Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout202-008MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Jim Regg DATE:
P.I. Supervisor
SUBJECT:
FROM:
Petroleum Inspector
Section:17 Township:8N Range:7E Meridian:Umiat
Drilling Rig:Rig Elevation:Total Depth:5950 ft MD Lease No.:ADL0373112
Operator Rep:Suspend:P&A:X
Conductor:16"O.D. Shoe@ 120 Feet Csg Cut@ Feet
Surface:7 5/8"O.D. Shoe@ 2236 Feet Csg Cut@ Feet
Intermediate:O.D. Shoe@ Feet Csg Cut@ Feet
Production:5.5"x3.5"O.D. Shoe@ 5927 Feet Csg Cut@ Feet
Liner:O.D. Shoe@ Feet Csg Cut@ Feet
Kill String:3.5"O.D. Tail@ 5416 Feet Tbg Cut@ 2670 Feet
Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified
Fullbore Bridge plug 2302 ft 1952 ft 15.8 ppg Wireline tag
Initial 15 min 30 min 45 min Result
Tubing
IA 1680 1600 1560
OA 1750 1680 1650
Initial 15 min 30 min 45 min Result
Tubing
IA
OA
Remarks:
Attachments:
John Hansen
Casing/Tubing Data (depths are MD):
Plugging Data (depths are MD):
Halliburton wireline tagged cement at 1916 ft MD. With the wireline correction of 36 ft that put cement at 1952 ft MD. The
toolstring was approximately 250 pounds with a 1.75-inch x 4-ft drive down bailer fitted with a mule shoe with a flapper valve.
The bailer sample showed good cured cement. The cement tag was performed on 10/16/2025 and the MIT was performed on
10/17/2025. This was due to lack of information provided at the jobsite regarding what was in the well and what we were testing
against in regards to the MIT. 0.7 bbls in and out for the MIT.
October 17, 2025
Guy Cook
Well Bore Plug & Abandonment
KRU 2P-451
ConocoPhillips Alaska Inc.
PTD 2020080; Sundry 325-522
None
Test Data:
P
Casing Removal:
rev. 3-24-2022 2025-1017_Plug_Verification_KRU_2P-451_gc
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: Extend Exp Date
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?
Yes No
9. Property Designation (Lease Number): 10. Field:
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD):
5950'None
Casing Collapse
Structural
Conductor
Surface
Intermediate
Production
Kill String
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 Exploratory Stratigraphic Development Service
14. Estimated Date for 15. Well Status after proposed work:
Commencing Operations: OIL WINJ WDSPL Suspended
16. Verbal Approval: GAS WAG GSTOR SPLUG
AOGCC Representative: GINJ Op Shutdown Abandoned
Contact Name:
Contact Email:
Contact Phone:
Authorized Title:
Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number:
Plug Integrity BOP Test Mechanical Integrity Test Location Clearance
Other Conditions of Approval:
Post Initial Injection MIT Req'd? Yes No
APPROVED BY
Approved by: COMMISSIONER THE AOGCC Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
BOP Sketch
9/30/2025
Date:
1900'
3-1/2"
1844'
Packer: Baker GBH-22 Locator/Seal Assy
SSSV: None
Perforation Depth MD (ft):
L-80
2205'
5515-5550', 5562-5578' (below
cement plug)
5900'
5-1/2"
5320-5355', 5367-5383'
(below cement plug)
5-1/2" x 3-1/2"
Perforation Depth TVD (ft):
120'
2236'
5732'5927'
16"
7-5/8"
88'
5416'
MD
120'
2160'
ConocoPhillips Alaska, Inc.
Length Size
Proposed Pools:
PRESENT WELL CONDITION SUMMARY
Meltwater Oil Pool -
Abandoned
TVD Burst
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL0373112
202-008
P.O. Box 100360, Anchorage, AK 99510 50-103-20402-00-00
Kuparuk River Field Meltwater Oil Pool - Suspended
AOGCC USE ONLY
Tubing Grade: Tubing MD (ft):
5413' MD and 5218' TVD
N/A
Jill Simek
Subsequent Form Required:
Suspension Expiration Date:
Will perfs require a spacing exception due to property boundaries?
Current Pools:
MPSP (psi): Plugs (MD):
17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval.
Authorized Name and
Digital Signature with Date:
Tubing Size:
Jill.Simek@conocophillips.com
(907) 263-4131
Staff Interventions Engineer
KRU 2P-451
5755' 2235' 2159'
2252', 2302', 3785',
5432', 5499'
N/A
Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
By Grace Christianson at 4:09 pm, Aug 27, 2025
Jill Simek Digitally signed by Jill Simek
Date: 2025.08.27 14:57:14
-08'00'
325-522
10-407
12/31/2025
X X
VTL 9/3/2025
No further extensions will be approved.
All conditions on original approved sundry apply.
DSR-9/10/25TS 9/10/25JLC 9/10/2025
Gregory C Wilson Digitally signed by Gregory C
Wilson
Date: 2025.09.11 08:46:26 -08'00'09/11/25
RBDMS JSB 091125
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
Commissioner, State of Alaska August 26, 2025
Alaska Oil & Gas Conservation Commission
333 West 7th Avenue Suite 100
Anchorage, Alaska 99501
Dear Commissioner:
Please find the attached 10-403 Application for Sundry Approval for
ConocoPhillips Alaska, Inc. well KRU 2P-451 (PTD# 202-008). We are
requesting to extend the Suspension Expiration Date to December 31, 2025, to
finish the P&A.
If you have any questions, please contact me at 263-4131.
Sincerely,
Jill Simek
Staff Well Interventions Engineer
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag: RKB 2,223.0 2P-451 6/28/2025 rogerba
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Milled/Underreamed Cement to 2253'. 2P-451 8/6/2025 famaj
Notes: General & Safety
Annotation End Date Last Mod By
NOTE: ZONES NOT LOADED INTO WELLVIEW YET 7/29/2009 triplwj
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 32.0 120.0 120.0 62.60 WELDED
SURFACE 7 5/8 6.87 31.5 2,236.2 2,159.7 29.70 L-80 BTCMOD
Kill String 5 1/2 4.95 26.7 1,900.0 1,843.8 15.50 L-80 BTCMOD
PRODUCTION
5.5"x3.5" @ 5439'
5 1/2 4.95 26.7 5,927.0 5,732.2 15.50 L-80 BTCMOD
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
26.6
Set Depth …
5,415.7
Set Depth …
5,221.1
String Max No…
3 1/2
Tubing Description
TUBING
Wt (lb/ft)
9.30
Grade
L-80
Top Connection
EUEM
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)
26.6 26.6 0.00 HANGER 8.000 FMC TUBING HANGER 3.500
496.3 495.9 5.54 NIPPLE 4.520 CAMCO DS NIPPLE CAMCO DS 2.875
5,302.7 5,108.1 1.56 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900
5,352.6 5,158.0 1.47 SLEEVE-C 4.500 BAKER CMU SLIDING SLEEVE BAKER CMU 2.813
5,368.6 5,174.0 1.46 NIPPLE 4.520 CAMCO D NIPPLE CAMCO D 2.750
5,413.0 5,218.3 1.42 SEAL 4.500 BAKER GBH-22 LOCATOR/SEAL
ASSY LANDED w/NO GO 2' OFF
PROD CSG LOCATOR @ 5419'
BAKER GBH-22 2.990
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)
2,302.0 2,221.9 19.07 CIBP CIBP set 2302' top, tested
1000 psi good test
10/30/2024 0.000
2,670.0 2,568.5 20.54 CUT 2.5" JET TUBING CUT 9/5/2024 2.992
5,318.0 5,123.4 1.52 TUBING
PUNCH
TUBING PUNCH, 3FT @ 6
SPF, 0 DEGREE PHASE.
8/6/2024 2.992
5,499.3 5,304.6 1.19 CIBP CIBP MID-ELEMENT AT 5500'
RKB, OAL = 1.37'
7/1/2024 0.000
5,800.1 5,605.4 1.13 Plug Catcher PLUG CATCHER SET IN 3.5"
PRODUCTION CASING
3/2/2002 0.000
Mandrel Inserts : excludes pulled inserts
Top (ftKB)
Top (TVD)
(ftKB)
Top
Incl (°)
St
ati
on
No
/S Serv
Valve
Type
Latch
Type
OD
(in)
TRO Run
(psi) Run Date Com Make Model
Port
Size (in)
5,302.7 5,108.1 1.56 1 GAS LIFT OPEN 1 9/4/2021
Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal ID
(in)
29.4 29.4 0.00 PRODUCTION 5.500 4.950
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
5,515.0 5,535.0 5,320.3 5,340.3 T-3, 2P-451 10/19/2020 6.0 APERF 2.5" Millenium 6 SPF 60°
Phase
5,535.0 5,550.0 5,340.3 5,355.3 T-3, 2P-451 10/19/2020 6.0 APERF 2.5" Millenium 6 SPF 60°
Phase
5,562.0 5,578.0 5,367.3 5,383.3 T-3, 2P-451 3/24/2002 6.0 IPERF 2.5" HSD 2506 Chgs, 60 deg
phase
Stimulation Intervals
Top (ftKB) Btm (ftKB)
Inter
val
Num
ber Type Subtype Start Date
Proppant
Designed (lb)
Proppant
Total (lb)
Vol Clean
Total (bbl)
Vol Slurry
Total (bbl)
5,562.0 5,578.0 1 FRAC 3/29/2002 0.0 0.00 0.00
Cement Squeezes
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Des Com
Pump Start
Date
5,432.0 5,499.3 5,237.3 5,304.6 Cement Plug Dump bailed cement 7/6/2024
5,432.0 5,499.3 5,237.3 5,304.7 Stage
Cementing
PUMPED 31 BBLS OF 15.8 CLASS G CEMENT
FOR INTERMEDIATE BALANCED PLUG
8/23/2024
2,235.0 2,302.0 2,158.6 2,221.9 Cement Plug Pump 12.4 bbls 15.8# Class G cement for ballanced
plug, wait required 11.5 hrs for cement to set up,
attempt to tag @ 11pm could not find good cement,
5K set down @ 2235'
MILLED OUT TO 2252' RKB, BY CTU 4
11/3/2024
2,223.0 2,252.0 2,147.3 2,174.7 Plug – Plug
Back /
Abandonment
Plug
Pumped 24 bbls of 15.8 ppg Premium cement w/
IsoGuard & MicroBond
6/1/2025
2P-451, 8/27/2025 9:46:41 AM
Vertical schematic (actual)
PRODUCTION 5.5"x3.5" @
5439'; 2,295.0-5,927.0
Plug Catcher; 5,800.1
IPERF; 5,562.0-5,578.0
FRAC; 5,562.0
APERF; 5,535.0-5,550.0
APERF; 5,515.0-5,535.0
CIBP; 5,499.3
Stage Cementing; 5,432.0 ftKB
Cement Plug; 5,432.0 ftKB
TUBING PUNCH; 5,318.0
GAS LIFT; 5,302.7
CUT; 2,670.0
CIBP; 2,302.0
Cement Plug; 2,252.0 ftKB
SURFACE; 31.5-2,236.2
Kill String ; 26.7-1,900.0
CONDUCTOR; 32.0-120.0
KUP PROD
KB-Grd (ft) RR Date
3/5/2002
Other Elev…
2P-451
...
TD
Act Btm (ftKB)
5,950.0
Well Attributes
Field Name
MELTWATER
Wellbore API/UWI
501032040200
Wellbore Status
PROD
Max Angle & MD
Incl (°)
21.46
MD (ftKB)
2,866.47
WELLNAME WELLBORE2P-451
Annotation
Last WO:
End DateH2S (ppm)
67
Date
12/21/2013
Comment
SSSV: NIPPLE
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Jim Regg DATE:
P.I. Supervisor
SUBJECT:
FROM:
Petroleum Inspector
Section: 17 Township: 8N Range: 7E Meridian: Umiat
Drilling Rig: N/A Rig Elevation: N/A Total Depth: 5950 ft MD Lease No.: ADL0373112
Operator Rep: Suspend: P & A X
Conductor: 16" O.D. Shoe@ 120 Feet Csg Cut@ Feet
Surface: 7-5/8" O.D. Shoe@ 2236 Feet Csg Cut@ Feet
Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet
Production: 5-1/2 x 3-1/2" O.D. Shoe@ 5927 Feet Csg Cut@ 2295 Feet
Liner: O.D. Shoe@ Feet Csg Cut@ Feet
Tubing: 3-1/2" O.D. Tail@ 5416 Feet Tbg Cut@ 2670 Feet
Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified
Surface Other 2252 ft 2223 ft 6.8 ppg Wireline tag
Initial 15 min 30 min 45 min Result
Tubing
IA
OA 1675 1575 1475
Initial 15 min 30 min 45 min Result
Tubing
IA
OA
Remarks:
Attachments:
Tubing and production strings have been pulled and all testing was done against casing. Same pressure loss every 15 minute
test interval (100 psi). Not enough cement. Plug was set on top of previous plug.
June 28, 2025
Bob Noble
Well Bore Plug & Abandonment
KRU 2P-451
ConocoPhillips Alaska Inc.
PTD 2020080; Sundry 325-240
none
Test Data:
F
Casing Removal:
Brent Rodgers
Casing/Tubing Data (depths are MD):
Plugging Data (depths are MD):
rev. 3-24-2022 2025-0628_Plug_Verification_KRU_2P-451_bn
9
9
9
9
9
9
999
9
9
9
9
9
9
9 9 9
9
9
gg
Plug was set on top of previous plug.
James B. Regg Digitally signed by James B. Regg
Date: 2025.08.27 13:26:52 -08'00'
C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\4MY18Q6V\2024-08-06_23088_KRU_2P-451_CaliperSurvey_LogData_Transmittal.docx
DELIVERABLE DISCRIPTION
Ticket # Field Well # API # Log Description Log Date
23088 KRU 2P-451 50-103-20402-00 Caliper Survey w// Log Data 06-Aug-25
DELIVERED TO
Company & Address
DIGITAL FILE
# of Copies
LOG PRINTS
# of Prints
CD’s
# of Copies
1
AOGCC
Attn: Natural Resources Technician
333 W. 7th Ave., Suite 100
Anchorage, Ak. 99501-3539
Delivered By: CPAI Sharefile
______________________________ _____________________________________
Date received Signature
______________________________ ______________________________________
PLEASE RETURN COPY VIA EMAIL TO:
DIANE.WILLIAMS@READCASEDHOLE.COM
READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503
PHONE: (907)245-8951
E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM
202-008
T40759
8/8/2025
Gavin
Gluyas
Digitally signed by
Gavin Gluyas
Date: 2025.08.08
11:23:36 -08'00'
CAUTION: This email originated from outside the State of Alaska mail system. Do not
click links or open attachments unless you recognize the sender and know the content
is safe.
From:Loepp, Victoria T (OGC)
To:Simek, Jill
Cc:Lau, Jack J (OGC); AOGCC Records (CED sponsored)
Subject:RE: 2P-451 P&A Next Steps (PTD#202-008/ Sundry #325-240)APPROVAL
Date:Monday, July 21, 2025 9:57:50 AM
Jill,
Approval is granted to mill the failed cement plug and replace with a new plug as outlined below.
Victoria
Victoria Loepp
Senior Petroleum Engineer
Alaska Oil & Gas Conservation Commission
Work: (907)793-1247
From: Simek, Jill <Jill.Simek@conocophillips.com>
Sent: Thursday, July 17, 2025 10:49 AM
To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>
Cc: Lau, Jack J (OGC) <jack.lau@alaska.gov>
Subject: 2P-451 P&A Next Steps (PTD#202-008/ Sundry #325-240)
Victoria,
On 5/31/25 the cement squeeze job was performed on 2P-451, per approved Sundry
procedure (see attached). Unfortunately, this cement plug did not pass a pressure test. The
plan forward is to mill out the failed cement plug and replace with a new plug (ie. repeat steps
1-4 on the sundry procedure). Once we get a passing (witnessed) pressure test, we will
continue with the remaining P&A steps.
Please let me know if this meets AOGCC approval.
Thanks,
Jill Simek
Well Interventions Engineer | ConocoPhillips Alaska
ATO-1400
M: 907-980-7503 / O: 907-263-4131
C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\BCJZ1PKL\30-May-252025-05-30_22648_KRU_2P-451_CaliperSurvey_LogData_Transmittal.docx
DELIVERABLE DISCRIPTION
Ticket # Field Well # API # Log Description Log Date
22648 KRU 2P-451 50-103-20402-00 Caliper Survey w/ Log Data 30-May-25
DELIVERED TO
Company & Address
DIGITAL FILE
# of Copies
LOG PRINTS
# of Prints
CD’s
# of Copies
1
AOGCC
Attn: Natural Resources Technician
333 W. 7th Ave., Suite 100
Anchorage, Ak. 99501-3539
Delivered By: CPAI Sharefile
______________________________ _____________________________________
Date received Signature
______________________________ ______________________________________
PLEASE RETURN COPY VIA EMAIL TO:
DIANE.WILLIAMS@READCASEDHOLE.COM
READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503
PHONE: (907)245-8951
E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM
202-008
T40527
6/4/2025
Gavin
Gluyas
Digitally signed by
Gavin Gluyas
Date: 2025.06.04
08:23:55 -08'00'
C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\BCJZ1PKL\2025-05-29_22222_KRU_2P-451_CaliperSurvey_LogData_Transmittal.docx
DELIVERABLE DISCRIPTION
Ticket # Field Well # API # Log Description Log Date
22222 KRU 2P-451 50-029-20402-00 Caliper Survey w/ Log Data 29-May-25
DELIVERED TO
Company & Address
DIGITAL FILE
# of Copies
LOG PRINTS
# of Prints
CD’s
# of Copies
1
AOGCC
Attn: Natural Resources Technician
333 W. 7th Ave., Suite 100
Anchorage, Ak. 99501-3539
Delivered By: CPAI Sharefile
______________________________ _____________________________________
Date received Signature
______________________________ ______________________________________
PLEASE RETURN COPY VIA EMAIL TO:
DIANE.WILLIAMS@READCASEDHOLE.COM
READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503
PHONE: (907)245-8951
E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM
202-008
T40523
6/3/2025
Gavin
Gluyas
Digitally signed
by Gavin Gluyas
Date: 2025.06.03
13:08:49 -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:
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?
Yes No
9. Property Designation (Lease Number): 10. Field:
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD):
5950'None
Casing Collapse
Structural
Conductor
Surface
Intermediate
Production
Kill String
Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft):
12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work:
Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service
14. Estimated Date for 15. Well Status after proposed work:
Commencing Operations: OIL WINJ WDSPL Suspended
16. Verbal Approval: Date: GAS WAG GSTOR SPLUG
AOGCC Representative: GINJ Op Shutdown Abandoned
Contact Name:
Contact Email:
Contact Phone:
Authorized Title:
Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number:
Plug Integrity BOP Test Mechanical Integrity Test Location Clearance
Other Conditions of Approval:
Post Initial Injection MIT Req'd? Yes No
APPROVED BY
Approved by: COMMISSIONER THE AOGCC Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
5/1/2025
1900'
3-1/2"
1844'
Packer: Baker GBH-22 Locator/Seal Assy
SSSV: None
Perforation Depth MD (ft):
L-80
2205'
5515-5550', 5562-5578' (below
cement plug)
5900'
5-1/2"
5320-5355', 5367-5383'
(below cement plug)
5-1/2" x 3-1/2"
Perforation Depth TVD (ft):
120'
2236'
5732'5927'
16"
7-5/8"
88'
5416'
MD
120'
2160'
ConocoPhillips Alaska, Inc.
Length Size
Proposed Pools:
PRESENT WELL CONDITION SUMMARY
Meltwater Oil Pool -
Abandoned
TVD Burst
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL0373112
202-008
P.O. Box 100360, Anchorage, AK 99510 50-103-20402-00-00
Kuparuk River Field Meltwater Oil Pool - Suspended
AOGCC USE ONLY
Tubing Grade: Tubing MD (ft):
5413' MD and 5218' TVD
N/A
Jill Simek
Subsequent Form Required:
Suspension Expiration Date:
Will perfs require a spacing exception due to property boundaries?
Current Pools:
MPSP (psi): Plugs (MD):
17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval.
Authorized Name and
Digital Signature with Date:
Tubing Size:
Jill.Simek@conocophillips.com
(907) 263-4131
Staff Interventions Engineer
KRU 2P-451
5755' 2235' 2159'
2235', 2302', 3785',
5432', 5499'
N/A
Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
By Grace Christianson at 12:52 pm, Apr 17, 2025
Jill Simek Digitally signed by Jill Simek
Date: 2025.04.17 09:40:30
-08'00'
325-240
9/30/2025
VTL 4/21/2025
X
10-407
DSR-4/17/25
X
SFD 4/21/2025*&:
Jessie L.
Chmielowski
Digitally signed by Jessie L.
Chmielowski
Date: 2025.04.22 10:38:03 -08'00'04/22/25
RBDMS JSB 042225
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a. A Variance is requested to 20 AAC 25.112(a)(1)(A) requiring cement 100’ below hydrocarbon bearing
zones. It is our intention to remove failed cement to ~50’ above existing CIBP, then to place ~300’ new
cement from TOC into the surface casing.
b. A Variance is requested to Order 196 requiring the cement to be logged. It is not our intention, nor
recommendation for the integrity of the abandonment, to mill out the cement plug once pumped.
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2P-451 P&A Schematic - Current
Conductor:
16" Conductor 120' KB
Production Casing Cement:
53 bbls of 15.8# Cement
Calculated TOC @ 2,936' KB
Production Casing:
5.5" x 3.5" @ 5,439' KB, 15.5# x 9.3#,
L-80 BTC Mod
Set @ 5,927’ KB
T-3 Peforations:
@ 5,515'– 5,578' KB (63')
Surface Casing:
7-5/8", 29.7#, L-80 BTC Mod
Set @ 2,236.2' KB (2159' TVD)
Production Tubing:
3 ½”, 9.3# L-80 EUE-8rd
Set @ 6,883.7' KB
6
5
C80 @ 2520' KB C80 @ 2520' KB
Plug #1 – Reservoir
TOC ±5432' RKB
Plug #2 – Intermediate
TOC ±3785' RKB
BOC @ ±5315' RKB
Surface Shoe Cement
TOC 2235' RKB (29' TVD)
BOC @ ±2302' RKB
Base of 5-½” Casing
used as kill string set at
1900' RKB
9.8 NaCl w/ freeze
protect
1
2
3
4
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2P-451 P&A Schematic - Proposed
Conductor:
16" Conductor 120' KB
Production Casing Cement:
53 bbls of 15.8# Cement
Calculated TOC @ 2,936' KB
Production Casing:
5.5" x 3.5" @ 5,439' KB, 15.5# x 9.3#,
L-80 BTC Mod
Set @ 5,927’ KB
T-3 Peforations:
@ 5,515'– 5,578' KB (63')
Surface Casing:
7-5/8", 29.7#, L-80 BTC Mod
Set @ 2,236.2' KB (2159' TVD)
Production Tubing:
3 ½”, 9.3# L-80 EUE-8rd
Set @ 6,883.7' KB
6
5
C80 @ 2520' KB C80 @ 2520' KB
Plug #1 – Reservoir
TOC ±5432' RKB
Plug #2 – Intermediate
TOC ±3785' RKB
BOC @ ±5315' RKB
Surface Shoe Cement
TOC milled to ~2252' RKB
BOC @ ±2302' RKB
5-½” Kill String set @
1900' RKB
Plug #4
TOC @ Surface
BOC ~1952' RKB
1
2
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Plug #3
TOC ~1952' RKB
BOC ~2252' RKB
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag: RKB 5,568.0 2P-451 6/16/2024 rogerba
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Pull 5.5" WRBP & Freeze protect well 2P-451 11/14/2024 claytg
Notes: General & Safety
Annotation End Date Last Mod By
NOTE: ZONES NOT LOADED INTO WELLVIEW YET 7/29/2009 triplwj
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 32.0 120.0 120.0 62.60 WELDED
SURFACE 7 5/8 6.87 31.5 2,236.2 2,159.7 29.70 L-80 BTCMOD
Kill String 5 1/2 4.95 26.7 1,900.0 1,843.8 15.50 L-80 BTCMOD
PRODUCTION
5.5"x3.5" @ 5439'
5 1/2 4.95 26.7 5,927.0 5,732.2 15.50 L-80 BTCMOD
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
26.6
Set Depth …
5,415.7
Set Depth …
5,221.1
String Max No…
3 1/2
Tubing Description
TUBING
Wt (lb/ft)
9.30
Grade
L-80
Top Connection
EUEM
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)
26.6 26.6 0.00 HANGER 8.000 FMC TUBING HANGER 3.500
496.3 495.9 5.54 NIPPLE 4.520 CAMCO DS NIPPLE CAMCO DS 2.875
5,302.7 5,108.1 1.56 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900
5,352.6 5,158.0 1.47 SLEEVE-C 4.500 BAKER CMU SLIDING SLEEVE BAKER CMU 2.813
5,368.6 5,174.0 1.46 NIPPLE 4.520 CAMCO D NIPPLE CAMCO D 2.750
5,413.0 5,218.3 1.42 SEAL 4.500 BAKER GBH-22 LOCATOR/SEAL
ASSY LANDED w/NO GO 2' OFF
PROD CSG LOCATOR @ 5419'
BAKER GBH-22 2.990
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)
2,302.0 2,221.9 19.07 CIBP CIBP set 2302' top, tested
1000 psi good test
10/30/2024 0.000
2,670.0 2,568.5 20.54 CUT 2.5" JET TUBING CUT 9/5/2024 2.992
5,318.0 5,123.4 1.52 TUBING
PUNCH
TUBING PUNCH, 3FT @ 6
SPF, 0 DEGREE PHASE.
8/6/2024 2.992
5,499.3 5,304.6 1.19 CIBP CIBP MID-ELEMENT AT 5500'
RKB, OAL = 1.37'
7/1/2024 0.000
5,800.1 5,605.4 1.13 Plug Catcher PLUG CATCHER SET IN 3.5"
PRODUCTION CASING
3/2/2002 0.000
Mandrel Inserts : excludes pulled inserts
Top (ftKB)
Top (TVD)
(ftKB)
Top
Incl (°)
St
ati
on
No
/S Serv
Valve
Type
Latch
Type
OD
(in)
TRO Run
(psi) Run Date Com Make Model
Port
Size (in)
5,302.7 5,108.1 1.56 1 GAS LIFT OPEN 1 9/4/2021
Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal ID
(in)
29.4 29.4 0.00 PRODUCTION 5.500 4.950
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
5,515.0 5,535.0 5,320.3 5,340.3 T-3, 2P-451 10/19/2020 6.0 APERF 2.5" Millenium 6 SPF 60°
Phase
5,535.0 5,550.0 5,340.3 5,355.3 T-3, 2P-451 10/19/2020 6.0 APERF 2.5" Millenium 6 SPF 60°
Phase
5,562.0 5,578.0 5,367.3 5,383.3 T-3, 2P-451 3/24/2002 6.0 IPERF 2.5" HSD 2506 Chgs, 60 deg
phase
Stimulation Intervals
Top (ftKB) Btm (ftKB)
Inter
val
Num
ber Type Subtype Start Date
Proppant
Designed (lb)
Proppant
Total (lb)
Vol Clean
Total (bbl)
Vol Slurry
Total (bbl)
5,562.0 5,578.0 1 FRAC 3/29/2002 0.0 0.00 0.00
Cement Squeezes
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Des Com
Pump Start
Date
5,432.0 5,499.3 5,237.3 5,304.6 Cement Plug Dump bailed cement 7/6/2024
3,785.0 5,321.0 3,616.4 5,126.4 Cement Plug PUMPED 31 BBLS OF 15.8 CLASS G CEMENT
FOR INTERMEDIATE BALANCED PLUG
8/23/2024
5,432.0 5,499.3 5,237.3 5,304.7 Stage
Cementing
PUMPED 31 BBLS OF 15.8 CLASS G CEMENT
FOR INTERMEDIATE BALANCED PLUG
8/23/2024
2,235.0 2,302.0 2,158.6 2,221.9 Cement Plug Pump 12.4 bbls 15.8# Class G cement for ballanced
plug, wait required 11.5 hrs for cement to set up,
attempt to tag @ 11pm could not find good cement,
5K set down @ 2235'
11/3/2024
2P-451, 4/16/2025 3:09:15 PM
Vertical schematic (actual)
PRODUCTION 5.5"x3.5" @
5439'; 2,295.0-5,927.0
Plug Catcher; 5,800.1
IPERF; 5,562.0-5,578.0
FRAC; 5,562.0
APERF; 5,535.0-5,550.0
APERF; 5,515.0-5,535.0
CIBP; 5,499.3
Stage Cementing; 5,432.0 ftKB
Cement Plug; 5,432.0 ftKB
TUBING PUNCH; 5,318.0
GAS LIFT; 5,302.7
Cement Plug; 3,785.0 ftKB
CUT; 2,670.0
CIBP; 2,302.0
SURFACE; 31.5-2,236.2
Cement Plug; 2,235.0 ftKB
Kill String ; 26.7-1,900.0
CONDUCTOR; 32.0-120.0
KUP PROD
KB-Grd (ft) RR Date
3/5/2002
Other Elev…
2P-451
...
TD
Act Btm (ftKB)
5,950.0
Well Attributes
Field Name
MELTWATER
Wellbore API/UWI
501032040200
Wellbore Status
PROD
Max Angle & MD
Incl (°)
21.46
MD (ftKB)
2,866.47
WELLNAME WELLBORE2P-451
Annotation
Last WO:
End DateH2S (ppm)
67
Date
12/21/2013
Comment
SSSV: NIPPLE
CAUTION: This email originated from outside the State of Alaska mail system. Do not
click links or open attachments unless you recognize the sender and know the content
is safe.
From:Simek, Jill
To:Loepp, Victoria T (OGC)
Subject:Re: [EXTERNAL]KRU 2P-415A (PTD 201-226, Sundry 325-203) Abandonments
Date:Monday, April 21, 2025 2:56:49 PM
This should be feasible.
From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>
Sent: Monday, April 21, 2025 10:58 AM
To: Simek, Jill <Jill.Simek@conocophillips.com>
Subject: [EXTERNAL]KRU 2P-415A (PTD 201-226, Sundry 325-203) Abandonments
Is August 31, 2025 adequate time to get cement to surface with an
abandonment date by September 30, 2025?
Victoria Loepp
Senior Petroleum Engineer
Alaska Oil & Gas Conservation Commission
Work: (907)793-1247
From: Simek, Jill <Jill.Simek@conocophillips.com>
Sent: Monday, April 14, 2025 4:49 PM
To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>
Subject: RE: [EXTERNAL]KRU 2P-415A (PTD 201-226, Sundry 325-203) Abandonments
Hi Victoria,
We plan to P&A 2P in 2 campaigns:
2P-415, 2P-419, 2P-422A, 2P-424A, 2P-429, & 2P-451 beginning in May
2P-406 & 2P-447 beginning in July (includes PWC plugs; sundries approved/in hand)
I am hoping to have wells cemented to surface by end of summer, then fit in excavations/WH
removal after that. Considering the scope has changed from rig P&A to off-rig remediation for
the 6 wells with June 30 expiration dates, will suspension extensions be considered?
Plugs will be pressure tested to 1500psi.
Slickline tags will just be BHA weight.
I am working up the remaining sundry applications and should have them submitted this week.
Thanks,
Jill Simek
ConocoPhillips Alaska
Staff Wells Engineer
700 G Street, ATO 1302, Anchorage, AK 99501
Phone: 907-263-4131 | Cell: 907-980-7503
From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>
Sent: Monday, April 14, 2025 10:46 AM
To: Simek, Jill <Jill.Simek@conocophillips.com>
Subject: [EXTERNAL]KRU 2P-415A (PTD 201-226, Sundry 325-203) Abandonments
CAUTION:This email originated from outside of the organization. Do not click links or open
attachments unless you recognize the sender and know the content is safe.
Jill,
Will these remainder 2P P&As be accomplished as a campaign, that is one after the other?
When is(are) the anticipated start date(s)? Completion dates(s)?
These wells have suspension expiration dates extended to June 31, 2025.
What slickline weight will the plugs be tagged to?
What pressure will the plugs be tested to?
Thank you,
Victoria
Victoria Loepp
Senior Petroleum Engineer
Alaska Oil & Gas Conservation Commission
Work: (907)793-1247
1a. Well Status:Oil SPLUG Other Abandoned Suspended
1b. Well Class:
20AAC 25.105 20AAC 25.110 Development Exploratory
GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test
2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry:
Aband.:
3. Address: 7. Date Spudded: 15. API Number:
4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number:
Surface:
Top of Productive Interval:17. Field / Pool(s):
GL: BF:
Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation:
4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number:
Surface: x- y- Zone- 4
TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD:
Total Depth: x- y- Zone- 4
5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD:
Submit electronic information per 20 AAC 25.050 N/A (ft MSL)
22. Logs Obtained:
N/A
23.
BOTTOM
16" B 110'
7.625" L-80 2160'
5.5" L-80 5213'
3.5" L-80 5732'
24. Open to production or injection? Yes No 25.
26.
Was hydraulic fracturing used during completion? Yes No
DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED
27.
Date First Production: Method of Operation (Flowing, gas lift, etc.):
Hours Tested: Production for Gas-MCF:
Test Period
Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr):
Press. 24-Hour Rate
5416' MD3-1/2"
CASING
(included above) 6.75"
TUBING RECORD
215 sx Class G6.75"
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
ConocoPhillips Alaska, Inc.
WAG
Gas
11/5/2024 202-008 / 324-506
TOP
SETTING DEPTH MD
suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log,
spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar
locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary.
N/A
BOTTOM
Kuparuk River Field/ Meltwater Oil Pool-
Suspended
N/A
50-103-20402-00-00
KRU 2P-451
ADL 0373112
1036' FNL, 1524' FWL, Sec. 17, T8N, R7E, UM
1364' FNL, 275' FWL, Sec. 17, T8N, R7E, UM
ALK 4998
2/21/2002
5950' MD / 5755' TVD
2235' MD / 2159' TVD
P.O. Box 100360, Anchorage, AK 99510-0360
443484 5868845
1363' FNL, 281' FWL, Sec. 17, T8N, R7E, UM
3/2/2002
CASING, LINER AND CEMENTING RECORD
List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion,
N/A
PACKER SET (MD/TVD)
42"
9.875"
392 sx AS I
32'370 sx AS IIIL, 120 sx LiteCrete
9.3#
32'
5408'
2236'32'
32'
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date perf'd or liner run):
15.5#
3785' (SW TOC) - 5318'
SUSPENDED
5515-5550' MD and 5320-5355' TVD (below cement plug)
5562-5578' MD and 5367-5383' TVD (below cement plug)
Gas-Oil Ratio:Choke Size:
31 bbls 15.8 ppg Cement (T x IA balance plug)
Per 20 AAC 25.283 (i)(2) attach electronic information
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
Sr Res EngSr Pet GeoSr Pet Eng
Oil-Bbl: Water-Bbl:
12.4 bbls 15.8 ppg cement (balanced plug)
Water-Bbl:
PRODUCTION TEST
N/A
Date of Test: Oil-Bbl:
Flow Tubing
2235' - 2302'
5408'
SIZE DEPTH SET (MD)
9. Ref Elevations: KB: 27'
5927'
27'
5213'
62.5#
29.7#
110'
27'
WT. PER
FT.GRADE
442240
442233
CEMENTING RECORD
5868526
1379' MD / 1356' TVD
SETTING DEPTH TVD
5868525
TOP HOLE SIZE AMOUNT
PULLED
Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment
By James Brooks at 3:04 pm, Nov 20, 2024
Suspended
11/5/2024
JSB
RBDMS JSB 112924
xGDSR-4/7/25
Conventional Core(s): Yes No Sidewall Cores:
N/A
30.
MD TVD
Surface Surface
1379' 1356'
Top of Productive Interval
N/A
31. List of Attachments: Schematics, Summary of Operations
32. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Contact Name: Shane Germann
Digital Signature with Date:Contact Email: shane.germann@conocophillips.com
Contact Phone:(907) 263-4597
Senior CTD/RWO Engineer
General:
Item 1a:
Item 1b:
Item 4b:
Item 9:
Item 15:
Item 19:
Item 20:
Item 22:
Item 23:
Item 24:
Item 27:
Item 28:
Item 30:
Item 31:
Formation Name at TD:
If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if
needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired.
Yes No
Well tested? Yes No
28. CORE DATA
If Yes, list intervals and formations tested, briefly summarizing test results for
each. Attach separate pages if needed and submit detailed test info including
reports and Excel or ASCII tables per 20 AAC 25.071.
NAME
Permafrost - Top
Permafrost - Base
29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS
N/A- Suspended
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core
analysis, paleontological report, production or well test results, per 20 AAC 25.070.
Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each
segregated pool is a completion.
TPI (Top of Producing Interval).
Authorized Name and
Authorized Title:
N/A- Suspended
Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and
other tests as required including, but not limited to: core analysis, paleontological report, production or well test results.
Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29.
Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool.
If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the
producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,
showing the data pertinent to such interval).
Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit
detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity,
permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology.
Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain).
Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical
laboratory information required by 20 AAC 25.071.
Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion,
suspension, or abandonment; or 90 days after log acquisition, whichever occurs first.
Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345),
and/or Easement (ADL 123456) number.
The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements
given in other spaces on this form and in any attachments.
The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic
diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from
a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071.
INSTRUCTIONS
Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov
Digitally signed by Shane Germann
DN: O=ConocoPhillips, CN=Shane Germann, E=
shane.germann@conocophillips.com
Reason: I have reviewed this document
Location:Date: 2024.11.20 14:20:47-09'00'
Foxit PDF Editor Version: 13.0.0
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag: RKB 5,568.0 2P-451 6/16/2024 rogerba
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Pull 5.5" WRBP & Freeze protect well 2P-451 11/14/2024 claytg
Notes: General & Safety
Annotation End Date Last Mod By
NOTE: ZONES NOT LOADED INTO WELLVIEW YET 7/29/2009 triplwj
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 32.0 120.0 120.0 62.60 WELDED
SURFACE 7 5/8 6.87 31.5 2,236.2 2,159.7 29.70 L-80 BTCMOD
Kill String 5 1/2 4.95 26.7 1,900.0 1,843.8 15.50 L-80 BTCMOD
PRODUCTION
5.5"x3.5" @ 5439'
5 1/2 4.95 26.7 5,927.0 5,732.2 15.50 L-80 BTCMOD
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
26.6
Set Depth …
5,415.7
Set Depth …
5,221.1
String Max No…
3 1/2
Tubing Description
TUBING
Wt (lb/ft)
9.30
Grade
L-80
Top Connection
EUEM
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)
26.6 26.6 0.00 HANGER 8.000 FMC TUBING HANGER 3.500
496.3 495.9 5.54 NIPPLE 4.520 CAMCO DS NIPPLE CAMCO DS 2.875
5,302.7 5,108.1 1.56 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900
5,352.6 5,158.0 1.47 SLEEVE-C 4.500 BAKER CMU SLIDING SLEEVE BAKER CMU 2.813
5,368.6 5,174.0 1.46 NIPPLE 4.520 CAMCO D NIPPLE CAMCO D 2.750
5,413.0 5,218.3 1.42 SEAL 4.500 BAKER GBH-22 LOCATOR/SEAL
ASSY LANDED w/NO GO 2' OFF
PROD CSG LOCATOR @ 5419'
BAKER GBH-22 2.990
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)
2,302.0 2,221.9 19.07 CIBP CIBP set 2302' top, tested
1000 psi good test
10/30/2024 0.000
2,670.0 2,568.5 20.54 CUT 2.5" JET TUBING CUT 9/5/2024 2.992
5,318.0 5,123.4 1.52 TUBING
PUNCH
TUBING PUNCH, 3FT @ 6
SPF, 0 DEGREE PHASE.
8/6/2024 2.992
5,499.3 5,304.6 1.19 CIBP CIBP MID-ELEMENT AT 5500'
RKB, OAL = 1.37'
7/1/2024 0.000
5,800.1 5,605.4 1.13 Plug Catcher PLUG CATCHER SET IN 3.5"
PRODUCTION CASING
3/2/2002 0.000
Mandrel Inserts : excludes pulled inserts
Top (ftKB)
Top (TVD)
(ftKB)
Top
Incl (°)
St
ati
on
No
/S Serv
Valve
Type
Latch
Type
OD
(in)
TRO Run
(psi) Run Date Com Make Model
Port
Size (in)
5,302.7 5,108.1 1.56 1 GAS LIFT OPEN 1 9/4/2021
Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal ID
(in)
29.4 29.4 0.00 PRODUCTION 5.500 4.950
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
5,515.0 5,535.0 5,320.3 5,340.3 T-3, 2P-451 10/19/2020 6.0 APERF 2.5" Millenium 6 SPF 60°
Phase
5,535.0 5,550.0 5,340.3 5,355.3 T-3, 2P-451 10/19/2020 6.0 APERF 2.5" Millenium 6 SPF 60°
Phase
5,562.0 5,578.0 5,367.3 5,383.3 T-3, 2P-451 3/24/2002 6.0 IPERF 2.5" HSD 2506 Chgs, 60 deg
phase
Stimulation Intervals
Top (ftKB) Btm (ftKB)
Inter
val
Num
ber Type Subtype Start Date
Proppant
Designed (lb)
Proppant
Total (lb)
Vol Clean
Total (bbl)
Vol Slurry
Total (bbl)
5,562.0 5,578.0 1 FRAC 3/29/2002 0.0 0.00 0.00
Cement Squeezes
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Des Com
Pump Start
Date
5,432.0 5,499.3 5,237.3 5,304.6 Cement Plug Dump bailed cement 7/6/2024
3,785.0 5,321.0 3,616.4 5,126.4 Cement Plug PUMPED 31 BBLS OF 15.8 CLASS G CEMENT
FOR INTERMEDIATE BALANCED PLUG
8/23/2024
5,432.0 5,499.3 5,237.3 5,304.7 Stage
Cementing
PUMPED 31 BBLS OF 15.8 CLASS G CEMENT
FOR INTERMEDIATE BALANCED PLUG
8/23/2024
2,235.0 2,302.0 2,158.6 2,221.9 Cement Plug Pump 12.4 bbls 15.8# Class G cement for ballanced
plug, wait required 11.5 hrs for cement to set up,
attempt to tag @ 11pm could not find good cement,
5K set down @ 2235'
11/3/2024
2P-451, 11/20/2024 9:34:36 AM
Vertical schematic (actual)
PRODUCTION 5.5"x3.5" @
5439'; 2,295.0-5,927.0
FLOAT SHOE; 5,926.4-5,927.0
FLOAT COLLAR; 5,831.7-
5,832.3
Plug Catcher; 5,800.1
FRAC; 5,562.0
IPERF; 5,562.0-5,578.0
APERF; 5,535.0-5,550.0
APERF; 5,515.0-5,535.0
CIBP; 5,499.3
Stage Cementing; 5,432.0 ftKB
Cement Plug; 5,432.0 ftKB
CSR; 5,420.0-5,439.4
LOCATOR; 5,418.9-5,420.0
SEAL; 5,413.0
SBE; 5,408.8-5,418.9
NIPPLE; 5,368.6
SLEEVE-C; 5,352.6
TUBING PUNCH; 5,318.0
GAS LIFT; 5,302.7
Cement Plug; 3,785.0 ftKB
CUT; 2,670.0
Annular Fluid - Saltwater/Brine;
2,302.0-2,670.0; 11/1/2024
CIBP; 2,302.0
SURFACE; 31.5-2,236.2
FLOAT SHOE; 2,234.7-2,236.2
Cement Plug; 2,235.0 ftKB
FLOAT COLLAR; 2,146.5-
2,147.9
Kill String ; 26.7-1,900.0
Annular Fluid - Saltwater/Brine;
240.0-2,236.0; 11/5/2024
PORT COLLAR; 1,024.9-
1,027.3
Annular Fluid - Diesel; 26.7-
240.0; 11/5/2024
CONDUCTOR; 32.0-120.0
HANGER; 31.5-34.0
HANGER; 26.7-29.4
KUP PROD
KB-Grd (ft) RR Date
3/5/2002
Other Elev…
2P-451
...
TD
Act Btm (ftKB)
5,950.0
Well Attributes
Field Name
MELTWATER
Wellbore API/UWI
501032040200
Wellbore Status
PROD
Max Angle & MD
Incl (°)
21.46
MD (ftKB)
2,866.47
WELLNAME WELLBORE2P-451
Annotation
Last WO:
End DateH2S (ppm)
67
Date
12/21/2013
Comment
SSSV: NIPPLE
2P-451 Post-RWO Schematic
Conductor:
16" Conductor 120' KB
Production Casing Cement:
53 bbls of 15.8# Cement
Calculated TOC @ 2,936' KB
Production Casing:
5.5" x 3.5" @ 5,439' KB, 15.5# x 9.3#,
L-80 BTC Mod
Set @ 5,927’ KB
T-3 Peforations:
@ 5,515'– 5,578' KB (63')
Surface Casing:
7-5/8", 29.7#, L-80 BTC Mod
Set @ 2,236.2' KB (2159' TVD)
Production Tubing:
3 ½”, 9.3# L-80 EUE-8rd
Set @ 6,883.7' KB
6
5
C80 @ 2520' KB C80 @ 2520' KB
Plug #1 – Reservoir
TOC ±5432' RKB
Plug #2 – Intermediate
TOC ±3815' RKB
BOC @ ±5315' RKB
Failed Plug #3 – Surface Shoe
TOC 2235' RKB (29' TVD)
BOC @ ±2302' RKB
Base of 5-½” Casing
used as kill string set at
1900' RKB
9.8 NaCl w/ freeze
protect
1
2
3
4
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DTTMSTART JOBTYP SUMMARYOPS
10/26/2024 RECOMPLETION Disconnect highline. Back well off 2K-19 @ 11:00. Pickup mats.
Clean up area around well in prep for Env. inspection. Prep rig for
move from 2K to 2P. Pull off 2K Pad @ 12:45. Move rig from 2K to
2P.
10/27/2024 RECOMPLETION Cont. rig move to 2P. rig on location 15:00, perform rig up checklist
and accept rig @ 00:00
10/28/2024 RECOMPLETION Continue rig up of hard line and misc rig equipment as it arrives
from 2K. PT lines to tanks. Kill well with 9.8# KW Brine. SD
Pumps. OWFF. Set and test BPV to 1,000 psi from below. ND old
tree. Inspect hanger neck thread. Good condition. Install test dart.
NU BOP's. Shell test. Perform initial BOP test to 250/2500 psi.
(witnessed waived by Sean Sullivan).
