIE IN PASS FROM 5775~ TO 5350'
09:55 FLAG LINE - LOG INTO SHOOTING POSITION & PERFORATE FROM 5668' - 5684'
10:00 POSITIVE INDICATION' - POOH
10:30. RIG DOWN GUN 6'
10:50'
10:55
RIG UP GUN 7 ;
RIH WITH 20' 2.5" HSD
1'1:45. CATCH FLAG.- LOG INTO SHOOTING. POSITION & PERFORATE FROM 5630' -5650' :
11:50. POSITIVE INDICATION - POOH
12:20 RIG 'DOWN GUN 7
12':30 RIG UP GUN 8
12:40 RIH WITH 8' 2.5' HSD
1'3:20
CATCH FLAG - LOG INTO SHOOTING POSITION & PERFORATE FROM 5622' - 5630'
13:25 POSITIVE INDICATION - POOH
13:50' RIG DOWN. GUN 8
14:05. RIG UP GUN 9
14:15 RIH. WITH 20' 2;5" HSD.
14:30 SIT DOWN O 2350'
14:35 ' GET THROUGH - CONT RIH
15;00 CATCH ,FLAG - LOG INTO SHOOTING POSITION & PERFORATE FROM 5594' - 5614'
15:40 RIG DOWN GUN 9
15:55 RIG. UP GUN 10
16:05 RIH WITH 20' 2.5" HSD
16:20
16:30
SIT DOWN O 2330~'
TAGGED OBSTRUCTION 4 TIMES @ SAME SPOT - CLEAN PICK UPS
16:35. TAGGED OBSTRUCTION 3 MORE TIMES
TIME
16:40
17:00
18:00
18:30
LOG ENTRY
POOH
START RIG DOWN
COMPLETE RIG DOWN - LEAVE LOCATION
RETURN TO CAMP
PHILLIPS Alaska, Inc.('
"WELL JOB SCOP'E
1 D-101 DRILLING SUPPORT-CAPITAL
DATE DAILY WORK
12/28/00 PERFORATING
DAY
KUPARUK RIVER UNIT
ELL SERVICE REPORT
1D-101(4-1))
OPERATION COMPLETE I SUCCESSFUL I KEY PERSON
~ Yes (~., No I ,~, Yes ("~., No ! SWS-STEPHENSON
~nma~ ~Dg i r~n~., ~Dg I~n~t,a~ IA I hnal IA- Im~t,a~ UA Ihna~ UA I I IL ~ze
oPSII oPS~I oPS~I oPSII oPsII oPSll 3.500"
JOB NUMBER
1221000908.1
UNIT NUMBER
SWS - 2145
SUPERVISOR
FERGUSON
Min IL) I L)epm
2.812 "I 5388 FT
DAILY SUMMARY
IPERFORATED 5504' - 5544' (2 RUNS) & 5574' - 5594' USING 2.5" HSD GUNS @ 4 SPF & 60 DEG PHASING WITH 31
J UJ CHARGES [EHD = 0.32" & TTP = 17.32"]
TIME LOG ENTRY
07:00 DEPART PRUDHOE SHOP FOR 1D-101
08:30 ARRIVE ON LOCATION - SPOT VEHICLES & EQUIPMENT
08:50 HOLD SAFETY MEETING
09:00 START RIG UP
10:10 PT FAILED - CUT O-RING
1.0:35 PT TO 300#
10:40 PT TO 3000#
10:50 RIH WITH 20' 2.5" HSD WITH ROLLERS
11:05 ' VERY SLOW GOING FROM 2200' TO 2500' BUT DID NOT SIT DOWN
11:30 LOG TIE IN PASS FROM 5575' TO 5350'
11:45 FLAG LINE - LOG INTO SHOOTING POSITION & PERFORATE FROM 5574'- 5594'
11:50 POSITIVE INDICATION - POOH
12:20' RIG DOWN GUN 1'
12:35 RIG UP GUN 2
12:45 RIH WITH 20' 2.5" HSD WITH ROLLERS
13~15 CATCH FLAG - LOG INTO SHOOTING POSITION & PERFORATE FROM 5524' - 5544'
13:20 POSITIVE INDICATION - POOH
14:00 RIG DOWN GUN 2
14:15 RIG UP GUN 3
14:20 RIH WITH 20' 2.5" HSD WITH ROLLERS
14:55 CATCH FLAG - LOG.INTO SHOOTING POSITION & PERFORATE FROM 5504'- 5524'
15:05 POSITIVE INDICATION - POOH ,
15:45 START RIG DOWN
17:00 COMPLETE RIG DOWN - LEAVE LOCATION
17:30 RETURN TO KIC
Schlumberger
NO. 831
Schlumberger Technology Corporation, by and through is Geoquest Division
3940 Arctic Blvd, Suite 300
Anchorage, AK 99503-5711
ATTN: Sherrie
Company:
Alaska Oil & Gas Cons Comm
Attn: Lori Taylor
3001 Porcupine Drive
Anchorage, AK 99501
Field: Kuparuk
Color
Well Job # Log Description Date BL Sepia Print
1 D-101 20514 SCMT 001209 1
3B-02 INJECTION PROFILE 001219 I I
185-o6
12/28/00
SIGNE~
DATE:
Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you.
15-Dec-00
AOGCC
3001 Porcupine Drive
Anchorage, AK 99501
Re: Distribution of Survey Data for Well 1D-101 GYRO
Dear Dear Sir/Madam:
Enclosed are two survey hard copies and 1 disk
Tie-on Survey:
Window / Kickoff Survey:
Projected Survey:
0.00' MD
'MD
0.00' MD
(if applicable
Please call me at 273-3545 if you have any questions or concerns.
Regards,
William T. Allen
Survey Manager
Attachment(s)
Kuparuk River Unit
Phillips Alaska
Kuparuk 1D, Slot ID-~01
1D-~01 GYRO
Surveyed: 26 November, 2000
SURVEY REPORT
15 December, 2000
Your Ref: APl 500292298600
Surface Coordinates: 5959859.23 N, 560490.42 E (70° f8' 03.2293" N, 149° 30' 36.2536" I/V)
Kelly Bushing: fOO. 94ft above Mean Sea Level
DRILLING SERVICES
Survey Ref: svy9339
A Halliburton Company
Sperry-Sun Drilling Services
Survey Report for ID-101 GYRO
Your Ref: AP1500292298600
Surveyed: 26 November, 2000
Kuparuk River Unit
Measured Sub-Sea Vertical Local Coordinates
Depth Incl. Azim. Depth Depth Northings Eastings
(ft) (ft) (ft) (ft) (ft)
0.00 0,000 0.000 -100.94 0.00 0.00 N 0.00 E
136.00 0,800 112.000 35.06 136.00 0.36 S 0.88 E
256.00 1,400 113.000 155.03 255.97 1.24 S 3.01 E
349.00 1.600 58.000 248.01 348.95 1.00 S 5.15 E
410.00 1.750 38.000 308.98 409.92 0.19 N 6.45 E
444.00 1.700 17.000 342.96 443.90 1.08 N 6.92 E
503.00 2.000 334.000 401.94 502.88 2.84 N 6.72 E
Global Coordinates
Northings Eastings
(ft) (ft)
5959859.23 N 560490.42 E
5959858.88 N 560491.30 E
5959858.01 N 560493.44 E
5959858.27.N 560495.58 E
5959859.47 N 560496.87 E
5959860.36 N 560497.33 E
5959862.12 N 560497.12 E
All data is in feet unless otherwise stated. Directions and coordinates are relative to True North.
Vertical depths are relative to Well. Northings and Eastings are relative to Well.
Magnetic Declination at Surface is 26.373° (18-Nov-00)
The Dogleg Severity is in Degrees per 100 feet.
Vertical Section is from Well and calculated along an Azimuth of 347,550° (True).
=Jased upon Minimum Curvature type calculations, at a Measured Depth of 503.00ft.,
'-~.-rhe Bottom Hole Displacement is 7.30ft., in the Direction of 67.086° (True).
Dogleg
Rate
(°/'lOOft)
0.59
0.50
1.50
0.98
1.85
2.35
Vertical
Section
0.00
-0.54
-1.86
-2.09
-1.21
-0.44
1.33
Phillips Alaska
Kuparuk 1D
Comment
AK-2 BP_CG
Continued...
15 December, 2000 - 9:09 - 2 - DriliQuest 2.00.05
Sperry-Sun Drilling SerVices
Survey Report for fD-f0f GYRO
Your Ref: AP1 500292298600
Surveyed: 26 November, 2000
Kuparuk River Unit
Phillips Alaska
Kuparuk 1D
Survey tool program for fD-lOf GYRO
From To
Measured Vertical Measured
Depth Depth Depth
(ft) (ft) (ft)
Vertical
Depth
(ft)
0.00 0.00 503.00 502.88
Survey Tool Description
AK-2 BP_CG
15 December, 2000 - 9:09 .3 - DriflQuest 2.00.05
15-Dec-00
AOGCC
3001 Porcupine Drive
Anchorage, AK 99501
Re: Distribution of Survey Data for Well 1D-101
Dear Dear Sir/Madam:
Enclosed are two survey hard copies and 1 disk
Tie-on Survey:
Window / Kickoff Survey:
Projected Survey:
503.00' MD
'MD
6,100.00' MD
(if applicable
Please call me at 273-3545 if you have any questions or concerns.
Regards,
William T. Allen
Survey Manager
Attachment(s)
Kuparuk River Unit
Phillips Alaska
Kuparuk 1D, Slot ID-lO1
ID-101
Surveyed: 26 November, 2000
SURVEY REPORT
15 December, 2000
Your Ref: APl 500292298600
Surface Coordinates: 5959859.23 N, 560490.42 E (70° f8' 03.2293" N,
Kelly Bushing: 100.94ft above Mean Sea Level
149° 30' 36.2536" W)
;l~,=,r-,r',~-sur-t.
nRII--LINI; SERVICES
Survey Ref: svy9346
A Halliburton Company
Sperry-Sun Drilling Services
Survey Report for fD-f0f
Your Ref: AP1500292298600
Surveyed: 26 November, 2000
Kuparuk River Unit
Measured
Depth
(ft)
Incl.
Azim.
