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Ͳ13
A
196
-1
97
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: Tubing Patch
Development Exploratory
Stratigraphic Service 6. API Number:
7. Property Designation (Lease Number): 8. Well Name and Number:
9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s):
11. Present Well Condition Summary:
Total Depth measured 7755'feet None feet
true vertical 6203' feet None feet
Effective Depth measured 6579'feet 5726', 5795'feet
true vertical 5589' feet 4987', 5039' feet
Perforation depth Measured depth
True Vertical depth
Tubing (size, grade, measured and true vertical depth) 3-1/2" J-55 5836' MD 5071' TVD
Packers and SSSV (type, measured and true vertical depth) 5726' MD
5795' MD
N/A
4987' TVD
5039' TVD
N/A
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure: N/A
13a.
Prior to well operation:
Subsequent to operation:
13b. Pools active after work:
15. Well Class after work:
Daily Report of Well Operations Exploratory Development Service Stratigraphic
Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL
Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG
Sundry Number or N/A if C.O. Exempt:
Authorized Name and
Digital Signature with Date: Contact Name:
Contact Email:
Authorized Title:Contact Phone:
N/A
Sr Pet Eng: Sr Pet Geo: Sr Res Eng:
WINJ WAG
0
Water-BblOil-Bbl
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
N/A
Packer: P2P Patch Packer
Packer: P2P Patch Packer
SSSV: None
Jan Byrne
jan.byrne@conocophillips.com
(907) 265-6471Senior Well Integrity Specialist
7229-7249', 7258-7308', 7356-7366', 7372-7380'
5927-5938', 5943-5969', 5992-5995', 5966-5998'
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)
184
Gas-Mcf
MD
630
Size
110'
1122 993115
0 2030
236
measured
TVD
7"
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
196-197
50-103-20089-01-00
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:
ADL0025531
Kuparuk River Field/ Kuparuk River Oil Pool
KRU 3H-13A
Plugs
Junk measured
Length
Production
Liner
5937'
1947'
Casing
5172'
3-1/2"
5970'
7755' 5983'
3037'
110'Conductor
Surface
Intermediate
16"
9-5/8"
74'
3072' 2929'
Burst Collapse
Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov
Kuparuk River Oil Pool
By Samantha Carlisle at 1:42 pm, Jan 31, 2024
Digitally signed by Jan Byrne
DN: OU=Wells AK, O=ConocoPhillips, CN=
Jan Byrne, E=jan.byrne@conocophillips.com
Reason: I have reviewed this document
Location: Anchorage tower
Date: 2024.01.31 13:31:37-09'00'
Foxit PDF Editor Version: 13.0.0
Jan Byrne
RBDMS JSB 020824
DSR-1/31/24
DTTMSTART JOBTYP SUMMARYOPS
1/10/2024 REPAIR WELL DELAYED START DUE TO WEATHER, SET 1.5" DV @ 5757'
RKB, CLEAN DRIFT W/ 21' DUMMY PATCH TO 5800' RKB,
PULLED 3 1/2 CATCHER @ 5849' RKB, EQUALIZED & PULLED
2.72" RBP @ 5859' RKB. IN PROGRESS.
1/11/2024 REPAIR WELL SET LOWER 2.72" P2P @ 5795' RKB (CE) (4.01' / SN:
CPP35095), SET 3 1/2 TTS TEST TOOL @ SAME, CMIT TBG x
IA 2500 PSI 3 FAILED TEST W/ SAME LLR (.2 BBLS IN 15 MIN'S)
RAN 3 1/2 STUBBY HOLE FINDER CMIT TBG x IA PASSED W/
HOLE FINDER ON 3 1/2 TTS TEST TOOL THEN PASSED WITH
HOLE FINDER OFF TEST TOOL, PULLED 3 1/2 TTS TEST TOOL
@ 5795' RKB, SET 2.70" PBR SPACER & ANCHOR LATCH (OAL
41.24' SN: CPBR35018 / CPAL35189) @ 5752.15' RKB. IN
PROGRESS.
1/12/2024 REPAIR WELL SET 3 1/2 TTS TEST TOOL IN 2.70" PBR @ 5752' RKB. JOB
SUSPENDED FOR WEATHER IN PROGRESS.
1/14/2024 REPAIR WELL CMIT TBG x IA 2500 (PASS), PULLED 3 1/2 TTS TEST TOOL @
5752' RKB. SET UPPER 2.72" P2P PATCH ASSEMBLY @
5726.36' (CE) (OAL 29.08' / SN: CPP35360 / CPAL35177). SET 3
1/2 TTS TEST TOOL @ 5724' RKB, MIT TBG 2500 (PASS) CMIT
TBG x IA 2500 PSI (PASS), PULLED 3 1/2 TTS TEST TOOL @
5724' RKB. JOB COMPLETE.
KRU 3H-13A Tubing Patch
Summary of Operations
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag: RKB 6,579.0 3H-13A 10/21/2023 rogerba
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Set patch assembly 3H-13A 1/14/2024 fergusp
Notes: General & Safety
Annotation End Date Last Mod By
NOTE: WAIVERED WELL: IA x OA COMMUNICATION 1/20/2004 triplwj
NOTE: WELL SIDETRACKED - ORIGINAL COMPLETION DATE 1/4/1988 1/6/1997 triplwj
Casing Strings
Csg Des OD (in) ID (in) Top (ftKB)
Set Depth
(ftKB)
Set Depth
(TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread
CONDUCTOR 16 15.06 36.0 110.0 110.0 62.50 H-40 WELDED
SURFACE 9 5/8 8.92 35.0 3,071.8 2,929.4 36.00 J-55 BTC
PRODUCTION POST
S/T
76.2833.05,970.05,172.5 26.00J-55BTC
LINER 3 1/2 2.99 5,808.4 7,755.0 5,983.2 9.30 L-80 BTC-MOD
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
27.0
Set Depth …
5,836.4
Set Depth …
5,071.0
String Max No…
3 1/2
Tubing Description
TUBING
Wt (lb/ft)
9.30
Grade
J-55
Top Connection
EUE 8rd
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)
27.0 27.0 0.00 HANGER 10.380 McEvoy 3 1/2" 5000# GEN III Tubing
hanger w/ J-55 Pup EUE 8rd top
McEvoy Gen III 2.992
501.5 501.4 0.85 NIPPLE 4.500 3 1/2" Camco 'DS' Nipple 4.50" OD,
2.812" ID
Camco DS 2.812
2,720.1 2,651.1 33.18 GAS LIFT 5.390 3 1/2" x 1" CAMCO 'KBUG',
5.390"OD, 2.920"ID
Camco KBUG 2.920
4,117.6 3,743.9 39.32 GAS LIFT 5.390 3 1/2" x 1" CAMCO 'KBUG',
5.390"OD, 2.920"ID
Camco KBUG 2.920
5,077.1 4,487.9 39.15 GAS LIFT 5.390 3 1/2" x 1" CAMCO 'KBUG',
5.390"OD, 2.920"ID
Camco KBUG 2.920
5,757.2 5,010.8 40.50 GAS LIFT 6.018 3 1/2" x 1 1/2" CAMCO 'MMM',
6.018"OD, 2.920"ID
Camco MMM 2.920
5,802.9 5,045.5 40.51 NIPPLE 4.500 3 1/2" CAMCO 'D' Nipple w/ 2.750"
No-Go Profile. MILLED OUT
10/23/18
Camco D 2.800
5,809.9 5,050.9 40.50 LOCATOR 4.000 BAKER LOCATOR Baker GBH-22 3.000
5,812.0 5,052.4 40.49 SEAL ASSY 4.000 BAKER GBH SEAL ASSEMLY w/10'
STROKE & SPECIAL LOCATOR TO
STAB INTO LINER TIE-BACK
SLEEVE/PACKER
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)
5,726.0 4,987.0 40.49 PACKER -
PATCH - UPR
Set upper patch assembly
( 2.72 P2P, XO, spacer pipe, &
anchor latch (OAL 29.08')
TTS Paragon
2
CPP3
5360/
CPAL
35177
1/14/2024 1.625
5,729.0 4,989.3 40.49 SPACER
PIPE
Spacer pipe CPAI 1/14/2024 1.600
5,740.0 4,997.7 40.49 LEAK Relay LDL located tubing leak
@ 5740' RKB.