10/29/2024 RECOMPLETION Complete BOP test, Blowdown. R/D testing equipment. Prep floor
to pull 3 1/2" EUE tubing. Pull BPV. MU 3 1/2" landing joint to
tubing hanger. Screw in TD. Set 10K down. BOLDS. Pull tubing
hanger to rig floor 85k off seat ,pick up to 195K no movement, call
out e-line with welltec cutter, perform cut @ 2650' stand back eline
pull on pipe, moving @ 85k rig down e-line. Circ STS. OWFF. pull
completion from cut
10/30/2024 RECOMPLETION RIH set CIBP @ 2302' top of plug, trip out of hole, pick up MSC,
TIH locate collars and perform cut @ 2295', attempt to circulate out
OA, no returns at surface, pressure up drill pipe 600 psi loosing
fluid to cut, TOOH lay down cutter, pull packoff attempt to pull
casing hanger to floor, pull 275K no movement
10/31/2024 RECOMPLETION Wait on E-line, install packoff and test, rig up AK E-line, RIH w/
CBL, found top cement 2245', rig down e-line, pick up msc, RIH
perform cut @ 2,225', circulate OA to 9.8#, tooh to pull casing, lay
down MSC, pull packoff, make up landing jt, un-seat hanger, pump
deep clean pill S to S, lay down 5.5" casing from cut @ 2,225'
11/1/2024 RECOMPLETION Attempt to pull the remainder of the 5 1/2" BTCMOD casing
11/2/2024 RECOMPLETION TIH to pull 5.5" from cut @ 2250, spear pull 65k over block wt, fish
moving, TOOH lay down fish, pick up clean out assemlby (junk
mill), tag top of cement 2245', clean out to top of fish @ 2,248',
pump sweeps, TOOH for fishing spear, lay down cleanout BHA and
inspect, pick up fishing spear and jars, TIH engage top of fish @
2,248', jar 28 hits, pull 300k straight pull, fish free, perform derrick
inspection tooh lay down fish 19.95', pick up cleanout bha, TIH tag
fill @ 2,250', clean out T/2,269', pump sweep S to S, flow check
well, TOOH lay down cleanout BHA # 11, pick up fishing spear
w/BHA # 12 Last 5 1/2" BTCMOD casing Recoved
11/3/2024 RECOMPLETION Cement firest stage spot,hold for 7 hrs and AOGCC State witness
Tag up If all good ,M/U Hanger ,land tubing,N/D BOP N/U Tree
Complete second stage cement to surf
11/4/2024 RECOMPLETION L/D 3 1/2" tubing and M/U 5 1/2"BTCMOD casing RIH spot casing
@ 1900 + -" M/U Hanger and Land casing
11/5/2024 RECOMPLETION RIH w/2 7/8" Pac and set RBP @ 2500' Test Same 2500 PSI if
Good POOH dry stand Back 2 7/8" D.P and N/D BOP and install
dry hole tree Test Flange to 2500 PSI Rig Release Midnight
2P-451 Plug and Abandon- Rig
Summary of Operations
Page 1/7
2P-451
Report Printed: 11/20/2024
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/26/2024
09:00
10/26/2024
10:00
1.00 MIRU, MOVE MOB P Disconnect highline. Pull support
equipment away from rig. Back well off
2K-19. Pickup mats. Clean up area
around well in prep for Env. inspection.
Prep rig for move from 2K to 2P.
0.0 0.0
10/26/2024
10:00
10/27/2024
00:00
14.00 MIRU, MOVE MOB P Start rig move from 2K to 2P. 0.0 0.0
10/27/2024
00:00
10/27/2024
05:00
5.00 MIRU, MOVE MOB P Continue rig move. Arrived at 2N @
05:00AM.
0.0 0.0
10/27/2024
05:00
10/27/2024
15:00
10.00 MIRU, MOVE MOB P Rig move from 2N to 2P. Arrive on
location @ 15:00. 0
0.0 0.0
10/27/2024
15:00
10/28/2024
00:00
9.00 MIRU, MOVE RURD P Rig up, perform rig accept checklist,
take on 9.8# Brine
Extra time for loads to make it from 2K
Rig Accepted 00:00
0.0 0.0
10/28/2024
00:00
10/28/2024
00:00
MIRU, MOVE MOB P Lay pit liner around well. Lay T-Mats.
Lay dance floor for rig in front of well.
Spot contingency dry hole tree behind
cellar. Continue to haul support
equipment from 2K Pad.
xxxxxxxxxxxxxxxxx
10/28/2024
00:00
10/28/2024
05:30
5.50 MIRU, MOVE RURD P Continue rig up of hard line and misc rig
equipment as it arrives from 2K. Set and
test BPV to 1,000 psi from below. ND
old tree. NU BOP's. Set slip over plug.
Shell test. Perform initial BOP test to
250/2500 psi.
0.0 0.0
10/28/2024
05:30
10/28/2024
06:45
1.25 MIRU, WELCTL KLWL P Kill well with 9.8# KW Brine. Pump 32
bbls hot Deep Clean pill. Pump 87 bbls
9.8# Brine. Measure clean 9.8# in
returns. SD Pumps. Blowdown lines.
0.0 0.0
10/28/2024
06:45
10/28/2024
07:15
0.50 MIRU, WELCTL OWFF P OWFF for 30-min. 0.0 0.0
10/28/2024
07:15
10/28/2024
08:00
0.75 MIRU, WELCTL MPSP P Set and test BPV to 1,000 psi from
below. Load and Process 100 Joints of
2 7/8" HT PAC DP.
0.0 0.0
10/28/2024
08:00
10/28/2024
13:30
5.50 MIRU, WHDBOP NUND P ND old tree. Clean out wellhead.
Function LDS. Hanger tree in cellar.
Tubing hanger neck threads in good
condition. Function test lift threads.
10.5 turns to MU. Set test dart. NU
BOP's.
0.0 0.0
10/28/2024
13:30
10/28/2024
15:15
1.75 MIRU, WHDBOP RURD P RU BOP testing equipment. Function
test rams and valves.
0.0 0.0
Rig: NORDIC 3
RIG RELEASE DATE 11/6/2024
Page 2/7
2P-451
Report Printed: 11/20/2024
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/28/2024
15:15
10/29/2024
00:00
8.75 MIRU, WHDBOP BOPE P Shell test passed @ 16:00. Perform
initial BOP test to 250/2500 psi. Initial
BOPE test, Tested BOPE at 250/2500
PSI for 5 Min each, Tested annular and
UPR w/ 2 7/8", 3 1/2" and 7" TJ. Test
blinds rams. ODS door seal on Blind
rams started leaking. Changed out.
Choke valves #1 to #13, upper and
lower top drive well control valves. Test
3 1/2" IF FOSV and IBOP. Test 3 ½”
EUE FOSV. Test 2" rig floor Demco kill
valve MM #13. Test manual and HCR
kill valves & manual and HCR choke
valves. Test two ea 2 1/6" gate auxiliary
valves below LPR. Test hydraulic and
manual choke valves to 1500 PSI and
demonstrate bleed off. Perform
accumulator test. Initial pressure=3000
PSI, after closure=1750 PSI, 200 PSI
attained = 22 sec, full recovery attained
= 112 sec. UVBR's=5 sec, Simulated
LPR=x sec. Annular= 10 sec.
Simulated blinds=x sec. HCR choke &
kill= 1 sec each. 4 back up nitrogen
bottles average = 2100 PSI. Test gas
detectors, PVT. Witnessed waived by
AOGCC rep Sean Sullivan.
0.0 0.0
10/29/2024
00:00
10/29/2024
01:00
1.00 MIRU, WHDBOP BOPE P Shell test passed @ 16:00. Perform
initial BOP test to 250/2500 psi. Initial
BOPE test, Tested BOPE at 250/2500
PSI for 5 Min each, Tested annular and
UPR w/ 2 7/8", 3 1/2" and 7" TJ. Test
blinds rams. ODS door seal on Blind
rams started leaking. Changed out.
Choke valves #1 to #13, upper and
lower top drive well control valves. Test
3 1/2" IF FOSV and IBOP. Test 3 ½”
EUE FOSV. Test 2" rig floor Demco kill
valve MM #13. Test manual and HCR
kill valves & manual and HCR choke
valves. Test two ea 2 1/6" gate auxiliary
valves below LPR. Test hydraulic and
manual choke valves to 1500 PSI and
demonstrate bleed off. Perform
accumulator test. Initial pressure=3000
PSI, after closure=1750 PSI, 200 PSI
attained = 22 sec, full recovery attained
= 112 sec. UVBR's=5 sec, Simulated
LPR=x sec. Annular= 10 sec.
Simulated blinds=x sec. HCR choke &
kill= 1 sec each. 4 back up nitrogen
bottles average = 2100 PSI. Test gas
detectors, PVT. Witnessed waived by
AOGCC rep Sean Sullivan.
0.0 0.0
10/29/2024
01:00
10/29/2024
02:30
1.50 MIRU, WHDBOP RURD P Blowdown lines. R/D testing equipment.
Install mousehole. Drain Stack. Prep
rig floor to pull 3 1/2" EUE tubing. Clean
and clear pipe shed from rig move prep
for laying down pipe
0.0 0.0
10/29/2024
02:30
10/29/2024
03:00
0.50 MIRU, WHDBOP MPSP P Pull BPV and test dart. 0.0 0.0
10/29/2024
03:00
10/29/2024
04:00
1.00 COMPZN, RPCOMP PULL P MU 3 1/2" EUE landing joint to tubing
hanger. Screw in TD. Set 10K down.
BOLDS. Pull hanger to rig floor. Unseat
hanger @ 85K. Pull to 195K no pipe
movement, continue to work pipe while
discussing plan forward with on-call
engineer
2,670.0 2,670.0
Rig: NORDIC 3
RIG RELEASE DATE 11/6/2024
Page 3/7
2P-451
Report Printed: 11/20/2024
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/29/2024
04:00
10/29/2024
11:00
7.00 COMPZN, RPCOMP WAIT T Wait on e-line and Welltec to mobilize to
2P, Welltec on location 7AM, E-line on
location 8am, E-line truck lost belt on
way to pad, replace belt and jump start
truck, re-head e-line,
2,670.0 2,670.0
10/29/2024
11:00
10/29/2024
12:00
1.00 COMPZN, RPCOMP RURD T Rig up e-line and pick up Welltec cutter 2,670.0 2,670.0
10/29/2024
12:00
10/29/2024
13:00
1.00 COMPZN, RPCOMP ELNE T RIH, stage cutter @ 2660', set down on
previous cut, pick up to 2650' perform
welltec cutter, posative indication from
tool movement, log out of hole pipe
shifted 1' indicating good cut, stand
back e-line, pull on pipe moving up hole
85k
2,670.0 2,670.0
10/29/2024
13:00
10/29/2024
14:00
1.00 COMPZN, RPCOMP CIRC P Circulate hot deep clean pill surface to
surface
2,670.0 2,650.0
10/29/2024
14:00
10/29/2024
18:00
4.00 COMPZN, RPCOMP PULL P Pull completion from cut @ 2650' / Lay
Down same 3 1/2" tubing
2,650.0 0.0
10/29/2024
18:00
10/29/2024
23:00
5.00 COMPZN, RPCOMP TRIP P Clean up Floor P/U BHA # 1 W 4 3/4 "
junk mill run xo t/ 2 7/8" HT Pac RIH /
Tag Stab @ 2650'
0.0 2,650.0
10/29/2024
23:00
10/30/2024
00:00
1.00 COMPZN, RPCOMP CIRC P Circ 2 BU 224 GPM w/2100 psi All Good
10/30/2024
00:00
10/30/2024
02:30
2.50 COMPZN, RPCOMP TRIP P Continue POOH w/ clean out Assy 2,600.0 0.0
10/30/2024
02:30
10/30/2024
03:00
0.50 COMPZN, RPCOMP BHAH P L/D clean out assy M/U CIBP 0.0 0.0
10/30/2024
03:00
10/30/2024
05:30
2.50 COMPZN, RPCOMP TRIP P P/U and RIH w/ 2 7/8 HTPAC 0.0 5.0
10/30/2024
05:30
10/30/2024
06:30
1.00 COMPZN, RPCOMP PACK P Set CIBP 2300' and test t/1000psi F/ 10
mins All good
0.0 2,300.0
10/30/2024
06:30
10/30/2024
09:00
2.50 COMPZN, RPCOMP TRIP P TOOH for MSC for 5.5" casing 2,300.0 0.0
10/30/2024
09:00
10/30/2024
09:30
0.50 COMPZN, RPCOMP BHAH P Lay down setting tool, pick up 5.5"
casing MSC
0.0 15.0
10/30/2024
09:30
10/30/2024
10:00
0.50 COMPZN, RPCOMP PRTS P Pressure test casing and CIBP 1000 psi
10 min
15.0 15.0
10/30/2024
10:00
10/30/2024
12:45
2.75 COMPZN, RPCOMP PUTB P Trip in hole picking up 2-7/8" HT Pac
tubing
15.0 2,260.0
10/30/2024
12:45
10/30/2024
13:45
1.00 COMPZN, RPCOMP CPBO P Cut 5.5" casing with MSC, Free spin 80
rpm @ 937 ft/lbs, pump 2 bpm @ 1124
psi rotary torque @ 1200 ft/lbs, Start cut
@ 13:25, torque work up to1500 ft/lbs,
cut complete @ 2,295''
2,260.0 2,295.0
10/30/2024
13:45
10/30/2024
18:00
4.25 COMPZN, RPCOMP OTHR P Drop 5/8" ball to open circ sub, circulate
70 bbls 9.8# hot deep clean followed by
9.8# brine unable to gain circulation on
OA, continue toubleshooting OA
circulation issues Decision was made
F/ Engineers to POOH
2,295.0 2,295.0
10/30/2024
18:00
10/30/2024
21:00
3.00 COMPZN, RPCOMP TRIP P POOH / Lay down YJOS 5 1/2" Cutter 2,295.0 0.0
10/30/2024
21:00
10/31/2024
00:00
3.00 COMPZN, RPCOMP BHAH P M/U Pack off pulling tool & Pull Pack off
L/D same M/U 5 1/2" casing Hanger
landing jt RIH latch up on Hanger
Attempt to Pull 5 1/2" casing no go 150K
t/ 250K
0.0 0.0
10/31/2024
00:00
10/31/2024
05:00
5.00 COMPZN, RPCOMP WAIT P Continue to work pipe and call out E-line
SLB T/ run CBL and service rig Pres up
on 5 1/2" casing 450 PSI no go bleed
down 250 psi no help Bleed off pres t/0
Stand by F/E-line
0.0 0.0
Rig: NORDIC 3
RIG RELEASE DATE 11/6/2024
Page 4/7
2P-451
Report Printed: 11/20/2024
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/31/2024
05:00
10/31/2024
06:00
1.00 COMPZN, RPCOMP PACK P R/D landing jt and P/U pack off running
tool & Install pack off and test same
0.0 0.0
10/31/2024
06:00
10/31/2024
07:00
1.00 COMPZN, RPCOMP RURD P Rig up E-line for CBL 0.0 0.0
10/31/2024
07:00
10/31/2024
08:30
1.50 COMPZN, RPCOMP ELOG P Perform CBL, top of cemenet @ 2245'
pull out of hole rig down e-line
0.0 0.0
10/31/2024
08:30
10/31/2024
09:30
1.00 COMPZN, RPCOMP BHAH P Pick up MSC BHA 0.0 20.0
10/31/2024
09:30
10/31/2024
12:00
2.50 COMPZN, RPCOMP PULD P TIH with MSC on singles 2-7/8" HT Pac 20.0 2,302.0
10/31/2024
12:00
10/31/2024
13:00
1.00 COMPZN, RPCOMP CPBO P Obtain perameters, locate cut @ 2295'
tag CIBP @ 2302, Drop singles to
2225', obtain perameters perform cut @
2225', 145 psi initial on OA, perform cut,
2,302.0 2,225.0
10/31/2024
13:00
10/31/2024
15:00
2.00 COMPZN, RPCOMP DISP P Displace OA with 9.8# brine, rig down
circulating hoses
2,225.0 2,225.0
10/31/2024
15:00
10/31/2024
17:00
2.00 COMPZN, RPCOMP TRIP P Trip out of hole with cutter 2,225.0 0.0
10/31/2024
17:00
10/31/2024
18:00
1.00 COMPZN, RPCOMP BHAH P Lay down cutter and BHA 0.0 0.0
10/31/2024
18:00
10/31/2024
21:00
3.00 COMPZN, RPCOMP CIRC P r/u to circ well clean w/ 70 bbls
deepclean pill @ 5 BBls Min w/ 400 psi
Around All good Pull Pack off and l/d
same P/U landing jt M/U to Hanger Pull
Hanger t/floor L/D same String wt 3300K
no over pull clean cut Monitor well 15
mins All Good
0.0 0.0
10/31/2024
21:00
10/31/2024
23:30
2.50 COMPZN, RPCOMP TRIP P L/D 5 1/2" BTCMOD Prod csaing Tot Jts
L/D 50 full jts 1 Cut Jt 36.13', (16
centralizers)
2,225.0 0.0
10/31/2024
23:30
11/1/2024
00:00
0.50 COMPZN, RPCOMP BHAH P Clean up Foor And Load 6 1/4" D.C in
shed
0.0 0.0
11/1/2024
00:00
11/1/2024
01:30
1.50 COMPZN, RPCOMP BHAH P M/U BHA #5 w/ spear 0.0 300.0
11/1/2024
01:30
11/1/2024
04:00
2.50 COMPZN, RPCOMP TRIP RIH T/2168' 300.0 2,168.0
11/1/2024
04:00
11/1/2024
07:00
3.00 COMPZN, RPCOMP CPBO Cut and slip Drilling line 60' service rig
Crew Change out t/go home
2,168.0 2,168.0
11/1/2024
07:00
11/1/2024
08:30
1.50 COMPZN, RPCOMP TRIP P RIH t/ 2225' Attempy to latch up on fish
No Success
2,168.0 2,225.0
11/1/2024
08:30
11/1/2024
11:00
2.50 COMPZN, RPCOMP TRIP P POOH l/d BHA # 5 Due to Pack off L/D
P.O. Add bull nose R.R BHA # 5
2,225.0 0.0
11/1/2024
11:00
11/1/2024
12:30
1.50 COMPZN, RPCOMP TRIP P RIH and Latch up on Fish @ 2225' 0.0 2,225.0
11/1/2024
12:30
11/1/2024
14:30
2.00 COMPZN, RPCOMP FISH P Attempt to Jar fish free Attempt 32 hits
and Straight pull 350k No go release
spear
2,225.0 2,225.0
11/1/2024
14:30
11/1/2024
17:30
3.00 COMPZN, RPCOMP TRIP P POOH / Inspection the Drk All good 2,225.0 0.0
11/1/2024
17:30
11/1/2024
18:00
0.50 COMPZN, RPCOMP BHAH P L/D BHA # 6 M/U BHA # 7 w/ Cutter 0.0 150.0
11/1/2024
18:00
11/1/2024
19:30
1.50 COMPZN, RPCOMP TRIP P RIH 150.0 2,295.0
11/1/2024
19:30
11/1/2024
22:00
2.50 COMPZN, RPCOMP OTHR P Check cut @ 2295' confirmed All good
pull up hole to 2270 cut and @ 2250' All
seems to be good cuts The cut
parameters p/u wt 62k s.o. wt 60k Tq
1400 lb @ 1bbl min W/ 300 psi @ 2bbls
min1100 psi
2,295.0 2,295.0
11/1/2024
22:00
11/2/2024
00:00
2.00 COMPZN, RPCOMP TRIP P POOH 2,295.0 0.0
Rig: NORDIC 3
RIG RELEASE DATE 11/6/2024
Page 5/7
2P-451
Report Printed: 11/20/2024
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/2/2024
00:00
11/2/2024
01:00
1.00 COMPZN, RPCOMP BHAH P P/U BHA # 8 0.0 300.0
11/2/2024
01:00
11/2/2024
02:00
1.00 COMPZN, RPCOMP TRIP P RIH 300.0 2,225.0
11/2/2024
02:00
11/2/2024
02:30
0.50 COMPZN, RPCOMP FISH P Latch up on Fish @ 2,232' up wt 70k SO
wt 65 pulled 25k over pulled fish free
2,225.0 2,220.0
11/2/2024
02:30
11/2/2024
03:30
1.00 COMPZN, RPCOMP TRIP P Monitor well 15 mins All Good POOH //
Trip out of hole inspect fish
2,220.0 300.0
11/2/2024
03:30
11/2/2024
05:00
1.50 COMPZN, RPCOMP BHAH P L/D BHA # 8 L/D 24.15' fish M/U #9 w/
6 3/4" junk mill
300.0 100.0
11/2/2024
05:00
11/2/2024
06:00
1.00 COMPZN, RPCOMP TRIP P RIH with clean out BHA # 9 100.0 2,160.0
11/2/2024
06:00
11/2/2024
06:45
0.75 COMPZN, RPCOMP REAM P Obtain perameters, Clean out to top of
fish @ 2250', Pump sweeps to clean out
hole
Perameters pump 3 bpm @ 665 psi ,
Rot 62 rpm @ 1700 ft/lbs, start milling
"cement" @ 2,245', found 5.5" stump @
2,248'
2,160.0 2,250.0
11/2/2024
06:45
11/2/2024
07:15
0.50 COMPZN, RPCOMP CIRC P Circulate S to S, flow check well 2,250.0 2,250.0
11/2/2024
07:15
11/2/2024
08:15
1.00 COMPZN, RPCOMP TRIP P TOOH for fishing assembly 2,250.0 300.0
11/2/2024
08:15
11/2/2024
08:45
0.50 COMPZN, RPCOMP BHAH P Lay down clean out BHA # 9 , inspect
mill
300.0 0.0
11/2/2024
08:45
11/2/2024
09:15
0.50 COMPZN, RPCOMP BHAH P Pick up fishing BHA# 10 5.5" spear 0.0 217.0
11/2/2024
09:15
11/2/2024
10:45
1.50 COMPZN, RPCOMP TRIP P Trip in hole with BHA# 10 on 3.5" drill
pipe T/ 2160'
217.0 2,160.0
11/2/2024
10:45
11/2/2024
11:45
1.00 COMPZN, RPCOMP JAR P Kelly up, pump 1 bbm/min @ 56 psi, up
wt 70K dn wt 66K, engage fish @
2,248', NG @ 2,254' , Jar at 150K
straight pull to 300K, 28 hits fish free
pick up wt 70 to 150 k for 20' , then pull
free @ 70k
2,160.0 2,254.0
11/2/2024
11:45
11/2/2024
12:15
0.50 COMPZN, RPCOMP SVRG P Perform derrick inspection 2,254.0 2,190.0
11/2/2024
12:15
11/2/2024
13:30
1.25 COMPZN, RPCOMP TRIP P TOOH with fish 2,190.0 219.0
11/2/2024
13:30
11/2/2024
14:00
0.50 COMPZN, RPCOMP BHAH P Lay down BHA# 10 and fish, 19.94
recovered
219.0 0.0
11/2/2024
14:00
11/2/2024
14:30
0.50 COMPZN, RPCOMP BHAH P Pick up clean out BHA 0.0 218.0
11/2/2024
14:30
11/2/2024
15:30
1.00 COMPZN, RPCOMP TRIP P Trip in hole set down 2,250 218.0 2,250.0
11/2/2024
15:30
11/2/2024
16:30
1.00 COMPZN, RPCOMP REAM P Ream down to 2269' tag top of fish,
sand returns at shakers, 3 bpm @ 577
psi, no losses
2,250.0 2,269.0
11/2/2024
16:30
11/2/2024
17:30
1.00 COMPZN, RPCOMP TRIP P POOH 2,269.0
11/2/2024
17:30
11/2/2024
18:30
1.00 COMPZN, RPCOMP BHAH P L/D Clean out Tools M/U BHA #12 w/
spear Assy
11/2/2024
18:30
11/2/2024
20:00
1.50 COMPZN, RPCOMP TRIP P RIH Tag top of Fish@ 2268" And Latch
up on Fish
11/2/2024
20:00
11/2/2024
21:00
1.00 COMPZN, RPCOMP FISH P Start Jarring on Fish 65 over string wt
and Straight pull 305K 26 hits fish pulled
free
11/2/2024
21:00
11/2/2024
22:00
1.00 COMPZN, RPCOMP OTHR P Monitor well service Rig due to jarring
11/2/2024
22:00
11/2/2024
23:30
1.50 COMPZN, RPCOMP TRIP P POOH 2,268.0 2,295.0
Rig: NORDIC 3
RIG RELEASE DATE 11/6/2024
Page 6/7
2P-451
Report Printed: 11/20/2024
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/2/2024
23:30
11/3/2024
00:00
0.50 COMPZN, RPCOMP BHAH P L/D BHA #12 w/ 25.25' 5 1/2" BTCMOD
casing Fish Cont
2,294.0 2,294.0
11/3/2024
00:00
11/3/2024
02:00
2.00 COMPZN, RPCOMP BHAH P Continue R/D BHA #12 YJOS Tools and
R/U 3 1/2 Tubing Equip and spot
Hulliburton Cementers
2,294.0 0.0
11/3/2024
02:00
11/3/2024
07:00
5.00 COMPZN, RPCOMP TRIP P P/U 3 1/2" EUE Cement string single in
the hole Nordic tongs failed to work Call
out GBR Crew and equipment
0.0 2,300.0
11/3/2024
07:00
11/3/2024
07:30
0.50 COMPZN, RPCOMP CIRC P Space out 5' off bottom , rig up head pin,
Circulate 3 bpm @ 91 psi, monitor loss
rate, no losses to report // PJSM with
cementers while circulating B/U
2,300.0 2,295.0
11/3/2024
07:30
11/3/2024
08:00
0.50 COMPZN, RPCOMP RURD P Rig up cement line to head pin // Double
block valves on cement line
2,295.0 2,295.0
11/3/2024
08:00
11/3/2024
09:30
1.50 COMPZN, RPCOMP WAIT T Batch mixer on cement truck leaking,
perform repairs
2,295.0 2,295.0
11/3/2024
09:30
11/3/2024
10:30
1.00 COMPZN, RPCOMP CMNT P Mix and pump balanced plug as follows:
5 bbls 9.8# NaCl
PT lines 3000 psi
23.9 bbls 10ppg spacer
shut choke drop 3.9" ball
12.4 bbls 15.8# cement
shut choke drop 3.9" wiper ball
6.1 bbls 10# spacer
10.9 bbls 9.8# Nacl to spot balanced
plug
Pump pressure when pump off 30 psi //
Break off circulation line well static
2,295.0 2,295.0
11/3/2024
10:30
11/3/2024
11:00
0.50 COMPZN, RPCOMP TRIP P Trip out 372' to get above cement // Max
pull speed 30'/min // 38k pick up wt
2,295.0 1,923.0
11/3/2024
11:00
11/3/2024
11:30
0.50 COMPZN, RPCOMP CIRC P Circulate S x S @ 3 bbls/min @ 98 psi //
No cement in returns // Trap 200 psi on
well shut in for cement cure
1,923.0 1,923.0
11/3/2024
11:30
11/3/2024
23:00
11.50 COMPZN, RPCOMP WOC P Wait for cement to cure tag time 11:00
pm
1,923.0 1,923.0
11/3/2024
23:00
11/4/2024
00:00
1.00 COMPZN, RPCOMP WASH P RIH and strart Washing F/2023' 2115' @
1 bbl min w/66 psi
1,923.0
11/4/2024
00:00
11/4/2024
02:00
2.00 COMPZN, RPCOMP WASH P Cont Washing T/2235' Hard Cement @
shoe 2235 + - Set down 3K w/no wash
off
2,235.0 2,235.0
11/4/2024
02:00
11/4/2024
03:00
1.00 COMPZN, RPCOMP CIRC P C.B.U. @ 5 bbls w/ 350 psi 2,235.0 2,235.0
11/4/2024
03:00
11/4/2024
03:30
0.50 COMPZN, RPCOMP OTHR P POOH 90' Test casing t/500 psi 10 mins
lost 260 PSI Bleed down t/ 0
2,235.0 2,185.0
11/4/2024
03:30
11/4/2024
07:30
4.00 COMPZN, RPCOMP TRIP P POOH L/D 3 1/2" EUE Tubing 2,185.0 0.0
11/4/2024
07:30
11/4/2024
08:30
1.00 COMPZN, RPCOMP CLEN P Rig down 3.5" handling equipment //
clean floor from laying down pipe // MT
3.5" out of pipe shed
0.0 0.0
11/4/2024
08:30
11/4/2024
10:30
2.00 COMPZN, RPCOMP BHAH P Bring in BHA componants for scraper
run and test packer // Make up Scraper
BHA
0.0 15.0
11/4/2024
10:30
11/4/2024
12:30
2.00 COMPZN, RPCOMP TRIP P TIH to 2200' 15.0 2,200.0
11/4/2024
12:30
11/4/2024
13:15
0.75 COMPZN, RPCOMP CIRC P Circulate 5.5 bpm @ 550 psi // slight
cement in returns
2,200.0 2,200.0
11/4/2024
13:15
11/4/2024
14:15
1.00 COMPZN, RPCOMP TRIP P TOOH lay down scraper 2,200.0 0.0
11/4/2024
14:15
11/4/2024
15:30
1.25 COMPZN, RPCOMP TRIP P TIH with test packer // Set @ 2130' 0.0 2,130.0
11/4/2024
15:30
11/4/2024
16:15
0.75 COMPZN, RPCOMP PRTS P Test OA 1500 psi for 30 min 2,130.0 2,130.0
Rig: NORDIC 3
RIG RELEASE DATE 11/6/2024
Page 7/7
2P-451
Report Printed: 11/20/2024
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
11/4/2024
16:15
11/4/2024
18:00
1.75 COMPZN, RPCOMP TRIP P Release packer TOOH for Casing string
run
2,130.0 0.0
11/4/2024
18:00
11/4/2024
19:30
1.50 COMPZN, RPCOMP BHAH P L/D test Packer and R/U t/ Run 5 1/2"
BTCMOD casing w/shoe,GBR equip
0.0
11/4/2024
19:30
11/4/2024
22:00
2.50 COMPZN, RPCOMP PULD P M/U 5 1/2" BTCMOD casing P/U out of
pipe shed T 1892'
11/4/2024
22:00
11/5/2024
00:00
2.00 COMPZN, RPCOMP THGR P P/U Landing Jt and M/U hanger and
land same,Install Pack Off test same
5000 PSI 15 mins All good L/D running
tool Prep f/ P/U 2 7/8 "w/RBP hook up
LRS and pump 5 BBls Down O.A. F/P.
All good Rig Down LRS
11/5/2024
00:00
11/5/2024
01:00
1.00 COMPZN, RPCOMP BHAH P Continue R/U small power Tongs & M/U
YJOS 5 1/2" RBP
0.0 0.0
11/5/2024
01:00
11/5/2024
04:30
3.50 COMPZN, RPCOMP TRIP P P/U out of pipe Shed 2 7/8" 0.0 1,500.0
11/5/2024
04:30
11/5/2024
05:30
1.00 COMPZN, RPCOMP MPSP P Set plug COE 1504' // Pressure test
1500 psi 10 min good test
1,500.0 1,512.0
11/5/2024
05:30
11/5/2024
07:30
2.00 COMPZN, RPCOMP TRIP P TOOH racking stands HT Pac in derrick
L/D YJOS Running tool
1,512.0 0.0
11/5/2024
07:30
11/5/2024
08:30
1.00 COMPZN, RPCOMP CIRC P R/U LRS and pump Diesel fill up casing
t/ surf
0.0 0.0
11/5/2024
08:30
11/5/2024
09:30
1.00 COMPZN, RPCOMP BHAH P Cont R/D Csaing euip and YJOS.Equip 0.0 0.0
11/5/2024
09:30
11/5/2024
15:00
5.50 COMPZN, WHDBOP NUND P N/D BOP N/U Dry hole tree ,Test
Flanget/t/2500 and plug 15 mins PSI .
Off load all fluids, Clean shaker screens.
Downloaded 3rd party tubing handleing
equipment.
0.0 0.0
11/5/2024
15:00
11/5/2024
18:00
3.00 COMPZN, WHDBOP RURD P R/D cellar polly berm. Rig down mud
shack, Smoke shack. Move out
dumpster,
0.0 0.0
11/5/2024
18:00
11/6/2024
00:00
6.00 DEMOB, MOVE OTHR X Due to high wind conditions,crew is on
light duty prepping f/rig move
RIG RELEASE Midnight
0.0 0.0
Rig: NORDIC 3
RIG RELEASE DATE 11/6/2024
ORIGINATED
TRANSMITTAL
DATE: 11/12/2024
ALASKA E-LINE SERVICES
TRANSMITTAL
#: 5150
42260 Kenai Spur Hwy
PO BOX 1481 - Kenai, Alaska 99611 FIELD Meltwater
PH: (907) 283-7374 FAX: (907) 283-7378
DELIVERABLE DESCRIPTION
TICKET # WELL # API #
LOG
DESCRIPTION
DATE OF
LOG
5150 2P-451 50103204020000 Cement Bond Log 31-Oct-2024
RECIPIENTS
ConocoPhillips Alaska, Inc.
DIGITAL FILES PRINTS CD'S
1 0 0 0 USPS
0
0 0
0
Received
By: Received By:
Signature Signature
AOGCC
DIGITAL FILES PRINTS CD'S
1 ShareFile 0 0 USPS
Attn: Natural Resources Technician II
abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision
aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501
Received
By: Received By:
Signature Signature
202-008
T39762
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2024.11.12 09:58:28 -09'00'
DNR
DIGITAL FILES PRINTS CD'S
1 SharePoint
Link 0 0 USPS
Attn: Natural Resource Tech II
DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501
Delivery Method: USPS
Received
By: Received By:
Signature Signature
Please return via e-mail a copy to both:
AR@ake-
line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Jim Regg DATE:
P.I. Supervisor
SUBJECT:
FROM:
Petroleum Inspector
Section: 17 Township: 8N Range: 7E Meridian: Umiat
Drilling Rig: Nordic 3 Rig Elevation: 25 ft Total Depth: 5950 ft MD Lease No.: ADL 0373112
Operator Rep: Suspend: P&A: X
Conductor: 16" O.D. Shoe@ 120 Feet Csg Cut@ NA Feet
Surface: 7-5/8" O.D. Shoe@ 2236 Feet Csg Cut@ NA Feet
Intermediate: NA O.D. Shoe@ NA Feet Csg Cut@ NA Feet
Production: 5-1/2"x3-1/2" O.D. Shoe@ 5927 Feet Csg Cut@ 2295 Feet
Liner: NA O.D. Shoe@ NA Feet Csg Cut@ NA Feet
Tubing: 3-1/2" O.D. Tail@ 5416 Feet Tbg Cut@ 2670 Feet
Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified
Open Hole Bridge plug 2302 ft MD unknown 9.8 ppg N/A
Initial 15 min 30 min 45 min Result
Tubing
IA
OA
Remarks:
Attachments:
I traveled to location to witness the tag and pressure test of the surface casing cement plug. This was to cover up a 59-foot open
hole section below the surface casing shoe. AOGCC approved a variance to 20 AAC 25.112(a)(1)(A). Cement was to be ~ 50
feet below the shoe to ± 150 feet inside the casing. After a twelve hour cure time they started washing down from 1931 ft MD
with the 3.5-inch work string. At 2120 ft MD they started to encounter brief 1K to 4k weight bobbles on the vernier hand with
occasional slight pump pressure increases. They worked down to a foot above the surface casing shoe (2235 ft MD) seeing
multiple spots with the same weight taken. As soon as the string stopped the weight/pump pressure would disappear. At the end
depth of 2235 ft MD, 5k lbs was set down and held. The rig will land out a workstring and move off the well for off-rig remedial
work.
November 4, 2024
Austin McLeod
Well Bore Plug & Abandonment
Kuraruk River Unit 2P-451
ConocoPhillips Alaska, Inc.
PTD 2020080; Sundry 324-506
none
Test Data:
Casing Removal:
Ronnie Dalton
Casing/Tubing Data (depths are MD):
Plugging Data (depths are MD):
rev. 3-24-2022 2024-1104_Plug_Verification_KRU_2P-451_am
9
9
9 9 9 9
9
9
99
9
9
9
9
9
9
9
99 9
9
9
gpp gppp pp
The rig will land out a workstring and move off the well for off-rig remedialp
work.
James B. Regg Digitally signed by James B. Regg
Date: 2024.11.21 15:01:22 -09'00'
ORIGINATED
TRANSMITTAL
DATE: 10/30/2024
ALASKA E-LINE SERVICES
TRANSMITTAL
#: 5146
42260 Kenai Spur Hwy
PO BOX 1481 - Kenai, Alaska 99611 FIELD Meltwater
PH: (907) 283-7374 FAX: (907) 283-7378
DELIVERABLE DESCRIPTION
TICKET # WELL # API #
LOG
DESCRIPTION
DATE OF
LOG
5146 2P-451 50103204020000 Tubing Cut Record 29-Oct-2024
RECIPIENTS
ConocoPhillips Alaska, Inc.
DIGITAL FILES PRINTS CD'S
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AOGCC
DIGITAL FILES PRINTS CD'S
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Attn: Natural Resources Technician II
abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision
aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501
Received
By: Received By:
Signature Signature
202-008
T39723
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2024.10.30 12:50:43 -08'00'
DNR
DIGITAL FILES PRINTS CD'S
1 SharePoint
Link 0 0 USPS
Attn: Natural Resource Tech II
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Received
By: Received By:
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Please return via e-mail a copy to both:
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1a. Well Status:Oil SPLUG Other Abandoned Suspended
1b. Well Class:
20AAC 25.105 20AAC 25.110 Development Exploratory
GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test
2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry:
Aband.:
3. Address: 7. Date Spudded: 15. API Number:
4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number:
Surface:
Top of Productive Interval:17. Field / Pool(s):
GL: BF:
Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation:
4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number:
Surface: x- y- Zone- 4
TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD:
Total Depth: x- y- Zone- 4
5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD:
Submit electronic information per 20 AAC 25.050 N/A (ft MSL)
22. Logs Obtained:
N/A
23.
BOTTOM
16" B 110'
7.625" L-80 2160'
5.5" L-80 5213'
3.5" L-80 5732'
24. Open to production or injection? Yes No 25.
26.
Was hydraulic fracturing used during completion? Yes No
DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED
27.
Date First Production: Method of Operation (Flowing, gas lift, etc.):
Hours Tested: Production for Gas-MCF:
Test Period
Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr):
Press. 24-Hour Rate
5408'
SIZE DEPTH SET (MD)
9. Ref Elevations: KB: 27'
5927'
27'
5213'
62.5#
29.7#
110'
27'
WT. PER
FT.GRADE
442240
442233
Sr Res EngSr Pet GeoSr Pet Eng
Oil-Bbl: Water-Bbl:
31 bbls 15.8 ppg Cement (T x IA balance plug)
Water-Bbl:
PRODUCTION TEST
N/A
Date of Test: Oil-Bbl:
Flow Tubing
3785' (SW TOC) - 5318'
SUSPENDED
5515-5550' MD and 5320-5355' TVD (below cement plug)
5562-5578' MD and 5367-5383' TVD (below cement plug)
Gas-Oil Ratio:Choke Size:
Per 20 AAC 25.283 (i)(2) attach electronic information
N/A
PACKER SET (MD/TVD)
42"
9.875"
392 sx AS I
32'370 sx AS IIIL, 120 sx LiteCrete
9.3#
32'
5408'
2236'32'
32'
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date perf'd or liner run):
15.5#
CEMENTING RECORD
5868526
1379' MD / 1356' TVD
SETTING DEPTH TVD
5868525
TOP HOLE SIZE AMOUNT
PULLEDTOP
SETTING DEPTH MD
suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log,
spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar
locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary.
N/A
BOTTOM
Kuparuk River Field/ Meltwater Oil Pool-
Suspended
N/A
50-103-20402-00-00
KRU 2P-451
ADL 0373112
1036' FNL, 1524' FWL, Sec. 17, T8N, R7E, UM
1364' FNL, 275' FWL, Sec. 17, T8N, R7E, UM
ALK 4998
2/21/2002
5950' MD / 5755' TVD
3785' MD / 3616' TVD
P.O. Box 100360, Anchorage, AK 99510-0360
443484 5868845
1363' FNL, 281' FWL, Sec. 17, T8N, R7E, UM
3/2/2002
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
ConocoPhillips Alaska, Inc.
WAG
Gas
9/5/2024 202-008 / 324-416
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
CASING, LINER AND CEMENTING RECORD
List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion,
(included above) 6.75"
TUBING RECORD
215 sx Class G6.75"
5416' MD3-1/2"
CASING
Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment
By James Brooks at 3:41 pm, Sep 18, 2024
Suspended
9/5/2024
JSB
RBDMS JSB 093024
xGDSR-10/14/24
Conventional Core(s): Yes No Sidewall Cores:
N/A
30.
MD TVD
Surface Surface
1379' 1356'
Top of Productive Interval
N/A
31. List of Attachments: Schematics, Summary of Operations
32. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Contact Name: Katherine O'Connor
Digital Signature with Date:Contact Email: katherine.oconnor@conocophillips.com
Contact Phone:(907) 263-3718
Senior Well Interventions Engineer
General:
Item 1a:
Item 1b:
Item 4b:
Item 9:
Item 15:
Item 19:
Item 20:
Item 22:
Item 23:
Item 24:
Item 27:
Item 28:
Item 30:
Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and
other tests as required including, but not limited to: core analysis, paleontological report, production or well test results.
Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29.
Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool.
If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the
producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,
showing the data pertinent to such interval).
Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit
detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity,
permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology.
Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain).
Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical
laboratory information required by 20 AAC 25.071.
Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion,
suspension, or abandonment; or 90 days after log acquisition, whichever occurs first.
Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345),
and/or Easement (ADL 123456) number.
The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements
given in other spaces on this form and in any attachments.
The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic
diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from
a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071.
INSTRUCTIONS
Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core
analysis, paleontological report, production or well test results, per 20 AAC 25.070.
Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each
segregated pool is a completion.
TPI (Top of Producing Interval).
Authorized Name and
Authorized Title:
N/A- SuspendedFormation Name at TD:
If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if
needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired.
Yes No
Well tested? Yes No
28. CORE DATA
If Yes, list intervals and formations tested, briefly summarizing test results for
each. Attach separate pages if needed and submit detailed test info including
reports and Excel or ASCII tables per 20 AAC 25.071.
NAME
Permafrost - Top
Permafrost - Base
29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS
N/A- Suspended
Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov
Digitally signed by Katherine O'Connor
DN: CN=Katherine O'Connor, O=ConocoPhillips, OU=Wells
Group, E=katherine.oconnor@conocophillips.com, C=US
Reason: I am the author of this document
Location:
Date: 2024.09.18 14:15:23-08'00'
Foxit PDF Editor Version: 13.0.0
Katherine
O'Connor
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag: RKB 5,568.0 2P-451 6/16/2024 rogerba
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Added jet tubing cut 2P-451 9/5/2024 jconne
Notes: General & Safety
Annotation End Date Last Mod By
NOTE: ZONES NOT LOADED INTO WELLVIEW YET 7/29/2009 triplwj
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 32.0 120.0 120.0 62.60 WELDED
SURFACE 7 5/8 6.87 31.5 2,236.2 2,159.7 29.70 L-80 BTCMOD
PRODUCTION
5.5"x3.5" @ 5439'
5 1/2 4.95 26.7 5,927.0 5,732.2 15.50 L-80 BTCMOD
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
26.6
Set Depth …
5,415.7
Set Depth …
5,221.1
String Max No…
3 1/2
Tubing Description
TUBING
Wt (lb/ft)
9.30
Grade
L-80
Top Connection
EUEM
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)
26.6 26.6 0.00 HANGER 8.000 FMC TUBING HANGER 3.500
496.3 495.9 5.54 NIPPLE 4.520 CAMCO DS NIPPLE CAMCO DS 2.875
5,302.7 5,108.1 1.56 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900
5,352.6 5,158.0 1.47 SLEEVE-C 4.500 BAKER CMU SLIDING SLEEVE BAKER CMU 2.813
5,368.6 5,174.0 1.46 NIPPLE 4.520 CAMCO D NIPPLE CAMCO D 2.750
5,413.0 5,218.3 1.42 SEAL 4.500 BAKER GBH-22 LOCATOR/SEAL
ASSY LANDED w/NO GO 2' OFF
PROD CSG LOCATOR @ 5419'
BAKER GBH-22 2.990
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)
2,001.0 1,938.5 20.34 TUBING
PUNCH
TUBING PUNCH, 3FT @ 4
SPF, 0 DEGREE PHASE.
8/26/2024 2.992
2,670.0 2,568.5 20.54 CUT 2.5" JET TUBING CUT 9/5/2024 2.992
5,318.0 5,123.4 1.52 TUBING
PUNCH
TUBING PUNCH, 3FT @ 6
SPF, 0 DEGREE PHASE.
8/6/2024 2.992
5,499.3 5,304.6 1.19 CIBP CIBP MID-ELEMENT AT 5500'
RKB, OAL = 1.37'
7/1/2024 0.000
5,800.1 5,605.4 1.13 Plug Catcher PLUG CATCHER SET IN 3.5"
PRODUCTION CASING
3/2/2002 0.000
Mandrel Inserts : excludes pulled inserts
Top (ftKB)
Top (TVD)
(ftKB)
Top
Incl (°)
St
ati
on
No
/S Serv
Valve
Type
Latch
Type
OD
(in)
TRO Run
(psi) Run Date Com Make Model
Port
Size (in)
5,302.7 5,108.1 1.56 1 GAS LIFT OPEN 1 9/4/2021
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
5,515.0 5,535.0 5,320.3 5,340.3 T-3, 2P-451 10/19/2020 6.0 APERF 2.5" Millenium 6 SPF 60°
Phase
5,535.0 5,550.0 5,340.3 5,355.3 T-3, 2P-451 10/19/2020 6.0 APERF 2.5" Millenium 6 SPF 60°
Phase
5,562.0 5,578.0 5,367.3 5,383.3 T-3, 2P-451 3/24/2002 6.0 IPERF 2.5" HSD 2506 Chgs, 60 deg
phase
Stimulation Intervals
Top (ftKB) Btm (ftKB)
Inter
val
Num
ber Type Subtype Start Date
Proppant
Designed (lb)
Proppant
Total (lb)
Vol Clean
Total (bbl)
Vol Slurry
Total (bbl)
5,562.0 5,578.0 1 FRAC 3/29/2002 0.0 0.00 0.00
Cement Squeezes
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Des Com
Pump Start
Date
5,432.0 5,499.3 5,237.3 5,304.6 Cement Plug Dump bailed cement 7/6/2024
3,785.0 5,321.0 3,616.4 5,126.4 Cement Plug PUMPED 31 BBLS OF 15.8 CLASS G CEMENT
FOR INTERMEDIATE BALANCED PLUG
8/23/2024
5,432.0 5,499.3 5,237.3 5,304.7 Stage
Cementing
PUMPED 31 BBLS OF 15.8 CLASS G CEMENT
FOR INTERMEDIATE BALANCED PLUG
8/23/2024
2P-451, 9/16/2024 5:37:03 PM
Vertical schematic (actual)
PRODUCTION 5.5"x3.5" @
5439'; 26.7-5,927.0
Plug Catcher; 5,800.1
IPERF; 5,562.0-5,578.0
FRAC; 5,562.0
APERF; 5,535.0-5,550.0
APERF; 5,515.0-5,535.0
CIBP; 5,499.3
Stage Cementing; 5,432.0 ftKB
Cement Plug; 5,432.0 ftKB
TUBING PUNCH; 5,318.0
GAS LIFT; 5,302.7
Cement Plug; 3,785.0 ftKB
CUT; 2,670.0
SURFACE; 31.5-2,236.2
TUBING PUNCH; 2,001.0
CONDUCTOR; 32.0-120.0
KUP PROD
KB-Grd (ft) RR Date
3/5/2002
Other Elev…
2P-451
...
TD
Act Btm (ftKB)
5,950.0
Well Attributes
Field Name
MELTWATER
Wellbore API/UWI
501032040200
Wellbore Status
PROD
Max Angle & MD
Incl (°)
21.46
MD (ftKB)
2,866.47
WELLNAME WELLBORE2P-451
Annotation
Last WO:
End DateH2S (ppm)
67
Date
12/21/2013
Comment
SSSV: NIPPLE
DTTMSTART JOBTYP SUMMARYOPS
8/6/2024 ACQUIRE
DATA
LOG CORRELATED TO TUBING TALLY DATED 04-MAR-2002
PUNCHER DEPTH=5318'-5321', CCL OFFSET=7.3', CCL STOP DEPTH=5310.7'
WELL LEFT S/I
8/7/2024 ACQUIRE
DATA
(P&A) CDDT TxIA (PASS)
8/23/2024 ACQUIRE
DATA
INTERMEDIATE CEMENT BALANCE PLUG.