503.00 2.000 334.000
567.04 4.280 286.650
660.71 7.400 274.620
753.93 7.000 279.800
845.98 7.980 291.000
Sub-Sea
Depth
(ft)
401.94
465.89
559.06
651.55
742.82
Vertical
Depth
(ft)
502.88
566.83
660.00
752.49
843.76
939.20 13.270 315.610 834.45 935.39
1031.61 15.140 328.470 924.05 1024.99
1124.19 20.950 326.500 1012.04 1112.98
1217.13 22.180 333.100 1098.49 1199.43
1314.41 24.000 341.710 1188.00 1288.94
1410.49 25.700 342.820 1275.18
1507.62 28.970 343.530 1361.45
1604.94 32.680 346.600 1445.01
1700.87 36.210 345.860 1524.11
1795.00 36.700 346.480 1599.82
1376.12
1462.39
1545.95
1625.05
1700.76
1891.53 42.270 339.850 1674.33 1775.27
1989.36 51.580 338.710 1741.07 1842.01
2087.11 54.560 344.370 1799.82 1900.76
2184.08 59.710 345.460 1852.43 1953.37
2281.70 64.510 348.340 1898.09 1999.03
2378.75 64.670 349.520 1939.73 2040.67
2475.13 65.190 349.600 1980.57 2081.51
2572.23 65.410 349.190 2021.15 2122.09
2669.84 65.860 351.080 2061.42 2162.36
2766.94 65.470 350.260 2101.43 2202.37
Local Coordinates
Northings Eastings
(ft) (ft)
2.84 N 6.72 E
4.53 N 3.94 E
6.02 N 5.42 W
7.47 N 17.00 W
10.71 N 28.50 W
20.69 N 42.04W
38.56 N 55.77W
62.69 N 71.24W
92.19 N 88.36W
127.37 N 102.88W
165.83 N 115.16W
208.52 N 128.06W
256.70 N 140.83W
309.38 N 153.76W
363.69 N 167.13W
422.29 N 185.08W
489.03 N 210.38W
563.11N 235.03W
641.73 N 256.20W
725.74N 275.70W
811.77 N 292.53W
897.63 N 308.35W
984.34 N 324.59W
1071.93 N 339.82W
1159.23 N 354.16W
Global Coordinates Dogleg
Northings Eastings Rate
(ft) (ft) (°/100ft)
5959862.12 N 560497.12 E
5959863.79 N 560494.32 E
5959865.20 N 560484.95 E
5959866.56 N 560473.36 E
5959869.71 N 560461.84 E
5959879.58 N 560448.22 E
5959897.34 N 560434.34 E
5959921.34 N 560418.67 E
5959950.71N. 560401.32 E
5959985.76 N 560386.52 E
5960024.12 N 560373.92 E
5960066.71 N 560360.69 E
5960114.78 N 560347.52 E
5960167.37 N 560334.17 E
5960221.57 N 560320.37 E
5960280.01 N 560301.95 E
5960346.55 N 560276.11 E
5960420.43 N 560250.86 E
5960498.88 N 560229.06 E
5960582.73 N 560208.88 E
5960668.62 N 560191.36 E
5960754.34 N 560174.85 E
5960840.92 N 560157.92 E
5960928.39 N 560141.98 E
5961015.57 N 560126.94 E
5.11
3.56
0.82
1.91
7.36
3.96
6.31
2.92
3.94
1.83
3.38
4.14
3.71
0.65
7.23
9.55
- 5.54
5.39
5.56
1.11
0.54
0.45
1.82
0.87
Vertical
Section
1.33
3.57
7.05
10.96
16.61
29.27
49.68
76.57
109.07
146.55
186.75
231.22
281.02
335.26
391.17
452.26
522.89
600.54
681.88
768.11
855.75
942.99
1031.16
1119.99
1208.33
Phillips Alaska
Kuparuk 1D
Comment
TIE ON POINT
MWD Magnetic
Continued...
15 December, 2000 - 9:09 - 2 - DriliQuest ZOO.05
Sperry-Sun Drilling Services
Survey Report for fD-f0f
Your Ref: AP1500292298600
Surveyed: 26 November, 2000
Kuparuk River Unit
Measured
Depth
(ft)
Incl.
Sub-Sea Vertical Local Coordinates
Depth Depth Northings Eastings
(ft) (ft) (ft) (ft)
2864.33 64.890 351.140 2142.31 2243.25
2962.16 65.380 350.670 2183.45 2284.39
3057.61 63.820 352.640 2224.39 2325.33
3154.44 62,160 354.430 2268,37 2369.31
3252.96 63.710 353.200 2313.19 2414.13
3349.77 63.900 350.860 2355.93 2456.87
3446.62 65.600 348.990 2397.25 2498.19
3542.71 67.880 348.250 2435.19 2536.13
3638.84 67.620 348.190 2471.59 2572.53
3735.01 67.350 348.970 2508.42 2609.36
3832.89 68.430 349.600 2545.26 2646.20
3928.91 65.900 349.980 2582.52 2683.46
4027.30 65.810 348.700 2622.77 2723.71
4123.54 65.370 349.110 2662.54 2763.48
4218.97 62.560 349.020 2704.42 2805.36
4316.23 61.890 349.990 2749.75 2850.69
4412.91 58.850 350.560 2797.54 2898.48
4510.23 55.160 351.290 2850.53 2951.47
4607.32 51.980 349.930 2908.18 3009.12
4704.77 48.390 350.770 2970.57 3071.51
4801.48 47.720 351.610 3035.21 3136.15
4899.13 44.470 349.630 3102.92 3203.86
4997.01 41.320 349.380 3174.62 3275.56
5093.85 39.400 348.540 3248.41 3349.35
5190.46 36.220 346.510 3324.73 3425.67
Global Coordinates Dogleg
Northings Eastings Rate
(ft) (ft) (o/.~ooft)
1246.46 N 368.45W 5961102.69 N 560111.95 E
1334.11N 382.48W 5961190.22 N 560097.22 E
1419.41 N 395.00W 5961275.41 N 560084.01 E
1505.12 N 404.72W 5961361.04 N 560073.59 E
1592.33 N 414.18VV 5961448.18 N 560063.43 E
1678.35 N 426.22W 5961534.10 N 560050.70 E
1764.59 N 441.56W 5961620.21 N 560034.67 E
1851.13 N 458.98W 5961706.60 N 560016.55 E
1938.23 N 477.14W 5961793.55 N 559997.69 E
2025.31 N 494.73W 5961880.49 N 559979.40 E
2114.40 N 511.59W 5961969.45 N 559961.82 E
2201.49 N 527.28W 5962056.40 N 559945.43 E
2289.72 N 543.89W 596214L50 N 559928.12 E
2375.72 N 560.75W 5962230.36 N 559910.56 E
2459.90 N 577.01W 5962314.41 N 559893.62 E
2544.51N 592.69W 5962398.89 N 559877.26 E
2627.33 N 606.89W 5962481.59 N 559862.40 E
.2707.92 N 619.77W 5962562.07 N 559848.87 E
2784.98 N 632.50W 5962639.03 N 559835.52 E
2858.76 N 645.06W 5962712.70 N 559822.37 E
2929.84 N 656.08W 5962783.69 N 559810.78 E
2999.24 N 667.51W 5962853.00 N 559798.79 E
3064.74 N 679.64W 5962918.40 N 559786.13 E
3126.29 N 691.64W 5962979.85 N 559773.64 E
3184.11N 704.39W 5963037.57 N 559760.42 E
1.01
0.66
2.48
2.38
1.93
2,18
2.48
2.48
0.28
0.80
1.25
2.66
1.19
0.60
2.95
1.12
3.19
3.84
3.46
3.74
0.95
3.63
3.22
2.06
3.53
Vertical
Section
1296.58
1385.19
1471.19
1556.98
1644.18
1730.78
1818.29
1906.55
1995.51
2084.34
2174.98
2263.40
2353.13
2440.74
2526.45
2612.45
2696.39
2777.85
2855.85
2930.60
3002.38
3072.62
3139.19
3201.88
3261.09
Phillips Alaska
Kuparuk 1D
Comment
Continued...
DrillQuest 2.00.05
15 December, 2000 - 9:09 - 3 -
Sperry-Sun Drilling Services
Survey Report for 1D-101
Your Ref: AP1500292298600
Surveyed: 26 November, 2000
Kuparuk River Unit
Measured Sub-Sea Vertical Local Coordinates
Depth Incl. Azim. Depth Depth Northings Eastings
(ft) (ft) (ft) (ft) (ft)
5287.03 33.490 346.060 3403.96 3504.90 3237.73 N 717.47W
5385.07 29.910 348.750 3487.37 3588.31 3287.97 N 728.76W
5481.85 24.930 351.630 3573.25 3674.19 3331.84 N 736.44W
5578.74 22.580 351.370 3661.93 3762.87 3370.44 N 742.20W
5674.80 20.220 347.070 3751.36 3852.30 3404,86 N 748.69W
5771.81 19.490 345.890 3842.61 3943.55 3436.90 N 756.38W
5868.08 19.010 345.480 3933.49 4034.43 3467.65 N 764.23W
5964.95 18.940 347.260 4025.10 4126.04 3498,26 N 771.65W
6037.58 19.060 346.550 4093.77 4194.71 3521,29 N 777.01W
6100.00 19.060 346.550 4152.77 4253.71 3541.12 N 781.75W
Global Coordinates
Northings Eastings
(ft) (ft) '
5963091.07 N 559746.91 E
5963141.23 N 559735.22 E
5963185.04 N 559727.18 E
5963223.59 N 559721.11 E
5963257.96 N 559714.35 E
5963289.93 N 559706.39 E
5963320.62 N 559698,30 E
5963351.16 N 559690.63 E
5963374.15 N _ 559685.09 E
5963393.94 N 559680.19 E
All data is in feet unless otherwise stated. Directions and coordinates are relative to True North.
Vertical depths are relative to Well. Northings and Eastings are relative to Well.
Magnetic Declination at Surface is 26.373° (18-Nov-00)
The Dogleg Severity is in Degrees per 100 feet.
._ Jertical Section is from Well and calculated along an Azimuth of 347.550° (True).
Based upon Minimum Curvature type calculations, at a Measured Depth of 6100.00ft.,
The Bottom Hole Displacement is 3626.38ft., in the Direction of 347.551 ° (True).
Dogleg
Rate
(°/100ft)
2.84
3.93
5.32
2.43
2.95
0.86
0.52
0.60
0.36
0.00
Vertical
Section
3316.27
3367.76
3412.26
3451.20
3486.2O
3519.15
3550.87
3582.36
3606.00
3626.38
Phillips Alaska
Kuparuk 1D
Comment
PROJECTED SURVEY
Continued...
f5 December, 2000 - 9:09 - 4 - DrillQuest 2.00,05
Sperry-Sun Drilling Services
Survey Report for fD-f0f
Your Ref: AP1500292298600
Surveyed: 26 November, 2000
Kuparuk River Unit
Phillips Alaska
Kuparuk 1D
Comments
Measured
Depth
(ft)
Station Coordinates
TVD Northings Eastings
(ft) (ft) (ft)
503.00 502.88 2.84 N 6.72 E
6100.00 4253.71 3541.12 N 781.75 W
Comment
TIE ON POINT
PROJECTED SURVEY
Survey tool program for lD-f01
From To
Measured Vertical Measured
Depth Depth Depth
(ft) (ft) (ft)
Vertical
Depth
(ft)
0.00 0.00 503.00 502.88
503.00 502.88 6100.00 4253.71
Survey Tool Description
AK-2 BP_CG
MWD Magnetic
__.
15 December, 2000 - 9:09 - $ - DrillQuest 2.00.05
ALASKA OIL AND GAS
CONSERVATION CO~LSllSSION
TONY KNOWLES, GOVERNOR
3001 PORCUPINE DRIVE
ANCHORAGE, AI. ASKA 99501-3192
PHONE: (907) 279-1433
FAX: (907) 276-7542
James Trantham
Drilling Engineering Supervisor
Phillips Alaska, Inc.
P O Box 100360
Anchorage, AK 99510-0360
Kuparuk River Unit 1 D- 101
Phillips Alaska, Inc.
Permit No: 200-183
Sur. Loc. 194'FSL, 595'FEL, Sec. 14, T11N, R10E, UM
Btmhole Loc. 1548'FNL, 1358'FEL, Sec. 14, T1 IN, R10E, UM
Dear Mr. Trantham:
Enclosed is the approved application for permit to drill the above referenced well. ~nular disposal has
not been requested as part of the Permit to Drill application for Kuparuk River Unit Well No. 1D-101
Please note that any disposal of fluids generated from this drilling operation which are pumped down the
surface/production casing annulus of a well approved for annular disposal on Drill Site ID must comply
with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not
authorize disposal of drilling waste in a volume greater than 35,000 barrels through the ammlar space of a.
single well or to use that well for disposal purposes for a period longer than one year.
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.
The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the
mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC
25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the
BOPE test 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 contacting the Commission petroleum
field inspector on the North Slope pager at 659-3607.
~niel T. Seamount, Jr.
Commissioner
BY ORDER OF THE COMMISSION
DATED this / ~ ~ day of November, 2000
dlf/Enclosures
cc: Department of Fish & Gmne, Habitat Section w/o encl.
Department of Environmental Conservation w/o encl.
