Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout198-229ORIGINATED
TRANSMITTAL
DATE: 3/18/2025
ALASKA E-LINE SERVICES
TRANSMITTAL
#: 5329
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
5329 1C-15 50029229320000 Injection Profile (IPROF) 5-Mar-2025
RECIPIENTS
Conoco
DIGITAL FILES PRINTS CD'S
1 FTP Transfer 0 0 USPS
Attn: NSK-69
Richard.E.Elgarico@conocophillips.com 700 G Street
lorna.c.collins@conocophillips.com Anchorage, AK 99503
Received
By: Received By:
Signature Signature
AOGCC
DIGITAL FILES PRINTS CD'S
1 ShareFile 0 0 USPS
Attn: Natural Resources Technician II
abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision
aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501
Received
By: Received By:
Signature Signature
198-229
T40215
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2025.03.18 09:29:15 -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
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Friday, December 13, 2024
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Brian Bixby
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
ConocoPhillips Alaska, Inc.
1C-15
KUPARUK RIV UNIT 1C-15
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 12/13/2024
1C-15
50-029-22932-00-00
198-229-0
W
SPT
6416
1982290 1604
1698 1699 1702 1702
480 640 640 640
OTHER P
Brian Bixby
10/18/2024
MITIA as per SUNDRY 324-009
30 MinPretestInitial15 Min
Well Name
Type Test
Notes:
Interval P/F
Well
Permit Number:
Type Inj TVD
PTD Test psi
API Well Number Inspector Name:KUPARUK RIV UNIT 1C-15
Inspection Date:
Tubing
OA
Packer Depth
790 2610 2540 2520IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitBDB241019121548
BBL Pumped:2.3 BBL Returned:2.2
Friday, December 13, 2024 Page 1 of 1
9
9
9
9
9 9
999
9 9
99
9
9
9
SUNDRY 324-009
James B. Regg Digitally signed by James B. Regg
Date: 2024.12.13 16:28:52 -09'00'
1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown
Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program
Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Pull LT Packer
Development Exploratory
Stratigraphic Service 6. API Number:
7. Property Designation (Lease Number): 8. Well Name and Number:
9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s):
11. Present Well Condition Summary:
Total Depth measured 9390'feet None feet
true vertical 6840' feet None feet
Effective Depth measured 9320'feet 8919'feet
true vertical 6777' feet 6417' feet
Perforation depth Measured depth
True Vertical depth
Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 8976' MD
Packers and SSSV (type, measured and true vertical depth) 8919' MD
2019' MD
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure: N/A
13a.
Prior to well operation:
Subsequent to operation:
13b. Pools active after work: Kuparuk River Oil Pool
15. Well Class after work:
Daily Report of Well Operations Exploratory Development Service Stratigraphic
Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL
Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG
Sundry Number or N/A if C.O. Exempt:
Authorized Name and
Digital Signature with Date: Contact Name:
Contact Email:
Authorized Title: Contact Phone:
6249' 4488'
Burst Collapse
Production
Liner
9354'
Casing
6209'
121'Conductor
Surface
Intermediate
16"
9-5/8"
80'
measured
TVD
7"
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
198-229
50-029-22932-00-00
P.O. Box 100360
Anchorage, AK 99510
3. Address:
ConocoPhillips Alaska, Inc.
N/A
5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work:
ADL0028242
Kuparuk River Field/ Kuparuk River Oil Pool
KRU 1C-15
Plugs
Junk measured
Length
measured
true vertical
Packer
Representative Daily Average Production or Injection Data
Casing Pressure Tubing Pressure
14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283)
~
Gas-Mcf
MD
~
Size
121'
~ ~~
INJECTOR ~~
~
324-009
Sr Pet Eng: Sr Pet Geo: Sr Res Eng:
WINJ WAG
~
Water-BblOil-Bbl
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
N/A
Packer: Baker S-3 Perm Packer
SSSV: Camco TRDP-4E Sfty Vlv (locked
Allen Echete
allen.eschete@conocophillips.com
(907) 265-6558Intervention Engineer
9096-9141'
6576-6616'
Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov
9393' 6843'
6468' TVD
6417' TVD
1796' TVD
By Grace Christianson at 3:00 pm, Apr 22, 2024
Digitally signed by Allen Eschete
DN: CN=Allen Eschete, E=Allen.Eschete@
ConocoPhillips.com
Reason: I am the author of this document
Location:
Date: 2024.04.22 08:29:42-08'00'
Foxit PDF Editor Version: 13.0.0
Allen Eschete
DSR-4/23/24
DTTMSTART JOBTYP SUMMARYOPS
3/7/2024 OPTIMIZE
WELL
DRIFT TBG W/ 2.5" CENT, 1.75" S-BAILER TO LINER TOP PACKER @ 8840' RKB, NO
OBSTRUCTIONS FOUND. LDFN, JOB IN PROGRESS.
3/8/2024 OPTIMIZE
WELL
MEASURE SBHP 5005 psi @ 8840' RKB, DRIFTED TBG W/ 2.75" GAUGE RING TO LTP
@ 8840' RKB. LDFN, JOB IN PROGRESS.
3/12/2024 OPTIMIZE
WELL
MADE ATTEMPT TO PULL LTP @ 8840' RKB, SHEARED PULLING TOOL. RDMO TEMP -
36. JOB IN PROGRESS.
3/15/2024 OPTIMIZE
WELL
ATTEMPT TO PULL LTP @ 8840' RKB, JOB IN PROGRESS
3/16/2024 OPTIMIZE
WELL
ATTEMPT TO PULL LTP @ 8840' RKB, JOB SUSPENDED, WIll RETURN WITH .160
WIRE.
3/26/2024 OPTIMIZE
WELL
ATTEMPT TO PULL LTP W/ .160 WIRE @ 8840'RKB. JOB IN PROGRESS
3/28/2024 OPTIMIZE
WELL
PULLED LINER TOP PACKER ASSEMBLY @ 8840'RKB, RECOVERED ELEMENT
DEBRIS FROM 8840'RKB. JOB COMPLETE
1C-15 Remove Liner Top Packer
Summary of Operations
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag: SLM 9,320.0 1C-15 12/7/2011 ninam
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Pulled LTP 1C-15 3/28/2024 rogerba
Notes: General & Safety
Annotation End Date Last Mod By
NOTE: View Schematic w/ Alaska Schematic9.0 11/17/2010 ninam
NOTE: 1C-15L1 DRILLED 4/15/03, 1C-15 PERFS LEFT OPEN 1C-15L1 4/15/2003 WV5.3
Conversio
n
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 41.0 121.0 121.0 62.58 H-40 WELDED
SURFACE 9 5/8 8.83 40.4 6,249.3 4,488.5 40.00 L-80 BTC
PRODUCTION 7 6.28 38.5 9,392.7 26.00 L-80 ABM-BTC
WINDOW L1 7 6.00 9,142.0 9,147.0 6,621.5 26.00 L-80
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
36.6
Set Depth
8,976.5
Set Depth
6,468.1
String Max No
3 1/2
Tubing Description
TUBING
Wt (lb/ft)
9.30
Grade
L-80
Top Connection
ABM-EUE
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)
36.6 36.6 0.00 HANGER 8.000 FMC GEN IV TUBING HANGER 3.500
2,019.3 1,796.2 49.18 SAFETY VLV 5.250 CAMCO TRDP-4E SAFETY VALVE
(LOCKED OUT 7/16/2004)
2.812
3,324.9 2,602.4 51.58 GAS LIFT 5.500 CAMCO KBMM 2.920
5,349.2 3,907.5 50.32 GAS LIFT 5.500 CAMCO KBMM 2.920
6,592.1 4,709.3 49.76 GAS LIFT 5.500 CAMCO KBMM 2.920
7,553.6 5,339.8 48.22 GAS LIFT 5.500 CAMCO KBMM 2.920
8,330.6 5,905.9 35.35 GAS LIFT 5.500 CAMCO KBMM 2.920
8,826.5 6,333.3 26.13 GAS LIFT 5.500 CAMCO MMM 2.371
8,876.2 6,377.9 26.07 NIPPLE 4.540 CAMCO W NIPPLE 2.812
8,919.3 6,416.7 26.08 PACKER 5.968 BAKER S-3 PERMANENT PACKER 3.875
8,964.5 6,457.3 25.98 NIPPLE 4.470 CAMCO D NIPPLE 2.75" ID -
MILLED OUT TO 2.80" ID 2/5/2003
2.800
8,975.6 6,467.3 25.94 SOS 4.520 BAKER SHEAR OUT SUB 3.000
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top (ftKB)
Top (TVD)
(ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in)
PATCH SURF CSG PATCH install
from bottom of starter head to
top of pup collar 1' 11.5", used
9 5/8" 40 #, .395 pipe for patch
material
4/10/2009
Mandrel Inserts : excludes pulled inserts
Top (ftKB)
Top (TVD)
(ftKB)
Top
Incl (°)
St
ati
on
No
/S Serv
Valve
Type
Latch
Type
OD
(in)
TRO Run
(psi) Run Date Com Make Model
Port
Size (in)
3,324.9 2,602.4 51.58 1 GAS LIFT DMY BK 1 0.0 7/16/2004 0.000
5,349.2 3,907.5 50.32 2 GAS LIFT DMY BK 1 0.0 7/16/2004 0.000
6,592.1 4,709.3 49.76 3 GAS LIFT DMY BK 1 0.0 7/16/2004 0.000
7,553.6 5,339.8 48.22 4 GAS LIFT DMY BK 1 0.0 7/16/2004 0.000
8,330.6 5,905.9 35.35 5 GAS LIFT DMY BK-5 1 0.0 2/12/2003 0.000
8,826.5 6,333.3 26.13 6 GAS LIFT DMY RK 1 1/2 0.0 7/16/2004 0.000
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
9,096.0 9,106.0 6,575.6 6,584.6 C-4, 1C-15 2/17/2002 6.0 APERF 2.5" HSD PJ Chgs, 60 deg
phase
9,106.0 9,126.0 6,584.6 6,602.7 C-3, 1C-15 12/30/1998 4.0 IPERF 2.5" HC DP
9,126.0 9,141.0 6,602.7 6,616.2 C-3, 1C-15 2/17/2002 6.0 APERF 2.5" HSD PJ 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)
9,096.0 9,142.0 1 FRAC 1/11/1999 0.0 0.00 0.00
Cement Squeezes
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Des Com
Pump Start
Date
9,141.0 9,390.0 6,616.2 Kickoff Plug cement plug bottom to 9141rkb 3/28/2003
1C-15, 4/16/2024 2:49:42 PM
Vertical schematic (actual)
L2 lateral; 8,953.0-12,235.0
PRODUCTION; 38.5-9,392.7
WINDOW L1; 9,142.0-9,147.0
LINER; 8,845.3-11,111.0
Kickoff Plug; 9,141.0 ftKB
APERF; 9,126.0-9,141.0
FRAC; 9,096.0
IPERF; 9,106.0-9,126.0
WHIPSTOCK; 9,108.0
APERF; 9,096.0-9,106.0
PACKER; 8,919.3
GAS LIFT; 8,330.6
GAS LIFT; 7,553.6
GAS LIFT; 6,592.1
SURFACE; 40.4-6,249.3
GAS LIFT; 5,349.2
GAS LIFT; 3,324.9
SAFETY VLV; 2,019.3
CONDUCTOR; 41.0-121.0
KUP INJ
KB-Grd (ft)
46.51
RR Date
12/15/199
8
Other Elev
1C-15
...
TD
Act Btm (ftKB)
9,390.0
Well Attributes
Field Name
KUPARUK RIVER UNIT
Wellbore API/UWI
500292293200
Wellbore Status
INJ
Max Angle & MD
Incl (°)
52.92
MD (ftKB)
2,783.33
WELLNAME WELLBORE1C-15
Annotation
Last WO:
End DateH2S (ppm) DateComment
SSSV: LOCKED OUT
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag: SLM 9,348.0 1C-15L1 6/28/2019 hazenmc
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: CUT LINER 1C-15L1 2/4/2022 bworthi1
Notes: General & Safety
Annotation End Date Last Mod By
NOTE: (Multi-Lat) 1C-15L1 DRILLED 4/15/2003, EXITS TO C-SANDS THRU ORIGINAL WELLBORE
1C-15 CMT PLUG
4/15/2003 lmosbor
NOTE: EXITS TO C-SANDS THRU CMT PLUG IN 1C-15 WELLBORE; PRODUCE THRU BOTH LEGS 4/15/2003 WV5.3
Conversio
n
Casing Strings
Csg Des OD (in) ID (in) Top (ftKB)
Set Depth
(ftKB)
Set Depth
(TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread
LINER 2.38 1.92 8,845.3 11,111.0 4.43 L-80 STL
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)
9,108.0 6,586.4 25.80 WHIPSTOCK NS HEW 8.75' long Northern
Solutions
HE 3/16/2022 0.000
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)
8,845.3 6,350.2 26.05 DEPLOY 2.700 BAKER DEPLOYMENT SLEEVE
w/ 3" GS
2.250
11,072.7 O-RING 1.380 BAKER O-RING SUB 1.000
11,105.4 XO THREAD 2.380 XO 1.920
11,108.9 XO THREAD 2.380 XO 1.900
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
10,344.0 11,075.0 C-3, C-4, C-3,
1C-15L1
4/12/2003 4.0 SLOTS SLOTTED LINER
1C-15L1, 4/16/2024 2:49:43 PM
Vertical schematic (actual)
LINER; 8,845.3-11,111.0
SLOTS; 10,344.0-11,075.0
L2 lateral; 8,953.0-12,235.0
PRODUCTION; 38.5-9,392.7
Kickoff Plug; 9,141.0 ftKB
APERF; 9,126.0-9,141.0
FRAC; 9,096.0
IPERF; 9,106.0-9,126.0
WHIPSTOCK; 9,108.0
APERF; 9,096.0-9,106.0
PACKER; 8,919.3
GAS LIFT; 8,330.6
GAS LIFT; 7,553.6
GAS LIFT; 6,592.1
SURFACE; 40.4-6,249.3
GAS LIFT; 5,349.2
GAS LIFT; 3,324.9
SAFETY VLV; 2,019.3
CONDUCTOR; 41.0-121.0
KUP INJ
KB-Grd (ft)
46.51
RR Date
12/15/199
8
Other Elev
1C-15L1
...
TD
Act Btm (ftKB)
11,207.0
Well Attributes
Field Name
KUPARUK RIVER UNIT
Wellbore API/UWI
500292293260
Wellbore Status
INJ
Max Angle & MD
Incl (°)
52.92
MD (ftKB)
2,783.33
WELLNAME WELLBORE1C-15
Annotation
Last WO:
End Date
4/13/2003
H2S (ppm) DateComment
SSSV: LOCKED OUT
Casing Strings
Csg Des OD (in) ID (in) Top (ftKB)
Set Depth
(ftKB)
Set Depth
(TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread
L2 lateral 2 3/8 1.99 8,953.0 12,235.0 6,566.7 4.70 L-80 ST-L
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)
9,241.6 6,660.8 85.97 Swell Packer 2.700 Swell Packer - Reactive Reactive Swell Pkr. 1.686
10,118.5 6,588.3 85.52 Deployment
Sleeve
2.375 NSAK 350-238, QCLL Receptical
- L80
Northern
Solutions
1.920
11,192.9 6,599.4 92.89 Deployment
Sleeve
2.375 NSAK 350-238, QCLL Receptical
- L80
Northern
Solutions
1.920
1C-15L2, 4/16/2024 2:49:43 PM
Vertical schematic (actual)
L2 lateral; 8,953.0-12,235.0
PRODUCTION; 38.5-9,392.7
WINDOW L1; 9,142.0-9,147.0
LINER; 8,845.3-11,111.0
Kickoff Plug; 9,141.0 ftKB
APERF; 9,126.0-9,141.0
FRAC; 9,096.0
IPERF; 9,106.0-9,126.0
WHIPSTOCK; 9,108.0
APERF; 9,096.0-9,106.0
PACKER; 8,919.3
GAS LIFT; 8,330.6
GAS LIFT; 7,553.6
GAS LIFT; 6,592.1
SURFACE; 40.4-6,249.3
GAS LIFT; 5,349.2
GAS LIFT; 3,324.9
SAFETY VLV; 2,019.3
CONDUCTOR; 41.0-121.0
KUP INJ
KB-Grd (ft)
46.51
RR Date
12/15/199
8
Other Elev
1C-15L2
...
TD
Act Btm (ftKB)
12,784.0
Well Attributes
Field Name
KUPARUK RIVER UNIT
Wellbore API/UWI
500292293261
Wellbore Status
INJ
Max Angle & MD
Incl (°)
103.09
MD (ftKB)
9,278.41
WELLNAME WELLBORE1C-15
Annotation End DateH2S (ppm) DateComment
1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown
Suspend Perforate Other Stimulate Pull Tubing Change Approved Program
Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Pull LT Packer
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.
Effective Depth MD: Effective Depth TVD: Junk (MD):
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) 265-6558
Interventions Engineer
KRU 1C-15
9141' 6616' 9141'
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:
allen.eschete@conocophillips.com
AOGCC USE ONLY
Tubing Grade: Tubing MD (ft):
8919' MD and 6417' TVD
8840' MD and 6345' TVD
2019' MD and 1796' TVD
Allen Eschete
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL0028242
198-229
P.O. Box 100360, Anchorage, AK 99510 50-029-22932-00-00
Kuparuk River Field Kuprauk River Oil Pool
ConocoPhillips Alaska, Inc.
Length Size
Proposed Pools:
PRESENT WELL CONDITION SUMMARY
Kuparuk River Oil Pool
TVD Burst
8976'
MD
121'
4488'
121'
6249'
16"
9-5/8"
80'
6209'
9096-9141'
9354'
6576-6616'
7"
Perforation Depth TVD (ft):
1/23/2024
3-1/2"
Packer: Baker S-3 Perm Packer
Packer: NS AK Mono-Pak LT Packer
SSSV: Camco TRDP-4E Safety Valve
(Locked out)
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
9393'6843'
Total Depth MD (ft):
9393'
Total Depth TVD (ft):
6843'
By Grace Christianson at 8:07 am, Jan 11, 2024
Digitally signed by Allen Eschete
DN: CN=Allen Eschete, E=Allen.Eschete@ConocoPhillips.com
Reason: I am the author of this document
Location:
Date: 2024.01.09 13:15:52-09'00'
Foxit PDF Editor Version: 13.0.0
Allen Eschete
324-009
*Per Well Completion Report received 3/20/99 SFD
SFD 1/12/2024
X
DSR-2/15/24
6840'*
VTL 02/15/2024
SFD ADL0025649,
6840'*9390'*1400
10-404
X
9390'*
*&:JLC 2/15/2024
Brett W. Huber,
Sr.
Digitally signed by Brett W.
Huber, Sr.
Date: 2024.02.15 18:04:06
-06'00'02/15/24
RBDMS JSB 022124
KRU 1C-15 (PTD 198-229), KRU 1C-15L1 (PTD203-032), KRU 1C-15L2 (PTD 222-029)
Well Work Jus ca on & Objec ves
1C-15 is a dual lateral CTD injector. The L2 lateral was drilled in April 2023, and a liner top packer was set
to shut o the original L1 and focus injec#on into L2. Performance over the past year has been
lackluster, and we want to reopen the L1 lateral to allow injec#on into both zones. This procedure is to
harvest a SBHP in the isolated L2 fault block to help diagnose performance in this zone, before pulling
the LTP to allow WAG injec#on into both laterals.
Risks/Job Concerns
• Min ID (1.781") is Northern Solu#ons AK Mono-Pak Liner Top Packer with 1.781" RX nipple @
8840' RKB
• Last tag was in L2 during CT FCO. Note break in liner in L2 from 10,002' to 10,118' RKB
• Max inclina#on and dog leg are given for L2 liner, no need to access these during this work.
Slickline
1. Verify with PE that well has been SI for 3 days minimum (72 hours)
2. MIRU SL, D&T with bailer as deep as possible. Note tag depth, suspected reasons for high tag,
nature of Dll/bailer returns, and any other details in WSR, as applicable.
3. Obtain SBHP with dual SPARTEK gauges
a) Perform 10 minute lubricator stop
b) 30 minute stop @ 8840' RKB (6345' TVD)
c) Pull up 100' TVD to 8728' RKB (6245' TVD) for 15 minute gradient stop
d) Record Dndings on WSR
4. Pull Northern Solu#ons AK Mono-Pak Liner Top Packer from top of liner at 8840' RKB.
5. POOH, RD. Return well to DSO to BOL when ready.
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag: SLM 9,320.0 1C-15 12/7/2011 ninam
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Set Liner Top Packer 1C-15 3/30/2022 zembaej
Notes: General & Safety
Annotation End Date Last Mod By
NOTE: View Schematic w/ Alaska Schematic9.0 11/17/2010 ninam
NOTE: 1C-15L1 DRILLED 4/15/03, 1C-15 PERFS LEFT OPEN 1C-15L1 4/15/2003 WV5.3
Conversio
n
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 41.0 121.0 121.0 62.58 H-40 WELDED
SURFACE 9 5/8 8.83 40.4 6,249.3 4,488.5 40.00 L-80 BTC
PRODUCTION 7 6.28 38.5 9,392.7 26.00 L-80 ABM-BTC
WINDOW L1 7 6.00 9,142.0 9,147.0 6,621.5 26.00 L-80
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
36.6
Set Depth …
8,976.5
Set Depth …
6,468.1
String Max No…
3 1/2
Tubing Description
TUBING
Wt (lb/ft)
9.30
Grade
L-80
Top Connection
ABM-EUE
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)
36.6 36.6 0.00 HANGER 8.000 FMC GEN IV TUBING HANGER 3.500
2,019.3 1,796.2 49.18 SAFETY VLV 5.250 CAMCO TRDP-4E SAFETY VALVE
(LOCKED OUT 7/16/2004)
2.812
3,324.9 2,602.4 51.58 GAS LIFT 5.500 CAMCO KBMM 2.920
5,349.2 3,907.5 50.32 GAS LIFT 5.500 CAMCO KBMM 2.920
6,592.1 4,709.3 49.76 GAS LIFT 5.500 CAMCO KBMM 2.920
7,553.6 5,339.8 48.22 GAS LIFT 5.500 CAMCO KBMM 2.920
8,330.6 5,905.9 35.35 GAS LIFT 5.500 CAMCO KBMM 2.920
8,826.5 6,333.3 26.13 GAS LIFT 5.500 CAMCO MMM 2.371
8,876.2 6,377.9 26.07 NIPPLE 4.540 CAMCO W NIPPLE 2.812
8,919.3 6,416.7 26.08 PACKER 5.968 BAKER S-3 PERMANENT PACKER 3.875
8,964.5 6,457.3 25.98 NIPPLE 4.470 CAMCO D NIPPLE 2.75" ID -
MILLED OUT TO 2.80" ID 2/5/2003
2.800
8,975.6 6,467.3 25.94 SOS 4.520 BAKER SHEAR OUT SUB 3.000
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top (ftKB)
Top (TVD)
(ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in)
8,840.0 6,345.4 26.05 PACKER Set NothernSolutions AK
Mono-Pak Liner Top Packer w/
1.781" RX nipple @ 8848'
RKB (See Attachments)
A2242
7201-
R00
3/30/2022 1.781
PATCH SURF CSG PATCH install
from bottom of starter head to
top of pup collar 1' 11.5", used
9 5/8" 40 #, .395 pipe for patch
material
4/10/2009
Mandrel Inserts : excludes pulled inserts
Top (ftKB)
Top (TVD)
(ftKB)
Top
Incl (°)
St
ati
on
No
/S Serv
Valve
Type
Latch
Type
OD
(in)
TRO Run
(psi) Run Date Com Make Model
Port
Size (in)
3,324.9 2,602.4 51.58 1 GAS LIFT DMY BK 1 0.0 7/16/2004 0.000
5,349.2 3,907.5 50.32 2 GAS LIFT DMY BK 1 0.0 7/16/2004 0.000
6,592.1 4,709.3 49.76 3 GAS LIFT DMY BK 1 0.0 7/16/2004 0.000
7,553.6 5,339.8 48.22 4 GAS LIFT DMY BK 1 0.0 7/16/2004 0.000
8,330.6 5,905.9 35.35 5 GAS LIFT DMY BK-5 1 0.0 2/12/2003 0.000
8,826.5 6,333.3 26.13 6 GAS LIFT DMY RK 1 1/2 0.0 7/16/2004 0.000
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
9,096.0 9,106.0 6,575.6 6,584.6 C-4, 1C-15 2/17/2002 6.0 APERF 2.5" HSD PJ Chgs, 60 deg
phase
9,106.0 9,126.0 6,584.6 6,602.7 C-3, 1C-15 12/30/1998 4.0 IPERF 2.5" HC DP
9,126.0 9,141.0 6,602.7 6,616.2 C-3, 1C-15 2/17/2002 6.0 APERF 2.5" HSD PJ 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)
9,096.0 9,142.0 1 FRAC 1/11/1999 0.0 0.00 0.00
Cement Squeezes
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Des Com
Pump Start
Date
9,141.0 9,390.0 6,616.2 Kickoff Plug cement plug bottom to 9141rkb 3/28/2003
1C-15, 1/9/2024 12:16:52 PM
Vertical schematic (actual)
L2 lateral; 8,953.0-12,235.0
PRODUCTION; 38.5-9,392.7
WINDOW L1; 9,142.0-9,147.0
LINER; 8,845.3-11,111.0
Kickoff Plug; 9,141.0 ftKB
APERF; 9,126.0-9,141.0
FRAC; 9,096.0
IPERF; 9,106.0-9,126.0
WHIPSTOCK; 9,108.0
APERF; 9,096.0-9,106.0
PACKER; 8,919.3
PACKER; 8,840.0
GAS LIFT; 8,330.6
GAS LIFT; 7,553.6
GAS LIFT; 6,592.1
SURFACE; 40.4-6,249.3
GAS LIFT; 5,349.2
GAS LIFT; 3,324.9
SAFETY VLV; 2,019.3
CONDUCTOR; 41.0-121.0
KUP INJ
KB-Grd (ft)
46.51
RR Date
12/15/199
8
Other Elev…
1C-15
...
TD
Act Btm (ftKB)
9,390.0
Well Attributes
Field Name
KUPARUK RIVER UNIT
Wellbore API/UWI
500292293200
Wellbore Status
INJ
Max Angle & MD
Incl (°)
52.92
MD (ftKB)
2,783.33
WELLNAME WELLBORE1C-15
Annotation
Last WO:
End DateH2S (ppm) DateComment
SSSV: LOCKED OUT
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag: SLM 9,348.0 1C-15L1 6/28/2019 hazenmc
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: CUT LINER 1C-15L1 2/4/2022 bworthi1
Notes: General & Safety
Annotation End Date Last Mod By
NOTE: (Multi-Lat) 1C-15L1 DRILLED 4/15/2003, EXITS TO C-SANDS THRU ORIGINAL WELLBORE
1C-15 CMT PLUG
4/15/2003 lmosbor
NOTE: EXITS TO C-SANDS THRU CMT PLUG IN 1C-15 WELLBORE; PRODUCE THRU BOTH LEGS 4/15/2003 WV5.3
Conversio
n
Casing Strings
Csg Des OD (in) ID (in) Top (ftKB)
Set Depth
(ftKB)
Set Depth
(TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread
LINER 2.38 1.92 8,845.3 11,111.0 4.43 L-80 STL
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)
9,108.0 6,586.4 25.80 WHIPSTOCK NS HEW 8.75' long Northern
Solutions
HE 3/16/2022 0.000
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)
8,845.3 6,350.2 26.05 DEPLOY 2.700 BAKER DEPLOYMENT SLEEVE
w/ 3" GS
2.250
11,072.7 O-RING 1.380 BAKER O-RING SUB 1.000
11,105.4 XO THREAD 2.380 XO 1.920
11,108.9 XO THREAD 2.380 XO 1.900
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
10,344.0 11,075.0 C-3, C-4, C-3,
1C-15L1
4/12/2003 4.0 SLOTS SLOTTED LINER
1C-15L1, 1/9/2024 12:16:55 PM
Vertical schematic (actual)
LINER; 8,845.3-11,111.0
SLOTS; 10,344.0-11,075.0
PRODUCTION; 38.5-9,392.7
L2 lateral; 8,953.0-12,235.0
Kickoff Plug; 9,141.0 ftKB
APERF; 9,126.0-9,141.0
FRAC; 9,096.0
IPERF; 9,106.0-9,126.0
WHIPSTOCK; 9,108.0
APERF; 9,096.0-9,106.0
PACKER; 8,919.3
PACKER; 8,840.0
GAS LIFT; 8,330.6
GAS LIFT; 7,553.6
GAS LIFT; 6,592.1
SURFACE; 40.4-6,249.3
GAS LIFT; 5,349.2
GAS LIFT; 3,324.9
SAFETY VLV; 2,019.3
CONDUCTOR; 41.0-121.0
KUP INJ
KB-Grd (ft)
46.51
RR Date
12/15/199
8
Other Elev…
1C-15L1
...
TD
Act Btm (ftKB)
11,207.0
Well Attributes
Field Name
KUPARUK RIVER UNIT
Wellbore API/UWI
500292293260
Wellbore Status
INJ
Max Angle & MD
Incl (°)
52.92
MD (ftKB)
2,783.33
WELLNAME WELLBORE1C-15
Annotation
Last WO:
End Date
4/13/2003
H2S (ppm) DateComment
SSSV: LOCKED OUT
Casing Strings
Csg Des OD (in) ID (in) Top (ftKB)
Set Depth
(ftKB)
Set Depth
(TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread
L2 lateral 2 3/8 1.99 8,953.0 12,235.0 6,566.7 4.70 L-80 ST-L
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)
9,241.6 6,660.8 85.97 Swell Packer 2.700 Swell Packer - Reactive Reactive Swell Pkr. 1.686
10,118.5 6,588.3 85.52 Deployment
Sleeve
2.375 NSAK 350-238, QCLL Receptical
- L80
Northern
Solutions
1.920
11,192.9 6,599.4 92.89 Deployment
Sleeve
2.375 NSAK 350-238, QCLL Receptical
- L80
Northern
Solutions
1.920
1C-15L2, 1/9/2024 12:16:55 PM
Vertical schematic (actual)
L2 lateral; 8,953.0-12,235.0
PRODUCTION; 38.5-9,392.7
WINDOW L1; 9,142.0-9,147.0
LINER; 8,845.3-11,111.0
Kickoff Plug; 9,141.0 ftKB
APERF; 9,126.0-9,141.0
FRAC; 9,096.0
IPERF; 9,106.0-9,126.0
WHIPSTOCK; 9,108.0
APERF; 9,096.0-9,106.0
PACKER; 8,919.3
PACKER; 8,840.0
GAS LIFT; 8,330.6
GAS LIFT; 7,553.6
GAS LIFT; 6,592.1
SURFACE; 40.4-6,249.3
GAS LIFT; 5,349.2
GAS LIFT; 3,324.9
SAFETY VLV; 2,019.3
CONDUCTOR; 41.0-121.0
KUP INJ
KB-Grd (ft)
46.51
RR Date
12/15/199
8
Other Elev…
1C-15L2
...
TD
Act Btm (ftKB)
12,784.0
Well Attributes
Field Name
KUPARUK RIVER UNIT
Wellbore API/UWI
500292293261
Wellbore Status
INJ
Max Angle & MD
Incl (°)
103.09
MD (ftKB)
9,278.41
WELLNAME WELLBORE1C-15
Annotation End DateH2S (ppm) DateComment
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Tuesday, June 14, 2022
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Matt Herrera
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
ConocoPhillips Alaska, Inc.
1C-15
KUPARUK RIV UNIT 1C-15
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 06/14/2022
1C-15
50-029-22932-00-00
198-229-0
W
SPT
6416
1982290 1604
2555 2555 2562 2555
420 535 535 535
4YRTST P
Matt Herrera
5/17/2022
MIT-IA Performed to 1800 PSI Per Operations
30 MinPretestInitial15 Min
Well Name
Type Test
Notes:
Interval P/F
Well
Permit Number:
Type Inj TVD
PTD Test psi
API Well Number Inspector Name:KUPARUK RIV UNIT 1C-15
Inspection Date:
Tubing
OA
Packer Depth
865 1800 1750 1740IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitMFH220518152049
BBL Pumped:1.1 BBL Returned:1
Tuesday, June 14, 2022 Page 1 of 1
9
9
9
9
9
9
9
9
9
9
James B. Regg Digitally signed by James B.
Regg
Date: 2022.06.14 14:05:09 -08'00'
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Originated: Delivered to:8-Apr-22Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL #1 1C-15 50-029-22932-00 907743115 Kuparuk River Multi Finger Caliper Field & Processed 16-Mar-22 0 12 1E-31 50-029-22791-00 907676477 Kuparuk River Packer Setting Record Field- Final 14-Feb-22 0 13 1L-29 50-029-22157-00 907706865 Kuparuk River Plug Setting Record Field- Final 25-Feb-22 0 14 1L-29 50-029-22157-00 n/a Kuparuk River Jet Cut Record Field- Final 14-Nov-21 0 15 2W-09 50-029-21235-00 907723402 Kuparuk River Multi Finger Caliper Field & Processed 1-Mar-22 0 16 2W-09 50-029-21235-00 n/a Kuparuk River Multi Finger Caliper Field & Processed 24-Jan-22 0 17 3B-02 50-029-21319-00 907705186 Kuparuk River Injection Profile Field- Final 23-Feb-22 0 18 3M-05 50-029-21706-00 n/a Kuparuk River Multi Finger Caliper Field & Processed 23-Jan-22 0 19 3Q-04 50-029-22219-00 n/a Kuparuk River Plug Setting Record Field- Final 20-Feb-22 0 110PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:198-229T364561C-1550-029-22932-00Meredith GuhlDigitally signed by Meredith Guhl Date: 2022.04.08 10:24:34 -08'00'
MEMORANDA • State of Alaska
Alaska Oil and Gas Conservation Commission
DATE: Wednesday,May 16,2018
TO: Jim Regg
P.I.Supervisor4./ (i SUBJECT: Mechanical Integrity Tests
[[[[ CONOCOPHILLIPS ALASKA,INC.
1C-15
FROM: Austin McLeod KUPARUK RIV UNIT 1C-15
Petroleum Inspector
Src: Inspector
Reviewed By:
P.I.Supry sgp
NON-CONFIDENTIAL Comm
Well Name KUPARUK RIV UNIT 1C-15 API Well Number 50-029-22932-00-00 Inspector Name: Austin McLeod
Permit Number: 198-229-0 Inspection Date: 5/13/2018 -
Insp Num: mitSAM180514080503
Rel Insp Num:
Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min
Well IC-15 ` TType Inj ®TVD 6416 - Tubing 1610 - 1609 1617 1614 -
PTD 1982290 - Type Test SPT Test psi 1604 IA 880 2405 2340 - 2330
BBL Pumped: 2 ` BBL Returned: 2 OA 570 - 730 - 730 - 730 •
Interval 4YRTST P/F P
Notes: MIT-1A
SCOW JUN 0 1201s
Wednesday,May 16,2018 Page 1 of 1
MEMORANDUM •
TO: Jim Regg ~Q~~ ~ ~ ~ i
P.I. Supervisor
FROM: John Crisp
Petroleum Inspector
State of Alaska •
Alaska Oil and Gas Conservation Commission
DATE: Tuesday, June 08, 2010
SUBJECT: Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA INC
1C-]s
KUPARUK RIV UNIT 1C-15
Src: Inspector
NON-CONFIDENTIAL
Reviewed By:
P.I. Suprv ~~~""
Comm
Well Name: KUPARUK RIV UNIT 1C-ls API Well Number: 50-029-22932-00-00 Inspector Name: John Crisp
Insp Num: mitJCr100524055359 permit Number: 198-229-0 Inspection Date: 5/21/2010
Rel Insp Num:
Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
_- ~ 1C-15 -___?-_.. ~~
Well Type Inj. I ~/ TVD ( 6416 / IA ~ _ s40 I
rt--- ~-
} 19szz9o
bps
"'
SPT
2220 / 2160
6so bso I
2140 ~
6~0
~
vA
i Test psi 1604
~TypeTest ,
P.T.D
--- I ---!- --~-- ---~-----1---~
-- ~ --
P ~ Tubing ~ 1148
4YRTST ,/
Interval P/F I _ 1153 1151 ~
______~_ I lls4
Notes: 2.1 bbls pumped for test. Adapter flange to tubing spool does not have full stud & nut engagement. Operator Reps made aware of deficiency.