LOAD TBG & IA WITH 9.8 PPG KWF. PUMPED 31 BBLS OF 15.8 PPG CEMENT
& DISPLACED CEMENT w/ 33 BBLS OF 9.8 PPG KWF. PLACING TOC IN TBG &
IA @ ~3815' MD. IN PROGRESS
8/26/2024 ACQUIRE
DATA
PUNCH TUBING OVER INTERVAL: 2001'-2004'. CIRCULATED 50 BBLS DIESEL
FOR FREEZE PROTECT.
JOB COMPLETE, READY FOR SLICKLINE STATE WITNESSED TAG AND TEST
9/2/2024 CHANGE
WELL TYPE
PERFORM STATE WITNESS TAG (Austin McLeod) TOC @ 3785' RKB.
PERFORM PASSING CMIT TO 2500 PSI. READY FOR E-LINE.
NETWORK# 10460711
9/4/2024 ACQUIRE
DATA
(P&A) FUNCTION TEST ALL T LDS/GNS (COMPLETE), T POT (PASSED) T
PPPOT (PASSED), FUNCTION TEST ALL IC LDS/GNS (COMPLETE), IC POT
(PASSED) IC PPPOT (PASSED),
9/5/2024 CHANGE
WELL TYPE
DRIFT TBG W/ 2.61" GUAGE RING TO 3000' RKB, NO WEIGHT SWINGS OR
ANOMALIES, READY FOR E LINE
9/5/2024 CHANGE
WELL TYPE
LOG CORRELATED TO TUBING TALLY DATED 3/4/2002
CUT TUBING W/ 2.5" JRC JET CUTTER AT 2670'
WELL LEFT S/I
NETWORK# 10460711
2P-451 Intermediate Suspend
Summary of Operations
ORIGINATED
TRANSMITTAL
DATE: 9/10/2024
ALASKA E-LINE SERVICES
TRANSMITTAL
#: 5039
42260 Kenai Spur Hwy
PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk River
PH: (907) 283-7374 FAX: (907) 283-7378
DELIVERABLE DESCRIPTION
TICKET # WELL # API #
LOG
DESCRIPTION
DATE OF
LOG
5039 2P-451 50103204020000 Tubing Cut Record 5-Sep-2024
RECIPIENTS
ConocoPhillips Alaska, Inc.
DIGITAL FILES PRINTS CD'S
1 0 0 0 USPS
0
0 0
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By: Received By:
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AOGCC
DIGITAL FILES PRINTS CD'S
1 ShareFile 0 0 USPS
Attn: Natural Resources Technician II
abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision
aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501
Received
By: Received By:
Signature Signature
202-008
T39536
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2024.09.10 11:27:49 -08'00'
DNR
DIGITAL FILES PRINTS CD'S
1 SharePoint
Link 0 0 USPS
Attn: Natural Resource Tech II
DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501
Delivery Method: USPS
Received
By: Received By:
Signature Signature
Please return via e-mail a copy to both:
AR@ake-
line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com
1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown
Suspend Perforate Other Stimulate Pull Tubing Change Approved Program
Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other:
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?
Yes No
9. Property Designation (Lease Number): 10. Field:
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD):
5950'None
Casing Collapse
Structural
Conductor
Surface
Intermediate
Production
Liner
Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft):
12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work:
Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service
14. Estimated Date for 15. Well Status after proposed work:
Commencing Operations: OIL WINJ WDSPL Suspended
16. Verbal Approval: Date: GAS WAG GSTOR SPLUG
AOGCC Representative: GINJ Op Shutdown Abandoned
Contact Name:
Contact Email:
Contact Phone:
Authorized Title:
Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number:
Plug Integrity BOP Test Mechanical Integrity Test Location Clearance
Other Conditions of Approval:
Post Initial Injection MIT Req'd? Yes No
APPROVED BY
Approved by: COMMISSIONER THE AOGCC Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
(907) 263-4597
Senior CTD Engineer
KRU 2P-451
5755' 3815' 3645' 3815', 5432', 5499'
N/A
Subsequent Form Required:
Suspension Expiration Date:
Will perfs require a spacing exception due to property boundaries?
Current Pools:
MPSP (psi): Plugs (MD):
17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval.
Authorized Name and
Digital Signature with Date:
Tubing Size:
shane.germann@conocophillips.com
AOGCC USE ONLY
Tubing Grade: Tubing MD (ft):
5413' MD and 5218' TVD
N/A
Shane Germann
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL0373112
202-008
P.O. Box 100360, Anchorage, AK 99510 50-103-20402-00-00
Kuparuk River Field Meltwater Oil Pool - Suspended
ConocoPhillips Alaska, Inc.
Length Size
Proposed Pools:
PRESENT WELL CONDITION SUMMARY
Meltwater Oil Pool -
Abandoned
TVD Burst
5416'
MD
120'
2160'
120'
2236'
5732'5927'
16"
7-5/8"
88'
2205'
5515-5550', 5562-5578' (below
cement plug)
5900'
5320-5355', 5367-5383'
(below cement plug)
5-1/2" x 3-1/2"
Perforation Depth TVD (ft):
10/20/2024
3-1/2"
Packer: Baker GBH-22 Locator/Seal Assy
SSSV: None
Perforation Depth MD (ft):
L-80
Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
By Grace Christianson at 2:29 pm, Sep 05, 2024
Digitally signed by Shane Germann
DN: O=ConocoPhillips, CN=Shane Germann
, E=shane.germann@conocophillips.com
Reason: I am the author of this document
Location:
Date: 2024.09.05 08:06:04-08'00'
Foxit PDF Editor Version: 13.0.0
324-506
XX
DSR-9/5/24
10-407
A variance from 20 AAC 25.112(a)(1)(A)which requires a cement plug from 100' below the base of the hydrocarbon-bearing strata is
granted to instead allow the recovery of 50' of production casing below the surface casing shoe and a cement plug placed across this
open hole section and 150' into the surface casing.
AOGCC witness required after wellhead cutoff and prior to top job if needed
X
X
A variance to Order 196 is granted that will eliminate the requirement of logging the cement placed across the hydrocarbon-bearing strata.
June 30, 2025
BOP test to 2500 psig
Annular preventer test to 2500 psig
VTL 10/20/24
726
SFD 10/4/2024
Abandon
See attached "Conditions of Approval"
Abandoned
*&:
Jessie L.
Chmielowski
Digitally signed by Jessie L.
Chmielowski
Date: 2024.10.21 20:06:54
-08'00'10/21/24
RBDMS JSB 102224
KRU 2P-451 Abandonment
Conditions of Approval:
1. A variance is granted from 20 AAC 25.112(a)(1)(A) which requires a cement plug from 100'
below the base of the hydrocarbon-bearing strata.
2.A variance is granted under 20 AAC 25.112(i) to allow the alternate plug placement described as
the recovery of 50' of production casing below the surface casing shoe and a cement plug
placed across this open hole section and 150' into the surface casing. The plug must pass a
State Witnessed pressure test and tag according to 20 AAC 25.112(g).
3. A variance to Order 196 is granted that will eliminate the requirement of logging the cement
placed across the hydrocarbon-bearing strata.
4. A failed pressure test of the surface casing shoe plug requires the submission of a new
sundry (10-403) to cover the rigless abandonment scope if planned. Completion of
workover operations under the original sundry will be complete and a 10-407 Well
Completion or Recompletion Report and Log must be filed with the Commission within 30
days following the completion of workover operations.
5. If surface abandonment operations are not initiated within 30 days after the successful
placement of the surface casing shoe plug (State witnessed pressure test and tag), a 10-407
Well Completion or Recompletion Report and Log must be filed with the Commission within
30 days after the completion of workover operations to date.
6. Plugging of the surface of a well must meet the requirements of 20 AAC 25.112(d) and 20
AAC 25.120.
7. AOGCC witness is required after the wellhead cutoff and prior to a top job.
Variances granted provide for at least equally effective plugging of the well and prevention of fluid
movement into sources of hydrocarbons or freshwater.
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Digitally signed by Shane Germann
DN: O=ConocoPhillips, CN=Shane
Germann, E=shane.germann@
conocophillips.com
Reason: I am the author of this
document
Location:
Date: 2024.09.05 08:06:28-08'00'
Foxit PDF Editor Version: 13.0.0
2P-451 Plug and Abandonment
Background & Objective
2P-451 was a producer shut-in in late 2020. It has no known tubing or IA integrity issues. This well
will be P&Ad as part of the 2P pad abandonment. 2P pad does not have any facilities or surface line
hookups, and the pad is slated to be used as storage for the Willow development project in 2026.
This well was suspended via reservoir cement plug and intermediate cement plug. The objective of
this procedure is to pump the surface casing shoe cement plug and final abandonment cement plug
with Nordic 3 and ultimately execute final abandonment.
Well Data
Meltwater Formation:
x Reservoir pressure 6/20/2021 = 2724 psi @ 5400’ TVD
x MASP = 2184 psi
C-80 Formation:
x OAP = 148 psi (11/5/22) (fluid packed with diesel)
x MASP = 726 psi
Anticipated intermediate plug TOC = ~3815’ RKB
Anticipated tubing cut depth = ~2670’ RKB
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2P-451 Well Suspension Schematic
Conductor:
16" Conductor 120' KB
Production Casing Cement:
53 bbls of 15.8# Cement
Calculated TOC @ 2,936' KB
Production Casing:
5.5" x 3.5" @ 5,439' KB, 15.5# x 9.3#,
L-80 BTC Mod
Set @ 5,927’ KB
T-3 Peforations:
@ 5,515'– 5,578' KB (63')
Surface Casing:
7-5/8", 29.7#, L-80 BTC Mod
Set @ 2,236.2' KB (2159' TVD)
Production Tubing:
3 ½”, 9.3# L-80 EUE-8rd
Set @ 6,883.7' KB
1
2
6
5
C80 @ 2520' KB C80 @ 2520' KB
Plug #1 – Reservoir
TOC ±5432' RKB
Plug #2 – Intermediate
TOC ±3815' RKB
BOC @ ±5315' RKB
3
4
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Surface Casing Plugs – Rig
Date: 8-30-2024
Prepared by: Shane Germann
Estimated Start Date: 10-20-2024
MIRU
1. MIRU on 2P-451.
2. Record shut-in pressures on the T & IA. If there is pressure, bleed oƯ IA and/or tubing
pressure and complete 30-minute NFT. Verify well is dead before proceeding.
3. ND Tree and NU BOPE. Test rams and annular to 250/2,500 PSI.
a. Will not set BPV due to two tested cement plugs below providing two barriers to
formation.
b. BOPE ConƱguration: Annular / Variable Bore Rams / Blind Rams / Pipe Rams
4. Circulate tubing and IA to brine.
Retrieve Tubing
5. MU landing joint and BOLDS.
6. Pull tubing from pre-rig cut to surface and LD.
Execute First Surface Casing Abandonment Plug
1. Set bridge plug in production casing 100’ MD below surface casing shoe
2. Cut production casing 50’ MD below surface casing shoe
3. Circulate OA to brine and complete 30-minute NFT.
a. Punch holes in production casing at the surface casing shoe if unable to achieve
circulation from production casing cut.
4. MU landing joint for production casing hanger and conƱrm casing is free from cut.
a. Contingency: If unable to pull production casing from original cut depth
i. Perform second cut inside surface casing shoe
ii. Pull casing down to upper cut and laydown
iii. PU DP and Ʊshing assembly
iv. TIH and engage cut stub of prod casing. Fish stub free.
v. Retrieve to surface. LD DP
5. Pump cement plug through the production casing cut. Utilize ~11 BBL of cement, plus
excess, to target a Ʊnal TOC ±150’ TVD inside the surface casing shoe. Slightly under
displace cement and pull 5-1/2” casing slowly to above Ʊnal TOC - allowing cement to Ʊll
the space vacated by the casing displacement. Ensure base of 5-1/2” casing is between
150’ – 200’ TVD inside the surface casing shoe based on space out of a casing collar at the
Ʋoor. Circulate the base of the prod casing clear of any residual cement. See table below for
cement volume calculations.
a. Contingency: if unable to pull prod casing from original cut depth
i. TIH with tubing to above the casing shoe
ii. Pump cement plug across the shoe through the tubing. PU and circulate the
base of the tubing clear
b. A Variance is requested to 20 AAC 25.112 requiring cement 100’ below hydrocarbon
bearing zones. It is our intention to recover 50’ of production casing from the open
hole section.
c. A Variance is requested to Order 196 requiring the cement to be logged. It is not our
intention, nor recommendation for the integrity of the abandonment, to drill out the
cement plug once pumped.
6. WOC
7. Tag cement and PT to 1,500 PSI with state witness
a. Pressure up to FIT equivalent and hold for 10 min to ensure no leak oƯ prior to
increasing pressure to full 1,500 PSI for 30-min state witness
b. If PT fails, the well will be suspended with KWF and a kill string in preparation for o Ư-
rig remediation.
2P-451 Well Surface Shoe Cement Schematic
Conductor:
16" Conductor 120' KB
Production Casing Cement:
53 bbls of 15.8# Cement
Calculated TOC @ 2,936' KB
Production Casing:
5.5" x 3.5" @ 5,439' KB, 15.5# x 9.3#,
L-80 BTC Mod
Set @ 5,927’ KB
T-3 Peforations:
@ 5,515'– 5,578' KB (63')
Surface Casing:
7-5/8", 29.7#, L-80 BTC Mod
Set @ 2,236.2' KB (2159' TVD)
Production Tubing:
3 ½”, 9.3# L-80 EUE-8rd
Set @ 6,883.7' KB
6
5
C80 @ 2520' KB C80 @ 2520' KB
Plug #1 – Reservoir
TOC ±5432' RKB
Plug #2 – Intermediate
TOC ±3815' RKB
BOC @ ±5315' RKB
Plug #3 – Surface Shoe
TOC 2076' RKB (2009' TVD)
BOC @ ±2340' RKB
Base of 5-½” Casing
200'-250' MD Inside
Surface Shoe
1
2
3
4
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Execute Final Abandonment Plug
8. Land workstring in casing hanger proƱle.
9. Circulate cement surface to surface until full cement returns observed on surface. See
table below for cement volumes.
RDMO
10. ND BOPE. NU dry hole tree.
a. Note: this step may be performed prior to pumping Ʊnal surface to surface
abandonment plug.
11. RDMO.
Cement Plug TOC BOC Section ID BBL/FT Volume Notes
Surface Shoe
2286 2336 Open Hole 6.75 0.03867 1.9 Displacement of Prod Casing
Stub Included in BBL/FT calc
2236 2286 Open Hole 6.75 0.04426 2.2
2076 2236 Surface Casing 6.87 0.04585 7.3
11.4 Total Volume of Plug
Surface Casing 23 2076 Surface Casing 6.87 0.04026 82.7 Displacement of Prod Casing
Included in BBL/FT calculation
Execute Final Abandonment
Surface Excavation
12. DHD to perform drawdown test on tubing, IA, and OA
13. Remove well house.
14. Bleed oƯ T/I/O to ensure all pressure is bled oƯ the system.
15. Remove tree in preparation for excavation and casing cut.
16. If shallow thaw conditions are found, have shoring box installed during the excavation
activity to prevent loose ground from falling into the excavation.
17. Cut oƯ wellhead and all casing strings at 4 feet below original ground level.
18. Perform top job if needed to ensure cement is at surface on all strings. AOGCC witness and
photo document required.
19. Send the casing head with stub to materials shop. Photo document.
20. Weld 1/4" thick cover plate (16" OD) over all casing strings with the following information
bead welded into the top. Photo document. AOGCC witness required.
a. ConocoPhillips
b. KRU 2P-451
c. PTD #: 202-008
d. API #: 50-103-20402-00-00
21. Remove cellar. Back Ʊll cellar with gravel/Ʊll as needed. Back Ʊll remaining hole to ground
level.
22. Obtain site clearance approval from AOGCC. RDMO.
23. Report the Ʊnal P&A has been completed to the AOGCC. Photo document Ʊnal location
condition after work is completed
Plug #4 – Surface
TOC 23' RKB
BOC @ ±2076' RKB
2P-451 Well Final P&A Schematic
Conductor:
16" Conductor 120' KB
Production Casing Cement:
53 bbls of 15.8# Cement
Calculated TOC @ 2,936' KB
Production Casing:
5.5" x 3.5" @ 5,439' KB, 15.5# x 9.3#,
L-80 BTC Mod
Set @ 5,927’ KB
T-3 Peforations:
@ 5,515'– 5,578' KB (63')
Surface Casing:
7-5/8", 29.7#, L-80 BTC Mod
Set @ 2,236.2' KB (2159' TVD)
Production Tubing:
3 ½”, 9.3# L-80 EUE-8rd
Set @ 6,883.7' KB
7
6
C80 @ 2520' KB C80 @ 2520' KB
Plug #1 – Reservoir
TOC ±5432' RKB
Plug #2 – Intermediate
TOC ±3815' RKB
BOC @ ±5315' RKB
Plug #3 – Surface Shoe
TOC 2076' RKB (2009' TVD)
BOC @ ±2340' RKB
1
2
3
54
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Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag: RKB 5,568.0 2P-451 6/16/2024 rogerba
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Punch Tubing 2P-451 8/26/2024 bworthi1
Notes: General & Safety
Annotation End Date Last Mod By
NOTE: ZONES NOT LOADED INTO WELLVIEW YET 7/29/2009 triplwj
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 32.0 120.0 120.0 62.60 WELDED
SURFACE 7 5/8 6.87 31.5 2,236.2 2,159.7 29.70 L-80 BTCMOD
PRODUCTION
5.5"x3.5" @ 5439'
5 1/2 4.95 26.7 5,927.0 5,732.2 15.50 L-80 BTCMOD
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
26.6
Set Depth …
5,415.7
Set Depth …
5,221.1
String Max No…
3 1/2
Tubing Description
TUBING
Wt (lb/ft)
9.30
Grade
L-80
Top Connection
EUEM
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)
26.6 26.6 0.00 HANGER 8.000 FMC TUBING HANGER 3.500
496.3 495.9 5.54 NIPPLE 4.520 CAMCO DS NIPPLE CAMCO DS 2.875
5,302.7 5,108.1 1.56 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900
5,352.6 5,158.0 1.47 SLEEVE-C 4.500 BAKER CMU SLIDING SLEEVE BAKER CMU 2.813
5,368.6 5,174.0 1.46 NIPPLE 4.520 CAMCO D NIPPLE CAMCO D 2.750
5,413.0 5,218.3 1.42 SEAL 4.500 BAKER GBH-22 LOCATOR/SEAL
ASSY LANDED w/NO GO 2' OFF
PROD CSG LOCATOR @ 5419'
BAKER GBH-22 2.990
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)
2,001.0 1,938.5 20.34 TUBING
PUNCH
TUBING PUNCH, 3FT @ 4
SPF, 0 DEGREE PHASE.
8/26/2024 2.992
5,318.0 5,123.4 1.52 TUBING
PUNCH
TUBING PUNCH, 3FT @ 6
SPF, 0 DEGREE PHASE.
8/6/2024 2.992
5,499.3 5,304.6 1.19 CIBP CIBP MID-ELEMENT AT 5500'
RKB, OAL = 1.37'
7/1/2024 0.000
5,800.1 5,605.4 1.13 Plug Catcher PLUG CATCHER SET IN 3.5"
PRODUCTION CASING
3/2/2002 0.000
Mandrel Inserts : excludes pulled inserts
Top (ftKB)
Top (TVD)
(ftKB)
Top
Incl (°)
St
ati
on
No
/S Serv
Valve
Type
Latch
Type
OD
(in)
TRO Run
(psi) Run Date Com Make Model
Port
Size (in)
5,302.7 5,108.1 1.56 1 GAS LIFT OPEN 1 9/4/2021
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
5,515.0 5,535.0 5,320.3 5,340.3 T-3, 2P-451 10/19/2020 6.0 APERF 2.5" Millenium 6 SPF 60°
Phase
5,535.0 5,550.0 5,340.3 5,355.3 T-3, 2P-451 10/19/2020 6.0 APERF 2.5" Millenium 6 SPF 60°
Phase
5,562.0 5,578.0 5,367.3 5,383.3 T-3, 2P-451 3/24/2002 6.0 IPERF 2.5" HSD 2506 Chgs, 60 deg
phase
Stimulation Intervals
Top (ftKB) Btm (ftKB)
Inter
val
Num
ber Type Subtype Start Date
Proppant
Designed (lb)
Proppant
Total (lb)
Vol Clean
Total (bbl)
Vol Slurry
Total (bbl)
5,562.0 5,578.0 1 FRAC 3/29/2002 0.0 0.00 0.00
Cement Squeezes
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Des Com
Pump Start
Date
5,432.0 5,499.3 5,237.3 5,304.6 Cement Plug Dump bailed cement 7/6/2024
3,815.0 5,321.0 3,645.2 5,126.4 Cement Plug PUMPED 31 BBLS OF 15.8 CLASS G CEMENT
FOR INTERMEDIATE BALANCED PLUG
8/23/2024
2P-451, 8/26/2024 2:01:41 PM
Vertical schematic (actual)
PRODUCTION 5.5"x3.5" @
5439'; 26.7-5,927.0
FLOAT SHOE; 5,926.4-5,927.0
FLOAT COLLAR; 5,831.7-
5,832.3
Plug Catcher; 5,800.1
FRAC; 5,562.0
IPERF; 5,562.0-5,578.0
APERF; 5,535.0-5,550.0
APERF; 5,515.0-5,535.0
CIBP; 5,499.3
Cement Plug; 5,432.0 ftKB
CSR; 5,420.0-5,439.4
LOCATOR; 5,418.9-5,420.0
SEAL; 5,413.0
SBE; 5,408.8-5,418.9
NIPPLE; 5,368.6
SLEEVE-C; 5,352.6
TUBING PUNCH; 5,318.0
GAS LIFT; 5,302.7
Cement Plug; 3,815.0 ftKB
SURFACE; 31.5-2,236.2
FLOAT SHOE; 2,234.7-2,236.2
FLOAT COLLAR; 2,146.5-
2,147.9
TUBING PUNCH; 2,001.0
PORT COLLAR; 1,024.9-
1,027.3
NIPPLE; 496.3
CONDUCTOR; 32.0-120.0
HANGER; 31.5-34.0
HANGER; 26.6
HANGER; 26.7-29.3
KUP PROD
KB-Grd (ft) RR Date
3/5/2002
Other Elev…
2P-451
...
TD
Act Btm (ftKB)
5,950.0
Well Attributes
Field Name
MELTWATER
Wellbore API/UWI
501032040200
Wellbore Status
PROD
Max Angle & MD
Incl (°)
21.46
MD (ftKB)
2,866.47
WELLNAME WELLBORE2P-451
Annotation
Last WO:
End DateH2S (ppm)
67
Date
12/21/2013
Comment
SSSV: NIPPLE
CAUTION: This email originated from outside the State of Alaska mail system. Do not
click links or open attachments unless you recognize the sender and know the content
is safe.
From:Germann, Shane
To:Loepp, Victoria T (OGC); Hobbs, Greg S
Cc:Dewhurst, Andrew D (OGC); Davies, Stephen F (OGC); O"Connor, Katherine
Subject:RE: [EXTERNAL]DS-2P Surface casing shoe abandonment operations questions
Date:Monday, September 30, 2024 3:20:07 PM
Victoria,
Greg Hobbs, Katherine O’Connor, and I compiled the answers in red to your questions below.
They should fill in points that were made in prior meeting discussions but not fully captured.
Let me know if anything further is needed.
Thanks,
Shane Germann
CTD/RWO Engineer
ConocoPhillips Alaska
Office: 907-263-4597
Cell: 406-670-1939
700 G St, ATO 664, Anchorage, AK 99501
From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>
Sent: Monday, September 30, 2024 11:28 AM
To: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Germann, Shane
<Shane.Germann@conocophillips.com>
Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Davies, Stephen F (OGC)
<steve.davies@alaska.gov>
Subject: [EXTERNAL]DS-2P Surface casing shoe abandonment operations questions
CAUTION:This email originated from outside of the organization. Do not click links or open
attachments unless you recognize the sender and know the content is safe.
Greg, Shane,
Outlined below are several requests/questions concerning the DS-2P
future abandonments:
1. I know we have reviewed this question in meetings but would like a
written response to this question: What are the
advantages/disadvantages to using the production casing as the
cementing string?
Efficiency and reduction of pipe handling on-rig are the biggest
advantages. Pulling the PC on each well would add a substantial
amount of rig time and pipe handling for the crews throughout the
entirety of the campaign. The only disadvantage of using the PC as
the cementing string is the tighter annulus clearance which can
increase the likelihood of cement contamination versus using a
smaller string. Our goal is to utilize the PC successfully considering
the changes we’re making to cement designs, but we’ll keep the
option open to use a smaller string (most likely 3.5” tubing) if we’re
seeing issues.
2. We had discussion concerning cutting the production casing 50’
below the surface casing shoe versus a deeper cut. There was some
discussion on the value of logging prior to making the cut. Also, there
was past experience information presented. Please provide
information justifying the 50’ cut below the surface casing shoe.
Experience with casing recovery operations have found that logs
may not show the extent of formation collapse around casing that
prevents it from being movable. The most recent example of this
was 3S-626 where logs showed free pipe, but cement debris led to
the pipe being pulled in 40-foot sections or less due to the cement
debris around it that was not noted from the logging pass. Greg
Hobbs brought extensive experience with slot recovery operations
from BP. That experience found that recovery of casing deeper than
50 feet below the surface casing shoe became significantly harder
with multiple cuts and jarring operations to retrieve the short sections
of casing. This experience was replicated in the few slot recovery
operations at Kuparuk in the past 10 years. The reflection of this
experience during our meetings led to the intermediate casing cut
point 50 feet below the surface shoe.
3. What modifications have been made in the cementing procedure for
the surface casing shoe plug given the difficulties in setting the plug
for 2P-415A?
Here are the cement design and procedure changes we’re targeting
for this campaign:
a. Targeting a 150’ TVD cement height instead of MD
b. Cement design- additives being utilized to help combat microannuli
and improve bond to casing
c. Improvements to wellbore cleanup techniques prior to pumping
cement (surfactant wash targeting a minimum contact time)
d. Batch mixing cement instead of mixing on the fly
4. If the well is suspended and the rig moved off, what are the plans,
including timing for the non-rig abandonment?
The general plan is to cleanout cement to the surface casing shoe
using a coil underreamer. Then do a hesitation squeeze program
with a fairly aggressive cement ramp, and lay in the same size plug
as the rig laid in. Specific timing for this would be based on SIMOPS
with the rig & excavation crew, but intention would be to follow the
rig timing fairly closely. The hope is still to get these wells fully
abandoned ASAP.
5. What are the timing plans for the surface abandonments included in
these sundries?
After the rig is successful abandoning the wells to surface, the
excavation crew will be following ~4 wells behind to do the
excavation and cuts.
Thank you,
Victoria
Victoria Loepp
Senior Petroleum Engineer
Alaska Oil & Gas Conservation Commission
Work: (907)793-1247
From:Germann, Shane
To:Loepp, Victoria T (OGC)
Subject:RE: [EXTERNAL]Meltwater C-80 Abandonment Sundries: KRU 2P-448, 2P-449, 2P-451
Date:Wednesday, September 25, 2024 2:52:29 PM
Hi Victoria,
That's correct, the depths provided are the top of the C-80. For the C-80 bottom depths, our geologist informed me
to use the top of the C37 which should be picked on each of the logs I sent you. He said the C-37 marker is the next
best correlative marker below the C-80 marker. I have provided those depths below:
2P-451 - 3556' RKB
2P-449 - 5119' RKB
2P-448A - 4594' RKB
We are planning to have 15 sundries/wells will this type of SC shoe cement plug.
Thanks,
Shane Germann
CTD/RWO Engineer
ConocoPhillips Alaska
Office: 907-263-4597
Cell: 406-670-1939
700 G St, ATO 664, Anchorage, AK 99501
-----Original Message-----
From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>
Sent: Wednesday, September 25, 2024 1:48 PM
To: Germann, Shane <Shane.Germann@conocophillips.com>
Subject: [EXTERNAL]Meltwater C-80 Abandonment Sundries: KRU 2P-448, 2P-449, 2P-451
For the three sundries, please send me the C80 bottom depths, RKB. I'm assuming the depths provided are the top
of the C-80?
Also, how many sundries(wells) will have this type of plug at the SC shoe?
-----Original Message-----
From: Germann, Shane <Shane.Germann@conocophillips.com>
Sent: Tuesday, September 17, 2024 9:11 AM
To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>
Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Davies, Stephen F (OGC)
<steve.davies@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>
Subject: RE: [EXTERNAL]Meltwater C-80 Abandonment Sundries: KRU 2P-448, 2P-449, 2P-451
CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open
attachments unless you recognize the sender and know the content is safe.
Hi Victoria,
I attached a PDF version of the slides I created for the 3 wells. Each well has a slide with its log and the desired
annotations described below. Please let me know if you have any questions.
Thanks,
Shane Germann
CTD/RWO Engineer
ConocoPhillips Alaska
Office: 907-263-4597
Cell: 406-670-1939
700 G St, ATO 664, Anchorage, AK 99501
-----Original Message-----
From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>
Sent: Friday, September 13, 2024 3:08 PM
To: Germann, Shane <Shane.Germann@conocophillips.com>
Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Davies, Stephen F (OGC)
<steve.davies@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>
Subject: [EXTERNAL]Meltwater C-80 Abandonment Sundries: KRU 2P-448, 2P-449, 2P-451
CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless
you recognize the sender and know the content is safe.
Shane,
Please provide for each well a log showing the C-80 and the depths of the SC shoe, retainer, cement plug TOC, TOC
outside PC and PC cut.
Victoria
Victoria Loepp
Senior Petroleum Engineer
Alaska Oil & Gas Conservation Commission
Work: (907)793-1247
1
Christianson, Grace K (OGC)
From:Loepp, Victoria T (OGC)
Sent:Monday, October 21, 2024 4:07 PM
To:Christianson, Grace K (OGC)
Subject:Fwd: [EXTERNAL]KRU DS-2P Sundries: Previous plug PT and tag
Please PDF this email and add it to the 3 2P sundries in the Commissioners folders
Thank you
Sent from my iPhone
Begin forwarded message:
From: "Germann, Shane" <Shane.Germann@conocophillips.com>
Date: October 21, 2024 at 3:57:14ௗPM AKDT
To: "Loepp, Victoria T (OGC)" <victoria.loepp@alaska.gov>
Cc: "Hobbs, Greg S" <Greg.S.Hobbs@conocophillips.com>, "O'Connor, Katherine"
<Katherine.OConnor@conocophillips.com>
Subject: RE: [EXTERNAL]KRU DS-2P Sundries: Previous plug PT and tag
Hi Victoria,
See below table for the data requested. This should cover the sundries submitted so far except for the
2P-434 which we’re checking pressures on. These pressures are the latest I had available which is from
the most recent work done on the well. If more recent pressures are desired, please advise as we’ll
have to request somebody take the readings. Keep in mind that other prep work being done on the
wells may affect the T&IA pressures due to U-tubing, circ outs, temperature changes, etc.
I’ll make sure to include this data for future submissions as well as show the actual TOC depths for
previous plugs on the schematics.
Well
Name
Previous plug
tag depth (RKB)
PT
Result
PT/Tag
Date
Tubing
Pressure
IA
Pressure
OA
Pressure
Date of
Pressures
2P-451 3785' Pass 9/2/2024 50 psi 50 psi 75 psi 9/5/2024
2P-449 7187' Pass 9/2/2024 0 psi 75 psi 190 psi 9/3/2024
2P-448A 5076' Pass 10/5/2024 0 psi 0 psi 220 psi 10/6/2024
2P-443 3789' Pass 9/2/2024 0 psi 0 psi 175 psi 9/4/2024
2P-441 3846' Pass 10/5/2024 0 psi 0 psi 230 psi 10/17/2024
2P-438 6495' Pass 9/2/2024 0 psi 0 psi 175 psi 9/3/2024
Thanks,
Shane Germann
CTD/RWO Engineer
CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open
attachments unless you recognize the sender and know the content is safe.
2
ConocoPhillips Alaska
Office: 907-263-4597
Cell: 406-670-1939
700 G St, ATO 664, Anchorage, AK 99501
From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>
Sent: Monday, October 21, 2024 12:36 PM
To: Germann, Shane <Shane.Germann@conocophillips.com>
Subject: [EXTERNAL]KRU DS-2P Sundries: Previous plug PT and tag
CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you
recognize the sender and know the content is safe.
Shane,
Please provide the following information for each 2P well abandonment sundry.
1. Date and results of passing state witnessed PT and tag of previous plug.
2. Current pressures of all annuli and tubing.
Please provide for 2P-448A, 2P-449 and 2P-451 asap and follow with the others.
Thank you,
Victoria
Victoria Loepp
Senior Petroleum Engineer
Alaska Oil & Gas Conservation Commission
Work: (907)793-1247
ORIGINATED
TRANSMITTAL
DATE: 9/3/2024
ALASKA E-LINE SERVICES
TRANSMITTAL
#: 5023
42260 Kenai Spur Hwy
PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk
PH: (907) 283-7374 FAX: (907) 283-7378
DELIVERABLE DESCRIPTION
TICKET # WELL # API #
LOG
DESCRIPTION
DATE OF
LOG
5023 2P-451 50103204020000 Tubing Puncher Record 26-Aug-2024
RECIPIENTS
Conoco
DIGITAL FILES PRINTS CD'S
1 FTP Transfer 0 0 USPS
Attn: NSK-69
tom.osterkamp@conocophillips.com 700 G Street
Anchorage, AK 99503
Received
By: Received By:
Signature Signature
AOGCC
DIGITAL FILES PRINTS CD'S
1 SharePoint
Link 0 0 USPS
Attn: Natural Resources Technician II
abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision
333 W. 7th Ave, Suite 100 - Anchorage, AK 99501
Received
By: Received By:
Signature Signature
202-008
T39516
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2024.09.04 10:13:13 -08'00'
DNR
DIGITAL FILES PRINTS CD'S
1 SharePoint
Link 0 0 USPS
Attn: Natural Resource Tech II
DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501
Delivery Method: USPS
Received
By: Received By:
Signature Signature
Please return via e-mail a copy to both:
AR@ake-
line.com tom.osterkamp@conocophillips.com
ORIGINATED
TRANSMITTAL
DATE: 8/8/2024
ALASKA E-LINE SERVICES
TRANSMITTAL
#: 4982
42260 Kenai Spur Hwy
PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk
PH: (907) 283-7374 FAX: (907) 283-7378
DELIVERABLE DESCRIPTION
TICKET # WELL # API #
LOG
DESCRIPTION
DATE OF
LOG
4982 2P-451 501032040200 Tubing Puncher Record 6-Aug-2024
RECIPIENTS
ConocoPhillips Alaska, Inc.
DIGITAL FILES PRINTS CD'S
1 0 0 0 USPS
0
0 0
0
Received
By: Received By:
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AOGCC
DIGITAL FILES PRINTS CD'S
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Attn: Natural Resources Technician II
abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision
333 W. 7th Ave, Suite 100 - Anchorage, AK 99501
Received
By: Received By:
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202-008
T39393
Gavin Gluyas
Digitally signed by Gavin
Gluyas
Date: 2024.08.08 13:38:28
-08'00'
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Delivery Method: USPS
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Please return via e-mail a copy to both:
AR@ake-
line.com 0
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Jim Regg DATE:
P.I. Supervisor
SUBJECT:
FROM:
Petroleum Inspector
Section:17 Township:8N Range:7E Meridian:Umiat
Drilling Rig:NA Rig Elevation:NA Total Depth:5950 ft MD Lease No.:ADL 0373112
Operator Rep:Suspend:X P&A:NA
Conductor:16"O.D. Shoe@ 120 Feet Csg Cut@ NA Feet
Surface:7-5/8"O.D. Shoe@ 2236 Feet Csg Cut@ NA Feet
Intermediate:NA O.D. Shoe@ NA Feet Csg Cut@ NA Feet
Production:5-1/2" x 3-1/2"O.D. Shoe@ 5927 Feet Csg Cut@ NA Feet
Liner:NA O.D. Shoe@ NA Feet Csg Cut@ NA Feet
Tubing:3-1/2"O.D. Tail@ 5416 Feet Tbg Cut@ NA Feet
Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified
Fullbore Balanced 5318 ft MD 3785 ft MD 9.8/6.7 ppg Wireline tag
Initial 15 min 30 min 45 min Result
Tubing 1720 1660 1630
IA 1850 1770 1740
OA 187 182 178
Initial 15 min 30 min 45 min Result
Tubing
IA
OA
Remarks:
Attachments:
I traveled to location to witness the slickline tag and combo mechanical integrity test (CMIT TxIA) of the intermediate cement
plug that was pumped on 8/23/2024. With an 1-3/4 inch bailer assembly they tagged at 3785 ft MD (minimal inclination) with
multiple hard set downs. Sample observed in bailer. With the tubing punched above us at 2001 ft MD they then completed a
passing CMIT to a target of 1500psi. Tubing punched at 5318 ft MD (bottom depth of plug) prior to cement job.
August 2, 2024
Austin McLeod
Well Bore Plug & Abandonment
Kuparuk River Unit 2P-451
ConocoPhillips Alaska, Inc.
PTD 2020080; Sundry 324-416
none
Test Data:CMIT TXIA
P
Casing Removal:
Sid Ferguson
Casing/Tubing Data (depths are MD):
Plugging Data (depths are MD):
rev. 3-24-2022 2024-0902_Plug_Verification_KRU_2P-451_am
Operations shutdownRepair WellFracture StimulatePlug PerforationsAbandon1. Type of Request:
Change Approved ProgramPull TubingOther StimulatePerforateSuspend
Alter Casing Other: Suspend-Intermediate PlugPerforate New Pool Re-enter Susp WellPlug for Redrill
5. Permit to Drill Number:4. Current Well Class:2. Operator Name:
DevelopmentExploratory
3. Address:ServiceStratigraphic 6. API Number:
8. Well Name and Number:7. If perforating:
What Regulation or Conservation Order governs well spacing in this pool?
NoYes
10. Field:9. Property Designation (Lease Number):
11.
Junk (MD):Effective Depth TVD:Effective Depth MD:Total Depth TVD (ft):Total Depth MD (ft):
None5950'
CollapseCasing
Structural
Conductor
Surface
Intermediate
Production
Liner
Packers and SSSV MD (ft) and TVD (ft):Packers and SSSV Type:
13. Well Class after proposed work:12. Attachments: Proposal Summary Wellbore schematic
ServiceDevelopmentExploratory StratigraphicDetailed Operations Program BOP Sketch
15. Well Status after proposed work:14. Estimated Date for
WDSPLOIL WINJCommencing Operations:Suspended
SPLUGGSTORWAGGASDate:16. Verbal Approval:
AOGCC Representative: GINJ AbandonedOp Shutdown
Contact Name:
Contact Email:
Contact Phone:
Authorized Title:
Sundry Number:Conditions of approval: Notify AOGCC so that a representative may witness
Location ClearancePlug Integrity BOP Test Mechanical Integrity Test
Other Conditions of Approval:
Post Initial Injection MIT Req'd? NoYes
APPROVED BY
Date:THE AOGCCCOMMISSIONERApproved by:
Sr Res EngSr Pet GeoSr Pet EngComm.Comm.
3-1/2"
Packer: Baker GBH-22 Loactor/Seal Assy
SSSV: None
Perforation Depth MD (ft):
L-80
2205'
5515-5550', 5562-5578' (below
cement plug)
5900'
5320-5355', 5367-5383'
(below cement plug)
5-1/2" x 3-1/2"
Perforation Depth TVD (ft):
120'
2236'
5732'5927'
16"
7-5/8"
88'
5416'
MD
120'
2160'
ConocoPhillips Alaska, Inc.
SizeLength
Proposed Pools:
PRESENT WELL CONDITION SUMMARY
Meltwater Oil Pool -
Suspended
BurstTVD
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL0373112
202-008
P.O. Box 100360, Anchorage, AK 99510 50-103-20402-00-00
Kuparuk River Field Meltwater Oil Pool - Suspended
AOGCC USE ONLY
Tubing MD (ft):Tubing Grade:
5413' MD and 5218' TVD
N/A
Katherine O'Connor
Subsequent Form Required:
Suspension Expiration Date:
Will perfs require a spacing exception due to property boundaries?
Current Pools:
MPSP (psi):
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:
katherine.oconnor@conocophillips.com
(907) 263-3718
Well Interventions Engineer
KRU 2P-451
21845237'5432'5755'
N/A
Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
Plugs (MD):
5432'
07/22/2024
Digitally signed by Katherine O'Connor
DN: CN=Katherine O'Connor, O=ConocoPhillips,
OU=Wells Group, E=katherine.oconnor@
conocophillips.com, C=US
Reason: I am the author of this document
Location:
Date: 2024.07.17 16:33:43-08'00'
Foxit PDF Editor Version: 13.0.0
Katherine
O'Connor
324-416
By Grace Christianson at 8:07 am, Jul 18, 2024
VTL 7/18/2024
X
10-407
A.Dewhurst 19JUL24
DSR-7/18/24
X
*&:
Jessie L.
Chmielowski
Digitally signed by Jessie L.
Chmielowski
Date: 2024.07.22 11:17:10
-08'00'07/22/24
RBDMS JSB 072324
2P-451 Intermediate Plug
Prepared by: Katherine O’Connor (214-684-7400)
Background & Objecve
2P-451 was a producer shut-in in late 2020. It has no known tubing or IA integrity issues. This well is
ultimately slated to be P&Ad on rig as part of the 2P pad abandonment. 2P pad does not have any
facilities or surface line hookups, and the pad is slated to be used as storage for Willow development
project in 2026. This well was suspend via reservoir plug. The objective of this procedure is to pump an
intermediate cement plug before rig P&A in Q4 2024.
Well Data
Reservoir pressure 06/20/21 = 2724 psi at 5400’ TVD = 0.504 psi/ft
MASP = 2184 psi
CMIT-TxIA passed 7/12/24
Procedure
Wireline & Pumping
1. Punch tubing at ±5315’ RKB
2. Pump the following schedule taking returns up the IA:
a. ±30 bbls surfactant wash
b. ±125 bbls KWF
c. ±31 bbls cement
d. ±33 bbls KWF displacement
3. This should leave TOC in tubing and IA hydrostatically balanced with cement top at 3815’ MD
1. RIH and tag TOC and perform CMIT-TxIA to 1500 psi (AOGCC Witnessed)
Eline/Relay
4. Cut tubing at ±2670’ RKB
Top Bottom Size ID bbls/ft ft volume ft/bbl notes
3-1/2" tubing 0 5315 3.5" 9.3# 2.99" 0.0087 5315 46.2 115.1 from punch depth
3-1/2" x 5-1/2" Annulus 0 5315 3.5" 9.3# x 5.5" 15.5# 4.95" x 3.5" 0.0119 5315 63.3 84.0 from punch depth
Tubing Cement 3815 5315 3.5" 9.3# 2.99" 0.0087 1500 13.0 115.1
Annular Cement 3815 5315 3.5" 9.3# x 5.5" 15.5# 4.95" x 3.5" 0.0119 1500 17.9 84.0
2P-451 Well Schematic
Conductor:
16" Conductor 120' KB
Production Casing Cement:
53 bbls of 15.8# Cement
Calculated TOC @ 2,936' KB
Production Casing:
5.5" x 3.5" @ 5,439' KB, 15.5# x 9.3#,
L-80 BTC Mod
Set @ 5,927’ KB
T-3 Peforations:
@ 5,515'– 5,578' KB (63')
Surface Casing:
7-5/8", 29.7#, L-80 BTC Mod
Set @ 2,236.2' KB
Production Tubing:
3 ½”, 9.3# L-80 EUE-8rd
Set @ 6,883.7' KB
1
2
3
7
5
6
4
Item Depth - tops (KB)
1 FMC Tubing Hanger 26.6'
2 Camco DS Nipple 496.3'
3 Baker CMU Sliding Sleeve 5,352.6'
4 Tubing Plug 5,368'
5 Camco D Nipple 5,368.6'
6
Baker GBH-22 Locator/Seal
Assembly Landed w/ No Go 2' Off
Prod CSG Locator @ 5419'
5,413'
7 Plug Catcher 5,800.1'
C80 @ 2520' KB C80 @ 2520' KB
Plug #2 – Intermediate
TOC ±3815' RKB
BOC @ ±5315' RKB
Plug #1 – Reservoir
TOC ±5432' RKB
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag: RKB 5,568.0 2P-451 6/16/2024 rogerba
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Dump Bail Cement on CIBP 2P-451 7/6/2024 fergusp
Notes: General & Safety
Annotation End Date Last Mod By
NOTE: ZONES NOT LOADED INTO WELLVIEW YET 7/29/2009 triplwj
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 32.0 120.0 120.0 62.60 WELDED
SURFACE 7 5/8 6.87 31.5 2,236.2 2,159.7 29.70 L-80 BTCMOD
PRODUCTION
5.5"x3.5" @ 5439'
5 1/2 4.95 26.7 5,927.0 5,732.2 15.50 L-80 BTCMOD
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
26.6
Set Depth …
5,415.7
Set Depth …
5,221.1
String Max No…
3 1/2
Tubing Description
TUBING
Wt (lb/ft)
9.30
Grade
L-80
Top Connection
EUEM
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)
26.6 26.6 0.00 HANGER 8.000 FMC TUBING HANGER 3.500
496.3 495.9 5.54 NIPPLE 4.520 CAMCO DS NIPPLE CAMCO DS 2.875
5,302.7 5,108.1 1.56 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900
5,352.6 5,158.0 1.47 SLEEVE-C 4.500 BAKER CMU SLIDING SLEEVE BAKER CMU 2.813
5,368.6 5,174.0 1.46 NIPPLE 4.520 CAMCO D NIPPLE CAMCO D 2.750
5,413.0 5,218.3 1.42 SEAL 4.500 BAKER GBH-22 LOCATOR/SEAL
ASSY LANDED w/NO GO 2' OFF
PROD CSG LOCATOR @ 5419'
BAKER GBH-22 2.990
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)
5,499.3 5,304.6 1.19 CIBP CIBP MID-ELEMENT AT 5500'
RKB, OAL = 1.37'
7/1/2024 0.000
5,800.1 5,605.4 1.13 Plug Catcher PLUG CATCHER SET IN 3.5"
PRODUCTION CASING
3/2/2002 0.000
Mandrel Inserts : excludes pulled inserts
Top (ftKB)
Top (TVD)
(ftKB)
Top
Incl (°)
St
ati
on
No
/S Serv
Valve
Type
Latch
Type
OD
(in)
TRO Run
(psi) Run Date Com Make Model
Port
Size (in)
5,302.7 5,108.1 1.56 1 GAS LIFT OPEN 1 9/4/2021
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
5,515.0 5,535.0 5,320.3 5,340.3 T-3, 2P-451 10/19/2020 6.0 APERF 2.5" Millenium 6 SPF 60°
Phase
5,535.0 5,550.0 5,340.3 5,355.3 T-3, 2P-451 10/19/2020 6.0 APERF 2.5" Millenium 6 SPF 60°
Phase
5,562.0 5,578.0 5,367.3 5,383.3 T-3, 2P-451 3/24/2002 6.0 IPERF 2.5" HSD 2506 Chgs, 60 deg
phase
Stimulation Intervals
Top (ftKB) Btm (ftKB)
Inter
val
Num
ber Type Subtype Start Date
Proppant
Designed (lb)
Proppant
Total (lb)
Vol Clean
Total (bbl)
Vol Slurry
Total (bbl)
5,562.0 5,578.0 1 FRAC 3/29/2002 0.0 0.00 0.00
Cement Squeezes
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Des Com
Pump Start
Date
5,432.0 5,499.3 5,237.3 5,304.6 Cement Plug Dump bailed cement 7/6/2024
2P-451, 7/16/2024 4:55:54 PM
Vertical schematic (actual)
PRODUCTION 5.5"x3.5" @
5439'; 26.7-5,927.0
Plug Catcher; 5,800.1
IPERF; 5,562.0-5,578.0
FRAC; 5,562.0
APERF; 5,535.0-5,550.0
APERF; 5,515.0-5,535.0
CIBP; 5,499.3
Cement Plug; 5,432.0 ftKB
GAS LIFT; 5,302.7
SURFACE; 31.5-2,236.2
CONDUCTOR; 32.0-120.0
KUP PROD
KB-Grd (ft) RR Date
3/5/2002
Other Elev…
2P-451
...