1 D-101 Spider Plots
Subject: ID-101 Spider Plots
Date: Sat, 11 Nov 2000 15:30:48 -1000
From: "Steve McKeever" <SMCKEEV@ppco.com>
To: tom_maunder@admin.state.ak, us
Tom
Please find attached 2 files, each at different scale, showing a plan view of
existing wells near to the proposed 1 D-101 well path.
Intersections with these nearby wells will be avoided by:
Use of MWD tools.
Use of gyro surveys when required due to magnetic interference (the 500 feet of
12-1/4" hole section at a minimum)
Use of steerable drilling assemblies while drilling all sections of 1D-101.
Use of careful directional planning and execution.
and
Strict adherence to the Phillips Drilling Anti-collision Policy, detailing
minimum clearance distances that must be maintained.
RECE.]VED
2000
Please call or e-mail should you have any questions.
Alaska Oil,& Ge~ C~s., Commission
~chor'~e
(See attached file: platformspider3.PDF)(See attached file: platformspider2.PDF)
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' [DescriptiOgn:: AdObe POrtable DOcument
1 of 1 11/13/00 9:01 AM
[3 RI L.L. INr= SERVICES
A Hiitllburtorl Company
Phillips Alaska
I DrillQuesf
700
~,,;~
400
300
200
100
Scale: linch = lOOft Eastings
-400 -300 -200 -100 0 100
-400 -300 -200 -100 0 100
Scale: linch [] 100ft Eastings Reference is True North
700
60O
5O0
400
300
200
100
PHILLI[.,S Alaska, Inc.
A Subsidiary of PHILLIPS PETROLEUM COMPANY
Phillips Alaska, Inc.
Post Office Box 100360
Anchorage, Alaska 99510
November 8, 2000
Alaska Oil and Gas Conservation Commission
3001 Porcupine Drive
Anchorage, AK 99501
(907) 279-1433
Re: Application for Permit to Drill:
West Sak 1 D-101
Surface Location:
Target Location:
Bottom Hole Location:
192' FSL, 594' FEL, Sec. 14, T11 N, R10E
1700' FNL, 1329' FEL, Sec. 14, T11N; R10E
1548' FNL, 1358' FEL, Sec. 14, T11 N, R10E
Dear Sirs: \ ~,. ~ c_~::~.-
Phillips Alaska, Inc. hereby applies for a Permit to Drill a development well West Sak 1 D-101.
The well will be drilled and completed using Nordic Rig 3. Please utilize documents on file for this rig.
Subject to AOGCC approval, fluids and cuffings generated from drilling the well will be pumped down an
approved and existing annulus on Drillsite 1 D, or hauled to an approved Prudhoe or GKA Class II disposal
well.
Also note that Phillips Alaska does not anticipate the presence of H2S in the formations to be encountered
in this well. However, there will be H2S and combustible gas monitoring equipment functioning on the rig as
is the standard operating procedure in the Kuparuk River Unit drilling operation.
The following people are the designated contacts for reporting responsibilities to the Commission:
A) Completion Report
(20 AAC 25.070)
Sharon AIIsup-Drake, Drilling Technologist
263-4612
B) Geologic Data and Logs
(20 AAC 25.071)
Mike Werner, Geologist
265-6191
Please note that the anticipated spud date for this well is November 16, 2000. Should you have any
questions or require further information, please contact Steve McKeever at 265-6826, or James Trantham
at 265-6434.
Sincerely,
St ve"~'U~;;eve r
Drilling Engineer
RECEIVED
NOV 08 2000
Nldm Oil & Gaa Ceils. Cemmimon
Attachments:
cc: West Sak 1 D-101 Well File
James Trantham ATO-1596
STATE OF ALASKA -
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
20 AAC 25.005
la. Type of worlc Drill F~ Redrill [~ I lb. Type of well. Exploratory E] Stratlgraphic Test E] Development Oil E]
Re-entry E] Deepen DI sewice r~ Development Gas D single Zone r~l Multiple Zone D
2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool
Phillips Alaska, Inc. RKB.30' /~/.,~.0 feet
3. Address 6. Property Designation Kuparuk River Field
P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25650 ALK 468 West Sak Oil Pool
4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC: 25.0251)
194' FSL, 595' FEL, Sec. 14, T11 N, R10E, UM Kuparuk River Unit Statewide
At top of productive Interval 8. Well number Number
1700' FNL, 1329' FEL, Sec. 14, T11N, R10E, UM 1D-101 #U-630610
At total depth 9. Approximate spud date Amount
1548' FNL, 1358' FEL, Sec. 14, T11N, R10E, UM November 16, 2000 $200,000
12. Distance to nearest property line I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD)
1700' @ Targ, feetI 1 D-102 14.6' @ 400' feet 2560 6138' MD / 4283' TVD
16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2))
iKickoff depth: 500 MD Maximum hole angle 65.7 ° Maximum surface 1450 psig At total depth (TVD) 1906 psig
18. Casing program Setting Depth
size Specitlcatlons Top Bottom Quantib/of Cement
Hole Caslnc, I Wei~lht Grade CoupIIn~l Lan~h MD TVD MD TVD (Include sta~ data)
24" 16" 151.54f X-65 BTC-MOD 118' 30' 30' 148' 148' 70 sx AS 1
12.25' 10.75" 40.5# J-55 BTC 470' 30' 30' 500' 500' 77 bbls ArtiCRETE
7.875' 5.5" x 15.5# L-80 BTCM 5425' 30' 30' 5455' 3647' 500 sx AS Lite &
7.875' 3.5" 9.3# L-80 EUE 8rd M 688' 5455' 3647' 6138' 4283' 310 sx Class G
5.5" 3.5' 9.3# L-80 EUE 8rd M 5425' 30' 30' 5455' 3647'
19. To be completed for Redrill, Re-ent~J, and Deepen Operations.
Present well condition summary
Total Depth: measured feet Plugs (measured)
true vertical feet
Effective Depth: measured feet Junk (measured)
true vertical feet
Casing Length Size Cemented Measured depth True Vertical depth
Conductor
Surface RECEIVED
Intermediate
Production NOV 08 ~t000
Liner
NiaOil&OasC~s.~
Perforation depth: measured ~~
true vertical
20. Attachments Firing fee ~] Property Plat r~ BoP Sketch D Diverler Sketch r"] Drilling program r~
Drilling fluid program [~] Time vs depth plot DRefraction analysis [~ Seabed report D 20 AAC 25.050 requirements r~
21. i hereby cer fy that the foregoing Is true and correct to the best of my knowledge Questions? Call Steve McKeever 265-682~
Signed
Title:
Pret~red bv ~h~ron AIIsuo-Drak~
Commission Use Onl}
Permit Number ~-/(~)3 I APl number I See cover letter
Conditions of approval Samples required D Yes [] No Mud Icg required E] Yes ~' No
Hydrogen sulfide measures [~ Yes [~] No Directional suwey required [~ Yes E] No
Requlred working pressure for BOPE I--'I2M; ~ 3M; D 5M; [~ 1OM;El [~
ORIGINAL SIGNED BY by order of ~,.~ ~,.t~ ~.~ ~
Approvedby ~ T_~,!!o.,. ~n..~..~.::.,,:f Commissioner the commission Date //" tY~)
ORIGINAL
Form 10-401 Rev. 12/1/85 · Submit in triplicate
[
~ West Sak Injection Well #1D-101
Permit to Drill Application: General Information, Drilling Fluid Program, Pressure
Calculations, Drilling Area Risks & General Procedure
Well Plan Summary
Well Purpose: West Sak Injection
Rig: Nordic Rig #3
Estimated Start Date: November 16, 2000
Expected Days to Drill and Complete: 9.8
Total Measured Depth, RKB: 6,138 E.
Total Vertical Depth, RKB: 4,283 E
Lo.q.qinfl/Formation Evaluation Pro§ram
Open Hole: MWD / GR / RES
Cased Hole Logs: CBL / GR / CCL aEer the rig has moved off
Drillinq Fluid System
RECEIVED
Tandem Geolograph / Swaco Shale Shakers
Hud Cleaners
Degassers
PVT System with visual and audio alarms
Trip Tank
Flow Sensor
Fluid Agitators
Note: Drilling Fluid Practices will be in accordance with appropriate regulations stated in 20 AAC 25.033.
Mud Prorjram
..
I'lUU I y~ Will U~ 0 ~U311UCIiU I1~11 WClI.~I Mahou U~IILUIIIL~ ~lUll r,
Znterval Density Viscosity YP PV :L0/s Gel AP! Solids
(ppg) (seconds)
Spud to 10-3/4" 8.5 - 8.8 250 - 300 40-60 7 - 14 20 - 28 8 - 15 <6%
Casing Point
10-3/4" Casing Point 8.8 - 9.4 75 - 150 18 - 25 15 - 35 10 - 25 5 - 7 <9%
to TD of 7-7/8" Hole
Reservoir 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/E, or 8.2 to 8.8'ppg EMW (equivalent mud weight), depending on the
TVD of the sand layer being evaluated. Assuming a 100 psi overbalance is required to safely drill and trip in this
formation, then a required mud weight of 9.3 ppg can be predicted as a maximum mud weight required to safely drill
this formation, assuming a TVD of 3,653'.
Experience in the area has proven that these zones can be safely drilled using a diver~er system for well control
purposes. The rig diver~er system will be filled with water or mud and function tested prior to spudding the well.
Following the running or the 5-1/2" x 3-1/2" tapered production casing, the diverter will be nippled down and an APT
5K 8OP stack will be nippled up and tested for cased hole operations.
Since the 5-1/2" x 3-1/2' tapered production casing will not be drilled out, leak off testing and maximum potential
surface pressure (MPSP) calculations are not necessary for drilling ahead. However, IvlPSP calculations for operations
in the cased hole are in order. Calculating MPSP based on the highest recorded reservoir pressure from the WS1-01
well, and assuming a gas gradient of 0.11 psi/E from the West Sak base to surface, the following MPSP can be
computed:
MPSP :(4143 E)(0.46 - 0.11 psi/E)
=1450 psi
Well 1D-101 Permit to Ddll Application
InformaO'on & Procedure
Page i ors
s(" (
The 5-1/2" 15.5# L-80 BTC ca co be used has a burst rating of 7,000 psi; 70 % of this burst rating is 4,900 psi.
After testing, a 3-1/2" tubing tieback string will be installed in the well to be used as the injection string.
D~rillin,q Area Risks
Drilling risks in the West Sak 1D-101 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, 9.4 ppg mud should be more than
adequate to control both the Ugnu and West Sak formation pressures without resulting in lost circulation.
Close Crossinq and Offset Well Interception Risk-;
Positional uncertainty calculations were performed on the proposed 1D-101 wellbore using worst case 3D elliptical
error models. Based on these calculations the following close approaches (existing wells having center lines which
may lie less than 30 feet from the centerline of the proposed well bore) are anticipated. For more information see
attached Sperry Anti-collision Report.
Center to Center
Existing Well Close Crossing Separation at Close
Name Depth - MD Crossing Depth
_ 1D-102 350, 15.65, -
_ 1D-102 400' 14.64'
1D-12 525' 29.55'
1D-14 825' 21.52'
Annular Pumping Activiti;;
Incidental fluids generated from drilling operations will be hauled to the nearest permitted disposal well or will be
pumped down the surface / production casing annulus of a permitted existing well on DS-1D. That annulus will be left
with a non-freezing fluid during any extended shut down (in excess of four hours) of pumping operations. The West
Sak 1D-101 surface casing by production tubing annulus will be filled with diesel and/or non-freezing brine after
setting the 3-1/2" tubing tieback string and prior to the drilling rig moving off of the well.