11/17/2023 0.000
5,752.0 5,006.8 40.50 PBR Set PBR assembly into lower
packer. (OAL 41.24')
TTS CPPB
R3501
8/CPA
L3509
5
1/11/2024 1.600
5,795.0 5,039.5 40.52 PACKER -
PATCH - LWR
Set P2P lower packer TTS Paragon
2
CPP3
5095
1/11/2024 1.630
5,948.0 5,155.9 41.02 WINDOW SIDETRACK CASING
WINDOW
1/6/1997 6.000
7,257.9 5,942.7 57.87 2 3/8" CTD
LINER TOP
2 3/8" CTD Liner bottom @
7944', lined up into mother
bore @ 7257.9'
11/20/2018 1.992
7,268.0 5,948.1 57.93 TIGHT SPOT BROACHED TBG TO 2.70" IN
TIGHT SPOTS @ 7267' &
7299' SLM. UNABLE TO
DRIFT 23.5' x 2.5" DUMMY
GUNS PAST 7275' SLM
8/16/2009
7,313.0 5,971.9 58.21 TIGHT SPOT BROACHED TBG TO 2.70" IN
TIGHT SPOTS @ 7267' &
7299' SLM. UNABLE TO
DRIFT 23.5' x 2.5" DUMMY
GUNS PAST 7275' SLM
8/16/2009
7,340.0 5,985.3 62.90 WHIPSTOCK BOT 3.5" Monobore XL
Whipstock
10/26/2018
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)
2,720.1 2,651.1 33.18 1 GAS LIFT GLV BK 1 1,205.0 11/29/2018 0.188
4,117.6 3,743.9 39.32 2 GAS LIFT OV BK 1 0.0 11/29/2018 0.250
5,077.1 4,487.9 39.15 3 GAS LIFT DMY BTM 1 0.0 11/29/2018 0.000
5,757.2 5,010.8 40.50 4 GAS LIFT OPEN RK 1 1/2 11/18/2023
3H-13A, 1/26/2024 7:19:24 AM
Vertical schematic (actual)
LINER; 5,808.4-7,755.0
AL1 LINER (Lost window);
7,729.6-10,347.0
2 3/8" CTD LINER TOP; 7,257.9
AL1-03 LINER; 7,257.9-7,944.0
APERF; 7,372.0-7,380.0
APERF; 7,356.0-7,366.0
WHIPSTOCK; 7,340.0
TIGHT SPOT; 7,313.0
IPERF; 7,258.0-7,308.0
TIGHT SPOT; 7,268.0
RPERF; 7,229.0-7,249.0
PRODUCTION POST S/T; 33.0-
5,970.0
WINDOW; 5,948.0
PACKER - PATCH - LWR;
5,795.0
PBR; 5,752.0
GAS LIFT; 5,757.2
LEAK; 5,740.0
SPACER PIPE; 5,729.0
PACKER - PATCH - UPR;
5,726.0
GAS LIFT; 5,077.1
GAS LIFT; 4,117.6
SURFACE; 35.0-3,071.8
GAS LIFT; 2,720.1
NIPPLE; 501.5
CONDUCTOR; 36.0-110.0
KUP PROD
KB-Grd (ft)
37.01
RR Date
1/9/1988
Other Elev…
3H-13A
...
TD
Act Btm (ftKB)
7,755.0
Well Attributes
Field Name
KUPARUK RIVER UNIT
Wellbore API/UWI
501032008901
Wellbore Status
PROD
Max Angle & MD
Incl (°)
99.27
MD (ftKB)
7,426.35
WELLNAME WELLBORE3H-13A
Annotation
Last WO:
End Date
1/6/1997
H2S (ppm)
150
Date
12/22/2017
Comment
SSSV: NIPPLE
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)
5,808.4 5,049.7 40.50 TIEBACK/
PACKER
6.000 BAKER LINER TIEBACK
SLEEVE w/BAKER C-2 ZXP
LINER TOP PACKER
5.250
5,840.9 5,074.4 40.45 XO THREAD 5.625 2.992
7,653.5 5,983.6 90.44 LANDING
COLLAR
4.188 2.992
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
7,229.0 7,249.0 5,927.3 5,937.9 C-4, UNIT B, 3H-
13A
5/9/2002 4.0 RPERF 2.5" HSD, PJ DP Chgs, 60°
ph
7,258.0 7,308.0 5,942.7 5,969.2 A-3, A-2, 3H-
13A
1/21/1997 4.0 IPERF 180° phasing; 2 1/2" HSD
Carrier
7,356.0 7,366.0 5,991.7 5,994.8 A-1, 3H-13A 8/25/2009 6.0 APERF 2" HMX Millenium, 60° pH
7,372.0 7,380.0 5,996.2 5,997.8 A-1, 3H-13A 8/25/2009 6.0 APERF 2" HMX Millenium, 60° pH
3H-13A, 1/26/2024 7:19:25 AM
Vertical schematic (actual)
LINER; 5,808.4-7,755.0
AL1 LINER (Lost window);
7,729.6-10,347.0
2 3/8" CTD LINER TOP; 7,257.9
AL1-03 LINER; 7,257.9-7,944.0
APERF; 7,372.0-7,380.0
APERF; 7,356.0-7,366.0
WHIPSTOCK; 7,340.0
TIGHT SPOT; 7,313.0
IPERF; 7,258.0-7,308.0
TIGHT SPOT; 7,268.0
RPERF; 7,229.0-7,249.0
PRODUCTION POST S/T; 33.0-
5,970.0
WINDOW; 5,948.0
PACKER - PATCH - LWR;
5,795.0
PBR; 5,752.0
GAS LIFT; 5,757.2
LEAK; 5,740.0
SPACER PIPE; 5,729.0
PACKER - PATCH - UPR;
5,726.0
GAS LIFT; 5,077.1
GAS LIFT; 4,117.6
SURFACE; 35.0-3,071.8
GAS LIFT; 2,720.1
NIPPLE; 501.5
CONDUCTOR; 36.0-110.0
KUP PROD 3H-13A
...