TD
Act Btm (ftKB)
5,950.0
Well Attributes
Field Name
MELTWATER
Wellbore API/UWI
501032040200
Wellbore Status
PROD
Max Angle & MD
Incl (°)
21.46
MD (ftKB)
2,866.47
WELLNAME WELLBORE2P-451
Annotation
Last WO:
End DateH2S (ppm)
67
Date
12/21/2013
Comment
SSSV: NIPPLE
1a. Well Status:Oil SPLUG Other Abandoned Suspended
1b. Well Class:
20AAC 25.105 20AAC 25.110 Development Exploratory
GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test
2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry:
Aband.:
3. Address: 7. Date Spudded: 15. API Number:
4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number:
Surface:
Top of Productive Interval:17. Field / Pool(s):
GL: BF:
Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation:
4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number:
Surface: x- y- Zone- 4
TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD:
Total Depth: x- y- Zone- 4
5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD:
Submit electronic information per 20 AAC 25.050 N/A (ft MSL)
22. Logs Obtained:
N/A
23.
BOTTOM
16" B 110'
7.625" L-80 2160'
5.5" L-80 5213'
3.5" L-80 5732'
24. Open to production or injection? Yes No 25.
26.
Was hydraulic fracturing used during completion? Yes No
DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED
27.
Date First Production: Method of Operation (Flowing, gas lift, etc.):
Hours Tested: Production for Gas-MCF:
Test Period
Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr):
Press. 24-Hour Rate
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
CASING, LINER AND CEMENTING RECORD
List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion,
(included above) 6.75"
TUBING RECORD
215 sx Class G6.75"
5416' MD3-1/2"
CASING
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
ConocoPhillips Alaska, Inc.
WAG
Gas
7/12/2024 202-008 / 323-608
50-103-20402-00-00
KRU 2P-451
ADL 0373112
1036' FNL, 1524' FWL, Sec. 17, T8N, R7E, UM
1364' FNL, 275' FWL, Sec. 17, T8N, R7E, UM
ALK 4998
2/21/2002
5950' MD / 5755' TVD
5432' MD / 5237' TVD
P.O. Box 100360, Anchorage, AK 99510-0360
443484 5868845
1363' FNL, 281' FWL, Sec. 17, T8N, R7E, UM
3/2/2002
CEMENTING RECORD
5868526
1379' MD / 1356' TVD
SETTING DEPTH TVD
5868525
TOP HOLE SIZE AMOUNT
PULLEDTOP
SETTING DEPTH MD
suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log,
spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar
locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary.
N/A
BOTTOM
Kuparuk River Field/ Meltwater Oil Pool-
Suspended
N/A
N/A
PACKER SET (MD/TVD)
42"
9.875"
392 sx AS I
32'370 sx AS IIIL, 120 sx LiteCrete
9.3#
32'
5408'
2236'32'
32'
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date perf'd or liner run):
15.5#
5432' (SW TOC) - 5499' 0.26 bbl 15.8 ppg Clss G cement
Water-Bbl:
PRODUCTION TEST
N/A
Date of Test: Oil-Bbl:
Flow Tubing
SUSPENDED
5515-5550' MD and 5320-5355' TVD (below cement plug)
5562-5578' MD and 5367-5383' TVD (below cement plug)
Gas-Oil Ratio:Choke Size:
Per 20 AAC 25.283 (i)(2) attach electronic information
Sr Res EngSr Pet GeoSr Pet Eng
Oil-Bbl: Water-Bbl:
5408'
SIZE DEPTH SET (MD)
9. Ref Elevations: KB: 27'
5927'
27'
5213'
62.5#
29.7#
110'
27'
WT. PER
FT.GRADE
442240
442233
Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment
Received by James Brooks
on 7/17/2024 at 9:59 AM
Suspended
7/12/2024
JSB
RBDMS JSB 071824
xGDSR-8/27/24
Conventional Core(s): Yes No Sidewall Cores:
N/A
30.
MD TVD
Surface Surface
1379' 1356'
Top of Productive Interval
N/A
31. List of Attachments: Schematics, Summary of Operations
32. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Contact Name: Katherine O'Connor
Digital Signature with Date:Contact Email: katherine.oconnor@conocophillips.com
Contact Phone:(907) 263-3718
Senior Well Interventions Engineer
General:
Item 1a:
Item 1b:
Item 4b:
Item 9:
Item 15:
Item 19:
Item 20:
Item 22:
Item 23:
Item 24:
Item 27:
Item 28:
Item 30:
Item 31:
Formation Name at TD:
If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if
needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired.
Yes No
Well tested? Yes No
28. CORE DATA
If Yes, list intervals and formations tested, briefly summarizing test results for
each. Attach separate pages if needed and submit detailed test info including
reports and Excel or ASCII tables per 20 AAC 25.071.
NAME
Permafrost - Top
Permafrost - Base
29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS
N/A- Suspended
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core
analysis, paleontological report, production or well test results, per 20 AAC 25.070.
Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each
segregated pool is a completion.
TPI (Top of Producing Interval).
Authorized Name and
Authorized Title:
N/A- Suspended
Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and
other tests as required including, but not limited to: core analysis, paleontological report, production or well test results.
Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29.
Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool.
If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the
producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,
showing the data pertinent to such interval).
Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit
detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity,
permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology.
Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain).
Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical
laboratory information required by 20 AAC 25.071.
Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion,
suspension, or abandonment; or 90 days after log acquisition, whichever occurs first.
Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345),
and/or Easement (ADL 123456) number.
The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements
given in other spaces on this form and in any attachments.
The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic
diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from
a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071.
INSTRUCTIONS
Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov
Digitally signed by Katherine O'ConnorDN: CN=Katherine O'Connor, O=ConocoPhillips, OU=Wells Group, E=
katherine.oconnor@conocophillips.com, C=US
Reason: I am the author of this document
Location:Date: 2024.07.17 08:55:53-08'00'
Foxit PDF Editor Version: 13.0.0
Katherine O'Connor
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag: RKB 5,568.0 2P-451 6/16/2024 rogerba
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Dump Bail Cement on CIBP 2P-451 7/6/2024 fergusp
Notes: General & Safety
Annotation End Date Last Mod By
NOTE: ZONES NOT LOADED INTO WELLVIEW YET 7/29/2009 triplwj
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 32.0 120.0 120.0 62.60 WELDED
SURFACE 7 5/8 6.87 31.5 2,236.2 2,159.7 29.70 L-80 BTCMOD
PRODUCTION
5.5"x3.5" @ 5439'
5 1/2 4.95 26.7 5,927.0 5,732.2 15.50 L-80 BTCMOD
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
26.6
Set Depth …
5,415.7
Set Depth …
5,221.1
String Max No…
3 1/2
Tubing Description
TUBING
Wt (lb/ft)
9.30
Grade
L-80
Top Connection
EUEM
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)
26.6 26.6 0.00 HANGER 8.000 FMC TUBING HANGER 3.500
496.3 495.9 5.54 NIPPLE 4.520 CAMCO DS NIPPLE CAMCO DS 2.875
5,302.7 5,108.1 1.56 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900
5,352.6 5,158.0 1.47 SLEEVE-C 4.500 BAKER CMU SLIDING SLEEVE BAKER CMU 2.813
5,368.6 5,174.0 1.46 NIPPLE 4.520 CAMCO D NIPPLE CAMCO D 2.750
5,413.0 5,218.3 1.42 SEAL 4.500 BAKER GBH-22 LOCATOR/SEAL
ASSY LANDED w/NO GO 2' OFF
PROD CSG LOCATOR @ 5419'
BAKER GBH-22 2.990
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)
5,499.3 5,304.6 1.19 CIBP CIBP MID-ELEMENT AT 5500'
RKB, OAL = 1.37'
7/1/2024 0.000
5,800.1 5,605.4 1.13 Plug Catcher PLUG CATCHER SET IN 3.5"
PRODUCTION CASING
3/2/2002 0.000
Mandrel Inserts : excludes pulled inserts
Top (ftKB)
Top (TVD)
(ftKB)
Top
Incl (°)
St
ati
on
No
/S Serv
Valve
Type
Latch
Type
OD
(in)
TRO Run
(psi) Run Date Com Make Model
Port
Size (in)
5,302.7 5,108.1 1.56 1 GAS LIFT OPEN 1 9/4/2021
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
5,515.0 5,535.0 5,320.3 5,340.3 T-3, 2P-451 10/19/2020 6.0 APERF 2.5" Millenium 6 SPF 60°
Phase
5,535.0 5,550.0 5,340.3 5,355.3 T-3, 2P-451 10/19/2020 6.0 APERF 2.5" Millenium 6 SPF 60°
Phase
5,562.0 5,578.0 5,367.3 5,383.3 T-3, 2P-451 3/24/2002 6.0 IPERF 2.5" HSD 2506 Chgs, 60 deg
phase
Stimulation Intervals
Top (ftKB) Btm (ftKB)
Inter
val
Num
ber Type Subtype Start Date
Proppant
Designed (lb)
Proppant
Total (lb)
Vol Clean
Total (bbl)
Vol Slurry
Total (bbl)
5,562.0 5,578.0 1 FRAC 3/29/2002 0.0 0.00 0.00
Cement Squeezes
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Des Com
Pump Start
Date
5,432.0 5,499.3 5,237.3 5,304.6 Cement Plug Dump bailed cement 7/6/2024
2P-451, 7/16/2024 4:55:54 PM
Vertical schematic (actual)
PRODUCTION 5.5"x3.5" @
5439'; 26.7-5,927.0
Plug Catcher; 5,800.1
IPERF; 5,562.0-5,578.0
FRAC; 5,562.0
APERF; 5,535.0-5,550.0
APERF; 5,515.0-5,535.0
CIBP; 5,499.3
Cement Plug; 5,432.0 ftKB
GAS LIFT; 5,302.7
SURFACE; 31.5-2,236.2
CONDUCTOR; 32.0-120.0
KUP PROD
KB-Grd (ft) RR Date
3/5/2002
Other Elev…
2P-451
...
TD
Act Btm (ftKB)
5,950.0
Well Attributes
Field Name
MELTWATER
Wellbore API/UWI
501032040200
Wellbore Status
PROD
Max Angle & MD
Incl (°)
21.46
MD (ftKB)
2,866.47
WELLNAME WELLBORE2P-451
Annotation
Last WO:
End DateH2S (ppm)
67
Date
12/21/2013
Comment
SSSV: NIPPLE
DTTMSTART JOBTYP SUMMARYOPS
6/16/2024 REPAIR WELL PULLED 2.75" CA-2 PLUG FROM D NIPPLE @ 5368' RKB, TAG TD W/ 2.625" DUMMY CIBP @
5568' RKB, READY FOR E-LINE
7/1/2024 REPAIR WELL LOAD IA WITH 43 BBLS CISW AND 31 BBLS DIESEL DURING RIG UP. LOAD TUBING WITH 31
BBLS 10.2 PPG BRINE (VAC TRUCK SIGHT GLASS SAID 44 BBLS ON TRUCK, LRS METER
AFTER PUMPING THE VAC TRUCK EMPTY SAID 31 BBLS PUMPED) AND 17 BBLS DIESEL. SET
CIBP MID-ELEMENT AT 5500'. PERFORM 2500 PSI CMIT-TxIA (PASS).
JOB COMPLETE, READY FOR SL
7/5/2024 REPAIR WELL DRIFT W/ 2.5" x 10' BAILER DWN TO CIBP @ 5499' RKB. DUMP BAIL ONE LOAD OF CEMENT
ON TOP OF CIBP, JOB IN PROGRESS.
7/6/2024 REPAIR WELL DUMP BAIL FROM TOP OF CIBP @ 5499' RKB TO 5456' RKB (43' OF CEMENT) AFTER 72
HOURS WILL BE READY FOR AOGCC WITNESSED TAG TOC & MIT.
7/12/2024 REPAIR WELL STATE WITNESS (SEAN SULLIVAN) TAG TOC @ 5432' RKB. CMIT TO 1500 PSI, PASSED.
READY FOR NEXT P&A STEPS.
2P-451 Suspend
Summary of Operations
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Jim Regg DATE:
P.I. Supervisor
SUBJECT:
FROM:
Petroleum Inspector
Section: 17 Township: 8N Range: 7E Meridian: Umiat
Drilling Rig: N/A Rig Elevation: N/A Total Depth: 5,950 ft MD Lease No.: ADL0373112
Operator Rep: Suspend: X P&A:
Conductor: 16" O.D. Shoe@ 120 Feet Csg Cut@ Feet
Surface: 7-5/8" O.D. Shoe@ 2,236 Feet Csg Cut@ Feet
Intermediate: N/A O.D. Shoe@ N/A Feet Csg Cut@ Feet
Production: 5-1/2"x 3-1/2" O.D. Shoe@ 5,927 Feet Csg Cut@ Feet
Liner: N/A O.D. Shoe@ N/A Feet Csg Cut@ Feet
Tubing: 3-1/2" O.D. Tail@ 5,416 Feet Tbg Cut@ Feet
Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified
Tubing Bridge plug 5,499 ft 5,396 ft 9.6 ppg KWF Wireline tag
Initial 15 min 30 min 45 min Result
Tubing 1750 1800 1860
IA 1750 1800 1860
OA 300 300 300
Initial 15 min 30 min 45 min Result
Tubing
IA
OA
Remarks:
Attachments:
Traveled to KRU 2P pad for multiple P&A's.This is the initial witnessed Tag and MIT-T of the 1st cmt plug for 2P-451. Upon
arival I met with Conoco rep Sid Ferguson, Little Red Servcies (LRS) operators and wireline crew to go over the plan for the day.
They began with a wireline tag with bailer and 300 lbs weight bar. A solid tag was made at 5,396 ft MD and returned a good cmt
sample that was grey in color and hard like clay. E-line rigged down and Little red rigged up for combination MIT TxIA. The MIT
was performed with no noticable losses to the plug or the OA. The sun came out and ambient temperature rose significantly
during this test. I gave an inconclusive due to the thermal effect although no losses were noticable.
July 12, 2024
Sully Sullivan
Well Bore Plug & Abandonment
KRU 2P-451
ConocoPhillips Alaska Inc.
PTD 2020080; Sundry 323-608
none
Test Data:
I
Casing Removal:
Sid Ferguson
Casing/Tubing Data (depths are MD):
Plugging Data (depths are MD):
rev. 3-24-2022 2024-0712_Plug_Verification_KRU_2P-451_ss
9
9
9999
9 9
9
9
9
9
9
9 9 9
9
9
9
9
9
9 9
9 9
9
9
combination MIT TxIAyygg
no noticable losses to the plug or the OA
gp
ambient temperature rose significantly p
during this test inconclusive due to the thermal effect
pg
James B. Regg Digitally signed by James B. Regg
Date: 2024.08.21 11:05:49 -08'00'
ORIGINATED
TRANSMITTAL
DATE: 7/10/2024
ALASKA E-LINE SERVICES
TRANSMITTAL
#: 4906
42260 Kenai Spur Hwy
PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk
PH: (907) 283-7374 FAX: (907) 283-7378
DELIVERABLE DESCRIPTION
TICKET # WELL # API #
LOG
DESCRIPTION
DATE OF
LOG
4906 2P-451 50103204020000 Plug Setting Record 1-Jul-2024
RECIPIENTS
Conoco
DIGITAL FILES PRINTS CD'S
1 FTP Transfer 0 0 USPS
Attn: NSK-69
tom.osterkamp@conocophillips.com 700 G Street
Anchorage, AK 99503
Received
By: Received By:
Signature Signature
AOGCC
DIGITAL FILES PRINTS CD'S
1 SharePoint
Link 0 0 USPS
Attn: Natural Resources Technician II
abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision
333 W. 7th Ave, Suite 100 - Anchorage, AK 99501
Received
By: Received By:
Signature Signature
202-008
T39138
Gavin Gluyas
Digitally signed by Gavin
Gluyas
Date: 2024.07.10 10:17:42
-08'00'
DNR
DIGITAL FILES PRINTS CD'S
1 SharePoint
Link 0 0 USPS
Attn: Natural Resource Tech II
DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501
Delivery Method: USPS
Received
By: Received By:
Signature Signature
Please return via e-mail a copy to both:
AR@ake-
line.com tom.osterkamp@conocophillips.com
1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown
Suspend Perforate Other Stimulate Pull Tubing Change Approved Program
Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________
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?
Yes No
9. Property Designation (Lease Number): 10. Field:
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD):
5950'None
Casing Collapse
Structural
Conductor
Surface
Intermediate
Production
Liner
Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft):
12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work:
Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service
14. Estimated Date for 15. Well Status after proposed work:
Commencing Operations: OIL WINJ WDSPL Suspended
16. Verbal Approval: Date: GAS WAG GSTOR SPLUG
AOGCC Representative: GINJ Op Shutdown Abandoned
Contact Name:
Contact Email:
Contact Phone:
Authorized Title:
Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number:
Plug Integrity BOP Test Mechanical Integrity Test Location Clearance
Other Conditions of Approval:
Post Initial Injection MIT Req'd? Yes No
APPROVED BY
Approved by: COMMISSIONER THE AOGCC Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
12/1/2023
3-1/2"
Packer: Baker GBH-22 Loactor/Seal Assy
SSSV: None
Perforation Depth MD (ft):
L-80
2205'
5515-5550', 5562-5578'
5900'
5320-5355', 5367-5383'
5-1/2" x 3-1/2"
Perforation Depth TVD (ft):
120'
2236'
5732'5927'
16"
7-5/8"
88'
5416'
MD
120'
2160'
ConocoPhillips Alaska, Inc.
Length Size
Proposed Pools:
PRESENT WELL CONDITION SUMMARY
Meltwater Oil Pool -
Suspended
TVD Burst
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL0373112
202-008
P.O. Box 100360, Anchorage, AK 99510 50-103-20402-00-00
Kuparuk River Field Meltwater Oil Pool
AOGCC USE ONLY
Tubing Grade: Tubing MD (ft):
5413' MD and 5218' TVD
N/A
Katherine O'Connor
Subsequent Form Required:
Suspension Expiration Date:
Will perfs require a spacing exception due to property boundaries?
Current Pools:
MPSP (psi): Plugs (MD):
17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval.
Authorized Name and
Digital Signature with Date:
Tubing Size:
katherine.oconnor@conocophillips.com
(907) 263-3718
Well Interventions Engineer
KRU 2P-451
5755' 5368' 5173' 5368'
N/A
Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
By Grace Christianson at 10:12 am, Nov 14, 2023
Digitally signed by Katherine O'Connor
DN: CN=Katherine O'Connor, O=ConocoPhillips,
OU=Wells Group, E=katherine.oconnor@
conocophillips.com, C=US
Reason: I am the author of this document
Location:
Date: 2023.11.09 13:04:34-09'00'
Foxit PDF Editor Version: 13.0.0
Katherine
O'Connor
323-608
12/31/2024
VTL 11/14/2023
X
SFD 11/16/2023 DSR-11/15/23
X
Suspend
10-407
*&:JLC 11/16/2023
Brett W. Huber,
Sr.
Digitally signed by Brett W.
Huber, Sr.
Date: 2023.11.16 15:25:30
-09'00'11/16/23
RBDMS JSB 111723
2P-451 Suspension
Date Wrien: 10-30-23
Execu on Date: Dec 1, 2023
Prepared by: Katherine O’Connor (214-684-7400)
Background & Objecve
2P-451 was a producer shut-in in late 2020. It has no known tubing or IA integrity issues. This well is
ultimately slated to be P&Ad on rig as part of the 2P pad abandonment. 2P pad does not have any
facilities or surface line hookups, and the pad is slated to be used as storage for Willow development
project in 2026. This well will be suspended in 2023, and it is currently planned to be fully abandoned in
2024.
Well Data
Reservoir pressure 06/20/21 = 2724 psi at 5400’ TVD
MASP = 2184 psi
Ice plug/hydrate in tubing & possibly IA
Tubing plug installed @ 5368’ KB on 9/4/2021
No gas lift valve in mandrel at 5303’ KB
Last drift 5573’ KB on 10/19/2020
Procedure
Coil
1. Remove ice plug in tubing as necessary, cleanout down to perfs
Slickline
1.Pull plug from tubing.
2. Drift with dummy CIBP to TD. If unable to get within 50’ of perforations, contact Katherine
O’Connor
3. Fluid pack tubing & IA as necessary with KWF and freeze protect
4. Set CIBP @ ±5500’ RKB (must be set within 50’ of the top of perforations).
5. Perform CMIT-T-IA to 2500 psi, record results
6. Dump bail at least 30’ of cement on top of CIBP
7. Allow 72 hours for cement to harden, notify AOGCC at least 24 hours in advance
8. RIH and tag TOC, approx. 5,470’ RKB (MUST BE AOGCC WITNESSED)
9. RU LRS as necessary. Perform pressure test to 1500 psi (MUST BE AOGCC WITNESSED)
10. Perform DDT to 0 psi and record results
DHD
1. Schedule wellsite inspection within 12 months of suspension approval
2P-451 Well Schematic
Conductor:
16" Conductor 120' KB
Production Casing Cement:
53 bbls of 15.8# Cement
Calculated TOC @ 2,936' KB
Production Casing:
5.5" x 3.5" @ 5,439' KB, 15.5# x 9.3#,
L-80 BTC Mod
Set @ 5,927’ KB
T-3 Peforations:
@ 5,515'– 5,578' KB (63')
Surface Casing:
7-5/8", 29.7#, L-80 BTC Mod
Set @ 2,236.2' KB
Production Tubing:
3 ½”, 9.3# L-80 EUE-8rd
Set @ 6,883.7' KB
1
2
3
7
5
6
4
Item Depth - tops (KB)
1 FMC Tubing Hanger 26.6'
2 Camco DS Nipple 496.3'
3 Baker CMU Sliding Sleeve 5,352.6'
4 Tubing Plug 5,368'
5 Camco D Nipple 5,368.6'
6
Baker GBH-22 Locator/Seal
Assembly Landed w/ No Go 2' Off
Prod CSG Locator @ 5419'
5,413'
7 Plug Catcher 5,800.1'
C80 @ 2520' KB C80 @ 2520' KB
Plug #1 – Reservoir
TOC ±5470' RKB
Originated:Delivered to:15-Dec-20
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-07 50-029-20658-00 n/a Kuparuk River Packer Setting Record Field- Final 26-Oct-20 0 1
2 1B-102 50-029-23167-00 906749775 Kuparuk River Multi Finger Caliper Field & Processed 7-Oct-20 0 1
3 1D-05 50-029-20417-00 906744243 Kuparuk River Packer Setting Record Field- Final 1-Oct-20 0 1
4 1R-17 50-029-22212-00 906744935 Kuparuk River Packer Setting Record Field- Final 5-Oct-20 0 1
5 2B-07 50-029-21080-00 906716400 Kuparuk River Multi Finger Caliper Field & Processed 2-Oct-20 0 1
6 2B-07 50-029-21080-00 906716400 Kuparuk River Leak Detect Log with ACX Processed 1-Oct-20 0 1
7 2H-11 50-029-20052-00 906792896 Kuparuk River Plug Setting Record Field- Final 31-Oct-20 0 1
8 2N-315 50-103-20270-00 906731635
Tarn
Participating
Area
Leak Detect Log with
TMD3D Field & Processed 28-Sep-20 0 1
9 2P-451 50-103-20402-00 906771682 Meltwater Perforation Record Field- Final 19-Oct-20 0 1
10 2T-38A 50-103-20229-01 906748612 Kuparuk River Plug Setting Record Field- Final 17-Oct-20 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 12/16/2020
12/16/2020 Abby Bell
PTD: 2020080
E-Set: 34415
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Steven G. Drake Digitally signed by Steven G. Drake
Date: 2020.11.04 07:18:00 -09'00'
By Samantha Carlisle at 10:37 am, Nov 04, 2020
SFD 11/5/2020DSR-11/4/2020 RBDMS HEW 10/4/2020
SFD 11/5/2020
SFD 11/5/2020
-00
VTL 2/17/21
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/012034/
566307218/03492:
Last Tag
Annotation Depth (ftKB) End Date Wellbore Last Mod By
Last Tag: SLM RKB 5,583.0 2/21/2018 2P-451 kwink
Last Rev Reason
Annotation End Date Wellbore Last Mod By
Rev Reason: Replaced OV, Add Perfs, Set Gauges 10/20/2020 2P-451 zembaej
Casing Strings
Casing Description
CONDUCTOR
OD (in)
16
ID (in)
15.06
Top (ftKB)
32.0
Set Depth (ftKB)
120.0
Set Depth (TVD) …
120.0
Wt/Len (l…
62.60
Grade Top Thread
WELDED
Casing Description
SURFACE
OD (in)
7 5/8
ID (in)
6.87
Top (ftKB)
31.5
Set Depth (ftKB)
2,236.2
Set Depth (TVD) …
2,159.7
Wt/Len (l…
29.70
Grade
L-80
Top Thread
BTCMOD
Casing Description
PRODUCTION 5.5"x3.5"
@ 5439'
OD (in)
5 1/2
ID (in)
4.95
Top (ftKB)
26.7
Set Depth (ftKB)
5,927.0
Set Depth (TVD) …
5,732.2
Wt/Len (l…
15.50
Grade
L-80
Top Thread
BTCMOD
Tubing Strings
Tubing Description
TUBING
String Ma…
3 1/2
ID (in)
2.99
Top (ftKB)
26.6
Set Depth (ft…
5,415.7
Set Depth (TVD) (…
5,221.1
Wt (lb/ft)
9.30
Grade
L-80
Top Connection
EUEM
Completion Details
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des Com
Nominal
ID (in)
26.6 26.6 0.00 HANGER FMC TUBING HANGER 3.500
496.3 495.9 5.54 NIPPLE CAMCO DS NIPPLE 2.875
5,352.6 5,158.0 1.47 SLEEVE-O BAKER CMU SLIDING SLEEVE 2.813
5,368.6 5,174.0 1.46 NIPPLE CAMCO D NIPPLE 2.750
5,413.0 5,218.3 1.42 SEAL BAKER GBH-22 LOCATOR/SEAL ASSY LANDED w/NO GO 2'
OFF PROD CSG LOCATOR @ 5419'
2.990
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top
(ftKB)
Top
(TVD)
(ftKB)
Top Incl
(°) Des Com Run Date ID (in) SN
5,368.6 5,174.0 1.46 2.75" C-Lock w/
Gauges
2.75" C-Lock, Flow thru sub, shock absorber,
and dual Spartek gauges (83" OAL)
10/20/2020 0.000
5,800.1 5,605.4 1.13 Plug Catcher PLUG CATCHER SET IN 3.5"
PRODUCTION CASING
3/2/2002 0.000
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft
)Type Com
5,515.0 5,535.0 5,320.3 5,340.3 T-3, 2P-451 10/19/2020 6.0 APERF 2.5" Millenium 6 SPF 60°
Phase
5,535.0 5,550.0 5,340.3 5,355.3 T-3, 2P-451 10/19/2020 6.0 APERF 2.5" Millenium 6 SPF 60°
Phase
5,562.0 5,578.0 5,367.3 5,383.3 T-3, 2P-451 3/24/2002 6.0 IPERF 2.5" HSD 2506 Chgs, 60 deg
phase
Frac Summary
Start Date
3/29/2002
Proppant Designed (lb) Proppant In Formation (lb)
Stg #
1
Start Date
3/29/2002
Top Depth (ftKB)
5,562.0
Btm (ftKB)
5,578.0
Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl)
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 5,302.7 5,108.1 CAMCO KBG-2-
9
1 GAS LIFT OV BTM 0.313 0.0 10/18/2020
Notes: General & Safety
End Date Annotation
11/29/2010 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0
7/29/2009 NOTE: ZONES NOT LOADED INTO WELLVIEW YET
2P-451, 10/22/2020 11:36:56 AM
Vertical schematic (actual)
PRODUCTION 5.5"x3.5" @
5439'; 26.7-5,927.0
Plug Catcher; 5,800.1
IPERF; 5,562.0-5,578.0
FRAC; 5,562.0
APERF; 5,535.0-5,550.0
APERF; 5,515.0-5,535.0
SEAL; 5,413.0
2.75" C-Lock w/ Gauges;
5,368.6
NIPPLE; 5,368.6
SLEEVE-O; 5,352.6
GAS LIFT; 5,302.7
SURFACE; 31.5-2,236.2
NIPPLE; 496.3
CONDUCTOR; 32.0-120.0
HANGER; 26.6
KUP PROD
KB-Grd (ft) Rig Release Date
3/5/2002
2P-451
...
TD
Act Btm (ftKB)
5,950.0
Well Attributes
Field Name
MELTWATER
Wellbore API/UWI
501032040200
Wellbore Status
PROD
Max Angle & MD
Incl (°)
21.46
MD (ftKB)
2,866.47
WELLNAME WELLBORE2P-451
Annotation
Last WO:
End DateH2S (ppm)
67
Date
12/21/2013
Comment
SSSV: NIPPLE
5,515.0 5,535.0 5,320.3 5,340.3 T-3, 2P-451 10/19/2020 6.0 APERF 2.5" Millenium 6 SPF 60°
Phase
5,535.0 5,550.0 5,340.3 5,355.3 T-3, 2P-451 10/19/2020 6.0 APERF 2.5" Millenium 6 SPF 60°
Phase
1 0 3 0 320 3 3 0 3 3 2 1 10 19 2020 6 0 2 6 S 60
/q
~C~lll~i~~~1~
Schlumberger -DCS
2525 Gambell Street, Suite 400
Anchorage, AK 99503-2838
ATTN: Beth
Well Job #
~~1j~R °~ ~ 'l_Ot1~3
~~~1 MAC ~ ~ 200
Log Description
N0.4617
Company: Alaska Oil & Gas Cons Comm
Attn: Christine Mahnken
333 West 7th Ave, Suite 100
Anchorage, AK 99501
Field: Kuparuk
Date BL Color CD
o212s1os
1A-02 (REVISED) 11994615 INJECTION PROFILE / % ~ .._.. ~ _, ~ 02111/08 1
1C-27 11970632 WFL V 02121/08 1
3R-21 11970633 LDL 02!22108 1
2P-451 11996604 SBHP SURVEY O - '~S 02/22/08 1
1C-11 11968846 LDL ~ - ~ 02/20/08 1
2P-438 11964581 SBHP SURVEY ap j - 02/26/08 1
2P-448A 11964582 SBHP SURVEY '~ 02/27/08 1
•
•
Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you.
e
Conoc;p.,illips
Alaska
e
JUL :G5 2006
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
31
June 06, 2006
Mr. Tom Maunder
Alaska Oil & Gas Commission
333 West ih Avenue, Suite 100
Anchorage, AK 99501
'0
Dear Mr. Maunder:
Enclosed please find a spreadsheet with a list of wells trom the Kuparuk field (KRU). Each of
these wells was found to have a void in the conductor by surface casing annulus. The voids that
were greater than 6 feet were first filled with cement to a level of 2.5 feet. The remaining
volume, 2.5 to 6 feet of annular void respectively was coated with a corrosion inhibiter,
RG2401, then filled with a viscous hydrocarbon based sealant, Royfi1l404B, engineered to
prevent water from entering the annular space. As per previous agreement with the AOGCC,
this letter and spreadsheet serves as notification that the treatments took place and meets the
requirements of form 10-404, Report of Sundry Operations.
The cement top-fill operation was completed on May 05,2006. Schlumberger Well Services
mixed 15.7 ppg Arcticset I in a blender tub. The cement was pumped into the conductor bottom
and cemented up via a hose run to the existing top of cement. The corrosion inhibitor and
sealant were pumped in a similar manner on May 18th, 19th and 31 st, 2006. The attached
spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on
each conductor.
Please call Marie McConnell or myself at 907-659-7224, if you have any questions.
Sincerely,
("~.s~~6 d~
C>6/~ 0 /06
Attachment
",",l" ,'"ì ¡-<1,'¿"
<::;IÙd ~- L.U 0
e
e
ConocoPhillips Alaska Inc.
Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off
Kuparuk Field
June 6,2006
Well Initial top Vol. of cement Final top of Cement top
Name PTD # of cement um ed cement off date
ft bbls ft
·
~
ConocoPhillips
Alaska
~C·.·.·E· '\IF¡ni
~ ~7¡ ¡ ~~ ....W"..ð
JUN J Z
i: ..,.
'" ;
Aisska Oil &. Gas Cons. CQrnrm£i}jan
Anchorage
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
,a(JQ- ðO~
June 06, 2006
Mr. Tom Maunder
Alaska Oil & Gas Commission
333 West ih Avenue, Suite 100
Anchorage, AK 99501
¿..' ;", ~ \t~' Y,", t';:"
";";:f~;I~í\~"h"':"'l .';'.)¡\3 ;/, i
'tft ;~,·,:i'Iþ,IÒ~"'"
Dear Mr. Maunder:
Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of
these wells was found to have a void in the conductor by surface casing annulus. The voids that
were greater than 6 feet were first filled with cement to a level of2.5 feet. The remaining
volume, 2.5 to 6 feet of annular void respectively was coated with a corrosion inhibiter,
RG2401, then filled with a viscous hydrocarbon based sealant, Royfill 404B, engineered to
prevent water from entering the annular space. As per previous agreement with the AOGCC,
this letter and spreadsheet serves as notification that the treatments took place and meets the
requirements of form 10-404, Report of Sundry Operations.
The cement top-fill operation was completed on May 05,2006. Schlumberger Well Services
mixed 15.7 ppg Arcticset I in a blender tub. The cement was pumped into the conductor bottom
and cemented up via a hose run to the existing top of cement. The corrosion inhibitor and
sealant were pumped in a similar manner on May 18th, 19th and 31 st, 2006. The attached
spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on
each conductor.
Please call Marie McConnell or myself at 907-659-7224, if you have any questions.
ConocoPhillips Problem Well Supervisor
Attachment
.
.
ConocoPhillips Alaska Inc.
Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off
Kuparuk Field
June 6,2006
Vol. of cement Final top of Cement top
um ed cement off date
bbls ft
Royfill4048
vol.
al
Corrosion
inhibitor/
sealant date
5/19/2006
.
.
~~\
"r
.".. . »....
MICROFILMED
07/25/06
DO NOT PLACE
ANY NEW MATERIAL
UNDER THIS PAGE
F:\LaserFiche\CvrPgs _Inserts\Microfilm _ Marker.doc
Permit to Drill
MD
5950 .-.-~
REQUIRED INFORMATION
~ c Pdt
~
I
ì .
r Pdt
2020080
~61
.)"2261
~261
U(2261
;J. :s A:.~ )..0 q '1
DATA SUBMITTAL COMPLIANCE REPORT
4/2/2004
Well Name/No. KUPARUK RIV U MELT 2P-451
Operator CONOCOPHILLIPS ALASKA INC
5J7ud 2 J Pi ~ ~&\j 2-
API No. 50-103-20402-00-00
1VD
Completion Date 3/24/2002
Completion Status
1-01L
5755 -
Mud Log ~t.:;
Samples No
Log Log Run
Scale Media No
2 Blu 1
1-3
1-3
25
25
Blu
25
25
Blu
25
25
Blu
Well Cores/Samples Information:
r
I
!
i
L_-
Name
Interval
Start Stop
Sent
Received
Current Status 1-01L
UIC N
Interval
Start Stop
0 5560
191
191
235
235
235
235
235
235
Sample
Set
Number
Directional Survey
Yes "'--'"
DATA INFORMATION
Types Electric or Other Logs Run:
Well Log Information:
Log/ Electr
Data Digital Dataset
Type Med/Frmt Number Name
~'
-V-eD C Tf
I Rpt
.e6 C Pdf
(data taken from Logs Portion of Master Well Data Maint)
)
5950
5950
5950
OH/
CH Received Comments
Gttstr12/1 0/2002 NÒ1Se--I::G9witbJ.,~"aTld
(.~ GráôrO ~ --
Open 11/12/2003 ì~I'J),.,
"
~,
Open 1111212003 ~"
'\
Open 11112/2003 Multiple Propagation \
Resistivity, Gamma Ray - '1
-~~P~._-----._- i
Open 11/12/200C/ Multiple Propagation ::\'.' .:./
Resistivity, Gan:\ma Ray-
RWD . rv (J )
Open 11/12/2003 'Caffpereorrectad'NE!ú¡;~n,
Optimized Rotational
Density - RWD .
Open 11/12/2003 Caliper Corrected Neutron,
Optimized Rotatíenal .
Density - RWD !'-ViJ I
Open 11/1212003 Caliper Corrected Neutr:~ in.
Optimized Rotational
Density - RWD
Open 11/12/2003 Caliper Corrected Neutron,
Optimized Rotational
Density - RWD j't'1--Ò
)
5950
5950
5950
5950
5950
Comments
Cores and/or Samples are required to be I
submitted. This record automatically created I
from Permit to Drill Module on: 1/2212002. -.J
Permit to Drill 2020080
MD
5950
1VD
ADDITIONAL INFORMATION
Well Cored? Y Ð
Chips Received?
~Y 1 N
YIN
Analysis
Received?
Comments:
Compliance Reviewed By:
5755
--
DATA SUBMITTAL COMPLIANCE REPORT
4/2/2004
Well Name/No. KUPARUK RIV U MELT 2P-451
Operator CONOCOPHILLIPS ALASKA INC
API No. 50-103-20402-00-00
Completion Date 3/24/2002
Completion Status
1-01L
Daily History Received?
1Y1N
cYYN
Formation Tops
~
Current Status 1-01L
UIC N
Cores andlor Samples are required to be
submitted. This record automatically created
from Permit to Drill Module on: 1/2212002.
Date:
J C¡-( ~ ~~'-f
)
)
TUBING
(()'5408,
00:3500,
10:2.992)
SURFACE ~
(()'2236,
00:7.625,
WI29.70)
ODUCTION
(()'5408,
00:5,500,
W115,50)
SLEEVE-O
(5352-5353,
00:4,500)
NIP
(5369-5370,
00:3.750)
LINER
(5408-5926,
00:3500,
WI9.30)
SEAL
(5412-5413,
00:4.500)
Perf
(5562-5578)
.~
. ..---,
ConocoPhillips Alaska, Inc.
II
-
1 ~
KRU
2P-451
2P-451
.--
API: 501032040200
SSSV Type: Nipple
Annular Fluid:
Reference Log:
Last Taç¡: 5580
Last Taç¡ Date: 5/7/2003
Casing String - ALL STRINGS
Description
CONDUCTOR
SURFACE
PRODUCTION
LINER
Tubing String - TUBING
Size I Top I Bottom
3.500 0 5408
Peñorations Summary
Interval I TVD I Zone
5562 - 5578 5367 - 5383
Stimulations & Treatments
Interval I Date I Type
5562 - 5578 3/29/2002 FRAC
Gas Lift MandrelsNalves
St I MD I TVD I Man I Man Type I V Mfr
1 5302 5107 CAr:~O KBG-2-9
Other (plugs, equip., etc.) - JEWELRY
Depth TVD Type
496 496 NIP CAMCO 'OS' NIPPLE
5352 5157 SLEEVE-O BAKER CMU SLIDING SLEEVE WICAMCO 2.813 OS PROFILE
5369 5174 NIP CAMCO '0' NIPPLE WINO GO PROFILE
Other (plugs, equip., etc.) - LINER
Depth TVD Type
5409 5214 SBE
5412 5217 SEAL
5419 5224 LOCATOR
5420 5225 CSR
5439 5244 XO
5832 5637 COLLAR WEATHERFORD GEMOCO FLOAT COLLAR
5926 5731 SHOE WEATHERFORD GEMOCO FLOAT SHOE SUPER SEAL II
General Notes
Date I Note
12130/200~WAIVERED WELL: CHARGING OA
Well Type:
Oriç¡ Completion:
Last Wl0:
Ref Loç¡ Date:
ill:
Max Hole Anç¡le:
PROD
315/2002
Anç¡le @ TS: deç¡ @
Anç¡le @ ill: 1 deg @ 5950
Rev Reason: Waivered Well
Last Update: 12/30/2003
5950 ftKB
21 deg @ 2866
Size
16.000
7.625
5.500
3.500
Top
0
0
0
5408
Bottom
120
2236
5408
5926
TVD
120
2160
5213
5731
Wt
62.60
29.70
15.50
9.30
Grade
Thread
L-80
L-80
L-80
BTCMOD
BTCMOD
EUE8rd
TVD
5213
I Grade I
L-80
Thread
EUEMOD
Wt
9.30
I Status 1Ft I SPF I Date I Type I Comment
16 6 3/24/2002 IPERF 2.5" HSD 2506 Chgs, 60
deg phase
I C-SAND FRAC
I V Type I V OD I Latch I Port I TRO I ~:t~ I C~~t
OV 1.0 INT 0.313 0 5/21/2003
Comment
Description
ID
2,875
2.813
2,750
Description
BAKER CASING SEALING RECEPTACLE
BAKER SEAL 80-40 GBH-22 LANDED WINO GO LOCATOR
ID
4.970
2.990
4.060
4.000
2,950
2,950
2.950
BAKER CASING SEAL RECEPTACLE SIZE 80-40
,"--"'"
,r---..
Casing Detail
75/8" Surface CasinQ
1m. ~ ~~s~~ !~H~I~~R~~~'CJ~~;
Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN
Jts 29 to 51
23 Jts
Nordic rig #3 RT to Landing ring
11" X 7 5/8" FMC Gen V fluted hanger w/ pup
75/8", 29.7#, L-80, BTCM
7 5/8" TAM Port Collar
75/8", 29.7#, L-SO, BTCM
Weatherford Float collar
75/8", 29.7#, L-80, BTCM
Weatherford Float shoe
RAT Hole
Jts 3 to 28
26 Jts
Jts 1 to 2
2 Jts
Run one bowspring centralizer per joint on joints 1-12. First 2 on stop
collars in the center of the joints, The rest below the casing collars
Let float Run one 9-7/8" X 7 5/8" bowspring above and below the
Tam Port collar
Remarks; String weights with Blocks: Up Wt 85k, On Wt 67k, Blocks 22k. Ran 51 Joints casing.
Drifted casing & Hanger with 6.151" plastic rabbit Used Arctic grade API modified thread compound
on all connections. Casing is non coated. All casing is new.
Well:
Date:
LENGTH
31.50
2.48
990.88
2.42
1119.20
1.39
86.82
1.50
15.00
NORDIC RIG #3
Supervisor: Donald L. Wester
2P-451
2/23/02
DEPTH
TOPS
31.50
33.98
1024.86
1027.28
2146.48
2147.87
2234.69
2236.19
2251.19
".--..,
..----.....
Legal Well Name: 2P-451
Common Well Name: 2P-451
Event Name: ROT - DRILLING
Report #:
Start:
1
2/14/2002
Spud Date: 2/19/2002
Report Date: 2/24/2002
End:
Hole Size:
TMD Set:
Date Set:
Csg Type:
Csg Size:
9.875 (in)
2,236 (ft)
2/23/2002
Surface Casing
7.625 (in.)
Hole Size:
sa TMD: (ft)
sa Date:
sa Type:
Hole Size:
TMD Set:
Date Set:
Csg Type:
sa TMD:
sa Date:
Cmtd. Csg:
Hole Size:
Top Set:
BTM set:
Plug Date:
Plug Type:
Drilled Out:
Cmtd. Csg:
(ft)
(ft)
Cmtd. Csg: OPEN HOLE
Cmtd. Csg:
Cement Co: Dowell Schlumberger
Cementer:
Pipe Movement: Reciprocating
Rot Time Start: :
Rec Time Start:14:00
Time End: :
Time End: 17:40
RPM:
SPM: 85
Init Torque: (ft-Ibf)
Stroke Length: 15.0 (ft)
Avg Torque: (ft-Ibf)
Drag Up: 85,000 (Ibs)
Max Torque: (ft-Ibf)
Drag Down: 67,000 (Ibs)
Type: Cement Casing Start Mix Cmt: 16:50 Disp Avg Rate: 5.80 (bbl/min) Retums: 208 bbl's
Volume Excess %: 400.00 Start Slurry Displ: 16:50 Disp Max Rate: 6.00 (bbl/min) Total Mud Lost: (bbl)
Meas. From: Start Displ: 17:56 Bump Plug: N Cmt Vol to Surf: (bbl)
Time Circ Prior End Pumping: 18:16 Press Prior: (psi)
To Cementing: 2.00 End Pump Date: 2/23/2002 Press Bumped: (psi) Ann Flow After: N
Mud Circ Rate: 252 (gpm) Top Plug: N Press Held: (min) Mixing Method:
Mud Circ Press: 490 (psi) Bottom Plug: N Float Held: N Density Meas By:
Type: Density: (ppg) Visc: (s/qt)
Bottom Hole Circulating Temperature: (OF)
Displacement Fluid Type:
PVIYP: (cp)/ (lb/100ft2) Gels 10 see: (lb/10Qft2) Gels 10 min: (lb/100ft2)
Bottom Hole Static Temperature: (OF)
Density: (ppg) Volume: (bbl)
Slurry Data
Fluid Type: FLUSH
Slurry Interval: (ft)
Water Source:
Description: CW100
To: 1,400.00 (ft) Cmt Vol: (bbl)
Slurry Vol: (sk)
Class:
Density: 10.70 (ppg) Yield: (ft3/sk)
Water Vol: (bbl) Other Vol: ()
Purpose: SPACER
Mix Water: (gal)
Foam Job: N
Test Data
Thickening Time:
Free Water: (%)
Fluid Loss: (cc)
Fluid Loss Pressure:
Temperature: (OF)
Temperature: (OF)
Temperature: (OF)
Time
Compressive Strength 1:
Compressive Strength 2:
Temp
(OF)
(OF)
Pressure
(psi)
(psi)
(OF)
Printed: 1/27/2004 4:25:01 PM
,~
.~
Legal Well Name: 2P-451
Common Well Name: 2P-451
Event Name: ROT - DRILLING
Report #:
Start:
1
2/14/2002
Spud Date: 2/19/2002
Report Date: 2/24/2002
End:
Test Press: 2,650 (psi)
For: 30 (min)
Cement Found between
Shoe and Collar: Y
Pressure: (ppge)
Tool: N
Open Hole: (ft)
Hrs Before Test:
Liner Lap:
Pos Test: (ppge)
Neg Test: (ppge)
Hrs Before Test:
Cement Found on Tool: N
Tool: N
Tool: N
CBL Run: N
Under Pressure: (psi)
Bond Quality:
Cet Run:
Bond Quality:
Temp Survey: N
Hrs Prior to Log:
N
Cement Top:
How Determined:
TOC Sufficient: N
Job Rating:
If Unsuccessful Detection Indicator:
Remedial Cementing Required:
Number of Remedial Squeezes:
(ft)
N
CEMENT
75/8" SURFACE CASING
MELTWATER # 2P-451
AFC: AK 0229
After casing on bottom reciprocate circulate and condition hole. Till mud thin and weight @ 9.6 ppg with PV < 15. Pump 5 bbl's of CW100
@ 8.6 ppg pressure test lines to 3500 psi. Continue pumping a total of 40 bbl's of CW1 00, Drop bottom plug, Followed by 40 bbls
MudPUSH XL @ 10.5 ppg WI Red dye. Followed by 370 sks (288 bbls) of Lead cement Aslite @ 10.7 ppg. Followed 120 sks (59 bbl's) of
LiteCRETE cement @ 12.0 ppg. Note! Stop reciprocating and land on hanger when you see CW100 or starts to get sticky. Drop top plug
and kick out w/1 0 bbl's water. Switch to rig pumps displace WI treated mud ( Do not exceed 6 bpm while displacing) You should bump
plug wI 89 bbl's (1254 stks) Slow rate to 3 bpm @ 1125 stks. CIP @ 1815 hrs 02123/02. Bump plug wI 2500 psi. Bleed off pressure Plug
held O.K. Cement returns to surface 208 bbl's
Printed: 1/27/2004 4:25:01 PM
r---
.r----..