Casinq and Tubing Rating~
RECEIVED
NOV 0Sa00
Wt 85% of 85% of
OD (Ppf) Grade Range Conn. Collapse Collapse Burst Burst
10-3/4 .... 40.5# .1-55 3 BTC 1,580 psi 1,343 psi 3,130 psi 2,660 psi
5-1/2" 15.5# L-80 3 8TCM 4,990 psi 4,241 psi 7,000 psi 5,950 psi
3-1/2" 9.3# L-80 2 EUE 8rd 10,530 psi 8,951 psi 10,160 psi 8,636 psi
General Procedure
1. Excavate cellar, install cellar box, set and cement 16" conductor. Weld landing ring on conductor.
2. MTRU Nordic Rig 3. Tnstall diverter and function test same.
3. Spud and directionally drill 12-1/4" hole to 500'.
4. Condition hole for casing.
5. Run and cement 10-3/4" casing to surface.
6. Spud and directionally drill 7-7/8" hole to desired targets through West Sak interval. Run MWD/LWD/ PWD
logging tools in drill string as required for directional monitoring and formation data gathering.
7. Circulate and condition hole to run casing. POOH.
8. Run and cement 3-1/2" 9.3# L-80 FUE 8rd x 5-1/2" 15.5# L-80 8TCIVl tapered casing string to surface. Displace
cement with mud and perform stage job or top job if required.
Note: 5-1/2" Port Collar to be installed @ +/- 600' TVD.
9. Nipple down diverter and install wellhead. Nipple up BOP stack and pressure test to 3000 psi.
10. Pressure casing to 3,000 psi for _30 minutes per AOGCC regulations..Record results.
Well 1D-10I Permit to Dffll Applica[~bn
Informal'on & Procedure
Page 2 of'$
11. PU and RIH with 3-1/2" tu~. ~ to just above seal bore extension and displace well to brine.
12. Sting into seal bore extension and space out.
13. Unsting seal assembly, and freeze protect well with diesel.
14. Sting back into seal bore extension and land tubing.
15. Using diesel, pressure test tubing and annulus to 3,000 psi for 30 minutes per AOGCC regulations. Record
results. Install back pressure valve.
16. Nipple down BOP stack. Install production tree and pressure test same.
17. Secure well and release rig.
18. Rig up E-line unit and RIH with CBL / CET. Run cement bond log across West Sak interval. Report results to
office for remedial action if necessary.
19. Rig up E-line unit and RIH with through-tubing perforating guns.
20. Perforate well overbalanced. POOH with perf guns. Repeat runs as required to perforate all desired West Sak
intervals. Rig down E-line unit.
21. Install back pressure valve, shut in and secure well.
RECEIVED
NOV 08 2000
Well ]D-lO] Permit to D/#/ App/ica#on
/nformaUon & Procedure
Page $ ors
Well # 1D-1 1, AFE #AK0124
West Sak ri nobore Injector
5-1/2" x 3-1/2" Tapered String
Planned Completion Schematic v3.0
Nordic Rig #3 RKB @ 0'
Eastings: 560,490.5
Northings: 5,959,859.0
PHILLIPS Alaska, Inc.
A Subsidiary of PHILLIPS PETROLEUM COMPAN~
Tubing Hanger:
3-1/2" Vetco-Gray w/3-1/2" EUE 8RD-Mod pin down.
16" Conductor
@ 148' MD
Gravel Isolation String
@ 500' MD
10-3/4" 40.5# J-55 BTC
Port Collar @ 600' MD:
TAM 5-1/2" BTC Box x Pin
RECEIVED
NOV
Production Tubing:
3-1/2" 9.3# L-80 EUE 8RD Mod to surface.
Production Casing
5-1/2" 15.5# L-80 LTCM or BTCM
XO / SBE to surface
Set XO / SBE +/- 100' above
top Perforation
D-Sands ~"t~,~
(plan to perforate after rig work)
B-Sands
(plan to perforate after rig work)
Gas Lift Mandrel:
3-1/2" x 1" Camco 'KBG-2-9' w/DV & latch, 3-1/2" x 6'
Handling Pups installed on top and bottom w/BTCM Pin x
EUE 8RD Mod Box Special Clearance Couplings.
I Joint 3-1/2" 9.3# L-80 EUE 8RD-Mod Tubing.
Landing Nipple: 3-1/2" Camco 'DS'w/2.812" No-Go Profile.
I Joint 3-1/2" 9.3# L-80 EUE 8RD-Mod Tubing.
Locator Seal Assembly: 3-1/2" Baker GBH-
22 '80-40' w/12' of Seals and Locator
3-1/2" x 6' L-80 Handling Pup installed on top. EUE
8RD-Mod Box up.
Casing Bore Receptacle Assembly @ +/- 5455' MD:
IBaker 5-1/2" XO / Handling Pup, BTC x LTC
Baker XO Coupling w/Iocator shoulder, LTC x SBE
Baker 5" OD x 4" ID Seal Bore Extension 12'
Baker XO, SBE x 3-1/2" EUE 8RD
3-1/2" 9.3# L-80 EUE 8RD Mod Tubing from
Landing Sleeve to SBE.
A-Sands
(plan to perforate after rig work)
Production Casing
3-1/2" 9.3# L-80 EUE 8RD-Mod
TD to XO / SBE
TD 7-718" Hole
6138' MD, 4283' TVD
Landing Sleeve: 3-1/2" Weatherford, installed in top of joint #3.
I Joints 3-1/2" 9.3# L-80 EUE 8RD-Mod Tubing.
Float Collar: 3-1/2" Weatherford w/3-1/2" EUE 8rd Box x Pin.
2 Joints 3-1/2" 9.3# L-80 EUE 8RD-Mod Tubing.
Float Shoe: 3-1/2" Weatherford w/3-1/2" EUE 8rd Box Up.
1D-101 Schematic v3.0
prepared by Steve McKeever
11/06/00
North Slopgr" qaska
Alaska Stat&. ,lane 4
Single Wall Target Data for PLAN: 1D-101 WPe
Unlm: fl
Coordinate
hint TVD TVD Noflhlngl EIBUnOI NonMngl ~lllngl Target
i InJ~.tor IGTi ~ I,oini 37~.on 3&f7.00 3.1U~82 ~ ?.1&ix w .%lG.13~h, Ofl N &t9735,00 l: CIicle
el
5 112' X 31/2' 6138.06
Total Depth:
End Dir, Start Sail @ 20.000°: 5684.46ftMD
K~ ruk 10 I DrillQues.'t'
PLAN- 1D-101 WPs -
3200
Begin Dir @ 3.00°/100fl : 4159.94ff MD,
2400
RECEIVED
NOV 082000
0
Z 1600
10 3/4' Casing- 500.00 MD, 500.00 TVD J~- -- -~-~
iIt//Begin Dir @ 1.50°/100ft : 500.00fl MD, 500.00ff TVD
Dir Rate @ 2.50°/100ft : 666.67ff MD, 666.61ff TVD
-800 0
I
').~/c('!.)r I,~, 5"[
800
End Dir, Start Sail @ 65.733°: 1892.29ftTVD
8OO
in Dir Rate @ 3.50°/100ft : 875.50ft MD, 874.60ft TVD
Rate @ 4.50°/100ft : 1086.98ft MD, 1082.32ft TVD
Begin Dir @ 6.00°/100ft : 1687.00ft
End DJr, Start Sail @ 37.041°:
1600
,2400
Irlcrease iq Dj~ R~te. @ 4.50°/100ft
increase in u r ,ate @ 3.50°/100ft
Increase in Dir Rate @ 2.50°/100ft
Begin Dir @ 1.50°/100ft : 50~).00ft MDr 500.00ft
Dir, Start Sail @ 37.041 o: 1626.87ftMD,1567.00ftTVD
in Dir @ 6.00°/100ft : 1777.20ft MD, 1687.00ft TVD
Reference is True Nort
~=..o Scale: linch = 80Oft
Dir, Start Sail @ 65.7:33°: 2272.40ftMD,1892.29ftTVD
A:.I5 Sa,d · 2.13~.00 7'VD
in Dir @ 3.00°/100ft : 4159.94ft MD, 2668.04ft TVD
- 3200
- 2400
O
- 1600 Z
- 800
-0
32OO
............................... Top Ugm, S(md.~' .. 3093.00 TVD
o
o
co
II
.c:
~= 4000
..
3'h,lc · 3570.00 TVD
, End Dir, Start Sail @ 20.000°: 5684.46ftMD,3756.001
............................ Wi,st.$'ak A2 · 3953.00 ?'VI'~
............................ Wrst ,Yak A f - ,I048.00
..... Base We,vt 5'(tk .. 4143.00 7~/1)
Total Depth: 6138.06ftMD,4182.25ftTVD
5 1/2" X 31/2" Liner - 6138.06 MD, 4283.25 TVD
I
0 800
Scale: linch = 800ft
I I I
1600 2400 3200
Section Azimuth: 347.779° (True North)
Vertical Section
Sperry-Sun Drilling Services
Proposal Data - PLAN · 1D-101 WPs - 1D-101 Wp7
6138.060
7 November, 2000 - 15:54 - 1 - DrillQuest
North Slope Alaska
Alaska State Plane 4
Kuparuk 1D
PLAN: 1D-101 WPs- 1D-101 Wp7
Revised: 7 November, 2000
PROPOSAL REPORT
7 November, 2000
ITl
Surface Coordinates: 5959859.23 N, 560490.42 E (70° 18' 03.2293" N,
Kelly Bushing: 101.0Oft above Mean Sea Level
149° 30' 36.2536" W)
Proposal Ref: pro9314
. . Services
rllllrlg w,;
.Sun D .
RECEIVED p?o poesralrRYee'PORde fv /ePdfCNN; lv eJber, 2000
NOV 08~
Verticat
North Stope Atast(a
Sub-Sea DePth No,things
Measured incl, Azim, Depth (`~t) (fl)
(m o.oo~
Oepth o.oo o.oO ~
[~) .~ o~ .oo 50.00 o.oo N
o.oo o.oOO o.oOO -5~.oo
50.00 0.000 0.000 .~ .00 100.00 0.00 N
100-00 0.000 0.000 49.00 150.00 0.00 N
150.00 0.000 0.000 99.00 200.00
0.000 0.000 0.00 N
250.00 0.00 N
200.00 149.00
250.00 0.000 0.000 300.00 0.00 N
300.00 0.000 0.000 199.00
350.00 0.000 0.000 249.00 350.00 0.00 N
400.00 0.000 0.000 299.00 400.00 0.00 N
450.00 -0.000 0.000 349.00 450.00 0.00 N
399.00 500.00
0.000 0.000 0.06
LOCal Coordinates
Eastings
0.oo E
0.00 E
0.00 E
0.00 E
0.00 E
0.00 E
0.00 E
0.00 E
0.00 E
o.oo E
o.o0 E
0.32 W
1.29 W
Alaska state plane 4
KuparUR 1 O
Verticat comment
Oogieg section
GlObal Coordinates Rate
Eastings (`ollOOtt)
Northings (,fi) o.o0
(`fi) 0.00
560490.42 E 0.00 0.00
5959859.?-3 N 560490.42- E 0.00
5959659.23 N 0.00 0.00
5959859.23 N 560490.42 E 0.00
5959659-23 N 560490.42 F.. 0.00
0,o0
5959659'23 N 560490.42 E 0.00 0.00
5959659-23 N 560490'42 E 0.00 0.00
560490.42 E 0.00 0.00
5959859'23 N 560490.47' E 0.00
5959859.23 N 0.00 ' 50°1100R .-:
5959659-23 N 560490.42 E 0.00 Be in Oi~ @ '"'
5959659.23 N 560490,42 E
560490,47- E 0.00 0.00 5090.00tt MD, 500.00tt
10 314" Casing
5959859-?-3 N
0.12
5959659-28 N 560490.10 E 1.50 0.50 . · Rate @
5959859.45 N 560489.13 E 1.50 1.11 increase_ ~n, Dtr. 666.67ff
5959859.72 N 560467.52 E 1.50 1.37 o RD°Il0u~t '
666.61tt tv
5959659-83 N 560486.83 E 1.50 .... - ""O
500.00
449.00 550.00 0.23 N 2.90 W
599.99 0.51 N 3.56
RECEIVED
V o e eo
North Slope Alaska
Sperry-Sun Drilling Services
Proposal Report for PLAN: 1D-101 WPs - 1D-101 Wp7
Revised: 7 November, 2000
Alaska State Plane 4
Kuparuk 1D
Measured
Depth
(ft)
Incl. Azim.