~® zB.c~2v ~>:~,~~~ -tom ~~.}->~ c~T ~~z~Ilo
S~s(zei,~j ~~F r~-Ei'~lex~~ ~ ~~~~~~
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Tuesday, June 08, 2010 Page I of 1
Page 1 of 1
Regg, James B (DOA)
__ ___
_ __ _ __ __
__
From: Regg, James B (DOA) ~ ~ (p
Sent: Friday, June 25, 2010 2:17 PM ',~~~ ~~Z I ~~~1 !C-1'~
To: 'NSK Well Integrity Proj';'NSK Problem Well Supv' ~ 1°~,- ZZ~~
Cc: DOA AOGCC Prudhoe Bay; Maunder, Thomas E (DOA)
Subject: ANSI 1500 Flanges
Inspectors have been finding ANSI 1500 flanges installed on the IA of some wells when out to witness
MITs. The rated working pressure for these flanges is 3700psi. If I understand the situation correctly, the
ANSI 1500 flange is installed on the IA and would either be directly exposed to test pressure approaching
the rated working pressure, or could be exposed to excessive injection pressures in the case of TxIA
communication (e.g., high injection pressures on gas injectors or via thermal expansion). During
witnessed MITs in late May 2010, ANSI 1500 fllanges were found on West Sak gas injectors KRU 1C-25
and 1C-27. In both occurances, CPAI was advised these are deficiencies. API defines the rated working
pressure of equipment to be the maximum internal pressure that the equipment is designed to contain or
control, and further notes that rated working pressure should not be confused with testing presssure (I
read that to say it is inappropriate to justify operating equipment at pressure exceeding rated work
pressure just because it was tested to the higher pressure). Exceeding the rated working pressure
represents an inappropriate risk to field personnel attending to the wells. Inspectors have not been able
to field verify if ANSI 1500 flanges have been hydrotested to proposed higher test pressure, and even if
the flange was tested, we question how you would account for the history (exposure to extreme temps,
harsh chemicals, corrosive fluids, etc.).
We are interested in understanding CPAI's safe operating practices regarding ANSI 1500 flanges. We
are also interested in reviewing any CPAI test policy that allows for the pressure rating of equipment to be
exceeded.
Other deficiencies noted during the KRU 1 C-pad inspections in late May:
- Two instances of tree flange adapters made up to tubing spool without full engagement of the nuts on
the studs (1 C-10, 1 C-15)
- KRU 1 C-119 and 1 C-121 were noted to have mandrel hangers off seat from conductor casing; WAG
injection lines were hanging from tree without support, placing the casings in a sideways bind.
- KRU 1 C-174 was observed to have orifice meter wrapped in absorbent and an oily waste bag; use and
condition of the orifice meter here needs to be explained.
Please address these items.
Jim Regg
AOGCC
333 W.7th Avenue, Suite 100
Anchorage, AK 99501
907-793-1236
6/25/2010
•
ConocoPhillips
,~as~ ~2ECEiVED
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360 JUN 1 1 2 0 0 9
Alaska OMB ~ Gas Cons. Comrniss~ar,
Anchora~a
June 9, 2009
Mr. Tom Maunder ~ ~ ~~ °~`~~
Alaska Oil & Gas Commission ~~,Fl~~, ,,~,~. w " ~~~,~ ~ ~ ... ~ ~.
333 West 7 Avenue, Suite 100
Anchorage, AK 99501
Dear Mr. Maunder:
Enclosed please fmd a spreadsheet with a list of wells from the Kuparuk field (KRin. Each of
these wells was found to have a void in the conductor. These voids were filled with cement if
needed and corrosion inhibitor, 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 was pumped May 27~', 2009. The corrosion inhibitor/sealant was pumped May 31St
and June 1St, 2009. The attached spreadsheet presents the well name, top of cement depth prior to
filling, and volumes used on each conductor.
Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions.
Sincerely,
,,-~;~'~
MJ Loveland
ConocoPhillips Well Integrity Projects Supervisor
•
ConocoPhillips Alaska Inc.
Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off
Report of Sundry Operations (10-404)
Kuparuk Field
Date 6/9/2009
Well Name
PTD #
Initial top of
cement
Vol. of cement
um ed
Final top of
cement
Cement top off
-date
Corrosion
inhibitor Corrosion
inhibitor/
sealant date
ft bbls ft al
1 A-06 181-116 n/a 0.25 22" 5/27/2009 1.70 5/31 /2009
1 C-08 181-052 9`6" 3.50 20" 5/27/2009 1.30 5/31 /2009
1 C-15 198-229 4' 10" 1.00 25" 5/27/2009 3.40 5/31/2009
1D-125A 200-044 4'9" 1.00 10" 5/27/2009 4.50 6/1/2009
1 H-03 182-115 15' 10" 2.00 24" 5/27/2009 2.60 5/31/2009
5~
MEMORANDUM
To: Jim Regg ~ ~ ~ ~ I ~~L
P.I. Supervisor '~ f
FROM: Chuck Scheve
Petroleum Inspector
•
State of Alaska
Alaska Oil and Gas Conservation Commission
DATE: Monday, May 04, 2009
SUBJECT: Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA INC
I C-15
KLTPARt1K RIV UNIT 1C-15
Src: Inspector
NON-CONFIDENTIAL
Reviewed By:
P.I. Suprv JB~~
Comm
Well Name: KUPARUK RIV UNIT 1C-15
Insp Num: mitCS090426151555
Rel Insp Num: API Well Number: 50-029-22932-00-00
Permit Number: 198-229-0 - Inspector Name: Chuck Scheve
Inspection Date: 4/26/2009
Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
Well Ic-IS Type Inj. ~' TVD 6415 IA 150 Iso Iso Iso
P.T.D 1982290 TypeTest sPT Test psi 1603.75 OA 510 1800 ~ 1760 1760 ~
Interval °T~R P/F P ~ Tubing Iooo Iooo Iooo Iooo
NOteS' MITOA post surface casing patch. ,,
vs. • 1~> k i 1 ?3 ~;.s C
Monday, May 04, 2009 Page I of 1
s~ ~lV~~
~ ~ ~
STATE OF ALASKA ~~~ ~, ~ ~Q~~
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATION~$~~ ~~~ ~ Gas Cons. Cammsssiorl
1. operations Pertormed: Abandon ^ Repair Well ^~ Plug Pertorations ^ Stimulate ^ Other C Repair
Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^
Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^
2.Operator Name: 4. Current Well Status: 5. Permit to Drill Number.
ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 198-229'ti
3. Address: Stratigraphic ^ Service LJ 6. API Number:
P. O. Box 100360, Anchorage, Alaska 99510 50-029-22932-00
7. KB Elevation (ft): 9. Well Name and Number.
RKB 102' 1 C-15
8. Property Designation: 10. Field/Pool(s):
ADL 28242, ALK 2292 Kuparuk River Field /Kuparuk Oil Pool
11. Present Well Condition Summary:
Total Depth measured 9390' feet
true vertical 6840' feet Plugs (measured)
Effective Depth measured feet Junk (measured)
true vertical feet
Casing Length Size MD TVD Burst Collapse
Structural
CONDUCTOR 121' 16" 121' 121'
SURFACE 6147' 9-5/8" 6249' 4488'
PRODUCTION 9288' 7" 9390' 6751'
SC Repair 1' 11 1/2"
Perforation depth: Measured depth: 9096-9142 .,~~,~3~~% ~~~~t ~' ~~~w
true vertical depth: 6576-6617
Tubing (size, grade, and measured depth) 3-1/2" , L-80, 8977' M D.
Packers &SSSV (type & measured depth) pkr= BAKER S-3 PERM PACKER pkr- 8919'
SSSV Camco TRDP -4e Locked out SSSV= 2019'
12. Stimulation or cement squeeze summary:
Intervals treated (measured) N/A
Treatment descriptions including volumes used and final pressure:
13. Representative Daily Average Production or Injection Data
Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure
Prior to well operation N/A N/A N/A N/A N/A
Subsequent to operation N/A N/A N/A N/A N/A
14. Attachments 15. Well Class after proposed work:
Copies of Logs and Surveys run _
Exploratory ^ ,~,(
Development ^ Service LI '
Daily Report of Well Operations _X 16. Well Status after proposed work:
Oil^ Gas^ WAGQ • GINJ^ WINJ ^ WDSPL^
17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or WA it C.O. Exempt:
308-418
contact ' /MJ o eland
Printed Na Perry KI Title Problem Well Supervisor
Signature `- Phone 659-7043 659-7043 Date 6/22/2008
~- _ ~` ~ ~~..~, ~-,.. Imo. .. iC.iK'a.- ~'izs.? ~ :l !!JU /~i ~~1~ ~ _ ,U~
- ~~•~
Fnrm 10-dOd RPViarKt (1st/2004 Submit Orioinal Only
• •
1 C-15
DESCRIPTION OF WORK COMPLETED
SUMMARY
Date Event Summary
03/23/09
04/10/09
04/11/09
04/14/09
purged with nitrogen.Cut and removed 5' of conductor.Chipped away bad cement and buffed
surtace casing.Drilled and tapped existing hole out to 1/2".Hole is 6" below flutes.
Weld 1' 11.5" patch from the bottom of the open flutes (starter head) to the top of pup collar,
used 9 5/8" 40pd .395 pipe f/patch material, Kakivik mag test & UT the welds -PASSED.
Read for MIT OA. T/I/O = SI/O/O.
Post SC repair - T/I/O = 0/0/0; Pressure OA to 500psi (no leaks), pressure to 1000psi (no
leaks), pressure to 1750psi with .5 bbls diesel; 0/0/1750; 15min reading T/I/O = 0/0/1700 no
visual leaks, bleed down, final T/I/O = 0/0/0
Install 4' 8.5" of 16" 62.5 # .375 conductor casing.
•
ConocoPhillips
Alaska
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
Apri128, 2009
Mr. Tom Maunder
Alaska Oil & Gas Commission
333 West 7~' Avenue, Suite 100
Anchorage, AK 99501
•
~~~~~:
~isska ~~;~ ~
~a~ fix. ~; : ~ ,
Anchora~
Dear Mr. Maunder:
Enclosed please find a 10-404 Report of Sundry Well Operations for ConocoPhillips
Alaska, Inc. well 1C-15(PTD 198-229) repair of shallow surface casing corrosion
damage.
Please call MJ Loveland or myself at 659-7043 if you have any questions.
Problem Well Supervisor
Attachments -10-404, w/picture of repair
•
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•
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ALASSA OIL A1~TD G~A-S
CO1~T5ER~ATIOI~T COMrIIS5IOI~T
•
SARAH PAUN, GOVERNOR
333 W. 7th AVENUE, SUITE 100
ANCHORAGE, ALASKA 99501-3539
PHONE (907) 279-1433
FAX (907)276-7542
MJ Loveland
Well Integrity Project Supr.
ConocoPhillips Alaska Inc. ~~ N0~ ~ ~ ZDO~
PO Box 100360
Anchorage, AK 99510
Re: Kuparuk River Field, Kuparuk Oil Pool, 1 C-15
Sundry Number: 308-418
Dear Ms. Loveland:
lq~
Enclosed is the approved Application for Sundry Approval relating to the
above referenced well. Please note the conditions of approval set out in the
enclosed form.
When providing notice for a representative of the Commission to witness any
required test, contact the Commission's petroleum field inspector at (907)
659-3607 (pager).
As provided in AS 31.05.080, within 20 days after written notice of this
decision, or such further time as the Commission grants for good cause
shown, a person affected by it may file with the Commission an application
for rehearing. A request for rehearing is considered timely if it is received by
4:30 PM on the 23rd day following the date of this letter, or the next working
day if the 23rd day falls on a holiday or weekend. A person may not appeal
a Commission decision to Superior Court unless rehearing has been
requested.
Sincerely,
Cathy . Foerster
Commissioner
/'
DATED this Z`t day of November, 2008
Encl.
• •
ConocoPhillips
~~
P.0. BOX 100360
ANCHORAGE, ALASKA 99510-0360
November 16, 2008
Mr. Tom Maunder
Alaska Oil and Gas Conservation Commission
333 West 7~` Avenue, Suite 100
Anchorage, AK 99501
Dear Mr. Maunder:
Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips
Alaska, Inc. well 1C-15 PTD 198-229 surface casing excavation and repair.
Please call Perry Klein or me at 659-7043 if you have any questions.
Sincerely,
i~~~ ~2 ~
MJ Loveland
ConocoPhillips
Well Integrity Projects Supervisor
Enclosures
STATE OF ALASKA U
ALASKA OIL AND GAS CONSERVATION COMMISSION `~
APPLICATION FOR SUNDRY APPROVAL.
20 AAC 25.280
• ~.
t
~-.
N
1
1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Pertorate ^ Waiver ^ Other Q
Alter casing ^ Repair well ^~ Plug Perforations ^ Stimulate ^ Time F~ctension ^
Change approved program ^ Pull Tubing ^ Pertorate New Pool ^ Re-enter Suspended Well ^ SC patch
2.Operator Name: 4. Current Well Class: 5. Permit to Drill Number:
ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 198-229 '
3. Address: Stratigraphic ^ Service Q 6. API Number:
P. O. Box 100360, Anchorage, Alaska 99510 50-029-22932-00 '
7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number:
where ownership or landownership changes:
Spacing Exception Required? Y@S^ NO ^ 1C-15
9. Property Designation: 10. KB Elevation (tt): 11. Field/Pool(s):
ADL 28242, ALK 2292 RKB 102' Kuparuk River Field /Kuparuk Oil Pool
12. PRESENT WELL CONDITI ON SUMMARY
Total depth MD (tt): Total Depth TVD (tt Effective Depth MO (ft): Effective Depth TVD (tt): Plugs (measured): Junk (measured):
9390' 6840' '
Casing Length Size MD TVD Burst Collapse
CONDUCTOR 121' 16" 121' 121'
SURFACE 6147' 9-5/8" 6249' 4488'
PRODUCTION g288' 7" 9390' 6751'
Perforation Depth MD (ft): Perforation Depth TVD (tt): Tubing Size: Tubing Grade: Tubing MD (tt):
9096-9142 6576-6617 3-1/2" L-80 8977'
Packers and SSSV Type: Packers and SSSV MD (tt)
Packer Baker S-3 Permanent Packer 8918'
SSSV Camco TRDP - 4e Locked out 2019'
13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work:
Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ •
15. Estimated Date for 16. Well Status after proposed work:
Commencing Operations: December 10, 2008 Oil ^ Gas ^ Plugged ^ Abandoned ^
17. Verbal Approval: Date: WAG Q GINJ ^ WINJ ^ WDSPL ^
Commission Representative:
18. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: MJ Loveland/ferry Klein
Printed Name MJ Lovela Title: Well Integrity Project Supr.
`~ ~
Signature ~, ,s.~.~ "
Phone 659-7043 Date ~_ ~ _ U ~
Commission Use Onl
Sundry Number:
Conditions of approval: Notify Commission so that a representative may witness
Plug Integrity ^ BOP Test
^ Mechanical Integrity Test ^
Location Clearance ^
``
(~ `
Other: ~~~v~ ~, Q~'t)~ ~ th Lv~rt ~~G~ ~ O'er ®-T ~ ~~L._ ~ ~-rc ~~
~a ~ ~~ N~~! ~ ~ ~~~~
Subsequent Form Required: L,..~~ ~
7"~ APPROVED BY ., ~/ p Q
l~'
'
~ U
Approved by: COMMISSIONER THE COMMISSION Date: i
l/
l
Form 10-403 R ised 06/2(~0~ (~ i (~ ~ ~~ ~' / ~,~~ Submit in Duplicate. ~~
•
ConocoPhillips Alaska, Inc.
Kuparuk Well 1C-15 (PTD 198-229)
SUNDRY NOTICE 10-403 APPROVAL REQUEST
11/15/08
This application for Sundry approval for Kuparuk well 1C-15 is for the repair of a surface casing
leak. The well is an injector and the mother bore 1C-15 was drilled in 1998 as a producer. A
coiled tubing sidetrack lateral was added and the well converted to an inj ection well in 2004. On
8/26/07 gas was reported bubbling form the surface casing by conductor annulus and was
subsequently reported to the AOGCC on 8/27/07. Diagnostics confirmed a leak in the surface
casing just below the starting head. With approval, repair of the surface casing will require the
following general steps:
1. Shut-in and secure well. Set positive pressure plug and fluid pack the IA as needed to
remove all gas. Freeze protect T and IA as needed. PT plug to verify barrier.
2. Excavate wellhead location.
3. Install nitrogen purge equipment.
4. Cut away the conductor casing and remove cement around surface casing leak for inspection.
` 5. Notify AOGCC Field Inspector of repair operation so they may witness the event.
6. Repair damaged surface casing to return the casing to operational integrity. Repair options
include sleeve patch, seal weld, lap patch, deposition weld and will be determined after
inspection of the casing damage.
7. QA/QC the repair welds and MIT-OA to verify integrity
8. Install anti-corrosion coating on exposed surface casing.
9. Patch the conductor and top off the conductor void with cement and waterproof sealant.
10. Backfill gravel around the wellhead.
11. Remove plugs and return the well to production.
12. Submit 10-404 report of repair operations to AOGCC.
1C-15 (PTD 1982290) MITIA fo~ application ~ Page 1 of 1
Regg, James B (DOA)
From: NSK Problem Well Supv [n1617@conocophillips.com]
Sent: Wednesday, October 31, 2007 7:47 AM ~~ ~ , ~~31(U
To: Maunder, Thomas E (DOA); Regg, James B (DOA) (.
Cc: NSK Problem Well Supv; NSK Well Integrity Proj
Subject: 1C-15 (PTD 1982290) MITIA for AA application
Attachments: MIT KRU 1 C-15 10-07-07.x1s
Tom & Jim,
Attached is the diagnostic MITIA that was performed for the AA application that you will be receiving in the mail. Please
let me know if you have any questions.
«MIT KRU 1C-15 10-07-07.x1s»
Brent Rogers
Problem Wells Supervisor
ConocoPhillips Alaska, Inc.
Desk Phone (907) 659-7224
Cell Phone (907) 943-1999
Pager (907) 659-7000 pgr. 909
~~ ~4V ~ ~ ZOD~
10/31 /2007
•
•
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
Mechanical Integrity Test
Email to: Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us ~'~
OPERATOR:
FIELD /UNIT !PAD:
DATE:
OPERATOR REP:
AOGCC REP:
ConocoPhillips Alaska Inc.
Kuparuk/ KRU / 1 C-15
10/07/07
Johnson/Bates AES
None
~ r~,.v`~
~.r 0
~~~
Packer De t Pretest Initial 15 Min. 30 Min.
Well 1 C-15 Ty e In'. N TVD 6,416' Tubin '2800 2800 2800 2800 Interval p
P.T.D. 1982290 T e test P Test si 1604 Casing 575 900 1850 1850 P/F P
Notes: MITIA for AA aplication. Not witnesed. ~' OA 0 0 0 0
Well Ty e Inj. TVD Tubing Interval
P.T.D. T e test Test si Casing P/F
Notes: OA
Well Ty e Inj. TVD Tubing Interval
P.T.D. Ty e test Test si Casin P/F
Notes: OA
Well T pe Inj. TVD Tubing Interval
P.T.D. T pe test Test si Casing P/F
Notes: OA
Well Type In', TVD Tubing Interval
P.T.D. Type test Test psi Casing P/F
Notes: OA
Well Ty e Inj. TVD Tubing Interval
P.T.D. Ty e test Test psi Casing P/F
Notes: OA
D =Drilling Waste M =Annulus Monitoring
G =Gas P =Standard Pressure Test
I =Industrial Wastewater R =Internal Radioactive Tracer Survey
N =Not Injecting A =Temperature Anomaly Survey
W =Water D =Differential Temperature Test
I =Initial Test
4 =Four Year Cycle
V =Required by Variance
T =Test during Workover
O =Other (describe in notes)
MIT Report Form
HFL 9(1/05 MIT KRU 1C-15 10-07-07.x1s
lC-15 PTD # 198-229, Notice ofsu.t surface casing leak
Regg, James 8 (DOA)
.\
Page 1 of 1
From: NSK Problem Well Supv [n1617@conocophillips.com]
Sent: Monday, August 27,20077:23 PM
To: Regg, James B (DOA); Maunder, Thomas E (DOA)
Subject: 1C-15 PTD # 198-229, Notice of suspect surface casing leak
Attachments: 1C-15 90 day TIO.gif; 1C-15.pdf
~q1 ~('E7\D 7
Jim & Tom,
1C-15 PTD # 198-229, MI gas injector, is suspect of having a shallow surface casing leak. v"
T/J/O=3040/1075/0 psi
Immediate action has been to bleed the OA to zero psi and WAG the well to water.
We plan to inject water for 7 day to sweep the MI from the well bore and near well bore area.
After 7 days on water the well will be shut in and additional diagnostics will be preformed to confirm or disprove the suspected
surface casing leak.
The well passed a 4 year state witnessed MITIA to 2715 psi on 5/8/06.
I've enclosed a 90 day TIO plot.
Let me know if you have any questions.
SCANNED SEP 1 1 2007
Perry Klein
Problem Well Supervisor
office (907) 659-7224
Cell (907) 943-1244
Pager (907) 659-7000 x909
n 1617@conocophillips.com
«1C-15 90 day TIO.gif» «1C-15.pdf»
9/5/2007
29-MAY -01 19: HI
WEEK
SCRATCH 32
FLOW TUBING PRESSURE
1111111
SCRATCH_32
OUTER ANNULUS PRES
1111111
J'ile:lllq/tempiTemporary Imcmet FiJesJOLK24/tC-i5 90 cia.V TIO.gif9l5!2007 12:5&;W PM
PKR
(8919·8920,
006,900)
1 5
NIP
(8965·8966
004470)
102.992)
SOS
(8976-8977 ,
OD3,500)
Perf
(9096-9106)
Perf
(9106-9126)
Perf
(9126·9142)
Wt:26,00)
.
.
ConocJ'Phillips
Alaska
RECEIVED
AUG 2 9 2007
Alaska Oil & Gas Cons. Commission
Anchorage
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
August 23, 2007
Mr. Tom Maunder
Alaska Oil & Gas Commission
333 West 7th Avenue, Suite 100 7
Anchorage, AK 99501 s\;ANNaJ SEP () () 200
f'\~~~~
Dear Mr. Maunder: .
Enclosed please find a spreadsheet with a list of wells ftom the Kuparuk field (KRU). Each of
thesé wells was fôund to have a void in the conductor. These voids were filled with a corrosion
inhibitor, engineered to prevent water ITom 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 corrosion inhibitor/sealant was pmnped between August 19 & 21, 2007. The attached
spreadsheet presents the well name, top of cement depth prior to filling, and volmnes used on
each conductor.
Please call me at 907-659-7043, if you have any questions.
~¡4~~·
M.J.¿el~d
ConocoPhillips Well Integrity Projects Supervisor
.
.
ConocoPhillips Alaska Inc.
Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off
Report of Sundry Operations (10-404)
Kuparuk Field
Date
8/21/2007
Corrosion
Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/
Well Name PTO# cement pumped cement date inhibitor sealant date
- ft bbls ft gal
1 0-28 204-237 18" N/A N/A N/A 10 8/19/2007
1 0-30 200-104 24" N/A N/A N/A 6.5 8/19/2007
10-34 200-143 14" N/A N/A N/A 4 8/19/2007
10-12 199-084 1" N/A N/A N/A 1.7 8/20/2007
10-14 199-089 2" N/A N/A N/A 3.4 8/20/2007
10-140 200-136 29'9" 3.4 12" 12/16/2006 14.5 8/20/2007
10-141 200-112 SF N/A N/A N/A 0.5 8/20/2007
'1C-11 199-172 'SF NA NA NA 0.5 8/21/2007
1C-12 196-177 SF NA NA NA 0.5 8/21/2007
1C-15 198-229 SF NA NA NA 0.5 8/21/2007
1C-16 198-246 22" NA NA NA 8 8/21/2007
1C-17 198-224 17" NA NA NA 1.7 8/21/2007
1C-18 199-005 SF NA NA NA 0.5 8/21/2007
1C-24 201-248 20" NA NA NA 11 8/21/2007
1C-26 199-051 3" NA NA NA 0.85 8/21/2007
1 C-27 199-043 4" NA NA NA 1.7 8/21/2007
1 C-28 205-104 SF NA NA NA 0.5 8/21/2007
1C-117 201-121 26" NA NA NA 12.3 8/21/2007
MEMORANDUM
FROM:
TO:
?~1 lolli(o,\
Jim Regg
P.I. Supervisor
John Spaulding
Petroleum Inspector
Well Name: KUPARUK RIV UNIT IC-15
Insp Num: mitJS040924105414
ReI Insp Num:
)
State of Alaska
Alaska Oil and Gas Conservation Commission
DATE: Friday, October 01, 2004
SUBJECT: Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA INC
1 C-15
KUPARUK RIV UNIT lC-IS
Src: Inspector
NON-CONFIDENTIAL
API Well Number: 50-029-22932-00-00
Permit Number: 198-229-0
)
Reviewed By:
P.I. Suprv 'JB~ )D/h/04~
Comm
Inspector Name: . John Spaulding
Inspection Date: 9/3/2004
Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
Well lC-IS Type Inj. S TVD 6416 IA 2500 3125 3200 3200
P.T. 1982290 TypeTest SPT Test psi 1604 OA
Interval INITAL PIF p Tubing 1430 1430 1430 1430
Notes:
Friday, October 01, 2004
~(;l\NNE[) OCT 1 8 2004-
Page I of I
)
ì
STATE OF ALASKA
ALASKA Oil AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
1. 'ope~ti()ns:F¢1o~~W·.·.. '.' '.~b~n~pn....:ÇJ::·... ·····i/R~Pärr'Jlle¡L,.:Ç1.· . . .:~I·U~ITrr~~~ti:Amfi,ÇJ ..:.·.·:¡:!iStiw·.m... ·..aU.... I.va.,...·..e..ter........·.:.Op..:.....··· . ..... '.; ...;.Ot~~r· .. ." .':0 Prod to MW AG
.'. ..... ..... .....;¡ }...~ltør:.q~*iri~O·) '.. .... F~';''''J~¡r~,J~J .,. p~ror~~~~~~::~~?~.[J: : .:,:' ,........ ...... .;. ..... ,: ,. ',; ··~i~~T~~h.~iorîP; .....
'çhång~.:,A.þþ~~~Jde/þ~r~1110¡·Qp~fat/$hutdowhO \' ·).:e~W~~t~.CJ·.··· ......,' " ,,' ·'·:.¡R~~.~~~ør:9~~p~rdå~]Wåll:0
2. Operator Name:4;qyrf~ht'/l{øIIJ3té1tºS;·;;··:: .<: ," ' '" ..,..... .... .... ..... 5. Permit to Drill Number:
ConocoPhillips Alaska, Inc.þ~ÿ~lc~p~~~ti¡'O ..E~ldläi9rÿ 0; 198-229/
3. Address: ., ··.St~atigt~Þhìè.O '.:::', ¡.Š~rJiçe/0: ... · ' 6. API Number:
P. O. Box 100360 50-029-22932-00
7. KB Elevation (ft): 9. Well Name and Number:
RKB 102' 1 C-15
8. Property Designation:
Kuparuk River Unit
11. Present Well Condition Summary:
Total Depth
Effective Depth
Casing
Structural
CONDUCTOR
SURFACE
PRODUCTION
Perforation depth:
10. Field/Pool(s):
Kuparuk Oil Pool
measured 9390' feet
true vertical 6840' feet
measured 9141 feet
true vertical 6276' feet
Length Size MD
121' 16" 121'
6147' 9-5/8" 6249'
9288' 7" 9390'
Plugs (measured)
Junk (measured)
TVD
Burst
Collapse
121'
448'
6840'
Measured depth: 9096-9142
true vertical depth: 6576-6617
Tubing (size, grade, and measured depth) 3-1/2" , L-80, 8977' MD.
Packers & SSSV (type & measured depth) pkr= BAKER S-3 PERM PACKER pkr= 8919'
sssv= SSSV SSSV= 2019'
12;StirnlJlation orëemel1t squeezesul11l11äry:
InterVals treated (l1leasured)
Treatment descriptions including volUmes üsed and final pressure:
13. Representative Daily Ayeråge Produc:tionorlnjectionData
Oil-Bbl .... Gäs-Met Water"Bbl .. Casinq Pressure Tubinç¡ Pressure
Prior to well operation· 218 89 794 1354 267
Subseq uentto operation 1463 25 . 25
14. AttachmEmts 15. Well Class aftërproposed work:
CopiesofLogsandSür'v'ëysrun___ ExploratorYO Development 0 Service 0
Daily Repòrt of Well Operations___X 16. WeU Status after proppsed work:
OilD GasO WAG 0 GINJO WINJ 0 WDSPLD
17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt:
srr-, l\ ~\i.¡~\~ 0..../,
~..' ~¿).r:¡j ti¡1 iJE~ /It 4 U f" '", .... ,. [. .
, ,Ii U ti U J ,¿.J I...I.~J
Title
Phone
::~~~~~n Engineer~å~/ eo/~i~ I
I
1PZ\ffìU~ OF LUll ;¿ ~·f.lml)~
~ Söb~~t'Original Only
Form 1 0-404 Revised 06/2004
ORIG\NAL
)
1 C-15
DESCRIPTION OF WORK COMPLETED
SUMMARY
')
Date Event Summary
07/17/04ICompleted Producer to Injector Conversion. Commenced PWI injection
i!
~i ~~~ t
í .....,
t<..i } "/ !:
.,~ ;:"'''''J. ":~' "¡
j~(',. <.vl
JUL-29-2004 11:08 PHILLIPS AK INC
. )
e·":: ConocoPhillips Alas~~. Inc._
1C-15 '... '
API~, J>00292293200
sssv Type: LOCKED our
ssSv
(~O'SI·2020.
OO;5,2S0)
NIP
(~~7ß,8/!77 .
OD~4..540)
PKR
(8919-8920,
OD:6,900)
NI~
(8965-8968.
00;4,470)
TUBING
(0-3977,
OD;3,SOO. J""
10:2.99:2)
SOS
(8976-8977,
OD:3.500)
Perf
($QS~91(J6)
Pr:rf
(9106-9126)
Perf
(9126-9142)
Õ>RODucnON
(0.939Q,
QD:7.000,
Wt:28.00)
':1ß¡,«,9~
!k~f,1>1~~iI.'
Gss Lift Mandre:I~-ªives
. St MD TVD Mãr,· Man Type V Mfr '.ïType, V OD Latch pòrï TRO
Mfr
1 3325 2603 CAMlJO KBMM
:2 6349. 3908. .ÇÀM·CO KBMM
3 ,6~~~. 4709 cAMto KBMM
4 7554 534Ö' 'CAMCO KB~.M",_..
5 8331 5906 CAMCO K8MM
6 8827 6334 CAMCO MtJfM"'~-
Other (plug$, equllb_~~t:_:J.~WELRY
Dépth TVQ __, " T.y~
_.~_Q19 ~ 1796 SSSV
8876 -6378 NIP
8919 . 6416 ÞKR
8965 '6458 'Nip""
S976 6468 sÒ§"'--
9141 aS16 PLUG
General Notes
Date Nate '" ,,,_ .. ,..
4/15/2003 AN UPPER LATERAL LËG, 1C-15L 1. WÃS-' DRilLED 4/15/2003, 1C-15 ÞERFS LI;FT OPEN. 1C-15L 1
EXITS TO C-$ANDS THROUGH CEMENT PLUG IN 1C·15 WELL60t\E. 1C-15 PERFS LEFT OPEN;
WELL WILL F'ROPU_C;..!.tlROUGH BOTH l.EGS,
Annular FII,Jid: ·bSUSW/KCI
Reference Log:' '37 RK~ ,_,
no Last Tsg: 9141, ~_~ß
Last TS!:J Date: 3J3Q(~003
Casinø String - ALL Sr~1NGS
'DeSCriPtion , ,. ..___ ., , .
CONDUCjOR:-
SURI=:ACE-··· ,
PRODUCTlpN
Túbin.:a String - TUBIÑ'G'"
$Im ,::=::'-1' . ,., Top
3.5.!lP ,_... 0
PerforatlQ~_$ümmarv
tnt~~!tJ ,~ -, TVD
9096 .. 9106-·' 6576 - 6585
Ø106·9126-'·· 6585 - 6603
912rr:"'9142 6603 - 6617
907 265 6224
P.02
')
KRU
1 C-15
Well Type~ "P80D
,... Orig 12115/1'998
Completion:
Last W/O:
·"":~o~e @ 'TS: 26 deä-(ã> ~p~~""
Angle @ TD: 26 deg @ 9390
Rev Reason; GLV DE$IGN,
'"'' Lock Qut SS$.,v
l?st Update; 712~O_04.,..
-Ref Log D:~te:
".ID:-}i390 ftKB
Max Hor~,ArtQ.I.~:: 53 deQ (êJJ 2783
Si2e
16.000
9,625
7.000
Top
·0
o
··'·'0
Bottom
121
6249
9390
"TVD
121
M,ß8
_ J~39Q~:,
wt I Gra~~" Thread
62.58 H:40 ··'WEL.DED
40.00 L-80 BTC
26.00 L·ß.9 '.':" Ä8M-6TC
~::fi~.~:'~l·" ~~
! "...~~}~",,~,l· GL~~e I
..Thread
... ~~Ë:ï~RD
Za,..~
C-4
.",__Ò:4-
Ó:3
Status
Ft SPF ,n Date Type .. Comment
10 6 2If'7Ï2'o02 APERF 2,5" HSD p~i Chgs, 60 deg
_ phase _.
20 ,,4 12/30/1998 ¡PERF 2.5" ..I:I"Ç DP
16 6 2/17/2002 APE~F 2.5" HS[rPJ Chg$, 60 deg
,... J?~~5e
CAMCO
CAMCO
C;AM c 0" ,
CAMëo
CAMCO
CAMCO
,.,._pMY
DMŸ
D-MY
DMY
DMY
DMY
QJiQO . 0
o.QQP"·, 0
0.000 .. 0
··"0.000 0
0.000 0
0.000 0
Date
Run
7/16/2004
7/16/2004
7/16/2004
7/1S/2004
2I12120ô:f
7/16I2g.94: ,
Vlv
CJJ'1~~
1.0 BK
1,0 BK
1.0 51(
1.0 eK
1.0 .... "·'sk-s
_..~.:.§.,"~~'~ R K
, ".... "15ëscript1on
CAMCO TRDP-4.EJ,,=-OCKED ÖÛT 7/1612004)
CAM~PWNIPPLE .....,
BAKER s-:fp'ERM PACKER ,,,. ..._._
CÄMCO D NIPPI,.E - MILLED OUT TQ,~.80" ïtf2/5I2003
BJ\fš~.R SHEAR OUT sua ..,., ".._,_.
CEM¡;,~f·pL.q.~..BOTTOM TO 9141' ~KB SET 3/28/~QØ·3·'"
ID
2,812
2.812,.
3.~Z5 ,
2.800 -.
2.992
0.000
.sCt?' ",-,.Þr,i\DE"--'''·'
r"M'\!JnrA ,f " /AUf" 8' í) )'''['
,., /"', ,ti' \,,i JL ,_I DI.)
._,_\~t~..·... ",-""'.
Re: IC-IS Map
)
)
(I C) ~q
lq1)/(~
Subject: Re: IC-I5 Map
From: Thomas Maunder <to~maunder@admin.state.ak.us>
Date: Tue, 22 Jun 200407:28:48 -0800
To: "Seitz, Brian" <Brian.Seitz@conocophillips.com>
Thanks Brian,
This will work, coupled with the spider plots I pulled from other wells in the
area. This pretty well confirms that there are no penetrations "through the roof"
within a 1/4 mile of either wellbore.
I did receive the bond log as well. I will finish processing your applications.
Tom
Seitz, Brian wrote:
Tom-
Let me know if this map will suffice for the 1C-15 conversion to injection.
Sandra Lemke forwarded the Cement Bond Log run on March 11, 2003, so I think
we're covered. If you need additional information, please do no hesitate to
call.
Regards, Brian
«lC-15L1 fig.ppt»
SC/~NNEf!) J~ ¡I~._ _~I ~ 2no'il
- .,)1 Ii ()_ U \' I;,
1 of I 6/22/2004 7:29 A~
IC-IS with CT
Lateral
/
/C-/4
ARC a Alaska, Inc.
~
~
C.....t.d by linçh For: LLOYD
Dot. plallltd : 25-Mgr-IVaa
Plot R.r.r.nt" i.. 23 V.",;on 15_
Coord1now are in r..t ,.J.,..nCII e!at 123.
True V.rtlçgl Deplh. or. r.r.r.nc. Est. RKB (Poal 16).
...
.....
INTEQ
Struoture : Pad 1 C Well : 23
FIeld : Kuparuk River Unit Looatlon: North Slope. Alaska
\
~
~
\(."- ~ ~()O·
6400
6600
7200 7600 6000 8400 6800
East (feet) ->
9200 9600 10000 10400 10600 11200 11600 12000 12400
4800 o/ð
4000 4400 4600
5200 5600
6000
4800
4400 -
~
4000 -
3600 -
~ \5 L'l. ~~
<,/6~ j
/' 6500
./
2600 - ø 6300
^
I
3200 -
,-...