WELL NAME
I JOB NUMBER I EVENT CODE 124 HRS PROG
2P-451 ODR
I RIG NAME & NO. I FIELD NAME I OCS NO.
NORDIC 3 n1433@ppco.com 3 Meltwater
ACCIDENTS LAST 24 HRS.?
TMD ITVD IDFS
2,256.0 2,174.0 3.00
AUTHMD I DAILY TANG
5,925.0 0
DAILY INT WIO MUD
0
DATE OF LAST SAFETY MEETING DAILY TOTAL
2/23/2002 219,775
ILEAKOFF AFE
AK0229
I NEXT CASING
(in) @
, 0.1>..
9.875
6.750
6.250
6.250
6.750
6,625
5,000
5.000
5.000
6.750
4.000
6.250
4.000
Bit
Mud Motor
Stabilizer - NonMag
Crossover - NonMag
MWD
Crossover - NonMag
Drill Pipe - Non-Mag 4 Comp Serv
Drill Pipe - Non-Mag 4 Comp Serv
Drill Pipe - Non-Mag 4 Comp Serv
Crossover
Drill Pipe - Heavy Wgt
Jars
Drill Pipe - Heavy Wgt
03:30 06:00 2.50 DRILL P TRIP
06:00 08:30 2.50 CASE P RUNC
08:30 09:00 0.50 CASE P SFTY
09:00 10:00 1.00 RIGMNT P RSRV
10:00 14:00 4.00 CASE P RUNC
14:00 16:00 2.00 CEMENT P CIRC
IREPTNO. I DATE
9 2/23/2002
¡CUM. TANGO
CUM INT ANG WI MUD
0
CUM COST WI MUD
907,233
AUTH.
2.810
2.810
2.250
2.875
2.810
2.810
2.810
2.250
2.250
2.250
2.250
Printed: 1/27/2004 4:39:39 PM
,r---..
~
2P-451
I JOB NUMBER I EVE~DC~DE 124 HRS PROG
ITMD ITVD IDFS
2,256.0 2,174.0 3.00
I REPT NO. I DATE
9 2/23/2002
WELL NAME
""",
19:00 20:30
20:30 00:00
1.50
3.50
CEMENT P
CASE P
OTHR
NUND
24 HR SUMMARY: Circ & condi for 75/8" csg, POOH, P/U & run 51 joints of 7 518" csg wI shoe @ 2236' MD. Circ and cement csg wI 288 bbls
lead cement, 59 bbl's of tail. Returns to surface 208 bbl's excess.. NID
. UNITS., '.
gals
bbls
-~SA~!!
Sì;RJfl.CE,
.. ' SeRVICE':
, ITEM
Rig Fuel
Rig Water
17
',()N HAND
3,174
41
. NO.
. REMARKS
REMARKS
2P-451
28 2P-451
3R-11
2P-451
2P-451
2P-451
.. .
Printed; 1/27/2004 4;39;39 PM
CASING TEST and FORMATION INTEGRITY TEST
Well Name:
2P-451
Supervisor: Don Wester
Date:
2125/2002
Reason(s) for test:
~ Initial Casing Shoe Test
0 Formation Adequacy for Annular Injection
0 Deep Test: Open Hole Adequacy for Higher Mud Weight
Casing Size and Description: 7-5/8" 29.7# L-80, BTCM
Casing Setting Depth: 2,236' TMD Hole Depth: 2,271' TMD
2,159' TVD 2,192' TVD
Mud Weight: 9.7 ppg Length of Open Hole Section: 35'
EMW= Leak-off Press. + Mud Weight = 560 psi + 9.7 ppg
0.052 x TVD 0,052 x 2,192'
EMW for open hole section = 14.6 ppg
\ \-\ :'\.!R--~
J.(5-Ù"1
Pump output =
0.0709 bps
Fluid Pumped = 3.3 bbl
3,200 psi
3,100 pSI
3,000 pSI
2,900 psi
2,800 psi
2,700 pSi
2,600 pSi
2,500 psi
2,400 psi
2,300 pSi
2,200 psi
2,100 pSI
2,000 pSi
1,900 psi
UJ 1,800 pSI
~ 1,700 psi
~ ~:~~~~::
íf 1,400 psi
1.300 pSI
1,200 pSI
1,100 pSI
1,000 pSI
900 psi
800 psi
700 pSI
~~~ ~:: ,j'\
400 pSI
300 PSI. I ,., . . . . . . .
200 psi
100 pSI I
0 pSI ~
0 . . ~ ~
I I I I I
¡TIME LINE
lONE MINUTE TICKS
I
II III III III III
111 I J I I J J ,
I
I II
. . .I.. .I... . .1... .I..
I
-LEAK-OFF TEST
-CASING TEST
-<>-LOT SHUT IN TIME
...-CASING TEST SHUT IN TIME I
-+- TIME LINE
,
I
I
/~~\\~'E\~.. ~. ~j
/ 14£111 vI
............:11......""
! . I
N N N ~ ~ . . . ~
0 . ~ N ~ 0 . ~ N
.
~
~
00
0
~
.
~
~
:8
ø
.
~
.
0
.
.
~
STROKES
NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above
LEAK-OFF DATA
MINUTES
FOR
LOT STROKES PRESSURE
0
0
~~=~~;~TJi~lj~~
8 stks i 250 psi
::::::::::::::::::: :::::j:?:~~~~:]:::::~~~E.~!:::::
12 stks i 250 psi
--------______m_- '----1-4-siks---r---2ŠÕ-pš¡----~
:::::::::: ::::: :::: t:::: j:~: ~ ~ ~ ~::: r::: ~:~~Ë:~!:::::
i 18 stks ¡ 240 psi!
:::::::::::::::::::[:::: ~?: ~ ~ ~~:::::::: ::~:~~ E. ~!:J
i 22 stks 240 psi i
[:::::::::::::::: ¡: ::: ~~: ~ ~ ~~:: ::::: :::~ ~~ Ë:~!::: : ~
i I 26 stks 240 psi ¡
I:::::::::::::::::: I:} ~:~ ~~ ~:::i ::: ~~~ ~~E]
32 stks ¡ 240 psi ¡
::::::::::::::::::: :::::~~~~~~::I::::~:~~E.~!:::::
36 stks i 240 psi
[::::::::::::::::::: ::::: ~ ~ ~ ~ ~ ~:: ::E: ::~:f~ ~:~ E: ~
¡ 42 stks ! 240 psi!
I::::::::::::::::::: :::::~::~}~~:::~:::::}1~*!¡:::::1
, "
¡ SHUT IN TIME i -----------------1~-;;~;:-;~-;;~~~-;;~~1
~~~~.~.Jif~
¡ 3.0 min ¡ 190 psi
Ë~:~~::~~~~~;;J
¡ 8.0min i I
I::::;~ :~~ ~:::: :::::::::::::: :::: :E: ::::: ::::: ::::]
CASING TEST DATA
MINUTES
FOR
CSG TEST
STROKES
PRESSURE
:::::::::::::::::::: :::::~:~~~::::r::::~~:~~::::::¡
2 stks : 380 psi:
,-----------------_. -----¡-štks----j-----S1Õ-p"šT----¡
;::::::::::::::::::: :::::~:~!~~::::¡::::~~~~?:~!~::]
i 8 stks i 1,300 psi!
¡ :::: ::::: ::::::::::::::! ~ :~!~~: ::: [: ::~ ~~ j: ?:~~: ::: ¡
I 12stks I 1,960 psi :
" I
~=::=l:==:===::!
. --- - ---- - --- - - -- - -. -- -- -- - - -- - ---- -- - - - - -- - -- - - -- - - m ----
)
- ---- -- -- -- -- -- -- - - n- -- -- - ---- ---- --- m____- -- - -- - - - --- --
SHUT IN TIME SHUT IN PRESSURE
r---õ~õmiñ-.--;----------------------2~65ö¡;s¡--
r::::: i ~~: ~~~:: :1:::::::::::: ::::::::: ~ ~~ ~?: ~!~:::
i 2.0 min ¡ 2,650 psi
r-- -- 3~ õ- ñiiñ - -- T - -- - m - ---m- - --- -- 2 ~6 5" õ ï;si ----
t:::: ~~ ~ ~ ~::: :i:: ::: ::::::::: :::: ::::: ~ ~~ ~ ~: ~~~ ::: ,
. ---- - -- - m - - - -- - -. -- --- - - - - - - - ------- -- -- - --- - - - - --- - - ---
6.0 min ¡ 2,650 psi I
. --- - - m -- -- -- -- -- ~ -- -- --- m - - -- - -- -- -- ------ - - ---- - - - - --I
7.0 min ¡ 2,650 psi
. - -- - ã ~Õ ñii ñ -- - T - - -- - - --- --- - --- - - - --2,6 5" õ ï;s i ---
'----9~õ-ñiiñ----' -----------------------2~65"õï;sf---
- - - - - - - --- - --- - -- - - - -- - - -- - m - -----on - - ------ - m -- m ---
10.0 min 2,640 psi
._---'¡5~õ-;riiñ---' -______m______-------2,64Õï;sf---
----2õ~öñ;iñ---. -----------------------2~64Õï;sf---
-------------------- ---------------------------------------
~~m~ ~~O~ ,
¡:::~~.:~:~J~:::: :::::::::::::::::::::::~~~~?:~!~:::¡
)
NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY
,"'--""',
~
I JOB NUMBER I EVENT CODE 124 HRS PROG
2P-451 ODR 503.0
SUPERVISOR I RIG NAME & NO. I FIELD NAME I OCS NO.
Donald L. Wester NORDIC 3 n1433@ppco.com 3 Meltwater
CURRENT STATUS ACCIDENTS LAST 24 HRS.?
Drlg ahead wI 6 3/4" hole @ 3043' MD 2916' TVD
24 HR FORECAST
TMD !WD IDFS
2,759.0 2,652.0 5.00
AUTHMD DAILYTANG
5,925.0 0
DAILY INT WIO MUD
0
DATE OF LAST SAFETY MEETING DAILY TOTAL
Short trip @ 3500' MD? 2/25/2002 133,641
I JAR HRS OF SERVICE 1 BHA HRS SINCE INSP I LEAKOF; 4.62 AFE AK0229 AUTH.
INC AZIM I LAST CASING I NEXT CASING LAST BOP PRES TEST
20.570 256.290 7.625 (in) @ 2,236.0 (ft) 5.500 (in) @ 5,925.0 (ft) 2/24/2002
liMliIJ!ilïl'lillí1Iii~Tr 0 l'eUMtØiÎj ! 0
WELL NAME
LITHOLOGY
LAST SURVEY: DATE TMD
2/25/2002 2,677.01
9.60
41
2
21
Bit
Mud Motor
Stabilizer - NonMag
LWD/MAP
LWD/SDN
LWD/MPR
MWD
Drill Pipe - Non-Mag 4 Comp Serv
Drill Pipe - Non-Mag 4 Comp Serv
Drill Pipe - Non-Mag 4 Comp Serv
Crossover
Drill Pipe - Heavy Wgt
Jars
Drill Pipe - Heavy Wgt
1
1
1
1
1
1
1
1
1
1
1
15
1
3
0.70
30.85
5.31
3.92
16.69
17.05
22.98
30.83
30.94
30.28
2.54
460.45
29.35
92.01
6.750
6.750
4.750
4.750
4.750
4.750
4.750
4.750
4.750
4.750
4.750
4.000
4.750
4.000
2,295.46 19.070
2,389.53 19.070
2,486.80 19.420
253.820 2,215.70 -130.78 -500.87
252.770 2,304.61 -139.61 -530.31
255.230 2,396.45 -148.44 -561.12
517.66 2,581.79 20.130
548.38 2,677.01 20.570
580.42
256.990 2,485.83 -156.15 -592.32
256.290 2,575.11 -163.80 -624.53
612.55
645.66
EMSCO
I REPT NO. 1 DATE
11 2/25/2002
ICUM. TANGO
CUM INTANG WI MUD
0
CUM COST WI MUD
1,174,003
2
2.250
2.690
2.690
2.690
2.250
2.250
2.250
2.250
FROM
00:00 01 :00
01 :00 04:00
04:00 05:30
05:30 06:00
06:00 07:00
07:00 08:00
08:00 09:00
09:00 10:00
ØODE mOUaLE
WELCTL P BOPE
DRILL P TRIP
DRILL P SFTY
DRILL P TRIP
RIGMNT P RSRV
DRILL P TRIP
DRILL P CIRC
DRILL P DEQT
SURFAC UD Test joint. Install wear ring.
SURFAC MIU BHA #2 Up load MWD. Reset Mudmotor to 1?
SURFAC PJSM Radioactive source. Load Source continue to P/U BHA
SURFAC RIH to 1152' Shallow test MWD Good.
SURFAC Service rig and top drive
SURFAC RIH tag cement @ 2144'
SURFAC Circ & condi Mud WI 75 spm @880 psi
SURFAC Test 7 5/8" to 2650 psi for 30 min O.K.
Printed: 1/27/2004 4:40:15 PM
,'--"'"
.~
2P-451
I JOB NUMBER 1 EVENT CODE 124 HRS PROG
COR 503.0
ITMD ITVD 1 DFS
2,759.0 2,652.0 5.00
IREPTNO. I DATE
11 2/25/2002
WELL NAME
\,.0:":.,;;\,/,,,
,-,,%
15:00 00:00
9.00
DRILL P
DRLG
PROD
24 HR SUMMARY: M/U BHA #2 RIH Test Csg. CIO Cmt & float equip. LOT test Broke dw @ 14.6 EMW DD 6.75" hole
S!:avICE"
,SERVICE;
2
1
4
"ITEM
Rig Fuel
Rig Water
UNITS
gals
bbls
USAGE
20
NO:
67 2P-451
2P-451
3R-11
RESERVOIR NAME
2P-417
DS4 G & I
3R-11
2P-451
2P-451
2P-451
Printed: 1/27/2004 4:40:15 PM
/"',
Casing Detail
.PHlllIPS Alaska, Inc.
~ A Subsidiary of PHILLIPS PETROLEUM COMPANY
# ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN
Nordic 3 RT to LOS PT = 26.65'
Jts.1-125
SBE
Loc.
CSR
XO
Pup
jts.# 15
MARKER
Jts 4 -14
Jts.1-3
RKB
5-1/2" GEN V CASING HANGER w/ pup
5-1/2", 15.5#, L-80,BTC MOD (125 joints)
Baker CSR Extension 6.03" 00 4.97" 10 x
Seal Locator Sub 6.07" 00 4.0610 x
Baker CSR Assy, SIZE 80-40, 5-1/2" x 4" x L-80 [desired @5400'] x
5 1/2" BT&C X 4.75" STUB ACME X
( 1 pup) 3 1/2" 9.3# L-80 8rd EUE X
3-1/2" 9.3# L-80 8rd EUE (1 joint)
3-1/2" 9.3# L-80 8rd EUE [Top of Bermuda 5502']
3-1/2" 9.3# L-80 8rd EUE (11 joints)
Weatherford Gemoco Float Collar Super Seal II
3-1/2" 9.3# L-80 8rd EUE (3 joints)
Weatherford Gemoco Float Shoe Super seal II
Plua Catcher in the top of joint #4 @ MD 5800.081
15 - 3.5" x 6.5" Bow Spring cent. & stop rings on jts# 1 thru 15,
10' above shoe on jt #1 [2 stop rings to lock in place]. Use a
stop ring in the middle of its 2 -15 such that centralizer floats
between the collar & stop ring.( 15 total cent. & 16 stop rings)
(16) 5.5 x 6.75 Bow spring cent. on the first 16 - 5.5" csg its.
(17 ) 5.5" X 6.5" centering guides on Jts# 77,80,83,86,89,92,
95,98,101,104,107,110,113,116,119, & 122.
~.
WELL: 2P-451
DATE: 3/02/2002
1 OF 1 PAGES
LENGTH DEPTH
TOPS
26.65
2.68
5379.50
10.04
1.12
19.42
.59
10.09
26.65
29.33
5408.83
5418.87
5419.99
5439.41
5440.00
5450.09
31.28 5450.09
6.09 5481.37
344.22 5487.46
.63 5831.68
94.05 5832.31
.60 5926.36
Shoe @ 5926.96
TD 6 3/4" Hole= 5950.00'
Hanger goes in the top of joint # 125
Fill each it and top up every 5 joints
Baker Lok all connections from the Top of the FC down
Break Circu at the shoe r5.5 " it # 391 , it # 77 & it # 115.
Watch for full returns at all times.
Bring pumps up over several minutes do not exceed 5 bpm.
Torque first 10 and average torque to Run-Watch Diamonds, I
if make up is ok continue to run @ this torque valve.
Nordic 3 Drlg. Supervisor: Ralph W. Bowie Jr.
REMARKS: String Weights with Blocks:???K Up, ???K On, ??K Blocks. Ran 161 Joints 5-1/2" and 21 joints
of 3-1/2" casing. Drifted 5.5" (4.825") & 3.5" (2.867") casing with plastic rabbit. Used Artie grade Jet Lube No
Lead thread compound on all connections. Casing is non-coated.
r---.
...-..."
Legal Well Name: 2P-451
Common Well Name: 2P-451
Event Name: ROT - DRILLING
Report #:
Start:
2
2/14/2002
Spud Date: 2/19/2002
Report Date: 2/25/2002
End:
Hole Size: 6.750 (in) Hole Size: Hole Size: Hole Size:
TMD Set: 5,926 (ft) SO TMD: (ft) TMD Set: Top Set: (ft)
Date Set: 3/3/2002 SO Date: Date Set: BTM set: (ft)
Csg Type: Production Casing SO Type: Csg Type: Plug Date:
Csg Size: 5.500 (in.) SO TMD: Plug Type:
SO Date: Drilled Out:
Cmtd. Csg: OPEN HOLE Cmtd. Csg: Cmtd. Csg: Cmtd. Csg:
Cement Co: Dowell Schlumberger Cementer: Steve Doughten Pipe Movement: Reciprocating
Rot Time Start: :
Rec Time Start:15:30
Time End: :
Time End: 18:00
RPM:
SPM: 1
Init Torque: (ft-Ibf)
Stroke Length: 30.0 (ft)
Avg Torque: (ft-Ibf)
Drag Up: (Ibs)
Max Torque: (ft-Ibf)
Drag Down: (Ibs)
Type: Pre-Flush Start Mix Cmt: 18:00 Disp Avg Rate: 4.00 (bbl/min) Returns: Full
Volume Excess 'Yo: Start Slurry Displ: 18:00 Disp Max Rate: 4.00 (bbl/min) Total Mud Lost: (bbl)
Meas. From: Start Displ: 18:30 Bump Plug: N Cmt Vol to Surf: (bbl)
Time Circ Prior End Pumping: 19:00 Press Prior: (psi)
To Cementing: 2.00 End Pump Date: 3/3/2002 Press Bumped: (psi) Ann Flow After: N
Mud Circ Rate: 168 (gpm) Top Plug: N Press Held: (min) Mixing Method: Batch
Mud Circ Press: 600 (psi) Bottom Plug: N Float Held: N Density Meas By:
Type: Density: (ppg) Visc: (s/qt)
Bottom Hole Circulating Temperature: (OF)
Displacement Fluid Type:
PVIYP: (cp)1 (lb/100ft2) Gels 10 sec: (lb/100ft2) Gels 10 min: (lb/100ft2)
Bottom Hole Static Temperature: (OF)
Density: (ppg) Volume: (bbl)
Slurry Data
Fluid Type: FLUSH
Slurry Interval: (ft)
Water Source:
To: (ft)
Description: CW100
Cmt Vol: (bbl)
Slurry Vol: (sk)
Density: (ppg)
Water Vol: (bbl)
Class:
Yield: (ft3/sk)
Other Vol: ()
Purpose:
Mix Water: (gal)
Foam Job: N
Test Data
Thickening Time:
Free Water: ('Yo)
Fluid Loss: (cc)
Fluid Loss Pressure:
Temperature: (OF)
Temperature: (OF)
Temperature: (OF)
Time
Compressive Strength 1:
Compressive Strength 2:
Temp
(OF)
(OF)
Pressure
(psi)
(psi)
(OF)
Printed: 1/27/2004 4:25:20 PM
~
~
Legal Well Name: 2P-451
Common Well Name: 2P-451
Event Name: ROT - DRILLING
Report #:
Start:
2
2/14/2002
Spud Date: 2/19/2002
Report Date: 2/25/2002
End:
Slurry Data
Fluid Type: FLUSH
Slurry Interval: (ft)
Water Source:
To: (ft)
Description: MUDPUSH XL Class:
Cmt Vol: (bbl) Density: 12.00 (ppg) Yield: (ft3/sk)
Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0
Test Data
Thickening Time:
Free Water: (%)
Fluid Loss: (cc)
Fluid Loss Pressure:
Time
Compressive Strength 1 :
Compressive Strength 2:
Temperature: (OF)
Temperature: (OF)
Temperature: (OF)
(OF)
Purpose:
Mix Water: (gal)
Foam Job: N
Temp
(OF)
CF)
Pressure
(psi)
(psi)
Slurry Data
Fluid Type: PRIMARY Description:
Slurry Interval: 5,926.00 (ftJTo: 4,300.00 (ft) Cmt Vol: 53.0 (bbl)
Water Source: Slurry Vol215 (sk)
Class: G
Density: 15.80 (ppg) Yield: (ft3/sk)
Water Vol: (bbl) Other Vol: 0
Test Data
Thickening Time:
Free Water: (%)
Fluid Loss: (cc)
Fluid Loss Pressure:
Time
Compressive Strength 1:
Compressive Strength 2:
Temperature: (OF)
Temperature: (OF)
Temperature: (OF)
(OF)
Purpose:
Mix Water: (gal)
Foam Job: N
Temp
(OF)
(OF)
Pressure
(psi)
(psi)
Test Press: (psi)
For: (min)
Cement Found between
Shoe and Collar:
Pressure: (ppge)
Tool:
Open Hole: (ft)
Hrs Before Test:
Liner Lap:
Pos Test: (ppge)
Neg Test: (ppge)
Hrs Before Test:
Cement Found on Tool:
Tool:
Tool:
CBL Run:
Under Pressure: (psi)
Bond Quality:
Cet Run:
Bond Quality:
Temp Survey:
Hrs Prior to Log:
(ft)
Cement Top:
How Determined:
TOC Sufficient:
Job Rating:
If Unsuccessful Detection Indicator:
Remedial Cementing Required:
Number of Remedial Squeezes:
Printed: 1/27/2004 4:25:20 PM
...----.
~
WELL NAME
1 JOB NUMBER EVENT CODE 124 HRS PROG
2P-451 ODR
1 RIG NAME & NO. I FIELD NAME I OCS NO.
NORDIC 3 n1433@ppco.com 3 Meltwater
ACCIDENTS LAST 24 HRS.?
Running completion
TMD TVD DFS
5,950.0 5.755.0 11.00
AUTHMD 1 DAILY TANG
5,925.0 0
DAILY INT WIO MUD
0
DATE OF LAST SAFETY MEETING DAILY TOTAL
3/3/2002 195,954
I LEAKOFF AFE
14.62 AK0229
I NEXT CASING LAST BOP PRES TEST
2,236.0 (ft) 5.500 (in) @ 5,925.0 (ft) 2/24/2002
1 REPT NO. I DATE
17 3/3/2002
1 CUM. TANGO
CUM INT ANG WI MUD
0
CUM COST WI MUD
1,984,778
SUPERVISOR
M.C. HElM
CURRENT STATUS
24 HR FORECAST
Run completion-nId=n/u Freeze protect-release rig.
LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP
LAST SURVEY: DATE TMD INC AZIM I LAST CASING
3/2/2002 5,866.15 0.970 257.340 7.625 (in) @
AUTH.
0
0
46
3
2
Bit 1 0.70 6.750
Mud Motor 1 30.85 6.750
Stabilizer - Non Mag 1 5.31 4.750 2.250
LWD/MAP 1 3.92 4.750
LWD/MPR 1 17.05 4.750
LWD/SDN 1 16.69 4.750
MWD 1 22.98 4.750
Drill Pipe - Non-Mag 4 Comp Serv 1 30.83 4.750 2.690
Drill Pipe - Non-Mag 4 Comp Serv 1 30.94 4.750 2.690
Drill Pipe - Non-Mag 4 Comp Serv 1 30.28 4.750 2.690
Crossover 1 2.54 4.750 2.250
Drill Pipe - Heavy Wgt 15 460.45 4.000 2.250
Jars 1 29.35 4.750 2.250
Drill Pipe - Heavy Wgt 3 92.01 4.000 2.250
21
13/13/13/1311
4,928.0
FROM TO HOÜR~¡
00:00 02:00 2.00 DRILL P
02:00 04:00 2.00 DRILL P
EMSCO
TRIP
RHÄSE,
PROD Complete pooh for csg.
TRIP
PROD
PJSM, recover rad source, drain up tools & down load Iwd tools. Ld Iwd I mwd
equip & bha.
04:00 06:00
2.00
CASE P
OTHR
PROD
Drain up stack, pull wear bushing, Install & test upper pipe rams 5.5" rams
for csg.
Printed: 1/27/2004 4:40:37 PM
~
."'-"'"
WELL NAME
2P-451
JOB NUMBER I EVE~;~DE 124 HRS PROG
ITMD ITVD IDFS REPTNO. I DATE
5,950.0 5,755.0 11.00 17 3/3/2002
07:00 08:30 1.50 CASE P
08:30 15:30 7.00 CASE P
15:30 18:00 2.50 CASE P
18:00 20:30 2.50 CEMENT P
20:30 22:30 2.00 CEMENT P
22:30 23:30 1.00 CEMENT P
23:30 00:00 0.50 CMPL TN P
. SE.RVICE
ITEM
Rig Fuel
Rig Water
UNITs
gals
bbls
2P-451
2P-451
2P-451
2P-451
2P-451
Ru to run csg I PJSM.
RUNC PROD Pu & run 3.5 section of csg to include XO to 5.5' & Baker CSR.
RUNC PROD Continue to run 5? csg as per program.
CIRC PROD Circ.-condition hole for cementing.
PUMP PROD Mix & pump cement as per program-bump plug-floats held.
PULD PROD Rig down cement head-clear floor of all cement equipment.
OTHR PROD Set 11" X 5.5" packotf & test to 5000#.
RURD PROD Change bails & rig up to run completion.
PERSONÑIËi::riA T A
NO.:,' HOut:lS;lfr'. ,¡'COMPANY";
2 Baker Hughes Inteq
1 Bariod
4 technodyne
, ..'~:cn.'."...'
.,...,.:'.
, S~RVICE '
3R-11
_:NO.:~... ,
290 2P-451
REMARKS'
Printed: 1/27/2004 4:40:37 PM
I ! I I
I I II I 1TIME LINE
. ... . . .. . . . . . . ONE MINUTE TICKS
I
--LEAK-OFF TEST
-CASING TEST
,...,-- LOT SHUT IN TIME
-+- CASING TEST SHUT IN TIME
~TIME LINE
\'~,~. t.~W~
--: ~f
I I
CASING TEST and FORMATION INTEGRITY TEST
Well Name:
2P-451
Date:
314/2002
Reason(s) for test:
0 Initial Casing Shoe Test
¡z Formation Adequacy for Annular Injection
0 Deep Test: Open Hole Adequacy for Higher Mud Weight
Casing Size and Description: 7-5/8" 29.7# L-80, BTCM X 5.5"
Casing Setting Depth: 2,236' TMD
2,159' TVD
Mud Weight: 9.6 ppg
EMW= Leak-off Press. + Mud Weight
0.052 x TVD
Length of Open Hole Section:
=
450 psi
0,052 x 2,192'
EMW for open hole section = 13.5 ppg
Pump output =
0.0709 bps
Fluid Pumped = 3,0 bbl
3,200 ps;
3,100 ps;
3,000 ps;
2,900 ps;
2,800 ps;
2,700 ps;
2,600 pSI
2,500 ps;
2,400 ps;
2,300 ps;
2,200 ps;
2,100 pSI
2.000 ps;
1,900 ps;
UJ 1,800ps;
gs 1,700ps;
~ 1,600 ps;
UJ 1,500ps;
8: 1,400ps;
1,300 ps;
1,200 ps;
1,100 ps;
1,000 ps;
900 ps;
800 ps;
700 ps;
600 ps;
~~~ ~:: j
300 ps;. T
200 psi
100 pSI
0 psi I ,
0 ~ 00
Supervisor: M.C. Heim
LEAK-OFF DATA
MINUTES
FOR
LOT STROKES PRESSURE
;¡
[::::::::::::::::~:::::~~!~~::::J::::!~:~~~:::::~
¡ 3 stks i 210 psi!
¡- - -- - m - - - - -- - m - . - - ---¡is tk ~ - -- - r---¡ SÕ I';~ ¡ ----1
I::::::::::::::::::: :~~::~~~[~::I~~::~~~~~~;:~~:~
F~::~::~::~~:~::~ :~:::~:~:~}~~::~::~:~::~~~:t:~;:~::~
r------------------ '----21-stks---- .---- -¡ÕÕI;-~¡----~
c::::: ~ ~:: ~:~::~ I:: ~~:~! ~~:~::; :~: ~ :~~~~~~! ~~: ~ ~
i i 27 stks : 400 psi
\ ), l t:.\\ \() F~:~::~::~:~:~:::f~:::~g}~~::::F::~~~~:~;:~::i
þo ~" b::::~:::~::::~:¡::::~g}~~:~~:¡~:~::~~~:~i;:~::~
' )-- d ( s -a 1---"y-------------r----4"2-;;tks----"-----¡õõï;~¡----1
1- - - -- - - - - - - -- -- -- -- ì -- - - - - -- - - - - - - -- - -- ------- -- m -- - - -- -"1
t:: ~:~:: ~~: ~::::: ~: ~ ~:::::~::~::: ::~ :~:: ~~::~:~: ~ ::~::: j
III III III ¡ i
i- m - -- - - - - -- -- --- - ~ - -- - - - - - - - - - - - - - - -- - -- m ---- - --- m ---!
1------------------- .------------------ .m__----__---------i
¡------------------- ,----- ----- ____m__--_--_--------------
I:: ~~:::: ~:::~:::: ~: : ~: ::~:~:::~: :~: ::r~::::~: ~ :~~~:: ~:: ~
1------------------- .---______mm---t-__-----------------
! ___mm---_m--L------------------~
: SHUT IN TIME: : SHUT IN PRESSURE 1
(- m - m - --- - - - - -- - t - -- m m -- - - m - -t - --- -- -- -- --- - - -- ---I
( 0.0 min ( : 400 psi:
t: ~:: ~~ ~ ~~! ~:: ~ t~:::::::::: ::~ J: :~~ :~: i~ P.~~!:: :~j
! 2.0 min 1 : 200 psi:
t-- - ---- --- - - - - - - - -- f - - --- - m --_no ------ - ------ - -- -- - - - ---I
L..--~ ~~.!:':! ~- - -- '. --- m --- - --- - - - - -- - -- - -~-~£_t>_~! - --- J
: 4.0 min '
:-----š.õ-rñiñ---- .-------_____--m- .--------------------
._---¡3".Õ-rñ iñ---- ._____m___m__m--___--_-----------~
- - - - - 7-. õ - rñ iñ --- --- - - m -- - - - - - - - - ---- --- -- - ..- -- -- -- ---
_m ---------- ----- .--m______---__--_--_m--_m--_-----
00 00 00 ~ ~ - 8.0min
0 ~ 00 N m g :-----9~õ-rñiñ----.----______m_---_-_----m__m___-----
t ::: ~~~ :~:~! ~:: t::::: :::::::::::I ::: ::: ::: :::::::::: ~
Hole Depth:
2,271' TMD
2,192'TVD
35'
+ 9.6 ppg
II III 111,111 III
I(
/,/?f
~ , - - - - - - -
I
I
m
~
m
00
~
m
0
~
00
~
~
N
~
N
00
~
~
0
~
~
~
STROKES
NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above
~
CASING TEST DATA
MINUTES
FOR
eSG TEST
STROKES
PRESSURE
. --- -- --- ------ m T -- - Õ - š tk Š - --- -- --- - -6" Õ ï;šï ----
-------------------1-m_--_m--_--_----------------------
( 2 stks 380 psi
. - - -- - - - --- - ---- - --1m -- 4" - ~t i(š - -- - ------ 81 Õ - jj ~ T' - --
:::~~::::::::::::::: :::::~:~~~~:::::::::~~~~~~:~~::::¡
8 stks 1,300 psi i
:::::::::: ::::: ::::: :::: ~~ :~!~~::: :::::: ~~~~:~: ~~!. J
¡ 12stks 1,960 psi i
-- -- -- -- -- --- - - m T -- - 1¡- ~i ks --- - '----2,3 ¡Õ ï; šf--1
: ::~::::::::::::::: t: :~~::~ !~~: :::;:::: ~~~ ~ ~: ~~:J
~::::::::::::::::::L::::::::::::::J::::::::::::::::j
. I ' ,
: ,
i SHUT IN TIME SHUT IN PRESSURE:
. - -- - - - - -. - - --- - -_on - - ------ - ----- m --- -- --- - -- --- - - -- - --I
0.0 min 2,650 psi:
:::::~~~:~~::::: :::::::::::::::::I::~~~~~:~~~]
2.0 min I 2,650 psi I
:::::~~~:~~~::::: ::::::::::::::::~t::~~~~~:~~~:::i
4.0 min ( 2,650 psi 1
'----5~õ-ñi¡;;m_. --- --------------------2:6sõï;;;-r--1
:::::~~~:~i~::::: :::::::::::::::::::::::~~~~:~~~J
._-- _!.~9_~¡~---_. ______m_------_-.----~~~?~_P.~!_---
8.0 min 2,650 psi
~-----------------_. ______m_- -----.---- --.---------------
: 9.0 min 2,650 psi
rm_'¡õ'-õ-rri¡ñ---' ------______m_--,_- -2:6¡õï;šf---
F~~~~:~~:::: :::::::::::::::::::::::~~~~~~~~~:::
t~ ~ ~ ~ ~~~~ ~J~ ~~ ~: ~~~ ~~~ :~~ ~ ~ ~~~~~~~~~ ~ ~~E~~ ~~~ ~~ ~ ~ ~
)
)
NOTE: TO CLEAR DATA. HIGHLIGHT AND PRESS THE DELETE KEY
,~
~
WELL NAME
I JOB NUMBER I EVENT CODE 124 HRS PROG
2P-451 ODR
1 RIG NAME & NO. I FIELD NAME I OCS NO.
NORDIC 3 n1433@ppco.com 3 Meltwater
ACCIDENTS LAST 24 HRS.?
LITHOLOGY
Rig up & drill.
I JAR HRS OF SERVICE I BHA HRS SINCE INSP
INC AZIM I LAST CASING
0.970 257.340 7.625 (in) @
TMD ITVD I DFS
5,950.0 5,755.0 12.00
AUTHMD I DAILY TANG
5,925.0 0
DAILY INT WIO MUD
0
DATE OF LAST SAFETY MEETING DAILY TOTAL
3/4/2002 278,909
I LEAKOFF AFE
14.62 AK0229
¡NEXT CASING
2,236.0 (ft) 5.500 (in) @
0
I REPT NO. I DATE
18 3/4/2002
I CUM. TANGO
CUM INTANG WI MUD
0
CUM COST WI MUD
2,263,687
SUPERVISOR
M.C. HElM
CURRENT STATUS
Spotting cuttings tank & Misc. Equipment.
24 HR FORECAST
AUTH.
LAST SURVEY: DATE TMD
3/2/2002 5,866.15
LAST BOP PRES TEST
2/24/2002
0
16:00 20:30
20:30 23:00
23:00 00:00
4.50
2.50
1.00
CMPL TN P
CMPL TN P
CMPL TN P
NUND
FRZP
OTHR
S,ERVICE
20
, TYPE
2P-417
DS4 G & I
:REMARKS
2P-451
2P-451
3R-11
:ZONE'-'"
2P-417
DS4 G & I
3R-11
2P-451
2P-451
2P-451
TOP '.
67
0
290
Printed: 1/27/2004 4:40:58 PM
'----...
Transmittal Form
INTEQ
To:
AOGCC
333 West 7th Ave, Suite 100
Anchorage, Alaska
99501
Attention:
Lisa Weepie
Reference:
2P-451
I' -=------- ---
Ii Contains the following:
II LDWG Compact Disc J f} 8 W \
I (Includes Graphic Image files)
I 1 LDWG lister summary
1
I!
Î
I
1 blue line - MPR Measured Depth Log
1 blue line - MPR TVD Log
1 blueline - CCN-ORD Measured Depth Log
1 blueline - CCN-ORD TVD Log
LAC Job#: 251311
Sent By: Glen Borel
Received B;;'\<cìlv ~ \.C~ ~1V\.
PLEASE ACKNOWLEDGE RECEIPT BY SIGNI
OR FAXING YOUR COpy
FAX: (907) 267-6623
Baker Hughes INTEQ
7260 Homer Drive
Anchorage, Alaska
99518
Direct: (907) 267-6612
FAX: (907) 267-6623
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"ill
BAKER
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HUGHES' ::
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Anchorage GEOScience Center
.
--
Date: Oct 22, 2003
Date:RECEIVED
NOV 12 2003
Scblumbepgep
Schlumberger Technology Corporation, by and through is Geoquest Division
3940 Arctic Blvd, Suite 300
Anchorage, AK 99503.5711
ATTN: Beth
1Y-27
1A-O5
2F-08
2N-321A
2P-451
2N-331
2A-13
2P-431
1Y-06A
1G-05
1H-04
1R-16
1Y-01
1R-10
1G-02
1Y-08
1 D-03
NO. 2579
Company:
Field:
Date BL Sepia
11114/02 1
10/26/02 1
11115102 1
10129102 1
11/03/02 1
10128102 1
11116102 1
10/31102 1
10130/02 1
11/18/02 1
11119/02 1
11122102 1
11125102 1
11121/02 1
11117102 1
11108/02 1
11/09/02 1
Well Job # Log Description
, 'i.~ -~~ I ~ ,,--S PRODUCTION PROFILE
f~/-IOL.j LDL
/ 'tJ -tJri J LDL
I ~ -/í ~::S INJECTION PROFILE
~~ -nor NOISE LOG
I "6-/ J INJECTION PROFILE
I .' 5- JLI'-I PRODUCTION PROFILE
aCG -05 3 NOISE LOG WITEMP
!~7- J 3, <./ PRODUCTION PROFILE
! ,~-o~o INJECTION PROFILE
I d -/03 INJECTION PROFILE
f '~-I.'i..-:S PROD PROFILE WfDEFT
r :.::)-0 S 0 INJECTION PROFILE
! R.9 -ell (0 INJECTION PROFILE
J<¡?' d-I.~~ INJECTION PROFILE
l'X3--01;; . INJECTION PROFILE
! Î 9-0 c¡ PROD PROFILE WIDEFT
SIG~~
DATE:
Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you.
12/04/02
Alaska Oil & Gas Cons Comm
Attn: Lisa Weepie
333 West 7th Ave, Suite 100
Anchorage, AK 99501
Kuparuk
)
CD
Color
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DEC 1 Cì 20U
:'-';j ~, i.'.;.:;~' '~;Qn:;:. ;::;.::río,mili"t!(¡'fi
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".--...,
PHilliPS Alaska, Inc.
A Subsidiary of PHilLIPS PETROLEUM COMPANY
Post Office Box 100360
Anchorage, Alaska 99510-0360
R. Thomas
Phone (907) 265.6830
Fax: (907) 265-6224
April 11, 2002
Commissioner Cammy Oechsli Taylor
State of Alaska
Alaska Oil & Gas Conservation Commission
333 West ih Avenue Suite 100
Anchorage, Alaska 99501
Subject: Completion Report for 2P-451 (202-008)
Dear Commissioner:
Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the
Meltwater well 2P-451.
If you have any questions regarding this matter, please contact Pat Reilly at 265-6048.
Sincerely,
..\'"<-~ \~
R. Thomas
Greater Kuparuk Team Leader
PAl Drilling
RT/skad
RECEIVED
APR 1 2 200!
Al88Ðt1 & GIs Cons. QJnmis8ion
, . Anchorage
00
~
r---..
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
Oil 0 Gas
2. Name of Operator
Phillips Alaska, Inc.
3. Address
P. O. Box 100360, Anchorage, AK 99510-0360
4. Location of well at surface
1036' FNL, 1524' FWL, Sec. 17, T8N, R7E, UM rGÕi\'~;¡~iõÑ-¡
At Top Producing Interval l.3.:.2.!L:O2L
1363' FNL, 281' FWL, Sec. 17, T8N, R7E, UM .' V-I'I,!,-Ct]-", 1.
At Total Depth ;.. :)t7). :_-- !
1364' FNL, 275' FWL, Sec. 17, T8N, R7E, UM--"",""",,-,J (ASP: 442233, 5868525)
5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No.
RKB 27' feet ADL 373112 ALK 4998
12. Date Spudded 13. Date T.D. Reached 14. Date comp:z-~~~r Aband. 115. Water Depth, if offshore
February 21, 2002 March 2, 2002 Marcl]$, 2002 NI A feet MSL
17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey '120. Depth where SSSV set
5950' MD 1 5755' TVD 5800' MD I 5607' TVD YES 0 No D Landing Nipple @ 496'
22. Type Electric or Other Logs Run
GRlRes/Den/Neu
23.
1. Status of well
D-'
Suspended
D
Abandoned D
Service D "".. .".,'lC"'~'f"P
,t<X'A~. ]~1\
r -f:." ""' ,.¡'
.""" .
b.H . -;
~~,,"A"""'.'
(ASP: 443484, 5868845)
(ASP: 442240, 5868526)
CASING SIZE WT. PER FT. GRADE
16" 62.5# B
7.625" 29.7# L-80
5.5" x 15.5# L-80
3.5" 9.3# L-80
CASING, LINER AND CEMENTING RECORD
SETTING DEPTH MD
TOP BOTTOM
Surface 110'
Surface 2236'
Surface 5408'
5408' 5927'
24. Perforations open to Production (MD + TVD of Top and Bottom and
interval, size and number)
5562' - 5578' MD
5367' - 5383' TVD
6 spf
Classification of Service Well
7. Permit Number
202-0081
8. API Number
50-103-20402-00
9. Unit or Lease Name
Kuparuk River Unit
10. Well Number
2P-451
11. Field and Pool
Kuparuk River Field
Meltwater Oil Pool
16. No. of Completions
21. Thickness of Permafrost
1379' (approx.)
42"
CEMENTING RECORD
392 sx AS 1
AMOUNT PULLED
HOLE SIZE
9.875"
6.75"
6.75"
370 sx AS IIIL, 120 sx LiteCrete
215sxCIassG
included above
3.5"
TUBING RECORD
DEPTH SET (MD)
5408'
PACKER SET (MD)
5420' (CSR)
25.
SIZE
26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED
5562' - 5578' MD 195899# of 16/20 proppant behind pipe
27.
Date First Production
April 3, 2002
Date of Test Hours Tested
PRODUCTION TEST
Method of Operation (Flowing, gas lift, etc.)
Gas Lift Oil
Production for OIL-BBL
2988
OIL-BBL
4/1112002 14 hours
Flow Tubing Casing Pressure
press. 287 psi 943
Test Period>
Calculated
GAS-MCF
4661
GAS-MCF
WATER-BBL
6
WATER-BBL
7
24-Hour Rate>
3583 4139
CORE DATA
Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips.
N/A
CHOKE SIZE IGAS-OIL RATIO
100 1560
OIL GRAVITY - API (carr)
not available
RECEIVED
APR 1 2 200~
Al8a0il& Gas Cons. Commission
, , Andtorage
Form 10-407 Rev. 7-1-80
CON.TINUf'D,ON.REYE;RSE ~DE¡
( ; [f ) :' r :" 'f \: . f 1
r- 'c. \ '-c.', \", ~-
RBDMS BFL
ADQ I ,h; ~V"','1
f'... --
1.:Jr-
Submit in duplicate
. .----..,
~,
¡ 29.
30.
GEOLOGIC MARKERS
FORMATION TESTS
MEAS.DEPTH
TRUE VERT. DEPTH
Include interval tested, pressure data, all fluids recovered and gravity.
GOR, and time of each phase.
NAME
T3.1
T3
T2
5364'
5500'
5594'
5169'
5305'
5399'
Annulus left open - freeze protected with diesel.
RECEIVED
APR 1 2 2002
AIaIka <II GIs ConI. Commission
AndIorage
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 Pat Reilly 265-6048
Signed~~~~---
Randy Thoma~
, ,T;t~
Kuparuk Team leader
Date
<'1/ (1/(;; Z
Prepared by Sharon Allsup-Drake
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 (OF, KB, etc.).
Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location
of the cementing tool.
Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection,
Shut-in, Other-explain.
Item 28: If no cores taken, indicate "none".
Form 10-407
DUPLICATE
,-'""""..
-'""""..,
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
2P-451
2P-451
ROT - DRILLING
NORDIC 3 n1433@ppco.com
Nordic 3
Start: 2/14/2002
Rig Release: 3/5/2002
Rig Number: 3
Spud Date: 2/19/2002
End:
Group:
2/15/2002
24.00 MOVE
RGRP MOVE
00:00 - 00:00
2/16/2002
OTHR MOVE
00:00 - 00:00
24.00 MOVE
2/17/2002
00:00 - 01 :30 1.50 MOVE MOVE MOVE
01 :30 - 05:00 3.50 MOVE MOVE MOVE
05:00 - 07:00 2.00 MOVE OTHR MOVE
07:00 - 17:30 10.50 MOVE MOVE MOVE
17:30 - 19:00 1.50 MOVE MOVE MOVE
19:00 - 00:00 5.00 MOVE MOVE MOVE
00:00 - 06:00 6.00 MOVE MOVE MOVE
06:00 . 21 :00 15.00 MOVE RURD MOVE
2/18/2002
21 :00 - 22:30
1.50 MOVE
SFTY MOVE
22:30 - 00:00
1.50 MOVE
RURD MOVE
2/1912002
12.00 RIGMNT RURD MOBMIR
00:00 - 12:00
12:00 - 00:00
12.00 RIGMNT OTHR MOBMIR
2/20/2002 00:00 . 09:00 9.00 DRILL RIRD MOBMIR
09:00 - 11 :00 2.00 DRILL TRIP MOBMIR
11 :00 - 12:00 1.00 WELCTL BOPE SURFAC
12:00 - 18:00 6.00 DRILL TRIP SURFAC
18:00 - 19:00 1.00 RIGMNT OTHR SURFAC
19:00 - 22:00 3.00 RIGMNT RURD SURFAC
22:00 - 00:00 2.00 RIGMNT RURD SURFAC
Rig maintenance. Installing power corrector
on 1R pad. Will move to 2P-451 a 40 mile m
ove after rig maintenance.
Continue Rig maintenance installing power c
orrector in SCR room. complete installion a
nd test power corrector. Started camp move
at 2130 hrs fI 1R to 2P pad
Prepair rig for move.
Move rig f/ 1R pad to spine road
Stand by at spine road for Phillips crew cha
nge
Conintue Rig move to Alpine turn off.
Stand by for Phillips crew change.
Continue rig move from Alpine to 2P pad.