WELLNAME WELLBORE3H-13A
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag 3H-13AL1 jennalt
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Added CTD liner top depth, H2S, tight spots 3H-13AL1 12/13/2018 jennalt
Casing Strings
Csg Des OD (in) ID (in) Top (ftKB)
Set Depth
(ftKB)
Set Depth
(TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread
AL1 LINER (2nd
window)
2 3/8 1.99 7,463.7 10,100.0 5,980.4 4.60 L-80 STL
3H-13AL1, 1/26/2024 7:19:26 AM
Vertical schematic (actual)
AL1 LINER (2nd window);
7,463.7-10,100.0
LINER; 5,808.4-7,755.0
AL1-03 LINER; 7,257.9-7,944.0
TIGHT SPOT; 7,313.0
2 3/8" CTD LINER TOP; 7,257.9
IPERF; 7,258.0-7,308.0
TIGHT SPOT; 7,268.0
RPERF; 7,229.0-7,249.0
PRODUCTION POST S/T; 33.0-
5,970.0
WINDOW; 5,948.0
PACKER - PATCH - LWR;
5,795.0
PBR; 5,752.0
GAS LIFT; 5,757.2
LEAK; 5,740.0
SPACER PIPE; 5,729.0
PACKER - PATCH - UPR;
5,726.0
GAS LIFT; 5,077.1
GAS LIFT; 4,117.6
SURFACE; 35.0-3,071.8
GAS LIFT; 2,720.1
NIPPLE; 501.5
CONDUCTOR; 36.0-110.0
KUP PROD
KB-Grd (ft)
37.01
RR Date
1/9/1988
Other Elev…
3H-13AL1
...
TD
Act Btm (ftKB)
10,100.0
Well Attributes
Field Name
KUPARUK RIVER UNIT
Wellbore API/UWI
501032008960
Wellbore Status
PROD
Max Angle & MD
Incl (°)
99.27
MD (ftKB)
7,426.35
WELLNAME WELLBORE3H-13A
Annotation
Last WO:
End DateH2S (ppm)
150
Date
12/22/2017
Comment
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag:3H-13AL1-
02
jennalt
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Added CTD liner top depth, H2S, tight spots 3H-13AL1-
02
12/13/2018 jennalt
Notes: General & Safety
Annotation End Date Last Mod By
NOTE: View Schematic w/ Alaska Schematic10.0 12/13/2018 jennalt
Casing Strings
Csg Des OD (in) ID (in) Top (ftKB)
Set Depth
(ftKB)
Set Depth
(TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread
AL1-02 LINER 2 3/8 1.99 7,721.9 9,473.0 4.60 L-80 STL
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)
7,721.9 5,989.9 86.34 ALUMINUM
BILLET
2.630 Aluminum Liner Top Billet BOT Billet 1.920
3H-13AL1-02, 1/26/2024 7:19:27 AM
Vertical schematic (actual)
AL1-02 LINER; 7,721.9-9,473.0
AL1-03 LINER; 7,257.9-7,944.0
LINER; 5,808.4-7,755.0
APERF; 7,372.0-7,380.0
APERF; 7,356.0-7,366.0
2 3/8" CTD LINER TOP; 7,257.9
WHIPSTOCK; 7,340.0
TIGHT SPOT; 7,313.0
IPERF; 7,258.0-7,308.0
TIGHT SPOT; 7,268.0
RPERF; 7,229.0-7,249.0
PRODUCTION POST S/T; 33.0-
5,970.0
WINDOW; 5,948.0
PACKER - PATCH - LWR;
5,795.0
PBR; 5,752.0
GAS LIFT; 5,757.2
LEAK; 5,740.0
SPACER PIPE; 5,729.0
PACKER - PATCH - UPR;
5,726.0
GAS LIFT; 5,077.1
GAS LIFT; 4,117.6
SURFACE; 35.0-3,071.8
GAS LIFT; 2,720.1
NIPPLE; 501.5
CONDUCTOR; 36.0-110.0
KUP PROD
KB-Grd (ft)
37.01
RR Date
1/9/1988
Other Elev…
3H-13AL1-02
...
TD
Act Btm (ftKB)
9,473.0
Well Attributes
Field Name
KUPARUK RIVER UNIT
Wellbore API/UWI
501032008962
Wellbore Status
PROD
Max Angle & MD
Incl (°)
99.27
MD (ftKB)
7,426.35
WELLNAME WELLBORE3H-13A
Annotation
Last WO:
End DateH2S (ppm)
150
Date
12/22/2017
Comment
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag:3H-13AL1-
03
jennalt
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Added CTD liner top depth, H2S, tight spots 3H-13AL1-
03
12/13/2018 jennalt
Notes: General & Safety
Annotation End Date Last Mod By
NOTE: View Schematic w/ Alaska Schematic10.0 12/13/2018 jennalt
Casing Strings
Csg Des OD (in) ID (in) Top (ftKB)
Set Depth
(ftKB)
Set Depth
(TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread
AL1-03 LINER 2 3/8 1.99 7,257.9 7,944.0 5,968.3 4.60 L-80 STL
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)
7,257.9 5,942.7 57.87 ALUMINUM
BILLET
2.630 Shorty Deployment Sleeve BOT Billet 1.920
3H-13AL1-03, 1/26/2024 7:19:27 AM
Vertical schematic (actual)
AL1-03 LINER; 7,257.9-7,944.0
LINER; 5,808.4-7,755.0
APERF; 7,372.0-7,380.0
APERF; 7,356.0-7,366.0
2 3/8" CTD LINER TOP; 7,257.9
WHIPSTOCK; 7,340.0
TIGHT SPOT; 7,313.0
IPERF; 7,258.0-7,308.0
TIGHT SPOT; 7,268.0
RPERF; 7,229.0-7,249.0
PRODUCTION POST S/T; 33.0-
5,970.0
WINDOW; 5,948.0
PACKER - PATCH - LWR;
5,795.0
PBR; 5,752.0
GAS LIFT; 5,757.2
LEAK; 5,740.0
SPACER PIPE; 5,729.0
PACKER - PATCH - UPR;
5,726.0
GAS LIFT; 5,077.1
GAS LIFT; 4,117.6
SURFACE; 35.0-3,071.8
GAS LIFT; 2,720.1
NIPPLE; 501.5
CONDUCTOR; 36.0-110.0
KUP PROD
KB-Grd (ft)
37.01
RR Date
1/9/1988
Other Elev…
3H-13AL1-03
...
TD
Act Btm (ftKB)
8,243.0
Well Attributes
Field Name
KUPARUK RIVER UNIT
Wellbore API/UWI
501032008963
Wellbore Status
PROD
Max Angle & MD
Incl (°)
100.97
MD (ftKB)
7,898.85
WELLNAME WELLBORE3H-13A
Annotation
Last WO:
End DateH2S (ppm)
150
Date
12/22/2017
Comment
Originated: Delivered to:29ͲNovͲ23
Halliburton Alaska Oil and Gas Conservation Comm.