0+-
Q)
Q)
'+-
'-'
6100
5900
5700
5500
5300
\ 5100
4900
4700
4500
4300
2000 - 4100
3900
\A-
1 600 -
"
'\
2400 -
..t:
-
L
o
~
1200 -
4500_ _}!...O~
4100 43~O_ __ -
BOO - 370Q... __3.!OQ. _- - - .-
3.300 _ ';5~0 _ .... -
~---
400 -
_ 4500 4900 5300 57~ _ _ !.1~0 _ _ .!5~0Jl[
~--------------
o -
300 - 4400
- 4000
- 3600
- 3200
- 2800
6700
6300 6500 __ [ll]
6100 __ _ - ... - -
5700 59~ _ .- - -
5100 5300 ":~O_ - _.---
4900 _ _ .- - - - -
_e--
41 00 4300 4500
-ID- -- - -+ _ __ _.4700 4900 5100 5300
_ - - - -..... _ ..... _ 5500 5700 5900 6100 6300
40D -0_ _ ___ _ .-.- _ -+ _ _ ~ _ _ _
. -
BOO
.,.-------~
.......
......
.....
~
4000 4400
6000
ì
6400 6800 7200 7600 BOOO 8400 BBOO 9200
I=" nc:!t (f,u~t' - '>
9600 10000 10400 10800 11200 11600 12000 12400
4BOO
5200
5600
.~
PJ,r
~",
~;-
Ó
,-,--J
~
~-I
~-
:"= .¿
'C~¿
-=J
J..J
g::
~
/?
.....'
(j
:fJ
^
- 2400 I
Z
0
"""'I
- 2000 -+-
::¡-
...-..
.....
- 1600 ~
'-J.
-1200
- 800
- 400
0
- 400
BOO
) 1 RECEIVED ~
STATE OF ALASKA , ð>:S' (~2
ALASKA OIL AND GAS CONSERVATION COMMISSION JUN 1 7 2004 6/,?_)
APPLICATION FOR SUNDRY APPROV A\lasi<a Oil & Gas Com~," Comm¡;ìSio~/5<
20 AAC 25.280 Am:;hor~ge
Operation Shutdown D Perforate D Waiver D Annular Disp. D
Plug Perforations D Stimulate D Time Extension D Other 0
Perforate New Pool D Re-enter Suspended Well D Convert to
Commencing Operations:
16. Verbal Approval:
Commission Representative:
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
:::::::ame -ð-= ;7 /-eØ
Commission Use Only
Sundry Number: . /
3D~-d--3+~
s>;-,,~,,4\~R~W~Y-~; ~~ H 1 ~20Gl,L
,'-" Y,1"'¥öCàttöh Cl'éch'éince U
Other: <...o.,^V'\~ W\\~ \~~~~f\.\~ 0\-. ~ \0 'ð ß.
~9fl
1. Type of Request:
D
D
D
Suspend D
D
D
Abandon
Alter casing
Change approved program
2. Operator Name:
ConocoPhillips Alaska, Inc.
3. Address:
P. O. Box 100360
7. KB Elevation (ft):
RKB 37'
8. Property Designation:
ADL 28242, ALK 2292
11.
Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft):
9390' 6840' 9141'
Casing Length Size
Repair well
Pull Tubing
CONDUCTOR
SURFACE
PRODUCTION
121'
6212'
9353'
16"
9-518"
7"
Perforation Depth MD (ft):
9096'-9142'
Packers and SSSV Type:
pkr= BAKER S-3 PERM PACKER
SSSV= SSSV
12. Attachments: Description Summary of Proposal IX]
Detailed Operations Program D BOP Sketch D
14. Estimated Date for
Perforation Depth TVD (ft):
6576'-6617'
07/01/04
Date:
4. Current Well Class:
Development _ 0
Stratigraphic D
Inipr.tnr
5. Permit to Drill Number:
198-229 ../
6. API Number:
Exploratory D
D
Service
V
50-029-22932-00
9. Well Name and Number:
1 C-15
10. Field/Pool(s):
Kuparuk River Field 1 Kuparuk Oil Pool
PRESENT WELL CONDITION SUMMARY
Effective Depth TVD (ft): Plugs (measured): Junk (measured):
6616' 9141'
MD TVD Burst
121' 121'
Collapse
6249'
9390'
4488'
6840'
Tubing Size:
3-1/2"
Tubing Grade:
L-80
Tubing MD (ft):
8977'
Packers and SSSV MD (ft)
pkr= 8919'
SSSV= 2019'
13. Well Class after proposed work:
Exploratory D Development 0
15. Well Status after proposed work:
Oil D Gas D
WAG 0 GINJ D
Service D
Plugged D
WINJ D
Abandoned D
WDSPL D
Contact: Brian Seitz @ 265-6961
Title: Kuparuk Staff Engineer
Phone ;2l,--6911 Date b /Í6/o'7
Conditions of approval: Notify Commission so that a representative may witness
Plug Integrity D
BOP Test D
Mechanical Integrity Test ~
Subsequent Form Required:
(/1,
Approved bY'- U V
Form 10-403 Revised 12/2003
----
t.2,·
~JL
o B~ M~'OtiA L
BY ORDER OF
THE COMMISSION
Date 74-ýt;1
INSTRUCTIONS ON REVERSE
Submit in Duplicate
)
<Þ\~\S'-1-
CL '}-'J- ~
tq u
KRU 1C-15 Conversion to Injection
Background
KRU lC-15 was drilled and completed as a C-sand producer in October of 1998. In
April of 2003, the well was sidetracked with coiled tubing while preserving the original
wellbore. After the sidetrack, the well was to be converted to MW AG injection to
provide support to an area of declining production. The plan is to now complete the
necessary facility work to convert the well and begin MW AG injection in July of 2004.
Summary of Operations
Surface slot 15 on DS-l C will be converted to MW AG service. Utilizing the standard
existing Kuparuk MW AG well tie-in design, this project will tie in an MI and WI lateral
with new hot taps on the headers.
".., , ,~u"~E"·'·" I' ", .-0 (~?nfP
~t;/4,~~W~·I¡. v~ U L 1 ,,) ,._ - lH
}
)
\~%-dd-'1
MECHANICAL INTEGRITY REPORT'
........
:, I G R E L E 1-. s:=:: .
OPER & FIELD C. ~J:\~ ¥-...\j~~~\:.
w"1:LL NU1iBER \ C-... \S
=PUD DA!E: :
~~
Ca.sing: '\
TD: '\~<\O,MD,. <O<6~1JTVD; ?BTD: '\ \"-\ \ MD Col.\ <0 TVD
Shoe: S,\S,Ù HD TVD i DV: \1 ~ HD ,Tvv
71"! ~LL DATÞ.
:':":Je:::-:
Shoe:
11D
TVD i -rop:
HD
~7D
:~bi::g: _~\I~\" Packe;: ~\~ HI)
H
:: ole S :"z e <6 \ t ~ anå ~ "
TVD i Set. ê. t %<=\ \. \
P er£'s S. 0<1. ~ to " \ '--\ :>.....
~ cl (.,0 5~ <.0 "-0 (p ~ \ ~
t:ECP..Þ..l~IC;'..L INTEGRITY - P liRT ¡ 1
Annulus Press Test: ~p
r 15 rnin
30 min
COü:iI:J.ents:
"".-
."to ~<., 5 b\a \
MECRÞ_1\lICAL INTEGRITY - PART ! 2 r ~ \ .\ S ':. ~,~ "!.
Cement: Volumes:', Þ..mt. Line.r ~~ i Csg \,\~~"j DV N ~ .
Cï:üt ~.¡o 1 to cover peri s ~ ~CJt.( t." "- '" \ (J \ -:...'/.. I .t}.. \ b ~ \
SuCÇ"\ Ù ~ "- \- \'0 c...c::. "-1 (t., ~ ~ ~fc..\..ç + 5'<:xJ ·
Theorecical Toe C~'C:)¿a'l.' 'G'-.. ::! %C<o<J'
Cement Bond Log (Yes or No) "
~o ~ "\ '-> Q \..(J: \ \G: "'-~.
In AOGCC File' J 1/t \ }ðs
\o~ -\:"-,<:",~~,, ~V~\,,~ S.d~O- <iA \(
GBL ~valuation, ~one above perfs
-
Prociu~tion Log: Typ~
Evaluation
. ~ i ~~ D\-\1è...\".)'\cL~ ~,,~ \ì'\.O ~\,\..'S. ,,~'? .\¡~~, v..:>-\~" \./4, ~\\e
'-., 0 N C L U S - 0 N S: 0 '\-~<L \ \- "'-ú....\1".- \ '-., __ \ ç'\- '\-. .
? ar t: if 1 :
?ar:: :Z:
k~ '\~ \~t"C(~·
".. 1R--~
. ~... (<0 (~"J -0 "--i
,~-, II '1'\ '\~ '~þ,.b'~~ T' L~ (;.\ .- '~ ">0 A ~
d~l(1~Ù\:J5'~Ib;,s.. .J U L 1 c,;~ tic ~h
,
03/25/03
S£hlumbepgep
NO. 2720
Schlumberger Technology Corporation, by and through is Geoquest Division
3940 Arctic Blvd, Suite 300
Anchorage, AK 99503-5711
A TIN: Beth
Company: Alaska Oil & Gas Cons Comm
Attn: Lisa Weepie
333 West 7th Ave, Suite 100
Anchorage, AK 99501
Field: Kuparuk
Well
Job#
Log Description
Date
BL
Color
CD
0_
1C-15 J C¡5?-~
1C-190,~D3-œ5
35-22 aJ3-0J
23101
23103
23102
SCMT
USIT
SCMT
03/11/03
03/09/03
03/06/03
1
1
1
---
RECFI~D
SIGNE~ (~~
DATE:
APR 1 4 2003
Alma Od & Gas Cons. Cornmiseion
A!M)orage
Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you.
SC/-\NNEC SEP 1 5 2003
~ )
..... . PhIlliPS Alaska, Inc.
~ A Subsidiary of PHILLIPS PETROLEUM COMPANY
)
Post Office Box 100360
Anchorage, Alaska 99510-0360
M. Mooney
Phone (907) 263-4574
Fax: (907) 265-6224
March 27, 2002
Commissioner Cammy Oechsli Taylor
State of Alaska
Alaska Oil & Gas Conservation Commission
333 West 7th Avenue
Suite 100
Anchorage, Alaska 99501
Subject: Report of Sundry Well Operations IC-I5 (198-229)
Dear Commissioner:
Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent
perforation operations on the KRU well IC-I5.
If there are any questions, please contact me at 263-4574.
Sincerely,
¡fit, µ{~
M. Mooney
Wells Team Leader
Phillips Drilling
MM/skad
....
RECEIVED
~NEll) APR 3 0 2002
APR 1 2002
AlllkaOllIGllCons. Commission
A.dø~
)
STATE OF ALASKA
ALASKA Oil AND GAS CONSERVATION COMMISSION
)
1. Operations performed:
Operation shutdown_
Pull tubing _
REPORT OF SUNDRY WELL OPERATIONS
2. Name of Operator
Phillips Alaska, Inc.
3. Address
P. O. Box 100360
Anchorage, AK 99510-0360
4. Location of well at surface
1634' FNl, 1239' FWl, Sec. 12, T11 N, R10E, UM
At top of productive interval
296' FSl, 1524' FWl, Sec. 6, T11 N, R11 E, UM
At effective depth
At total depth
4936' FNl, 3254' FEl, Sec. 6, T11 N, R11 E, UM
12. Present well condition summary
Total depth: measured
true vertical
Effective depth: measured
true vertical
Casing Length Size
CONDUCTOR 121' 16"
SURFACE 6249' 9-5/8"
PRODUCTION 9390' 7"
Perforation depth:
measured 9096' - 9142'
true vertical 6576' - 6617'
Stimulate
Alter casing _
5. Type of Well:
Development _X
Exploratory _
Stratigraphic _
Service_
(asp's 562247, 5968605)
(asp's 567918,5970630)
9390 feet
6840 feet
Plugs (measured)
9146 feet
6621 feet
Junk (measured)
Cemented
9 cu yds High Early
850 sx ASIII LW, 610 sx Class G
178sx Class G
Tubing (size, grade, and measured depth) 3-1/2",9.3#, L-80 Tbg @ 8977' MD.
Packers & SSSV (type & measured depth) BAKER S-3 PERM PACKER @ 8919' MD.
CAMCO TRDP-4E @ 2019' MD.
13. Stimulation or cement squeeze summary
Intervals treated (measured) N/A
Treatment description including volumes used and final pressure
14. Representative Dailv Average Production or Injection Data
Oil-Bbl Gas-Met Water-Bbl
258 452 1234
Prior to well operation
Subsequent to operation 150 550
15. Attachments
Copies of Logs and Surveys run_
Daily Report of Well Operations _X Oil X Gas
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Signed J I J'
Michael Mooney /'f~ AI{~
Form 10-404 Rev 06/15/88 ·
Title: Wells Team Leader
Plugging _ Perforate _X
Repair well_ Other _
6. Datum elevation (DF or KB feet)
RKB 102 feet
7. Unit or Property name
Kuparuk Unit
8. Well number
1 C-15
9. Permit number / approval number
198-229 /
10. API number
50-029-22932
11. Field 1 Pool
Kuparuk Oil Pool
Measured Depth
121'
6249'
9390'
True vertical Depth
121'
4488'
6840'
RECEIVED
APR
1 2002
AIaskaOH&GaiCons. Commission
AnchoIage
CasinQ Pressure
TubinQ Pressure
221
257
1749
Suspended _
Service
Questions? Call Mike Mooney 263-4574
Date 4/¡/it---:"
Prepared by Sharon Allsup-Drake 263-4612
~
o RIG I N A L stNINEIJ APR 3 0 2002
SUBMIT IN DUPLICATE
Date
02/06/02
02/07/02
02/14/02
02/15/02
02/17/02
)
)
1 C-15 Event H ¡story
Comment
DRIFTED TBG W/23' X 2.565"DUMMY TO 9138' RKB. EST. 12' RATHOLE. (4' ABOVE PROPOSED BTM
PERF). INSTALLED DV @ 8827' RKB. IN PROGRESS. [TAG, GLV]
INSTALLED OV @ 6592' RKB. GLV'S @ 5349' & 33251 RKB. [GLV]
BAILED SAND IN CSG TO -9147' RKB. IN PROGRESS
BAILED FILL IN CSG TO -9151' RKB. +/- 9' RATHOLE BELOW PROPOSED BTM PERF.
PERF C SAND INTERVALS (9096' - 9106') & (9126'- 9142') W/2.5" HSD, 2506 PJ CHGS,6 SPF, 60 DEG
PHASING. TAGGED TD @ 9146' [PERF]
..-.......-....
.. ._.........-.-~.__...
Page 1 of 1
3/15/2002
SCANNED APR 3 0 2002
')
J
,... 30"-0 I
198-229-0
KUPARUK RIV UNIT
1 C-15
50- 029-22932-00 PHILLIPS ALASKA INC
Roll #1: Start: Stop Roll #2:
MD 09390 TVD .9_~§j-º_. t.ði'mpletion Date:
Start Stop
__!~(~Ql98 Completed Status:t-01b___
Current:
T Name Interval Sent Received T/C/D
lV'"'8866 1-3 SPERRY MPT/GR/EWR4/CNP/SLD 01-1 2/24/99 2/24/99
~DGR/CNP/SLD-MD' FINAL 122-9390 01-1 2/24/99 2/24/99
~GR/CNP/SLD-TVD FINAL 121-6840 01-1 2/24/99 2/24/99
,
W'DGRlEWR4-Mp FINAL 122-9390 OH 2/24/99 2/24/99
¿~GRlEWR4-TVD' FINAL 121-6840 01-1 2/24/99 2/24/99
~TAT PRES/TEM FINAL 8980-9126 CH 5 1/6/99 1/15/99
~~'~RVY RPT ~~RY 0-9390. 01-1 12/19/98 12/23/98
<SRVYRPT ~RRY 0~11918. ,~ 01-1 1/27/99 1/28/99
b -'t3{()
~
~---
--_.,-_._..-~
-.--.-.- --------- --
-.-- -,---_..
Thursday, January 25,2001
Page I of I
)
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Phillips Alaska, Inc.
Post Office Box 100360
Anchorage, Alaska 99510-0360
Telephone 907-276-1215
April 28, 2000
Ms. Wendy Mahan
Natural Resource Manager
Alaska Oil and Gas Conservation Commission
3001 Porcupine Drive
Anchorage, Alaska 99501-3192
Re: Kuparuk Area Annular Injection, First Quarter, 2000
Dear Ms. Mahan:
Please find reported below the volumes injected into surface casing by production casing annuli during
the first quarter of 2000, as well as total volumes injected into annuli for which injection authorization
expired during the first quarter of 2000.
Annular Injection during the first quarter of 2000:
h(1) h(2) h(3) Total for Previous New
Well Name Volume Volume Volume Quarter Total Total
)..,~ - I 0 ~ CD1-32 25683 100 0 25783 7548 33331
)'\~- \\~ CD1-42 4320 100 0 4420 387 4807
,~"I .. H 2- CDl-36 33174 100 0 33274 393 33667
'Zt:JO .. C) 3 CD1-38 9064 100 0 9164 0 9164
9.-'-oq8 1L-28 3884 100 0 3984 0 3984
q~- z..z..~
Total Volumes into Annuli for which Injection Authorization Expired during the first quarter 2000:
Total
Volume
Injected
48990
Well Name
IC-15
Total h(l)
Volume
48890
Total h(2)
Volume
100
Total h(3)
Volume
o
Status of Annulus
Open. Freeze Protected
Please call me at 263-4603 should you have any questions.
Sincerely,
?~YI1~
Paul Mazzolini
Drilling Team Leader
r" '-..... _. ,. '--'
')
Randy Thomas
Doug Chester
Kuparuk Environmental: Engel/Snodgrass
B. Morrison and M. Winfree
Sharon Allsup-Drake
Well Files
)
Ms. Wendy Mahan
AOGCC
FirstQuarter 2000 Annular Injection Report
Page Two
,)
ARCO Alaska, Inc.
Post Office Box 100360
Anchorage, Alaska 99510-0360
Telephone 907 2761215
July 27, 1999
Ms. Wendy Mahan
Natural Resource Manager
Alaska Oil and Gas Conservation Commission
3001 Porcupine Drive
Anchorage, Alaska 99501-3192
Re: Kuparuk Area Annular Injection, Second Quarter, 1999
Dear Ms. Mahan:
)
~~
~~
Please find reported below volumes injected into surface casing by production casing annuli during
the second quarter of 1999, as well as total volumes injected into annuli for which injection
authorization expired during the second quarter of 1999.
Annular Injection during the second quarter of 1999:
h(l) h(2) h(3) Total for
Volume Volume Volume Quarter
34380 100 0 32195
3779 100 0 3879
33933 100 0 34033
34216 100 0 34316
12071 100 0 12171
9505 100 0 9605
'98 - 2."Z.- ~
Well Name
1C-15
2L-313
CDl-19
lC-25
CDl-40
1 C-23
'l~-z.. 9
~~'O1..~
1<1 - 03 I
~g 0"'1 ~ 7f
:'I'~ o·-;¡A
Previous
Total
16795
8654
o
o
o
o
New
Total
48990
12533
34033
34316
12171
9605
Total Volumes into Anllulifor which Injection Authorization Expired during the quarter
Total
Total h(l) Total h(2) Total h(3) Volume
Well Name Volume Volume Volume Injected Status of Annulus
'1~- c4a. ID-10 35473 100 0 35573 Open, Freeze Protected
~ 8 - 0" I 2N -323 32696 100 0 32796 Open, Freeze Protected
~ ß c~ z. 2N-343 17895 100 0 17995 Open, Freeze Protected
'"15 - c ~ 1. 2N -329 9 100 0 109 Open, Freeze Protected
Please call me at 263-4603 should you have any questions.
Sincerely,
?~fY1~
Paul Mazzolini
Drilling Team Leader
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Ms. Wendy Mahan
AOGCC
Second Quarter 1999 Annular Injection Report
Page Two
cc: Mike Zanghi
Paul Mazzolini
Randy Thomas
Kuparuk Environmental: Engel/Snodgrass
Morrison and Winfree
Sharon Allsup-Drake
Well Files
, ,
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;907 265 1155
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April 21, 1999
Mr. Blair Wondzell
Alaska Oil and Gas Conservation Commission
3001 Porcupine Drive
Anchorage, Alaska 99501
RE; Request Modification of Annular Pumping Volume Limits
KRU - WelJ IC-I5
Dear Mr. Wondzel1:
As an update to yesterday's facsimile message regarding the referenced annular injection volume,
I am updating you to the current volume injected as of this morning and the antÍcípated volumes
over the next few days. As of midnight, we had injected a cumulative volume of 32,550 barrels
into the annulus of lC~15. OUf cun-ent operations consist of running and cementing our 7"
intennediate casing, which will result in excess of 1,000 barrels of additional volume. It is
anticipated we will be finishing this well up in the next 3 - 4 days and the volume of cuttings and
fluid will easily exceed the 35,000 threshold.
As stated in the facsil1Úle sent yesterday, our only alternative at this point is to 11m an additional
1500" of 2" line to the 1 C-17 well. We believe doing so will greatly increase the risk of a frozen
injection line and the potential for a spill. Exposed surface injection line also poses an increased
safety risk to personnel operating in proximity to pressurized injection lines.
Again, we respectfully request timely dispensation for additional volume allotment up to 50,000
barrels for the IC-15 annu1us in order to avoid the aforementioned risks. Due to the current
volumes already injected and the anticipated volumes to be injected, it is imperative that any
dispensation be granted as soon as possible. Thank you for your immediate attention to this
request.
cc: Mike Zanghi
I-':,~.\
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17 !.~...
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Ales}::J
4-21 -99 ; 10: 1 1 AM; ARCO ALASI<A, I f\lC
;907 265 1155
# 1/ 2
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TONY KNOWLES, GOVERNOR
ALASKA. OIL AMI GAS
CONSERVATION COltDlISSIOlV
3001 PORCUPINE DRIVE
ANCHORAGE, ALASKA 99501-3192
PHONE: (907) 279-1433
FAX: (907) 276-7542
April 20, 1999
Paul Mazzolini
Drilling T earn Leader
ARCO Alaska, Inc. C¡
P.O. Box 100360 ð:}
Anchorage, AK 99510-0360 Ct~ ~
Re: Annular Disposal Waiver Request to Exceed Volume Linútation i~
Dear Mr. Mazzolini:
We have reviewed your April 20, 1999 request for a waiver to 20 AAC 25. 080( d)( 1).
The waiver would allow ARCa to dispose of a volume of fluids greater than 35,000
barrels into the annular space of well 1 C-15. If approved, the waiver would allow the
injection of the remainder of waste generated from drilling well IC-25 into welllC-15.
The remaining total is estimated less than 15,000 barrels.
Although another annulus is available in well 1 C-17, this well is located quite a distance
from the I C-25 well. Injection into the 1 C-17 annulus would require approximately 1500'
of additional injection line. Additional risks of line freeze-up and spill potential would be
incurred if injection into the 1 C-17 annulus is required at this time.
The Commission concludes that the additional fluids generated from drilling of the 1 C- 25
well may be injected into the 1 C-15 annulus.
./
J
Robert N. Christenson, P.E.
Chairman
4-2.0-99; 10: 1 6AM; ARCO ALASI-<A, I NC
i907 265 1155
# 1/ 2.
Fax No. 907.265.1155 )
ARC' Alaska, Inc.
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April 20~ 1999
Mr. Blair W ondzell
Alaska Oil and Gas Conservation Commission
300 I Porcupine Drive
Anchorage~ Alaska' 99501
RE: Request Modification of Annular Pumping Volume Limits
KRU - WelllC-15
Dear Mr. WondzeIl:
ARca Alaska~ Inc. is currently contracting Pool Rig 6 for the drilling program scheduled for IC
Pad in the Gas Storage Area of the Kuparak River Unit. Present drilling operations are underway
on the initial well, I C-25, and via the use of the on-site ball mill, excess drilling fluids and
cuttings are being i~ected into the annulus of well 1 C-15. The target injection annulus was
permitted for annular injection in January 1999 and had previously accepted 16,805 barrels
during drilling operations undertaken by Parker 245 on ] C pad earlier this year.
Our current operations have resulted in a cumulative injection volume into the 1 C-15 annulus of
32,105 barrels of fluid to date, with additional volumes expected from lC-25 operations.
Although I C-17 is also a pennitted annulus for injection, we are requesting a modification to the
existing 35,000 barrel per annuli injection limitation in order to allow ARCO to finish operations
on IC-25 by contÜming to inject into IC-I5. It is anticipated the remaining volumes from lC-25
will not exceed 15~OOO additional barrels.
The request for the volume dispensation will allow us to continue to inject into the IC-I5 and
avoid the -1500' of additional injection line necessary to inject into the IC-I7 annulus. We
believe by avoiding running additional injection line, we greatly reduce the likelihood of line
freeze up during periods of no injection and ultimately a reduced risk for line breakage and spills.
The additional volume to inject is not anticipated to result in additional risk to the IC-IS well
annulus.
As stated earlier, we are approaching the regulated injection limit of 35,000 barrels into IC-I5.
Therefore we respectfully request a prompt response to this dsipensation in order to avoid
conflicting with AOGCC regulations and to prudently handle additional volumes from lC-25. If
you have any questions, please contact Bill Lloyd at 265-6531 or Paul Mazzolini at 263-4603.
Sincerely,
?JfY7~
Paul Mazzolini
Drillíng Team Leader
Cc: Mike Zanghi
ARca Alaska, Inc. \
Post Office Box . vJ360
Anchorage Alaska 99510-0360
Telephone 907 276 1215
April 9, 1999
Ms. Wendy Mahan
Natural Resource Manager
Alaska Oil and Gas Conservation Commission
3001 Porcupine Drive
Anchorage, Alaska 99501-3192
Re: Kuparuk Area Annular Injection, First Quarter, 1999
Dear Ms. Mahan:
)
9a,
èè.~
~~
~~
Please find reported below volumes injected into surface casing by production casing annuli during
the first quarter of 1999, as well as total volumes injected into annuli for which injection
authorization expired during the first quarter of 1999.
Annular Injection during the first quarter of 1999:
h(l) h(2) h(3)
Volume Volume Volume
25326 100 0
8397 100 0
27507 100 0
15 0 0
4202 100 0
16695 100 0
8554 100 0
Well Name
2N-315
2L-325
2N-321A
3K-23
3K-25
lC-15
2L-313
Total for
Quarter
25426
8497
27607
15
4302
16795
8654
Previous
Total
See Note #1 below
11883
o
o
o
o
o
New
Total
25426
20380
27607
15
4302
16795
8654
Note #1: Well # 2N-315. The previollsly reported volume (~t'220 barrels was pumped into this annulus durin!? the drilling of the well. This was the
volume required to flush andfreeze protect the annulus durin!? initial drillin!? operations. not a volume of disposal fluids injected prior to the receipt of
authorization fÓr annular injection.
Total Volumes into Annuli for which Injection Authorization Expired during the quarter
Total
Volume
Injected
35095
26900
Well Name
1 C-12
1 C-13
Total h(l)
Volume
34995
26800
Total h(2)
Volume
100
100
Total h(3)
Volume
o
o
Status of Annulus
Open, Freeze Protected
Open, Freeze Protected
Additionally, to prevent any possible confusion regarding previous reports of volumes injected, and
to insure that the State's records are in agreement with ARCO's, we would like to repeat and
supplement information we provided with our letter of February 26,1999. The information below is
only for those wells for which injection volumes may not have been properly reported at the time of
injection. Again, these volumes are the same as those reported with our February 26th letter, and are
only reported here again for the sake of clarity.
ARCO Alaska. Inc. is a Subsidiary of Atlantic Richfield Company
AR3B-6003-C
)
)
Ms. Wendy Mahan
AOGCC
First Quarter 1999 Annular Injection Report
Page Two
Total
Total h(l) Total h(2) Total h(3) Volume Current Status of
Well Name Volume Volume Volume Injected Annulus
2A-22 16749 100 0 16849 Open, Freeze Protected
2F -19 20725 100 0 20825 Open, Freeze Protected
3K-27 37173 100 0 37273 Open, Freeze Protected
3K-26 33970 100 0 34070 Open, Freeze Protected
lE-31 33645 100 0 33745 Open, Freeze Protected
lE-32 45205 100 0 45305 Open, Freeze Protected
3Q-22 6245 100 0 6345 Open, Freeze Protected
lQ-24 23158 100 0 23258 Open, Freeze Protected
lQ-26 25931 100 0 26031 Open, Freeze Protected
Please call me at 263-4603 should you have any questions.
Sincerel y,
7~fYJ+--
Paul Mazzolini
Drilling Team Leader
cc: Mike Zanghi
Paul Mazzolini
Randy Thomas
Kuparuk Environmental: Engel/Snodgrass
Morrison and Winfree
Sharon Allsup-Drake
Steve McKeever
Well Files
)
,)
5pe~~V-5un
CRIL.L.ING SERVICES
WELL LOG TRANSMITTAL
To:
State of Alaska
Alaska Oil and Gas Conservation Comm.
Attn.: Lori Taylor
3001 Porcupine Dr.
Anchorage, Alaska 99501
February 24, 1999
RE:
9~' ~~9
MWD Formation Evaluation Logs lC-15, AK-l\t1M-90033
The technical data listed below is being submitted herewith. Please address any problems or concerns
to the attention of
Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518
IC-I5:
2" x 5" rvm Resistivity & Gamma Ray Logs:
50-029-22932-00
1 Blueline
1 Folded Sepia
2" x 5" TVD Resistivity & Gamma Ray Logs:
50-029-22932-00
1 Blueline
1 Folded Sepia
2" x 5":MD Neutron & Density Logs:
50-029-22932-00
1 Blueline
1 Folded Sepia
2" x 5" TVD Neutron & Density Logs:
50-029-22932-00
1 Blueline
1 Folded Sepia
-;)
C'
....'~ ",' :,1.;
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."~.'~:.,.,:'.).;
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:....:J..
......¡.....
5631 Silverado Way, Suite G · Anchorage, Alaska 99518 . (907) 273-3500 . Fax (907) 273-3535
A Halliburton Company
y
sper'r'\I-5Un
CRILLING SERVICES
)
WELL LOG TRANSMITTAL
To: State of Alaska February 24, 1999
Alaska Oil and Gas Conservation Comm.
Attn.: Lori Taylor ?~
3001 Porcupine Dr. 1>.? l2
Anchorage, Alaska 99501 '1 ~ 1; 1; \s;;
RE: MWD Formation Evaluation Logs lC-15, AK-1\1M-90033
1 LDWG formatted Disc with verification listing.
API#: 50-029-22932-00
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COpy
OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:
Sperry-Sun Drilling Service
Attn: Ali Turker
5631 Silverado Way, Suite G.
Anchorage, Alask~ 9951.:~....
. I' ,¡'~: S ~;t
Date:
',.: 1~'1'1 ::J. \, ",~'.. ~ '-' ..........
:·~'·~C;1·:~: :;:,...:~~..;,
5631 Silverado Way, Suite G . Anchorage, Alaska 99518 . (907) 273-3500 . Fax (907) 273-3535
A Halliburton Company
)
)
~~
~~
ARCO Alaska, Inc.
Post Office Box 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
January 20, 1999
Mr. Robert Christenson
Commissioner
State of Alaska
Alaska Oil & Gas Conservation Commission
3001 Porcupine Drive
Anchorage, Alaska 99501
RECEIVED
JAN 20 1999
NaskaOil & Gas Cons. Commission
Anchorage
Subject: IC-I5 (Permit No. 98-229) Well Completion Report
OR\G\NAL
Dear Mr. Commissioner:
Enclosed is the well completion report for the completion on KRU IC-I5.
If there are any questions, please call 265-6890.
Sincerely,
~~. c:k.Q
G. C. Alvord
Kuparuk Drilling Team Leader
AAI Drilling
GCA/skad
1 Status of Well
) STATE OF ALASKA )
.\lASKA Oil AND GAS CONSERVATION COMMISSION '
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
Classification of Service Well
Oil []] GAS D
2 Name of Operator
ARCO Alaska, Inc
3 Address
P.O. Box 100360, Anchorage, AK 99510-0360
4 location of well at surface
SUSPENDED D
ABANDONED:]
SERVI CE 0--------------------------
7 Permit Number
98-229
8 API Number
'1",'
50-029-22932
9 Unit or lease Name
1634' FNl, 1239' FWl, Sec. 12, T11N, R10E, UM
At Top Producing Interval
: ,~Li~:
t¿7;~.V~
~.
. ~'.._....u......~
t· ,,-.J,...... ~..."
~ '....~.-M\ ..W\:\!I\I:"'i!·
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)·t'
~i;>~\. '; .,.,.~
t-'·", '''~~ I-'~~
i¡.::~~,:.,.;.~~;t~=., .:
Kuparuk River Unit
10 Well Number
296' FSl, 1524' FWl, See 6, T11N, R11E, UM
At Total Depth
1 C-15
11 Field and Pool
341' FSl, 1648' FWl, Sec. 6, T11N, R11E, UM
5 Elevation in feet (indicate KB, OF, etc.)
RKB 41" Pad 60'
12 Date Spudded
04-Dec-98
6 lease Designation and Serial No.
KUPARUK RIVER
Kuparuk River Oil Pool
17 Total Depth (MD+TVD)
9390' MD & 6840' TVD
13 Date T.D. Reached
12-Dec-98
18 Plug Back Depth (MD+TVD)
9300' MD & 6759' TVD
ADl 28242 AlK 2292
14 Date Compo , Susp. or Aband~115 Water Depth, if offshore 116 No. of Completions
~ ~~"", NA feet MSl 1
19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost
YES ~ NO D 2019 feet MD 2020 APPROX
22 Type Electric or Other logs Run
MWD/GR/ReslDen-Neu, CCl
CASING SIZE wr
16" 62.5#
9.625" 40#
7" 26#
CASING, LINER AND CEMENTING RECORD
SETTING DEPTH MD I
GRADE TOP BTM HOLE SIZE CEMENT RECORD
H-40 SURF. 121' 24" 9 cu yds. High Early
l-80 SURF. 6249' 12.25" 850 sx ASIII lW, 610 sx Class G
l-80 SURF. 9390' 8.5" 178 sx Class G
23
24 Perforations open to Production (MD+TVD of Top and Bottom and
interval, size and number)
3.5"
TUBING RECORD
DEPTH SET (MD) PACKER SET (MD)
8977' 8919'
25
SIZE
9106'-9126' MD 6585'-6603' TVD
4 spf
26 ACID, FRACTURE, CEMENT SQUEEZE, ETC
DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED
9106'-9126' see attachments
27
Date First Production
1/18/99
Date of Test Hours Tested
1/19/99 12
Flow Tubing Casing Pressure
Press. 220 0
PRODUCTION TEST
Method of Operation (Flowing, gas lift, etc.)
Flowing
PRODUCTION FOROll-BBl GAS-MCF
TEST PERIOD 1388 756
CALCULATED Oll-BBl GAS-MCF
WATER-BBl CHOKE SIZE GAS-Oil RATIO
290
176
554
WATER-BBl Oil GRAVITY-API (corr)
24-HOUR RATE:
2715
1503
580
o
28 CORE DATA
Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips.
N/A
OR\G\NAl RtCE\VEO
~., ~.: '20 1999
. . I ~S\Of¡
~ - ~- ."-'¡ '(~~l'''~' .j.....',:;,..¡,,'~.
/\'\ ~ 1'1. ~ ,vL
I"\. as .~ ..." .Änch'JragB
Form 10-407
Rev. 7-1-80
Submit in duplicate
CONTINUED ON REVERSE SIDE
,)
)
9.
30.
GEOLOGIC MARKERS
FORMATION TESTS
MEAS DEPTH
Include interval tested, pressure data, all fluids recovered and gravity,
TRUE VERT. DEPTH GOR, and time of each phase.
NAME
Top Kuparuk C
Top Kuparuk A
9089'
9390'
6569'
6840'
Annulus left open - freeze protected with diesel.
31. LIST OF ATTACHMENTS
Summary of Daily Drilling Reports, Directional Survey
32. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Signed Þ t. ~
Title ~. p,(, T~ L....&..r DATE tJ b ( 9~
prepare-d ~ Narilh/Number Sharon Allsup-Drake/263-4612
INSTRUCTIONS
General: This form is designed for submitting a complete and correct well completion report and log on
all types of lands and leases in Alaska.
Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt
water disposal, water supply for injection, observation, injection for in-situ combustion.
Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements
given in other spaces on this form and in any attachments.
Item 16 and 24: If this well is completed for separate production from more than one interval (multiple
completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported
in item 27. Submit a separate form for each additional interval to be separately produced, showing the
data pertinent to such interval.
Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.).
Item 23: Attached supplemental records for this well should show the details of any multiple stage cement-
ing and the location of the cementing tool.
Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In-
jection, Gas Injection, Shut-in, Other-explain.
Item 28: If no cores taken, indicate "none".
Form 10-407
Date: 1/8/99
)
)
ARCO ALASKA INC.