900.00 8.176 303.876
950.00 9.644 310.045
1000.00 11.193 314.560
1050.00 12.794 317,974
1086.98 14.000 320.000
Sub-Sea
Depth
(ft)
797.87
847.27
896.44
945.35
981.32
Vertical
Depth
(ft)
898.87
948.27
997.44
1046.35
1082.32
Local Coordinates Global Coordinates
Northings Eastings Northings Eastings
(ft) (ft) (ft) (ft)
10.01 N 22.71W 5959869.06 N 560467.63 E
14.69 N 28.87W 5959873.69 N 560461.43 E
20.79 N 35.53W 5959879.73 N 560454.72 E
28.31N 42.70W 5959887.19 N 560447.49 E
34.78 N 48.31W 5959893.62 N 560441.83 E
Dogleg
Rate
(°/lOOft)
3.50
3.50
3.50
3.50
3.50
Vertical
Section
14.59
20.47
27.84
36.70
44.21
Comment
Increase in Dir Rate @
4.50°/100ft : 1086.98ft MD,
1082.32ft TVD
1100.00 14.510 321.171 993.94 1094.94
1150.00 16.515 325.000 1042.12 1143.12
1200.00 18.574 328.011 1089.79 1190.79
1250.00 20.672 330.435 1136.88 1237.88
1300.00 22.798 332.428 1183.33 1284.33
1350.00 24.945 334.095 1229.05 1330.05
1400.00 27.107 335.513 1273.98 1374.98
1450.00 29.282 336.736 1318.04 1419.04
1500.00 31.466 337.804 1361.18 1462.18
1550.00 33.659 338.746 1403.31 1504.31
37.25 N 50.35W 5959896.08 N 560439.77 E
47.96 N 58.36W 5959906.71 N 560431.68 E
60.53 N 66.65W 5959919.22 N 560423.28 E
74.97 N 75.23W 5959933.59 N 560414.59 E
91.23 N 84.06W 5959949.78 N 560405.62 E
109.30 N 93.16W 5959967.78 N 560396.39 E
129.16 N 102.49W 5959987.56 N 560386.90 E
150.76 N 112.04W 5960009.08 N 560377.17 E
174.08 N 121.80W 5960032.32 N 560367.22 E
199.08 N 131.75W 5960057.24 N 560357.07 E
4.50
4.50
4.50
4.50
4.50
4.50
4.50
4.50
4.50
4.50
47.07
59.22
73.27
89.19
106.96
126.55
147.93
171.06
195.92
222.46
1600.00 35.857 339.585 1444.39 1545.39
1626.87 37.041 340.000 1466.00 1567.00
1650.00 37,041 340.000 1484.47 1585.47
1700.00 37.041 340.000 1524.38 1625.38
1702.03 37,041 340.000 1526.00 1627.00
1722.08 37,041 340.000 1542.00 1643.00
1750.00 37.041 340.000 1564.29 1665.29
1777.20 37.041 340.000 1586.00 1687.00
1800.00 38.336 340.718 1604.04 1705.04
1850.00 41.191 342.159 1642.47 1743.47
225.72 N 141.88W 5960083.80 N 560346.72 E
240.70 N 147.40W 5960098.74 N 560341.09 E
253.80 N 152.16W 5960111.79 N 560336.22 E
282.10 N 162.46W 5960140.01N 560325.69 E
283.25 N 162.88W 5960141.16 N 560325.26 E
294.60 N 167.01W 5960152.47 N 560321.04 E
310.40 N 172.77W 5960168.23 N 560315.16 E
'325.80 N 178.37W 5960183.58 N 560309.43 E
338.93 N 183.05W 5960196.67 N 560304.64 E
369.24 N 193.22'W 5960226.90 N 560294.23 E
4.50
4.50
0.00
0.00
0.00
0.00
0.00
0.00
6.00
6.00
250.64
266.45
280.26
310.10
311.31
323.28
339.94
356.17
370.00
401.78
End Dir, Start Sail @ 37.041 °
: 1626.87ftMD,1567.00ftTVD
Base Permafrost
Begin Dir @ 6.00°/100ft :
1777.20ft MD, 1687.00ft TVD
Continued...
7 November, 2000 - 15:53 - 3 - DrillQuest 2.00,05
North Slope Alaska
Measured Sub-Sea Vertical
Depth Incl. Azim. Depth Depth
(ft) (ft) (ft)
1900.00 44.062 343.444 1679.26 1780.26
1950.00 46.947 344.602 1714.30 1815.30
2000.00 49.841 345.655 1747.49 1848.49
2050.00 52.745 346.623 1778.76 1879.76
2100.00 55.656 347.518 1808.00 1909.00
2150.00 58.573 348.353 1835.15 1936.15
2200.00 61.495 349.138 1860.12 1961.12
2250.00 64.421 349.880 1882.85 1983.85
2272.40 65.733 350.201 1892.29 1993.29
2300.00 65.733 350.201 1903.63 2004.63
2350.00 65.733 350.201 1924.18 2025.18
2400.00 65.733 350.201 1944.73 2045.73
2450.00 65.733 350.201 1965.28 2066.28
2500.00 65.733 350.201 1985.83 2086.83
2550.00 65.733 350.201 2006.38 2107.38
2600.00 65.733 350.201 2026.93 2127.93
2614.78 65.733 350.201 2033.00 2134.00
2650.00 65.733 350.201 2047.48 2148.48
2700.00 65.733 350.201 2068.03 2169.03
2750.00 65.733 350.201 2088.58 2189.58
2800.00 65.733 350.201 2109.13 2210.13
2850.00 65.733 350.201 2129.68 2230.68
2900.00 65.733 350.201 2150.23 2251.23
2950.00 65.733 350.201 2170.77 2271.77
3000.00 65.733 350.201 2191.32 2292.32
Sperry-Sun Drilling Services
Proposal Report for PLAN: 1D-101 WPs - 1D-101 Wp7
Revised: 7 November, 2000
Local Coordinates Global Coordinates
Northings Eastings Northings Eastings
(ft) (ft) (ft) (fi)
401.59 N 203.22W 5960259.17 N 560283.97 E
435.87 N 213.03W 5960293.37 N 560273.89 E
472.00 N 222.62W 5960329.43 N 560264.01E
509.88 N 231.96W 5960367.23 N 560254.37 E
549.40 N 241.02W 5960406.68 N 560244.98 E
590.46 N 249.79W 5960447.66 N 560235.88 E
632.94 N 258.24W 5960490.07 N 560227.09 E
676.72N 266.34W 5960533.79 N 560218.64 E
696.73 N 269.86W 5960553.77 N 560214.96 E
721.53 N 274.14W 5960578.52 N 560210.48 E
766.44 N 281.90W 5960623.38 N 560202.36 E
811.36 N 289.65W 5960668.23 N 560194.24 E
856.28 N 297.41W 5960713.08 N 560186.12 E
901.19 N 305.17W 5960757.94 N 560178.00 E
946.11N 312.93W 5960802.79 N 560169.89 E
991.03 N 320.69W 5960847.64 N 560161.77 E
1004.30 N 322.98W 5960860.90 N 560159.37 E
1035.95 N 328.44W 5960892.50 N 560153.65 E
1080.86 N 336.20W 5960937.35 N 560145.53 E
1125.78 N 343.96W 5960982.20 N 560137.41E
1170.70 N 351.72W 5961027.06 N 560129.29 E
1215.61N 359.47W 5961071.91N 560121.17 E
1260.53 N 367.23W 5961116.76 N 560113.05 E
1305.45 N 374.99W 5961161.62 N 560104.93 E
1350.36 N 382.75W 5961206.47 N 560096.82 E
Dogleg
Rate
(°/100ft)
6.00
6.00
6.00
6.00
6.00
6.00
6.00
6.00
6.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
Alaska State Plane 4
Kuparuk 1D
Vertical
Section Comment
435.51
471.09
508.43
547.43
587.97
629.96
673.26
717.77
738.07
763.21
808.75
854.29
899.83
945.37
990.91
1036.45
1049.91
1082.00
1127.54
1173.08
1218.62
1264.16
1309.70
1355.24
1400.78
End Dir, Sta~ Sail @ 65.733°
:2272.40ffMD,1892.29ffTVD
K-15 Sand
Continued...
7 November, 2000 - 15:53 - 4 - DrillQuest 2.00.05
North Slope Alaska
Measured Sub-Sea Vertical
Depth Incl. Azim. Depth Depth
(ft) (ft) (ft)
3050.00 65.733 350.201 2211.87 2312.87
3100.00 65.733 350.201 2232.42 2333.42
3150.00 65.733 350.201 2252.97 2353.97
3200.00 65.733 350.201 2273.52 2374.52
3250.00 65,733 350.201 2294.07 2395.07
3300.00 65.733 350,201 2314.62 2415.62
3350.00 65.733 350.201 2335.17 2436.17
3400.00 65.733 350.201 2355.72 2456.72
3450.00 65.733 350.201 2376.27 2477.27
3500.00 65.733 350.201 2396.82 2497.82
3550.00 65.733 350.201 2417.37 2518.37
3600.00 65.733 350.201 2437.92 2538.92
3650.00 65.733 350.201 2458.46 2559.46
3700.00 65.733 350.201 2479.01 2580.01
3750.00 65.733 350.201 2499.56 2600.56
3800.00 65.733 350.201 2520.11 2621.11
3850.00 65.733 350.201 2540.66 2641.66
3900.00 65,733 350.201 2561.21 2662.21
3950.00 65.733 350.201 2581.76 2682.76
4000.00 65.733 350.201 2602.31 2703.31
4050.00 65,733 350.201 2622.86 2723.86
4100.00 65.733 350.201 2643.41 2744.41
4150.00 65.733 350.201 2663.96 2764.96
4159.94 65.733 350.201 2668.04 2769.04
4200.00 64.532 350.193 2684.89 2785.89
Sperry-Sun Drilling Services
Proposal Report for PLAN: 1D-101 WPs - 1D-101 Wp7
Revised: 7 November, 2000
Local Coordinates Global Coordinates
Northings Eastings Northings Eastings
(ft) (ft) (ft) (ft)
1395.28 N 390.50W 5961251.32 N 560088.70 E
1440.20 N 398.26W 5961296.18 N 560080.58 E
1485.12 N 406.02W 5961341.03 N 560072.46 E
1530.03 N 413.78W 5961385.88 N 560064.34 E
1574.95 N 421.53W 5961430.74N 560056.22 E
1619.87 N 429.29 W 5961475.59 N 560048.10 E
1664.78 N 437.05 W 5961520.44 N 560039.98 E
1709.70 N 444.81 W 5961565.30 N 560031.86 E
1754.62 N 452.56 W 5961610.15 N 560023.74 E
1799.54 N 460.32 W 5961655.00 N 560015.63 E
1844.45 N 468.08W 5961699.86 N 560007.51E
1889.37 N 475.84W 5961744.71 N 559999.39 E
1934.29 N 483.59W 5961789.56 N 559991.27 E
1979.20 N 491.35W 5961834.41 N 559983.15 E
2024.12 N 499.11W 5961879.27 N 559975.03 E
2069.04 N 506.87W 5961924.12 N 559966.91E
2113.96 N 514.63W 5961968.97 N 559958.79 E
2158.87 N 522.38W 5962013.83 N 559950.67 E
2203.79 N 530.14W 5962058.68 N 559942.56 E
2248.71N 537.90W 5962103.53 N 559934.44 E
2293.62 N 545.66W 5962148.39 N 559926.32 E
2338.54 N 553.41W 5962193.24 N 559918.20 E
2383.46 N 561.17W 5962238.09 N 559910.08 E
2392.39 N 562.71W 5962247.01N 559908.46 E
2428.20 N 568.90W 5962282.77 N 559901.99 E
Dogleg
Rate
(°/100ft)
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
3.00
Alaska State Plane 4
Kuparuk 1D
Vertical
Section
1446.33
1491.87
1537.41
1582.95
1628.49
1674.03
1719.57
1765.12
1810.66
1856.20
1901.74
1947.28
1992.82
2038.36
2083.91
2129.45
2174.99
2220.53
2266.07
2311.61
2357.15
2402.69
2448.24
2457.29
2493.60
Comment
Begin Dir @ 3.00°/100ft :
4159.94ft MD, 2668.04ft TVD
Continued.,.