Wireline & PerforatingAttn.:Natural Resource Technician
Attn: Fanny Haroun 333 West 7th Avenue, Suite 100
6900 Arctic Blvd. Anchorage, Alaska99501
Anchorage, Alaska 99518
Office: 907Ͳ275Ͳ2605
FRS_ANC@halliburton.com
The technical data listed below is being submitted herewith. Please address any problems or
concernstotheattention of the sender above
WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL #
12VͲ14 50Ͳ029Ͳ21294Ͳ00 n/a Kuparuk River Packer Setting Record FieldͲFinal 5ͲMarͲ23 0 1
22WͲ01 50Ͳ029Ͳ21273Ͳ00 n/a Kuparuk River Leak Detect Log FieldͲFinal 16ͲNovͲ23 0 1
32WͲ01 50Ͳ029Ͳ21273Ͳ00 908964770 Kuparuk River Multi Finger Caliper Field & Processed 16ͲNovͲ23 0 1
42WͲ01 50Ͳ029Ͳ21273Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 15ͲNovͲ23 0 1
53FͲ08 50Ͳ029Ͳ21464Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 5ͲJunͲ23 0 1
63GͲ09 50Ͳ103Ͳ20129Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 22ͲNovͲ23 0 1
73HͲ13A 50Ͳ103Ͳ20089Ͳ01 n/a Kuparuk River Leak Detect Log FieldͲFinal 17ͲNovͲ23 0 1
83HͲ13A 50Ͳ103Ͳ20089Ͳ01 908964771 Kuparuk River Multi Finger Caliper Field & Processed 18ͲNovͲ23 0 1
93HͲ13A 50Ͳ103Ͳ20089Ͳ01 n/a Kuparuk River Plug Setting Record FieldͲFinal 17ͲNovͲ23 0 1
10 3JͲ15 50Ͳ029Ͳ21497Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 1ͲOctͲ23 0 1
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:
Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518
FRS_ANC@halliburton.com
Date:Signed:
Transmittal Date:
1. 2V-14 PTD: 185-031 T38189
2. 2W-01 PTD: 185-010 T38190
3. 3F-08 PTD: 185-246 T38191
4. 3G-09 PTD: 190-067 T38192
5. 3H-13A PTD: 196-197 T38193
6. 3J-15 PTD: 185-289 T38194
12/1/2023
73HͲ13A 50Ͳ103Ͳ20089Ͳ01 n/a Kuparuk River Leak Detect Log FieldͲFinal 17ͲNovͲ23 0 1
83HͲ13A 50Ͳ103Ͳ20089Ͳ01 908964771 Kuparuk River Multi Finger Caliper Field &Processed 18ͲNovͲ23 0 1
93HͲ13A 50Ͳ103Ͳ20089Ͳ01 n/a Kuparuk River Plug Setting Record FieldͲFinal 17ͲNovͲ23 0 1
Kayla
Junke
Digitally signed
by Kayla Junke
Date: 2023.12.01
13:20:08 -09'00'
THE STATE
°fALASKA
1.1
GOVERNOR BILL WALKER
James Ohlinger
Staff CTD Engineer
ConocoPhillips Alaska, Inc.
P.O Box 100360
Anchorage, AK 99510-0360
Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3H -13A
Permit to Drill Number: 196-197
Sundry Number: 318-474
Dear Mr. Ohlinger:
Alaska Oil and Gas
Conservation Commission
333 West 7th Avenue
Anchorage, Alaska 99501
Main: 907.297.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
Enclosed is the approved application for the sundry approval relating to the above referenced well.
Please note the conditions of approval set out in the enclosed form.
As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further
time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC
an application for reconsideration. A request for reconsideration is considered timely if it is
received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if
the 23rd day falls on a holiday or weekend.
Hollis S. French
Chair
r
DATED this ZS day of October, 2018.
HBDMSL U oC, 2 4 2018
STATE OF ALASKA _ +
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
1. Type of Request: Abandon ❑ Plug Per orations ❑ 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: CO261 B Whipstock ❑✓ .
2. Operator Name:
4. Current Well Class:
5. Permit to Drill Number:
ConocoPhillips Alaska, Inc.
Exploratory ❑ Development ❑✓ .
Stratigraphic ❑ Service ❑
196-197
3. Address:
6. API Number:
PO Box 100360, Anchorage, AK 99510
50-103-20089-01 -00
7. If perforating:
8. Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool? N/A
KRU 31-1-13A
Will planned perforations require a spacing exception? Yes ❑ No ❑
9. Property Designation (Lease Number):
10. Field/Pool(s):
ADL 25531
Kuparuk River Oil Field / Ku aruk River Oil Pool
11. PRESENT WELL CONDITION SUMMARY
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD):
7755' 6203' 7653' 6150' 4299 N/A N/A
Casing Length Size MD TVD Burst Collapse
Structural
Conductor 74' 16" 110' 110'
Surface 3037' 9-5/8" 3072' 2929'
Intermediate
Production 5937' 7" 5970' 5173'
Liner 1947' 3-1/2" 7755' 6203'
Perforation Depth MD (ft):Perforation
Depth TVD (ft):
Tubing Size:
Tubing Grade:
Tubing MD (ft):
7229' - 7249', 7258' - 7308'
5927' - 5938', 5943'- 5969'
7356'- 7366', 7372'- 7380'
5994' - 6000', 6002'- 6007'
3-1/2"
J-55
5836'
Packers and SSSV Type: Packer (Baker C-2 ZXP Liner Top)
Packers and SSSV MD (ft) and TVD (ft): Packer (5808'/ 5050')
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: 24 -Oct -18
OIL 0 WINJ ❑ WDSPL ❑ Suspended ❑
GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑
16. Verbal Approval: Date:
Commission Representative:
GINJ ❑ Op Shutdown ❑ Abandoned ❑
17. 1 hereby certify that the foregoing is true and the procedure approved herein will not
be deviated from without prior written approval.
Authorized Name: James Ohlinger Contact Name: Keith Herring
Authorized Title: Staff CTD Engineer Contact Email: Keith. E.Herrin co .com
Contact Phone: 263-4321
Authorized Signature: Date: 101.7JzX
COMMISSION OSE ONLY
Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ,r
J
lXJ
Plug Integrity ❑ BOP Test M Mechanical Integrity Test ❑ Location Clearance ❑
Other: )50/> tr5-t -�v 4-9005 / y
�iinvd�✓�rrvi� i�s� 1� z✓rov/os,
Post Initial Injection MIT Req'd? Yes ❑ No
�
Spacing Exception Required? Yes ❑ NoA
d Subsequent Form Required: /� - A
i
APPROVED BY
1 1
Approved by: COMMISSIONER THE COMMISSION Date: V }
Q �F0%b3 Revised 4/21lBDM� ve®tqplij./�li�%/M 1I fbf it �om the date of approval. `/Attachments
Submit Form and v
I
w_�` V HL 1*040�o enn trip Duplicate
9
ConocoPhillips
Alaska
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
October 23, 2018
Commissioner - State of Alaska
Alaska Oil & Gas Conservation Commission
333 West 7th Avenue Suite 100
Anchorage, Alaska 99501
Dear Commissioner:
ConocoPhillips Alaska, Inc. hereby submits Sundry Application (10-403) to set a whipstock in the KRU 3H -13A
(PTD# 196-197). — --
Attached to this application are the following documents:
- 10-403 Sundry Application for KRU 3H -13A
- Operations Summary in support of the 10-403 Sundry Application
- Proposed Pre -CTD Schematic
- Current Well Bore Schematic
If you have any questions or require additional information, please contact me at 907-263-4321.
Sincerely,
Keith Herring
ConocoPhillips Alaska
Coiled Tubing Drilling Engineer
KRU 3H -13A (PTD# 196-197) Summary for Sundry
Background
KRU well 3H -13A is a Kuparuk producer equipped with 3-1/2" tubing and 3-1/2" production liner. The CTD
sidetrack will utilize four laterals to target the Kuparuk sands to the south and north of the existing 3H -13A
wellbore. The laterals will increase throughput and A -Sand recovery.
Prior to CTD operations slickline will conduct a dummy whipstock drift and obtain a static bottom hole pressure.
Service coil will mill the "D" nipple and conduct a fill cleanout.
Nabors CDR3-AC will run and set a whipstock at 7,338' MD. The whipstock will be utilized to cut a window in the
3-1/2" liner and drill four CTD laterals.
Pre -CTD Work
1. RU Slickline: Drift tubing with dummy whipstock and obtain SBHP.
2. RU Service Coil: Mill out "D" nipple and conduct fill cleanout.
3. Prep site for Nabors CDR3-AC.
Rig Work
1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test.
2. 3H-13AL1 Lateral (Al sand - south)
a. Set top of whipstock at 7,338' MD.
b. Mill 2.80" window at 7,338' MDQ,_
c. Drill 3" bi-center lateral to TD of 10,600' MD.