WELL SUMMARY REPORT
Page: 1
--------------------------------------------------------------------------------
--------------------------------------------------------------------------------
WELL:1C-15
WELL ID: AK9141 TYPE:
AFC: AK9141
STATE:ALASKA
AREA/CNTY: NORTH SLOPE EAST
FIELD: KUPARUK RIVER UNIT
SPUD:12/04/98 START COMP:
RIG:RIG # 245
WI: 0% SECURITY:O
API NUMBER: 50-029-22932-00
--------------------------------------------------------------------------------
--------------------------------------------------------------------------------
BLOCK:
FINAL:
12/03/98 (D1) MW:
TD: 0' ( 0) DRILLING
SUPV:G.R. WHITLOCK
12/04/98 (D2)
TD: 1353' (1353)
SUPV:G.R. WHITLOCK
12/05/98 (D3)
TD: 3670' (2317)
SUPV:G.R. WHITLOCK
12/06/98 (D4)
TD: 5434' (1764)
SUPV:G.R. WHITLOCK
12/07/98 (D5)
TD: 6259' ( 825)
SUPV:G.R. WHITLOCK
12/08/98 (D6)
TD: 6259' ( 0)
SUPV:DON E. BREEDEN
9.2 VISC: 138 PV/YP: 35/45 APIWL: 8.9
RIG ON HIGHLINE 3.5 HRS
Move rig to 1C-15 and accept at 1330 hrs. 12/3/98. N/U
diverter stack.
MW: 10.1 VISC: 186 PV/YP: 45/66
DRILLING @2300' RIG ON HIGHLINE 24 HRS
APIWL:
6.2
Function test diverter. Drill from 121'-621'. Lot of fine
gravel plus shaker screen blanking off caused overloading
of ball mill. Drill from 621' to 1259'. Encountered gas cut
mud at 1201'. Circulated out gas cut mud. Drill from 1259'
to 1353'.
MW: 10.2 VISC: 185 PV/YP: 48/56
DRILLING @ 4390 RIG ON HIGHLINE 24 HRS
APIWL:
5.5
Drill from 1353' to 2659'. Circ out gas cut mud. Drill from
2659' to 2847'. Circ hole clean. RIH. Tight from 710' to
1200'. Drill from 2847' to 3670'.
MW: 10.2 VISC: 202 PV/YP: 47/51
DRILLING @ 5608'
APIWL: 5.8
RIG ON H
Circ gas cut mud, MW cut to 7.3 ppg. Drill from 3670' to
5434'. Circ low vis sweep around. POOH. Started to swab at
1450' .
MW: 10.3 VISC: 168 PV/YP: 41/56 APIWL: 5.8
CIRCULATIN RIG ON HIGHLINE 24 HR
RIH, hit bridges @ 1324' to 1357'. Drill from 5434' to
6259'. POOH to 1500' (tight spot). Circ and wash through
tight spot from 1500' to 1250'. RIH w/hole opener assembly.
Hit bridge @ 1600'.
MW: 10.4 VISC: 135 PV/YP: 47/60 APIWL: 5.8
CIRCULATE TO CONDITION MUD & HOLE FOR CEMENTING @ 0530.
Wash and ream from 1600' to 1800'. CBU. Wash and ream
through tight spot from 2268' to 2200'. Run 9-5/8" casing.
)
\
)
Date: 1/8/99
ARCO ALASKA INC.
WELL SUMMARY REPORT
12/09/98 (D7)
TD: 6259' ( 0)
SUPV:DON E. BREEDEN
MW: 10.2 VISC: 66 PV/YP: 27/29
DRILLING OUT 9-5/8" CASING.
Page: 2
APIWL:
6.0
Run 9-5/8" casing. Pump cement. NU BOPE and test to
300/3000 psi.
12/10/98 (D8) MW: 8.8 VISC: 47 PV/YP: 13/21
TD: 7600' (1341) DRILLING @ 8075'
SUPV:DON E. BREEDEN
APIWL: 7.6
Drill out cement and floats to 6249'. Drill 20' new hole to
6279'. Perform FIT to 16.0 ppg EMW, no leak-off. Drill 30'
more hole to 6309'. Re-test formation, 15.7 ppg EMW. Drill
from 6309' to 7600'.
12/11/98 (D9) MW: 10.2 VISC: 52 PV/YP: 21/25
TD: 9024' (1424) DRILLING @ 9125'
SUPV:DON E. BREEDEN
APIWL: 4.6
Drill from 7600' to 8932'. Test formation, 13.3+ ppg EMW.
Drill to 9024'. Weight up to 10.2 ppg.
12/12/98 (DI0) MW: 10.3 VISC: 50 PV/YP: 18/31
TD: 9390'( 366) PRE-JOB SAFETY MEETING ,ON RUNNING 7" CASING
SUPV:DON E. BREEDEN
Drill from 9024' to 9390' .
12/13/98 (Dll) MW: 8.7 VISC: o PV/YP: 0/ 0
TD: 9390' ( 0) NU BOP STACK
SUPV:DON E. BREEDEN
Run 7" casing. Pump cement.
APIWL: 3.8
APIWL: 0.0
12/14/98 (D12)
TD: 9390' ( 0)
SUPV:DON E. BREEDEN
MW: 8.7 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0
REVERSING 88 BBLS DIESEL INTO 3-1/2" X 7" ANNULUS (WILL U-TU
ND BOPE. NU BOPE and test to 300/3500 psi. Run 3.5"
completion assembly.
12/15/98 (D13) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0
TD: 9390' (0) RIG RELEASED
SUPV:DEARL W. GLADDEN
Run 3.5" tubing. Freeze protect well. ND BOP. NU master
valve and test to 5000 psi. Release rig @ 1300 hrs. 12/15/98
RE(E~VED
, 1\ !<" 0 0 1099
d¡.....l~ ,(.- ;:¡"
,Alaska OB & Gas Cons. Commlssîon
Anchorage
ARCO Alaska, Inc.
')
)
KUPARUK RIVER UNIT
WELL SERVICE REPORT
K1 (1 C-15(W4-6))
JOB NUMBER
1226981601.2
UNIT NUMBER
WELL
1 C-15
DATE
12/30/98
DAY
1
FIELD
ESTIMATE
~~
"'".
JOB SCOPE
PERFORATE, PERF SUPPORT
DAILY WORK
PERFORATE/SBHP
OPERATION COMPLETE SUCCESSFUL
YES YES
KEY PERSON
ALLDREDGE
SUPERVISOR
SCHUROSKY
Signed
AFC#
999151
Initial Tbg Press
400 PSI
CC#
230DS10CG
Final Tbg Press
600 PSI
Initial Inner Ann
o PSI
Final Inner Ann Initial Outer Ann Final Outer Ann
o PSI 250 PSI 250 PSI
CAlLY SUMMARY
PERFORATE 20' OF C SAND FROM 9106' TO 9126'. USED 2- 1/2" HC GUN WITH 4 SPF, DP CHARGES. 180 DEG PHASE AND +1-
90 DEG FROM BOTTOM ORIENTATION. TAKE SBHP AT 9126' OF 3397 PSI AND 8980' OF 3335 PSI FOR 20 MIN STOPS.[Perf,
Pressure Data]
TIME LOG ENTRY
07:30 MIRU SWS E-LlNE, HOLD TGSM. PERF GUN SAFETY.
08:30 TEST TOOLS AND PU 20' GUN.
09:30 PT LUB AND BOP TO 3000 PSI.
10:00 RIH WITH GUN GAMMARAY, CCL, 20' X 2.5" HC WITH 4 SPF DP, 180 DEG PHASING AND ORIENTED TO +1- 90
DEG FROM BOTTOM.
11:15 AT 9250' E-LlNE DEPTH. LOG UP AND TIE IN TO MWD GAMMA RAY LOG FOR DEPTH CONTROL.BLEED
WELLHEAD TO 0 PSI.
12:15 SHOOT PERF GUN 9106' TO 9126' WITH GOOD INDICATION AT SURFACE, WELLHEAD PRESSURE INCREASE
TO 500 PSI. LOG COLLARS COMMING UP. POOH.
14:00 AT SURFACE WITH GUN, CHECK FOR DUDS. ALL SHOTS FIRED. MAKE UP PRESSUREfTEMP TOOLS.
15:00 RIH WITH GAMMARAY, CCL, PRESSUREfTEMP. TO 9126' FOR 20 MINS AND 8980' FOR 20 MINS SBHP. 3397 PSI
@ 9126' AND 3335 PSI @ 8980'
16:30 POOH.
17:30 RDMO.
ARCO Alaska, Inc.
~~
~".
JOB SCOPE
FRAC, FRAC SUPPORT
DAILY WORK
IC' SAND FRAC
OPERATION COMPLETE
YES
WELL
1 C-15
DATE
01/11/99
DAY
1
FIELD
ESTIMATE
J
)
KUPARUK RIVER UNIT
WELL SERVICE REPORT
K1 (1 C-15(W4-6»
JOB NUMBER
0110991551.6
UNIT NUMBER
SUCCESSFUL
YES
KEY PERSON
OS-YOAKUM
SUPERVISOR
SMITH
AFC#
999151
Initial Tbg Press
900 PSI
CC#
230DS10CG
Final Tbg Press
900 PSI
Signed
Initial Inner Ann
o PSI
Final Inner Ann Initial Outer Ann Final Outer Ann
o PSI 250 PSI 725 PSI
DAILY SUMMARY
PUMP 'C' SAND FRAC @ 15 BPM WI 50# DELAYED XL GW. TOTAL PROP PUMPED= 54,200#. PROP PLACED IN PERFS=
52,001#. PROP LEFT IN THE WELLBORE= 2199#. MAX TREATING PSI=6345. NO TSO. JOB DESIGN WAS 49,625#.10 PPA PROP
@ PERFS. EST. TOP OF FILL @ 9193'.[Frac-Refrac]
TIME LOG ENTRY
05:30 MIRU FRAC EQUIPMENT.
07:35 SAFETY MTG, 16 PEOPLE ON SITE.
08:20 PRIME UP PUMPS & PT TREATING LINE TO 10,000 PSI. GOOD TEST.
08:25 PUMP 200 BBL SW @ 30 BPM; WHTP=5360 PSI.
08:32 PUMP 50 BBL BD STAGE 50# DEL. XL GW, 15 BPM; WHTP=3804 PSI.
08:35 PUMP 50 BBL 1 PPA 20/4050# DEL XL GW, 15 BPM; WHTP=3905 PSI.
08:38 PUMP FLUSH 10 BBL 50# DEL XL GW, 15 BPM; WHTP=5300 PSI.
08:39 PUMP FLUSH 115 BBLS SW, 15 BPM; WHTP=5319 PSI. PERFORM STEP DOWN RATE TEST AT END OF FLUSH
STAGE @ 13, 8 & 5 BPM RATES.
08:48 SHUTDOWN, OBTAIN ISIP= 1823 PSI CLOSURE PSI= +1- 1702 PSI.
09:00 PUMP 75 BBL 50# DEL XL GW, 5 BPM; WHTP= 2083 PSI.I2490 PSI.
09:13 PUMP 15 BBL SW FLUSH, 15 BPM; WHTP= 4440 PSI.
09:14 PUMP 80 BBL SW FLUSH, 15 BPM; WHTP= 4880 PSI. 14070 PSI.
09:20 SHUTDOWN; ISIP= 1946 PSI. CP=1695 PSI. DECREASE PAD BY 10 BBLS. FG= .70
10:00 PUMP 80 BBL PAD, 5 BPM 50# DEL XL GW; WHTP= 2719 PSI 13081 PSI.
10:13 PUMP 25 BBL 15 BPM, 2 PPA 12/18 50# DEL XL GW; WHTP= 4829 PSI
10:16 PUMP 125 BBL STG 15 BPM, 3.5 PPA RAMP 12/1850# DEL XL GW; WHTP= 5400 PSI.I5560 PSI.
10:23 PUMP 121 BBL STG 15 BPM, 6 PPA RAMP TO 10 PPA 12/1850# DEL XL GW; WHTP= 5246 PSI/5173 PSI.
10:31 PUMP FLUSH 7 BBL 15 BPM, DEL XL GW; WHTP= 5365 PSI.
10:32 PUMP FLUSH 38 BBL, 15 BPM SW; WHTP= 4999 PSI.
10:35 PUMP 35 BBL DSL, 15 BPM; WHTP= 4436 PSI.
10:38 SHUTDOWN. ISIP= 2130 PSI.
')
')
TIME LOG ENTRY
11 :00 START RIGGING DOWN FRAC EQUIPMENT. BLED IA PRESS. DOWN TO 0 PSI.
RECEIVED
"rAN 20 '1999
Alaska Oil & Gas Cons. Commission
Anchorage
= SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-02510 Sidetrack No. Page of 3
Company ARCO A~SKA, INC. Rig Contractor & No. PARKER DRILLlNG,CO - #245. Field KUPARUK RIVER UNIT
Well Name & No. 1 C-PAD/1 C#15 Survey Section Name SPERRY SUN BHI Rep.
INì~ WELL DATA
Target lVD (FT) Target Coord. NIS Slot Coord. NIS -1634.00 Grid Correction 0.000 Depths Measured From:RKB g¡ MSLD SSD
Target Description Target Coord. ENI Slot Coord. 5IW 1239.00 Magn. Declination 27.360 Calculation Method MINIMUM CURVATURE
Target Direction (DO) Build\Walk\DL per: 100ft~ 30mD 10mD Vert. Sec. Azim. 70.91 Magn. to Map Corr. 27.360 Map North to: OTHER
SURVEY DATA
Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate
Date Tool Depth Angle Direction Length lVD Section N(+) I S(-) E(+) I W(-) DL Build (+) Right (+) Comment
Type (FT) (DO) (DO) (FT) (FT) (FT) (FT) (per 100FT) Drop (-) Left (-)
0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT
04-DEC-98 MWD 121.00 0.00 0.00 121.00 121.00 0.00 0.00 0.00 0.00 0.00 9 1/2"MACH 1 C-AK0-1.3deg. ~
04-DEC-98 MWD 196.57 0.50 130.09 75.57 196.57 0.17 -0.21 0.25 0.66 0.66 .~
04-DEC-98 MWD 289.29 1.14 66.42 92.72 289.28 1.30 -0.10 1.41 1.10 0.69
04-DEC-98 MWD 380.51 4.08 33.86 91.22 380.40 4.79 2.95 4.05 3.48 3.22
04-DEC-98 MWD 467.75 6.68 55.71 87.24 467.26 12.17 8.39 9.97 3.74 2.98 25.05
04-DEC-98 MWD 560.18 9.39 60.53 92.43 558.77 24.77 15.13 20.98 3.02 2.93 5.21
04-DEC-98 MWD 650.83 13.14 66.05 90.65 647.66 42.32 22.96 36.84 4.30 4.14 6.09
04-DEC-98 MWD 741.09 17.12 67.00 90.26 734.78 65.81 32.31 58.45 4.42 4.41 1.05
04-DEC-98 MWD 832.29 18.86 65.72 91.20 821.51 93.88 43.62 84.25 1.96 1.91 -1 .40
04-DEC-98 MWD 923.54 20.46 65.15 91.25 907.44 124.44 56.39 112.17 1.77 1.75 -0.62
04-DEC-98 MWD 1014.48 23.36 65.63 90.94 991 .80 158.21 70.51 143.02 3.19 3.19 0.53
04-DEC-98 MWD 1103.11 27.00 66.55 88.63 1072.00 195.78 85.77 177.49 4.13 4.11 1.04
04-DEC-98 MWD 1197.49 29.90 68.54 94.38 1154.97 240.66 1 02.91 219.05 3.23 3.07 2.11 ~
04-DEC-98 MWD 1291.89 31.46 70.16 94.40 1236.16 288.80 119.88 264.12 1.87 1.65 1.72 '~
05-DEC-98 MWD 1385.95 32.69 69.77 94.06 1315.86 338.74 136.99 311.05 1.33 1.31 -0.41
05-DEC-98 MWD 1477.32 34.43 70.72 91.37 1392.00 389.25 154.06 358.58 1.99 1.90 1.04
05-DEC-98 MWD 1571 .48 37.23 70.85 94.16 1468.33 444.36 172.19 410.63 2.97 2.97 0.14
05-DEC-98 MWD 1664.87 39.16 71.25 93.39 1541.72 502.11 190.94 465.24 2.08 2.07 0.43
05-DEC-98 MWD 1758.49 41.94 72.39 93.62 1612.85 562.95 209.91 523.07 3.07 2.97 1.22
05-DEC-98 MWD 1848.37 44.10 70.80 89.88 1678.56 624.26 229.29 581 .24 2.69 2.40 -1.77
05-DEC-98 MWD 1943.70 46.67 71.27 95.33 1745.51 692.12 251.33 645.41 2.72 2.70 0.49
05-DEC-98 MWD 2037.62 49.79 71.28 93.92 1808.07 762.15 273.82 711 .74 3.32 3.32 0.01
05-DEC-98 MWD 2224.79 50.89 70.27 187.17 1927.53 906.24 321 .27 847.79 0.72 0.59 -0.54
~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-02510 Sidetrack No. Page 2 of 3
-
Company ARCO ALASKA, INC. Rig Contractor & No. PARKER DRILLlNG,CO - #245. Field KUPARUK RNER UNIT
Well Name & No. 1 C-PAD/1 C#15 Survey Section Name SPERRY SUN BHI Rep.
'IV,Æ:Q
WELL DATA
Target ND (FT) Target Coord. NIS Slot Coord. NIS -1634.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSLD SSD
Target Description Target Coord. E/W Slot Coord. E/W 1239.00 Magn. Declination 27.360 Calculation Method MINIMUM CURVATURE
Target Direction (DO) Build\Walk\DL per: 100ft~ 30mD 10mD Vert. Sec. Azim. 70.91 Magn. to Map Corr. 27.360 Map North to: OTHER
SURVEY DATA
Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate
Date Tool Depth Angle Direction Length ND Section N(+) I S(-) E(+) I W(-) DL Build (+) Right (+) Comment
Type (FT) (DO) (DO) (FT) (FT) (FT) (FT) (per 100FT) Drop (-) Left (-)
05-DEC-98 MWD 2503.73 51.94 72.55 278.94 2101.51 1124.24 390.74 1054.44 0.74 0.38 0.82 9 1//2"MACH 1 XL-AK0-1.3deg.
05-DEC-98 MWD 2783.32 52.92 73.39 279.59 2271 .98 1345.70 455.63 1266.33 0.42 0.35 0.30 ~
05-DEC-98 MWD ~'-
3067.10 52.53 71.37 283.78 2443.86 1571 .42 523.97 1481.53 0.58 -0.14 -0.71
05-DEC-98 MWD 3349.36 51 .49 71.27 282.26 2617.60 1793.87 595.22 1692.26 0.37 -0.37 -0.04
06-DEC-98 MWD 3623.77 50.91 71.88 274.41 2789.54 2007.71 662.81 1895.15 0.27 -0.21 0.22
06-DEC-98 MWD 3903.44 49.96 71.48 279.67 2967.68 2223.28 730.57 2099.82 0.36 -0.34 -0.14
06-DEC-98 MWD 4183.63 49.15 72.04 280.19 3149.44 2436.49 797.32 2302.34 0.33 -0.29 0.20
06-DEC-98 MWD 4467.50 50.06 70.72 283.87 3333.41 2652.66 866.36 2507.20 0.48 0.32 -0.47
06-DEC-98 MWD 4741.49 49.56 70.89 273.99 3510.22 2861 .97 935.18 2704.86 0.19 -0.18 0.06
06-DEC-98 MWD 5020.73 48.05 70.27 279.24 3694.13 3072.07 1005.03 2903.03 0.57 -0.54 -0.22
06-DEC-98 MWD 5299.76 50.60 70.73 279.03 3875.98 3283.67 1075.65 3102.50 0.92 0.91 0.16
07-DEC-98 MWD 5581.65 49.01 70.41 281.89 4057.90 3498.98 1147.26 3305.55 0.57 -0.56 -0.11
07 -DEC-98 MWD 5862.52 50.35 70.50 280.87 4239.63 3713.12 1218.90 3507.36 0.48 0.48 0.03
07-DEC-98 MWD 6196.13 49.65 69.58 333.61 4454.08 3968.64 1306.13 3747.56 0.30 -0.21 -0.28 ~
9-
10-DEC-98 MWD 6421 .92 50.05 69.01 225.79 4599.66 4141.16 1367.15 3909.00 0.26 0.18 -0.25 6 3/4"MACH 1XL-AKO-1.2 DEG. .~
10-DEC-98 MWD 6700.19 49.58 72.04 278.27 4779.24 4353.70 1438.03 4109.37 0.85 -0.17 1.09
10-DEC-98 MWD 6980.93 49.32 72.33 280.74 4961 .76 4566.96 1503.29 4312.46 0.12 -0.09 0.10
10-DEC-98 MWD 7263.47 48.62 72.19 282.54 . 5147.23 4780.04 1568.24 4515.46 0.25 -0.25 -0.05·
11-DEC-98 MWD 7544.25 48.24 73.78 280.78 5333.54 4989.95 1629.71 4716.32 0.44 -0.14 0.57
11-DEC-98 MWD 7820.39 47.69 73.60 276.14 5518.44 5194.81 1687.31 4913.16 0.20 -0.20 -0.07
11-DEC-98 MWD 7913.39 43.94 72.36 93.00 5583.25 5261.44 1706.80 4976.93 4.14 -4.03 -1.33
11-DEC-98 MWD 8006.26 41.17 70.16 92.87 5651 .66 5324.23 1726.94 5036.40 3.39 -2.98 -2.37
11-DEC-98 MWD 8098.97 40.41 69.32 92.71 5721.85 5384.78 1747.91 5093.22 1.01 -0.82 -0.91
11-DEC-98 MWD 8193.04 37.71 67.96 94.07 5794.89 5444.01 1769.48 5148.42 3.01 -2.87 -1 .45
~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-02510 Sidetrack No. Page 3 of 3
Company ARCO ALASKA, INC. Rig Contractor & No. PARKER DRILLlNG,CO - #245. Field KUPARUK RNER UNIT
Well Name & No. 1 C-PAD/1 C#15 Survey Section Name SPERRY SUN BHI Rep.
IN.Æ:Q
WELL DATA
Target TVD (F1) Target Coord. NIS Slot Coord. NIS -1634.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL 0 SSD
Target Description Target Coord. E/W Slot Coord. E/W 1239.00 Magn. Declination 27.360 Calculation Method MINIMUM CURVATURE
Target Direction (DO) Build\Walk\DL per: 100ft~ 3OmO 10mO Vert. Sec. Azim. 70.91 Magn. to Map Corr. 27.360 Map North to: OTHER
SURVEY-DATA
Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate
Date Tool Depth Angle Direction Length TVD Section N(+) I S(-) E(+) IW(-) DL Build (+) Right (+) Comment
Type (FT) (DO) (DO) (FT) (F1) (F1) (F1) (per 100FT) Drop (-) Left (-)
11-DEC-98 MWD 8286.24 35.49 67.64 93.20 5869.71 5499.49 1790.47 5199.87 2.39 -2.38 -0.34 6 3/4"MACH 1 XL-AK0-1.2 DEG.
11-DEC-98 MWD 8376.67 35.21 68.13 90.43 5943.46 5551.74 1810.17 5248.34 0.44 -0.31 0.54 ,
J_
11-DEC-98 MWD 8470.34 32.20 67.73 93.67 6021.38 5603.64 1829.69 5296.51 3.22 -3.21 -0.43
11-DEC-98 MWD 8563.98 29.76 66.87 93.64 6101 .66 5651.74 1848.28 5340.98 2.65 -2.61 -0.92
11-DEC-98 MWD 8656.64 29.30 67.53 92.66 6182.28 5697.31 1865.98 5383.08 0.61 -0.50 0.71
11-DEC-98 MWD 8750.51 26.55 70.22 93.87 6265.22 5741.23 1881.86 5424.05 3.22 -2.93 2.87
11-DEC-98 MWD 8840.81 26.05 70.41 90.30 6346.17 5781.24 1895.34 5461.72 0.56 -0.55 0.21
11-DEC-98 MWD 8931.76 26.09 69.79 90.95 6427.86 5821 .20 1908.94 5499.31 0.30 0.04 -0.68
12-DEC-98 MWD 9020.72 25.79 70.38 88.96 6507.86 5860.11 1922.20 5535.89 0.44 -0.34 0.66
12-DEC-98 MWD 9119.72 25.80 70.18 99.00 6597.00 5903.19 1936.73 5576.44 0.09 0.01 -0.20
12-DEC-98 MWD 9214.01 26.09 69.78 94.29 6681.78 5944.44 1950.86 5615.20 0.36 0.31 -0.42
12-DEC-98 MWD 9299.38 25.96 69.62 85.37 6758.50 5981.88 1963.85 5650.34 0.17 -0.15 -0.19 PROJECTED TO TD
12-DEC-98 MWD 9390.00 25.96 69.62 90.62 6839.97 6021.54 1977 .67 5687.52 0.00 0.00 0.00 CLO.DIST =6021.55'AZI=70.83
~
-.J
sper-r-y-sun
CAILLING seRVices
19-Dec-98
AOGCC
Lori Taylor
3001 Porcupine Drive
Anchorage, AK 99501
0,
erg --- ~ '
Re: Distribution of Survey Data for Well 1 C-15
Dear Lori Taylor:
Enclosed are two survey hard copies.
Tie-on Survey:
Window / Kickoff Survey:
Projected Survey:
0.00' MD
'MD
9,390.00' MD
(if appl ¡cable)
Please call me at 563-3256 if you have any questions or concerns.
Regards,
'(/"
Ii!"~
/'
c?lcwl
R, fL:',' ,""" rrJiE Do,
'r:ij "tr"'" '
:" ~ ~}¡~\'ì ·~.fM,1 tti'W~..: .. 'CtfrfIR
William T. Allen
Survey Manager
Attachment(s)
Alaska ()H & -Gas COilS. Commî$!ion
Anchon~g~
5631 Silverado Way, Suite G . Anchorage, Alaska 99518 . (907) 273-3500 . Fax (907) 273-3535
A Halliburton Company
Survey Ref: svy119
DEC 23 1998
AJa5kÇ1 Ojl & Gas Cons. Commission
A.nuhoralle
REr'E· ·$\JED-
Õ1 ~~Y ~ V
"-'~§" f.íìAJ
[ 1 k) if. '> ,,\! Ii t .
CJ J \ i t.J f \! f·:\ L~..
erg· ~;)1
...~o¡r__1iI<C.
Your Ref: API-500292293200
KBE - 101.3'
MWD Survey Instrument
Surface Coordinates: 5968605.15 N, 562247.15 E (70019' 29.1089" N, 149029' 42.9191" W)
--.- ali!r'''''Y-5Un
DRILLING seRVices
17 December, 1998
-~=-....
SURVEY REPORT
North Slope Alaska
ASP Zone 4
Kuparuk 1 C, Slot 1 C-15
1C-15
Job No. AKMM90033, Surveyed: 4 December, 1998
DrillQuest
-2-
17 December, 1998 - 15:54
Continued.. .
Sperry-Sun Drilling Services
Survey Report for 1C-15
Your Ref: API-5OO292293200
Job No. AKMM90033, Surveyed: 4 December, 1998
ASP Zone 4
North Slope Alaska Kuparuk 1 C
Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical
Depth Inct. Azim. Depth Depth Northings Eastlngs Northlngs Eastlngs Rate Section Comment
.- (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) (ft)
0.00 0.000 0.000 -101.30 0.00 O.OON O.OOE 5968605.15 N 562247.15 E 0.00
121.00 0.000 0.000 19.70 121.00 O.OON O.OOE 5968605.15 N 562247.15 E 0.000 0.00
196.57 0.500 130.090 95.27 196.57 0.218 0.25E 5968604.94 N 562247.40 E 0.662 0.17
289.29 1.140 66.420 187.98 289.28 0.108 1.41 E 5968605.06 N 562248.56 E 1.102 1.30
380.51 4.080 33.860 279.10 380.40 2.95N 4.05E 5968608.14 N 562251.17 E 3.485 4.79
467.75 6.680 55.710 365.96 467.26 8.39N 9.97E 5968613.62 N 562257.05 E 3.743 12.17
560.18 9.390 60.530 457.47 558.77 15.13 N 20.98 E 5968620.45 N 562268.00 E 3.019 24.77
650.83 13.140 66.050 546.36 647.66 22.96 N 36.84 E 5968628.41 N 562283.80 E 4.300 42.32
741.09 17.120 67.000 633.48 734.78 32.31 N 58.45 E 5968637.95 N 562305.33 E 4.418 65.81
832.29 18.860 65.720 720.21 821.51 43.62 N 84.25 E 5968649.47 N 562331.03 E 1.956 93.88
923.54 20.460 65.150 806.14 907.44 56.39 N 112.17E 5968662.47 N 562358.84 E 1.766 124.44
1014.48 23.360 65.630 890.50 991.80 70.51 N 143.02 E 5968676.85 N 562389.58 E 3.195 158.21
1103.11 27.000 66.550 970.70 1072.00 85.77 N 177.49 E 5968692.39 N 562423.92 E 4.131 195.78
1197.49 29.900 68.540 1053.67 1154.97 102.91 N 219.05 E 5968709.87 N 562465.34 E 3.232 240.66
1291.89 31.460 70.160 1134.86 1236.16 119.88 N 264.12 E 5968727.22 N 562510.27 E 1.870 288.80
1385.95 32.690 69.770 1214.56 1315.86 136.99 N 311.05 E 5968744.72 N 562557.05 E 1.326 338.74
-- 1477.32 34.430 70.720 1290.70 1392.00 154.06 N 358.58 E 5968762.17 N 562604.44 E 1.989 389.25
1571.48 37.230 70.850 1367.03 1468.33 172.19 N 410.63 E 5968780.74 N 562656.34 E 2.975 444.36
1664.87 39.160 71.250 1440.42 1541.72 190.94 N 465.24 E 5968799.94 N 562710.79 E 2.083 502.11
1758.49 41.940 72.390 1511.55 1612.85 209.91 N 523.07 E 5968819.39 N 562768.46 E 3.073 562.95
1848.37 44.100 70.800 1577.26 1678.56 229.29 N 581.24 E 5968839.25 N 562826.4 7 E 2.689 624.26
1943.70 46.670 71.270 1644.21 1745.51 251.33 N 645.41 E 5968861.83 N 562890.45 E 2.719 692.12
2037.62 49.790 71.280 1706.77 1808.07 273.82 N 711.74 E 5968884.86 N 562956.60 E 3.322 762.15
2224.79 50.890 70.270 1826.23 1927.53 321.27 N 847.79 E 5968933.44 N 563092.25 E 0.720 906.24
2503.73 51.940 72.550 2000.21 2101.51 390.74 N 1054.44 E 5969004.62 N 563298.31 E 0.742 1124.24
DrlllQuest
-3-
17 December, 1998 -15:54
Continued. ..
Sperry-Sun Drilling Services
Survey Report for 1C-15
Your Ref: API-500292293200
Job No. AKMM90033, Surveyed: 4 December, 1998
ASP Zone 4
North Slope Alaska Kuparuk 1 C
Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical
Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastlngs Rate Section Comment
- (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 o Oft) (ft)
2783.32 52.920 73.390 2170.68 2271.98 455.63 N 1266.33 E 5969071.27 N 563509.65 E 0.424 1345.70
3067.10 52.530 71.370 2342.56 2443.86 523.97 N 1481.53 E 5969141.39 N 563724.28 E 0.583 1571.42
3349.36 51.490 71.270 2516.30 2617.60 595.22 N 1692.26 E 5969214.38 N 563934.42 E 0.370 1793.87
3623.77 50.910 71.880 2688.24 2789.54 662.81 N 1895.15 E 5969283.66 N 564136.74 E 0.273 2007.71
3903.44 49.960 71.480 2866.38 2967.68 730.57 N 2099.82 E 5969353.12 N 564340.84 E 0.357 2223.28
4183.63 49.150 72.040 3048.14 3149.44 797.32 N 2302.34 E 5969421.54 N 564542.79 E 0.327 2436.49
4467.50 50.060 70.720 3232.11 3333.41 866.36 N 2507.20 E 5969492.28 N 564747.08 E 0.478 2652.66
4741.49 49.560 70.890 3408.92 3510.22 935.18 N 2704.86 E 5969562.73 N 564944.16 E 0.189 2861.97
5020.73 48.050 70.270 3592.83 3694.13 1005.03 N 2903.03 E 5969634.22 N 565141.74 E 0.566 3072.07
5299.76 50.600 70.730 3774.68 3875.98 1075.64 N 3102.50 E 5969706.49 N 565340.62 E 0.922 3283.67
5581.65 49.010 70.410 3956.60 4057.90 1147.26 N 3305.55 E 5969779.79 N 565543.07 E 0.571 3498.98
5862.52 50.350 70.500 4138.34 4239.64 1218.90 N 3507.36 E 5969853.10 N 565744.28 E 0.478 3713.12
6196.13 49.650 69.580 4352.78 4454.08 1306.13 N 3747.56 E 5969942.32 N 565983.75 E 0.298 3968.64
6421.92 50.050 69.010 4498.36 4599.66 1367.15 N 3909.00 E 5970004.68 N 566144.67 E 0.262 4141.16
6700.19 49.580 72.040 4677.94 4779.24 1438.03 N 4109.37 E 5970077.22 N 566344.45 E 0.849 4353.70
-...- 6980.93 49.320 72.330 4860.46 4961.76 1503.29 N 4312.46 E 5970144.16 N 566546.99 E 0.121 4566.96
7263.47 48.620 72.190 5045.93 5147.23 1568.23 N 4515.46 E 5970210.79 N 566749.45 E 0.251 4780.04
7544.25 48.240 .73.780 5232.24 5333.54 1629.71 N 4716.32 E 5970273.92 N 566949.79 E 0.445 4989.95
7820.39 47.690 73.600 5417.14 5518.44 1687.31 N 4913.16E 5970333.15 N 567146.15 E 0.205 5194.81
7913.39 43.940 72.360 5481.95 5583.25 1706.80 N 4976.93 E 5970353.17 N 567209.75 E 4.144 5261.44
8006.26 41.170 70.160 5550.36 5651.66 1726.94 N 5036.40 E 5970373.81 N 567269.05 E 3.385 5324.23
8098.97 40.410 69.320 5620.55 5721.85 1747.91 N 5093.22 E 5970395.25 N 567325.70 E 1.011 5384.78
8193.M 37.710 67.960 5693.59 5794.89 1769.48 N 5148.42 E 5970417.28 N 567380.72 E 3.011 5444.01
8286.24 35.490 67.640 5768.41 5869.71 1790.47 N 5199.87 E 5970438.69 N 567431.99 E 2.391 5499.49
8376.67 35.210 68.130 5842.16 5943.46 1810.17N 5248.34 E 5970458.79 N 567480.30 E 0.441 5551.74
DrlllQuest
-4-
17 December, 1998 - 15:54
Continued.. .
Based upon Minimum Curvature type calculations, at a Measured Depth of 9390.00ft.,
The Bottom. Hole Displacement is 6021.55ft., in the Direction of 70.826° (True).
The Dogleg Severity is in Degrees per 100ft.
Vertical Section is from Well and calculated along an Azimuth of 70.910° (True).
Magnetic Declination at Surface is 27.353° (03-Dec-98)
All data is in feet unless otherwise stated. Directions and coordinates are relative to True North.
Vertical depths are relative to Well. Northings and Eastings are relative to Well.
ASP Zone 4
North Slope Alaska Kuparuk 1C
Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical
Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment
~--.., (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) (ft)
8470.34 32.200 67.730 5920.08 6021.38 1829.69 N 5296.51 E 5970478.71 N 567528.30 E 3.222 5603.64
8563.98 29.760 66.870 6000.36 6101.66 1848.28 N 5340.98 E 5970497.67 N 567572.61 E 2.648 5651.74
8656.64 29.300 67.530 6080.98 6182.28 1865.98 N 5383.08 E 5970515.72 N 567614.56 E 0.608 5697.31
8750.51 26.550 70.220 6163.92 6265.22 1881.86 N 5424.05 E 5970531.94 N 567655.40 E 3.222 5741.23
8840.81 26.050 70.410 6244.87 6346.17 1895.34 N 5461.72 E 5970545.73 N 567692.96 E 0.562 5781.24
8931.76 26.090 69.790 6326.56 6427.86 1908.94 N 5499.30 E 5970559.64 N 567730.43 E 0.303 5821.20
9020.72 25.790 70.380 6406.56 6507.86 1922.20 N 5535.89 E 5970573.20 N 567766.91 E 0.445 5860.11
9119.72 25.800 70.180 6495.70 6597.00 1936.73 N 5576.44 E 5970588.07 N 567807.34 E 0.088 5903.19
9214.01 26.090 69.780 6580.48 6681.78 1950.86 N 5615.20 E 5970602.52 N 567845.98 E 0.359 5944.43
9299.38 25.960 69.620 6657.20 6758.50 1963.85 N 5650.33 E 5970615.80 N 567881.00 E 0.173 5981.88
9390.00 25.960 69.620 6738.67 6839.97 1977.67 N 5687.52 E 5970629.93 N 567918.07 E 0.000 6021.54 Projected Survey
Sperry-Sun Drilling Services
Survey Report for 1C-15
Your Ref: API-500292293200
Job No. AKMM90033, Surveyed: 4 December, 1998
DrillQuest
-5-
Tie~n Survey
Projected Survey
O.OOE
5687.52 E
O.OON
1977.67 N
0.00
6839.97
Comment
Station Coordinates
TVD Northings Eastings
(ft) (ft) (ft)
ASP Zone 4
Kuparuk 1C
Sperry-Sun Drilling Services
Survey Report for 1C-15
Your Ref: API-500292293200
Job No. AKMM90033, Surveyed: 4 December, 1998
17 December, 1998 -15:54
----
Comments
Measured
Depth
(ft)
0.00
9390.00
_.