7 November, 2000 - 15:53 - 5 - DrillQuest 2,00.05
North Slope Alaska
Measured
Depth
(ft)
Incl. Azim.
Sub-Sea
Depth
(ft)
Vertical
Depth
(ft)
4250.00 63.032 350.182 2706.98 2807.98
4300.00 61.532 350.171 2730.23 2831.23
4350.00 60.032 350.159 2754.64 2855.64
4400.00 58.532 350.148 2780.18 2881.18
4450.00 57.032 350.136 2806.84 2907.84
4500.00 55.532 350.123 2834.59 2935.59
4550.00 54.032 350.110 2863.42 2964.42
4600.00 52.532 350.096 2893.32 2994.32
4650.00 51.032 350.082 2924.25 3025.25
4700.00 49.532 350.068 2956.20 3057.20
4750.00 48.032 350.052 2989.14 3090.14
4754.27 47.904 350.051 2992.00 3093.00
4800.00 46.532 350.036 3023.06 3124.06
4850.00 45.032 350.019 3057.93 3158.93
4900.00 43.532 350.002 3093.73 3194.73
4950.00 42.032 349.983 3130.42 3231.42
5000.00 40.532 349.963 3167.99 3268.99
5050.00 39.032 349.942 3206.42 3307.42
5100.00 37.532 349.919 3245.66 3346.66
5150.00 36.032 349.895 3285.71 3386.71
Sperry-Sun Drilling Services
Proposal Report for PLAN: 1D-101 WPs - 1D-101 Wp7
Revised: 7 November, 2000
5200.00 34.533 349.869 3326.52 3427.52
5250.00 33.033 349.841 3368.08 3469.08
5300.00 31.533 349.810 3410.35 3511.35
5350.00 30.033 349.777 3453.30 3554.30
5368.08 29.490 349.764 3469.00 3570.00
Local Coordinates Global Coordinates
Northings Eastings Northings Eastings
(ft) (ft) (ft) (ft)
2472.40 N 576.55W 5962326.91 N 559893.99 E
2516.01 N 584.10W 5962370.46 N 559886.09 E
2559.01N 591.55W 5962413.39 N 559878.29 E
2601.36 N 598.90W 5962455.68 N 559870.60 E
2643.03 N 606.14W 5962497.30 N 559863.02 E
2684.01 N 613.27W 5962538.21 N 559855.56 E
2724.25 N 620.28W 5962578.39 N 559848.23 E
2763.73 N 627.17W 5962617.82 N 559841.02 E
2802.42N 633.93W 5962656.46 N 559833.95 E
2840.31 N 640.56W 5962694.29 N 559827.01 E
2877.35 N 647.05W 5962731.28 N 559820.22 E
2880.47 N 647.60W 5962734.40 N 559819.65 E
2913.53 N 653.40W 5962767.41 N 559813.58 E
2948.83 N 659.61W 5962802.65 N 559807.09 E
2983.20 N 665.67W 5962836.98 N 559800.76 E
3016.65 N 671.57W 5962870.37 N 559794.59 E
3049.13 N 677.31W 5962902.81N 559788.59 E
3080.63 N 682.89W 5962934.27 N 559782.75 E
3111.13 N 688.31W 5962964.72 N 559777.09 E
3140.61 N 693.55W 5962994.15 N 559771.60 E
3169.04 N 698.63W 5963022.54 N 559766.30 E
3196.40 N 703.52W 5963049.87 N 559761.19 E
3222.69 N 708.24W 5963076.11 N 559756.26 E
3247.87 N 712.78W 5963101.26 N 559751.52 E
3256.70 N 714.37W 5963110.08 N 559749.86 E
Dogleg
Rate
(°ll00ff)
3.00
3.00
3.00
3.00
3.00
3.00
3.00
3.00
3.00
3.00
3.00
3.00
3.00
3.00
3.00
3.00
3.00
3.00
3.00
3.00
3.00
3.00
3.00
3.00
3.00
Alaska State Plane 4
Kuparuk 1D
Vertical
Section Comment
2538.42
2582.64
2626.24
2669.18
2711.45
2753.00
2793.81
2833.86
2873.11
2911.54
2949.12
2952.28
2985.82
3o21.63
3056.51
3090.44
3123.41
3155.38
3186.33
3216.25
3245.11
3272.89
3299.58
3325.15
3334.12
Top Ugnu Sands
K-13 Shale
Continued...
7 November, 2000 - 15:53 - 6 - DrillQuest 2,00.05
North Slope Alaska
Measured
Depth Incl. Azim.
(ft)
Sub-Sea
Depth
(ft)
Vertical
Depth
(ft)
"~-~'~'~~'~""' 5400.00 28.533 349.741 3496.91 3597.91
~.! ¥5450.00 27.033 349.701 3541.15 3642.15
A..~',~,,,) 5500.00 25.533 349.656 3585.98 3686.98
,,,,~(~ 5524.33 24.803 349.633 3608.00 3709.00
5550.00 24.033 349.607 3631.37 3732.37
5594.26 22.706 349.558 3672.00 3773.00
5600.00 22.533 349.551 3677.30 3778.30
5636.34 21.443 349.506 3711.00 3812.00
5650.00 21.034 349.488 3723.73 3824.73
5684.46 20.000 349.439 3756.00 3857.00
5700.00 20.000 349.439 3770.60 3871.60
5750.00 20.000 349.439 3817.59 3918.59
5765.34 20.000 349.439 3832.00 3933.00
5800.00 20.000 349.439 3864.57 3965.57
5850.00 20.000 349.439 3911.56 4012.56
5887.72 20.000 349.439 3947.00 4048.00
5900.00 20.000 349.439 3958.54 4059.54
5950.00 20.000 349.439 4005.53 4106.53
5988.81 20.000 349.439 4042.00 4143.00
6000.00 20.000 349.439 4052.51 4153.51
Sperry-Sun Drilling Services
Proposal Report for PLAN: 1D-101 WPs - 1D-101 Wp7
Revised: 7 November, 2000
6050.00 20.000 349.439 4099.50 4200.50
6100.00 20.000 349.439 4146.48 4247.48
6138.06 20.000 349.439 4182.25 4283.25
Local Coordinates Global Coordinates
Northings Eastings Northings Eastings
(ft) (fi) (ft) (ft)
3271.94 N 717.12W 5963125.29 N 559746.98 E
3294.87 N 721.28W 5963148.19 N 559742.64 E
3316.65 N 725.25W 5963169.93 N 559738.49 E
3326.83 N 727.11W 5963180.10 N 559736.55 E
3337.27 N 729.02W 5963190.52 N 559734.56 E
3354.53 N 732.20W 5963207.76 N 559731.24 E
3356.70 N 732.60W 5963209.93 N 559730.83 E
3370.08 N 735.07W 5963223.29 N 559728.24 E
3374.95 N 735.97W 5963228.14 N 559727.30 E
3386.82 N 738.18W 5963240.00 N 559725.00 E
3392.05 N 739.15W 5963245.22 N 559723.98 E
3408.86 N 742.29W 5963262.00 N 559720.71E
3414.02 N 743.25W 5963267.15 N 559719.71E
3425.67 N 745.42W 5963278.79 N 559717.44 E
3442.48 N 748.56W 5963295.57 N 559714.18 E
3455.16 N 750.92W 5963308.24 N 559711.71 E
3459.29 N 751.69W 5963312.36 N 559710.91E
3476.10 N 754.82W 5963329.15 N 559707.64 E
3489.15 N 757.26W 5963342.18 N 559705.10 E
3492.92 N 757.96W 5963345.93 N 559704.37 E
3509.73N 761.09W 5963362.72N 559701.10 E
3526.54 N 764.23W 5963379.50 N 559697.83 E
3539.34 N 766.61W 5963392.28 N 559695.34 E
Dogleg
Rate
(o/looft)
3.00
3.00
3.00
3.00
3.00
3.00
3.00
3.00
3.00
3.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
Alaska State Plane 4
Kuparuk 1D
Vertical
Section
3349.59
3372.88
3395.01
3405.35
3415.96
3433.51
3435.71
3449.31
3454.26
3466.33
3471.64
3488.74
3493.98
3505.83
3522.93
3535.82
3540.02
3557.11
3570.38
3574.21
3591.30
3608.40
3621.41
Comment
West Sak D
West Sak B
West Sak A4
End Dir, Start Sail @ 20.000°
: 5684.46ftMD,3756.00ftTVD
West Sak A3
Target - Injector 16 T1.
300.00 Radius.
West Sak A2
West Sak A1
Base West Sak
Total Depth:
6138.06ftMD.4182.25ftTVD
5 1/2" X 3 1/2" Liner
Continued...
7 November, 2000- 15:53 - 7- DrillQuest 2.00.05
oe
North Slope Alaska
Sperry-Sun Drilling Services
Proposal Report for PLAN: 1D-101 WPs - 1D-101 Wp7
Revised: 7 November, 2000
Alaska State Plane 4
Kuparuk 1D
All data is in feet unless otherwise stated. Directions and coordinates are relative to True North.
Vertical depths are relative to PLAN: 1 D-101 WPs. Northings and Eastings are relative to PLAN: 1 D-101 WPs.
The Dogleg Severity is in Degrees per 100 feet.
Vertical Section is from 1 D-104 WPs and calculated along an Azimuth of 347.779° (True).
BaSed upon Minimum Curvature type calculations, at a Measured Depth of 6138.06ft.,
The Bottom Hole Displacement is 3621.41ft., in the Direction of 347.779° (True).
Comments
Measured Station Coordinates
Depth TVD Northings Eastings
(ft) (ft) (ft) (ft)
500.00 500.00 0.00 N 0.00 E
666.67 666.61 0.63 N 3.58 W
875.50 874.60 8.24 N 19.88 W
1086.98 1082.32 34.78 N 48.31 W
1626.87 1567.00 240.70 N 147.40 W
1777.20 1687.00 325.80 N 178.37 W
2272.40 1993.29 696.73 N 269.86 W
4159.94 2769.04 2392.39 N 562.71 W
5684.46 3857.00 3386.82 N 738.18 W
Comment
Begin Dir @ 1.50°/100ft : 500.00ft MD, 500.00ft TVD
Increase in Dir Rate @ 2.50°/100ft : 666.67ft MD, 666.61ft TVD
Increase in Dir Rate @ 3.50°/100ft : 875.50ft MD, 874.60ft TVD
Increase in Dir Rate @ 4.50°/100ft : 1086.98ft MD, 1082.32ft TVD
End Dir, Start Sail @ 37.041 o: 1626.87ftMD,1567.00ftTVD
Begin Dir @ 6.00°/100ft : 1777.20ft MD, 1687.00ft TVD
End Dir, Start Sail @ 65.733°: 2272.40ftMD,1892.29ftTVD
Begin Dir @ 3.00°/100ft : 4159.94ft MD, 2668.04ft TVD
End Dir, Start Sail @ 20.000°: 5684.46ftMD,3756.00ftTVD
Continued...