Run 2-3/8" slotted liner with aluminum billet from TD up to 7,750' MD.
3. 3H-13AL1-01 Lateral (A2/A3 sand - south)
a. Kickoff of the aluminum billet at 7,750' MD.
b. Drill 3" bi-center lateral to TD of 10,600' MD.
c. Run 2-3/8" slotted liner with aluminum billet from TD up to 7,430' MD.
4. 3H-13AL1-02 Lateral (Al sand - north)
a. Kickoff of the aluminum billet at 7,430' MD.
b. Drill 3" bi-center lateral to TD of 10,000' MD.
c. Run 2-3/8" slotted liner with aluminum billet from TD up to 7,650' MD.
5. 3H-13AL1-03 Lateral (A2/A3 sand - north)
a. Kickoff of the aluminum billet at 7,650' MD.
b. Drill 3" bi-center lateral to TD of 10,000' MD.
c. Run 2-3/8" slotted liner with deployment sleeve from TD up to 7,330' MD.
6. Freeze protect, ND ROPE, and RDMO Nabors CDR3-AC rig.
Post -Rig Work
1. Obtain SBHP and change out gas lift design.
2. Return well to production.
3H -13A Proposed CTD Schematic
at 110' MD
', 36# J-55
at 3072' MD
tcked at
MD (1997)
C -sand pens
7229-7249' MD
A -sand parts
7258'-7308' MD
7356'-7366' MD
7372'-7380' MD
3-1/2", 9.3#, L-80 liner
5808'-7755' MD
3-1/2" Cemoo DS -nipple at 502' MD (2.813" min ID)
3-1/2" 9.3# L-80 EUE 8rd Tubing to surface
3-1/2" Camco KBUG gas lift mandrels 2720', 4118', 8 5077' MD
3-1/2" Camco MMM gas lift mandrel 5757' MD
3-1/2" Camco D -nipple at 5803' MD (2.750" min ID)
Baker 3-1/7' GBH -22 seal assembly at 5812' MD (3" ID)
Liner too
Baker 5" x 7" ZXP liner top packer at 5808' MD
Baker 5" x 7" HMC liner hanger at 5822' MD
Baker SBE (12' length with 4" ID seal bore)
Landing collar at 7654' MD
Tight spot in 3-12"
liner 7268'-7313' MD
KOP at 7338' MD
Baker 3-1/2" XL
Monobore whipstock
3H-13AL1.03 wp03
TD @ 10,000' MD
Liner top at 7330' MD
3H-13AL1-02 wp02
TD @ 10,000MD
Liner Billet at 7650' MD
@ 10,600' MD
:r Billet @ 7430' MD
3H-13AL1 wp04
TD @ 10,600 MD
Liner Billet @ 7,750' MD
LGIG- a7
• • Zcp2-toi
WELL LOG TRANSMITTAL# DATA LOGGED
‘O/LJ201S
K.BENDER
To: Alaska Oil and Gas Conservation Comm. October 23, 2015
Attn.: Makana Bender
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
RECEIVED
OCT 2 8 2015
RE: Multi FingerCaliper, Jewelry RCBL, and Log: 3H 13A
AOGCC
Run Date: 9/13/2015
The technical data listed below is being submitted herewith. Please address any problems or
concerns to the attention of:
Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518
FRS_ANC@halliburton.com
3H-13A
Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom
50-103-20089-01
Radial Cement Bond Log 1 color log
50-103-20089-01 � -��''`'
SCANNED
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE
TRANSMITTAL LETTER TO THE ATTENTION OF:
Halliburton
Wireline & Perforating
Attn: Fanny Sari
6900 Arctic Blvd.
Anchorage, Alaska 99518
Office: 907-275-2605
Fax: 907-273-3535
FRS_ANC@halliburton.com
Date: Signed: m,..4,247"....,Gx)
ConocoPhillips
a~~
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
July 160i, 2010
Commissioner Dan Seamount
Alaska Oil & Gas Commission
333 West 70i Avenue, Suite 100
Anchorage, AK 99501
Commissioner Dan Seamount:
~2~C~IVED
JUL, 2 ~1 2Q1~1
~~SSka (k{ & Gat Gott. Cenxnission
a~tclmr~ge
3~N19aA
Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRT~. Each of
these wells was found to have a void in the conductor. These voids were filled with 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 corrosion inhibitor/sealant was pumped July 110i, 120', 130' 2010. The attached spreadsheet
presents the well name, top of cement depth prior to filling, and volumes used on each
conductor.
Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions.
Sincerely,
1
Perry Klein
ConocoPhillips Well Integrity Projects Supervisor
~~
ConocoPhillips Alaska Inc.
Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off
Report of Sundry Operations (10-404)
Kuparuk Field
Date 7/16/10 2T. 3H PAD
Well Name
API #
PTD #
Initial top o
cement
Vol. of cement
um ed
Final top of
cement
Cement top off
date
Corcosion
inhibitor Corrosion
inhibitor/
sealant date
ft bbls ft al
2T-22 50103202240000 1950860 8" n/a 8" n/a 3.8 7/12/2010
2T-23 50103202160000 1950320 8" n/a 8" n/a 2.1 7/12/2010
2T-27A 50103202170100 2090900 7" n/a 7" Na 1.7 7/12/2010
2T-32 50103202180000 1950490 36" n/a 36" n/a 11.9 7/12/2010
2T 37 50103202270000 1951010 22" n/a 22" n/a 2.5 7/11/2010
2T-38A 50103202290100 1972050 8" Na 8" Na 1.7 7/11/2010
2T-203 50103205200000 2051970 22" Na 22" Na 5.1 7/13/2010
2T-208 50103205180000 2051870 13" Na 15" Na 2.5 7/13!2010
2T-210 50103202730000 1982030 18" Na 18" Na 5.1 7/12/2010
2T-217A 50103203340100 2000740 8" n/a 8" Na 1.7 7/12/2010
3H-13A 50103200890100 1961970 SF Na 22" Na 3.8 7/11/2010
~ ~ ;~ .., a~.,..., ~ ~ ~.,,„.~~~
• STATE OF ALASKA •
;t~l~ "~ ; (~'~``~
s. '_x
ALASKA OIL AND GAS CONSERVATION COMMISSION ,_''_ ,, ,,~{;;;:,
REPORT OF SUNDRY WELL OPERATIONS
1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ~ Stimulate ^ Other ^
Alter Casing ^ Pull Tubing ^ Pertorate New Pool ~ Waiver ^ Time Extension ^
Change Approved Program ^ Operat. Shutdown^ Perforate ~ Re-enter Suspended Well ^
2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number.
ConocoPhillips Alaska, IIIC. Development 0 Exploratory ~ 196-197 /
3. Address: Stratigraphic ^ Service ^ 6. API Number:
P. O. Box 100360, Anchorage, Alaska 99510 50-103-20089-01 ~"
7. KB Elevation (ft): 9. Well Name and Number:
RKB 71' 3H-13A ~
8. Property Designation: 10. Field/Pool(s):
ADL 25531 / ~
Kuparuk Oii Field / Kuparuk River Oil Pool
11. Present Well Condition Summary:
Total Depth measured 7755' ~ feet
true verticai 6202'' feet Plugs (measured)
Effective Depth measured 7653' feet Junk (measured)
true vertical 6150' feet
Casing Length Size MD ND Burst Collapse
Structurai
CONDUCTOR 110' 16" 110' 110'
SURFACE 3001' 9-5/8" 3072' 2930'
PRODUCTION 5887' 7" 5958' 5163'
LINER 1947' 3-1/2" 7755' 6202'
/ g/
Perforation depth: Measured depth: 722g'-7249', 7258'-7308', 7356'-7366', 7372'-7380'
true vertical depth: 5926'-5936', 5941'-5968', 5993'-5998', 6001'-6005' .