North Slope Alaska
GeoQuest
3940 Arctic Blvd
Anchorage, AK 99503
ATTN: Sherrie
Well
~g. "d.?'C¡ 1C-15
c.r 8' ).?f1 1 C- 17
¥ 1 C- 17
q~. d.-3'-f 1 Q-07 A
S'G~kh
Job #
Log Description
Date
NO. 12216
1/11/99
Company Alaska Oil & Gas Cons Comm
Attn: Lori Taylor
3001 Porcupine Drive
Anchorage, AK 99501
Field: Kuparuk
BL
Sepia
STATIC PRESS/TEMP
SCMT
SCMT
GR/CCL/TEMP
981230
981224
981224
981212
DATE:
Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you.
-..--
1
1
1
1
RE(;EIVE1~)
I L~¡~ 1 5 1??9
Alaska Oil & Gas Cons. COlHmi,)i¡ion
Anchorage
.
.. "
.
.".
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
)
)
~
APPLICATION FOR SUNDRY APPROVALS
1. Type of Request: Abandon _ Suspend _ Operation Shutdown _ Re-enter suspended well _
Alter casing _ Repair well_ Plugging _ Time extension _ Stimulate
Change approved program _ Pull tubing _ Variance Perforate Other X Annular Injection
2. Name of Operator
ARCO Alaska, Inc.
3. Address
P. O. Box 100360, Anchorage, AK 99510
5. Type of Well:
Development X_
Exploratory _
Stratigraphic _
Service
6. Datum elevation (DF or KB)
41' RKB feet
7. Unit or Property name
Kuparuk River Field
4. Location of well at surface
1634' FNL, 1239' FWL, Sec. 12, T11 N, R10E, UM
At top of productive interval
297' FSL, 1524' FWL, Sec. 6, T11 N, R11 E, UM
At effective depth
At total depth
341' FSL, 1648' FWL, Sec. 6, T11N, R11E, UM
12. Present well condition summary
Total Depth: measured
(approx) true vertical
Effective depth: measured
(approx) true vertical
Casing Length
Structural
Conductor 80'
Surface 6208'
Intermediate
Production 9349'
Liner
Perforation depth: measured
N/A
true vertical
8. Well number
1 C-15
9. Permit number
98-229
10. API number
50-029-22932
11. Field/Pool
Kuparuk River Fieldl Kuparuk River Oil Pool
9390' feet Plugs (measured)
6840' feet
9051' feet Junk (measured)
6535' feet None
Size Cemented Measured depth True vertical depth
16" 9 CY High Early 121 ' 121 '
9.625" 850 sx ASIIILW 6249' 4488'
& 610 Class G
7" 178 sx Class G 9390' 6840'
ORIGIJIJ.L
RECE'VED
JAN C 7 1999
Alaska Oil & Gas Cons. commtssiol1
Anchorage
Tubing (size, grade, and measured depth)
3.5", 9.3#, L-80 @ 8977'
Packers and SSSV (type and measured depth)
Baker S-3 Perm. packer @ 8919' MD, Camco 3.5" TRDP-4E @ 2019' MD
13. Attachments Description summary of proposal _ Detailed operation program _
Contact Chip Alvord at 265-6120 with any questions. LOT test, surface cement details and casing detail sheets l
14. Estimated date for commencing operation
January 1. 1999
16. If proposal was verbally approved
Name of approver
Date approved
BOP sketch
15. Status of well classification as:
Oil -1L Gas
Suspended _
Service
17. I hereby certify that the fOreg~in'tJis true and correct to the best of my knowledge.
Signed þ- t. ax.. Title Kuparuk Drilling T earn Leader Date -:!'f 1/6 ( J ,9
. ~A-~ ,fLVD ,Q.i) FOR COMMISSION USE ONLY
Conditions of approval: Notify Commission so representative may witness
Plug integrity _ BOP Test _ Location clearance_
Mechanical Integrity Test _ Subsequent form require 1 O-----ß.~f.!- of flnllcAð.I Dc.1~
¡APprOVal N°'3 78- 33'Q
Approved by the order of the Commission
Form 10-403 Rev 06/15/88
ORIGINAL SIGNED BY
Robert N. Christenson
,.o"eÓ C.O~~ Commissioner
f>,\.>? \\.\tneö ¡] Ú
",e J / 7 J-
/.~_L. .-.---
Date /- B - ýf
SUBMIT IN TRIPLICATE
(d
" STATE OF ALASKA')¡.
ALA:.. )OIL AND GAS CONSERVATION COMr\illùSION
APPLICATION FOR SUNDRY APPROVALS
1. Type of Request: Abandon Suspend
Altercasing Repair welT
Change approved program
2. Name of Operator
ARCO Alaska, Inc.
3. Address
P. O. Box 100360, Anchorage, AK 99510
Operation Shutdown Re-enter suspended well
Plugging Tíme extension Stimulate -
Pull tubing _ Variance Perforate - Other X Annular Injection
5. 'I ype of Well: 6. lJatum elevation (lJl- or KB)
Development X_
Exploratory 41' RKB feet
Stratigraphic - 7. Unit or Property name
Service - Kuparuk River Field
4. Location of well at surface
1634' FNL, 1239' FWL, Sec. 12, T11N, R10E, UM
At top of productive interval
297' FSL, 1524' FWL, Sec. 6, T11N, R11E, UM
At effective depth
At total depth
341' FSL, 1648' FWL, Sec. 6, T1~N, R11E, UM
12. \Jresent well condition summary
Total Depth: measured
(approx) true vertical
Effective depth: measured
(approx) true vertical
Casing Length
Structural
Conductor 80'
Surface 6208'
Intermediate
Production 9349'
Liner
Perforation depth: measured
NIA
true vertical
8. Well number
1 C-15
9. Permit number
98-229
10. API number
50-029-22932
11. Held/\Jool
Kuparuk River Fieldl Kuparuk River Oil Pool
9390' feet Plugs (measured)
6840' feet
9051' feet Junk (measured)
6535' feet None
Size Cemented
16" 9 CY High Early
9.625" 850 sx ASIIILW
& 610 Class G
7" 178 sx Class G
Measured depth True vertical depth
121' 121'
6249' 4488'
9390' 6840'
Tubing (size, grade, and measured depth)
3.5" , 9.3#, L-80 @ 8977'
Packers and SSSV (type and measured depth)
Baker S-3 Perm. packer @ 8919' MD, Camco 3.5" TRDP-4E @ 2019' MD
ORIGIN/. L
4>I'Q
" ()~C' ~ '/ ÝI'i)
G}lcr (9 ~
A6'QaO ~c9
~/Jc~ o~
~I'O/,~ ~ C
cqe OIQl)¡i
i88l
:101)
13. Attachments Description summary of proposal Detailed operation program
Contact Chip Alvord at 265-6120 with any questions. LOT tesf,Surface cement details and casing detail sheers X
BOP sketch
14. Estimated date for commencing operation
January 1, 1999
16. If proposal was verbally approved
Name of approver Date approved Service
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
15. Status of well classification as:
Oil X Gas
Suspended
Signed Title Kuparuk Drilling Team Leader Date
1-01-< CUMMISSION USI::: ONLY
Conditions of approval: Notify Commission so representative may witness
Plug integrity BOP Test Location clearance _ ,.., _.....1
Mechanical I n1eg rity Test _ Subsequeilf form require 10------.R.epok øf ,4,.I7.<.J( ct.#- \'?' i"$PO:J01
Approved by the order of the Commission
I-orm 10-403 Kev 06/15/88
rZ.e$u. ðm; -t+eo
¡APprOVal NJ9f - 3æ
Commissioner Date
SU8MII IN I KIPLlCA II:::
1- 1--99 ~~~
PHilliPS Inc.
A Subsidiary of PHIlliPS PETROLEUM'COMPANY
1C-15
SSSV
(2019.2020,
OO:5.250)
GasUl!
MandrelNalve
1 (3325-3326,
00:5.390)
GasUl!
MandrelNalve
2 (5349--5350,
00:5.390)
GasLìft
MandrelNalve
3 (6592-6593,
OO:5.390)
Gas Lift
MandrelNalve
4 (7554-7555,
OO:5.390)
GasUl!
MandrelNalve
5 {8331-8332,
00:5.390}
GasLìft
MandrelNalve
6 (8827-8828,
00:6.018)
NIP
(8876-8877,
00:4.540)
TUBING
{0-89ll,
00:3.500,
10:2.992}
PKR
(8919.8920,
OO:6.900)
PRODUCTION
(0..9390,
OD:7.oo0,
wt:26.00)
NIP
(8965-8966,
OD:4.470)
SOS
(8976.8977,
OD:3.500)
Perf
(9106-9126)
"\.
KRU
1 C..15
API: 500292293200
SSSV TyPe: TRDP
Annular Fluid: DSUSW/KCI
Well Type: PROD
Orig Completion: 12/15/1998
Last W/O:
Ref Log Date:
TO: 9390 ftKB
2783
Angle @ TS: 26 deg @ 9092
Angle @ TD: 26 deg @ 9390
Rev Reason: FORMAT update by
ImO
Last Update: 9/4/2001
Reference Log:
Last Tag:
Last T a¡;¡ Date:
Description
CONDUCTOR
PRODUCTION
SURFACE
Size Top Bottom TVD Wt Grade Thread
16.000 0 121 121 62.58 H--40 WELDED
7.000 0 9390 9390 26.00 L-80 ABM-BTC
9.625 0 6249 4488 40.00 L-80 BTC
Wt Grade Thread
9.30 L.ßO EUE-8RD
Comment
St MD TVD Man Man VMfr V Type VOD Latch Port TRO Date VI"
Mfr Type Run Cmnt
1 3325 2603 CAMeO KBMM CAMCO GLV 1.0 BK2 0.156 1319 5/13/1999
2 5349 3908 CAMCO KBMM CAMCO GLV 1.0 BK2 0.188 1351 5/13/1999
3 6592 4709 CAMeO KBMM CAMCO GLV 1.0 BK2 0.188 1342 5/13/1999
4 7554 5340 CAMCO KBMM CAMCO OV 1.0 BK2 0.250 0 10/12/1999
5 8331 5906 CAMCO KBMM CAMCO GLV 1.0 BK2 0.250 1427 5/13/1999
6 8827 6334 CAMCO MMM CAMCO OV 1.5 RK 0.250 0 5/13/1999
~ttje·rr{ ¡w~uèl$~equij:~r.;.'¡"':a_II..R¥"
Depth TVD Type Description II)
2019 1796 SSSV CAMCO TROP--4E 2.812
8876 6378 NIP CAMCO W NIPPLE 2.812
8919 6416 PKR BAKER 8-3 PERM PACKER 3.875
8965 6458 NIP CAMCO D NIPPLE 2.750
8976 6468 SOS BAKER SHEAR OUT SUB 2.992
Well Name:1 C-15
)
\
II
Page 1
Rpt Date
12/03/98
12/03/98
12/03/98
12/04/98
12/04/98
12/04/98
12/04/98
12/04/98
12/04/98
12/04/98
12/04/98
12/04/98
12/04/98
12/04/98
12/05/98
12/05/98
12/05/98
12/05/98
12/05/98
12/05/98
12/05/98
12/05/98
12/05/98
12/05/98
12/06/98
12/06/98
12/06/98
12/06/98
12/06/98
12/06/98
12/06/98
12/06/98
12/06/98
12/07/98
12/07/98
12/07/98
12/07/98
12/07/98
12/07/98
12/07/98
12/07/98
12/07/98
12/07/98
12/07/98
12/07/98
12/08/98
12/08/98
12/08/98
12/08/98
12/08/98
Beain End
Time Time
08:00 13:30
13:30 18:00
18:00 24:00
00:00 01 :00
01 :00 02:00
02:00 03:30
03:30 06:00
06:00 07:00
07:00 12:00
12:00 12:30
12:30 16:00
16:00 22:00
22:00 22:30
22:30 24:00
00:00 08:00
08:00 09:30
09:30 11 :00
11:00 12:30
12:30 15:30
15:30 16:00
16:00 16:30
16:30 18:30
18:30 19:30
19:30 24:00
00:00 01 :30
01 :30 12:00
12:00 12:30
12:30 17:30
17:30 18:30
18:30 21 :00
21 :00 21 :30
21 :30 22:30
22:30 24:00
00:00 00:30
00:30 01 :30
01 :30 04:00
04:00 04:30
04:30 13:00
13:00 15:30
15:30 18:00
18:00 19:30
19:30 20:30
20:30 22:00
22:00 22:30
22:30 24:00
00:00 03:30
03:30 06:30
06:30 11 :00
11:00 13:00
13:00 24:00
Type Op
MIRU
NU_ND
OTHER
OTHER
TEST
BHA
DRIL
WIPERTR
DRIL
RIGS
CIRC
DRIL
CIRC
DRIL
DRIL
CIRC
DRIL
CIRC
WIPERTR
BHA
RIGS
WIPERTR
CIRC
DRIL
CIRC
DRIL
RIGS
DRIL
CIRC
TRIP_OUT
CIRC
TRIP_OUT
BHA
BHA
RIGS
TRIP _IN
CIRC
DRIL
CIRC
TRIP_OUT
CIRC
TRIP_OUT
BHA
BHA
TRIP _IN
TRIP _IN
CIRC
TRIP_OUT
CASG
CASG
Release rig from 1 C-17 at 08:00 hrs. Move rig 700' and turn rig 180 deg. Accept rig at 13:30 hrs
N/U diverter stack.
P/U 70 stand d.p. and 10 stds hwdp
P/U HWDP and d.c.'s
Function test diverter and check for leaks
M/U BHA. Orient directional tools and program MWD.
Drill from 121'-204'
POOH unplug jet. RIH-50' fill
Drill from 204' to 621'. Lot of fine gravel plus shaker screen blanking off caused overloading of ball
mill.
Service rig and top drive
Process cuttings
Drill from 621' to 1259'. Encountered gas cut mud at 1201'
Circulated out gas cut mud. (cut from 10.1 to 8.4 ppg)
Drill from 1259' to 1353'
Drill from 1353' to 2659'
Circ out gas cut mud
Drill from 2659' to 2847'
Circ hole clean
Pump out of hole
Service MWD-change orifice
Service rig and topdrive. Install new air slips
RIH. Tite from 710' to 1200'
CBU. Check gas cut mud
Drill from 2847' to 3670'.
Circ gas cut mud- MW cut to 7.3 ppg
Drill from 3670' to 5173'
Service rig and topdrive
Drill from 5173' to 5434'
Circ low vis sweep around
POOH. Started to swab at 1450'. Filled through Top drive to 1200'. Able to circulate and take right fill
Circulate at 1200'
Finish POOH
Download MWD and change bit
Download MWD
Cut drilling line
RIH Hit bridges @ 1324' to 1357'
Circ and cond mud
Drill from 5434' to 6259'
Circ
POOH to 1500' (tight spot)
Circ and wash through tight spot from 1500' to 1250'
POOH
Download MWD. UD bha
M/U holeopener assembly
RIH. Hit bridge @ 1600'. Circ and wash @ bridge
Wash & ream from 1600' to 1800'. CBU. RIH.
Circulate lo-visc sweep around. Circulate & condition mud & hole.
POH. Wash & ream through tight spot from 2268' to 2200', worked back through OK. LD hole
opener & stabilizers.
RU to run casing. Hold pre-job safety meeting.
Run 9-5/8" surface casing. Circulate casing volume every 25 joints. Wash through tight spots
between 1848' & 2300'. (149 joints in hole at midnight.)
1
Well Name:1 C-15
)
)
Page 2
Rpt Date Beain End Type Op
Time Time
12/09/98 00:00 01:00 CASG
12/09/98 01:00 07:00 CIRC
12/09/98 07:00 12:00 CASG
12/09/98 12:00 13:30
12/09/98 13:30 14:30
12/09/98 14:30 16:00
12/09/98 16:00 18:00
12/09/98
12/09/98
12/09/98
12/10/98
12/10/98
12/10/98
12/10/98
12/10/98
12/10/98
12/1 0198
12/1 0198
12/10/98
12/10/98
18:00 18:30
18:30 22:30
22:30 24:00
00:00 02:30
02:30 04:00
04:00 05:00
05:00 07:00
07:00 07:30
07:30 09:30
09:30 10:30
10:30 11:00
11 :00 11 :30
11 :30 12:00
12/10/98 12:00 12:30
12/10/98 12:30 24:00
12/11/98 00:00 17:00
12/11/98
12/11/98
17:00 18:30
18:30 19:30
12/11/98 19:30 21:00
12/11/98 21 :00 24:00
12/12/98
12/12/98
12/12/98
12/12/98
12/12/98
12/12/98
12/12/98
12/12/98
12/12/98
12/12/98
12/12/98
12/12/98
12/12/98
00:00 01 :30
01 :30 02:00
02:00 03:00
03:00 03:30
03:30 04:00
04:00 04:30
04:30 09:30
09:30 11 :00
11 :00 13:00
13:00 13:30
13:30 14:30
14:30 17:30
17:30 23:00
NU_ND
NU_ND
NU_ND
BOPE
PREP
BHA
TRIP _IN
TRIP _IN
CIRC
TEST
CLN_OUT
DRIL
CIRC
EVAL
DRIL
CIRC
EVAL
RIGS
DRIL
DRIL
CIRC
EVAL
DRIL
CIRC
WIPERTR
RIGS
WIPERTR
CIRC
DRIL
CIRC
DRIL
CIRC
WIPERTR
RIGS
WIPERTR
CIRC
TRIP _OUT
Comments
Run 9-5/8" surface casing. MU hanger & landing joint. Land casing.
Circulate & condition mud & hole for cementing. Reciprocate pipe, 31 OK# Up, 160K# Down.
Circulated -3500 Bbls, 11.1 BPM, 800 psi.
Single Stage Cement Job: Dowell flush lines & test to 3500 psi; Pump 20 Bbls ARCO Wash, first 3
Bbls with flakes; Pump 40 Bbls, 10.5 ppg ARCO Spacer; Mix & pump 662 Bbls, 850 sx, 10.7 ppg AS
III LW Lead Cement; Drop bottom plug; Mix & pump 122 Bbls, 15.8 ppg Class G (+ additives) Tail
Cement; Drop top plug; Chase plug with 5 Bbls Tail Cement (610 sx total) & 20 Bbls wash-up water;
Displace with mud using rig pump; Bumped plug; Pressured up to 2000 psi & held 2 minutes, OK;
Checked floats, OK. Full returns. Got 10.7 ppg Cement returns to surface. Reciprocated casing until
166 Bbls Lead Cement had rounded the shoe. CIP @ 1030 hrs. Wash cement out of riser &
flowline. LD cement head & landing joint.
Wash down & ND diverter system. RD casing tools. RU rig tools.
NU FMC Gen 4 speed head.
NU BOPE.
Test BOPE to 300 psi & 3000 psi. Test accumulator. Witnessing of test waived by Lou Grimaldi,
AOGCC Field Inspector.
Set wear bushing. RD test tools.
PU BHA #4. Orient & program tools. Load RA sources.
RIH with HWDP. RIH PU 5" DP.
RIH, PU 54 jts DP. RIH with stands to 6146'.
Circulate out cement contaminated mud.
Test 9-5/8" casing to 3000 psi for 30 minutes, no loss, OK.
Tag cement @ 6156'. Drill out cement & floats to 6249'. Clean out rathole to 6259'.
Drill 20' of new hole to 6279'. (0.11 ADT).
Circulate hole clean & displace to new mud.
Testformation to 1775 psi with 8.4 ppg mud, no leak-off. 16.0 ppg EMW - FIT.
Drill 30' more hole to 6309'. (0.11 ADT).
CBU.
Re-test formation. Broke down at 1700 psi with 8.4 ppg mud. 15.7 ppg EMW - LOT. Pressure
dropped quickly & held at 850 psi for 10 minutes (Shut-in is 12.0+ ppg EMW).
Service rig & top drive.
Drill from 6309' to 7600' MD; 5370' TVD; & drilling ahead. (8.88 ADT).
Drill from 7600' to 8932' MD, 6429' TVD. (12.94 ADT). Pumped hi-visc sweep at 7833', lo/hi-visc
sweeps at 8283'. (LWD Base HRZ @ 8838' MD, 6340' TVD).
Circulate 30 Bbl Lo-visc & 50 Bbl Hi-vise sweeps around.
Pull 5 stands. Test formation: Pumped-in at 878 psi with 9.6 ppg Mud; 13.3+ ppg EMWat 9-5/8"
shoe at 4488' TVD (12.2+ ppg at present TD).
RIH 5 stands. Drill to 9024' MD, 6511' TVD. (1.16 ADT). Start weighting up from 9.6 ppg to 10.2 ppg.
Circulate & finish weighting up to 10.2 ppg. Work pipe & monitor hole for 20 minutes, static. CBU, no
gas cut.
Short trip out to 9-5/8" shoe.
Service rig.
RIH, no fill on bottom. No loss or gain on short trip.
Pump Lo/Hi-visc sweeps. CBU, no gas or oil at bottoms up.
Drill from 9024' to 9054'. Drilling break, ROP increase. (0.19 ADT).
CBU, OK.
Drill to 9390' MD, 6840' TVD. (3.50 ADT). LWD picks: Base HRZ @ 8838' MD; Top D @ 9042'
MD; Top C4 @ 9085' MD; Top B @ 9250' MD.
Pump 50 Bbl Lo-visc & 50 Bbl Hi-vise sweeps & circulate around.
Short trip into 9-5/8" shoe.
Service rig & monitor hole.
RIH.
Circulate Lo/Hi-visc sweeps around. Condition mud & hole. Monitor well, static. Pump slug.
POH.
2
)
Page 3
Well Name:1C-15
)
Rpt Date
12/12/98
12/13/98
12/13/98
12/13/98
12/13/98
12/13/98
12/13/98
Beain End
Time Time
23:00 24:00
00:00 03:00
03:00 04:00
04:00 05:00
05:00 06:30
06:30 17:30
17:30 20:30
12/13/98 20:30 24:00
Type Op
TRIP_OUT
BHA
BHA
PREP
CASG
CASG
CIRC
CASG
12/14/98 00:00 02:30 CASG
12/14/98
12/14/98
12/14/98
12/14/98
12/14/98
12/14/98
12/14/98
12/14/98
12/14/98
12/14/98
12/14/98
12/15/98
12/15/98
02:30
03:00
04:00
06:00
07:30
08:00
11 :30
12:00
12:30
17:00
17:30
00:00
00:30
03:00
04:00
06:00
07:30
08:00
11 :30
BOPE
NU_ND
NU_ND
NU_ND
BOPE
SLlK_LlN
PREP
RIGS
LOADSHE
RUN_COM
RUN_COM
RUN_COM
RUN_COM
P
12/15/98 03:00 04:00 RUN_COM
12/15/98 04:00 05:00 RUN_COM
P
12:00
12:30
17:00
17:30
24:00
00:30
03:00
Sperry Sun & rig crew safety meeting on removing RA sources. POH.
Down load L WD tools.
LD Sperry Sun tools & mud motor.
Cut off 100' of drilling line. Adjust brakes.
RU to run casing. Pull wear bushing. Pre-job safety meeting.
Run 7" casing to 9390'. Break circulation at 3324', circulate casing volume at 5464' & 7533'.
Circulate & condition mud & hole for cementing. 1275 Bbls total, 7.5 BPM, 1000 psi. Reciprocate
pipe, 300K# Up, 155K# Down.
Start batch mixing cement. Flush mud out of pump suctions with water. Dowell flush line with 5 Bbls
water & test to 3500 psi. Pump 20 Bbls ARCO wash & 40 Bbls of 12.0 ppg ARCO spacer. Drop
bottom plug. Pump 38 Bbls, 178 sx, 15.8 ppg batch mixed Class G 'GasBlok' cement. Flush out lines
to cement head with water. Drop top plug & displace with 3% KCI Sea Water using rig pump, 5.1
BPM. Bumped plug. Full returns. Reciprocated casing until just before bumping plug. CIP @ 2310
hrs. Pressured up on plugs to 3500 psi & held for 30 minute casing test, no loss. Bled off & checked
floats, OK.
RD cementing equipment. Raise BOP. Set slips on 7" with 225K#. Cut off 7". LD stub & landing
joint.
Change upper pipe rams.
ND BOPE.
Dress 7" stub & NU FMC Gen 4,11" 3 Ksi x 7-1/16" 5 Ksi Tubing Head.
NU BOPE.
Test BOPE: Upper pipe rams, floor safety valve, & all breaks to 300 psi & 3500 psi.
RU HES slickline. Run 6.015" gauge ring & junk basket, tagged PBTD @ 9317' SLM. JB clean, only
small bits of debris.
RU to run tubing.
Service rig & top drive.
Finish strapping & drifting tubing. Load jewelry into short side of shed & strap. Finish tubing detail.
Pre-job safety meeting.
Run 3-1/2" completion assembly. (210 joints of 279 joints run at midnight).
Pick Up SSSV Valve & Control Line,Test 5000 PSI
Run 3 1/2 TBG. , 34 Bands t/279 Jts,P/U Tubing Hanger,Land Jt, Conn Control Line t/Hanger,Test
t/5000 psi Drop Ball@2:30
Land Tubing Hanger,Tighten Lock Downs To Specs.05:00
Set Packer2500 psi,Press up t/3000 psi, Test Tbg. f/1 0 Min, Press up t/3300 psi Shear SOS Valve,
Bleed Tbg. Down t/1500 psi, Press Test ANN. t/3500 psi f/10 min, Bleed Tbg Down t/400 psi To
Shear RP Valve
Freeze Protect,Pump@2.5 BPM ,600 psi - Pumped 95 Bbls Diesel,Let U-tube f/15 Min
12/15/98 05:00 06:30 RUN_COM
p
12/15/98 06:30 07:00 RUN_COM RID Test Equip.,UD Landing Jt - Set Back Press Valve
p
12/15/98 07:00 08:30 RUN_COM Freeze Protect 9518 X 7" ANN. - Broke Down@1250 psi - Pumped 300 bbl water,62 SPM @1550 psi,
P Pumped 80 bbls Diesel @ 3 BPM @ 1250 - Shut In Well w/1050 psi on Ann.
12/15/98 08:30 10:00 NU_ND NID BOP - Change Rams back t/4 1/2" X 7" Variables
12/15/98 10:00 11 :00 NU_ND Pick Up Master valve & nipple up - Test Pack off t/5000 psi f/1 0 Min - Test Control Line packing
t/5000 psi f/1 0 Min
12/15/98 11 :00 13:00 OTHER LID 57 Jts 5" DP out of Derrick for Move -Release Rig @ 13:00 Hrs.
CBU., CBU. Cheek gas cut mud, Cire, Cire and eond mud, Cire and wash through tight spot
3
CASING I TUBING I LINER DETAil
9-5/8" Surface Casing
WELL: 1 C-15 KRU
DATE: 12/9/98
1 OF 1 PAGES
LENGTH DEPTH
TOPS
ARCOAlaska,lnc.
Subsidiary of Atlantic Richfield Company
# ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN
RKB to Landing Ring - Parker Rig #245 40.44
FMC Gen 4 Fluted Mandrel Casing Hanger & pup 2.27 40.44
25 Jts 9-5/811, 40#, L-80, BTC Casing (Joints #138 - #162) 964.78 42.71
TAM Port Collar 3.01 1007.49
135 Jts 9-5/811, 40#, L-80, BTC Casing (Joint #3 - #137) 5159.00 1010.50
Gemoco Float Collar 1.48 6169.50
2 Jts 9-5/811, 40#, L-80, BTC Casing (Joints # 1 & #2) 76.73 6170.98
Gemoco Float Shoe 1.64 6247.71
Bottom of Shoe ==» 6249.35
I
TD of 12-1/4" Hole = 6259' MD
(-10' of Rathole)
Baker Lok thru Float Collar
Install TAM Port Collar on top of Jt # 137
Run FMC Hanger on Top of Joint # 162
16 Bow Spring Centralizers: 1 / Jt on first 15 joints, first 2 on stop ring in middle of joint;
& 1 on Joint #18.
2 Rigid Straight Blade Centralizers: Slide 1 on Jt # 137 & Jt # 138
Leave OUT 6 joints: # 163 thru # 168
Remarks: String Weights with Blocks: 310K# Up, 160K# Dn, 75K# Blocks. Ran 162 joints of casing.
Drifted casing with 8.67911 plastic rabbit. Used Arctic Grade API Modified No Lead thread compou
on all connections. Torqued connections to the base of the triangle stamp.
Parker Rig #245
Drilling Supervisor: G.R. Whitlock / Don E. Breeden
· .
)
)
ARca ALASKA INC CASING TALLY
PAGE: 1 of 1
WELL NUMBER: 1 C- 15 Kuparuk River Unit RIG: Parker Rig #245
TUBING DESCRIPTION: 9-5/8",40#, L-80, BTC Casing - Range 3 - Class A
DATE: 12/8/98
Column 1 Column 2 Column 3 Column 4 Column 5 Column 6 Column 7 Column 8
Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet
39.25 26 39.43 51 38.65 76 39.21 101 38.50 126 37.63 151 38.80 176
37.48 27 38.80 52 36.86 77 39.22 .102 34.82 127 37.02 152 37.88 177
39.27 28 38.93 53 38.73 78 38.72 103 38.16 128 39.23 153 39.24 178
38.69 29 38.75 54 38.74 79 38.68 104 39.24 129 37.07 154 39.42 179
34.90 30 35.50 55 39.26 80 39.67 105 38.89 130 39.42 155 39.20 180
36.96 31 39.23 56 39.27 81 36.61 106 36.54 131 37.72 156 39.30 181
38.70 32 38.82 57 38.82 82 37.58 107 37.83 132 38.92 157 38.70 182
37.85 33 36.77 58 38.89 83 38.66 108 38.83 133 37.69 158 38.81 183
39.24 34 39.23 59 38.29 84 35.74 109 37.08 134 37.19 159 38.90 184
38.18 35 39.47 60 40.02 85 39.30 110 39.16 135 38.11 160 39.22 185
39.42 36 37.27 61 39.22 86 38.97 111 39.42 136 34.87 161 39.24 186
39.24 37 38.69 62 39.23 87 37.10 112 40.12 137 39.22 162 38.18 187
39.23 38 38.66 63 37.32 88 37.53 113 37.24 138 38.30 188
39.20 39 37.38 64 36.39 89 38.80 114 39.32 139 38.66 .:J64 ô9746 189
38.76 40 37.39 65 35.09 90 38.71 115 37.52 140 38.65 -tßS 3&82.. 190
16 39.26 41 37.37 66 38.23 91 39.37 116 38.35 141 37.80 -t66 8&:68.. . 191
17 38.34 42 38.70 67 38.80 92 40.54 117 39.45 142 38.06 t61 39-:00 . 192
t\I"II~lø'''I~ 37.78 43 38.69 68 36.57 93 39.21 118 39.22 143 37.83 ·468 a9:-25 193
; -jlll'lll I, ::~I: I:
19 36.63 44 34.17 69 38.91 94 35.95 119 38.65 144 39.32 169 194
20 38.78 45 37.05 70 38.80 95 37.27 120 36.81 145 38.80 170 195
21 39.47 46 36.50 71 39.26 96 39.31 121 34.31 146 37.75 171 196
22 37.65 47 35.61 72 38.96 97 40.31 122 36.00 147 37.94 172 197
23 37.95 48 39.45 73 36.36 98 38.24 123 39.00 148 38.22 173 198
24 39.46 49 39.20 74 38.99 99 39.45 124 38.12 149 37.34 174 199
25 38.89 50 38.48 75 37.03 100 38.85 125 39.25 150 39.22 175 200
Tot 960.58 Tot 949.54 Tot 956.69 Tot 963.00 Tot 951 .83 Tot 951. 98 Tot 701.30 Tot
TOTAL LENGTH THIS PAGE = 6434.92
DIRECTIONS: RKB to LandinQ Ring = 40.44'
TOTAL JOINTS THIS PAGE = 168 FMC Fluted Mandrel CasinQ HanQer = 2.27'
TAM Port Collar = 3.01 '
Gemoco Float Collar = 1 .48'
Gemoco Float Shoe = 1 .641
LandinQ Joint = 44.97'
/..
)
...~
~" ARCa Alaska, Inc.
I Well Name: 1C-15
Rig Name: RIG # 245
)
Cementing Details
I
Casing Size
9·5/8"
Angle thru KRU:
51· Slant
Report Date: 12109/98
AFC No.: AK9141
% washout:
State type used, intervals .covered and spacing
16 Gemoco Bow Spring Centralizers: 11 Jt on first 15 joints, first 2 on stop ring in middle of joint & ion Jt #18. 2 ROTCO Rigid
Straight Blade Centralizers: 1 on joint on both sides of TAM Port Collar at 1007'.
I
Hole Diameter:
12-1/4"
Centralizers
Comments:
Mud
Comments:
Weight:
10.3 ppg
PV(prior cond):
49
Gels before:
20/36
Gels after:
12118
Wash 0
Comments:
Type:
ARCO Wash
Spacer 0
Comments:
Type:
ARCO B45
Lead Cement 0
Comments:
Type:
ASIIILW
Mix wtr temp:
70· F
Report Number: 7
Field: Kuparuk
Shoe Depth:
6249'
LC Depth:
FC @ 6169'
PV(after cond):
28
YP(prior cond):
46
YP(after cond):
31
Total Volume Circulated:
3500 Bbls
Volume:
20 Bbls
Weight:
8.34 ppg
Volume:
40 Bbls
Weight:
10.5 ppg
No. of Sacks:
850 ax
Weight:
10.7 ppg
. Yield:
4.44 ds
Tall Cement
. Comments:
o
Additives:
Class G + 30% D53 + 0.6% D46 + 1.5% D79 +1.5% S1 + 50% D124 + 9% D44 (BWOW)
Type: Mix wtr temp: No. of Sacks:
G 70· f 610 sx
Yield:
1.17 ds
Displacement 0
Comments:
Additives:
Class G + 1.0% S1 + 0.2% D46 + 0.3% D6S
Rate(before tail at shoe):
7.8 BPM
Reciprocation length:
-12'
Theoretical Displacement:
468 Bbls
Calculated top of cement:
Cemented to Surface
CP:
Date: 1219/98
Time:1030 hrs
Remarks:
Weight:
15.8 ppg
Rate(tail around shoe):
6.3 BPM
Str. Wt. Up:
310K# (75K# Blocks)
Str. Wt. Down:
160K# wI Blocks
Str. WI. in mud:
151K#
Reciprocation speed:
-20fpm
Actual Displacement:
474 Bbls
Bumped plug:
Yes
Floats held:
Yes
Circulate & condition mud & hole for cementing. Reciprocate pipe, 310K# Up, 160K# Down. Circulated -3500 Bbls, 11.1 BPM, 800 psi.
Dowell flush lines & test to 3500 psi. Pump 20 Bbls ARCO Wash, first 3 Bbls with fiakes. Pump 40 Bbls 10.5 ppg ARCO Spacer. Mix & pump 662 Bbls, 850 sx,
10.7 ppg AS III LW Lead Cement. Drop bottom plug. Mix & pump 122 Bbls,15.8ppg Class G (+addltlves) Tall Cement. Drop top plug. Chase plug with 5 Bbls
Tall Cement (610 sx total) & 20 Bbls wash·up water. Displace with mud using rig pump. Bumped plug. Pressured up to 2000 psi & held 2 minutes, OK, Checked
floats, OK. Full returns. Got 10.7 ppg Cement returns to surface. Reciprocated casing until 166 Bbls Lead Cement had rounded the shoe.CIP @ 1030 hrs,
1219/98.
¡Cement Company:
Dowell
I Rig Contractor:
Parker
APproved By: fl ¿/' L 1
Don E. Breeden ~ ~"""''''~;--1
CASING TEST and FORMATION INTEGRITY TEST
Well Name:
1 C-15
Supervisor:
Don Breeden
Casing Size and Description:
Casing Setting Depth:
Date:
12/10/98
95/8",40.0 ppf, L-80, BMTC
6,249' TMD
4,488' TVD
Mud Weight: 8.4 ppg EMW= Leak-off Press. + MW
0.052 x TVD
Hole Depth: 4,508' TVD (6279' MD)
1,800 psi + 8.4 ppg EMW at Shoe
LOT = (0.052 x 4,488') = 16.1 ppg
Fluid Pumped = 4.2 bbl Pump output = 0.1010 bps
JmJE'u[frJE
._=1= II +-+---t-==ç::fjt="II£ Hlr II)~
-7-~:-~:_:_:j:_~m-,* ' , , ,n ,1.1,
/ ,~.....,
~
:')I))¡::..._
.'¡'.,-IL,,,,-
.,11))':1".1--
:~I:':(I':"", -
~ ~",,(, .:',;.