Continue to move rig fl 2N pad to 2P pad. 0
n pad @ 0430 hrs. Move over well 2p.451 @
0600 hrs
Berm up, spot verious rig equipment, close i
n rig and warm up, R/U Hi-line power. Repla
ce stairs and cuttiong shut driller side, Cha
nge out save sub to HT38, reset top drive to
rque. Thaw and worm up Hi-line switch traile
r .
Pre-spud meeting wI Nordic crews, baker mw
d hands, Phillips safety engineer Rich Nelso
n, Drilling engineer Pat reilly, Rig co. Man
wester
R/U baker intec MWD unit string lines. Put c
amp on Hlline power @ 2300 hrs 02/18/2002.
Set diverter under rig.
Continue working with Hi-line cabe, Switch g
ear and power corrector. Set in 16" devertor
equipin well room. Conductor connector to
low for this rig. Wait on equipment to arrive
Continue testing Hi-line power cable & powe
r corrector. Set in Bariod solids control unit
. Load pipe shed wI DP & BHA. Work on dive
rter change out Tee. To low cut out window t
0 allow gun barrell and diverter down 3". CI
0 drip pan to 21" and installing riser. Accep
trig @ 1800 hrs.
Continue N/U 20" riser on diverter & diverte
r tank.
R/U to P/U 4" HT-38 drill pipe
Test Diverter. State man John Spalding waiv
ed.
P/U 18 its 4" HWDP stand back in derrick. C
ontinue to P/U 4" dp stand back
PJSM Service rig and top drive.
Continue to wire baker mwd unit. Power corr
ector.
M/U 9 7/8" bit & mud motor. Prepair to clo 1
Printed: 4/4/2002 8:56:43 AM
~
,~
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
2P-451
2P-451
ROT - DRILLING
NORDIC 3 n1433@ppco.com
Nordic 3
Start: 2/14/2002
Rig Release: 3/5/2002
Rig Number: 3
Spud Date: 2/19/2002
End:
Group:
2/2012002 22:00 - 00:00 2.00 RIGMNT RURD SURFAC
2/21/2002 00:00 - 00:30 0.50 DRILL TRIP SURFAC
00:30 - 03:30 3.00 DRILL DRLG SURFAC
03:30 - 04:30 1.00 DRILL TRIP SURFAC
04:30 - 05:30 1.00 DRILL TRIP SURFAC
05:30 - 10:00 4.50 DRILL TRIP SURFAC
10:00 - 00:00 14.00 DRILL DRLG SURFAC
2/22/2002 00:00 - 02:00 2.00 DRILL WIPR SURFAC
02:00 - 03:00 1.00 RIGMNT OTHR SURFAC
03:00 - 04:00 1.00 DRILL WIPR SURFAC
04:00 - 19:30 15.50 DRILL DRLG SURFAC
19:30 - 20:30 1.00 DRILL CIRC SURFAC
20:30 - 00:00 3.50 DRILL WIPR SURFAC
2/23/2002 00:00 - 01 :30 1.50 DRILL CIRC SURFAC
01 :30 - 03:30 2.00 DRILL TRIP SURFAC
03:30 - 06:00 2.50 DRILL TRIP SURFAC
06:00 - 08:30 2.50 CASE RUNC SURFAC
08:30 - 09:00 0.50 CASE SFTY SURFAC
09:00 - 10:00 1.00 RIGMNT RSRV SURFAC
10:00 - 14:00 4,00 CASE RUNC SURFAC
14:00 - 16:00 2.00 CEMENTCIRC SURFAC
16:00 - 19:00
3.00 CEMENT PUMP SURFAC
19:00 - 20:30
1.50 CEMENTOTHR SURFAC
6" conductor to 110'
M/U 9-7/8" Bit #1, on motor BHA #1 CIO 16"
conductor to 110'
Drill 9-7/8" hole fl 110' to 235'
Circ @ 5 bpm clean hole. POOH stand back.
M/U Baker MWD
Orient MWD, up load mwd
RIH Test MWD failed. POOH Change out MW
D tool RIH
Continue Directional drilling 9 718" Hole f/ 2
35' to 1215' MD 1151' TVD. Up wt 50K, dn
wt 50K, Rt wt 50k, Tq on btm 1550 ftllb, Pu
mp sweeps as needed. Haul cuttings to Nabo
rs 19 ball mill 28 cu/yrd, Excess to DS 4 G
& I 52 culyrd
Circ three bottoms up @ 1215' MD. Short tri
p to flex pipe. Hole in good condition.
Service rig and top drive. PJSM
RIH to 1215' No Fill. Hole in good condition
Continue drilling 9 7/8" hole f/ 1215' to 225
l' MD, 2174' TVD TD. Pump sweeps as need
e d.
Circ and condition hole. Pump sweep plus 3
bottoms up.
Wiper trip to to HWDP. Hole in good conditi
on. R.I.H. to 2251' No Fill.
Circ & condi hole f/ 7 5/8" csg @ 2251' MD.
POOH Stand back 4" DP & HWDP. Hole in go
od condition. Drag 0-5K up wt 70k
LID flex collars, Down load MWD LID same,
LID Motor and bit.
R/U GBR Csg crew to run 7 5/8"
PJSM wI cementers, rig crew and truck drive
r s .
Service rig and top drive. Cl0 wash pipe.
P/U and run 51 joints 7 5/8" 29.7# L-80 BTC
M casing wI float and shoe to 2236' MD.
M/U Hanger & Cement head on landing joint.
Circ 5 bottoms up land hanger. Reciprocate
ppipe 12' while circ @ 6 bpm 520 psi. total
8600 stk. 609 bbl's. up wt 85k, dn wt 67k
Pump cement as perprgram 40 bbl's CW100
drop bottom plug followed by 40 bbl's 10.5
Mud push followed by 288 bbl's 10.7 ppg Asl
ite cmt lead followed 59 bbl's 12.0 ppg Lite
crete cement. Drop bottom plug kick out wI
10 bbl's water and displced wI mud 89 bbl's
wI rig pump 1254 strokes. Bump plug wI 250
0 psi held 5 min. CIP @ 1815 hrs 02/23/02
Bleed of pressure Floats held O.K.
Pull landing jt. R/U stack washing tool 40 rp
Printed: 41412002 8:56:43 AM
/~
,~
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
2P-451
2P-451
ROT - DRILLING
NORDIC 3 n1433@ppco.com
Nordic 3
Start: 2/14/2002
Rig Release: 3/5/2002
Rig Number: 3
Spud Date: 2/19/2002
End:
Group:
2/2312002 19:00 - 20:30 1.50 CEMENTOTHR SURFAC
20:30 - 00:00 3.50 CASE NUND PROD
2/24/2002 00:00 - 04:00 4.00 WELCTL NUND PROD
04:00 - 07:00 3.00 WELCTL NUND PROD
07:00 - 12:00 5.00 WELCTL NUND PROD
12:00 - 17:00 5.00 WELCTL BOPE PROD
17:00 - 20:30 3.50 WELCTL EaRP PROD
20:30 - 00:00 3.50 WELCTL EaRP PROD
2/2512002 00:00 - 01 :00 1.00 WELCTL BOPE PROD
01 :00 - 04:00 3.00 DRILL TRIP PROD
04:00 - 05:30 1.50 DRILL SFTY PROD
05:30 - 06:00 0.50 DRILL TRIP PROD
06:00 - 07:00 1.00 RIGMNT RSRV PROD
07:00 - 08:00 1.00 DRILL TRIP PROD
08:00 - 09:00 1.00 DRILL CIRC PROD
09:00 - 10:00 1.00 DRILL DEaT PROD
10:00 - 12:30 2.50 CEMENT DSHO PROD
12:30 - 13:00 0.50 DRILL DRLG PROD
13:00 - 13:30 0.50 DRILL CIRC PROD
13:30 - 15:00 1.50 DRILL LOT PROD
15:00 - 00:00
9.00 DRILL
DRLG PROD
2/2612002 00:00 - 08:30 8.50 DRILL DRLG PROD
08:30-11:00 2.50 DRILL CIRC PROD
11 :00 - 12:00 1.00 DRILL WIPR PROD
12:00 - 13:00 1.00 DRILL FIT PROD
13:00 - 13:30
0.50 WELCTL OTHR PROD
m 13 bpm use 100 bbl. 30' up & dn
N/D 16" Diverter CIO gun barrell and "T". Of
f load casing tools. Change out bails.
Continue N/D 16" diverter & gun barrell clo
diverter "T". CIO Saver sub
Install and orient FMC 11" 5M well head. T
est gas alarms
N/U 11" 5M thripple gate BOP's. Changed pi
pe rams to 4" & drip pan.
Test BOP's 250-3000
Repair FL Cameron manual choke valve. Par
ts in Dead Horse behind Nabors rig 18 Move
Install new repair kit. Test No Good. C/o wI
new valve. Test ssame 300-3000 O.K
LID Test joint. Install wear ring.
M/U BHA #2 Up load MWD. Reset Mudmotor t
0 1?
PJSM Radioactive source. Load Source conti
nue to PIU BHA
RIH to 1152' Shallow test MWD Good.
Service rig and top drive
RIH tag cement @ 2144'
Circ & condi Mud W/ 75 spm @880 psi
Test 7 5/8" to 2650 psi for 30 min O.K.
Cl0 Cmt float collar @ 2248' & shoe @ 2236
, Cmt to 2251' orignal TO
Drill 30' new hole.
Circulate and condition mud LOT test
Preform LOT test broke down @ 560 psi 14.
6 ppg EMW. Injected @ 11.3 ppg @ 4 culft P
erlmin wI 240 psi 2192' TVD and 9.7 ppg M
ud weight.
Continue drictional drilling 6 3/4" hole FI 22
81' to 2759' MD 2652' TVD. Up wt 70k, Rt w
t 70K @ 45 rpm dw wt 68k 90 spm 1400 psi.
Pump sweeps as needed.
Dir drlg 2759 - 3204'.
Cir cond mud for F.I.T.,sweep hole & spot I
ow water loss pill to cover open hole sectio
n.
Pooh for F.I.T. to 2210'.
Conduct F.I.T. to 15.3 ppg emw. Calculati
ons: Csg shoe @ 2236 ' md I 2159 tvd, mw =
9.6 ppg, open hole to 2251' when csg ran,
current td 3204'. Formation broke back @
640 psi wI 18 gals pumped, pumped an addit
ional 45 gallons @ 320 psi. SI & system ble
d back to 210 psi in 5 minutes & held for 5
minutes @ 210 psi. Bled back 10 gallons.
EMW = 9.6 ppg + 640 psi imposed I [.052
x 2159'] EMW = 15.3 ppg.
Rig down test equip & blow down pump.
Printed: 4/4/2002 8:56:43 AM
,...-...,
~
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
2P-451
2P-451
ROT - DRILLING
NORDIC 3 n1433@ppco.com
Nordic 3
Start: 2/14/2002
Rig Release: 3/5/2002
Rig Number: 3
Spud Date: 2/19/2002
End:
Group:
2/2612002
13:30 - 14:30
14:30 - 15:00
15:00 - 00:00
2/27/2002
00:00 - 18:30
1.00 RIGMNT RSRV PROD
0.50 DRILL TRIP PROD
9.00 DRILL
DRLG PROD
18.50 DRILL
DRLG PROD
18:30 - 20:00 1.50 DRILL CIRC PROD
20:00 - 22:00 2.00 DRILL WIPR PROD
22:00 - 23:00 1.00 DRILL OTHR PROD
23:00 - 00:00 1.00 WAlTON OTHR PROD
2/28/2002
00:00 - 02:30
02:30 - 04:00
04:00 - 17:30
17:30 - 20:00
2.50 WAlTON SPLY PROD
1.50 DRILL
TRIP
PROD
13.50 DRILL
DRLG PROD
2.50 DRILL
PROD
CIRC
Service rig & tds.
Rih to 3114', precautionary wash - ream to t
d of 3204, no fill.
Drlg 3204 - 3583' [tvd = 3422']. Bit wt 2 -5
k Ibs, Wts up I dwn I rot 79 I 75 I 77k Ibs @
40 -45- rpm. Torque on I off bottom 1850 I
1650 ft-Ibs. ECDs 10.5 - 10.8 ppg. Preca
utionary sweeping hole each 500', sweeps br
inging up 50% additional material. ADT [24
hrs] = 13. 1 hrs: 1.3 slide + 11.8 rot. ADT t
his bit = 19.1 hrs: 1.6 slide + 17.5 rot.
Held ops I planning meeting @ 1900 hrs.
Dir Drlg 3583' md [ 3422' tvd] - 4369' md [4
186' tvd]. PP I rate = 1490 psi I 5.2 bpm.
Torque off I on bottom @ 40 rpm = 18 1 20k
ft-Ibs. Diff pump press on - off bottom = 1
70 psi. Pu I so 1 rot [40 rpms] weights = 90
182 I 88k Ibs. Bit weights 4 - 8k Ibs. Pre
cautionary sweeping hole wI 30 bbl hi vis sw
eeps [per 500'], recovering moderate increa
se in amt of material. Maintaining ecd in th
e 10.3 to 10.8 ppg range. adt last 24 hrs
= 13.5 hrs = ast 2.8 + art 10.7 adt this bit
32.6 hrs = ast 4.4 + art 28.2
Pump 1 cir 30 bbl sweep & cir till clean shak
ers.
Pooh to 2190', no over pulls.
Police floor,'ser tds & x-out tongs.
High line power down on entire location @ 2
331 hrs. Started rig generators as emergen
cy power - continued to run rig maintenance
as per opportunity. NOTE: power retund
to normal wI all x-cks made by ppco line p
ower & rig personel @ 0230hrs.
Continue to trace high line power supply int
eruption. Trace problem to 1N pad junction
box that had been snow blowned by snow re
moval equipment.
Rih 4369' [4186' tvd], precautionary wash re
am 90', no fill, good trip.
Dir Drlg 4369' md [ 4186' tvd] - 4928' md [4
784' tvd]. PP I rate = 1710 psi I 5.2 bpm.
Torque off I on bottom @ 40 rpm = 22 I 24k
ft-Ibs. Diff pump press on - off bottom = 2
60 psi. Pu 1 so I rot [40 rpms] weights = 98
190 I 95k Ibs. Bit weights 2 - 5k Ibs. Pre
cautionary sweeping hole wI 30 bbl hi vis sw
eeps [per 500'], recovering moderate increa
se in amt of material. Maintaining ecd in th
e 10.3 to 10.5 ppg range. Adt [24 hrs] =
9.8 hrs = 2.2 ast + 7.6 art. Adt this bit = 4
2.4 hrs = 6.6 ast + 35.8 art.
Cir I sweep I cond hole I evaluate Iwd tools
Printed: 4/4/2002 8:56:43 AM
/'"'- ,
.~
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
2P-451
2P-451
ROT - DRILLING
NORDIC 3 n1433@ppco.com
Nordic 3
Start: 2/14/2002
Rig Release: 3/5/2002
Rig Number: 3
Spud Date: 2/19/2002
End:
Group:
2/28/2002
17:30 - 20:00
20:00 - 23:30
23:30 - 00:00
3/1/2002
00:00 - 02:30
02:30 - 03:30
03:30 - 04:00
04:00 - 05:00
05:00 - 06:30
06:30 - 07:00
07:00 - 00:00
3/2/2002
00:00 - 13:00
13:00 - 15:00
15:00 - 17:00
17:00 - 18:00
18:00 - 20:00
20:00 - 23:00
3/3/2002
23:00 - 00:00
00:00 - 02:00
2.50 DRILL
3.50 DRILL
0.50 DRILL
2.50 DRILL
1.00 DRILL
CIRC
TRIP
TRIP
PROD
PROD
PROD
TRIP
PROD
TRIP
PROD
0.50 DRILL TRIP PROD
1.00 RIGMNT RSRV PROD
1.50 DRILL TRIP PROD
0.50 DRILL TRIP PROD
17.00 DRILL
13.00 DRILL
2.00 DRILL
2.00 DRILL
DRLG PROD
DRLG PROD
PROD
WIPR PROD
1.00 RIGMNT RSRV PROD
2.00 DRILL WIPR PROD
3.00 DRILL
1.00 DRILL
2.00 DRILL
CIRC
PROD
CIRC
TRIP
PROD
PROD
Make surface cks.
Pooh to Iwd equip.
PJSM 1 dl Iwd tools I recover radiation sour
ce lops incomplete @ rpt time.
Complete down load, pull to bit & break out
[good shape - not scratched],lay out LWD 1
PWD tools. Pu I mu bha, orient tool face.
Load source after PJSM.
Rih wI bha, rot by tam, run a stand & condu
ct shallow test on tools.
Continue in hole to above shoe @ 2190'.
Slip & cut drlg line & ser rig I tds.
Cont to rih to 4840'.
Precautionary wash I ream final 90' to td of
4928', no detectable fill, good trip in.
Dir Drlg 4928' md [ 45072' tvd] - 5455 md [5
260' tvd]. PP I rate = 1710 psi 1 5.2 bpm.
Torque off 1 on bottom @ 40 rpm = 22 I 32k
ft-Ibs. Diff pump press on - off bottom = 2
00 psi. Pu I so I rot [40 rpms] weights = 10
6 1100 1104 Ibs. Bit weights 2 - 5k Ibs. Pr
ecautionary sweeping hole wI 30 bbl hi vis s
weeps [per 500'], recovering small increase
in amt of material. Maintaining ecd in the
10.3 to 10.5 ppg range. 24 hr adt = 11.4 h
rs = ast 3.6 + art 7.8 adt this bit = 53.8hrs
, ast 10.2 = art 43.6. problems wI Hi Line
power from 1430 - 1700 hrs, camp & rig on
independent systems, no inturption in drlg a
ctivity to note.
Dir Drlg 5455 md [5260' tvd] - 5950' md { [
5755' tvd] 5? - 3? csg string td} PP I rate
= 1850 psi I 5.2 bpm. Torque off I on botto
m @ 40 rpm = 2.2 I 3.5k ft-Ibs. Diff pump p
ress on - off bottom = 250 psi. Pu 1 so I ro
t [40 rpms] weights = 112 1105 1107 Ibs. Bi
t weights 2 - 5k Ibs. Precautionary sweepin
g hole wI 30 bbl hi vis sweeps [per 500'], re
covering small increase in amt of fine mat
erial. Ecd running 10.3 to 10.5 ppg. Adt I
ast 24 hrs = 9.8 hrs = art 8.4 + last 1.4 hrs.
Adt this bit = 21.2hrs = art 16.2 + ast 5.0
Cir sweep & cir shakers clean.
Short trio to 2200'. No over pulls off bot to
m.
Rig service.
Rih to td of 5890', precationary wash I ream
to td of 5950', no fill.
Cir I cond @ [near] td, cir spot clean mud in
open hole section.
Pooh for prod csg.
Complete pooh for csg.
Printed: 4/4/2002 8:56:43 AM
~..-....
,..,......."
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
2P-451
2P-451
ROT - DRILLING
NORDIC 3 n1433@ppco.com
Nordic 3
Start: 2/14/2002
Rig Release: 3/5/2002
Rig Number: 3
Spud Date: 2/19/2002
End:
Group:
3/312002 02:00 - 04:00 2.00 DRILL TRIP PROD
04:00 - 06:00 2.00 CASE OTHR PROD
06:00 - 07:00 1.00 CASE SFTY PROD
07:00 - 08:30 1.50 CASE RUNC PROD
08:30 - 15:30 7.00 CASE RUNC PROD
15:30 - 18:00 2.50 CASE CIRC PROD
18:00 - 20:30 2.50 CEMENT PUMP PROD
20:30 - 22:30 2.00 CEMENT PULD PROD
22:30 - 23:30 1.00 CEMENT OTHR PROD
23:30 - 00:00 0.50 CMPL TN RURD PROD
3/4/2002 00:00 - 00:30 0.50 CMPL TN RURD CMPL TN
00:30 - 07:30 7.00 CMPL TN RUNT CMPLTN
07:30 - 11 :30 4.00 CMPL TN OTHR CMPL TN
11:30-12:00 0.50 CMPL TN RUNT CMPL TN
12:00 - 12:30 0.50 CMPL TN OTHR CMPL TN
12:30 - 14:30 2.00 CMPL TN CIRC CMPL TN
14:30 - 16:00 1.50 CMPL TN SOHO CMPL TN
16:00 - 20:30 4.50 CMPL TN NUND CMPL TN
20:30 - 23:00 2.50 CMPL TN FRZP CMPL TN
23:00 - 00:00 1.00 CMPL TN OTHR CMPL TN
3/5/2002 00:00 - 02:30 2.50 CMPL TN OTHR CMPL TN
PJSM, recover rad source, drain up tools &
down load Iwd tools. Ld Iwd 1 mwd equip &
b h a.
Drain up stack, pull wear bushing, Install &
test upper pipe rams 5.5" rams for csg.
Ru to run csg I PJSM.
Pu & run 3.5 section of csg to include XO to
5.5' & Baker CSR.
Continue to run 5? csg as per program.
Circ.-condition hole for cementing.
Mix & pump cement as per program-bump plu
g-floats held.
Rig down cement head-clear floor of all cem
ent equipment.
Set 11" X 5.5" packoff & test to 5000#.
Change bails & rig up to run completion.
Change out bails & rig up to run completion.
PJSM-Run completion as per program.
Gaulded threads on make up of 2 'DS' 9 chr
ome 'DS' nipples. Replace same.
Finish running completion.
Service rig.
Pump hi vis sweep & displace well with seaw
ate r.
Make up hanger & land same-test tbg. 1000#
& annulus 3000# for 30 mins.-chart same. (
shear DCK @ 3000#)
Rig down landing jt.-nipple down bope & nip
pie up tree-test same 5000#.
Freeze protect well wI 50 bbls. diesel & equ
alize same.
Establish leak off on 5.5" X 7 5/8" annulus
& freeze protect same wI 40 bbls. diesel.
Rig down circ. lines-move misc. rig support
equipment-prep rig for move while equalizin
g freeze protect-set back pressure valve. (R
elease rig @ 0230 3/5/2002) Move rig off we
II & clean location.
Printed: 41412002 8:56:43 AM
Date
03/13/02
03/24/02
03/28/02
03/29/02
03/30/02
03/31/02
/~
~
2P-451 Event History
Comment
DRIFTED TBG W/23' X 2.565"DUMMY GUN. TAGGED FILL @ 5751' RKB. SET DV @ 5302' RKB. PT TBG &
CSG. GOOD TESTS. [PT TBG-CSG, TAG, GLV]
PERFORATED INTERVAL 5562' - 5578' W/ 2.5" HSD, 2506 HJ CHGS, 6 SPF, 60 DEG PHASING. EOB
METHOD W/ 3500 PSI. WHTP PRESSURE DROPPED IMMEDIATELY TO 1000 PSI UPON SHOT. LOG
SBHP @ 5570' (MID PERFS)= 2412 PSI, AND @ 5303' (STATION #1)= 2286 PSI, [PERF]
PULLED DV & SET 1" BTM LATCH SPARTEK SPG @ 5303' RKB (3 SEC SAMPLES START @ 06:30 HRS.
03/29/02). TESTED TBG & CSG TO 3500 PSI, OK. [PRESSURE DATA]
PLACED 195,899 LBS OF 16/20 PROPPANT BEHIND PIPE. SCREENED OUT WITH 10 PPA ON PERFS.
PUMPED JOB @ 30 BPM WITH AN AVERAGE TREATING PRESSURE OF 4700 PSI. SCREENOUT
PRESSURE WAS 7270 PSI, THEN PRESSURE IMMEDIATELY DROPPED TO ZERO. BRING PUMPS BACK
ONLINE AND WERE ABLE TO PUMP DOWNHOLE, FLUSHED WITH 35 BBLS OF GEL AND SHUTDOWN.
FREEZE PROTECTED TREE WITH DIESEL.
FISHED METAL FINGER FROM 15' SLM. [FISH]
PERFORMED A REVERSE FILL CLEAN OUT TO 5744' CTMD. STARTED TO LOOSE RETURNS EACH
TIME ACHIEVING THIS DEPTH. WELL FREEZE PROTECTED TO TOP PERF 5562'. LEAVE WELL FOR
WIRELINE. [FCO]
Page 1 of 1
4/1/2002
~
~
aOé)-uo1S
Phillips Alaska, Inc.
Drill Site 2P
451
slot #451
Meltwater
North Slope, Alaska
SUR V E Y
LIS TIN G
by
Baker Hughes INTEQ
Your ref: MIID <0-5950' >
OUr ref: svy6708
License:
Date printed: 4-Mar-2002
Date created: 24-Feb-2002
Last revised: 3-Mar-2002
Field is centred on 441964.235,5869891.466,999.00000 ,N
Structure is centred on 441964.235,5869891.466,999.00000 ,N
Slot location is n70 3 8.338,w150 27 8.152
Slot Grid coordinates are N 5868844.800, E 443484.330
Slot local coordinates are 1035.15 S 1528.17 E
Projection type: alaska - Zone 4, Spheroid: Clarke - 1866
Reference North is True North
'"
,r----..
r-----..
Phillips Alaska, Inc. 8URVEY LI8nNG Page 1
Drill Site 21',451 Your ref: MND <0-5950'>
Meltwater,North 81ope, Alaska Last revised: 3-Ka:r-2002
Measured Inclin Azimuth True Vert RECTANGULAR Dogleg Vert G RID COO R D 8
Depth Deqrees Degrees Depth COO R DIN ATE 8 Deg/100ft 8ect Easting Northing
0.00 0.00 0.00 0.00 O.OON O.OOE 0.00 0.00 443484.33 5868844.80
110.00 0.00 0.00 110.00 O.OON O.OOE 0.00 0.00 443484.33 5868844.80
198.87 0.18 83.67 198.87 0.02N O.14E 0.20 -0.14 443484.47 5868844.81
291.19 0.26 256.29 291.19 0.028 0.08E 0.48 -0.07 443484.41 5868844.78
382.88 3.25 263.32 382.83 0.378 2.70W 3.26 2.71 443481.62 5868844.45
475.33 5.10 260.86 475.03 1.338 9.37W 2.01 9.40 443474.96 5868843.54
567.35 7.03 266.13 566.53 2.368 19.02W 2.18 19.00 443465.29 5868842.59
661.70 8.53 262.96 660.01 3.608 31.73W 1.65 31.60 443452.58 5868841.44
693.95 8.70 262.61 691.89 4.218 36.52W 0.55 36.39 443447.78 5868840.87
784.14 10.63 256.29 780.80 7.068 51.37W 2.44 51.48 443432.91 5868838.13
880.80 11.07 255.58 875.73 11.488 69.02W 0.48 69.67 443415.23 5868833.84
974.52 12.30 257.34 967.51 15.918 87.47W 1.37 88.64 443396.75 5868829.56
1068.46 13.97 256.29 1058.99 20.798 108.25W 1.80 109.98 443375.93 58681124.83
1164.53 15.91 254.88 1151.81 26.988 132.23W 2.05 134.75 443351.91 5868818.83
1261.46 17.93 254.88 1244.54 34.348 159.46W 2.08 162.96 443324.62 5868811.68
1356.95 19.78 255.23 1334.90 42.298 189.28W 1.94 193.81 443294.75 5868803.96
1448.49 19.78 254.88 1421. 04 50.288 219.21W 0.13 224.79 443264 :76 5868796.20
1543.93 20.83 254.18 1510.55 59.128 251.13W 1.13 257.91 443232.78 5868787.60
1640.04 20.65 254.18 1600.43 68.408 283.87W 0.19 291.94 443199.97 5868778.58
1735.16 20.57 254.53 1689.46 77 . 438 316.12W 0.15 325.41 443167.66 5868769.79
1828.69 20.48 254.54 1777.05 86.178 347. 72W 0.10 358.20 443136.00 5868761.29
1920.89 20.57 254.18 1863.40 94.898 378. 85W 0.17 390.53 443104.80 5868752.81
2015.70 20.30 253.82 1952.24 104.018 410. 67W 0.31 423.62 443072.92 5868743.93
2108.34 19.78 253.47 2039.27 112.958 441.13W 0.58 455.35 443042.39 5868735.23
2198.70 19.51 253.12 2124.37 121.688 470.23W 0.33 485.71 443013.23 5868726.72
2295.46 19.07 253.82 2215.70 130. 77S 500.87W 0.51 517.66 442982.53 5868717.86
2389.53 19.07 252.77 2304.61 139.61S 530. 31W 0.36 548.38 442953.02 5868709.25
2486.80 19.42 255.23 2396.45 148. 44S 561.12W 0.91 580.42 442922.15 5868700.66
2581.79 20.13 256.99 2485.83 156.14S 592. 32W 0.98 612.55 442890.90 5868693.19
2677.01 20.57 256.29 2575.11 163.808 624.53W 0.53 645.66 442858.63 5868685.78
2771.80 21.01 255.93 2663.73 171.878 657.19W 0.48 679.30 442825.91 5868677.95
2866.48 21.46 256.29 2751.98 180.118 690.48W 0.49 713.59 442792.56 5868669.98
2961.23 20.65 253.82 2840.41 188.878 723.37W 1.27 747.62 442759.61 5868661.47
3055.99 21.09 253.12 2928.95 198. 48S 755.73W 0.53 781.36 442727.18 5868652.11
3153.02 21.36 253.12 3019.40 208.688 789.35W 0.28 816.46 442693.49 5868642.16
3244.94 20.39 253.47 3105.28 218.098 820.72W 1.06 849.20 442662.05 5868632.99
3340.13 19.25 255.58 3194.83 226.728 851.81W 1.41 881.46 442630.90 5868624.60
3434.71 19.95 254.88 3283.93 234.818 882.49W 0.78 913.19 442600.16 5868616.74
3529.40 19.42 253.47 3373.09 243.508 913.18W 0.75 945.08 442569.41 5868608.29
3624.24 18.11 254.18 3462.88 252.018 942.47W 1.40 975.58 442540.05 5868600.01
3718.90 17.14 253.12 3553.10 260.078 969.98W 1.08 1004.22 442512.49 5868592.15
3813.63 16.26 255.23 3643.84 267.508 996.16W 1.13 1031.44 442486.26 5868584.92
3908.36 15.38 254.53 3734.98 274.248 1021. 09W 0.95 1057.26 442461.28 5868578.38
4003.09 15.38 253.82 3826.31 281. 098 1045.26W 0.20 1082.38 442437.06 5868571.71
4097.72 14.06 254.18 3917.84 287.728 1068.37W 1.40 1106.42 442413.90 5868565.26
4192.48 12.57 256.64 4010.05 293.248 1089.48W 1.68 1128.23 442392.75 5868559.90
4291.56 12.57 257.34 4106.75 298.098 1110.49W 0.15 1149.79 442371.71 5868555.21
4381.67 11.87 257.34 4194.82 302.278 1129. lOW 0.78 1168.85 442353.07 5868551.17
4476.26 10.81 259.10 4287.56 306.088 1147.30W 1.18 1187.42 442334.84 5868547.50
4571.10 9.05 257.34 4380.98 309.408 1163.32W 1.88 1203.75 442318.80 5868544.30
All data in feet unle88 otherwise stated. Calculation USes minimum curvature method.
Coordinates from slot U51 and i'VD from rotary table (254.00 Ft above mean sea level).
Bottom hole distance is 1291.23 on azimuth 255.24 degrees from wellhead.
Vertical section is from N 0.00 E 0.00 on azimuth 255.28 degrees.
Grid is alaska - Zone 4.
Grid coordinates in FEET and computed using the Clarke - 1866 spheroid
Presented by Baker Hughes INTEQ
.r---..
~
Phillips Alaska, Inc. SURWY LIS'l'ING paqe 2
Drill Site 21',451 Your ref: MIfD <0-5950'>
Keltwater,North Slope, Alaska Last revised: 3-Kar-2002
Keasured Inclin Azimuth 'l'rue Vert REC'l'ANGULAR Doqleg Vert GRID COORDS
Depth Deqrees Degrees Depth COORDINA'l'ES Deg/l00ft: Sect Easting Northing
4665.82 8.96 255.58 4474.53 312. 87S 1177.73W 0.31 1218.57 442304.37 5868540.94
4760.39 7.65 255.58 4568.11 316.27S 1190.96W 1.39 1232.23 442291.11 5868537.64
4855.05 6.77 252.42 4662.02 319.525 1202.3SW 1.02 1244.10 442279.67 5868534.48
4947.56 6.68 257.34 4753.89 322.355 1212.83W 0.63 1254.93 442269.20 5868531.73
5044.49 5.36 261.56 4850.29 324.25S 1222. 81W 1.44 1265.06 442259.21 5868529.91
5138.98 3.43 264.02 4944.49 325.19S 1229.98W 2.05 1272.24 442252.02 5868529.02
5233.61 1.76 247.50 5039.02 326.04S 1234.14W 1.92 1276.48 442247.86 5868528.20
5328.28 1.49 253.47 5133.66 326.955 1236.66W 0.34 1279.15 442245.33 5868527.31
5422.95 1.41 260.50 5228.30 327.49S 1238. 99W 0.21 1281.54 442243.00 5868526.79
5517.60 1.14 269.29 5322.92 327. 70S 1241. OSW 0.35 1283.62 442240.91 5868526.60
5612.34 1.14 264.72 5417.64 327.805 1242. 96W 0.10 1285.46 442239.02 5868526.52
5707.09 0.79 262.26 5512.38 327.975 1244.55W 0.37 1287.04 442237.44 5868526.35
5801. 92 1.14 253.47 5607.20 328. 33S 1246.1OW 0.40 1288.63 442235.88 5868526.01
5866.15 0.97 257.34 5671.42 328.635 1247.24W 0.29 1289.81 442234.74 5868525.72
5950.00 0.97 257.34 5755.25 328.945 1248. 63W 0.00 1291.23 442233.35 5868525.42
AJ.l data in feet unless otherwise stated. Calculation uses minimum curvature method.
Coordinates from slot 11451 and'l'VD from rot:ary t:&ble (254.00 li't above mean sea level) .
Bottom hole dist:ance is 1291.23 on azimuth 255.24 degrees from wellhead.
Vertical section is from N 0.00 E 0.00 on azimuth 255.28 degrees.
Grid is alaska - Zone 4.
Grid coordinates in FEE'l' and computed using the Clarke - 1866 spheroid
Presented by Balter Hughes IN'l'EQ
"
~
~
Phillips Alaska, Inc.
Drill Site 2P,451
Melt:water,North Slope, Alaska
SURVEY LISTING Page 3
Your ref: MIlD <0-5950' >
Last: revised: 3-&r-2002
Comments in wellpath
lID
TVD
Rectangular Coorda.
COIIIIII8nt:
-----------------------------------------------------------------------------------------------------------
5950.00
5755.25
328.94S
1248.63W Projected Dat:a - NO SURVEY
Casing posit:ions in suing 'A'
--~~~___~.mn__--_-------- -.
Top lID
Top TVD
Rectangular Coorda.
Bot: lID
Bot: TVD
Rectangular Coorda.
Casing
-----------------------------------------------------------------------------------------------------------
0.00
0.00
O.OON O.OOE 2236.00 2159.55 125.25S 482.11W 7 5/8 CSG
Target:s associated with this wellpath
Geographic Locat:ion T.V.D. Rectangular Coordinat:es Revised
Target: name
-----------------------------------------------------------------------------------------------------------
2P-45l MW(X) RVSD 09 442236.000,5868527.000,999.00
5379.00
327.34S
1245.99W 22-Feb-2001
-...
~
~~!Æ~E (ill! !Æ~!Æ~~~!Æ
ALAS IiA 0 IL AND GAS
CONSERVATION COMMISSION
TONY KNOWLES, GOVERNOR
/
333 W. 7'" AVENUE, SUITE 100
ANCHORAGE, ALASKA 99501-3539
PHONE (907) 279-1433
FAX (907) 276-7542
Chuck Mallary
Drilling Engineering Supervisor
Phillips Alaska, Inc.
PO Box 100360
AnchorageAK 99510-0360
Re:
Kuparuk River Unit 2P-451
Phillips Alaska, Inc.
Pennit No: 202-008
Sur. Loc. 1035' FNL, 1524' FWL, Sec. 17, T8N, R7E, UM
Btmho1e Loc. 1362' FNL, 277' FWL, Sec. 17. T8N, R7E, UM
Dear Mr. Johnson:
Enclosed is the approved application for pennit to drill the above referenced well.
The pennit to drill does not exempt you from obtaining additional pennits required by law from other
governmental agencies, and does not authorize conducting drilling operations until all other required
pennitting determinations are made.
Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to
ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be
contingent on obtaining a well cemented surface casing confinned by a valid Fonnation Integrity Test
(FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission for approval on
fonn 10-403 prior to the start of disposal operations.
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 Kuparuk River Unit 2P
must comply with the requirements and limitations of20 AAC 25.080. Approval of this pennit to drill
does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular
space of a single well or to use that well for disposal purposes for a period longer than one year.
The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the
mechanical integrity (M!) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC
25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the
BOPE test perfonned before drilling below the surface casing shoe, must be given so that a representative
of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum
field inspector on the North Slope pager at 659-3607.
Sincerely,
ÚA~-~U
c~echsli Tay1~r lJ -~ .
Chair
BY ORDER OF THE COMMISSION
DATED this 31st day of January, 2002
cc:
Department ofFish & Game, Habitat Section wlo encl.
Department of Environmental Conservation wlo encl.
,-...
/"""\
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
20 AAC 25.005
1b. Type of well. Exploratory U Stratigraphic Test U
Service [2] Development Gas D Single Zone [2]
5. Datum elevation (DF or KB)
RKB = 254 feet AMSL
;JJ;(6~a~~~ 4998 .ðÒ
7. Unit or property Name
Kuparuk River Unit
8. Well number
2P-451
Drill l;d Redrill U
DDeepen D
1a. Type of work:
Re-entry
2. Name of Operator
Phillips Alaska, Inc.
3. Address
P.O. Box 100360 Anchorage, AK 99510-0360
4. Location of well at surface
1035' FNL, 1524' FWL, Sec. 17, T8N, R7E, UM
At top of productive interval
1362' FNL, 277' FWL, Sec. 17, T8N, R7E, UM
At total depth
1362' FNL, 277' FWL, Sec. 17, T8N, R7E, UM
12. Distance to nearest property line I 13. Distance to nearest well
1362'@TD feet 2P-448A59.1'@312.5'
16. To be completed for deviated wells
Kickoff depth: 300 MD
18. Casing program
size
Maximum hole angle
Hole Casing Weight
42' 16' 62.5#
9.625' 7.625' 29.7#
6.75' 5.5' 15.5#
6.75' 3.5" 9.3#
Specifications
Grade Coupling
H-40 Weld
L-80 BTCM
L-80 BTCM
L-80 EUE8rd
Length
80'
2201'
5200'
695'
19. To be completed for Redrill. Re-entry, and Deepen Operations.
Present well condition summary
Total Depth:
feet
feet
measured
true vertical
Effective Depth:
feet
feet
measured
true vertical
Casing
Conductor
Surface
0
Size
Cemented
Length
Perforation depth:
measured
true vertical
9. Approximate spud date
January 29, 2002
14. Number of acres in property
~ fÇS3
17. Anticipated pressure (see 20 MC 25.035 (e)(2»)
Maximum surface 1900 psig At total depth (TVD) 2635 psig
Setting Depth
feet
20
A\,~,-()')
àM H )/;¡)/I/Þ-
Development Oil U
Multiple Zone D
10. Field and Pool
Kuparuk River Field
Meltwater Oil Pool
11. Type Bond (see 20 MC 25.0251)
Statewide
Number
#59-52-180
Amount
$200,000
15. Proposed depth (MD and TVD)
5925 ' MD I 5729 ' 1VD
Top Bottom Quantity of Cement
MD TVD MD TVD (include stage data)
30' 30' 110' 110' 9 cu yds High Early
30' 30' 2231' 2155' 370 sx AS III L & 120 sx LiteCRETE
30' 30' 5230' 5034' 250 sx Class G
5230' 5034' 5925' 5729' see above
Plugs (measured)
Junk (measured)
Measured depth
True Vertical depth
RECEIVED
JAN 1 5 2002
Alaska Oil & Gas Cons. Commission
Anchorage
20. Attachments Filing fee [2] Property Plat D BOP Sketch [2] Diverter Sketch [2] Drilling program [2]
Drilling fluid program [2]Time vs depth plot [Fefraction analysis DSeabed report D 20 AAC 25.050 requirements [2]
21. I hereby certify that the ;¡egoing is true and ect to the best of my knowledge Questions? Call Pat Reilly 3!2.-6048
Signed C. L Title: DrillingEngineeringSupervisor Date ILl .;:jail Ô-¡,
Chuck Mallary PrAnRrArf hv ShRmn AlIslln-nrRkA
Commission Use Only
permitNu~.2~2 -coca I AP~;- iD3-2Ö'I'ðz.-~1 Approvaldate I ~)Io:)-
Conditions of approval Samples required l Ves ~ No Mud log required
Hydrogen sulfide measures DYes B No Directional survey required
Required working pressure for BOPE D2M; D 3M; D 5M; D 10M; D
Other:Te~+- ~O,)& -\-0 3000 f w. ~ýÆ
Approved by
Original Signed By
Cammy Oechsli
Form 10-401 Rev. 12/1/85.
~ Yes
D
Commissioner
by order of
the commission
ORIGINAL
Jsee cover letter
for other requirements
,-:ves ~NO
D No,,¿t
Date
1/31 /0-'
Submit in triplicate
j"-.....
~ation for Permit to Drill, Well 2P-451
Saved: 15-Jan-02
Permit It - Meltwater 2p. 451
Application for Permit to Drill Document
Mo)ximizE
W~II V(1II,1~
Table of Contents
1. Well Name .................................................................................................................3
Requirements of 20 AAC 25.005 (f)........................................................................................................ 3
2. Location Summary ................................................................................................... 3
Requirements of 20 AAC 25.005(c)(2) ................................................................................................... 3
Requirements of 20 AAC 25. 050(b)........................................................................................................ 3
3. Blowout Prevention Equipment Information ......................................................... 4
Requirements of 20 AAC 25.005(c)(3) ................................................................................................... 4
4. Drilling Hazards Information ................................................................................... 4
Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 4
5. Procedure for Conducting Formation Integrity Tests ........................................... 4
Requirements of 20 AAC 25.005 (c)(5) ..........................................................,..............."..,................,.. 4
6. Casing and Cementing .Program............................................................................ 4
Requirements of 20 AAC 25. 005(c)(6) ................ ........................ .......................................... ................. 4
7. Diverter System Information ................................................................................... 5
Requirements of 20 AAC 25.005(c)(7) .......................................................,........................................... 5
8. Drilling Fluid Program ............................................................................................. 5
Requirements of 20 MC 25. 005(c) (B) ................................................................................................... 5
9. Abnormally Pressured Formation Information ...................................................... 6
Requirements of 20 AAC 25.005 (c)(9) ..................................................................................................6
10. Seismic Analysis ...................................................................................................... 6
Requirements of 20 MC 25.005 (c)(10) ................................................................................................ 6
11. Seabed Condition Analysis ..................................................................................... 6
Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 6
12. Evidence of Bonding ............................................................................................... 6
Requirements of 20 MC 25.005 (c)(12) ................................................................................................ 6
ORIGINAL
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13. Proposed Drilling Program .....................................................................................6
Requirements of 20 AAC 25.005 (c)(13) .........................................,...................................................... 6
14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 7
Requirements of 20 AAC 25.005 (c)(14) ..................."...........................................................................7
15. Attachments .............................................................................................................7
Attachment 1 ADGCC Form 10-401 (Front of permit package) ..............................................,.........".. 7
Attachment 2 Directional Plan.............................................................. ................................................. 7
Attachment 3 Drilling Hazards Summary............................................................................................... 7
Attachment 4 Well Schematic... ........,.. ....,.... ............................................... """"""""""""""""""""" 7
Attachment 5 Cement Details............................................ ....... ............................................................. 7
0 Q I ~ I ^/~ L
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A~ation for Permit to Drill, Well 2P-451
Saved: 15-Jan-02
1. Well Name
Requirements of 20 AAC 25.005 (f)
Each well must be identified by a unique name designated by the operator and a unique API number assžqned by the commission
under 20 MC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API
number by adding a suffix to the name de!>ignated for the well by the operator and to the number assigned to the well by the
commission.
The well for which this Application is submitted will be designated as 2P-451.
2. Location Summary
Requirements of 20 AAC 25.005(c)(2)
An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the
commission and identified in the application:
(2) a plat identifying the property and the property's owners and showing
(A)the coordinates of the proposed location of the well at the surfac~ at the top of each objective formation, and at total deptl"
referenced to governmental section lines.
(B) the coordinates of the proposed iocation of the well at the surface, referenced to the state plane coordinate system for this
state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration'
(C) the proposed depth of the well at the top of each objeäive formation and at total depth,'
Location at Surface
NGS Coordinates
Northings: 5868844.80
1036' FNL, 1524' FWL, See 17, T8N, R7E, UM
I RKB Elevation: 254.0 ft AMSL
Eastings: 443484.33 Pad Elevation: 224.0 ft AMSL
Location at Top of
Productive Interval
(Bermuda Formation)
NGS Coordinates
Northings: 5868527.00
1362' FNL, 277' FWL, Sec 17, T8N, R7E, UM
Eastings: 442236.02
Measured Depth (RKB feet):
True Vertical Depth (55 feet):
True Vertical Depth (RKB feet):
5540'
5090'
5344'
Location at Total Depth
NGS Coordinates
Northings: 5868526.99 Eastings: 442235.97
1362' FNL, 277' FWL, See 17, T8N, R7E, UM
Measured Depth (RKB feet): 5925'
True Vertical Depth (55 feet): 5475'
True Vertical Depth (RKB feet): 5729'
and
(D) other ¡i¡fo/mation required by 20 AAC 25.0S0(b);
Requirements of 20 AAC 25.050(b)
If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) must
(1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200
feet of any portion of the proposed well;
Please see Attachment 2: Directional Plan
and
(2) for all wells within 200 feet of the proposed wellbore
(A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records,
and show that each named operator has been furnished a copy of the application by certified mai~' or
(B) state that the applicant is the only affected owner.
The Applicant is the only affected owner.
OR/~/^'ß t
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3. Blowout Prevention Equipment Information
Requirements of 20 AAC 25.005(c)(3)
An application for a Permit to Drill must be accompanied by each of the following Item~ except for an Item already on file with the
commission and identified in the application:
(3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20
AAC 25.037, as applicable,'
Please refer to Nordic Rig 3 BOP Schematic currently on file with the Commission.
4. Drilling Hazards Information
Requirements of 20 AAC 25.005 (c)(4)
An application for a PermIt to Drill must be accompanied by each of the following item~ except for an item already on file with the
commission and identified in the application:
(4) information on drilling hazard~ including
(A) the maximum downhole pressure that may be encountere~ criteria used to determine it and maximum potential surface
pressure based on a methane gradient.:
The expected reservoir pressures in the Bermuda sands in the 2P pad area vary from 0.44 to 0.46 psijft,
or 8.5 to 8.9 ppg EMW (equivalent mud weight). These are pressures obtained from drilling and testing
operations on the nearby exploration wells, Meltwater North #1 and Meltwater North #2/2A.
The maximum potential surface pressure (MPSP) based on the the above maximum pressure gradient, a
methane gradient (0.11) and the vertical depth of the expected base of the Bermuda formation is:
MPSP =(5429 ft)(0.46 - 0.11 psi/ft)
=1900 psi
Assuming a leak off of 16.0 ppg (0.83 psi/ft) based on open hole LOT results from offset well Meltwater
2P-448, formation breakdown at the surface casing shoe (2155' TVD) can be expected to occur at 1793
psi. Therefore, the MPSP may be based on the maximum pressure gradient as calculated above.