' i~~€;
~. _,
r r
'-w~ ~, ~r W;~,~ ~:~ ~ ~" ~~~I.~C~
Tubing (size, grade, and measured depth) 3.5" , J-55 , 5836'
Packers & SSSV (type & measured depth) Baker'C-2 ZXP liner top pkr ~ 5a22'
Camco'DS' nipple @ 501'
12. Stimulation or cement squeeze summa ry:
Intervals treated (measured) not applicable
Treatment descriptions including volumes used and final pressure:
13. Representative Daily Average Production or Injection Data
Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure
Prior to well operation 100 533 404 -- 151
Subsequent to operation 101 706 360 -- 156
14. Attachments 15. Well Class after work:
Copies of Logs and Surveys run _ Exploratory ^ Development ~ Service ^
Daily Report of Well Operations _X 16. Well Status after work:
Oil^~ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^
17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt:
none
Contact John Peirce @ 26 5-6471
Printed Name John Peirce Title Wells Engineer
Signature / ~~//
~ Phone: 265-6471 Date q"1, ~"~9
a~l'K.
'` Pre ared b Sharon Alls Drake 263-4612
~ ,~~~~~~~~
"~ ~~~~ ~~~ ~ ~~ :~ ~, ~r~r~Y~
Form 10-404 Revised 04/2006 t~ ubmit Original Only
DATE SUMMARY
8/12/09 RIH & CLEAN I
3H-13A Well Work Summary
RAT
HOLE BELOW THE LOWER SET OF PERF 7308' MD.AVERAGE RETURN RATE OF
80% DURING CLEANING OPERATION USING SLICK-DIE AND DIE GEL & GAS LIFT
WITH A SMALL TRACE OF FILL IN RETURNS.RETURN WELL OVER TO DSO.JOB
COMPLETE.
8/15/09 TAGGED WITH 2" BAILER (a~ 7656' RKB. UNABLE TO PASS 7263' SLM WITH 23.5'
DUMMY GUNS. BROACHED TIGHT COLLARS @ 7263' & 7299' SLM TO 2.35": IN
PROGRESS.
8/16/09 BROACHED TBG TO 2.70" IN TIGHT SPOTS la~ 7267' & 7299' SLM. UNABLE TO DRIFT
23.5' x 2.5" DUMMY GUNS PAST 7275' SLM. DRIFTED TO 7500' SLM WITH 10' x 2.5"
DUMMY GUNS. READY FOR E/L.
8/25/09 PERFORATED INTERVALS: 7372- 38Q. 7356-7366 WITH 2.0" MILLENNIUM HMX, 6SPF,
DP, 60 DEG PHASING. LOG CORRELATED TO SLB PERFORATION RECORD 1/21/1997.
` _ _.,~ KU P
C~(KD~~~~jp~ I ~ Well Attnbutes
~ We1lEoreAPVUWI FieldName
Q'°~~~"~ ~~~`~ ~ 501032008901 KUPARUK
Canment iH:
_ _ we~Cqnig, 3N~J3a9~erzrn~azsu......i -SSSV~NIPPLE .
_ ._ Stl~cvnal AC'~i Annotation 'Depth(flKB) ~En
Last Taq: SLM I 7 656.0 I 8
niF
PAC
~~C
LINER
Tubin~
Tubing
TUBING
nci
4.
5,
5,
5,
5,
7.229 7.249
7.258 7,308
7,356 7,366
7,372 7,380
'DS' Nipple
Bottom of Seal Assy.
UNIT B,
NOTE: WELL SIDETR4CKED -
NOTE~ WAIVERED WELL: IA x
NOTE TIGHT SPOT tl- 7268' -
5,
1880 Comment
Y. w/ 10' siroke
3H-13A
ID ~TD
Act Bbn (flKB)
12 ~ 7.755.0
iRig Release Daf
1 , 1/9/1988
HSD Cavier
~ pH
9 PH
L
T
/./~S
lds
C!;:J - - - ---I"
fAtJ'LL LOG
TRANSMITTAL
)
11~ - /'17
ProActive Diagnostic Services, Inc.
To:
State of Alaska AOGCC
333 W. 7th Street
Suite 700
Anchorage. Alaska 99501
RE:
~istribution - Final Print(s)
The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of
this transmittal letter to the attention of :
Joey Burton / Jeni Thompson
ProActive Diagnostic Services, Inc.
P. O. Box 1389
Stafford, TX 77497
WELL
DATE
LOG
TYPE
DIGITAL
OR
CD-ROM
1
MYLAR /
SEPIA
FILM
1
BLUE LINE
PRINT(S)
REPORT
OR
BLUE LINE
Open Hole
1
Res. Eva!. CH
1
1
1
Mech. CH
KRU 3H-13a
4-9-04
Caliper Survey
1 Rpt or
2 Color
Signed~~¿ ¡J~
Print Name: ¡fe/e¡t} ~ W4RM~.()
Date:
/1 ¡J jr/¡ RECEIVED
APR 262004
Alaska Oil & Gas Cons. Commission
Anchorage
PRoACTivE DiAGNosTic SERviCES, INC., PO ßox 1 ~69 STAffoRd IX 77477
Phone:(281) 565-9085 Fax:(281) 565-1369
E-mail: pds@memorylog.com
Website: www.memorylog.com
SCANNED NO'! 0 8 2004
clr3s
1,6--/"
Memory Multi-Finger Caliper
Log Results Summary
Company:
Log Date:
Log No. :
Run No.:
Pipe1 Desc.:
Pipe1 Use:
ConocoPhillips Alaska, Inc.
April 9, 2004
5405
1
3.5" 9.3 lb. L-80
Tubing
Well:
Field:
State:
API No.:
Top Log IntvI1.:
Bot. Log IntvI1.:
3i:Þ13A
Kuparuk
Alaska
50-103-20089-01
Surface
5,841 Ft. (MD)
Inspection Type:
Corrosive & Mechanical Damage Inspection
COMMENTS:
This log is tied into the D Nipple @ 5,803' (Driller's Depth).
This log was run to assess the condition of the tubing with respect to corrosive and mechanical damage. The
3.5" tubing appears to be in good to fair condition. A 21 % wall penetration is recorded in joint 158. The
damage appears in the form of Isolated Pitting. The remainder and majority of the tubing appears to be in
good condition, with no other significant wall penetrations, areas of cross-sectional wall loss or I.D.
restrictions recorded.
The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Pages of this
report.
MAXIMUM RECORDED WALL PENETRATIONS:
Isolated Pitting
( 21%)
Jt.
158
@
4,912 Ft. (MD)
No other significant wall penetrations (>19%) are recorded throughout the tubing.
MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS:
No significant areas of cross-sectional wall loss (> 8%) are recorded throughout the tubing.
MAXIMUM RECORDED ID RESTRICTIONS:
No significant I.D. restrictions are recorded throughout the tubing.
RECEIVED
APR 26 2004
Alaska Oil & Gas Cons. Commission
Anchorage
I Field Engineer: R.A. Richey
Analyst: M. Lawrence
Witness: B. Gathman
ProActive Diagnostic Services, Inc. I P.O. Box 1369, Stafford, TX 77497
Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-maii: PDS@memorylog.com
Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: 659-2314
SCANNED NOV 0 5 2004
lclds.