2.800 psi
2.700 psi
2.600 psi
2.500 psi
2.400 psi
2.300 psi
2.200 psi
2.1 00 psi
2.000 psi
~ 1.900 psi
~ ::m~
æ ::~ ~
g: 1.400 psi
1.300 psi
1.200 psi
1.100 psi
1.000 psi
æ~=/""f-
600 psi
SOOpsi
~~~¡I
o 2 4 6 8 10 121416182022242628203234363840424446485052545658ro626<1666870727476780082848688909294969810101010101111111111
dddddddddddddddddddddddddddddddddddddddddddddddddd0246802468
k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k .1 .1 .1 .1 .1 .1 d .1 .1 .1
kkkkkkkkkk
~ LEAK-OFF TEST
~CASING TEST
- LOT SHUT IN TIME
-:i- CASING TEST SHUT IN TIME
--+- TIME UNE
STROKES
NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above
I
LEAK-OFF DATA
MINUTES
FOR
FIT STROKES PRESSURE
II':II~I"'¡ _ -J~- Q~tJ5s 1 Q~~-=~J
12 stks ! 73 psi 1
¡ 4štks -f166p-šil
-r 6 stks ~- DŠ5 psi!
~=-T=) s~ks ~¡3ŠÕ~p_si ~J
! ! 10 stks 1 468 psi ¡
1--------+------+--------------1
! ¡ 12 stks 1 565 psi ¡
r---------T---14-stkš--T--Š56 psi -1
} +-- -+------1
1 1 16 stks 1 737 psii
! ¡--1ãstkŠ-Taõ"9psf--l
}- -t-- - I -------i
: : 20 stks ! 885 psi !
r----¡-22stks - i 965 pS-i-1
L---------i-------~----------...1
! ¡ 24 stks ! 1,047 psi ¡
r--f2Sštks i 1,132 psT-'
r--- ¡ 28stkS-f~225-pSi 1
¡----130 stks ! 1,311pSil
¡-------¡-j2 stks i 1 ;397 psi1
1--------4- ---+-------1
! ! 34 stks 1 1,485 psi 1
! --¡-- 36 stk"S-I-f:569-j)ši--l
t--- [- ---+--------;-i
! ! 38 stks 1 1,650 pSI 1
r ! 40stks ~25-pSi I
:-------f - [----,
~-=--==t-= 42_~~~=~~
¡ i I I
l SHUT IN T~~L__ SHU"'!"JN PRE~SU_RE
: 0.0 min 1 .! 1,802 psi !
:---------I----------+---------~
11.0 min 1 : 1,745 psi :
r2-:OñÏiñ-1-------¡-:¡;69~fp-Ši1
t-----. -------+------I
! 3.0 min ! ¡ 1,650 psi ¡
¡ 4.0 miñ-l------!1:600-psi!
}- - ---I ---+--------i
! 5.0 min ! i 1,565 psi 1
¡ 6.0 min ! T1;53 0 -p-Si--1
:-- i--- I - ---,
! 7.0 m~n ~ +--1~~8 ps~ !
¡ 8.0 m~n ¡ ___ ! 1 ,468 ps~ ~
i 9.0 mtn : ! 1,440 pSI !
L1-0.0_ min__-l ---=---==!1,41~iÐ
CASING TEST DATA
MINUTES
FOR
CSG TEST STROKES PRESSURE
[==-~=~=~~___¡=-o~-ki~~==~1!~~J~==~J
1 . . ! 4 stks ¡ 95 pSI ¡
[====---=-J=--Š-st~~~~~~l_~~1~p:!!=]
! ¡ 12 stks ! 520 psi I
[==--=--=~_-I=_~~~§=-r-!!O -p~!_J
i 1 20 stks 1 885 psi !
}-----------+-----------+--------------I
! ! 24 stks 1 1,065 psi !
r--------1----2ã-stks--T-:¡~275psi--1
}----------f--------+------i
i ! 32 stks 1 1,485 psi i
r-------------!--36-štkS---f1~71õ-ps¡--1
}---------------f----------i------------------f
! ! 40 stks ! 1,945 psi !
r-------------T---« štkST-2~2õ5-pši-1
~------------+_-------i-----------;
! ! 48 stks ! 2,440 psi 1
C==--==--====C- 52~~š---I~~~žº~~ps¡--J
~==:=-~=--~~~t-=::~~==:j
~===~~~~~=-·-!---~-----~~~--t==~=--=~-=~=~
t---------t~=~_=~~~=_~-- i ! .
! SHUT IN TIME: ! i
¡.--------t------------- ----------I
1 0.0 min 1 ! 2,950 psi ¡
r--.¡-:-Õ miñ--T------------r-~9šops¡--1
r2~Õ-m1ñ-l----------------r-~9ŠÕ-psi--l
r-3:0ñïiñ----ì---------------f-2~950-psTl
D~õm]~~_-r==~~=~=~=]--~~50 piC]
: 5.0 min· 1 ! 2,950 psi !
[~1õ~o!ñfñ-J=~~~~=~=~=~=~--~~~j)~p~[J
¡ 15.0 min ¡ ¡ 2,950 psi !
r- 20.0 -rñfñ--!--------------f-2~9-50psi-l
t-------;-----------i-------------;
: 25.0 min ! ! 2,950 psi !
r-3õ:omfñ-T----------r-2~950-psi -1
~~~~t~~~
--
.-
NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY
CASING TEST and FORMATION INTEGRITY TEST
Well Name:
1C-15
Date:
12/10/98
Supervisor:
Don Breeden
Casing Size and Description:
95/8",40.0 ppf, L-80, BMTC
Casing Setting Depth:
6,249' TMD
4,488' TVD
Mud Weight: 8.4 ppg EMW= Leak-off Press. + MW
0.052 x TVD
Hole Depth: 4,527' TVD (6309' MD)
1,685 psi + 8.4 ppg EMW at Shoe
LOT = (0.052 x 4,488') = 15.6 ppg
Fluid Pumped = 4.2 bbl Pump output = 0.1010 bps
TIME LINE
--~ ,',¡,!L:_:_:_:_!JJ J J .r,: ~~~I~'~~
3 300 D!.J
J ;ùj D~
':\ 100r.':';
.' 1)).1 (..1
_ :'XIJ:.,...
2800 psi
2700 psi
2600 psi
2500 psi
2.400 psi
2300 psi
2200 psi
2100 psi
2(J(X) psi
~ 1:~g~
~ 1.700 psi
~ J:~ ~
Q" 1.400 psi
1.300 psi
1.200 psi
1.1 00 psi
1.(J(X) psi
900 psi
BOO psi
700 psi
600 psi
SOOpsi
400 psi
300 psi ..,1f
200 psi
100 psi .
o psi
o 2 ~ 6 8 10121~ 161820222~26283032343638«J42M~6<l85052545658ffi6264666870727~76780082848688ÇQ929~96981O10101010 1111111111
dddddddddddddddddddddddddddddddddddddddddddddddddd02~6802~68
k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k 5151 51 51 51 51 51 51 51 51
kkkkkkkkkk
,J-'
?-'
~.-
~ LEAK-OFF TEST
-a-CASING TEST
-+- LOT SHUT IN TIME
--:k- CASING TEST SHUT IN TIME
-+- TIME LINE
/-
STROKES
NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above
LEAK-OFF DATA
MINUTES
FOR
FIT STROKES PRESSURE
--------------------,
L______~--9~~~-¡-----º-p-~--~
¡ ! 2 stks ! 28 psi !
i==--=-j _~ stks ¡-iõ-ä-p-š-i 1
! ! 6 stks ¡ 210 psi ¡
L_~=--=_j___~tks _ ! --E..~psi-=J
! ! 10 stks ! 407 psi !
:----------4-----------+----------------1
! ! 12 stks ! 492 psi ¡
r------¡---14-sikš----r--s77-p-šT--,
-------I--- I -------1
¡ . ¡ 16 stks ! 669 psi !
¡-----¡-18"Stk"s ¡ 745-psï--¡
- -'I --+-------~
! ! 20 stks ! 820 psi i
r - --1-- 22stks ¡ 910 psT-l
, -i----"'--------:---;
i ! 24 stks ! 974 psi ¡
L__ - ¡ __~ stkS-n:~?~e~~J
i ¡ 28stks ¡ 1,138 psi ¡
L_______~J~~-30 s~__l~~iZp~lJ
! ! 32 stks ! 1,298 psi !
:------~---- + --I
! ! 34 stks ! 1,382 psi !
r------I--36-stks-r-1 ,464psT-'
~--------f--------+-------:-.~
! ! 38 stks ! 1,545 pSI ¡
r---- ¡ 40 stkš-T-~6'¡S-psn
~__=~~:-_42 stk:_E~~~=¡
i I I I
! SHUT IN TIME! SHUT IN PRESSURE
r 0.0 min ¡-------T--goopš¡--l
t----;---j---------t--------·---,
~---!.:Q-!TI~n _+-________+__~?.~.P..~~--~
~--~-º-~-~----------_i_- 856 p~.!._~
, 3 0·, , 851 . I
~ . m~n __~------+__-----.P-!?~-~~
~ 4.0 m'n~------¡~li~~-~
, 5 O· I , 850 . ,
~ . m~n i------+--P..~--!
; 6.0 mln ; ; . 850 pSI I
- -i-----: - ~
~ 7.0 m~n ~_ __! 849 ~~--4
: 8.0 mln : I 849 pSI ;
¡-g:üñïinr---- ¡ 848 Psi 1
. . I I
'-1 O.Q~Jn J=--=-r- 848Ë.~!=J
..
CASING TEST DATA
MINUTES
FOR
eSG TEST STROKES PRESSURE
C~=-~==J---Q~~ik~--=r~=~~º~~~=J
! ! 4 stks ! 95 pSI . !
r--~====]=__~~!~~==I---~j~~I~J
¡ i 12 stks ! 520 psi ¡
[==--==~~_L_~_~~ks__~I=~f?]~~rJ
! ! 20 stks ¡ 885 psi. ¡
~----------------+_-----------{------------------4
¡ ¡ 24 stks ! 1,065 psi !
r---------------¡-iã stks---T--.. ,27S-r;ši-¡
~------------~ -----{------------4
! ! 32 stks ! 1,485 psi !
¡--------------1---36sikS--r~7~fopsi-l
----------_t----------i------------4
! i 40 stks ! 1,945 psi !
¡-------------r--~ï~¡_sik"š--r2~2õ5p-ŠTl
~------------t--------.¡_-----------~
! ! 48 stks ! 2,440 psi !
[=-~-~=~===]=_-_~~_~~~-=I~=~º~~e~J
~=-~==~~=-~:I:::::=~-=::-~====:=~
~===~==~~~~=~~~-==~~~==~~=t~~=~~~~~=-~=~=~~
r---------t===~=~~~_~! ;
! SHUT IN TIME! i !
~-------------t-----------------i------------;
! 0.0 min ! ¡ 2,950 psi !
~=~~~~~~~=i~~~=~~~~~~=---f~-~~g~~~1
[-&0 m¡ñ-!-----~--------T~9ŠO psT-l
[~=~~~!!!I~~=I~~~==~~~~=~~=I~~~~9-ši!~~iJ
! 5.0 min ! ! 2,950 psi i
[=i~~~~J~=---~=====~I~~~~~~~e~J
! . 15.0 min ¡ ! 2,950 psi !
r- 20J) niiñ--¡---------------T-2~95-õ-r;si-l
~--------_t-------------+-------------~
! 25.0 min ! ! 2,950 psi ¡
r-30.ÕminT--------¡-'2:9so psTl
~~~~~4:1ª:_I=-~j
--
-
NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY
CASING TEST and FORMATION INTEGRITY TEST
Well Name:
Supervisor:
1 C-15
Casing Size and Description:
Don Breeden
Mud Weight:
Casing Setting Depth:
9.6 ppg
Hole Depth:
UJOO psi
900 psi
BOO psi
700 psi
600 psi
w
0::
::J
~ soapsl
w
0::
11.
400 psi
300 psi
200 psi
100 psi
6,429' TVD
878 psi + 9.6 ppg
LOT = (0.052 x 4,488')
Fluid Pumped = 3.6 bbl
95/8",40.0 ppf, L-80, BMTC
6,249' TMD
Date:
12/11/98
4,488' TVD
(8932' MD)
EMW = Leak-off Press. + MW
0.052 x TVD
EMW at Shoe
= 12.2 ppg
Pump output = 0.1010 bps
~ LEAK-OFF TEST
-'-CASING TEST
-+- LOT SHUT IN TIME
~,,- CASING TEST SHUT IN TIME
-+- TIME LINE
---~~:~I~~I
.
'~
.....
o psi
o sll< 2 sll< 4 stlc 6 sll< 8 stlc 10 stlc 12 stlc 14 stlc 16stlc 18 sll< 20 sll< 22 stlc 24 sll< 26 sll< 28 stlc 30 s1\< 32 stlc 34 stlc 36stlc 3B stlc 40stlc 42 sll< 44 stlc 46stlc <lBstlc SOstlc
STROKES
NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above
LEAK-OFF DATA
MINUTES
FOR
FIT STROKES PRESSURE
.----------- ~-------
L-----J-- 0 s!'5~~º_p~__~
i ! 2 stks ¡ 20 psi !
f ---r-4 st~r-4õp-šT--l
L ____.&_______~______________1
! i 6 stks i 80 psi !
r 1_ -8 stks =!i~_ª_Esi--l
! ! 10 stks i 206 psi ¡
~----4 --+---------1
i ! 12 stks ! 278 psi !
r-----î-14 stks i 334-psi !
I-- t --+------1
! ¡ 16 stks ! 391 psi !
r- - ¡ 18 stks ! 438 pši--l
t-----i I ------I
¡ ! 20 stks ! 511 psi ¡
r- 122 stks ¡ 5iop-š¡--1
"'---1 +--------1
i ! 24 stks ! 631 psi !
L-__==L26st~ 1-6~PSi-]
¡ i 28 stks i 732 psi !
¡ ! 30 stks ! 783 -psi 1
L---=--L 32 ~~ks . - å32 psi -J
! ¡ 34 stks 878 psi !
¡ i 36 stks - i 857pšT!
·r ,- -'---1
F - j---=~-r-=~~~~j
¡¡I t
LSHUT IN TIM.s._____~HUT IN PRE~~URE
! 0.0 min ¡ i 713 psi !
r-----7-1-------t---..---..---;----;
~--!.:.º- m~n __~---------+.2i~--I?.~-~
I 2.0 mln : I 493 pSI I
r-- . 1-- ----t--------.--
~ª.:P m~n i ---- i ~~_.P..~---~
~ 4.0 ml~_ ____~4I?sl --i
~ 5.0 m~n 1_ I 445 .p..s~ -I
~ 6ß_ ml.~~ ¡ 437 P~--i
~Zß m~_{-___+ 431 ps~ ~
! 8.0 m~n ¡----+-~!>.P~~-J
! 9.0 mln ! ! 421 pSI !
L_1 0.0 min I __L~!? -psi--l
CASING TEST DATA
MINUTES
FOR
CSG TeST STROKES PRESSURE
r-------_----------_-..-------.
t~~=t:~1~ -~
~- ---l~~=--~-=--==~~~r==---===~
t==~=~~=t====~---=~~==-1
[-- ---=--=-~==:::::::==+-=-=-=1
r-~~=g;~=r~~
~-----~~=t=_---=-=~1------1
! ---t-_~~~==~-- i ,
! SHUT INTIME! I ¡
r~~!~~~~~~~¡
~==--==~~~~~~=-~~~===r===-~
~-=-~====~t=~~~=~=~~-i==~=-~~~~~~~~~
r-~==--=+-=:::=~~_r-=--===~~
¡~~~~1~~_~~~~;~~
--
~.
NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY
)
)
TONY KNOWLES, GOVERNOR
ALASIiA OIL AND GAS
CONSERVATION COMMISSION
3001 PORCUPINE DRIVE
ANCHORAGE. ALASKA 99501-3192
PHONE: (907) 279-1433
FAX: (907) 276-7542
November 23, 1998
Chip Alvord, Drilling Team Leader
ARCO Alaska, Inc.
POBox 100360
Anchorage, AK 99510-0360
Re: Kuparuk River Unit lC-15
ARCO Alaska, Inc.
Permit No: 98-229
Sur Loc: 1634'FNL, 1239'FWL, Sec. 12, TIIN, RI0E, UM
Btmhole Loc. 335'FSL, 1649'FWL, Sec. 06, TIIN, RIlE, UM
Dear Mr. Alvord:
Enclosed is the approved application for permit to drill the above referenced well.
The permit to drill does not exempt you from obtaining additional permits required by law from
other governmental agencies, and does not authorize conducting drilling operations until all other
required permitting determinations are made.
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 confimled by a valid
Fommtion Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted
to the Commission on form 10-403 prior to the start of disposal operations.
Please note that any disposal of fluids generated from this drilling operation which arc pumped
down the surface/production casing annulus of a well approvcd for annular disposal on Drill Site
1 C must comply with the requirements and limitations of 20 AAC 25.080. Approval of this
permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000
barrc1s through thc annular space of a single well or to use that wcll for disposal purposcs for a
period longer than one year.
c
Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035.
Sufficient notice (approximately 24 hours) must be givcn to allow a representative of the
Commission to ,\ritness~;:)l uf n PE installed prior to drilling new hole. Notice may be given
by contacting the m iSSlO ctrol m field inspector on the North Slope pager at 659-3607.
~CldY) . ..
David W. John ton
Chaimlan
BY ORDER OF THE COMMISSION
dlf/Enclosures
cc: Department of Fish & Game, Habitat Section w/o cncl.
Department of Environmental Conservation w/o encl.
) STATE OF ALASKA )
ALASKA UIL AND GAS CONSERVATION COMMISSIV¡\J
PERMIT TO DRILL
20 AAC 25.005
1 a. Type of Work Drill X Redrill 0 1 b Type of Well Exploratory 0 Stratigraphic Test 0 Development Oil X
Re-Entry 0 Deepen 0 Service 0 Development Gas 0 Single Zone X Multiple Zone 0
2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool
ARGO Alaska, Inc. RKB 41', Pad 60' feet Kuparuk River Field
3. Address 6. Property Designation Kuparuk River Oil Pool
P. O. Box 100360, Anchorage, AK 99510-0360 ADL 28242, ALK 2292
4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 MC 25.025)
16341 FNL, 1239' FWL, Sec. 12, T11N, R10E, UM
At top of productive interval (@ TARGET)
Kuparuk River Unit
8. Well number
Statewide
Number
297' FSL, 1540' FWL, Sec. 6, T11 N, R11 E, UM
At total depth
1 C-1 5
9. Approximate spud date
#U-630610
Amount
335' FSL, 1649' FWL, Sec. 6, T11 N, R11 E, UM 11/24/98 $200,000
12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TV D)
property line 1 C-02 9347' MD
297' @ Target feet 23.7' @ 533' feet 2560 6761' TVD feet
16. To be completed for deviated wells 17. Anticipated pressure (see 20 MC 25.035(e)(2))
Kickoff depth 300' feet Maximum hole angle 50.37° Maximum surface 2502 psig At total depth (TVD) 3245 psig
18. Casing program Setting Depth
size Specifications Top Bottom Quantity of cement
Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data)
24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' ±200 CF
12.25" 9.625" 40.0# L-80 BTC 6187' 41' 41' 6228' 4485' 853SxArcticsetlllL&
596 Sx Class G
8.5" 7" 26.0# L-80 BTC MOC 9306' 41' 41' 9347' 6761' 250 Sx Class G
19. To be completed for Redrill, Re-entry, and Deepen Operations.
Present well condition summary
Total depth: measured feet
true vertical feet
Plugs (measured)
Effective depth:
measured
true vertical
feet
feet
Junk (measured)
Casing
Length
Size
Cemented
Measured depth
True Vertical depth
Structural
Conductor
Surface
Intermediate
Production
Liner
20. Attachments Filing fee X Property plat 0
Drilling fluid program X Time vs depth plot 0
BOP Sketch X
Refraction analysis 0
DivE'rter Sketch
REct'VEO
~.' aV' -,- LI. 1998
\'~ '
commission
í\\ut',ka 0" & Gas Cons.
X' A~0RoJ8§61m X
ORIGINAL
Perforation depth:
measured
true vertical
Seabed report 0
20 AAC 25.050 requirements X
21. I hereby certify that the foregoing is true and correct to the best of my knowledge
Signed ~ ~ (XQ
Title Drilling Team Leader
Commission Use Only
I API number I Approval date .'1 "13 /J /1 I See cover. letter for
50- ð.z.. 9 - .2-..;z. '7 3 2..... . - ~ ...... 7"V other reqUIrements
Samples required 0 Yes ~ No Mud log required 0 Yes HI No
Yes 0 No Directional survey required g] Yes 0 No
o 2M 0 3M 0 5M 0 10M 0 15M
Date III ~ I) ð
PelJI!~umber
ß- Z.Z /"
Conditions of approval
Hydrogen sulfide measures .B
Required working pressure for BOPE
Other:
Uriginal Signed By
David \N. Johnston
Commissioner
by order of
the commission
Date
//~;;'3 ·~f~
Approved by
Form 10-401 Rev. 7-24-89
Submit in triplicate
ARCO Alaska, Inc.
Kuparuk Drillsite Development
Post Office Box 100360
Anchorage, Alaska 99510
Telephone 907 265-6206
)
)
~~
~",
Michael Zanghi
Supervisor
Nov 2, 1998
Alaska Oil and Gas Conservation Commission
3001 Porcupine Drive
Anchorage, AK 99501
(907) 279-1433
Re: Application for Permit to Drill
1 C-15
Kuparuk Development Production Well, Kuparuk River Unit
Dear Sirs:
ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the Kuparuk
interval from 1 C pad in the Kuparuk River Unit rKRU"). The well is designed to penetrate and further
develop the production potential of the Kuparuk sands in the vicinity of 1 C pad.
The well is designated as a conventional production well using a 9 5/8" surface casing string, a 7"
longstring to TD and 3-1/2" tubing.
Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent
information attached to this application includes the following:
1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a).
2) Fee of $ 100 payable to the State of Alaska per 20 AAC 25.005 (c) (1).
3) A directional plat showing the surface and bottomhole locations proposed for the well per
20 AAC 25.005 (c) (2).
4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC
25.050.
5) Diagrams and descriptions of the BOP and diverter equipment to be used as required by
20 AAC 25.035 (a) (1) and (b)
6) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A
wellbore schematic is also attached visually depicting the proposed well and completion
design.
7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are
attached in this APD package.
8) A copy of the proposed drilling program, including a request for approval of annular
pumping operations is attached.
9) Also note that ARCO does not anticipate the presence of H2S in the formations to be
encountered in this well. However, there will be H2S monitoring equipment functioning on
the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation.
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany
'Þ"'!
\
')
)
10) Please note that because of the large volume of regional information available in this area,
ARCO considers this well to be a development well, and as such, no mudlogging
operations such as type log generation and sample catching are planned.
Please note that the anticipated spud date for this well is November 24. 1998. If you have any
questions or require further information, please contact Scott Goldberg at (907) 263-4622 or Chip Alvord
at (907) 265-6120.
Sincerely,
>~~~ ~~
Scott Goldberg c..-/
Operations Drilling Engineer
cc: Kuparuk 1C-15 Well File
Chip Alvord ATO-1030
MJ Loveland NSK6
)
)
Drill and Case Plan for 1 C-15 Kuparuk Producer
General Procedure:
1. Excavate cellar, install cellar box, set and cement 16" conductor to +1- 120' RKB. Weld
landing ring on conductor.
2. Move in 1 rig up drilling rig. Install diverter & function test same.
3. Spud and directionally drill 12 1/4" hole to the surface casing point at 6228' MD. Run MWD 1
LWD logging tools in drill string as required for directional monitoring and formation data
gathering.
4. Condition hole for casing, trip out.
5. Run and cement 9 5/8" 40# L80 BTC casing string to surface.
· Employ lightweight permafrost cement lead slurry to assure cement returns to the surface
in a one stage job. Adequate excess cement will be pumped to ensure cement reaches
the surface during the cement job.
· TAM Port Collar will be placed in the casing string at 1000' MD to be used in the event
that cement does not reach the surface in the primary one stage job.
6. Nipple down diverter, nipple up BOP's. Test BOP's. Notify AOGCC 24 hours before test
7. Make up 8 Y2" bit and BHA and drill stage collar and RIH to top of float equipment
· Pressure test casing to 3000 psi for 30 minutes
· Record results and fax to town
8. Drill float equipment and approximately 20' of new hole
· Perform LOT
· Record results and fax to town
9. Drill 8 Y2" hole to TO at ±9347' MD
10. Run and cement 7" 26# L80 BTC-Mod
11. RIH with bit and scrapers
Pressure test casing to 3000 psi for 30 minutes
. Displace well to filtered seawater
12. Run and land 3 Y2" tubing with gas lift completion and packer
13. Nipple down BOP's. Install production tree and pressure test same.
14. Secure well, release rig
1 C-15
Page 1
SG,11/02/98,v1
)
')
DRilliNG FLUID PROGRAM, PRESSURE CALCULATIONS &
DRilliNG AREA RISKS
Kuparuk 1C-15 Producer
Drilling Fluid Type
Surface Hole: Extended Bentonite Slurry
Production Hole: Low Solids Non-Dispersed System
Drilling Fluid Properties:
Formation Density FV YP PV Filtrate
ppg sec/qt Ib/100 ft2 cP ml/30 min
Permafrost 8.9 120-140 25-40 16-20 12-15
West Sak 9.5-9.8 50-80 15-25 20-26 7-8
Colville 8.8-9.5 35-40 5-8 4-8 8-15
HRZ 9.5 40-50 8-20 15-25 5-6
Kalubik 9.5 40-50 8-20 15-25 5-6
Kuparuk C Sands 9.5 50-60 (Tau 0) 7-9 20-30 12.0
Drilling Fluid System:
Tandem Brandt Scalping Shale Shakers
Triple Derrick Flow Line Cleaners
Solids Processing System to Minimize Drilling Waste
Desander, Mud Cleaner, Centrifuges, Degasser
Pit Level Indicator (Visual and Audio Alarm)
Trip Tank
Fluid Flow Sensor
Fluid Agitators
Mud Hoppers with Mixing Pumps
MASP (Maximum Anticipated Surface Pressure):
Based on estimated Static Bottom Hole Pressure data from nearby wells, expected reservoir pressures in the
Kuparuk sands in the 1 C pad area are approximately 9.2 ppg EMW (equivalent mud weight), depending on the
TVD of the sand layer being evaluated. Assuming a 150 psi overbalance is required to safely drill and trip in this
formation, then a required mud weight of 9.7 ppg can be predicted as a maximum mud weight required to safely
drill this formation, assuming a TVD of 6514'.
Calculating MASP based on the most recent reservoir pressure data from nearby wells, and assuming a gas
gradient of 0.11 psi/ft from the Kuparuk base to surface, the following MASP can be computed:
MASP =
=
(6761 ft)(0.48 - 0.11 psi/ft)
2502 psi
1 C-15
Page 1
SG,11/02/98,v.1
)
)
Drilling Area Risks:
Drilling risks in the 1 C-15 area are lost circulation and potential borehole instability in and below the permafrost
formation. Lost circulation will be addressed with lost circulation material (LCM) and reduced circulating rates as
needed. Borehole instabilty will be addressed through mud treatments and control drilling if necessary. In
addition, there is a possibility of shallow gas on 1 C-Pad. This will be addressed through control drilling and mud
treatments.
Well Proximity Risks:
The nearest existing well to 1C-15 is 1C-02. As designed, the minimum distance between the two wells would
be 23.7' at 5331 MD.
Annular Pumping Activities:
Incidental fluids generated from drilling operations will be hauled to the nearest permitted disposal well or will be
pumped down the surface I production casing annulus of a annular disposal permitted existing well on
DS-1 C. Our record indicate that 1 C-13 has approximately 25,000 bbls remaining under the maximum permitted
volume. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping
operations. The 1 C-15 well will be freeze protected after running the 3 Y2" tubing and prior to the drilling rig
moving off of the well.
A ~ul-'A'" J)'~PO~-A l.-
pG-A... 5C1ÞT1 6ø~Ó-E..e..C:t.. YE..$ .... THt:...'l ~~ ~\)~..,. 11'\1 ~ I\J
OIV TH. 5 W>E.,a..t-- nllÞ I C) 8'" I ASc.."D HlrI\ To 5 E.¡\).[) A FÃ>t NIl N F'O · L4M
2>t:::..l:- A1l ~ L t-)--LD .
1 C-1 5
Page 2
5G, 11 /04/98,v.1
TAM International Port Collar set at
+1-1000' MD
Surface csg.
9 5/8" 40# L·80 BTC
(+1-6228' MD I 4485' TV D)
All depths reference
Parker 245 RKB
Production csg.
7" 26# L -80 BTC-Mod
TD to surface
(+1- 9347' MD 16761' TVD)
~u 1C-15 Producer COmPleti,J
8 1/2" Hole / 7" Longstring Casing
~
~
~
~
~
~
~
~
~
~
~
~
~
~
~
~
~
~
~
~
~
~
........f¡!
! ~
~ ~
~ ~
~ ~
~ ~
~ ~
~ ~
~ ~
~ ~
~ ~
~ ~
~ ~
~ ~
~ ~
~ ~
~ ~
~ ~
~ ~
~ ~
~ ~
~ ~
~ ~
~ ~
~ ~
~ ~
~ ~
~ ~
~ ~
~ ~
~ ~
~ ~
~ ~
~ ~
~ ~
~ ~
~ ~
~ ~
~ ~
~ ~
~ ~
~ ~
~ ~
~ -- ~
~ -- ~
~ ~
~ ~
~ ~
-
~ I I ~
~ ~
~ ~
~ ~
~ ~
~ ~
~ ~
~ ~
~ ~
~ :J ~
~ ~
~ ~
~ ~
! . ¡
~ ~
~ ~
~ ~
~ ~
~ ~
~ ~
~ ~
~ ~
~ ~
~ ~
~ ~
9 þ::
~ ~
~ ~
~ ~
~ ~
J. ~
.... ....
~
~
~
~
~
~
~
~
~
~
~
~
~
~
~
L. 3-1/2" 5M FMC Gen IV tubing hanger with 3-1/2" L-80 EUE 8RD-Mod
pin down
K. 3-1/2" 9.3# L-80 EUE 8RD-Mod tubing to surface
J. 3-1/2" Camco 5M TRDP-4E SSSV, EUE 8rd-Mod, 3 1/2" x 6' pups
I. 3-1/2" 9.3# L-80 EUE 8RD-Mod tubing to SSSV w/3 1/2" x 1"
mandrels wI DV's and BK latches. EUE 8rd-Mod connections and 3 1/2"
x 10' pups. Mandrels spaced out as follows:
GLM#
TVD-RKB
MD-RKB
H. 3-1/2" x 1-1/2" Camco 'MMM' mandrel wI RP Shear Valve & RK
latch, 3-1/2" x 10' pups installed, L-80 EUE 8RD-Mod
G. 1 jt 3-1/2" L-80 EUE 8RD-Mod tubing
F. 3 1/2" Camco W Nipple wI 2.81 Selective Profile (No pups)
E. 1 jt 3-1/2" L-80 EUE 8RD-Mod tubing
D. Baker SAB-3 3 1/2" x 7" Packer with 10' 3 1/2" EUE
8rd-Mod pups
C. 1 jt 3-1/2" L-80 EUE 8RD-Mod tubing
B. 3-1/2" Camco "D" landing nipple wI 2.75" ID, No Go profile, EUE 8RD-Mod
(No pups)
A. Tubing Tail with 3 1/2" Shear Out Sub to be set +1- 100 above top
Kuparuk (10' 3 1/2" EUE 8rd Mod pup above)
Future Perforations
SG, 11/2198, v.1
~~~:!~~~
WJ.~~ITE~;'¡i.€!?l:;¡j
Casing Depth
Casing OD
Casing Weight
Hole Size
Upper Casing Volume/Foot
Upper Annulus Volume/Foot
Shoe Joint Length
500' MD above West Sak
Base Permafrost
Class
Excess Requirement
Additive 1
Additive 2
Additive 3
Additive 4
Additive 5
Additive 6
Density
Yield
Water Requirement
Thickening Time
671
853
~ ~.. II
j~
1 C-15 Cement Volumes
Surface Hole
feet
inches
Ibs/ft
inches
bbl/ft
bbl/ft
feet
feet
feet
bbls
sacks
%
%
-%
%
%
%
Class
Excess Requirement
Additive 1
Additive 2
Additive 3
Additive 4
Density
Yield
Water Requirement
Thickening Time
126
596
bbls
sacks
%
___~ .~ 0/ó
%
%
~ i %
~,I %
1C-15 Cement Volumes
Longstring Production Hole
~r~iil~r.rnmrot
Intermediate Casing
IlAV(i!~,!~~t~~..~~i.~rnWl1\ll
Int. Casing Depth
Int. Casing OD
Int. Casing Weight
Hole Size
Casing Volume/Foot
Annulus Volume/Foot
Surface Casing Depth
Shoe Joint Length
Required Cement Length
Class
Excess Requirement
Additive 1
Additive 2
Additive 3
Additive 4
Additive 5
Additive 6
Density
Yield
Water Requirement
Thickening Time
53
250
bbls
sacks
500 -
500 -
1000 -
1500 -
~
+- 2000 -
Q.)
Q.)
'+-
-....-
2500 -
...c
+-
0...
Q.)
o
.3000 -
o
u
3500 -
+-
I-
Q.)
>
4000 -
Q.)
:J
l-
I--
I
V
4500 -
5000 -
5500 -
6000 -
6500 -
70CO -
)
)
ARca Alaska, Inc.
Created by MichQelson
For: GOLDBERG
Structure: Pad 1 C Well: 15
Oote plotted: 22-0ot-98
Plot Ro(or4]nco i:J I ~ Version #4.
Cc ordinctes ere in feet reference slot 115.
Field: Kuparuk River Unit Location: North Slope, Alaska
True Vertiool Depth. ore reference RKB (Porker 1245).
IR.
Was
INTEQ
~~
~~
500
o
500
1000
East (feet) ->
1500 2000 2500 3000 3500 4000 4500 5000 5500 6000
TO - Casing Pt
TARGET - Top C4 ..þ
End of Drop / 7 Casing Pt ~
Begin Angle Drop
SURFACE LOCATION:
1634' FNL. 1239' FWL
SEC. 12, T11N, R10E
o -
o RKB ELEVATION: 101
""
o KOP TVO=300 TMD=300 OEP=O
. 3.00 BEGIN TURN TO TARGET TVD=466 TMD=467 DEP=7
8.82
14.73
20.70 DLS: 3.00 deg per 100 it
26.67
32.66
38.65
44.64
EOC TVD=1783 TMD=1991 DEP=693
BASE PERMAFROST TVD=1801 TMD=2020 DEP=715
TARGET LOCATION:
297' FSL, 1540' FWL
SEC. 6, T11 N. R11 E
TARGET
TVD=6514
TMD=9074
DEP=5905
NORTH 1931
EAST 5581
TO LOCATION:
335' FSL, 1649' FWL
SEC. 6, T11N, R11E
70.91 AZIMUTH
5905' (TO TARGET)
u"'Plone of Proposalu",
MAXIMUM ANGLE
50.37 DEG
TOP WEST SAK SANDS TVD=3856 TMD=5242 OEP=3196
~'v
ws 1 0 TVD=4285 TMO=5914 DEP=3714
C100 TVD==4395 TMD==6087 DEP==3847
9 5/8" CASING PT TVD=4485 TMD==6228 DEP=3956
C80 TVD=4657 TMD=6498 DEP=4163
BEGIN ANGLE DROP TVO=5428 TMD=7706 DEP=5094
C60 TVD=5437 TMD=7721 DEP=5105
C50 TVD=5459 TMD=7755 DEP=5131
C40 TVD = 5733 TMD=8146 DEP=5410
C30 TVD=6099 TMD=8604 DEP=5686
C20 TVD=6226 TMD=8752 DEP=5762
BASE HRZ TVD=6307 TMD=8845 DEP=5806
K-1 MARKER TVD=6384 TMO=8931 OEP=5844 32.49
END OF DROP - 7" CASING PT TVD=6423 TMD=8974 DEP=5863 28.49
TOP D TVO=6479 TMD=90.36 DEP=5889 \"~
TARGET T/C4 TVD=6514 TMD=9074 DEP=5905 þ
TOP C3 TVD=6550 TMD=9114 DEP=5922
TOP C2 TVD=6579 TMD=9146 DEP=S936 ~\.
TOP C1 TVD=6625 TMO=9197 DEP=5957
T/ B SHALE TVD=6649 TMD=9223 DEP=5968
TO -CASING PT TVD=6761 TMD=9347 OEP=6021
48.49
44.49
40.49 DLS: 2.00 deg per 100 ft
36.49
o
1000
1500 2000 2500
3000 3500 4000 4500 5000 5500
6000 6500
500
Vertical Section (feet) ->
Azimuth 70.91 with reference 0.00 N, 0.00 E from slot # 15
2500
- 2000
^
I
- 1500
Z
0
::¡.