(B) data on potential gas zone~'
The CAIRN interval is expected from 5330' MD to 5431' MD (5134' TVD to 5235' TVD).
and
(C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zone~ and zones
that have a propensity for differential sticking;
Please see Attachment 3: Drilling Hazards Summary.
5. Procedure for Conducting Formation Integrity Tests
Requirements of 20 AAC 25.005 (c)(5)
An application for a Permit to Drill must be accompanied by each of the followlÌ7g Item~ except for an item already on file with the
commission and identified in the application:
(5) a description of the procedure for conducting formation integrity test~ as required under 20 AAC 25. O30(f);
A formation integrity test will be performed after drilling out below surface in accordance with the Phillips
Alaska LOT / FIT procedure, currently on file with the Commission.
6. Casing and Cementing Program
Requirements of 20 AAC 25.005(c)(6)
An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file wIth the
commission and Identified in the application:
(6) a complete proposed casing and cementing program as required by 20 MC 25. 030, and a description of any slotted liner, pre-
perforated liner, or screen to be installed;
ORIGINAL
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Casing and Cementing Program
Hole Top 8tm
Csg/Tbg Size Weight Length MDITVD MDITVD
00 (in) (in) (Ib/ft) Grade Connection (ft) (ft) (ft) Cement Program
30 X 16 42 62.5 H-40 Welded 80 30 / 30 110 / 110 9 cy High
Insulated Early
7-5/8 9-7/8 29.7 L-80 BTC,AB 2201 30/ 30 2231 / 2155 370 sx 10.7
Modified ppg AS3 Lead,
120 sx 12.0
ppg LiteCrete
Tail
Planned Top of
Cement:
Surface
51/2 6-3/4 15.5 L-80 BTC,AB 5200 30/ 30 5230 / 5034 250 sx 15.8
Modified ppg Class 'G'
3-1/2 6-3/4 9.3 L-80 EUE, 8rd 695 5230 / 5034 5925 / 5729 Planned Top of
Mod Cement:
4730' MD
7. Diverter System Information
Requirements of 20 AAC 25.005(c)(7)
An application for a Permit to Drill must be accompanied by each of the following item~ except for an Item already on file with the
commission and identified in the application:
(7) a diagram and description of the diverter system as required by 20 MC 25. 03~ unless this requirement is waived by the
commission under 20 MC 25.035(h)(2);
Please refer Nordic Rig 3 Oiverter Schematic currently on file with the Commission.
8. Drilling Fluid Program
Requirements of 20 AAC 25.005(c)(8)
An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the
commission and identitied in the application:
(8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 MC 25.033;
Water based drilling fluid systems will be utilized to drill this well from spud to TO. These systems will be
built and maintained to the following specifications:
Spud to 9-5/8" Drill Out to Top Bermuda
Sutface Casing Top Bermuda To Well TD
Initial Value Final Value Initial Value Final Value Initial Value Final Value
Density (ppg) 9.6 9.6 9.6 9.6 9.6 9.6
Funnel Viscosity 50 80 50 65 50 65
(seconds)
Yield Point 35 45 15-20 18-25 20 30
(cP)
Plastic Viscostiy 13 23 8-18 10-18 6 14
(1M 00 sf)
10 second Gel 10 15 3-6 4-9 4 7
Strength (lb/100 sf)
10 minute Gel 15 40 4 8 4 8
Strength (lb/100 sf)
pH 9.5-10 9.5-10 9.0-9.5 9.0-9.5 7.5-8.5 7.5-8.5
API Fiftrate(cc) <15 <6 <6 <6 8-10 8-10
nR/r, !~r~ ,
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Please refer to Nordic Rig 3 Fluid System Components currently on file with the Commission.
9. Abnormally Pressured Formation Information
Requirements of 20 AAC 25.005 (c)(9)
An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the
commission and identified in the application:
(9) for an exploratory or strat(qraphic test we/~ a tabulation setting out tlie depths of predicted abnormally goo-pressured strata as
required by 20 MC 25.033(0/
Not applicable: Application is not for an exploratory or stratigraphic test well.
10. Seismic Analysis
Requirements of 20 AAC 25.005 (c)(10)
An application for a Permit to Drill must be accompanied by each of the following Items, except for an item already on file with the
commission and identified in the application:
(10) for an exploratory or stratigraphic test wel¿ a seismic refraction or ret1ection analysis as required by 20 MC 25.061(a)/
Not applicable: Application is not for an exploratory or stratigraphic test well.
11. Seabed Condition Analysis
Requirements of 20 AAC 25.005 (c)(11)
An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the
commission and identified in the application:
(11) for a well drilled from an offshore platform, mobile bottom-founded structUl~ jack-up fig, or lioating drilling vesse~ an analysis
of seabed condttions as required by 20 MC 25.061(b)/
Not applicable: Application is not for an offshore well.
12. Evidence of Bonding
Requirements of 20 AAC 25.005 (c)(12)
An application for a Pem7it to Drill must be accompanied by each of the following items, except for an Item already on file with the
commis..'"iion and identified in tIle application:
(12) evidence showing that the requirements of 20 MC 25.025 {Bondtng}have been met.
Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission.
13. Proposed Drilling Program
Requirements of 20 AAC 25.005 (c)(13)
An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file witll the
commission and identified in the applicàtion:
The proposed drilling program is listed below. Please refer as well to Attachment 4: Well
Schematic:
1. Excavate cellar, install cellar box, set and cement 16" x 30" insulated conductor to +/- 110' RKB.
Weld landing rin~nductor. /
~: ~: ~:~ :::~CJd~;1I :n::~, ~~:: 7~:I:~~:a:~:::'POint (+1- 2231 MD') according to
directional plan. Run MWD I LWD logging tools in drill string for directional monitoring and formation
data gathering. {J;e/ 'òIRê~77ðÂÎRL .,¿Þ
4. Run and cement 7-5/8" 29.7# L-80 BTCM casing to surface using ArcticSet 3 lead slurry and
LiteCrete tail to assure cement returns to the surface. Adequate tail cement will be pumped to
ensure cement reaches the surface. Displace cement with mud.
5. Nipple down diverter and install wellhead. Nipple up BOPE and test to 3000 psi. Record results.
6. Shut in BOP's and pressure test casing to 2500 psi for 30 minutes. Record results.
ORIGINAL
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7. Drill out cemenÿmd 20' minimum to 50' maximum of new hole. Perform formation integrity test not
to exceed 16.0 ppg EMW.
8. Directionally drill 6 3/4" hole to well total depth (+/- 5925' MD) according to directional plan. Run
MWD / LWD logging tools in drill string for directional rn9.nitoring and formation data gathering.
Circulate and condition hole. POOH,I/1 ¡J>:Ø'A?/,;ee5tS/~//VELL rllso m~~'Í ~.
~ <!A:$l~:5ÑÞ.L ..b T..Z:>, ¿ ~P'7 ~ ¿M ~/'h/~
9. Run open hole e-line or drill pipe conveyed logs as n eded. If ..till! t4.- ~ ~..I;~~..J. ~
10. Run and cement 5 112" 15.5# L-80 BTCM x 3 112" 9.3# L-80 8 RND tapered production casing string
with Baker casing seal receptacle crossover (CSR). Place CSR +/- 100' above the planned top
perforation.
11. Run and land 3 V2" tubing. Displace well to completion brine.
12. Pull landing joint. Install BPV. Nipple down BOP stack, and nipple up production tree. Pull BPV.
Install test plug. Pressure test production tree. Pull test plug. Secure well.
13. Freeze protect well. Set BPV. Release rig and turn well over to production.
14. Clean location and RDMO.
14. Discussion of Mud and Cuttings Disposal and Annular Disposal
Requirements of 20 AAC 25.005 (c)(14)
An application for a Permit to Drill mustc be accompanied by each of the following itemSr except for an item already on file with the
commission and identified in the application:
(14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the
operator intends to request authorization under 20 MC 25.080 for an annular disposal operation in the well;
Waste fluids generated during the drilling process will be disposed of down a permitted annulus on 2P
pad or hauled to a Class II disposal well. All cuttings to be disposed of will be either disposed of down
the annulus or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for
disposal down an approved disposal well.
At the end of drilling operations, a request will be submitted for this well to be permitted for annular
pumping of fluids occurring as a result of future drilling operations on 2P pad.
15. Attachments
Attachment 1 AOGCC Form 10-401 (Front of permit package)
Attachment 2 Directional Plan
Attachment 3 Drilling Hazards Summary
Attachment 4 Well Schematic
Attachment 5 Cement Details
ORIGINAL
2P-451 PERMIT IT 011402.doc
Page 7 of 7
Printed: 15-Jan-O2
,r-,
,?'--.
....,-.-.-----....-,
Alaska,
Inc.
C"oled by bmichoel For: P Reilly
Dole ploUed , I1-Jon-2002
Plot Refe"nce is 2P-451 V""ion #2,
Co"dinole, "e in feel "fe,ence "ot #451.
Verticol Depth' "e "f«ence ,,'ory
350 -
700 -
1050 -
1400 -
1750-
.--..
+-
Q)
Q) 2100-
4-
------
.r:::
+- 2450 -
Q.
Q)
0
0 2800-
()
:;:
L
Q) 3150-
>
Q)
::J 3500-
L
I-
I
V 3850-
4200 -
4550 -
4900 -
5250 -
5600 ..
5950
rucfure : Drill Site 2P
Well: 451
Locotion : North Slope, Alaska!
Field: Meltwater
_\!!
IW<m
-
~
0 -
I Estimated RKB Eìev:254'
255.28 AZIMUTH
1288' (TO TARGET)
KOP
* 2,00
" 4,00
" 6,00
8.00
Begin Bld/Trn
11.97
13.96
15,94 OLS: 2.00 de9 per 100 It
17.93
19.92 EOC
Base Permafrost
...Plane of Proposol...
DLS: 2,00 deg per 100 It
Bose West Sak /
~ \. 7 5/8 CSG
C80
TANGENT ANGLE
20 DEG
C50
C40
~~\3 Begin Drop
18.53
17,53 DLS: 1.00 deg per 100 It
16.53
15,53
14,53
13.53
12,53
11.53
10,53
9,53
8.53
7,53
6.53
5,53
4,53
5 1/2 X 3 1/2 Crossover 11 3.53
11 2.5314.1 (Top Cairn)
; ).5313.1 (Base Cairn)
EOD " 10.53 13 (Top Bermuda)
Target ----I--
* T2 (Base Bermuda)
C35 (Top Aìbian)
J,.L TD - Csg pt
0
350
3150
3500
700
1050
1400
1750
2100
2450
2800
Vertical Section (feet) ->
Azimuth 255.28 with reference 0.00 N, 0.00 E from slot #451
ORIGINAL
r~I'lIDC"
, r-n L .-.;t r
<:::>
::0
---
(;'")
---
~
r--
C'eo!ed by bmlehael For: P Reilly
Date platted: 11-Jan-2002
Pia! Refe,enee Is 2P-451 Ve"lan #2.
Cao,dlno!es o'e In fee! ,efe'enee slat #451.
Ve,tleal Depths o'e 'efe'enee ,a!aoy
..
....
INTF.Q
I TO LOCATION: I
1362' FNL, 277' FWL
SEC, 17, T8N, R7E
I TARGET LOCATION: I
1362' FNL, 277' FWL
SEC. 17, T8N, R7E
U'
I TOP BERMUDA I
LOCATION:
1362' FNL, 277' FWL
SEC. 17, T8N, R7E
~
..-\ '";::i
..-\ '-"..-\ ""-
::, ~~-;'-"
o¡;.<g ~~'~~
U'~ cP~,,--,'";::i
..-\~ cP '!; @ 0 0
CJ ~ '!;..-\ 1 0 -Co Ò
\ ~12,'ô'6~' ~,'iß
~%. '6,~CJJ~2.,i,
~ ." - -------- ~
-cc./
,.
1320
1260
1200
1140
1080
1020
960
900
Phillip s
Alaska,
Inc.
Structure: Drill Site 2P
Fieid : Meltwafer
Well: 451
Location: North Slope, Alaska
255.28 AZIMUTH
1288' (TO TARGET)
...Piane at Proposal'"
,
TRUE
840
780
720
540
480
660
600
<- West (feet)
U'
(¡;
0
If>
C'>
If>
'}
420
30D
240
360
I';HI~LlP~
cP
'"
"%,.
g1
0-
'::i
?
I ESTIMATED SURFACE
LOCATION:
1036' FNL, 1524' FWL
SEC. 17, T8N, R7E
180
120
6D
I ,',:
0
480
60
')
- 120
- 60
- 0
(/)
0
C
-+-
:r
- 180
.--..
-.
CD
CD
-+-
'--"
)
- 240
I
V
- 300
- 360
- 420
Philli p s Alaska, Inc.
Created by bmichoel For: P Reilly Strucfure : Drill Site 2P Well: 451
Dote plotted: 11-Jon-2002
Plot Reference is 2P-451 Version #2, Field: Melfwafer Locatian : North Slope, Alaska
Coordinates are in feet reference slot #451. .
Vertical Depths are reference rotary
.-
8f&\rs
INTRQ
~~~~ PROF~LE COMMENT DATA ~~~~
----- Point ----- MD Inc Dir TVD North East V. Sect Deg/100 )
KOP 300.00 0.00 260.00 300.00 0.00 0.00 0.00 0.00
Begin Bld/Trn 800.00 10.00 260.00 797.47 -7.56 -42.86 43.37 2.00
<::) EOC 1303.81 20.00 254.94 1283.51 -37.62 -169.46 173.46 2.00
::0 Base Permafrost 1378.82 20.00 254.94 1354.00 -44.29 -194.24 199.12 0.00
--- Base West Sak 2017.33 20.00 254.94 1954.00 -1 01 .04 -405.12 417.49 0.00
~ 7 5/8 CSG 2231 .26 20.00 254.94 2155.03 -120.05 -475.77 490.66 0.00
---
~ C80 2331 .26 20.00 254.94 2249.00 -128.94 -508.80 524.86 0.00
C50 3102.79 20.00 254.94 2974.00 -197.52 - 763.61 788.74 0.00
r-- C40 3390.12 20.00 254.94 3244.00 -223.06 -858.51 887.01 0.00
C37 3544.43 20.00 254.94 3389.00 -236.77 -909.47 939.78 0.00
Begin Drop 3553.07 20.00 254.94 3397.13 -237.54 -912.33 942.74 0.00
5 1/2 X 3 1/2 Crosso 5230.26 3.23 254.94 5034.11 -324.97 -1237.21 1279.18 1.00, )
T4.1 (Top Cairn) 5330.26 2.23 254.94 5134.00 -326.21 -1241.81 1283.94 1.00
13.1 (Base Cairn) 5431.31 1.22 254.94 5235.00 -327.00 -1244.74 1286.98 1.00
13 (Top Bermuda) 5540.32 0.13 254.94 5344.00 -327.33 -1245.98 1288.26 1.00
EOD 5552.58 0.00 254.94 5356.26 -327.33 -1245.99 1288.27 1.00
Target 5575.30 0.00 254.94 5378.98 -327.34 -1245.99 1288.27 0.00
2P-451 MW(X) RVSO 09 5575.32 0.00 254.94 5379.00 -327.34 -1245.99 1288.27 0.00
T2 (Base Bermuda) 5625.32 0.00 254.94 5429.00 -327.34 -1246.00 1288.28 0.00
C35 (Top Albian) 5770.32 0.00 254.94 5574.00 -327.34 -1246.01 1288.29 0.00
~'-"'.
Phillips Alaska, Inc.
Drill Site 2P
451
slot #451
Meltwater
North Slope, Alaska
PROPOSAL LISTING
by
Baker Hughes INTEQ
Your ref: 2P-451 version *2
Our ref: prop4474
License:
Date printed: ll-Jan-2002
Date created: 22-Feb-2001
Last revised: ll-Jan-2002
Field is centred on 441964.235,5869891. 466,999.00000, N
Structure is centred on 441964.235,5869891. 466,999.00000, N
Slot location is n70 3 8.338, w150 27 8.152
Slot Grid coordinates are N 5868844.800, E 443484.330
Slot local coordinates are 1035.15 S 1528.17 E
Projection type: alaska - Zone 4, Spheroid: Clarke - 1866
Reference North is True North
ORIGINAL
..-"
/"'-.
,~
Phillips Alaska, Inc, PROPO5AL LI5TING Page 1
Drill 5ite 2P,451 Your ref : 2P-451 Version #2
Meltwater,North 51ope, Alaska Last revised: ll-Jan-2002
Measured Inclin Azimuth True Vert R E C TANGULAR G RID COORD5 G E 0 G RAPHIC
Depth Degrees Degrees Depth COO RDINATE5 Easting Northing COO R DINATES
0.00 0.00 260.00 0.00 - O.OON O.OOE 443484.33 5868844.80 n70 3 08.34 w150 27 08.15
300.00 0,00 260,00 300.00 O.OON O.OOE 443484.33 5868844.80 n70 3 08.34 w150 27 08.15
400.00 2.00 260.00 399.98 0.30S 1. 72W 443482.61 5868844.51 n70 3 08.34 w150 27 08.20
500.00 4.00 260.00 499.84 1.215 6.87W 443477.45 5868843.64 n70 3 08.33 w150 27 08.35
600.00 6.00 260.00 599.45 2. 73S 15.46W 443468.86 5868842.19 n70 3 08.31 w150 27 08.60
700.00 8.00 260.00 698.70 4.845 27.46W 443456.84 5868840.17 n70 3 08.29 w150 27 08.94
800.00 10.00 260.00 797.47 7.565 42. 86W 443441.42 5868837.57 n70 3 08.26 w150 27 09.39
900.00 11.97 258.34 895.63 1l.16S 61. 57W 443422.68 5868834.11 n70 3 08.23 w150 27 09.93
1000.00 13.96 257.14 993.07 15. 94S 83. 49W 443400.73 5868829.49 n70 3 08.18 w150 27 10.56
1100.00 15.94 256.24 1089.68 21.90S 108. 59W 443375.58 5868823.73 n70 3 08.12 w150 27 11.28
1200.00 17.93 255.53 1185.34 29. 01S 136.84W 443347.28 5868816.83 n70 3 08.05 w150 27 12.09
1300.00 19.92 254.96 1279.93 37.28S 168.21W 443315.86 5868808.80 n70 3 07.97 w150 27 13.00
1303.81 20.00 254.94 1283.51 37.625 169. 46W 443314.60 5868808.48 n70 3 07.97 w150 27 13.03
1378.82 20.00 254.94 1354.00 44.29S 194. 24W 443289.78 5868802.00 n70 3 07.90 w150 27 13.75
1500.00 20.00 254.94 1467.87 55.06S 234.26W 443249.68 5868791.53 n70 3 07.80 w150 27 14.90
2000.00 20.00 254.94 1937.71 99. 50S 399.39W 443084.23 5868748.36 n70 3 07.36 w150 27 19.66
2017.33 20.00 254.94 1954.00 101. 04S 405.12W 443078.49 5868746.86 n70 3 07.34 w150 27 19.82
2231.26 20.00 254.94 2155.03 120,055 475.77W 443007.70 5868728.39 n70 3 07.16 w150 27 21. 86
2331.26 20.00 254.94 2249.00 128.945 508.80W 442974.61 5868719.75 n70 3 07.07 w150 27 22.81
2500.00 20.00 254.94 2407.56 143. 94S 564. 53W 442918.78 5868705.18 n70 3 06.92 w150 27 24.41
3000.00 20.00 254.94 2877.41 188.38S 729.66W 442753.32 5868662.00 n70 3 06.49 w150 27 29.17
3102.79 20.00 254.94 2974.00 197. 52S 763. 61W 442719.31 5868653.13 n70 3 06.40 w150 27 30.15
3390.12 20.00 254.94 3244.00 223. 06S 858.51W 442624.23 5868628.31 n70 3 06.15 w150 27 32.88
3500.00 20.00 254.94 3347.25 232.82S 894.80W 442587.87 5868618.83 n70 3 06.05 w150 27 33.93
3544.43 20.00 254.94 3389.00 236.77S 909.47W 442573.17 5868614.99 n70 3 06.01 w150 27 34.35
3553.07 20.00 254.94 3397.13 237.545 912.33W 442570.31 5868614 .24 n70 3 06.00 w150 27 34.43
3600.00 19.53 254.94 3441.29 241. 665 927. 65W 442554.96 5868610.24 n70 3 05.96 w150 27 34.87
3700.00 18.53 254.94 3535.82 250.14S 959.14W 442523.41 5868602.00 n70 3 05.88 w150 27 35.78
3800.00 17.53 254.94 3630.91 258.185 989. 03W 442493.46 5868594.19 n70 3 05.80 w150 27 36.64
3900.00 16.53 254.94 3726.52 265.795 1017.31W 442465.13 5868586.79 n70 3 05.73 w150 27 37.46
4000.00 15.53 254.94 3822.63 272.97S 1043.97W 442438.41 5868579.82 n70 3 05.65 w150 27 38.22
4100.00 14.53 254.94 3919.21 279.715 1069.02W 442413.32 5868573.27 n70 3 05.59 w150 27 38.95
4200.00 13 .53 254.94 4016.23 286.015 1092. 43W 442389.86 5868567.15 n70 3 05.53 w150 27 39.62
4300.00 12.53 254.94 4113.65 291. 87S 1114. 20W 442368.05 5868561.46 n70 3 05.47 w150 27 40.25
4400.00 11.53 254.94 4211.45 297.28S 1134.33W 442347.88 5868556.20 n70 3 05.42 w150 27 40.83
4500.00 10.53 254.94 4309.60 302.265 1152. 80W 442329.37 5868551.37 n70 3 05.37 w150 27 41.36
4600.00 9.53 254.94 4408.07 306.785 1169. 62W 442312.52 5868546.97 n70 3 05.32 w150 27 41.84
4700.00 8.53 254.94 4506.83 310.865 1184.78W 442297 .33 5868543.01 n70 3 05.28 w150 27 42.28
4800.00 7.53 254.94 4605.85 314.495 1198.27W 442283.82 5868539.48 n70 3 05.25 w150 27 42.67
4900.00 6.53 254.94 4705.10 317.675 1210.09W 442271.97 5868536.39 n70 3 05.22 w150 27 43.01
5000.00 5.53 254.94 4804.54 320.405 1220.23W 442261.81 5868533.74 n70 3 05.19 w150 27 43.30
5100.00 4.53 254.94 4904.16 322.685 1228. 70W 442253.32 5868531. 52 n70 3 05.17 w150 27 43.55
5200.00 3.53 254.94 5003.91 324.51S 1235.49W 442246.52 5868529.75 n70 3 05.15 w150 27 43.74
5230.26 3.23 254.94 5034.11 324.97S 1237.21W 442244.80 5868529.30 n70 3 05.14 w150 27 43.79
5300.00 2.53 254.94 5103.77 325.88S 1240. 59W 442241.41 5868528.41 n70 3 05.13 w150 27 43.89
5330.26 2.23 254.94 5134.00 326. 21S 1241.81W 442240.19 5868528.09 n70 3 05.13 w150 27 43.92
5400.00 1.53 254.94 5203.70 326.805 1244. 02W 442237.98 5868527.52 n70 3 05.13 w150 27 43.99
5431.31 1.22 254.94 5235.00 327.005 1244. 74W 442237.25 5868527.33 n70 3 05.12 w150 27 44.01 ~~b
5500.00 0.53 254.94 5303.68 327.275 1245. 75W 442236.24 5868527.06 n70 3 05.12 w150 27 44.04 "t~~
5540.32 0.13 254.94 5344.00 327. 33S 1245.98W 442236.02 5868527.00 n70 3 05.12 w150 27 44.04
All data in feet unless otherwise stated. Calculation uses minimum curvature method.
Coordinates from slot #451 and TVD from rotary table 1254.00 Ft above mean sea level).
Bottom hole distance is 1288.30 on azimuth 255.28 degrees from wellhead.
Total Dogleg for wellpath is 40.07 degrees.
Vertical section is from N 0.00 E 0.00 on azimuth 255.28 degrees.
Grid is alaska - Zone 4.
Grid coordinates in FEET and computed using the Clarke - 1866 spheroid
Presented by Baker Hughes INTEQ
ORIGINAL
,1'"""--,
---\
Phillips Alaska, Inc. PROPOSAL LISTING Page 2
Drill Site 2P,45l Your ref : 2P-45l version #2
Meltwater,North Slope, Alaska Last revised : ll-Jan-2002
Measured Inclin Azimuth True Vert RECTANGU L A R G RID COORDS G EO GRAPHIC
Depth Degrees Degrees Depth COORDINA T E S Easting Northing COO RDINATES
5552.58 0.00 254.94 5356.26 327.33S 1245. 99W 442236.00 5868527.00 n70 3 05.12 w150 27 44.04
5575.30 0.00 254.94 5378.98 327.34S 1245. 99W 442236.00 5868527.00 n70 3 05.12 w150 27 44.04
5575.32 0.00 254.94 5379.00 327.34S 1245. 99W 442236.00 5868527.00 n70 3 05.12 w150 27 44.04
5625.32 0.00 254.94 5429.00 327.34S 1246. OOW 442236.00 5868527.00 n70 3 05.12 w150 27 44.04
5770.32 0.00 254.94 5574.00 327.34S 1246. 01W 442235.98 5868527.00 n70 3 05.12 w150 27 44.04 f~
5925.32 0.00 254.94 5729.00 327.34S 1246.02W 442235.97 5868526.99 n70 3 05.12 w150 27 44.04
All data in feet unless otherwise stated. Calculation uses minimum curvature method.
Coordinates from slot #451. and TVD from rotary table (254.00 Ft above mean sea level).
Bottom hole distance is 1288.30 on azimuth 255.28 degr....s from w..llh..ad.
Total Dogleg for wellpath is 40.07 degrees.
Vertical section is from N 0.00 E 0.00 on azimuth 255.28 degrees.
Grid is alaska - Zone 4.
Grid coordinates in FEET and comput..d using the Clarke - 1866 spheroid
Presented by Baker Hughes INTEQ
ORIGINAL
,r--,
""-\
Phillips Alaska, Inc.
Drill 5ite 2P, 451
Meltwater,North 51ope, Alaska
PROPO5AL LI5TING Page 3
Your ref, 2P-451 Version #2
Last revised, ll-Jan-2002
Comments in wellpath
- - - - - - - - - - - ---------
-- - - - - - - - - - -- - ------
MD
TVD
Rectangular Coorcls.
Comment
- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - --
300.00 300.00 O.OON O.OOE KOP
800.00 797.47 7.565 42. 86W Begin B1dlTrn
1303.81 1283.51 37.625 169.46W EOC
1378.82 1354.00 44.295 194. 24W Base Permafrost
2017.33 1954.00 101. 045 405.12W Base West 5ak
2231.26 2155.03 120.055 475.77W 7 5/8 C5G
2331.26 2249.00 128.945 508. 80W C80
3102.79 2974.00 197.525 763. 61W C50
3390.12 3244.00 223 .065 858.51W C40
3544.43 3389.00 236. TI5 909.47W C37
3553.07 3397.13 237.545 912.33W Begin Drop
5230.26 5034.11 324.975 1237.21W 5 1/2 X 3 1/2 Crossover
5330.26 5134.00 326.215 1241. 81W T4.1 (Top Cairn)
5431.31 5235.00 327.005 1244. 74W T3.1 (Base Cairn)
5540.32 5344.00 327.335 1245.98W T3 (TOp Bermuda)
5552.58 5356.26 327.335 1245. 99W EOD
5575.30 5378.98 327.345 1245.99W Target
5575.32 5379.00 327.345 1245. 99W 2P-451 MW(X) RV5D 09 Jan 01
5625.32 5429.00 327.345 1246.00W T2 (Base Bermuda)
5770.32 5574.00 327.345 1246.01W C35 (Top Albian)
5925.32 5729.00 327.345 1246.02W TD - Csg pt
Casing positions in string 'A'
-- ----- -- -- - - - - - - - - - -- - - - -- ---
-------- - - - - - - - - - - - - - - - - - -----
Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing
- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - --
0.00
0.00
0.00
0.00
O.OON
O.OON
O. ODE
O. OOE
5925.32
2231. 26
5729.00
2155.03
327.345
120.055
1246. 02W 3 1/2 C5G
475.77W 7 5/8 C5G
Ta][gets associated with this wellpath
----- - - - -------------- ------------ - --
---- -- - - - ---------------- -------- - ---
Target name
Geographic Location
T.V.D.
Rectangular Coordinates
Revised
- -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - --
2P-451 MW (X) RV5D 09 442236.000,5868527.000,999.00
5379.00
327.345
1245.99W 22-Feb-2001
ORIGINAL
,r-...
Phillips Alaska, Inc.
Drill Site 2P
451
slot #451
Meltwater
North Slope, Alaska
PROPOSAL LISTING
by
Baker Hughes INTEQ
Your ref: 2P-451 version #2
Our ref: prop4474
License:
Date printed: ll-Jan-2002
Date created: 22-Feb-2001
Last revised: ll-Jan-2002
on 441964.235,5869891.466,999.00000,N
on 441964.235,5869891.466,999. OOOOO,N
8.338,w150 27 8.152
5868844.800, E 443484.330
1035.15 S 1528.17 E
4, Spheroid: Clarke - 1866
Projection
Reference North is True North
ORIGINAL
/"'"",
,~
----
, \
Phillips Alaska, Inc. PROPOSAL LISTING Page 1
Drill Site 2P, 451 Your ref : 2P-451 Version #2
Meltwater,North Slope, Alaska Last revised : 11-Jan-2002
Measured Inclin. Azimuth True Vert RECTANGULAR Dogleg Vert
Depth Degrees Degrees Depth COORDINATES Degl100ft Sect
0.00 0.00 260.00 0.00 0(0 N 0.00 E 0.00 0.00
300.00 0.00 260.00 300.00 0 00 N 0.00 E 0.00 0.00 KOP
400.00 2.00 260.00 399.98 0 J30 S 1.72 W 2.00 1. 74
500.00 4.00 260.00 499.84 1.21 S 6.87 W 2.00 6.95
600.00 6.00 260.00 599.45 2.73 S 15.46 W 2.00 15.64
700.00 8.00 260.00 698.70 4.84 S 27.46 W 2.00 27.79
800.00 10.00 260.00 797.47 7 56 S 42.86 W 2.00 43.37 Begin BldlTrn
900.00 11. 97 258.34 895.63 11116 S 61.57 W 2.00 62.39
1000.00 13.96 257.14 993.07 15,94 S 83.49 W 2.00 84.80
1100.00 15.94 256.24 1089.68 21 ro S 108.59 W 2.00 110.59
1200.00 17.93 255.53 1185.34 136.84 W 2.00 139.72
1300.00 19.92 254.96 1279.93 ~; ]~~ ~ 168.21 W 2.00 172 .16
1303.81 20.00 254.94 1283.51 37.62 S 169.46 W 2.00 173.46 EOC
1378.82 20.00 254.94 1354.00 44.29 S 194.24 W 0.00 199.12 Base Permafrost
1500.00 20.00 254.94 1467.87 55.06 S 234.26 W 0.00 240.56
2000.00 20,00 254.94 1937.71 99.50 S 399.39 W 0.00 411.57
2017.33 20.00 254.94 1954.00 101. 04 S 405.12 W 0.00 417.49 Base West Sak
2231.26 20.00 254.94 2155.03 120.05 S 475.77 W 0.00 490.66 7 5/8 CSG
2331.26 20.00 254.94 2249.00 128.94 S 508.80 W 0.00 524.86 C80
2500.00 20.00 254.94 2407.56 143.94 S 564.53 W 0.00 582.57
3000.00 20.00 254.94 2877.41 188.38 S 729.66 W 0.00 753.58
3102.79 20.00 254.94 2974.00 197.52 S 763.61 W 0.00 788.74 C50
3390.12 20.00 254.94 3244.00 223.06 S 858.51 W 0.00 887.01 C40
3500.00 20.00 254.94 3347.25 232.82 S 894.80 W 0.00 924.59
3544.43 20.00 254.94 3389.00 236.77 S 909.47 W 0.00 939.78 C37
3553.07 20.00 254.94 3397.13 237.54 S 912.33 W 0.00 942.74 Begin Drop
3600.00 19.53 254.94 3441. 29 241.66 S 927.65 W 1.00 958.61
3700.00 18.53 254.94 3535.82 250.14 S 959.14 W 1.00 991.22
3800.00 17.53 254.94 3630.91 258.18 S 989.03 W 1.00 1022.17
3900.00 16.53 254.94 3726.52 265.79 S 1017.31 W 1.00 1051.45
4000.00 15.53 254.94 3822.63 272.97 S 1043.97 W 1.00 1079.07
4100.00 14.53 254.94 3919.21 279.71 S 1069.02 W 1.00 1105.00
4200.00 13 .53 254.94 4016.23 286.01 S 1092.43 W 1.00 1129.25
4300.00 12.53 254.94 4113.65 291.87 S 1114.20 W 1.00 1151. 79
4400.00 11.53 254.94 4211.45 297.28 S 1134.33 W 1.00 1172.64
4500.00 10.53 254.94 4309.60 302.26 S 1152.80 W 1.00 1191.77
4600.00 9.53 254.94 4408.07 306.78 S 1169.62 W 1.00 1209.19
4700.00 8.53 254.94 4506.83 310.86 S 1184.78 W 1.00 1224.88
4800.00 7.53 254.94 4605.85 314.49 S 1198.27 W 1.00 1238.85
4900.00 6.53 254.94 4705.10 317.67 S 1210.09 W 1.00 1251.09
5000.00 5.53 254.94 4804.54 320.40 S 1220.23 W 1. 00 1261.60
5100.00 4.53 254.94 4904.16 322.68 S 1228.70 W 1.00 1270.37
5200.00 3.53 254.94 5003.91 324.51 S 1235.49 W 1.00 1277.39
5230.26 3.23 254.94 5034.11 324.97 S 1237.21 W 1. 00 1279.18 5 1/2 X 3 1/2 Crossover
5300.00 2.53 254.94 5103.77 325.88 S 1240.59 W 1.00 1282.68
5330.26 2.23 254.94 5134.00 326,21 S 1241. 81 W 1. 00 1283.94 T4.1 (Top Cairn)
5400.00 1. 53 254.94 ~O 326.80 S 1244.02 W 1. 00 1286.23
5431.31 1.22 254.94 5235.00 327,00 S 1244.74 W 1. 00 1286.98 T3.1 (Base Cairn)
5500.00 0.53 254.94 5303.68 327.27 S 1245.75 W 1.00 1288.02
5540.32 0.13 254.94 5344.00 327,33 S 1245.98 W 1.00 1288.26 T3 (Top Bermuda)
All data is in feet unless otherwise stated.
Coordinates from slot #451 and TVD from rotary table (254.00 Ft above mean sea level).
Bottom hole distance is 1288.30 on azimuth 255.28 degrees from wellhead.
Total Dogleg for we11path is 40.07 degrees.
Vertical section is from N 0.00 E 0.00 on azimuth 255.28 degrees.
Calculation uses the minimum curvature method.
Presented by Baker Hughes INTEQ
ORIGINAL
,r----..
~"
Phillips Alaska, Inc.
Drill Site 2P, 451
Meltwater, North Slope, Alaska
PROPOSAL LISTING Page 2
Your ref: 2P-451 Version #2
Last revised: ll-Jan-2002
Measured Inclin. Azimuth True Vert
Depth Degrees Degrees Depth
RECTANGULAR
COORDINATES
Dogleg Vert
Deg/100ft Sect
1. 00 1288.27 EOD
0.00 1288.27 Target
0.00 1288.27 2P-45l MWIX) RVSD 09 Jan 01
0.00 1288.28 T2 (Base Bermuda)
0.00 1288.29 C35 (Top Albian)
0.00 1288.30 TD - Csg pt
5552.58 0.00 254.94 5356.26 327.33 S 1245.99 W
5575.30 0.00 254.94 5378.98 327,34 S 1245.99 W
5575.32 0.00 254.94 5379.00 327.34 S 1245.99 W
5625.32 0.00 254.94 5429.00 327 34 S 1246.00 W
5770.32 0.00 254.94 5574.00 327.34 S 1246.01 W
5925.32 0.00 254.94 5729.00 327,34 S 1246.02 W
All data is in feet unless otherwise stated.
Coordinates from slot #451 and TVD from rotary table (254.00 Ft above mean sea level).
Bottom hole distance is 1288.30 on azimuth 255.28 degrees from wellhead.
Total Dogleg for wellpath is 40.07 degrees.
Vertical section is from N 0.00 E 0.00 on azimuth 255.28 degrees.
Calculation uses the minimum curvature method.
Presented by Baker Hughes INTEQ
ORIGINAL
/-"'"
"'-"'\
Phillips Alaska, Inc.
Drill 5ite 2P,451
Meltwater,North 51ope, Alaska
PROPO5AL LI5TING Page 3
Your ref: 2P-451 Version #2
Last revised: ll-Jan-2002
Comments in wellpath
----- - - - ------- - ----
----- -- - - -----------
MD
TVD
Rectangular Coords.
Comment
- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - --
300.00 300.00 0.00 N 0.00 E KOP
800.00 797.47 7.56 5 42.86 W Begin Bld/Trn
1303.81 1283.51 37.62 5 169.46 W EOC
1378.82 1354.00 44.29 5 194.24 W Base Permafrost
2017.33 1954.00 101.04 5 405.12 W Base West 5ak
2231.26 2155.03 120.05 5 475.77 W 7 5/8 C5G
2331.26 2249.00 128.94 5 508.80 W C80
3102.79 2974.00 197.52 5 763.61 W C50
3390.12 3244.00 223.06 5 858.51 W C40
3544.43 3389.00 236.77 5 909.47 W C37
3553.07 3397.13 237.54 5 912.33 W Begin Drop
5230.26 5034.11 324.97 5 1237.21 W 5 112 X 3 1/2 Crossover
5330.26 5134.00 326.215 1241.81 W T4.1 (Top Cairn)
5431.31 5235.00 327.00 5 1244.74 W T3.1 (Base Cairn)
5540.32 5344.00 327.33 5 1245.98 W T3 (Top Bermuda)
5552.58 5356.26 327.33 5 1245.99 W EOD
5575.30 5378.98 327.345 1245.99 W Target
5575.32 5379.00 327.345 1245.99 W 2P-451 MW(X) RV5D 09 Jan 01
5625.32 5429.00 327.345 1246.00 W T2 (Base Bermuda)
5770.32 5574.00 327.345 1246.01 W C35 (Top Albian)
5925.32 5729.00 327.345 1246.02 W TD - Csg pt
Casing positions in string 'A'
- - ------ - - - - ---- - - - - - - - - ------
- - ------ - - -- ---- -- - - - - - - ------
Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing
- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - --
0.00
0.00
0.00
0.00
O.OON
O.OON
O.OOE
O.OOE
5925.32
2231. 26
5729.00
2155.03
327.345
120.055
1246. 02W 3 1/2 C5G
475.77W 7 5/8 C5G
Targets associated with this wellpath
- ----- - - -------- - ---------------- - - --
------- - - ------ - - - ---------------- - --
Target name
Geographic Location
T.V.D.
Rectangular Coordinates
Revised
- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - --
2P-451 MW(X) RV5D 09 442236.000,5868527.000,999.00
5379.00
327.345
1245.99W 22-Feb-2001
ORIGINAL
"--"",
SUMMARY
Phillips Alaska, Inc.
Drill Site 2P
451
slot #451
Meltwater
North Slope, Alaska
C LEA RAN C E
by
Baker Hughes INTEQ
/'""<',
R E paR T
Your ref: 2P-45l version #2
Our ref: prop4474
License:
Date printed: l5-Jan-2002
Date created: 22-Feb-200l
Last revised: ll-Jan-2002
Field is centred on 44l964.235,586989l.466,999.00000,N
Structure is centred on 44l964.235,586989l.466,999.00000,N
Slot location is n70 3 8.338,w150 27 8.152
Slot Grid coordinates are N 5868844.800, E 443484.330
Slot local coordinates are 1035.15 S 1528.17 E
Projection type: alaska - Zone 4, Spheroid: Clarke - 1866
Object wellpath
MWD <0-9224'>,,438,Drill S~te 2P
MWD <0-8974'>,,429,Drill S~te 2P
MWD <0 - 6008'>,,417,Drill Site 2P
MWD <3660 - 11075'>, ,415,Dril~ Site 2P
MWD <5552 - 9038'>,,415A,Dril~ Site 2P
MWD <0-6860'>,,420,Drill S~te 2P
MWD <0-2040'>,,448,Drill S~te 2P
MWD <754 - 8663'>,,448A,Drill Site 2P
MWD <4000 - 7593'>,,448B,Dril~ Site 2P
PMSS <0-6300'>, ,MWN#2,Meltwater North #2
PMSS <2212-7349'>"MWN#2A,Meltwater North #2
PMSS <0-6122'>, ,MWN#l,Meltwater North #1
PMSS <0-8935'>, ,MWSouthl,Meltwater South #1
Reference North is True North
Closest approach with 3-D
Last revised Distance
4-Jun-2001 259.4
18-Dec-2001 440.1
25-May-2001 679.9
2-Dec-2001 719.6
17-Dec-2001 719.6
14-Jan-2002 620.1
28-Dec-2001 59,1
10-Jan-2002 59.1
14-Jan-2002 59.1
26-Feb-2001 4344.6
26-Feb-2001 2869.9
26-Feb-2001 6444.3
6-Mar-2001 46706.6
ORIGINAL
Minimum Distance method
M.D. Diverging from M.D.
312.5 312.5
80.0 80.0
0.0 0.0
240.0 240.0
240.0 240.0
180.0 180.0
312.5 1480.0
312.5 1700.0
312.5 1700.0
100.0 5925.3
5925.3 5925.3
5620.0 5620.0
5925.3 5925.3
~
..-....
Phillips Alaska, Inc.
Drill Site 2P
451
slot #451
Meltwater
North Slope, Alaska
PRO PO S ALL I S TIN G
INCLUDING POSITION UNCERTAINTIES
by
Baker Hughes INTEQ
Your ref: 2P-45l Version #2
Our ref: prop4474
License:
Date printed: 15-Jan-2002
Date created: 22-Feb-2001
Last revised: 11-Jan-2002
Field is centred on 441964.235,5869891.466,999.00000,N
Structure is centred on 441964.235,5869891.466,999.00000,N
Slot location is n70 3 8.338,w150 27 8.152
Slo~ Grid coordinates are N 5868844.800, E 443484.330
Slot local coordinates are 1035.15 S 1528.17 E
Projec~ion type: alaska - Zone 4, Spheroid: Clarke - 1866
Reference North is True North
ORIGINAL
/"""".,
/""',
Phillips Alaska, Inc. PROPOSAL LISTING Page 1
Drill Site 2P,45l Your ref : 2P-451 Version #2
Meltwater,North Slope, Alaska Last revised : 11-Jan-2002
Measured Inclin. Azimuth True Vert R E C TANGU L A R Vert Ellipse Semi Axes Minor
Depth Degrees Degrees Depth COO RDINA T E S Sect Major Minor Vert. Azi.
0.00 0.00 260.00 0.00 0.00 N 0.00 E 0.00 0.00 0.00 0.00 N/A
300.00 0.00 260.00 300.00 0.00 N 0.00 E 0.00 0.78 0.78 0.45 N/A
400.00 2.00 260.00 399.98 0.30 S I.72W 1. 74 1. 05 1. 05 0.60 N/A
500.00 4.00 260.00 499.84 1.21 S 6.87 W 6.95 1. 36 1. 31 0.75 80.00
600.00 6.00 260.00 599.45 2.73 S 15.46 W 15.64 1. 73 1. 58 0.90 80.00
700.00 8.00 260.00 698.70 4.84 S 27.46 W 27.79 2.22 1. 86 1. 05 80.00
800.00 10.00 260.00 797.47 7.56 S 42.86 W 43.37 2.83 2.16 1. 21 80.00
900.00 11. 97 258.34 895.63 11.16 S 61. 57 W 62.39 3.59 2.46 1. 37 79.50
1000.00 13.96 257.14 993.07 15.94 S 83.49 W 84.80 4.51 2.79 1. 53 78.88
1100.00 15.94 256.24 1089.68 21. 90 S 108.59 W 110.59 5.61 3.13 1. 70 78.24
1200.00 17.93 255.53 1185.34 29.01 S 136.84 W 139.72 6.89 3.50 1. 87 77.65
1300.00 19.92 254.96 1279.93 37.28 S 168.21 W 172 .16 8.37 3.88 2.06 77 .10
1303.81 20.00 254.94 1283.51 37.62 S 169.46 W 173.46 8.42 3.90 2.07 77.08
1378.82 20.00 254.94 1354.00 44.29 S 194.24 W 199.12 9.56 4.19 2.21 76.85
1500.00 20.00 254.94 1467.87 55.06 S 234.26 W 240.56 11.41 4.67 2.45 76.47
2000.00 20.00 254.94 1937.71 99.50 S 399.39 W 411.57 19.15 6.69 3.45 75.82
2017.33 20.00 254.94 1954.00 101. 04 S 405.12 W 417.49 19.42 6.76 3.48 75.81
2231.26 20.00 254.94 2155.03 120.05 S 475.77 W 490.66 22.76 7.64 3.91 75.69
2331.26 20.00 254.94 2249.00 128.94 S 508.80 W 524.86 24.32 8.05 4.12 75.64
2500.00 20.00 254.94 2407.56 143.94 S 564.53 W 582.57 26.95 8.75 4.46 75.55
3000.00 20.00 254.94 2877.41 188.38 S 729.66 W 753.58 34.77 10.82 5.48 75.41
3102.79 20.00 254.94 2974.00 197.52 S 763.61 W 788.74 36.39 11.25 5.69 75.39
3390.12 20.00 254.94 3244.00 223.06 S 858.51 W 887.01 40.89 12.45 6.28 75.34
3500.00 20.00 254.94 3347.25 232.82 S 894.80 W 924.59 42.61 12.90 6.51 75.32
3544.43 20.00 254.94 3389.00 236.77 S 909.47 W 939.78 43.30 13.09 6.60 75.32
3553.07 20.00 254.94 3397.13 237.54 S 912.33 W 942.74 43.44 13 .12 6.62 75.31
3600.00 19.53 254.94 3441.29 241. 66 S 927.65 W 958.61 44.15 13.32 6.71 75.31
3700.00 18.53 254.94 3535.82 250.14 S 959.14 W 991. 22 45.58 13.72 6.91 75.30
3800.00 17.53 254.94 3630.91 258.18 S 989.03 W 1022.17 46.90 14.11 7.10 75.29
3900.00 16.53 254.94 3726.52 265.79 S 1017.31 W 1051.45 48.13 14.49 7.28 75.28
4000.00 15.53 254.94 3822.63 272.97 S 1043.97 W 1079.07 49.27 14.86 7.46 75.27
4100.00 14.53 254.94 3919.21 279.71 S 1069.02 W 1105.00 50.32 15.22 7.63 75.26
4200.00 13.53 254.94 4016.23 286.01 S 1092.43 W 1129.25 51.28 15.57 7.80 75.26
4300.00 12.53 254.94 4113.65 291.87 S 1114.20 W 1151.79 52.16 15.91 7.96 75.25
4400.00 11.53 254.94 4211.45 297.28 S 1134.33 W 1172.64 52.96 16.24 8.12 75.25
4500.00 10.53 254.94 4309.60 302.26 S 1152.80 W 1191.77 53.68 16.55 8.27 75.24
4600.00 9.53 254.94 4408.07 306.78 S 1169.62 W 1209.19 54.32 16.85 8.42 75.24
4700.00 8.53 254.94 4506.83 310.86 S 1184.78 W 1224.88 54.89 17.15 8.57 75.24
4800.00 7.53 254.94 4605.85 314.49 S 1198.27 W 1238.85 55.39 17.42 8.71 75.24
4900.00 6.53 254.94 4705.10 317.67 S 1210.09 W 1251. 09 55.83 17.69 8.86 75.23
5000.00 5.53 254.94 4804.54 320.40 S 1220.23 W 1261. 60 56.20 17.95 9.00 75.23
5100.00 4.53 254.94 4904.16 322.68 S 1228.70 W 1270.37 56.51 18.19 9.14 75.23
5200.00 3.53 254.94 5003.91 324.51 S 1235.49 W 1277.39 56.76 18.43 9.27 75.23
5230.26 3.23 254.94 5034.11 324.97 S 1237.21 W 1279.18 56.81 18.50 9.32 75.23
5300.00 2.53 254.94 5103.77 325.88 S 1240.59 W 1282.68 56.95 18.65 9.41 75.23
5330.26 2.23 254.94 5134.00 326.21 S 1241. 81 W 1283.94 56.99 18.72 9.45 75.23
5400.00 1. 53 254.94 5203.70 326.80 S 1244.02 W 1286.23 57.09 18.86 9.55 75.23
5431.31 1. 22 254.94 5235.00 327.00 S 1244.74 W 1286.98 57.12 18.93 9.59 75.23
5500.00 0.53 254.94 5303.68 327.27 S 1245.75 W 1288.02 57.18 19.07 9.69 75.23
5540.32 0.13 254.94 5344.00 327.33 S 1245.98 W 1288.26 57.21 19.15 9.74 75.23
All data is in feet unless otherwise stated.