Well:
Field:
Company:
Country:
3H-13A
Kuparuk
ConocoPhillips Alaska, Inc.
USA
I Tubing: Nom.OD
3.5 ins
Weight
9.3 ppf
Grade & Thread
l-BO
Penetration and Metal Loss (% wall)
- penetration body
200
metal loss body
150
~
.HI
0 0 to 1 to 1 0 to
1% 10% 20%
100
50
20 to 40 to over
40% 85% 85%
Number of joints analysed (total = 192)
pene. 0 93 98 1 0
loss 41 151 0 0 0
0
0
Damage Configuration ( body)
60
40
20
0
isolated
pitting
line ring
corrosion corrosion
hole / poss
¡ble hole
general
corrosion
Number of joints damaged (total = 60)
55 4 1 0
0
"!
PDS Report Overview
Body Region Analysis
- penetration body
0
1 -
~
=-
r-
Ë:
~
49 iI1!i!!L.
I
t
991
.-
I!!!!5æ=-
I
81:..
14911-
J-
E='"
IJ
~
....
Survey Date:
Tool Type:
Tool Size:
No. of Fingers:
Analyst:
Nom.lD
2.992 ins
GlM 1
GlM2
GlM3
GLM4
April 9, 2004
MFC 24 No. 99628
1.69
24
M. lawren ce
Nom. Upset
3.5 ins
Upper len. lower len.
1.2 ins 1.2 ins
Damage Profile (% wall)
mm metal loss body
50
100
Bottom of Survey = 186.6
Analysis Overview page 2
PDS REPORT JOINT TABULATION SHEET
Pipe: 3.5 in 9.3 ppf L-80 Well: 3 H-13A
Body Wall: 0.254 in Field: Kuparuk
Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc
Nomina! 1.0.: 2.992 in Country: USA
Survey Date: April 9, 2004
Joint Depth Pen. Pen. Pen. Meta! Min. I Damage Profile
No. (Ft.) Upset Body % Loss 1.0. Comments (% wall)
(Ins.) (Ins.) % (Ins.) 0 50 100
1 19 0 0.03 10 2 2.92 Lt. Deposits.
1.1 50 0 0.01 5 1 2.94 PUP
1.2 56 0 0.01 5 1 2.94 PUP
2 62 0 0.03 10 2 2.89 Lt. Deposits.
3 94 0 0.03 10 2 2.93 Lt. Deposits.
4 124 0 0.04 16 2 2.88 Shallow pitting.
5 153 0 0.03 12 1 2.91
6 184 0 0.03 10 2 2.91
7 216 0 0.03 13 2 2.90 Shallow pitting.
8 246 0 0.04 16 2 2.91 Shallow pitting.
9 277 0 0.03 11 2 2.91
10 309 0 0.05 19 4 2.90 Shallow pitting.
11 338 0 0.04 14 2 2.91 Shallow corrosion.
12 370 0 0.03 13 2 2.92 Shallow pitting.
13 402 0 0.03 13 2 2.90 Shallow pitting.
14 430 0 0.02 9 2 2.91
15 459 0 0.01 2 2 2.93
15.1 490 0 0 0 0 2.81 DS NIPPLE
16 491 0 0.03 13 4 2.91 Shallow pitting.
17 523 0 0.02 9 2 2.92
18 556 0 0.04 14 2 2.91 Shallow pitting.
19 588 0 0.03 11 2 2.90
20 616 0 0.03 10 2 2.90
21 648 0 0.03 12 2 2.91
22 677 0 0.03 10 2 2.93
23 709 0 0.03 11 1 2.91
24 739 0 0.03 13 3 2.92 Shaliow pitting.
25 770 0 0.02 9 2 2.92
26 802 0 0.03 10 2 2.91
27 833 0 0.02 9 2 2.91
28 863 0 0.02 8 2 2.93 ~
29 894 0 0.02 9 1 2.92
30 925 0 0.02 8 1 2.92 ~
31 956 0 0.03 10 2 2.90
32 984 0 0.02 9 1 2.90 fIB
33 1015 0 0.01 4 1 2.91 ~
34 1046 0 0.02 9 2 2.91
35 1076 0 0.02 9 2 2.91
36 1107 0 0.01 5 2 2.92
37 1138 0 0.02 9 2 2.93
38 1169 0 0.02 9 1 2.92
39 1200 0 0.02 9 2 2.91 ,
40 1231 0 0.03 12 1 2.91
41 1262 0 0.03 11 2 2.91
42 1293 0 0.03 10 2 2.92
43 1324 0 0.01 4 1 2.92
44 1354 0 0.01 5 3 2.91 ~
45 1386 0 0.01 5 1 2.91
46 1417 0 0.02 9 2 2.92 ,.
47 1449 0 0.03 10 2 2.92 ~
I Penetration Body
Meta! Loss Body
Page 1
PDS REPORT JOINT TABULATION SHEET
Pipe: 3.5 in 9.3 ppf L-80 Well: 311-BA
Body Wall: 0.254 in Field: Kuparuk
Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc.
Nominai I.D.: 2.992 in Country: USA
Survey Date: April 9, 2004
Joint Depth Pen. Pen. Pen. L Metal ¡ Min. Damage ProfHe L
No. (Ft.) Upset Body % Loss I.D. Comments (% wall)
(Ins.) (Ins.) % (Ins.) 50 100
48 1479 0 0.04 14 1 2.91 Shallow pitting.
49 1510 0 0.02 8 2 2.91
50 1541 0 0.02 9 2 2.90
51 1573 0 0.02 9 4 2.91
52 1604 0 0.01 4 2 2.90
53 1635 0 0.03 11 2 2.90
54 1666 0 0.02 9 2 2.89 Lt. Deposits.
55 1696 0 0.01 4 2 2.91
56 1728 0 0.03 10 2 2.90
57 1759 0 0.02 9 1 2.92
58 1791 0 0.03 11 2 2.90
59 1822 0 0.01 6 3 2.90 Lt. Deposits.
60 1853 0 0.01 4 2 2.88
61 1884 0 0.04 14 2 2.90 Shallow pitting.
62 1915 0 0.04 14 8 2.91 Shallow corrosion.
63 1947 0 0.04 14 2 2.91 Shallow pitting. Lt. Deposits.
64 1978 0 0.03 10 2 2.91
65 2010 0 0.02 9 2 2.90
66 2041 0 0.03 13 6 2.90 Shallow pitting.
67 2070 0 0.03 10 2 2.90
68 2100 0 0.03 10 2 2.89
69 2131 0 0.03 13 3 2.91 Shallow pitting.
70 2164 0 0.02 8 2 2.92
71 2194 0 0.03 10 2 2.90
72 2225 0 0.03 11 2 2.90
73 2254 0 0.03 11 1 2.90
74 2285 0 0.02 8 2 2.91
75 2316 0 0.02 9 1 2.92
76 2347 0 0.02 9 2 2.91
77 2377 0 0.03 11 2 2.B9
78 2407 0 0.02 9 2 2.90
79 2438 0 0.03 11 2 2.91
80 2469 0 0.03 13 3 2.90 Shallow pitting.
81 2500 0 0.03 13 2 2.92 Shallow pitting.
82 2531 0 0.04 14 2 2.91 Shallow pitting.
83 2562 0 0.03 13 2 2.90 Shallow pitting.
84 2593 0 0.02 9 3 2.91
85 2625 0 0.04 14 1 2.90 Shallow pitting.
86 2654 0 0.03 12 2 2.90 Shallow pitting. Lt. Deposits.