- 1000 :::r
,--..,
-
CD
CD
- 500 -I-
"-'"
- 0
TARGET ANGLE
25 DEG
)
ARCO Alaska, Inc.
Pad lC
15
slot #15
Kuparuk River Unit
North Slope, Alaska
---
PRO P~S ALL I S TIN G
INCLUDING POSITION UNCERTAINTIES
by
Baker Hughes INTEQ
Your ref
Our ref
License
15 Version #4
prop2943
Date printed
Date created
Last revised
21-0ct-98
22-May-98
21-0ct-98
Field is centred on n70 16 18.576,w150 5 56.536
Structure is centred on n70 19 45.173,w149 30 19.124
Slot location is n70 19 29.102,w149 29 42.960
Slot Grid coordinates are N 5968604.409, E 562245.762
Slot local coordinates are 1634.00 S 1239.00 E
Projection type: alaska - Zone.4, Spheroid: Clarke - 1866
Reference North is True North
)
ARCO Alaska, Inc.
Pad lC,15
Kuparuk River Unit,North Slope, Alaska
Measured Inclin. Azimuth True Vert
Depth Degrees Degrees Depth
0.00
100.00
200.00
300.00
400.00
466.67
500.00
600.00
700.00
800.00
900.00
1000.00
1100.00
1200.00
1300.00
1400.00
1500.00
1600.00
1700.00
1800.00
1900.00
1991.12
2000.00
2019.99
2500.00
3000.00
3500.00
4000.00
4500.00
5000.00
5241. 84
5500.00
5914.43
6000.00
6086.89
6227.99
6497.65
6500.00
7000.00
7500.00
7705.95
7720.50
7754.54
7800.00
7900.00
8000.00
8100.00
8145.67
8200.00
8300.00
5.00
5.93
8.82
11. 77
14.73
17.71
20.70
23.68
26.67
29.67
32.66
35.65
38.65
41. 65
44.64
47.64
50.37
50.37
50.37
50.37
50.37
50.37
50.37
50.37
50.37
50.37
50.37
50.37
50.37
50.37
50.37
50.37
50."37
50.37
50.37
50.37
50.08
49.40
48.49
46.49
44.49
42.49
41. 58
40.49
38.49
0.00
0.00
0.00
0.00
3.00
0.00
50.00
50.00
50.00
50.00
0.00
100.00
200.00
300.00
399.95
466.46
499.64
598.80
697.18
794.51
890.51
984.94
1077.52
1168.01
1256.16
1341.72
1424.46
1504.15
1580.58
1653.54
1722.82
1782.59
1788.25
1801.00
2107.17
2426.08
2745.00
3063.91
3382.83
3701. 75
3856.00
4020.66
4285.00
4339.58
4395.00
4485.00
4657.00
4658.50
4977.41
5296.33
5427.69
5437.00
5459.00
5488.86
5556.43
5626.53
5699.08
5733.00
5773.98
5851.15
R E C TAN G U L A R
COO R DIN ATE S
0.00 N
0.00 N
0.00 N
0.00 N
1.68 N
4.67 N
6.62 N
13.50 N
21,87 N
31. 73 N
43.05 N
55.79 N
69.92 N
85.41 N
102.20 N
120.26 N
139.52 N
159.95 N
181. 49 N
204.07 N
227.63 N
249.91 N
252.11 N
257.08 N
376.33 N
500.56 N
624.78 N
749.00 N
873.22 N
997.45 N
1057.53 N
1121. 67 N
1224.63 N
1245.89 N
1267.48 N
1302.53 N
1369.53 N
1370.11 N
1494.34 N
1618.56 N
1669.73 N
1673.33 N
1681. 71 N
1692.77 N
1716.55 N
1739.55 N
1761. 75 N
1771.62 N
1783.12 N
1803.63 N
0.00 E
0.00 E
0.00 E
0.00 E
2.01 E
5.57 E
8.07 E
18.90 E
34.67 E
55.36 E
80.90 E
111. 22 E
146.24 E
185.86 E
229.97 E
278.46 E
331.19 E ....
388.02 E
448.78 E
513.32 E
581.46 E
646.52 E
652.99 E
667.57 E
1017.50 E
1382.00 E
1746.50 E
2111. 00 E
2475.50 E
2840.00 E
3016.30 E
3204.50 E
3506.62 E
3569.00 E
3632.35 E
3735.21 E
3931.80 E
3933.51 E
4298.01 E
4662.51 E
4812.65 E
4823.23 E
4847.82 E
4880.27 E
4950.04 E
5017.53 E
5082.67 E
5111. 62 E
5145.37 E
5205.56 E
Dogleg
Deg/100ft
)
PROPOSAL LISTING Page 1
Your ref 15 Version #4
Last revised: 21-0ct-98
Vert
Sect
0.00
0.00
0.00
0.00
3.00
0.00
0.00
0.00
0.00 KOP
2.45
50.00
53.76
60.18
63.43
65.39
66.70
67.64
68.36
68.92
69.38
69.76
70.08
70.36
70.61
70.82
71.02
71.18
71.18
71. 18
71.18
71.18
71.18
71.18
71.18
71.18
71.18
71.18
71.18
71.18
71.18
71.18
71.18
71.18
71.18
71.18
71.18
71.18
71.18
71.i8
71.18
71.18
71.18
71.18
71.18
71.18
3.00
3.00
3.00
3.00
3.0.0
6.79 Begin Turn to Target
9.79
22.27
39.92
62.69
3.00
3.00
3.00
3.00
3.00
90.53
123.35
161.06
203.57
250.75
3.00
3.00
3.00
3.00
3.00
302.48
358.61
418.99
483.46
551.84
3.00
3.00
0.00
0.00
0.00
623.93
692.70 EOC
699.54
714.93 Base Permafrost
1084.62
0.00
0.00
0.00
0.00
0.00
1469.70
1854.79
2239.87
2624.95
3010.04
0.00
0.00
0.00
0.00
0.00
3196.29 Top West Sak Sands
3395.12
3714.30 WS10
3780.20
3847.12 C100
0.00
0.00
0.00
0.00
0.00
3955.79 9 5/8" Casing pt
4163.48 C80
4165.29
4550.37
4935.45
0.00
2.00
2.00
2.00
2.00
5094.07 Begin Angle Drop
5105.25 C60
5131. 23 C50
5165.51
5239.22
2.00
2.00
2.00
2.00
2.00
5310.52
5379.34
5409.92 C40
5445.58
5509.17
All data is in feet unless otherwise stated.
Coordinates from slot #15 and TVD from RKB (Parker #245) (101.00 Ft above mean sea level) .
Bottom hole distance is 6020.63 on azimuth 70.91 degrees from wellhead.
Total Dogleg for wel1path is 76.10 degrees.
Vertical section is from wellhead on azimuth 70.91 degrees.
Calculation uses the minimum curvature method.
Presented by Baker Hughes INTEQ
}
ARCO Alaska, Inc. PROPOSAL LISTING Page 2
Pad lC,15 Your ref 15 Version #4
Kuparuk River Unit,North Slope, Alaska Last revised : 2l-0ct-98
Measured Inclin. Azimuth True Vert R E C T A N G U L A R Dogleg Vert
Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/l00ft Sect
8400.00 36.49 71.18 5930.49 1823.27 N 5263.17 E 2.00 5570.03
8500.00 34.49 71.18 6011. 91 1841.99 N 5318.11 E 2.00 5628.08
8600.00 32.49 71.18 6095.31 1859.79 N 5370.34 E 2.00 5683.25
8604.37 32.40 71.18 6099.00 1860.55 N 5372.56 E 2.00 5685.60 C30
8700.00 30.49 71.18 6180.58 1876.64 N 5419.78 E 2.00 5735.48
8752.43 29.44 71.18 6226.00 1885.09 N 5444.56 E 2.00 5761. 67 C20
8800.00 28.49 71.18 6267.62 1892.52 N 5466.37 E 2.00 5784.70
8844.62 27.60 71.18 6307.00 1899.29 N 5486.22 E 2.00 5805.68 Base HRZ
8900.00 26.49 71.18 6356.33 1907.41 N 5510.05 E 2.00 5830.86
8930.84 25.87 71.18 6384.00 1911.80 N 5522.93 E 2.0.0 5844.46 K-l Marker
8974.43 25.00 71.18 6423.37 1917.84 N 5540.66 E 2.00 5863.19 End o~ Drop / 7" Casing pt
9000.00 25.00 71.18 6446.54 1921. 32 N 5550.88 E 0.00 5873.99
9035.82 25.00 71.18 6479.00 1926.21 N 5565.21 E 0.00 5889.13 Top D
9074.42 25.00 71.18 6513.99 1931. 47 N 5580.65 E 0.00 5905.44 TARGET - Top C4
9074.43 25.00 71.18 6514.00 1931. 47 N 5580.66 E 0.00 5905.45 lC-H Conv or Heel Rvsd 21-0ct-98
9114.16 25.00 71.18 6550.00 1936.89 N 5596.55 E 0.00 5922.24 Top C3
9146.15 25.00 71.18 6579.00 1941.25 N 5609.35 E ... 0.00 5·935 . 76 Top C2
9196.91 25.00 71.18 6625.00 1948.17 N 5629.65 E 0.00 5957.21 Top Cl
9223.39 25.00 71.18 6649.00 1951.78 N 5640.24 E 0.00 5968.40 Top B Shale
9346.97 25.00 71.18 6761. 00 1968.63 N 5689.68 E 0.00 6020.63 TD - Casing pt
All data is in feet unless otherwise stated.
Coordinates from slot #15 and TVD from RKB (Parker #245) (101.00 Ft above mean sea level) .
Bottom hole distance is 6020.63 on azimuth 70.91 degrees from wellhead.
Total Dogleg for wellpath is 76.10 degrees.
vertical section is from wellhead on azimuth 70.91 degrees.
Calculation uses the minimum curvature method.
Presented by Baker Hughes INTEQ
)
ARCO Alaska, Inc.
Pad lC,15
Kuparuk River Unit,North Slope, Alaska
MD
TVD
Rectangular Coords.
)
PROPOSAL LISTING Page 3
Your ref 15 Version #4
Last revised: 21-0ct-98
Comments in wellpath
============~~======
Comment
-----------------------------------------------------------------------------------------------------------
300.00
466.67
1991.12
2019.99
5241. 84
5914.43
6086.89
6227.99
6437.65
7705.95
7720.50
7754.54
8145.67
8604.37
8752.43
8844.62
8930.84
8974.43
9035.82
9074.42
9074.43
9114.16
9146.15
9196.91
9223.39
9346.97
300.00
466.46
1782.59
1801. 00
3856.00
4285.00
4395.00
4485.00
4657.00
5427.69
5437.00
5459.00
5733.00
6099.00
6226.00
6307.00
6384.00
6423.37
6479.00
6513.99
6514.00
6550.00
6579.00
6625.00
6649.00
6761. 00
TOp MD Top TVD
0.00 N
4.67 N
249.91 N
257.08 N
1057.53 N
1224.63 N
1267.48 N
1302.53 N
1369.53 N
1669.73 N
1673.33 N
1681. 71 N
1771.62 N
1860.55 N
1885.09 N
1899.29 N
1911.80 N
1917.84 N
1926.21 N
1931. 47 N
1931. 47 N
1936.89 N
1941. 25 N
1948.17 N
1951.78 N
1968.63 N
0.00 E
5.57 E
646.52 E
667.57 E
3016.30 E
3506.62 E
3632.35 E
3735.21 E
3931. 80 E
4812.65 E
4823.23 E
4847.82 E
5111. 62 E
5372.56 E
5444.56 E
5486.22 E
5522.93 E
5540.66 E
5565.21 E
5580.65 E
5580.66 E
5596.55 E
5609.35 E
5629.65 E
5640.24 E
5689.68 E
Rectangular Coords.
KOP
Begin Turn to Target
EOC
Base Permafrost
Top West Sak Sands
WSI0
CI00
9 5/8" Casing pt
C80
Begin Angle Drop
C60
C50
C40
C30
C20
Base HRZ
K-l Marker
End of Drop A.. 7" Casing pt
Top D
TARGET - Top C4
lC-H Conv or Heel Rvsd 21-0ct-98
Top C3
Top C2
Top Cl
Top B Shale
TD - Casing pt
Casing positions in string 'A'
============~=================
Bot MD Bot TVD
Rectangular Coords.
-----------------------------------------------------------------------------------------------------------
Casing
Target name
0.00
0.00
0.00
0.00
0.00
0.00
O.OON
O.OON
O.OON
O.OOE
O.OOE
O.OOE
6227.99
8974.43
9346.97
1302.53N
1917.84N
1968.63N
4485.00
6423.37
6761. 00
Targets associated with this wellpath
=====================================
3735.21E
5540.66E
5689.68E
Geographic Location
1931. 47N
Rectangular Coordinates
5580.66E 22-May-98
9 5/8" Casing
7" Casing
5 1/2" Casing
-----------------------------------------------------------------------------------------------------------
Revised
T.V.D.
lC-H Conv or Heel Rv 567810.000,5970581.000,2.0000 6514.00
)
ARCO Alaska, Inc.
Pad 1C,15
Kuparuk River Unit,North Slope, Alaska
Measured Inclin. Azimuth True Vert
Depth Degrees Degrees Depth
0.00
100.00
200.00
300.00
400.00
466.67
500.00
600.00
700.00
800.00
900.00
1000.00
1100.00
1200.00
1300.00
1400.00
1500.00
1600.00
1700.00
1800.00
1900.00
1991.12
2000.00
2019.99
2500.00
3000.00
3500.00
4000.00
4500.00
5000.00
5241. 84
5500.00
5914.43
6000.00
6086.89
6227.99
6497.65
6500.00
7000.00
7500.00
7705.95
7720.50
7754.54
7800.00
7900.00
8000.00
8100.00
8145.67
8200.00
8300.00
5.00
5.93
8.82
11. 77
14.73
17.71
20.70
23.68
26.67
29.67
32.66
35.65
38.65
41. 65
44.64
47.64
50.37
50.37
50.37
50.37
50.37
50.37
50.37
50.37
50.37
50.37
50.37
50.37
50.37
50.37
50.37
50.37
50."37
50.37
50.37
50.37
50.08
49.40
48.49
46.49
44.49
42.49
41. 58
40.49
38.49
0.00
0.00
0.00
0.00
3.00
0.00
50.00
50.00
50.00
50.00
0.00
100.00
200.00
300.00
399.95
466.46
499.64
598.80
697.18
794.51
890.51
984.94
1077 . 52
1168.01
1256.16
1341. 72
1424.46
1504.15
1580.58
1653.54
1722.82
1782.59
1788.25
1801. 00
2107.17
2426.08
2745.00
3063.91
3382.83
3701. 75
3856.00
4020.66
4285.00
4339.58
4395.00
4485.00
4657.00
4658.50
4977.41
5296.33
5427.69
5437.00
5459.00
5488.86
5556.43
5626.53
5699.08
5733.00
5773.98
5851.15
R E C TAN G U L A R
COO R DIN ATE S
1634.00 S
1634.00 S
1634.00 S
1634.00 S
1632.32 S
1629.33 S
1627.38 S
1620.50 S
1612.13 S
1602.27 S
1590.95 S
1578.21 S
1564.08 S
1548.59 S
1531.80 S
1513.74 S
1494.48 S
1474.05 S
1452.51 S
1429.93 S
1406.37 S
1384.09 S
1381.89 S
1376.92 S
1257.67 S
1133.44 S
1009.22 S
885.00 S
760.78 S
636.55 S
576.47 S
512.33 S
409.37 S
388.11 S
366.52 S
331. 47 S
264.47 S
263.89 S
139.66 S
15.44 S
35.73 N
39.33 N
47.71 N
58.77 N
82.55 N
105.55 N
127.75 N
137.62 N
149.12 N
169.63 N
1239.00 E
1239.00 E
1239.00 E
1239.00 E
1241.01 E
1244.57 E
1247.07 E
1257.90 E
1273.67 E
1294.36 E
1319.90 E
1350.22 E
1385.24 E
1424.86 E
1468.97 E
1517.46 E
1570.19 E
1627.02 E
1687.78 E
1752.32 E
1820.46 E
1885.52 E
1891.99 E
1906.57 E
2256.50 E
2621. 00 E
2985.50 E
3350.00 E
3714.50 E
4079.00 E
4255.30 E
4443.50 E
4745.62 E
4808.00 E
4871. 35 E
4974.21 E
5170.80 E
5172.51 E
5537.01 E
5901.51 E
6051. 65 E
6062.23 E
6086.82 E
6119.27 E
6189.04 E
6256.53 E
6321.67 E
6350.62 E
6384.37 E
6444.56 E
Dogleg
Degll00ft
PROPOSAL LISTING Page 1
Your ref 15 Version #4
Last revised : 21-0ct-98
Vert
Sect
0.00
0.00
0.00
0.00
3.00
0.00
0.00
0.00
0.00 :¡COP
2.45
50.00
53.76
60.18
63.43
65.39
66.70
67.64
68.36
68.92
69.38
69.76
70.08
70.36
70.61
70.82
71. 02
71.18
71.18
71.18
71.18
71.18
71.18
71. 18
71.18
71.18
71.18
71.18
71.18
71.18
71.18
71.18
71.18
71.18
71.18
71.18
71.18
71.18
71.18
71.18
71.18
71. 18
71.18
71.18
71. 18
71.18
3.00
3.00
3.00
3.00
3.00
6.79 Begin Turn to Target
9.79
22.27
39.92
62.69
3.00
3.00
3.00
3.00
3.00
90.53
123.35
161. 06
203.57
250.75
3.00
3.00
3.00
3.00
3.00
302.48
358.61
418.99
483.46
551. 84
3.00
3.00
0.00
0.00
0.00
623.93
692.70 EOC
699.54
714.93 Base Permafrost
1084.62
0.00
0.00
0.00
0.00
0.00
1469.70
1854.79
2239.87
2624.95
3010.04
0.00
0.00
0.00
0.00
0.00
3196.29 Top West Sak Sands
3395.12
3714.30 WS10
3780.20
3847.12 Cl00
0.00
0.00
0.00
0.00
0.00
3955.79 9 5/8" Casing pt
4163.48 C80
4165.29
4550.37
4935.45
0.00
2.00
2.00
2.00
2.00
5094.07 Begin Angle Drop
5105.25 C60
5131. 23 C50
5165.51
5239.22
2.00
2.00
2.00
2.00
2.00
5310.52
5379.34
5409.92 C40
5445.58
5509.17
All data is in feet unless otherwise stated.
Coordinates from NW Corner of Sec. 12, T11N, R10E and TVD from RKB (Parker #245) (101.00 Ft above mean sea level).
Bottom hole distance is 6020.63 on azimuth 70.91 degrees from wellhead.
Total Dogleg for wellpath is 76.10 degrees.
Vertical section is from wellhead on azimuth 70.91 degrees.
Calculation uses the minimum curvature method.
Presented by Baker Hughes INTEQ
)
)
)'
ARCO Alaska, Inc. PROPOSAL LISTING Page 2
Pad 1C,15 Your ref 15 Version #4
Kuparuk River Unit, North Slope, Alaska Last revised : 21-0ct-98
Measured Inclin. Azimuth True Vert R E C T A N G U L A R Dogleg Vert
Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/100ft Sect
8400.00 36.49 71.18 5930.49 189.27 N 6502.17 E 2.00 5570.03
8500.00 34.49 71.18 6011.91 207.99 N 6557.11 E 2.00 5628.08
8600.00 32.49 71.18 6095.31 225.79 N 6609.34 E 2.00 5683.25
8604.37 32.40 71.18 6099.00 226.55 N 6611. 56 E 2.00 5685.60 C30
8700.00 30.49 71.18 6180.58 242.64 N 6658.78 E 2.00 5735.48
8752.43 29.44 71.18 6226.00 251. 09 N 6683.56 E 2.00 5761. 67 C20
8800.00 28.49 71.18 6267.62 258.52 N 6705.37 E 2.00 5784.70
8844.62 27.60 71.18 6307.00 265.29 N 6725.22 E 2.00 5805.68 Base HRZ
8900.00 26.49 71.18 6356.33 273.41 N 6749.05 E 2.00 5830.86
8930.84 25.87 71.18 6384.00 277.80 N 6761.93 E 2. (}O 5844.46 K-1 Marker
8974.43 25.00 71.18 6423.37 283.84 N 6779.66 E 2.00 5863.19 End of Drop / 7" Casing pt
9000.00 25.00 71.18 6446.54 287.32 N 6789.88 E 0.00 5873.99
9035.82 25.00 71.18 6479.00 292.21 N 6804.21 E 0.00 5889.13 Top D
9074.42 25.00 71.18 6513.99 297.47 N 6819.65 E 0.00 5905.44 TARGET - Top C4
9074.43 25.00 71.18 6514.00 297.47 N 6819.66 E 0.00 5905.45 1C-H Conv or Heel Rvsd 21-0ct-98
9114 .16 25.00 71.18 6550.00 302.89 N 6835.55 E 0.00 5.922.24 Top C3
9146.15 25.00 71.18 6579.00 307.25 N 6848.35 E ..... 0.00 5935.76 Top C2
9196.91 25.00 71.18 6625.00 314.17 N 6868.65 E 0.00 5957.21 Top C1
9223.39 25.00 71.18 6649.00 317.78 N 6879.24 E 0.00 5968.40 Top B Shale
9346.97 25.00 71.18 6761. 00 334.63 N 6928.68 E 0.00 6020.63 TD - Casing pt
All data is in feet unless otherwise stated.
Coordinates from NW Corner of Sec. 12, T11N, R10E and TVD from RKB (Parker #245) (101.00 Ft above mean sea level).
Bottom hole distance is 6020.63 on azimuth 70.91 degrees from wellhead.
Total Dogleg for wellpath is 76.10 degrees.
Vertical section is from wellhead on azimuth 70.91 degrees.
Calculation uses the minimum curvature method.
Presented by Baker Hughes INTEQ
)
ARCO Alaska, Inc.
Pad lC,15
Kuparuk River Unit,North Slope, Alaska
PROPOSAL LISTING Page 3
Your ref 15 Version #4
Last revised: 21-0ct-98
Comments in we11path
======~============~
MD
TVD
Rectangular Coords.
Comment
-----------------------------------------------------------------------------------------------------------
300.00 300.00 1634.00 S 1239.00 E KOP
466.67 466.46 1629.33 S 1244.57 E Begin Turn to Target
1991.12 1782.59 1384.09 S 1885.52 E EOC
2019.99 1801.00 1376.92 S 1906.57 E Base Permafrost
5241. 84 3856.00 576.47 S 4255.30 E Top West Sak Sands
5914.43 4285.00 409.37 S 4745.62 E WS10
6086.89 4395.00 366.52 S 4871. 35 E Cl00
6227.99 4485.00 331. 47 5 4974.21 E 9 5/8" Casing pt
6497.65 4657.00 264.47 5 5170.80 E C80
7705.95 5427.69 35.73 N 6051.65 E Begin Angle Drop
7720.50 5437.00 39.33 N 6062.23 E C60
7754.54 5459.00 47.71 N 6086.82 E C50
8145.67 5733.00 137.62 N 6350.62 E C40
8604.37 6099.00 226.55 N 6611. 56 E C30
8752.43 6226.00 251.09 N 6683.56 E C20
8844.62 6307.00 265.29 N 6725.22 E Base HRZ
8930.84 6384.00 277.80 N 6761.93 E K-1 Marker
8974.43 6423.37 283.84 N 6779.66 E End of Drop ;..,. 7" Casing pt
9035.82 6479.00 292.21 N 6804.21 E Top D
9074.42 6513.99 297.47 N 6819.65 E TARGET - Top C4
9074.43 6514.00 297.47 N 6819.66 E 1C-H Conv or Heel Rvsd 21-0ct-98
9114.16 6550.00 302.89 N 6835.55 E Top C3
9146.15 6579.00 307.25 N 6848.35 E Top C2
9196.91 6625.00 314.17 N 6868.65 E Top C1
9223.39 6649.00 317.78 N 6879.24 E Top B Shale
9346.97 6761. 00 334.63 N 6928.68 E TD - Casing pt
Casing positions in string 'A'
==============================
Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing
-----------------------------------------------------------------------------------------------------------
0.00
0.00
0.00
0.00
0.00
0.00
1634.005
1634.00S
1634.005
1239.00E
1239.00E
1239.00E
6227.99
8974.43
9346.97
4485.00
6423.37
6761. 00
331. 475
283.84N
334.63N
4974.21E
6779.66E
6928.68E
9 5/8" Casing
7" Casing
5 1/2" Casing
Targets associated with this we11path
========================z====~=======
Target name
Geographic Location
T.V.D.
Rectangular Coordinates
Revised
----------------------------------------------------------------------------.------------------------------
lC-H Conv or Heel Rv 567810.000,5970581.000,2.0000 6514.00
297.47N
6819.66E 22-May-98
)
ARCO Alaska, Inc. PROPOSAL LISTING Page 1
Pad lC,15 Your ref 15 Version #4
Kuparuk River Unit, North Slope, Alaska Last revised : 21-0ct-98
Measured Inclin. Azimuth True Vert R E C T A N G U L A R Vert Ellipse Semi Axes Minor
Depth Degrees Degrees Depth C 0 0 R D I N A T E S Sect Major Minor Vert. Azi.
0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 0.00 0.00 N/A
100.00 0.00 50.00 100.00 0.00 N 0.00 E 0.00 0.26 0.26 0.15 N/A
200.00 0.00 50.00 200.00 0.00 N 0.00 E 0.00 0.52 0.52 0.30 N/A
300.00 0.00 50.00 300.00 0.00 N 0.00 E 0.00 0.78 0.78 0.45 N/A
400.00 3.00 50.00 399.95 1. 68 N 2.01 E 2.45 1. 06 1. 05 0.60 50.00
466.67 5.00 50.00 466.46 4.67 N 5.57 E 6.79 1.28 1. 22 0.70 50.00
500.00 5.93 53.76 499.64 6.62 N 8.07 E 9.79 1. 40 1.31 0.75 50.90
600.00 8.82 60.18 598.80 13.50 N 18.90 E 22.27 1. 90 1. 60 0.90 55.78
700.00 11.77 63.43 697.18 21.87 N 34.67 E 39.92 2.59 1. 90 1.06 59.04
800.00 14.73 65.39 794.51 31.73 N 55.36 E 62.69 3.53 2.22 1.22 61.34
900.00 17.71 66.70 890.51 43.05 N 80.90 E 90.53 4.74 2.5ª 1. 40 63.05
1000.00 20.70 67.64 984.94 55.79 N 111.22 E 123.35 6.25 2.96 1.59 64.36
1100.00 23.68 68.36 1077.52 69.92 N 146.24 E 161.06 8.08 3.38 1.80 65.40
1200.00 26.67 68.92 1168.01 85.41 N 185.86 E 203.57 10.26 3.82 2.03 66.24
1300.00 29.67 69.38 1256.16 102.20 N 229.97 E 250.75 12.82 4.29 2.30 66.94
1400.00 32.66 69.76 1341.72 120.26 N 278.46 E 302.48 15.77 4.79 2.61 67.51
1500.00 35.65 70.08 1424.46 139.52 N 331.19 E -..358.61 19.13 5.30 2.97 68.00
1600.00 38.65 70.36 1504.15 159.95 N 388.02 E 418.99 22.91 5.83 3.37 68.43
1700.00 41. 65 70.61 1580.58 181. 49 N 448.78 E 483.46 27.13 6.37 3.83 68.79
1800.00 44.64 70.82 1653.54 204.07 N 513.32 E 551. 84 31. 78 6.92 4.34 69.11
1900.00 47.64 71.02 1722.82 227.63 N 581. 46 E 623.93 36.88 7.46 4.91 69.39
1991.12 50.37 71.18 1782.59 249.91 N 646.52 E 692.70 41. 88 7.96 5.48 69.62
2000.00 50.37 71.18 1788.25 252.11 N 652.99 E 699.54 42.37 8.00 5.53 69.64
2019.99 50.37 71.18 1801.00 257.08 N 667.57 E 714.93 43.48 8.11 5.66 69.66
2500.00 50.37 71.18 2107.17 376.33 N 1017.50 E 1084.62 70.08 10.72 8.73 70.27
3000.00 50.37 71.18 2426.08 500.56 N 1382.00 E 1469.70 97.95 13.46 11. 99 70.54
3500.00 50.37 71.18 2745.00 624.78 N 1746.50 E 1854.79 125.86 16.21 15.26 70.68
4000.00 50.37 71.18 3063.91 749.00 N 2111. 00 E 2239.87 153.79 18.96 18.55 70.77
4500.00 50.37 71.18 3382.83 873.22 N 2475.50 E 2624.95 181.73 21. 71 21.83 70.84
5000.00 50.37 71.18 3701. 75 997.45 N 2840.00 E 3010.04 209.69 24.47 25.12 70.88
5241. 84 50.37 71.18 3856.00 1057.53 N 3016.30 E 3196.29 223.21 25.80 26.72 70.90
5500.00 50.37 71.18 4020.66 1121. 67 N 3204.50 E 3395.12 237.64 27.23 28.42 70.92
5914.43 50.37 71.18 4285.00 1224.63 N 3506.62 E 3714.30 260.82 29.51 31.15 70.94
6000.00 50.37 71.18 4339.58 1245.89 N 3569.00 E 3780.20 265.61 29.98 31. 71 70.95
6086.89 50.37 71.18 4395.00 1267.48 N 3632.35 E 3847.12 270.46 30.46 32.28 70.95
6227.99 50.37 71.18 4485.00 1302.53 N 3735.21 E 3955.79 278.36 31.24 33.21 70.96
6497.65 50.37 71.18 4657.00 1369.53 N 3931. 80 E 4163.48 293.44 32.73 34.99 70.97
6500.00 50.-37 71.18 4658.50 1370.11 N 3933.51 E 4165.29 293.57 32.74 35.00 70.97
7000.00 50.37 71.18 4977.41 1494.34 N 4298.01 E 4550.37 321. 53 35.51 38.30 70.99
7500.00 50.37 71.18 5296.33 1618.56 N 4662.51 E 4935.45 349.50 38.27 41.59 71.00
7705.95 50.37 71.18 5427.69 1669.73 N 4812.65 E 5094.07 361. 02 39.40 42.95 71. 01
7720.50 50.08 71.18 5437.00 1673.33 N 4823.23 E 5105.25 361.79 3g.48 43.04 71. 01
7754.54 49.40 71.18 5459.00 1681. 71 N 4847.82 E 5131.23 363.61 39.67 43.26 71. 01
7800.00 48.49 71.18 5488.86 1692.77 N 4880.27 E 5165.51 366.03 39.93 43.54 71. 01
7900.00 46.49 71.18 5556.43 1716.55 N 4950.04 E 5239.22 371.06 40.49 44.14 71. 01
8000.00 44 .49 71.18 5626.53 1739.55 N 5017.53 E 5310.52 375.80 41. 05 44.69 71. 02
8100.00 42.49 71.18 5699.08 1761.75 N 5082.67 E 5379.34 380.25 41. 62 45.21 71.02
8145.67 41. 58 71.18 5733.00 1771.62 N 5111.62 E 5409.92 382.15 41.87 45.44 71.02
8200.00 40.49 71.18 5773.98 1783.12 N 5145.37 E 5445.58 384.41 42.18 45.70 71.02
8300.00 38.49 71.18 5851.15 1803.63 N 5205.56 E 5509.17 388.27 42.73 46.15 71. 02
All data is in feet unless otherwise stated.
Coordinates from slot #15 and TVD from RKB (Parker #245) (101.00 Ft above mean sea level) .
Bottom hole distance is 6020.63 on azimuth 70.91 degrees from wellhead.
Vertical section is from wellhead on azimuth 70.91 degrees.
Calculation uses the minimum curvature method.
presented by Baker Hughes INTEQ
)
ARCO Alaska, Inc. PROPOSAL LISTING Page 2
Pad 1C,15 Your ref 15 Version #4
Kuparuk River Unit, North Slope, Alaska Last revised : 21-0ct-98
Measured Inclin. Azimuth True Vert R E C T A N G U L A R Vert Ellipse Semi Axes Minor
Depth Degrees Degrees Depth C 0 0 R D I NA T E S Sect Major Minor Vert. Azi.
8400.00 36.49 71.18 5930.49 1823.27 N 5263.17 E 5570.03 391. 85 43.28 46.57 71. 02
8500.00 34.49 71.18 6011.91 1841.99 N 5318.11 E 5628.08 395.14 43.82 46.96 71. 02
8600.00 32.49 71.18 6095.31 1859.79 N 5370.34 E 5683.25 398.15 44 .35 47.31 71.03
8604.37 32.40 71.18 6099.00 1860.55 N 5372.56 E 5685.60 398.27 44.37 47.33 71. 03
8700.00 30.49 71.18 6180.58 1876.64 N 5.419.78 E 5735.48 400.89 44.87 47.64 71. 03
8752.43 29.44 71.18 6226.00 1885.09 N 5444.56 E 5761. 67 402.19 45.13 47.79 71.03
8800.00 28.49 71.18 6267.62 1892.52 N 5466.37 E 5784.70 403.36 45.37 47.93 71. 03
8844.62 27.60 71.18 6307.00 1899.29 N 5486.22 E 5805.68 404.35 45.58 48.05 71. 03
8900.00 26.49 71.18 6356.33 1907.41 N 5510.05 E 5830.86 405.58 45.85 48.19 71.03
8930.84 25.87 71.18 6384.00 1911.80 N 5522.93 E 5844.-46 406.20 45.99 48.27 71.03
8974.43 25.00 71.18 6423.37 1917.84 N 5540.66 E 5863.19 407.09 46.2Q 48.37 71. 03
9000.00 25.00 71.18 6446.54 1921. 32 N 5550.88 E 5873.99 407.61 46.32 48.44 71. 03
9035.82 25.00 71.18 6479.00 1926.21 N 5565.21 E 5889.13 408.33 46.49 48.52 71.03
9074.42 25.00 71.18 6513.99 1931. 47 N 5580.65 E 5905.44 409.12 46.67 48.62 71.03
9074.43 25.00 71.18 6514.00 1931.47 N 5580.66 E 5905.45 409.12 46.67 48.62 71. 03
9114.16 25.00 71.18 6550.00 1936.89 N 5596.55 E 5922.24 409.93 46.85 48.71 71.03
9146.15 25.00 71.18 6579.00 1941.25 N 5609.35 E ~935. 76 410.58 47.01 48.79 71. 03
9196.91 25.00 71.18 6625.00 1948.17 N 5629.65 E 5957.21 411. 61 47.24 48.92 71. 03
9223.39 25.00 71.18 6649.00 1951. 78 N 5640.24 E 5968.40 412 . 14 47.37 48.98 71. 03
9346.97 25.00 71.18 6761. 00 1968.63 N 5689.68 E 6020.63 414.66 47.95 49.28 71. 03
POSITION UNCERTAINTY SUMMARY
==~======~====~~=====m~~======
Depth
From To
Survey Tool
Error Model
Position Uncertainty
Major Minor Vert.
----------------------------------------------------------------------------------------------------
9347
ARCO (H.A. Mag)
User specified
414.66
47.95
49.28
1. Ellipse dimensions are half axis.
2. Casing dimensions are not included.
3. Ellipses are calculated on 2.58 standard deviations.
4. Uncertainty calculations start at drill depth zero.
5. Surface position uncertainty 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 other.
7. Detailed description of the INTEQ error models can be found
-in the Ec*Trak manual.
All data is in feet unless otherwise stated.
Coordinates from slot #15 and TVD from RKB (Parker #245) (101.00 Ft above mean sea level) .
Bottom hole distance is 6020.63 on azimuth 70.91 degrees from wellhead.
Vertical section is from wellhead on azimuth 70.91 degrees.
Calculation uses the minimum curvature method.
Presented by Baker Hughes INTEQ
,
)
ARCO Alaska, Inc.
Pad 1C,15
Kuparuk River Unit,North Slope, Alaska
PROPOSAL LISTING Page 3
Your ref 15 Version #4
Last revised: 21-0ct-98
Comments in wellpath
~======~=~==========
MD
TVD
Rectangular Coords.