Coordinates from slot #451 and TVD from rotary table (254.00 Ft above mean sea level).
Bottom hole d~stance is 1288.30 on azimuth 255.28 degrees from wellhead.
Vertical section is from N 0.00 E 0.00 on azimuth 255.28 degrees.
Calculation uses the minimum curvature method.
Presented by Baker Hughes INTEQ
ORIGINAL
,~
/-...,
Phillips Alaska, Inc. PROPOSAL LISTING Page 2
Drill Site 2P,451 Your ref : 2P-451 Version #2
Meltwater,North Slope, Alaska Last revised : ll-Jan-2002
Measured Inclin. Azimuth True Vert R E C TANGU L A R Vert Ellipse Semi Axes Minor
Depth Degrees Degrees Depth COO RDINA T E S Sect Major Minor Vert. Azi.
5552.58 0.00 254.94 5356.26 327.33 S 1245.99 W 1288.27 57.22 19.17 9.76 75.23
5575.30 0.00 254.94 5378.98 327.34 S 1245.99 W 1288.27 57.23 19.21 9.79 75.23
5575.32 0.00 254.94 5379.00 327.34 S 1245.99 W 1288.27 57.23 19.21 9.79 75.23
5625.32 0.00 254.94 5429.00 327.34 S 1246.00 W 1288.28 57.27 19.31 9.86 75.23
5770.32 0.00 254.94 5574.00 327.34 S 1246.01 W 1288.29 57.36 19.61 10.06 75.23
5925.32 0.00 254.94 5729.00 327.34 S 1246.02 W 1288.30 57.47 19.92 10.27 75.23
POSITION UNCERTAINTY SUMMARY
------------------------------
------------------------------
Depth
From To
Survey Teol
Error Model
position Uncertainty
Major Minor Vert.
----------------------------------------------------------------------------------------------------
0
5925
ARCO (H.!'.) Mag)
User specified
57.47
19.92
10.27
1. Ellipse dimensions are r.alf axis.
2. Casing dimensions are nüt included.
3. Ellipses are calculated on 2.58 standard deviations.
4. Uncertainty calculations start at drill depth zero.
5. Surface position uncert~inty is not included.
6. Where two surveys are tied together the errors of one are considered
to have a systematic relationship to the corresponding errors of the
7. Detailed description of the INTEQ error models can be found
in the Ec*Trak manual.
other.
All data is in feet unless otherwise stated.
Coordinates from slot #451 and TVD from rotary table (254.00 Ft above mean sea level).
Bottom hole d~stance is 1288.30 on azimuth 255.28 degrees from wellhead.
Vertical section is from N 0.00 E 0.00 on azimuth 255.28 degrees.
Calculation uses the minimum curvature method.
Presented by Baker Hughes INTEQ
ORIGIIVAL
,"-"'"
~
Phillips Alaska, Inc.
Drill 8ite 2P,45l
Meltwater,North 8lope, Alaska
PROPO8AL LI8TING Page 3
Your ref: 2P-451 Version #2
Last revised: Il-Jan-2002
Comments in wellpath
--------------------
--------------------
MD
TVD
Rectangular Coords.
Comment
-----------------------------------------------------------------------------------------------------------
300.00 300.00 0.00 N 0.00 E KOP
800.00 797.47 7.56 8 42.86 W Begin Bld/Trn
1303.81 1283.51 37.62 8 169.46 W EOC
1378.82 1354.00 44.29 S 194.24 W Base Permafrost
2017.33 1954.00 101.04 8 405.12 W Base West 8ak
2231.26 2155.03 120.05 8 475.77 W 7 5/8 C8G
2331. 26 2249.00 128.94 8 508.80 W C80
3102.79 2974.00 197.52 8 763.61 W C50
3390.12 3244.00 223.06 8 858.51 W C40
3544.43 3389.00 236.77 8 909.47 W C37
3553.07 3397.13 237.54 8 912.33 W Begin Drop
5230.26 5034.11 324.97 8 1237.21 W 5 1/2 X 3 1/2 Crossover
5330.26 5134.00 326.21 8 1241.81 W T4.1 (Top Cairn)
5431. 31 5235.00 327.00 8 1244.74 W T3.1 (Base Cairn)
5540.32 5344.00 327.33 8 1245.98 W T3 (Top Bermuda)
5552.58 5356.26 327.33 8 1245.99 W EOD
5575.30 5378.98 327.34 8 1245.99 W Target
5575.32 5379.00 327.34 8 1245.99 W 2P-451 MW(X) RV8D 09 Jan 01
5625.32 5429.00 327.34 8 1246.00 W T2 (Base Bermuda)
5770.32 5574.00 327.34 8 1246.01 W C35 (Top Albian)
5925.32 5729.00 327.34 8 1246.02 W TD - Csg pt
Casing positions in string 'A'
------------------------------
------------------------------
Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing
-----------------------------------------------------------------------------------------------------------
0.00
0.00
0.00
0.00
O.OON
O.OON
O.OOE
O.OOE
5925.32
2231.26
5729.00
2155.03
327.348
120.058
1246. 02W
475.77W
3 1/2 C8G
7 5/8 C8G
Targets associated with this wellpath
-------------------------------------
-------------------------------------
Target name
Geographic Location
T.V.D.
Rectangular Coordinates
Revised
-----------------------------------------------------------------------------------------------------------
2P-451 MW(X) RV8D 09 442236.000,5868527.000,999.00
5379.00
327.348
1245.99W
22-Feb-2001
ORIGINAL
r----
~
2P-451 DrillinQ Hazards Summary
(to be pos~ed in Rig Floor Doghouse Prior to Spud)
(See Well Plan for further discussion of these risks)
Mitigation Strategy
Good drilling practices. LCM as needed.
Stay within ECD Hard line of 11.0 ppg.
Pumping and rotating out on all trips to
reduce swab and barite sag potential.
Surface CasinQ Interval
Event Risl( Level
Conductor Broach _ow
Well Collision _ow
Gravel and sand _ow
sloughing
ShakerfTrough Cuttings _ow
System Overflow
Permafrost Hydrates _ow
Shoe Fracture/Lost
Returns during cement
job
_ow
Production Casina Interval
Event
Lost Circulation in
Bermuda interval
High ECD and
swabbing if higher
MW is required
Hole stability during
e-line runs
Risk Leve~
High .¡
Low
Mitigation Strategy
Monitor cellar continuously during interval.
Careful well planning and surveying,
adherence to anti-collision policy
Elevated mud viscosity from spud; Hi dens
sweeps.
Controlled ROP
Controlled drilling, reduced pump rates,
higher mud weights, cold mix water and
mud, lower viscosities, and lecithin
additions as needed
Reduced pump rates, and lightweight tail
cement
Moder,.(e Emphasis on maintaining mud properties.
Clean out runs as needed. Good drilling
practices
ORIGINAL
2P-451 Drilling Hazards Summary. doc
prepared by Pat Reilly
01/15/02
Page 1 of 1
~
Meltwater 2P-4~1
Proposed Completion Schematic
Slim hole Base Case - 3-1/2" Completion String
r ~
~ ~
I ~
~ ~
I ~
~ I
~ I
~ ~
~ ~
~ ~
16" 62.6# ... I
@+1-110'MD I~
Port Collar 1000' MD
Depths are
based on / I
Doyon 141 I
RKB I
~
~
~
~
~
~
~
~
J
Surface csg.
7-5/8" 29.7# L-80 BTCM
+1- 2~' MD 12155' 1VD
12' Pup (Critical)
Intermediate csg.
5-112" 15.5# L-80 BTCM
run CSR to surface
+1- 5230' MD 15034 1VD
Future Perforations
Production csg
3-1/2;19.3# L-80 EUE8RD
TD to CSR
+/- 5925' MD / 5729' TVD
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PHilliPS Alaska, Inc.
A Subsidiary of PHilLIPS PETROLEUM COMPANY
3-112" FMC Gen 5 Tubing Hanger, 3-1/2" L-BO EUEBRD pin down
3-1/2" 9.3# L-BO EUEBRD Spaceout Pups as Required
3-1/2" 9.3# L-BO EUE8RD Tubing to Surface
3-1/2" Cameo 'DS' nipple wI 2.875" No-Go Profile. 3-112" x 6' L-80 handling
pups installed above and below, EUEBRD set at +1- 500' MD
3-112" 9.3# L-80 EUE8RD tubing to landing nipple
3-1/2" x 1" Cameo 'KBG-2-9' mandrel wI DCK-3 shear valve and bottom latch
(Max. OD 4.725", ID 2.90"), IBT box x box, pinned for 3000 psi shear (casing to
tubing differential), 3-1/2" x 6' L-BO EUE8RD box x IBT pin handling pup installed
above, 3-1/2" x 6' L-BO IBT pin x EUE8RD pin handling pup installed below
1 jt 3-1/2" 9.3# L-80 EUE8RD tubing
3-112" Baker 'CMU' sliding sleeve w/2.813" Cameo No-Go profile, EUE8RD
box x pin. 3-1/2" x 6' L-BO EUEBRD handling pups installed above
3-1/2" Cameo 'D' nipple wI 2.75" No-Go profile. 3-1/2" x 12' L-80 EUE8RD
handling pup installed above. 3-1/2" x 6' L-BO EUE8RD handling pup below
1 jt 3-112" 9.3# L-BO EUEBRD tubing
3-112" Baker 80-40 GBH-22 casing seal assembly wI 15' stroke, 3-1/2" L-BO
EUE8RD box up, 3-112" x 6' L-80 EUE8RD handling pup installed on top
- Baker Casing Seal Receptacle, 80-40, 5-1/2"BTCM x 3-112" EUE8RD
Baker 5" OD x 4" ID 17' Seal Bore Extension
CSR set at +1- 100' MD above the top of the Bermuda (OR 100' MD ABOVE THE
- TOP OF THE CAIRN IF THE CAIRN IS PRESENT)
~
ORIGINAL
PJR,01/14/02
Rig: Doyon 141
Location: Kuparuk (Meltwater)
Client: Phillips Alaska, Inc.
Revision Date: 1/14/2002
Prepared by: Kevin Tanner
Location: Anchorage, AK
Phone: (907) 265-6205
Mobile: (907) 230-6628
email: ktanner@slb.com
< TOC at Surface
Previous Csg.
< 16",62.6#, H-40 grade
Welded Connection
at 120 ft. MD
< Base of Permafrost
at 1,379 ft. MD
(1,354 ft. 1VD)
< Top of Tail at
1 ,399 ft. MD
< 75/8",29.7#, L-80 grade
BTC, AB Modified
in 9718" OH
~
TO at 2,231 ft. MD
(2,155ft.1VD)
Mark of Schlumberger
Schlumberger
Preliminary Job Design based on limited input data. For estimate purposes only.
Volume Calculations and Cement Systems
(Volumes are based on 450% excess in the permafrost and 45% excess below the
permafrost. Top of tail slurry is designed to be 20' below base of permafrost.)
Lead Slurry (minimum pump time 170 min.)
ASLite @ 10.7 pp~, Class G + 50%D124, 9%D44, 0.4%D46, 30%D53, 1.5%S1,
1.5%D79 - 4.44 ft /sk
0.9513 ft3/ft x (120') x 1.00 (no excess) =
0.2148 fe/ft x (1379' -120') x 5.50 (450% excess) =
0.2148 fe/ft x (1399' - 1379') x 1.45 (45% excess) =
114.2 fe + 1487.4 fe+ 6.2 fe =
1607.8 fe I 4.44 ft3/sk =
Round up to 370 sks
114.2 fe
1487.4 fe
6.2 ft3
1607.8 ft3
362.1 sks
Have 270 sks of additional Lead on location for Top Out stage, if necessary.
Tail Slurry (minimum pump time 121 min.)
LiteCRET::: @ 12.0 ppg - 2.40 ft%k
0.2148 felft x (2231' -1399') x 1.45 (45% excess) =
0.2578 felft x 80' (Shoe Joint) =
259.1 ft3 + 20.6 fe =
279.7 ft3/ 2.40 fe/sk =
Round up to 120 sks
259.1 ft3
20.6 fe
279.7 fe
116.5 sks
BHST = 53°F, Estimated BHCT = 70°F.
(BHST caculated using a gradient of 2.3°F/1 00 ft. below the permafrost)
PUMP SCHEDULE
Pump Rate Stage Stage Time Cumulative
Sté ge (bpm) Volume (min) Time
(bbl) (min)
CW100 6 40 6.7 6.7
Drop Bo'1om Plug 3.0 9.7
Mud ;)USH XL 6 40 6.7 16.4
Lead Slurry 6 293 48.8 65.2
-ail Slurry 6 51 8.5 73.7
Drop Top Plug 3.0 76.7
Displacement 6 79 13.2 89.9
BJmp Plug 3 20 6.7 96.6
MUD REMOVAL
Recommended Mud Properties: 9.8 ppg, Pv < 15, T y < 15. As thin and light as possible
to aid in mud removal during cementing.
Spacer Properties: 10.5 ppg MudPUSH* XL, Pv z 17-20, Tv z 20-25
Centralizers: Recommend 1 per joint across zones of interest for proper cement
placement.
ORIGINAL
Rig: Doyon 141
Location: Kuparuk (Meltwater)
Client: Phillips Alaska, Inc.
Revision Date: 1/14/2002
Prepared by: Chris Avant
Location: Anchorage, AK
Phone: (907) 265-6067
Mobile: (907) 233-8808
email: ceavant@slb.com
Previous Csg.
< 7518",29.7#, L-80 grade
BTC, AB Modified
at 2,231 ft. MD
Schlumbøpgøp
Preliminary Job Cesign based on limited input data. For estimate purposes only.
Volume Calculations and Cement Systems
(Volumes are based on 75% excess. Top of tail slurry is designed to be 500' above
casing X-over.
Tail Slurry (minimum thickening time 125 min.)
GasBLOK wI Class G + 053,0600,0135,0800,0047,0065, per lab testing
@ 15.8 ppg, 1.2 ft%k
0.0835 fe/ft x 500' x 1.75 (75% excess) =
0.1817 fe/ft x (5925' - 5230') x 1.75 (75% excess) =
0.0488 ft3/ft x 80' (Shoe Joint) =
73.1 fe + 221 fe + 3.9 fe =
298.0 ft31 . .2 fe/sk =
Round up to 250 sks
73.1 fe
221 fe
3.9 fe
298.0 fe
248.3 sks
BHST = 133°F, Estimated BHCT = 114°F.
(BHST ca culated using a gradient of 2.3°F/1 00 ft. below the permafrost)
PUMP SCHEDULE
Pump Rate Stage Stage Time Cumulative
< 51/2",15.5#, L-80 grade Stage (bpm) Volume (min) Time
BTC, AB Modified (bbl) (min)
in 6 3/4" OH CW100 6 60 10.0 10.0
Drop B010m Plug 3.0 13.0
Mud=>USH XL 6 40 6.7 19.7
Tail Slurry 6 53 8.8 28.5
Drop Top Plug 3.0 31.5
Displacement 6 121 20.2 51.7
B Jmp Plug 3 9 3.0 54.7
t
< Top of Tail at
4,730 ft. MD
< X-over at 5,230 ft. MD
< Top of Berrruda Fm.
at 5,540 ft. MD
< 31/2",9.3#, L-80 grade
BJE, 8rd Modified
in 6 3/4" OH
TO at 5,925 ft. MD
(5,729 ft. lVD)
Mark of Schlumberger
MUD REMOVAL
Recommended Mud Properties: 9.6 ppg, Pv < 15, T y < 15. As thin and light as possible
to aid in mud removal during cementing.
Spacer Properties: 12.0 ppg MudPUSH* XL, Pv'" 19-22, T y ". 22-29
Centralizers: Recommend 1 per joint across zones of interest for proper cement
placement.
ORIGINAL
~
PHILLI~ oJ Alaska, Inc.
A Subsidiary of PHILL PS PETROLEUM COMPANY
~
/JJSA- I i2l If) 'L
4- q~\-O)
Phillips Alaska, Inc.
Post Office Box 10\J360
Anchorage, AlaskE 99510
January 15, 2002
Ms. Cammy Oechsli Taylor
Commissioner
Alaska Oil and Gas Conservation Commission
333 West 7'h Avenue, Suite 100
Anchorage, AK 99501
(907) 279-1433
Re:
Application for Permit to D"iII:
KRU 2P-451
Surface Location:
Target Location:
Bottom Hole Location:
1035'FNL, 1524' FWL,Sec. 17,T8N,R7E
1362'FNL,277'FWL,Sec.17,T8N,R7E
1362'FNL,277'FWL,Sec.17,T8N, R7E
Dear Commissioner:
Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore development well KRU 2P-451.
The well will be drilled and comple~ed using Do~. Please utilize documents on file for this rig.
'/jlI<J r (J.(,L 3 '
Subject to AOGCC approval, fluids and cuttings generated from drilling the well will be pumped down an
approved and existing annulus on Drillsite 2P, or hauled to an approved Prudhoe or GKA Class II disposal
well.
The following people are the desig lated contacts for reporting responsibilities to the Commission:
A) Completion Report Sharon Allsup-Drake, Drilling Technologist
(20 MC 25.070) 263-4612
B)
Geologic Data and Logs
(20 AAC 25.071)
Steve Moothart, Geologist
265-6965
If you have any questions or require further information, please contact Pat Reilly at (907) 265-6048.
Sincerely,
qhU~~
Drilling Engineering Supervisor
RECEIVED
JAN 1 5 2002
Alaska Oil & Gas Cons. Commission
Anchorage
ORIGINAL
/~
. .. . .
PÞUI..J..JPS...........J\LASi(A ..JNC.
KUP ARÙKSA TELLITEDIS8ÙRŠÉMENT ACCT
P.O. Box)103240. .
Anphorage, A'> 99510....3240
PAY
TO THE
ORDERQF:
STATE OF ALASKA
AOGCC .
333 W.7TH AVENUE, SUITE 1 C 0
~
. ..
. .
NUMBER. 2 aBIDO 220 $
. . JANUARYlt,2002
VO IDAFTER90DA YS....'
EXACTLy**h******100 DOLLARS AND DOCENTS $********100.00
...... .
.~
BANK = ONE.
-
BANK ONE, NA - 0710
Chicago, IL
Payable through
First USA Bank, NA
TRACE NUMBER: 206002203
<~p -t{5l ¡
III 20bOO 220jlll 1:0 ~ . .00 2B jl:
c;~p ¿:;?~
011 2 7 ... 7 j III
...
, r---
.--....
TRANS~T AL LETTER CHECK LIST
CIR CLE APPR ø PRIA TE LETIER/P ARA GRAPHS TO
BEINCLUPED IN TRANSNDTTALLETTER
WELVNAME Kf?tJ 2fZ#!
CHECK 1
STANDARD LETTER
DEVELOPMENT
DEVELOPMENT
REDRILL
EXPLORATION
INJECTION WELL
~'
INJECTION WELL
RED RILL
CHECK WØA T APPLIES
ADD-ON~ (OPTIONS)
MULTI LA 'fERAL
(If api number last two (2)
digits are be~ween 60-69)
PILOT HOLE (PH)
ANNULAR: DISPOSAL
U-J NO
ANNULA~ DISPOSAL
<-.J YES
ANNULAR DISPOSAL
THIS WEl¡.L
DISPOSAL INTO OTHER
ANNUL~ +
SPACING EXCEPTION
Templates are located m drive\jody\templates
"CLUE"
The permit is for a new wellbore segment of existing well
~PermitNo, ,API No. . '
Production should continue to be reported as a function of
the original API number stated above.
In accordance with 20 AAC 25.005(t), all records, data and
logs acquired for the pilot hole must be clearly
differentiated in both name (name on permit plus PH)
and API number (50 -70/80) from
records, data and logs acquired for well (name on permit).
Annular disposal has not been requested. . .
Annular Disposal of drilling wastes will not be approved. . .
Annular Disposal of drilling wastes will not be approved. . .
Please note that an disposal of fluids generated.. .
Enclosed is the approved application for permit to drill the
above referenced well. The permit is approved. sùbject to
full compliance with 20 AAC 25.055. Approval to peñorate
and produce is contingent upon issuance of a conservation
order approving a spacing exception.
(Company Name) will assume the liability of any protest to
the spacing exception that may occur.
, K~¿¿
WELL PERMIT CHECKLIST COMPANY ~11;?..s WELL NAME ;Zߥ'5""1 PROGRAM: exp - dev - redrll- serv / wellbore sag _ann. disposal para req-
FIELD & POOL t./91J/~/;) INITCLASS ,¿je.r- frA~//I/ GEOLAREA B9D UNIT# V///(d") ON/OFFSHORE 011
ADMINISTRATION 1. Pe nnit fee attached. . . . .. . . . . . . . . h'-' .. . . . .. ~N _bI ~ // /I.£e- k -4R - /l-P
2. Lease number appropriat~. ~ ~r:~. ~ I (Q -:76.1 @ ~ ~( AJ7 O(lJ::L ~ L 373//2, ß
3.Uniquewellnameandnumber.................. Y N
4.Welllocatedinadefinedpool.................. N
5. Well located proper distance from drilling unit boundary. . . . - N
6. Well located proper distance from other wells.. . . . . . . . . N
7. Sufficientacreageavailable'indrillingunit............ .
8. If deviated, is wellbóre plat induded.. . . . . . . . . . . . . . N
9. Operator only affected party.. . . . . . . . . . . . . . . . . . N
10. Operator has appropriate bond in force. . . . . . . . . . . . . N
11. Pennit can be issued without conservation order. . . . . . . . N
12. Pennit can,be issued without administrative approval.. . . . . N
13. Can permit be approved before 15-day wait.. . . . . . . . . . N
14. Conductor string provided . . . . . . . . " . . . . . . . .-: ~ N
15. Surface casing protects all known USDWs. . . . . . . . . . . N
16. CMT vol adequate to circulate on conductor & surf csg. . . . . N
17. GMT vol adequate to tie-in long string to surf csg. . . . . . . . Y N mA
18. CMT will cover all known productive horizons. . . . . . . . . . ~ N
19. Casing designs adequate for C, T, B & pennafrost. . . . . . . . N .
20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N .llLO'ý c1.'L¿
21. If a re-<:trill, has a 10-403 for abandonment been approved. . . ~y N N/A.
22. Adequate well bore separation proposed.. . . . . . . . . . . . N
23. If diverter required, does it meet regulations. . . . . . . . . . N
24. Drilling fluid program schematic & equip list adequate. . . . . N
25. BOPEs, do they meet regulation. . . . . . , . . . . . . . . . ~ N I\l- 3 '_J, ¡ , . -^
DATE¡ 26. BOPE press rating appropriate; test to 3000 psig. N MfS p::. 1'100 fC-L ~ -\ec"" f ì"é't;S. ~ CfPULr<.. 't-f"~
IILL 1JL' 27. Choke-manifoldcompliesw/APIRP-53(May84)........ N
\/ 28. Work will occur without operation shutdbwn. . . . . . . . . . . 'ti,
'! ,-CD 29. Is presence of H:25 gas probable.. . . . . . . . . . . . . . . . Y af
30. Pennit can be issued w/o hydrogen sulfide measures. . . .. /~ .' '/ - J'.- ,-I
31. Datapresentedonpotentialoverpressurezones.. . . . . . ^~ '=x~~ ~¿ldN- ~~ .t<3 <~3S-~ð ~¡'57Z-9~
; 32. Seismicanal~~isofshaJlowgaszones. . . . . . . . . . .~. f't Y N # o'r~yÆ cy Eø:14) 1? g:ð"~)Æ{) .
, A~ DATE 33. Seabed condItion survey (If off-shore). . . . . . . . . . . . . Y N D (/ ¿J f/l/O
. ",LIp /,/.{'..¿YZ-- 34. Contact name/phone for weekly progress reports [explora only] Y N
I
ANNULAR DISPOSAl35. With proper cementing records, this plan .
(A) will contain waste in a suitable receiving zone; . . . . . . .
(B) will not contaminate freshwater; or cause drilling waste. ..
to surface;
(C) will not impair mechanical integrity of the well used for disposal; Y N
(D) will not damage producing fonnation or impair recovery from a Y N
pool; and
(E) will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N
GEOL~~Y..: ENÇ'INEERING: UIC/Annuiar COMMISS,ION:.. . commentslln.s.tructions:. .' '. . p
~þ~ .~ V-- WM 8~s ,h .--10 ~ /}O iL--d( ¡(~ Þ-u-J ,~dløðð'« ~'~/o ð?--
'? 'I\lli~.,., \ '" -0 ~ J M H 'iM I ( II àll f». hU ;;< P. )I" {.".¡ 11 .ft.- p.£ ~. . r-o/V ,..d! ~ vI fh d Á
' /~" ~,(?,? /Æ _0 ,'- .
~If ¿r:rü-Y;, ¡..¿..ce,,~ zp-¥/Ç" ,#t!1.J¿4£ ~ ~~. .8 a-J. . ~r;~~
(J~I"'t¡;dÍ~~ 6v~.'-"t. Cß~. . ~ //"../ ~-r ~~z.ry~
/lo~t:!C- . ~ ~ ;t'P'/9?S-.£. Z/< 0//7 ~ ~ ~Æ. ~.-
Ò J;t::23 /,Z,;;.¡-ó/
A~~ DATE
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ENGINEERING
A~FA
;~
,GEOLOGY
APPR
DATE
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c:\msoffice\wordian\diana\checklist (rev. 11/011100)
,,-....
--.....,
Well History File
APPENDIX
Infonnation of detailed nature that is not
particularly gennane to the Well Pennitting Process
but is part of the history file.
To improve the readability of the Well History file and to
simplify finding information, infonnation of this
nature is accumulated at the end of the file under APPENDIX.
No special effort has been made to chronologically
organize this category of information.
,
, r--..
..----....
&O&~
,.
**** REEL HEADER ****
LDWG
03/10/22
AWS
01
RECEIVE[)
NOV 12 2003
Ataaka on , GII tìonI. QØÎ-
AlkfkJ65~
**** TAPE HEADER ****
LDWG
03/10/22
01
*** LIS COMMENT RECORD ***
!!!!!!!!!!!!!!!!!! !
! ! !!!!!!!!! !! !! !!! !
TAPE HEADER
MELTWATER UNIT
MWD/MAD LOGS
#
WELL NAME:
API NUMBER:
OPERATOR:
LOGGING COMPANY:
TAPE CREATION DATE:
#
JOB DATA
LDWG File Version 1.000
Extract File: LISTAPE.HED
2P-451
501032040200
Phillips Alaska, Inc.
BAKER HUGHES INTEQ
22-0CT-03
JOB NUMBER:
LOGGING ENGINEER:
OPERATOR WITNESS:
MWD RUN 1
1
S. TUFT ON
D. WESTER
MWD RUN 2
2
G. SUTING
D. WESTER
MWD RUN 3
3
C. WONG
R. BOWIE
#
SURFACE LOCATION
SECTION:
TOWNSHIP:
RANGE:
FNL:
FSL:
FEL:
FWL:
ELEVATION(FT FROM MSL 0)
KELLY BUSHING:
DERRICK FLOOR:
GROUND LEVEL:
17
8N
7E
254.00
224.00
#
WELL CASING RECORD
OPEN HOLE CASING DRILLERS
BIT SIZE (IN) SIZE (IN) DEPTH (FT)
1ST STRING
2ND STRING
3RD STRING
PRODUCTION STRING
42.000
9.875
6.750
16.000
7.625
110.0
2236.0
5950.0
#
REMARKS:
PER PHILLIPS ALASKA STANDING ORDER, THE GAMMA RAY
CURVE FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS
WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED.
INDIVIDUAL MWD RUN DATA WAS MERGED IN THE FIELD PRIOR
TO DELIVERY FROM THE WELL SITE.
SURFACE LOCATION:
LAT : N 70 DEG
LONG: W150 DEG
LOG MEASURED FROM
3' 8.338"
27' 8.152"
D.F. AT 254.0 FT. ABOVE PERM. DATUM
_e_~~ 'b "'- ~
".
~
.~
(1. .L.).
COMMENTS:
(1) Baker Hughes INTEQ run 1 utilized a Gamma Ray with
MAP (Modular Annular Pressure) services from 235 - 2251
feet MD (235 - 2174 TVD).
(2) Baker Hughes INTEQ runs 2 & 3 utilized the
slimhole Advantage Porosity Logging Service (APLS)
which includes the Optimized Rotational Density (ORD),
Caliper Corrected Neutron (CCN), along with MAP
(Modular Annular Pressure) and MPR Resistivity
services from 2251 - 5950 feet MD (2174 - 5755 TVD).
REMARKS:
(1) Depth of 16" Casing Shoe - Driller: 110 feet MD
(110 TVD)
(2) The interval from 2208 - 2251 feet MD (2133 - 2174
TVD) was not logged due to sensor-bit offset at the
7 5/8" casing point.
(3) Depth of 7 5/8" Casing Shoe - Logger: 2236 feet MD
(2160 TVD)
Depth of 7 5/8" Casing Shoe - Driller: 2234 feet MD
(2158 TVD)
(4) The Neutron Porosity sensor had an intermittent
transmission error. The following intervals are
missing Neutron data:
2469 - 2480 feet MD (2380 - 2390 feet TVD)
2614 - 2632 feet MD (2516 - 2533 feet TVD)
3048 - 3067 feet MD (2921 - 2939 feet TVD)
3244 - 3256 feet MD (3104 - 3116 feet TVD)
3740 - 3745 feet MD (3573 - 3578 feet TVD)
4326 - 4332 feet MD (4140 - 3146 feet TVD)
(5) The interval from 4323 to 4373 feet MD (4137-
4186' TVD) was logged up to 12.0 hours after being
drilled due to a short trip caused by a rig power
outage.
(6) The interval from 4877 to 4927 feet MD (4684 -
4733 TVD) was logged up to 15.3 hours after being
drilled due to a trip to change out the MWD tool.
(7) The interval from 5899 to 5950 feet MD (5704-5755
TVD) was not logged due to sensor-bit offset at TD.
$
Tape Subfile: 1
90 records...
Minimum record length:
Maximum record length:
8 bytes
132 bytes
**** FILE HEADER ****
LDWG
.001
1024
*** LIS COMMENT RECORD ***
!!! ! !!!!!!!!!!!!!!!
!!!!!!!!!!!!!!!!!! !
FILE HEADER
FILE NUMBER:
EDITED MERGED MWD
Depth shifted and
DEPTH INCREMENT:
#
FILE SUMMARY
PBU TOOL CODE
MWD
$
LDWG File Version 1.000
Extract File: FILEO01.HED
1
clipped curves; all bit runs merged.
.5000
START DEPTH
191. 0
STOP DEPTH
5950.0
#
BASELINE CURVE FOR SHIFTS:
CURVE SHIFT DATA (MEASURED DEPTH)
--------- EQUIVALENT UNSHIFTED DEPTH ---------
~
BASELINE DEP'~
$
~
#
MERGED
PBU
MWD
MWD
MWD
$
DATA SOURCE
TOOL CODE
BIT RUN NO
1
2
2R
MERGE TOP
191. 0
2207.0
4872.0
MERGE BASE
2207.0
4872.0
5950.0
#
REMARKS:
MERGED PASS.
NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH
REFERENCE FOR THIS WELL.
Bit run 1 (191 - 2207' MD) contains Gamma Ray & ROP
data only.
$
#
*** INFORMATION TABLE: CONS
MNEM VALU
------------------------------
WDFN
LCC
CN
WN
FN
COUN
STAT
2p451_5.xtf
150
Phillips Alaska, Inc.
2P-451
Meltwater
North Slope
Alaska
*** INFORMATION TABLE: CIFO
MNEM CHAN DIMT CNAM
ODEP
----------------------------------------------------
GR GR GRAM 0.0
RPD RPD RPD 0.0
RPS RPS RPS 0.0
RHOB RHOB BDCM 0.0
DRHO DRHO DRHM 0.0
PEF PEF DPEM 0.0
NPHI NPHI NPCKSM 0.0
ROP ROP ROPS 0.0
FET FET RPTH 0.0
MTEM MTEM TCDM 0.0
* FORMAT RECORD (TYPE# 64)
Data record type is: a
Datum Frame Size is: 44 bytes
Logging direction is down (value= 255)
optical Log Depth Scale Units: Feet
Frame spacing: 0.500000
Frame spacing units: [F ]
Number of frames per record is:
One depth per frame (value= 0)
Datum Specification Block Sub-type is:
23
1
FRAME SPACE = 0.500 * F
ONE DEPTH PER FRAME
Tape depth ID: F
10 Curves:
Name Tool Code Samples Units Size Length
1 GR MWD 68 1 GAP I 4 4
2 RPD MWD 68 1 OHMM 4 4
3 RPS MWD 68 1 OHMM 4 4
4 RHOB MWD 68 1 G/C3 4 4
5 DRHO MWD 68 1 G/C3 4 4
6 PEF MWD 68 1 BN/E 4 4
~
7 NPHI MWD 1 PU-S 4 4
8 ROP MWD 68 1 FPHR 4 4
9 FET MWD 68 1 HR 4 4
10 MTEM MWD 68 1 DEGF 4 4
-------
40
Total Data Records: 501
Tape File Start Depth 191.000000
Tape File End Depth 5950.000000
Tape File Level Spacing = 0.500000
Tape File Depth Units = feet
**** FILE TRAILER ****
Tape Subfile: 2
549 records...
Minimum record length:
Maximum record length:
8 bytes
4124 bytes
**** FILE HEADER ****
LDWG
.002
1024
*** LIS COMMENT RECORD ***
!!!!!!!!!!!!!!!!!! !
!!!!!!!!!!!!!!!!!! !
FILE HEADER
FILE NUMBER:
RAW MWD
Curves and
BIT RUN NO:
DEPTH INCREMENT:
#
FILE SUMMARY
VENDOR TOOL CODE
MWD
$
LDWG File Version 1.000
Extract File: FILE011.HED
2
..------...
log header data for each bit run in separate files.
1
.2500
START DEPTH
191. 0
STOP DEPTH
2207.0
#
LOG HEADER DATA
DATE LOGGED:
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
VENDOR TOOL CODE
DIR
GRAM
$
BOTTOM)
TOOL TYPE
DIRECTIONAL
GAMMA RAY
#
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT):
#
BOREHOLE CONDITIONS
MUD TYPE:
22-FEB-02
MSB 18704
6.75 MAP
MEMORY
2251.0
191. 0
2207.0
0
.0
19.5
TOOL NUMBER
DAS 7071
1211
9.625
110.0
F.W. Spud
r-----.
MUD DENSI'l. (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 TEMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
#
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
#
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
#
REMARKS:
BIT RUN 1 (MWD Run 1).
GR-Directional.
CURVE GLOSSARY:
GRAM - GAMMA RAY APPARENT (MWD-API)
ROPS - RATE OF PENETRATION (FPHR)
$
#
*** INFORMATION TABLE: CONS
MNEM VALU
------------------------------
WDFN
LCC
CN
WN
FN
COUN
STAT
2p4 51. xtf
150
Phillips Alaska, Inc.
2P-451
Meltwater
North Slope
Alaska
*** INFORMATION TABLE: CIFO
MNEM CHAN DIMT CNAM
ODEP
GRAM
ROPS
----------------------------------------------------
GRAM
ROPS
GRAM
ROPS
0.0
0.0
* FORMAT RECORD
(TYPE# 64)
Data record type is: 0
Datum Frame Size is: 12 bytes
Logging direction is down (value= 255)
Optical Log Depth Scale Units: Feet
Frame spacing: 0.250000
Frame spacing units: [F ]
Number of frames per record is:
One depth per frame (value= 0)
Datum Specification Block Sub-type is:
84
1
FRAME SPACE =
0.250 * F
ONE DEPTH PER FRAME
Tape depth ID: F
2 Curves:
Name
Tool
Code Samples Units
Length
Size
1
2
68
68
1
1
GAP I
FPHR
4
4
GRAM
ROPS
MWD
MWD
-------
8
,..-----..,
9.
.0
.0
6500
.0
.000
.000
.000
.000
.00
.000
.0
4
4
60.0
.0
.0
.0
0
~
...---...
Total Data Recol,_:
97
Tape File Start Depth 191.000000
Tape File End Depth 2207.000000
Tape File Level Spacing = 0.250000
Tape File Depth Units = feet
**** FILE TRAILER ****
Tape Subfile: 3
170 records...
Minimum record length:
Maximum record length:
8 bytes
4124 bytes
**** FILE HEADER ****
LDWG
.003
1024
*** LIS COMMENT RECORD ***
!!!!!!!!!!!!!!!!!! !
!!!!!!!!!!!!!!!!!! !
FILE HEADER
FILE NUMBER:
RAW MWD
Curves and
BIT RUN NO:
DEPTH INCREMENT:
#
FILE SUMMARY
VENDOR TOOL CODE
MWD
$
LDWG File Version 1.000
Extract File: FILEO12.HED
3
log header data for each bit run in separate files.
2
.2500
START DEPTH
2207.0
STOP DEPTH
4872.0
#
LOG HEADER DATA
DATE LOGGED:
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:
28-FEB-02
MSB 18704
4.75 TC
MEMORY
4928.0
2207.0
4872.0
0
7.7
19.5
#
TOOL STRING (TOP TO
VENDOR TOOL CODE
DIR
CCN
ORD
MPR
GRAM
$
BOTTOM)
TOOL TYPE
DIRECTIONAL
CAL. COR. NEUTRON
OPT. ROT. DENSITY
MULT. PROP. RESIS.
GAMMA RAY
TOOL NUMBER
DAS 1363
SDN 45227
SDN 45227
MPR 1088
SRIG 2116
#
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT):
6.750
2236.0
#
BOREHOLE CONDITIONS
MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S):
MUD PH:
MUD CHLORIDES (PPM):
KCL Polymer
9.60
.0
.0
29000
~
~
FLUID LOS~ ,C3):
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TEMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
.000
.000
.000
.000
#
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
#
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
#
Sandstone
0.00
.000
.0
0
REMARKS:
BIT RUN 2 (MWD Run 2).
GR/MPR/oRD/cCN.
CURVE GLOSSARY:
GRAM - GAMMA RAY APPARENT (MWÐ-API)
RPCL - DEEP PHASE RESISTIVITY (OHMM)
RPCH - SHALLOW PHASE RESISTIVITY (OHMM)
BDCM - BULK DENSITY COMPENSATED (G/CC)
DRHM - DENSITY CORRECTION (G/CC)
DPEM - PHOTOELECTRIC CROSS SECTION (B/E)
NPCK - NEUTRON POROSITY, CALIPER & SALINITY
CORRECTED (SANDSTONE PU)
ROPS - RATE OF PENETRATION (FPHR)
RPTH - FORMATION EXPOSURE TIME (MIN)
TCDM - TEMPERATURE (DEGF)
PER PHILLIPS ALASKA (WAYNE CAMPAIGN), THE
FOLLOWING CURVES ARE NOT PRESENTED ON THE
MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR
THE SAKE OF COMPLETENESS:
RACL - DEEP ATTENUATION RESISTIVITY (OHMM)
RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM)
$
#
*** INFORMATION TABLE: CONS
MNEM VALU
------------------------------
WDFN
LCC
CN
WN
FN
COUN
STAT
2p4 51. xU
150
Phillips Alaska, Inc.
2P-451
Meltwater
North Slope
Alaska
*** INFORMATION TABLE: CIFO
MNEM CHAN DIMT CNAM
ODEP
----------------------------------------------------
GRAM GRAM GRAM 0.0
RPCL RPCL RPD 0.0
RPCH RPCH RPS 0.0
RACL RACL RAD 0.0
RACH RACH RAS 0.0
BDCM BDCM BDCM 0.0
DRHM DRHM DRHM 0.0
DPEM DPEM DPEM 0.0
NPCK NPCK NPCKSM 0.0
ROPS ROPS ROPS 0.0
RPTH RPTH RPTHM 0.0
TCDM TCDM TCDM 0.0
* FORMAT RECORD (TYPE# 64)
Data record type is: 0
Datum Frame Size is: 52 bytes
Logging direction is down (value= 255)
Optical Log Depth Scale Units: Feet
96.0
.0
.0
.0
..---.'
~------....
Frame spacing: -.250000
Frame spacing units: [F ]
Number of frames per record is:
One depth per frame (value= 0)
Datum Specification Block Sub-type is:
19
1
FRAME SPACE =
0.250 * F
ONE DEPTH PER FRAME
Tape depth ID: F
12 Curves:
Name Tool Code Samples units Size Length
1 GRAM MWD 68 1 GAP I 4 4
2 RPCL MWD 68 1 OHMM 4 4
3 RPCH MWD 68 1 OHMM 4 4
4 RACL MWD 68 1 OHMM 4 4
5 RACH MWD 68 1 OHMM 4 4
6 BDCM MWD 68 1 G/C3 4 4
7 DRHM MWD 68 1 G/C3 4 4
8 DPEM MWD 68 1 BN/E 4 4
9 NPCK MWD 68 1 PU-S 4 4
10 RaPS MWD 68 1 FPHR 4 4
11 RPTH MWD 68 1 MINS 4 4
12 TCDM MWD 68 1 DEGF 4 4
-------
48
Total Data Records: 562
Tape File Start Depth 2207.000000
Tape File End Depth 4872.000000
Tape File Level Spacing = 0.250000
Tape File Depth Units = feet
**** FILE TRAILER ****
Tape Subfile: 4
664 records...
Minimum record length:
Maximum record length:
8 bytes
4124 bytes
**** FILE HEADER ****
LDWG
.004
1024
*** LIS COMMENT RECORD ***
!!!!! ! ! ! !!!!!!!!!!!
!!!!!!!!!!!!!!!!!! !
FILE HEADER
FILE NUMBER:
RAW MWD
Curves and
BIT RUN NO:
DEPTH INCREMENT:
#
FILE SUMMARY
VENDOR TOOL CODE
MWD
$
LDWG File Version 1.000
Extract File: FILEOI3.HED
4
log header data for each bit run in separate files.
2R
.2500
START DEPTH
4872.0
STOP DEPTH
5950.0
#
LOG HEADER DATA
DATE LOGGED:
OI-MAR-02
~
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
VENDOR TOOL CODE
DIR
CCN
ORD
MPR
GRAM
$
#
BOTTOM)
TOOL TYPE
DIRECTIONAL
CAL. COR. NEUTRON
OPT. ROT. DENSITY
MULT. PROP. RESIS.
GAMMA RAY
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 TEMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
#
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
#
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
#
REMARKS:
#
~
MSB 18704
4.75 TC
MEMORY
5950.0
4872.0
5950.0
0
1.0
19.5
TOOL NUMBER
DAS 1434
SDN 44706
SDN 44706
MPR 1073
SRIG 2117
6.750
2236.0
KCL Polymer
9.60
.0
.0
29000
.0
.000
.000
.000
.000
96.0
.0
.0
.0
Sandstone
0.00
.000
.0
0
BIT RUN 2R (MWD Run 3).
GR/MPR/oRD/cCN.
CURVE GLOSSARY:
GRAM - GAMMA RAY APPARENT (MWD-API)
RPCL - DEEP PHASE RESISTIVITY (OHMM)
RPCH - SHALLOW PHASE RESISTIVITY (OHMM)
BDCM - BULK DENSITY COMPENSATED (G/CC)
DRHM - DENSITY CORRECTION (G/CC)
DPEM - PHOTOELECTRIC CROSS SECTION (B/E)
NPCK - NEUTRON POROSITY, CALIPER & SALINITY
CORRECTED (SANDSTONE PU)
ROPS - RATE OF PENETRATION (FPHR)
RPTH - FORMATION EXPOSURE TIME (MIN)
TCDM - TEMPERATURE (DEGF)
PER PHILLIPS ALASKA (WAYNE CAMPAIGN), THE
FOLLOWING CURVES ARE NOT PRESENTED ON THE
MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR
THE SAKE OF COMPLETENESS:
RACL - DEEP ATTENUATION RESISTIVITY (OHMM)
RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM)
$
*** INFORMATION TABLE: CONS
MNEM VALU
WDFN
2p451.xtf
------------------------------
,,--..,
LCC
CN
WN
FN
COUN
STAT
150
Phillips Alaska, Inc.
2P-451
Meltwater
North Slope
Alaska
*** INFORMATION TABLE: CIFO
MNEM CRAN DIMT CNAM
ODEP
----------------------------------------------------
GRAM GRAM GRAM 0.0
RPCL RPCL RPD 0.0
RPCH RPCH RPS 0.0
RACL RACL RAD 0.0
RACH RACH RAS 0.0
BDCM BDCM BDCM 0.0
DRHM DRHM DRHM 0.0
DPEM DPEM DPEM 0.0
NPCK NPCK NPCKSM 0.0
ROPS ROPS ROPS 0.0
RPTH RPTH RPTHM 0.0
TCDM TCDM TCDM 0.0
* FORMAT RECORD (TYPE# 64)
Data record type is: 0
Datum Frame Size is: 52 bytes
Logging direction is down (value= 255)
Optical Log Depth Scale Units: Feet
Frame spacing: 0.250000
Frame spacing units: [F ]
Number of frames per record is:
One depth per frame (value= 0)
Datum Specification Block Sub-type is:
19
1
FRAME SPACE = 0.250 * F
ONE DEPTH PER FRAME
Tape depth ID: F
12 Curves:
Name Tool Code Samples Units Size Length
1 GRAM MWD 68 1 GAP I 4 4
2 RPCL MWD 68 1 OHMM 4 4
3 RPCH MWD 68 1 OHMM 4 4
4 RACL MWD 68 1 OHMM 4 4
5 RACH MWD 68 1 OHMM 4 4
6 BDCM MWD 68 1 G/C3 4 4
7 DRHM MWD 68 1 G/C3 4 4
8 DPEM MWD 68 1 BN/E 4 4
9 NPCK MWD 68 1 PU-S 4 4
10 ROPS MWD 68 1 FPHR 4 4
11 RPTH MWD 68 1 MINS 4 4
12 TCDM MWD 68 1 DEGF 4 4
-------
48
Total Data Records: 227
Tape File Start Depth 4872.000000
Tape File End Depth 5950.000000
Tape File Level Spacing = 0.250000
Tape File Depth Units = feet
**** FILE TRAILER ****
Tape Subfile: 5
329 records...
Minimum record length:
8 bytes
~
- .
r----,
Maximum record length.
**** TAPE TRAILER ****
LDWG
03/10/22
01
**** REEL TRAILER ****
LDWG
03/10/22
AWS
01
Tape Subtile: 6
Minimum record length:
Maximum record length:
~.
4124 bytes
2 records...
132 bytes
132 bytes