7 November, 2000 - 15:53 - 8 - DrillQuest 2.00.05
/VOV 08
North Slope Alaska
Sperry-Sun Drifting Services
Proposal Report for PLAN: 1D-101 WP$ - 1D-101 Wp7
Revised: 7 November, 2000
Alaska State Plane 4
Kuparuk 1D
Formation Tops
Formati on Plane
(Below Well Origin)
Sub-Sea Dip Dip Dir.
(ft) Deg. Deg.
Profile
Measured Vertical
Depth Depth
(st) (ft)
1542.00 0.000 0.000 1722.08 1643.00
2033.00 0.000 0.461 2614.78 2134.00
2992.00 0.000 0.000 4754.27 3093.00
3469.00 0.000 0.000 5368.08 3570.00
3608.00 0.000 0.000 5524.33 3709.00
3672.00 0.000 0.000 5594.26 3773.00
3711.00 0.000 0.000 5636.34 3812.00
3756.00 0.000 0.000 5684.46 3857.00
3832.00 0.000 0.000 5765.34 3933.00
3947.00 0.000 0.000 5887.72 4048.00
4042.00 0.000 0.000 5988.81 4143.00
Penetration Point
Sub-Sea
Depth Northings Eastings
(ft) (ft) (ft)
1542.00 294.60 N 167.01W
2033.00 1004.30 N 322.98W
2992.00 2880.47 N 647.60W
3469.00 3256.70N 714.37W
3608.00 3326.83 N 727.11W
3672.00 3354.53 N 732.20W
3711.00 3370.08 N 735.07W
3756.00 3386.82 N 738.18W
3832.00 3414.02 N 743.25W
3947.00 3455.16 N 750.92W
4042.00 3489.15 N 757.26W
Formation Name
Base Permafrost
K-15 Sand
Top Ugnu Sands
K-13 Shale
West Sak D
West Sak B
West Sak A4
West Sak A3
West Sak A2
West Sak A1
Base West Sak
Continued...
7 November, 2000 - 15:53 - 9 - DrillQuest 2.00.05
*or oa
North Slope Alaska
Sperry-Sun Drilling Services
Proposal Report for PLAN: 1D-101 WPs - 1D-101 Wp7
Revised: 7 November, 2000
Alaska State Plane 4
Kuparuk 1D
Casing details
From To
Measured Vertical Measured Vertical
Depth Depth Depth Depth
(ft) (ft) (ft) (ft)
<Sudace> <Sudace>
<Sudace> <Sudace>
500.00 500.00
6138.06 4283.25
Casing Detail
10 3/4" Casing
5 1/2" X 3 1/2" Liner
Targets associated with this wellpath
Target
Name
Injec~r16 SE-edge
Injector 16 T1
Mean Sea Level/Global Coordinates:
Geographical Coordinates:
Target Radius:
Mean Sea Level/Global Coordinates:
Geographical Coordinates:
Target Radius:
Target Entry Coordinates
TVD Northings Eastings
(ft) (ft) (ft)
3857.00
3756.00
150.00ff
3857.00
3756.00
300.00ff
3386.82 N 738.18W
5963240.00 N 559725.00 E
70°18'36.5413"N 149°30'57.7865"W
3386.82 N 738.18W
5963240.00 N 559725.00 E
70°18'36.5413"N 149° 30'57.7864"W
Target
Shape
Circle
Circle
Target
Type
7 November, 2000-15:53 - 10- DrillQuest 2.00.05
American Express', c~h A~l'v-anc~ Dz'~.~l= 190
~u~ by Inked ~y~n~ S~ In~
~~, ~o ~OT VALID FO~ A~OUN~ O~E~ $ I ~
·
WELL PERMIT CHECKLIST COMPANY ~///~ ~-~ WELL NAME /~:> -/~ / PROGRAM: exp dev
FIELD & POOL V~)/~--~ INIT CLASS~y ~ ~;t~u"/~__. ./~//"1/"-JGEOL AREA
ADMINISTRATION
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 ddlling unit boundary ....
6. Well located proper distance from other wells ..........
7. Sufficient acreage available in drilling unit ............
8. If deviated, is wellbore plat included ...............
9. Operator only affected party ...................
10. Operator has appropriate bond in force .............
11. Permit can be issued without conservation order ........
12. Permit can be issued without administrative approval ......
13. Can permit be approved before 15-day wait ...........
ENGINEERING
DATE
14. Conductor string provided ...................
15. Surface casing protects all known USDWs ...........
16. CMT vol adequate to circulate on conductor & surf csg .....
17. CMT vol adequate to tie-in long string to surf csg ........
18. CMT will cover all known productive horizons ..........
19. Casing designs adequate for C, T, B & permafrost .......
20. Adequate tankage or reserve pit .................
21. If a re-drill, has a 10-403 for abandonment been approved...
22. Adequate wellbore separation proposed .............
23. If diverter required, does it meet regulations ..........
24. Drilling fluid program schematic & equip list adequate .....
25. BOPEs, do they meet regulation ................
26. BOPE press rating appropriate; test to ~,~(3L~ psig.
27. Choke manifold complies w/APl RP-53 (May 84) ........
28. Work will occur without operation shutdown ...........
29. Is presence of H2S gas probable ............. . .....
redrll
serv u/ wellbore seg
GEOLOGY
30.
31.
32.
33.
34.
ANNULAR DISPOSAL35. With proper cementing records, this plan
(A) will contain waste in a suitable receiving zonei .......
APPR DATE (B) will not contaminate freshwater; or cause drilling waste...
to surface;
(C) will not impair mechanical integrity of the well used for disposal;
(D) will not damage producing formation or impair recovery from a
pool; and
(E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412.
ann. disposal para req
UNIT# ~)///~=~)
ON/OFF SHORE
Permit can be issued wlo hydrogen sulfide measures ..... y
Data presented on potential overpressure zones ......
Seismic analysis of shallow gas zones; .......... ~./~ ~ Y N
~ Y N
Seabed ~ndition suwey (if off-shorn) ..... ~ .
Conta~ name/phone for weekly progress re~ [~plomto~ only] Y N
Y N
YY NN / ~- k ~~.
Commentsllnstructions:
GEOLOGY.' ENGINEERING: UIG/A~ular COMMISSION:
0
Z
0
,("
c:Vnsoffice\wOrdianMiana\checklist (rev. 11101fl00)
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 APPEN. DIXi
..
No 'special'effort has been made to chronologically
organize this category of information.
Sperry-Sun Drilling Services
LIS Scan Utility
SRevision: 3 $
LisLib SRevision: 4 $
Wed Sep 26 08:15:16 2001
Reel Header
Service name ............. LISTPE
Date ..................... 01/09/26
Origin ................... STS
Reel Name ................ UNKNOWN
Continuation Number ...... 01
Previous Reel Name ....... UNKNOWN
Comments ................. STS LIS Writing Library. Scientific Technical Services
Tape Header
Service name ............. LISTPE
Date ..................... 01/09/26
Origin ................... STS
Tape Name ................ UNKNOWN
Continuation Number ...... 01
Previous Tape Name ....... UNKNOWN
Comments ................. STS LIS Writing Library. Scientific Technical Services
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:
1D-101
500292298600
Phillips Alaska, Inc.
Sperry-Sun Drilling Services
25-SEP-01
MW/) RUN 1 MWD RUN 2 MWD RUN 3
AK-MM-00273 AK-MM-00273 AK-MM-00273
A. WEAVER A. WEAVER A. WEAVER
D. WESTER D. HIEM D. HIEM
JOB NUMBER:
LOGGING ENGINEER:
OPERATOR WITNESS:
SURFACE LOCATION
SECTION:
TOWNSHIP:
RANGE:
FNL:
FSL:
FEL:
FWL:
ELEVATION (FT FROM MSL 0)
KELLY BUSHING:
DERRICK FLOOR:
GROUND LEVEL:
MWD RUN 99
AK-MM-00273
A. WEAVER
D. HIEM
14
lin
10E
192
594
.00
100.94
70.70
WELL CASING RECORD
1ST STRING
2ND STRING
3RD STRING
PRODUCTION STRING
REMARKS:
OPEN HOLE CASING DRILLERS
BIT SIZE (IN) SIZE (IN) DEPTH (FT)
7.875 10.750 505.0
1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE
NOTED.
2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD).
3. MWD RUNS 1, 2, AND 3 ARE DIRECTIONAL WITH DUAL GAMMA
RAY (DGR) UTILIZING
GEIGER-MUELLER TUBE DETECTORS AND ELECTROMAGNETIC
WAVE RESISTIVITY
PHASE-4 (EWR4).
4. VERTICAL RESISTIVITY INVERSION (VRI) DATA ARE
PRESENTED AS A DEEP PHASE
ENHANCED CURVE (RDVR) IN MWD MERGED DATA; AND AS 4
ENHANCED CURVES AND
4 MODELLED CURVES IN THE FINAL RAW INDIVIDUAL MWD
FILE (RUN 99).
5. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED PER
E-MAIL FROM D.
SCHWARTZ, PHILLIPS ALASKA, INC., DATED 1/30/01. MWD
DATA ARE CONSIDERED
PDC.
6. MWD RUNS 1, 2, AND 3 REPRESENT WELL 1D-101 WITH
API$: 50-029-22986-00.
THIS WELL REACHED A TOTAL DEPTH (TD) OF
6100'MD/4253.73'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.
MEXP = FORWARD-MODELED EXTRA SHALLOW PHASE RESISTIVITY.
MESP = FORWARD-MODELED SHALLOW PHASE RESISTIVITY.
MEMP = FORWARD-MODELED MEDIUM PHASE RESISTIVITY.
MEDP = FORWARD-MODELED DEEP PHASE RESISTIVITY.
VEXP = INVERSION-DERIVED EXTRA SHALLOW PHASE RESITIVITY
(ENHANCED).
VESP = INVERSION-DERIVED SHALLOW PHASE RESITIVITY
(ENHANCED).
VEMP = INVERSION-DERIVED MEDIUM PHASE RESITIVITY
(ENHANCED).
VEDP = INVERSION-DERIVED DEEP PHASE RESITIVITY
(ENHANCED).
File Header
Service name ............. STSLIB.001
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 01/09/26
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 START DEPTH
GR 475.5
FET 495.5
RPD 495.5
RPM 495.5
RPS 495.5
RPX 495.5
ROP 520.0
RDVR 4800.5
$
BASELINE CURVE FOR SHIFTS:
CURVE SHIFT DATA (MEASURED DEPTH)
BASELINE DEPTH
$
MERGED DATA SOURCE
PBU TOOL CODE
MWD
MWD
$
REMARKS:
STOP DEPTH
6050.5
6057.5
6057.5
6057.5
6057.5
6057.5
6099.5
6057.0
EQUIVALENT UNSHIFTED DEPTH
BIT RUN NO MERGE TOP MERGE BASE
1 475.5 1800.5
2 1800.5 3986.0
3 3986.0 6099.5
99 4800.5 6057.0
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
Depth Units .......................