Comment
-----------------------------------------------------------------------------------------------------------
300.00 300.00 0.00 N 0.00 E KOP
466.67 466.46 4.67 N 5.57 E Begin Turn to Target
1991.12 1782.59 249.91 N 646.52 E EOC
2019.99 1801. 00 257.08 N 667.57 E Base Permafrost
5241.84 3856.00 1057.53 N 3016.30 E Top West Sak Sands
5914.43 4285.00 1224.63 N 3506.62 E WS10
6086.89 4395.00 1267.48 N 3632.35 E C100
6227.99 4485.00 1302.53 N 3735.21 E 9 5/8" Casing pt
6497.65 4657.00 1369.53 N 3931. 80 E C80
7705.95 5427.69 1669.73 N 4812.65 E Begin Angle Drop
7720.50 5437.00 1673.33 N 4823.23 E C60
7754.54 5459.00 1681. 71 N 4847.82 E C50
8145.67 5733.00 1771.62 N 5111. 62 E C40
8604.37 6099.00 1860.55 N 5372.56 E C30
8752.43 6226.00 1885.09 N 5444.56 E C20
8844.62 6307.00 1899.29 N 5486.22 E Base HRZ
8930.84 6384.00 1911. 80 N 5522.93 E K-1 Marker
8974.43 6423.37 1917.84 N 5540.66 E End of Drop ¡.. 7" Casing pt
9035.82 6479.00 1926.21 N 5565.21 E Top D
9074.42 6513.99 1931.47 N 5580.65 E TARGET - Top C4
9074.43 6514.00 1931.47 N 5580.66 E 1C-H Conv or Heel Rvsd 21-0ct-98
9114.16 6550.00 1936.89 N 5596.55 E Top C3
9146.15 6579.00 1941.25 N 5609.35 E Top C2
9196.91 6625.00 1948.17 N 5629.65 E Top C1
9223.39 6649.00 1951.78 N 5640.24 E Top B Shale
9346.97 6761. 00 1968.63 N 5689.68 E TD - Casing pt
Casing positions in string 'A'
==============================
Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing
-----------------------------------------------------------------------------------------------------------
0.00
0.00
0.00
0.00
0.00
0.00
O.OON
O.OON
O.OON
O.OOE
O.OOE
O.OOE
6227.99
8974.43
9346.97
4485.00
6423.37
6761. 00
1302.53N
1917.84N
1968.63N
3735.21E
5540.66E
5689.68E
9 5/8" Casing
7" Casing
5 1/2" Casing
Targets associated with this we11path
=====================================
Target name
Geographic Location
T.V.D.
Rectangular Coordinates
Revised
-----------------------------------------------------------------------------------------------------------
1C-H Conv or Heel Rv 567810.000,5970581.000,2.0000 6514.00
1931. 47N
5580.66E 22-May-98
ARCO Alaska, Inc.
Pad 1C,15
Kuparuk River Unit, North Slope, Alaska
Measured Inclin
Deptb Degrees
0.00
100.00
200.00
300.00
400.00
466.67
500.00
600.00
700.00
800.00
900.00
1000.00
1100.00
1200.00
1300.00
1400.00
1500.00
1600.00
1700.00
1800.00
1900.00
1991. ~2
2000.00
2019.99
2500.00
3000.00
3500.00
4000.00
4500.00
5000.00
5241. 84
5500.00
5914.43
6000.00
6086.89
6227.99
6497.65
6500.00
7000.00
7500.00
7705.95
7720.50
7754.54
7800.00
7900.00
8000.00
8100.00
8145.67
8200.00
8300.00
0.00
0.00
0.00
0.00
3.00
5.00
5.93
8.82
11. 77
14.73
17.71
20.70
23.68
26.67
29.67
32.66
35.65
38.65
41. 65
44.64
47.64
50.37
50.37
50.37
50.37
50.37
50.37
50.37
50.37
50.37
50.37
50.37
50.37
50.37
50.37
50.37
50.37
50.3ì
50.37
50.37
50.37
50.08
49.40
48.49
46.49
44.49
42.49
41. 58
40.49
38.49
Azimuth
Degrees
0.00
50.00
50.00
50.00
50.00
50.00
53.76
60.18
63.43
65.39
66.70
67.64
68.36
68.92
69.38
69.76
70.08
70.36
70.61
70.82
71. 02
71.18
71.18
71.18
71.18
71.18
71.18
71.18
71.18
71.18
71.18
71.18
71.18
71.18
71.18
71.18
71.18
71.18
71.18
71.18
71.18
71.18
71.18
71.18
71.18
71.18
71.18
71.18
71.18
71.18
True Vert
Depth
0.00
100.00
200.00
300.00
399.95
466.46
499.64
598.80
697.18
794.51
890.51
984.94
1077.52
1168.01
1256.16
1341. 72
1424.46
1504.15
1580.58
1653.54
1722.82
1782.59
1788.25
1801.00
2107.17
2426.08
2745.00
3063.91
3382.83
3701.75
3856.00
4020.66
4285.00
4339.58
4395.00
4485.00
4657.00
4658.50
4977.41
5296.33
5427.69
5437.00
5459.00
5488.86
5556.43
5626.53
5699.08
5733.00
5773.98
5851.15
R E C TAN G U L A R
COO R DIN ATE S
O.OON
O.OON
O.OON
O.OON
1.68N
4.67N
6.62N
13.50N
21. 87N
31.73N
43.05N
55.79N
69.92N
85.41N
102.20N
120.26N
139.52N
159.95N
181.49N
204.07N
227.63N
249.91N
252.11N
257.08N
376.33N
500.56N
624.78N
749.00N
873.22N
997.45N
1057.53N
1121.67N
1224.63N
1245.89N
1267.48N
1302.53N
1369.53N
1370.11N
1494.34N
1618.56N
1669.73N
1673.33N
16 81. 71N
1692.77N
1716.55N
1739.55N
1761.75N
1771.62N
1783.12N
1803.63N
O.OOE
O.OOE
O.OOE
O.OOE
2.01E
5.57E
8.07E
18.90E
34.67E
55.36E
·80.90E
111. 22E
146.24E
185.86E
229.97E
278.46E
331.19E
388.02E
448.78E
513.32E
581.46E
646.52E
652.99E
667.57E
1017.50E
1382.00E
1746.50E
2111.00E
2475.50E
2840.00E
3016.30E
3204.50E
3506.62E
3569.00E
3632.35E
3735.21E
3931.80E
3933.51E
4298.01E
4662.51E
4812.65E
4823.23E
4847.82E
4880.27E
4950.04E
5017.53E
5082.67E
5111.62E
5145.37E
5205.56E
)
PROPOSAL LISTING Page 1
Your ref 15 Version #4
Last revised: 21-0ct-98
G RID
Easting
562245.76
562245.76
562245.76
562245.76
562247.75
562251.29
562253.78
562264.55
562280.25
5623.00.86
562326.30
562356.51
562391. 41
562430.90
562474.88
562523.21
~ 562575.78
562632.43
562693.01
562757.36
562825.30
562890.17
562896.62
562911.15
563260.07
563623.51
563986.96
564350.40
564713.85
565077.29
565253.08
565440.73
565741.98
565804.18
565867.34
565969.90
566165.92
566167.62
566531.07
566894.51
567044.22
567054.77
567079.29
567111. 64
567181.21
567248.51
567313.45
567342.32
567375.98
567435.99
COO R D S
Northing
5968604.41
5968604.41
5968604.41
5968604.41
5968606.11
5968609.13
5968611.10
5968618.06
5968626.56
5968636.59
5968648.11
5968661.10
5968675.51
5968691. 32
5968708.47
5968726.91
5968746.61
5968767.50
5968789.52
5968812.62
5968836.74
5968859.54
5968861. 80
5968866.88
5968988.97
5969116.14
5969243.31
5969370.48
5969497.64
5969624.81
5969686.32
5969751.98
5969857.39
5969879.15
5969901. 25
5969937.14
5970005.73
5970006.32
5970133.49
5970260.66
5970313.04
5970316.74
5970325.32
5970336.63
5970360.98
5970384.53
5970407.25
5970417.35
5970429.13
5970450.13
G E 0 G RAP H I C
COO R DIN ATE S
n70 19 29.10
n70 19 29.10
n70 19 29.10
n70 19 2'9.10
n70 19 29.12
n70 19 29.15
n70 19 29.17
n70 19 29.23
n70 19 29.32
n70 19 29.41
n70 19 29.53
n70 19 29.65
n70 19 29.79
n70 19 29.94
n70 19 30.11
n70 19 30.28
n70 19 30.47
n70 19 30.67
n70 19 30.89
n70 19 31.11
n70 19 31.34
n70 19 31.56
n70 19 31.58
n70 19 31.63
n70 19 32.80
n70 19 34.02
n70 19 35.24
n70 19 36.46
n70 19 37.68
n70 19 38.90
n70 19 39.49
n70 19 40.12
n70 19 41.13
n70 19 41. 34
n70 19 41.55
n70 19 41. 90
n70 19 42.55
n70 19 42.56
n70 19 43.78
n70 19 45.00
n70 19 45.50
n70 19 45.54
n70 19 45.62
n70 19 45.73
n70 19 45.96
n70 19 46.19
n70 19 46.40
n70 19 46.50
n70 19 46.61
n70 19 46.81
w14 9 29 42. 96
w14 9 29 42. 96
w1492942.96
w149 29 42.96
w149 29 42.90
w149 29 42.80
w149 29 42.72
w149 29 42.41
w149 29 41. 95
w149 29 41. 34
w14 9 29 40. 60
w149 29 39.71
w149 29 38.69
w149 29 37.53
w149 29 36.25
w149 29 34.83
w14 9 2 9 33. 29
w149 29 31. 63
w14 9 2 9 29. 86
w149 29 27.98
w149 29 25.99
w149 29 24.09
w149 29 23.90
w149 29 23.47
w149 29 13.26
w149 29 02.62
w14 9 28 51. 98
w14 9 28 41. 33
w149 28 30.69
w14 9 28 20. 05
w149 28 14.90
w149 28 09.41
w14 9 28 00. 59
w149 27 58.76
w14 9 27 56. 91
w149 27 53.91
w14 9 27 48. 17
w149 27 48.12
w149 27 37.48
w149 27 26.83
w14 9 27 22. 45
w149 27 22.14
w14 9 27 21. 42
w149 27 20.47
w149 27 18.44
w149 27 16.47
w149 27 14.56
w149 27 13.72
w149 27 12.73
w149 27 10.97
All data in feet unless otherwise stated. Calculation uses minimum curvature method.
Coordinates from slot #15 and TVD from RKB (Parker #245) (101.00 Ft above mean sea level).
Bottom hole distance is 6020.63 on azimuth 70.91 degrees from wellhead.
Total Dogleg for wellpath is 76.10 degrees.
Vertical section is from wellhead on azimuth 70.91 degrees.
Grid is alaska - Zone 4.
Grid coordinates in FEET and computed using the Clarke - 1866 spheroid
Presented by Baker Hughes INTEQ
) )
ARCO Alaska, Inc. PROPOSAL LISTING Page 2
Pad lC,15 Your ref 15 Version #4
Kuparuk River Unit, North Slope, Alaska Last revised : 21-0ct-98
Measured Inclin Azimuth True Vert R E C T A N G U L A R G RID C o 0 R D S G E 0 G R A P H I C
Depth Degrees Degrees Depth C 0 0 R D I NA T E S Easting Northing C 0 0 R D I N A T E S
8400.00 36.49 71.18 5930.49 1823.27N 5263.17E 567493.43 5970470.23 n70 19 47.01 w149 27 09.29
8500.00 34.49 71.18 6011. 91 1841. 99N 5318.llE 567548.22 5970489.40 n70 19 47.19 w149 27 07.69
8600.00 32.49 71.18 6095.31 1859.79N 5370.34E 567600.29 5970507.62 n70 19 47.37 w149 .27 06.16
8604.37 32.40 71.18 6099.00 1860.55N 5372.56E 567602.50 5970508.39 n70 19 47.37 w149 27 06.10
8700.00 30.49 71.18 6180.58 1876.64N 5419.7BE 567649.58 5970524.87 n70 19 47.53 w149 27 04.72
8752.43 29.44 71.18 6226.00 1885.09N 5444.56E 567674.30 5970533.51 n70 19 47.61 w149 27 03.99
8800.00 28.49 71.18 6267.62 1892.52N 5466.37E 567696.04 5970541.12 n70 19 47.69 w149 27 03.36
8844.62 27.60 71.18 6307.00 1899.29N 5486.22E 567715.84 5970548.05 n70 19 47.75 w149 27 02.78
8900.00 26.49 71.18 6356.33 1907.41N 5510.05E 567739.60 5970556.37 n70 19 47.83 w149 27 02.08
8930.84 25.87 71.18 6384.00 1911. 80N 5522.93E 5677 S2. 44 5970560.86 n70 19 47.88 w149 27 01.71
8974.43 25.00 71.18 6423.37 1917.84N 5540.66E 567770.11 5970567.04 n70 19 47.93 w149 27 01.19
9000.00 25.00 71.18 6446.54 1921. 32N 5550.88E 567780.31 5970570.61 n70 19 47.97 w149 27 00.89
9035.82 25.00 71.18 6479.00 1926.21N 5565.21E 567794.60 5970575.61 n70 19 48.02 w149 27 00.47
9074.42 25.00 71.18 6513.99 1931.47N 55BO.65E 567810.00 5970581. 00 n70 19 48.07 w149 27 00.02
9074.43 25.00 71.18 6514.00 1931.47N 5580.66E 567810.00 5970581. 00 n70 19 48.07 w149 27 00.02
9114. H 25.00 71.18 6550.00 1936.89N 5596.55E 567825.84 5970586.54 n70 19 48.12 w149 26 59.56
9146.15 25.00 71.18 6579.00 1941.25N 5609.35E ..... 567838.61 5970591. 01 n70 19 48.16 w149 26 59.18
9196.91 25.00 71.18 6625.00 1948.17N 5629.6SE 5678S8.85 5970598.09 n70 19 48.23 w149 26 58.59
9223.39 25.00 71.18 6649.00 19S1.78N S640.24E 567869.41 5970601. 79 n70 19 48.27 w149 26 S8.28
9346.97 25.00 71.18 6761. 00 1968.G3N 5G89.G8E 567918.70 5970G19.04 n70 19 48.43 w149 26 56.84
All data in feet unless otherwise stated. Calculation uses minimum curvature method.
Coordinates from slot #15 and TVD from RKB (Parker #245) (101.00 pt above mean sea level).
Bottom hole distance is G020.63 on azimuth 70.91 degrees from wellhead.
Total Dogleg for wellpath is 76.10 degrees.
Vertical section is from wellhead on azimuth 70.91 degrees.
Grid is alaska - Zone 4.
Grid coordinates in PEET and computed using the Clarke - 1866 spheroid
Presented by Baker Hughes INTEQ
ARCO Alaska, Inc.
Pad 1C,15
Kuparuk River Unit, North Slope, Alaska
PROPOSAL LISTING Page 3
Your ref 15 Version #4
Last revised: 21-0ct-98
Comments in wellpath
====================
MD
TVD
Rectangular Coords.
Comment
.----------------------------------------------------------------------------------------------------------
300.00 300.00 O.OON O.OOE KOP
466.67 466.46 4.67N 5.57E Begin Turn to Target
1991.12 1782.59 249.91N 646.52E EOC
2019.99 1801. 00 257.08N 667.57E Base Permafrost
5241. 84 3856.00 1057.53N 3016.30E Top West Sak Sands
5914.43 4285.00 1224.63N 3506.62E WSI0
6086.89 4395.00 1267.48N 3632.35E CIOO
6227.99 4485.00 1302.53N 3735.21E 9 5/8" Casing pt
6497.65 4657.00 1369.53N 3931. 80E C80
7705.95 5427.69 1669.73N 4812.65E Begin Angle Drop
7720.50 5437.00 1673.33N 4823.23E C60
7754.54 5459.00 1681. 7lN 4847.82E C50
8145.67 5733.00 1771. 62N 5111.62E C40
8604.37 6099.00 1860.55N 5372.56E C30
8752.43 6226.00 1885.09N 5444.56E C20
8844.62 6307.00 1899.29N 5486.22E Base HRZ
8930.84 6384.00 1911. 80N 5522.93E K-l Marker
8974.43 6423.37 1917.84N 5540.66E End of Drop 1--7 " Casing pt
9035.82 6479.00 1926.21N 5565.21E Top D
9074.42 6513.99 1931.47N 5580.65E TARGET - Top C4
9074.43 6514.00 1931.47N 5580.66E lC-H Conv or Heel Rvsd 21-0ct-98
9114.16 6550.00 1936.89N 5596.55E Top C3
9146.15 6579.00 1941.25N 5609.35E Top C2
9196.91 6625.00 1948.17N 5629.65E Top Cl
9223.39 6649.00 1951. 78N 5640.24E Top B Shale
9346.97 6761. 00 1968.63N 5689.68E TD - Casing pt
Casing positions in string 'A'
==============================
Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing
-----------------------------------------------------------------------.-----------------------------------
0.00
0.00
0.00
0.00
0.00
0.00
O.OON
O.OON
O.OON
O.OOE
O.OOE
O.OOE
6227.99
8974.43
9346.97
4485.00
6423.37
6761. 00
1302.53N
1917.84N
1968.63N
3735.21E
5540.66E
5689.68E
9 5/8" Casing
7" Casing
5 1/2" Casing
Targets associated with this wellpath
================~=~==================
Target name
Geographic Location
T.V.D.
Rectangular Coordinates
Revised
-----------------------------------------------------------------------------------------------------------
lC-H Conv or Heel Rv 567810.000,5970581.000,2.0000 6514.00
1931. 47N
5580.66E 22-May-98
Created by fin-:h
For: GOLDBERG
Dole plolled : 22-0c\-98
Plot Reference is 15 Version /14.
Coordinate. ore in reet reference 5101 1115.
True Vertical Depths a,.e ,.eferençe RKB (Parker 6245).
....
~
fNTEQ
80 40
480 -
440-
400 -
80
, 120
o
40
360 -
////(f;)
,///1300
^
I
320 _ "",////,/í500
280 _ """"""",///12:>,
240 _ ///,//í 400
200 - 1 1 O~// /
_ ~/ ,,/í 300
......ç:. ""
160- ...~
,,--...
-t-
(l)
Q)
'>-
'--"
....c
-t-
!.....
o
Z
800
120 -
700
80
ARca Alaska,
Inc.
~~
~".
Structure: Pad 1 C Well : 15
Field : Kuparuk River Unit Location: North Slope, Alaska
160
240
East (feet) ->
280 320 360 400 440
800
200
ø
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/
//'//
/,////
2100
2000
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I
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,///' - 400
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//..../i2~?-/// _.---.--------- _,//,/--
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80 40 0 40 80 120
480
520
560
600
640
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720
760
----
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- 280
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- 120
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///1600
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2300
Qb- 0
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,----H300··-
@----_.
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I
320 360
East (feet) ->
I-'---¡--- 80
760 800
I
400
I
440
I
480
I
520
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560
I
600
I
640
I
680
I
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...,//~100 .-- .
..' ,/' //'~2700
..."" ,. "
//... ,..,/0//2000 //2600
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""".........,//,/.2000 ,/ "
......... /,///"1900 ,//,,/'.....2400
///,/ ///.....i;oo
,..,,/'''í 900 ' ,
.' //,/;1800 ////
,.""" ~,
800 -Øf" .,///,/' ,////'2200
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/'~'1 700 /,/
//,/,//,,/2100
/;' 600 /"2~00
, /
600 - ø-r/ ,///'
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- Ø;'900
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1400
1300 -
1200 -
1100 -
1000 -
900
^
I
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-+-
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Q)
-
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700
...c
-+-
~
o
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ARca Alasl{a~
Inc.
~~
~,,-
Created by finch
For: GOLDBERG
Structure : Pod 1 C Well : 15
Dale plaUed : 22-0cl-96
Pial Reference is 15 Version /Ii.
Coordinates are in f~ct reference slot * 15.
True Vertical Dcpth~ orc refercnce RKB (Parker 1245).
Field : Kuporuk River Unit Location: North Slope, Alaska
.a.
~
INTEQ
East (feet) ->
700
800
1000
2800
1400
1400
900
1100
1200
1300
1500
1600
1700
1800
1900
2000
2100
2200
2300
2400
2500
2600
2700
- 1300
2800
- 1200
2300
- 1100
_s:::0 - 1000
280_?-~----::--0J
_/-::::-:.--.-,-- 3600 -
2700/,,:::>/ 3500 - 900
_-;;;:::::::::::::::'--3400
2600~:~~~~- 3300
t 31?_9~3200
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1 800 2 7~g_::;~?9.::::;2:~~f~~::;;/
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// 3200 22~9",-'----~~_/-,//~2;~~
,,/.... 3100 2100 _.-,.-' -
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- 800
700
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--+.
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600
5000 5200
5500 5800
- 500
6100
6300 32~_Q-..@-
6500 _-.----.
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_---------·-2800·- 6900
----'2700
300
.........
-----i6Ó;--
300
--...-...-
-------
-----"2SÓO
_--·-----24ÓO
200 - ~,/(800
~
100
o
- 200
----...---
------2200
2300
-...--..-
- 100
_---------ií-õó
--"2000
o
- --"""T-,--,-----.----.---
700
900
1100
2800
1200
1300
1400
1800
1900
2000
1000
1500
1600
1700
2100
2200
800
2300
2400
2500
2600
2700
East (feet) ->
ARca
Alaska,
Grected by rinoh For: GOLDBERG
Dole pl~ited : 22 -Ocl- 96
prot Reference is 15 Version /J4.
CQordinol~s ort: in teet rderence sIal 615.
True VcrlicQI Depths orc reference RKB (Porker 1245).
Structure: Pad 1 C Well: 15
Field : Kuporuk River Unit Location: North Slope, Alaska
.n.
BfILs
INTEQ
East (feet) ->
2000
2600
4200
2800
.3000
3200
3400
3600
2200
2400
3800
4000
2800
^
I
3100&
/'
",I'
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" ,:,~,~,~// /3;~~~500
. / 3300
,/ ,,//-3100
,,1"
."..,.",.,~,~,~,?,./ /,/2900
2000 - . ..' . .//",,/';;00
1 800 - ør' ,
~ //,,/2500
1600 -([fJ'
2600 -
2400 -
2200 -
4100
390?,JI~
3~?,O, //~?-~.~//// -- /'
__ ~,""/"--47;~-/- 4900
33.0.9..--'/-- _
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31 o~...../~~~~~~~~-43âo
2 7~9-~:::::::š;~~:,~o.~;~::::::;:~;;/4; 00
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,~
1f!ty····2500
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-+-
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1200 -
".-....
-+-
(l)
(l)
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[ill]
- /3900
1 400 -@
1000 -
800 -
600 -
4700
5100 5700 ~
6300 ",,""-3900
.J-100 3500
2~.~~___ ---6700
270q.._
-@J-.--
200 -
o
---r- I
2000
2800
3200
4200
3400
3600
3800
3000
4000
2200
2400
2600
East (feet) ->.
Inc.
4400
4600
4800
5000
5200
5400
4900
4300
-~.."
--51'~0
. _//"61 00
,-..' 5900
....-",.-..'55~~·-...·5 700
.' 5 ~OO
4400
4600
5400
4800
5000
5200
5600
5100
----..-
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--6500
5600
~~
~".
5800
6000
6200
2800
- 2600
- 2400
---
- 2200
- 2000
- 1800
^
- 1600 I
Z
- 1400 0
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-+-
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- 800
- 600
- 400
- 200
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6000
6200
-t
l-\RCO Alaska,
L
Inc.
~~
~".
Structure: Pad 1 C Well: 15
Field: Kuparuk River Unit Location: North Slope. Alaska
----
WELL PROFILE DATA
Ecat v. S.ct o.Q/' 00
----- Point ----- ~O Oir "M)
Tic on 0.00 0,00 0.00 0,00
KOP JOO.OO 0.00 ~.OO JOO.OO
a-91" Turn 10 Torq.~ +66.G7 ~.oo ~.OO 466, +6
End at 8uild/Turn 1991. 12 ~0.J7 71. '8 1782.~9
End at Hold 770~.G~ ~0.J7 71. '8 ~427.69
End at Orop(Turn 897UJ 2~.00 71. '8 642J.J7
Tor9~t 1 C-H Con... or H. 907UJ 2~.00 71.18 6~".OO
T,O. ðl Eno of Hold 9J46.97 2~.00 71. 18 6761.00
r
/320
310
300 / 11 OC
290 ~
280
270
260
----
0.00 0.00 0,00 0,00
For: GOLDBERG
Creotl:!d by michael
0,00 0.00 0.00 0.00
Dale plotted: 22-0ct-S6
4,67 ~.~7 6.79 J.oo
Plot Reference 13' ,:> Vcr~ion 14.
Coordinates Qre in r..t r.t,ranco slot N 1~,
H9.9' 646.~2 692.70 J,oo
True Vertical Depths orc reference RICB (Porker 1245)
1669.7J 4812.6~ ~094.07 0,00
.-
BfBLs'
19'7.84 ~~40,66 ~86J,19 2.00
lNTEQ
19J 1..7 ~380.66 ~90~,4~ 0,00
'968.6J ~689.68
TRUE NORTH
<=:r
~
o
1 0
@
30
6020.6J
0.00
350
330
34~
210
20
50
60
70
80
90
100
1 1 0
120
130
140
2'0
150
160
Normal Plane Travelling Cylinder
1 70
All depths shown are Measured depths on Reference Well
)
ARCO Alaska. Inc.
Pad 1C
15
slot #15
Kuparuk River Unit
North Slope, Alaska
)
T R A VEL L I N G C Y L I N D E R C LEA RAN C ERE P 0 R T
INCLUDING POSITION UNCERTAINTIES
by
Baker Hughes INTEQ
Your ref
Our ref
License
Date printed
Date created
Last revised
15 Version #4
prop2943
22-0ct-98
22-May-98
2l-0ct-98
Field is centred on n70 16 18.576,w150 5 56.536
Structure is centred on n70 19 45.173,w149 30 19.124
Slot location is n70 19 29.102,w149 29 42.960
Slot Grid coordinates are N 5968604.409, E 562245.762
Slot local coordinates are 1634.00 S 1239.00 E
Projection type: alaska - Zone 4, Spheroid: Clarke - 1866
Reference North is True North
Report is limited to clearances less than 500 feet
proximities will incorporate ellipses - when survey tools are defined for both wells.
Ellipse separation in reverse brackets, e.g. )10.2(, where available.
The No-Go Option UNCERTAINTY EDGE-EDGE DISTANCE is calculated by reducing the
CENTER-CENTER DISTANCE by both wells' MAJOR UNCERTAINTY RADII in the TC plane,
each radius scaled by a Safety Factor of 1.
Object wellpath
DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4*
GMS <0-7753'>,,5,Pad 1C
PMSS <0-10980'>,,14,Pad 1C
PMSS <0-17089'>,,12.Pad 1C
PMSS <0-11300'>,,11,Pad 1C
GMS <0-9784'>.,7,Pad 1C
GMS <0-9600'>..8.Pad 1C
GMS <0-7780'>,,1,Pad 1C
PGMS <0-9002'>,,10GI,Pad 1C
GMS <0-9700'>,,3,Pad 1C
GMS <0-7575'>,,4,Pad lC
MMS <6948-7570'>"WS#24,Pad 1C
GMS <0-10243'>,,6,Pad lC
MSS <0-7000'>,,9GI,Pad lC
GMS <0-7615'>,,2,Pad 1C
PMSS <0-8677'>,,13,Pad 1C
Closest approach with Travelling
Last revised
5-Aug-92
18-Mar-98
7-Jan-98
19 -Mar- 97
5 -Aug- 92
5-Aug-92
5-Aug-92
5 -Aug- 92
5 -Aug- 92
5-Aug-92
17-Dec-97
5-Aug-92
2-Jan-98
21-0ct-98
17-Feb-98
Distance
)325.9{
) 85.3 (
) 439.2 (
) 724. 9 (
)566.7{
)689.1(
) 124.6 (
) 585.7 (
) 87.1 (
) 206.7 (
}3973.4{
)447.1{
)736.9{
) 23.7 (
}423.6{
M.D.
388.9
833.3
2380.0
322.2
355.6
388.9
888.9
333.3
355.6
366.7
9347.0
355.6
355.6
533.3
344.4
Cylinder method
Diverging from M.D.
388.9
7706.0
2380.0
322.2
355.6
388.9
888.9
333.3
355.6
366.7
9347.0
8974.4
355.6
533.3
344.4
'I,~
.., KUPARUK RIVER L)IT"
20" DIVERTER SCHEMA'TIC
---.J
L--
6 DO NOT SHUT IN DIVERTER
~ L:: ·AND VALVE AT SAME TIME
UNDER ANY CIRCUMSTANCES.
5
4
~ MAINTFNANCF & nPFRAT,nN
.. 1. UPON INITIAL INSTALLATION:
· CLOSE VALVE AND RLL PREVENTER WITH WATER TO
ENSURE NO LEAKS.
3 · CLOSE PREVENTER TO VERIFY OPERATION AND
TI-lATTIiE VALVE OPENS IMMEDIATELY.
I ~ 2. CLOSE ANNULAR PREVENTER IN THE EVENT1HAT AN
INFlUX OF WELLBORE FLUIDS OR GAS IS CETEC'TED.
¡ ..L---J OPEN VALVE TO ACHIEVE DIVERSION.
\ 2 )
LJ
1
ARCO ALASKA. INC.. REOUESTS APPROVAL OF nilS
DIVERTER SYSTEM AS A VARIANCE FROM 20AAC2S.035(b)
. .
1. 16" CONDUCTOR.
2. SLlP.QN WELD STARTING HEAD.
3. DIVERTER ASSEMBLY WITH ONE 2-1/16"· 2000 PSI BALL VALVE.
4. 20"·2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET.
5. ONE 16" HCR KNIÆ VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON
CLOSURE OF ANNULAR PAEVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN
PREVAILING WIND CONDITIONS.
6. 20" - 2000 PSI ANNULAR PAEVENTER.
OKP 11/9/94
..
~
---..J
L-..;.
7
2
<
~
{
{
6
L.,
5
~
=(
4
3
~ 2
\ 1 )
B1
1. 16" - 2000 PSI STARTING HEAD
2. 11" - 3000 PSI CASING HEAD
3. 11" - 3000 PSI X 13-518" - 5000 PSI
SPACER SPOOL
4. 13-5'8" - 5000 PSI VARIABLE PIPE RAMS
5. 13-518" - 5000 PSI DRLG SPOOL WI
CHOKE AND KILL LINES
6. 13-518" - 5000 PSI DOUBLE RAM WI
PIPE RAMS ON TOP. BLIND RAMS ON BTM
7. 13-518" - 5000 PSI ANNULAR
>
>
>
~
13 5/8" 5000 PSI BOP STACK
ACCUMULATOR CAPACITY TEST
1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL
WITH HYDRAULIC FLUID.
2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH
1500 PSI DOWNSTREAM OF THE REGULATOR.
3. OBSERVE TIME. THEN CLOSE ALL UNITS SIMULTANEOUSLY AND
RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS
ARE CLOSED WITH CHARGING PUMP OFF.
4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT
IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING
PRESSURE.
BOP STACK TEST
1. FILL BOP STACK AND MANIFOLD WITH WATER.
2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED.
PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT
IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD.
3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES
ON THE MANIFOLD. ALL OTHERS OPEN.
4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES.
INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 3 MINUTES.
BLEED TO ZERO PSI. TEST ANNULAR PREVENTOR TO 3000 PSI ONLY.
5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE
VALVES.
6. CLOSE TOP PIPE RAMS AND HeR VALVES ON KILL AND CHOKE LINES.
7. TEST TO 250 PSI AND 5000 PSI AS IN STEP 4.
CONTINUE TESTING ALL VALVES, LINES. AND CHOKES WITH A 250 PSI
LOW AND 5000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST
ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE.
8. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM
RAMS TO 250 PSI AND 5000 PSI FOR 3 MINUTES.
9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE.
CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR 3 MINUTES. BLEED TO
ZERO PSI.
10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD
AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE
DRILLING POSITION.
11. TEST STANDPIPE VALVES TO 5000 PSI FOR 3 MINUTES.
12. TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI WITH KOOMEY PUMP.
13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM.
SIGN AND SEND TO DRILLING SUPERVISOR.
14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY
OPERA TE BOPE DAILY.
NOTE: PRIOR TO DRILLING OUT OF THE INTERMEDIATE CASING SHOE
ALL Flß.NGES AND SEALS BROKEN BE1Vv'EEN THIS TEST AND THE PRIOR
ONE WILL BE TESTED TO 250 PSI LOW AND 5000 PSI HIGH
SENT BY:
11-20-58 ;11:35AM
ARCO ALASKA~
)
~
907 276 7542;# 11 1
~~
~",
ARCO Alaska, Inc.
Kuparuk Drlllsite Development
PosL Office ßox 100360
Anchorage, Alaska 99510
Telephone 907265-6206
)
Michael Zanghi
Supervisor
Nav 20, 1998
Alaska Oil and Gas Conservation Commission
3001 Porcupine Drive
Anchorage, AK 99501
{907} 279" 1433
Re; Application for Annular' Disposal
1C..15
Kuparuk Development Production Well, Kuparuk River Unit
Dear Sirs:
We request that 1 C-15 be permitted for annular pumping of fluids occurring as a result of drilling
operatio!'ls, per regulation 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated
prior to initiating annular pumping. Thére will be no USDW1s open below the shoe or potable/industrial
water walls within one mile of the receiving zone. Reference the Permit to Drill Application for other
formation markers in this well.
Surfaoe casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-
500' thick shales are pCirl of the Colville Group and are known to provide vertical barriers to fluid flow. The
surfaoe casing shQe will be set a minimum of 100' vertically below the base of the West Sak into the heart
of the shales.
The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl
without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0
ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of
1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by:
Max Shoe preSsure = (12.0 ppy) it (0.052) * (Surf. Shoe TVD) + 1 ,500 psi
= (12.0 ppg) W (0.052) .. (4485') + 1,500 psi
Max Pressure -= 4,298 psi
This pressure is conservative, sInce frictionallQsses while pumping have not been takan into
consideration. The surface and production casing strings exposed to the annular pumping operations
have sufficient strength by using the 85% collapse and burst ratings.
Fluids to be disposed of in the annulus will be limited lo drilling wastes associated with drilling a well as
defined in 20 AAC 25.080 (h).
If you have any questions or require further information, please contact Scott Goldberg at (907) 263-
4622 or Chip Alvord at (9Q7) 265-6120.
Sincerely,
\,. ..:~-' ~'.',~,,?~ ."..
~- .' ~~-?....
Scott Go dberg c.:,.~~""..
Operations Drilling Engineer
ARCO Alaøka, Inc. Is a Subsidiary of A1lan1h:RiçhfialdCompany
t\c\JClv':D
MOV 20 1998
Alaska 00 & Gas· Coos. Commistioo
~
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INIT CLASS -Ai--' ._..L~!L_. _...q' GEOL AREA _.lr.2-~._-.----_..... UNII tI //('~C) ON/OFF SHORE. OYÙ
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. _~~ _',. _ ... _.. _.n __ __ ~.. .... ~
. ._. ... _ _ _~ _ ... __ _._., .~.. ~ _ u
WELL PERMIT CHECKLIST
_...-.. --..-. --.---.-. .-" -,..
FlEl.D & pooICl90/CJo.
-.-.---.... ,....---.---.-.-..
ADMINISTRA TION
APPI~ /l~~r..i
, dZ.-_./f:ff$?'
ENGJNE1;.BING
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(A) will contain waste in a suitable receiving zone;
(n) will not contaminate freshwater; or cause drilling waste.
10 slIrface;
(C) will not impair mechanical integrity of the well used for disposal; Y N
(I)) will not dmnage producing formation or impair recovery from a Y N
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.=--;=.J.!ieL_~!!..!~!: circumvent 20 AAC 25.252 or 20 AAC 25.412.
GEOl.OGY: ENGINEERING: UIC/Annular COMMISSION:
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1 Permit fee attached.
2. I ease number appropriate.
3 Unique well name and number.
4 Welllocaled in a defined pool. .
5 Welllocaled proper distance horn drilling unit boundary.
G Well located proper distance from other wells
7 Sufficient ncreage available in drilling unit
8 If deviated, is well bore plat included
9 Operator only affected party. .
10 Operator has appropriate bond in force.
11. Permit can be issued without conservation order.
12 Per mit can be issued without administrative approval.
13 Can permit be approved before 15-day wait. .
---...-, ....- -- ..._--
14 Conductor string provided . . .
15 Sur filce casing protects all known USDWs.
16 CM I vol adequate to circulate on conductor & surf csg.
17 CM r vol adequate to tie-in long string to surf esg.
18 CM r will cover all known productive horizons. . .
19. Casing designs adequate for C, T, B & permafrost.
20. Adequate tankage or reserve pit.. . . . . . . . . .
21. If a re·drill, has a 10-403 for abandonment been approved.
22. Adequate wellbore separation proposed.. .
23 If díverter required, does it meet regulations
24. Drilling fluid program schematic & equip list adequate.
25 80[>[s, do they meet regulation. . .
26. BOPE press rating appropriate; test to .5""(')6<"":)
27. Choke manifold complies w/API RP-53 (May 84) .
28 Work will occur without operation shutdown.
29. Is presence of H2S gas probable.. . . . .
'3Õ- Peïllïit can be issued wlo hydrogen sulfide measures.
31 Data presented on potential overpressure z.ones .
32 Seismic analysis of shallow gas zones.
33 Seabed condition survey (if off-shore). .
:~-1 Contact name/phone for weekly progrnss reports
(exploratory only]
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