Datum Specification Block sub-type...0
Name Service Order
Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1
ROP MWD FT/H 4 1 68 4 2
GR MWD API 4 1 68 8 3
RPX MWD OHMM 4 1 68 12 4
RPS MWD OHMM 4 1 68 16 5
RPM MWD OHMM 4 1 68 20 6
RPD MWD OHMM 4 1 68 24 7
FET MWD HOUR 4 1 68
RDVR MWD OHMM 4 1 68
28
32
Name Service Unit Min Max
DEPT FT 475.5 6099.5
ROP MWD FT/H 0.31 578.28
GR MWD API 13.93 127.09
RPX MWD OHMM 0.49 279.59
RPS MWD OHMM 0.67 1803.29
RPM MWD OHMM 0.32 2000
RPD MWD OHMM 0.58 2000
FET MWD HOUR 0.17 10.9
RDVR MWD OHMM 1.381 202.471
Mean Nsam
3287.5 11249
121.892 11160
67.2995 11151
24.8863 11125
37.0537 11125
58.3097 11125
74.5511 11125
0.633181 11125
10.0872 2514
First
Reading
475.5
520
475.5
495.5
495.5
495.5
495.5
495.5
4800.5
Last
Reading
6099 5
6099 5
6050 5
6057 5
6057 5
6057 5
6057 5
6057 5
6057
First Reading For Entire File .......... 475.5
Last Reading For Entire File ........... 6099.5
File Trailer
Service name ............. STSLIB.001
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 01/09/26
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 ....... 01/09/26
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
GR 475.5
RPS 495.5
RPX 495.5
RPM 495.5
RPD 495.5
FET 495.5
ROP 520.0
$
LOG HEADER DATA DATE LOGGED:
STOP DEPTH
1757.0
1764.0
1764.0
1764.0
1764.0
1764.0
1800.5
21-NOV-00
SOFTWARE
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME):
TD DRILLER (FT):
TOP LOG INTERVAL (FT):
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
Depth Units .......................
Datum Specification Block sub-type...0
Insite
4.15
Memory
1800.0
4.3
36.2
TOOL NUMBER
PB01724FGR4
PB01724FGR4
7.875
LSND
9.40
124.0
9.2
400
5.8
2.900
2.070
1.900
3.770
64.0
92.4
64.0
64.0
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1
ROP MWD010 FT/H 4 1 68 4 2
GR MWD010 API 4 1 68 8 3
RPX MWD010 OHMM 4 1 68 12 4
RPS MWD010 OHMM 4 1 68 16 5
RPM MWD010 OHMM 4 1 68 20 6
RPD MWD010 OHMM 4 1 68
FET MWD010 HOUR 4 1 68
24
28
Name Service Unit Min Max
DEPT FT 475.5 1800.5
ROP MWD010 FT/H 0.31 578.28
GR MWD010 API 19.99 117.35
RPX MWD010 OHMM 0.49 279.59
RPS MWD010 OHMM 0.67 1585.04
RPM MWD010 OHMM 0.99 2000
RPD MWD010 OHMM 1.38 2000
FET MWD010 HOUR 0.26 1.25
Mean
1138
110.631
65.8608
57.0817
89.6919
144.487
185.563
0.508633
Nsam
2651
2562
2564
2538
2538
2538
2538
2538
First
Reading
475.5
520
475.5
495.5
495.5
495.5
495.5
495.5
Last
Reading
1800.5
1800.5
1757
1764
1764
1764
1764
1764
First Reading For Entire File .......... 475.5
Last Reading For Entire File ........... 1800.5
File Trailer
Service name ............. STSLIB.002
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 01/09/26
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 ....... 01/09/26
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
GR
RPS
RPM
FET
RPX
RPD
ROP
$
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
START DEPTH STOP DEPTH
1757.5 3942.5
1764.5 3949.5
1764.5 3949.5
1764.5 3949.5
1764.5 3949.5
1764.5 3949.5
1801.0 3986.0
23-NOV-00
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME):
TD DRILLER (FT):
TOP LOG INTERVAL (FT):
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
Depth Units .......................
Datum Specification Block sub-type...0
Insite
4.15
Memory
3986.0
36.7
68.4
TOOL NUMBER
PB01724FGR4
PB01724FGR4
7.875
LSND
9.40
81.0
9.0
350
4.8
3.400
2.200
2.300
4.400
62.0
99.5
62.0
62.0
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1
ROP MWD020 FT/H 4 1 68 4 2
GR MWD020 API 4 1 68 8 3
RPX MWD020 OHMM 4 1 68 12 4
RPS MWD020 OHMM 4 1 68 16 5
RPM MWD020 OHMM 4 1 68 20 6
RPD MWD020 OHMM 4 1 68 24 7
FET MWD020 HOUR 4 1 68
28
Name Service Unit Min Max
DEPT FT 1757.5 3986
ROP MWD020 FT/H 9.06 404.9
GR MWD020 API 13.93 116.06
RPX MWD020 OHMM 1.92 272.53
RPS MWD020 OHMM 0.74 1803.29
RPM MWD020 OHMM 0.32 2000
RPD MWD020 OHMM 0.58 2000
FET MWD020 HOUR 0.17 5.09
Mean
2871.75
136.229
64.695
22.1805
33.7867
56.0017
73.1623
0.505534
Nsam
4458
4371
4371
4371
4371
4371
4371
4371
First
Reading
1757.5
1801
1757.5
1764.5
1764.5
1764.5
1764.5
1764.5
Last
Reading
3986
3986
3942 5
3949 5
3949 5
3949 5
3949 5
3949 5
First Reading For Entire File .......... 1757.5
Last Reading For Entire File ........... 3986
File Trailer
Service name ............. STSLIB.003
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 01/09/26
Maximum Physical Record..65535
File Type ................ LO
Next File Name ........... STSLIB.004
Physical EOF
File Header
Service name ............. STSLIB.004
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 01/09/26
Maximum Physical Record..65535
File Type ................ LO
Previous File Name ....... STSLIB.003
Comment Record
FILE HEADER
FILE NUMBER: 4
RAW MWD
Curves and log header data for each bit run in separate files.
BIT RUN NUMBER: 3
DEPTH INCREMENT: .5000
FILE SUMMARY
VENDOR TOOL CODE START DEPTH STOP DEPTH
GR 3943 . 0 6050.5
RPD 3950.0 6057 . 5
RPM 3950 . 0 6057 . 5
RPS 3950.0 6057 . 5
RPX 3950.0 6057.5
FET 3950.0 6057 . 5
ROP 3986.5 6099 . 5
$
LOG HEADER DATA
DATE LOGGED: 24 -NOV- 00
SOFTWARE
SURFACE SOFTWARE VERSION: Insite
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME):
TD DRILLER (FT):
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT):
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
MINIMTJMANGLE:
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
Depth Units .......................
Datum Specification Block sub-type...0
4.15
Memory
6100.0
18.9
65.8
TOOL NUMBER
PB01724FGR4
PB01724FGR4
7.875
LSND
9.40
82.0
9.0
1000
3.8
2.850
1.860
3.300
2.800
65.0
103.4
65.0
65.0
Name Service Order
Units Size Nsam Rep Code Offset
DEPT FT 4 1 68 0
ROP MWD030 FT/H 4 1 68 4
GR MWD030 API 4 1 68 8
RPX MWD030 OHMM 4 1 68 12
RPS MWD030 OHMM 4 1 68 16
RPM MWD030 OHMM 4 1 68 20
RPD MWD030 OHMM 4 1 68 24
FET MWD030 HOUR 4 1 68 28
Channel
1
2
3
4
5
6
7
8
Name Service Unit Min Max
DEPT FT 3943 6099.5
ROP MWD030 FT/H 5.99 267.84
GR MWD030 API 24.94 127.09
RPX MWD030 OHMM 1.89 70.63
RPS MWD030 OHMM 1.92 92.63
RPM MWD030 OHMM 1.91 83.21
RPD MWD030 OHMM 2.08 92.95
FET MWD030 HOUR 0.25 10.9
Mean
5021.25
113.892
70.8748
8.3102
8.75299
8.82446
9.16225
0.840498
Nsam
4314
4227
4216
4216
4216
4216
4216
4216
First
Reading
3943
3986.5
3943
3950
3950
3950
3950
3950
Last
Reading
6099.5
6099.5
6050.5
6057.5
6057.5
6057.5
6057.5
6057.5
First Reading For Entire File .......... 3943
Last Reading For Entire File ........... 6099.5
File Trailer
Service name ............. STSLIB.004
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 01/09/26
Maximum Physical Record..65535
File Type ................ LO
Next File Name ........... STSLIB.005
Physical EOF
File Header
Service name ............. STSLIB.005
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 01/09/26
Maximum Physical Record..65535
File Type ................ LO
Previous File Name ....... STSLIB.004
Comment Record
FILE HEADER
FILE NUI~BER: 5
RAW MWD
Curves and log header data for each bit run in separate files.
BIT RUN NUMBER: 99
DEPTH INCREMENT: .5000
FILE SUMMARY
VENDOR TOOL CODE START DEPTH STOP DEPTH
VESP ,4800.5 6057 . 0
VEXP 4800 . 5 6057 . 0
VEMP 4800.5 6057 . 0
VEDP 4800.5 6057.0
MEXP 4800.5 6057.0
MESP 4800.5 6057 . 0
MEMP 4800 . 5 6057 . 0
MEDP 4800.5 6057.0
$
LOG HEADER DATA
DATE LOGGED: 24 -NOV- 00
SOFTWARE
SURFACE SOFTWARE VERSION: Insit'e
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME):
TD DRILLER (FT):
TOP LOG INTERVAL (FT):
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
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
Depth Units .......................
Datum Specification Block sub-type...0
4.15
Computed
6100.0
18.9
65.8
TOOL NUMBER
PB01724FGR4
7.875
LSND
9.40
82.0
9.0
1000
3.8
2.850
1.860
3.300
2.800
65.0
103.4
65.0
65.0
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1
VEXP MWD099 OHMM 4 1 68 4 2
VESP MWD099 OHMM 4 1 68 8 3
VEMP MWD099 OHMM 4 1 68 12 4
VEDP MWD099 OHMM 4 1 68 16 5
MEXP MWD099 OHMM 4 1 68 20 6
MESP MWD099 OHMM 4 1 68 24 7
MEMP MWD099 OHMM 4 1 68 28 8
MEDP MWD099 OHMM 4 1 68 32 9
Name Service Unit Min Max
DEPT FT 4800.5 6057
VEXP MWD099 OHMM 1.384 103.861
VESP MWD099 OHMM 1.402 170.035
VEMP MWD099 OHMM 1.372 184.015
VEDP MWD099 OHMM 1.381 202.471
MEXP MWD099 OHMM 1.862 67.702
MESP MWD099 OHMM 1.923 85.386
MEMP MWD099 OHMM 1.842 89.091
MEDP MWD099 OHMM 1.962 99.055
First Last
Mean Nsam Reading Reading
5428.75 2514 4800.5 6057
8.62461 2514 4800.5 6057
9.36731 2514 4800.5 6057
9.54079 2514 4800.5 6057
10.0872 2514 4800.5 6057
8.24529 2514 4800.5 6057
8.74938 2514 4800.5 6057
8.76309 2514 4800.5 6057
9.10512 2514 4800.5 6057
First Reading For Entire File .......... 4800.5
Last Reading For Entire File ........... 6057
File Trailer
Service name ............. STSLIB.005
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 01/09/26
Maximum Physical Record..65535
File Type ................ LO
Next File Name ........... STSLIB.006
Physical EOF
Tape Trailer
Service name ............. LISTPE
Date ..................... 01/09/26
Origin ................... STS
Tape Name ................ UNKNOWN
Continuation Number ...... 01
Next Tape Name ........... UNKNOWN
Comments ................. STS LIS Writing Library.
Reel Trailer
Service name ............. LISTPE
Date ..................... 01/09/26
Origin ................... STS
Reel Name ................ UNKNOWN
Continuation Number ...... 01
Next Reel Name ........... UNKNOWN
Comments ................. STS LIS Writing Library.
Scientific Technical Services
Scientific Technical Services
Physical EOF
Physical EOF
End Of LIS File