87 2685 0 0.03 11 2 2.91
87.1 2717 0 0 0 0 N/A GLM 1 (Latch @ 9:00)
88 2723 0 0.03 13 2 2.91 ShaliQw pitting.
89 2755 0 0.03 10 2 2.91
90 2786 0 0.03 13 2 2.91 Shallow pitting. Lt. Deposits.
91 2B17 0 0.02 9 3 2.91
92 2849 0 0.03 13 3 2.91 Shallow pitting.
93 2880 0 0.02 9 2 2.91
94 2910 0 0.03 10 2 2.91
95 2941 0 0.03 12 2 2.90
96 2973 0 0.03 11 1 2.92 Lt. Deposits.
I Penetration Body
Metal Loss Body
Page 2
PDS REPORT JOINT TABULATION SHEET
Pipe: 3.5 in 9.3 ppf L-80 Well: 3H-13A
Body Wall: 0.254 in Field: Kuparuk
Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc.
Nominal 1.0.: 2.992 in Country: USA
Survey Date: April 9, 2004
I Joint I Depth Pen. Pen. Pen. Metal Min. I Damage Profile I
No. (Ft.) Upset Body % Loss 1.0. Comments (% wall)
(Ins.) (Ins.) % (Ins.) 0 50 100
97 3004 0 0.03 11 2 2.88 Lt. Deposits.
98 3035 0 0.03 10 2 2.90 Lt. Deposits.
99 3065 0 0.03 13 3 2.90 Shallow pitting. Lt. Deposits.
100 3096 0 0.03 11 2 2.90
101 3128 0 0.03 10 1 2.90 Lt. Deposits.
102 3158 0 0.04 14 2 2.88 Shallow pitting. Lt. Deposits.
103 3189 0 0.03 11 2 2.88
104 3220 0 0.04 14 2 2.90 Shallow pitting. Lt. Deposits.
105 3251 0 0.03 12 2 2.90
106 3282 0 0.03 13 3 2.90 Shallow pitting. Lt. Deposits.
107 3313 0 0.02 9 1 2.91 Lt. Deposits.
108 3343 0 0.03 II 2 2.90 Lt. Deposits.
109 3374 0 0.04 17 8 2.89 Shallow corrosion.
110 3405 0 0.03 13 2 2.90 Shallow pitting.
111 3437 0 0.03 13 2 2.90 Shallow pitting. Lt. Deposits.
112 3467 0 0.03 13 1 2.88 Shallow pitting. Lt. Deposits.
113 3498 0 0.03 13 3 2.90 Shallow pitting.
114 3530 0 0.03 13 2 2.89 Shallow pitting. Lt. Deposits.
115 3559 0 0.03 13 2 2.90 Shailow pitting. Lt. Deposits.
116 3591 0 0.03 12 2 2.91
117 3620 0 0.03 13 2 2.90 Shallow pitting. Lt. Deposits.
118 3651 0 0.03 13 2 2.89 Shallow pitting. Lt. Deposits.
119 3681 0 0.04 16 2 2.91 Shallow pitting. Lt. Deposits.
120 3712 0 0.03 11 1 2.92
121 3743 0 0.02 9 2 2.91 Lt. Deposits.
122 3774 0 0.03 12 3 2.89 Lt. Deposits.
123 3806 0 0.03 11 2 2.91
124 3837 0 0.03 10 2 2.92
125 3867 0 0.03 11 2 2.91 Lt. Deposits.
126 3898 0 0.03 13 2 2.90 Shallow pitting.
127 3930 0 0.03 13 3 2.89 Shallow pitting. Lt. Deposits.
128 3962 0 0.02 9 1 2.89
129 3990 0 0.02 9. 3 2.91 ~
130 4021 0 0.03 12 2 2.91 Shallow pitting.
131 4053 0 0.03 12 3 2.91
132 4083 0 0.03 12 2 2.90 Lt. Deposits.
132.1 4114 0 0 0 0 N/A GLM 2 (Latch @ 9:00) ~
133 4121 0 0.02 9 2 2.90 Lt. Deposits.
134 4153 0 0.02 9 3 2.92
135 4184 0 0.03 11 1 2.91
136 4216 0 0.03 11 2 2.90
137 4246 0 0.03 10 2 2.89 Lt. Deposits.
138 4277 0 0.03 11 2 2.90
139 4309 0 0.03 13 4 2.90 Shallow pitting. Lt. Deposits.
140 4340 0 0.03 11 1 2.92
141 4372 0 0.03 10 2 2.91
142 4403 0 0.03 12 1 2.91 Lt. Deposits.
143 4433 0 0.04 17 3 2.89 Shallow pitting. Lt. Deposits.
144 4465 0 0.03 11 2 2.91 Lt. Deposits.
145 4496 0 0.02 9 1 2.91 ~
I Penetration Body
Metal Loss Body
Page 3
PDS REPORT JOINT TABULATION SHEET
Pipe: 3.5 in 9.3 ppf L-80 Well: 3H-13A
Body Wall: 0.254 in Field: Kuparuk
Upset Wall: 0.254 in Company: ConocoPhilfips Alaska, Inc
NominaII.D.: 2.992 in Country: USA
Survey Date: April 9, 2004
Joint Depth Pen. Pen. I Pen. Metal Min. Damage Profile I
No. (Ft.) Upset Body % Loss 1.0. Comments (% wall)
(Ins.) (Ins.) % (Ins.) 0 50 100
146 4527 0 0.02 9 2 2.92 Lt. Deposits. .'
147 4558 0 0.03 11 2 2.90 Lt. Deposits.
148 4589 0 0.03 10 2 2.90 Lt. Deposits.
149 4618 0 0.03 10 2 2.90 Lt. Deposits.
150 4650 0 0.04 15 2 2.91 Shallow pitting. Lt. Deposits.
151 4680 0 0.02 9 1 2.92
152 4710 0 0.03 11 3 2.90
153 4739 0 0.02 9 1 2.90 Lt. Deposits.
154 4769 0 0.03 13 1 2.91 Shallow pitting. Lt. Deposits.
155 4801 0 0.03 11 2 2.90 Lt. Deposits.
156 4831 0 0.03 10 5 2.91
157 4863 0 0.02 7 2 2.94
1.58 4894 0 0.05 21 1 2.90 Isolated pitting. Lt. Deposits.
159 4926 0 0.02 9 2 2.89 Lt Deposits.
160 4957 0 0.02 9 2 2.90 Lt. Deposits.
161 4988 0 0.02 9 2 2.89
162 5016 0 0.03 10 2 2.88
163 5047 0 0.02 8 1 2.91
164 5076 0 0.01 5 1 2.92 ~
164.1 5107 0 0 0 0 N/A GLM 3 (Latch @ 11 :00)
165 5114 0 0.04 14 2 2.90 Shallow pitting. Lt. Deposits.
166 5146 0 0.03 13 2 2.89 Shallow pitting.
167 5176 0 0.03 10 2 2.88
168 5206 0 0.03 13 1 2.88 Shallow pitting. Lt. Deposits.
169 5235 0 0.03 13 2 2.86 Shallow pitting. Lt. Deposits.
170 5267 0 0.03 11 3 2.86 Lt. Deposits.
171 5297 0 0.01 6 1 2.89
172 5326 0 0.02 9 2 2.91
173 5355 0 0.03 13 2 2.89 Line shallow corrosion. Lt Deposits.
174 5384 0 0.03 12 2 2.90 Shallow pitting.
175 5415 0 0.02 9 2 2.87 Lt. Deposits.
176 5444 0 0.04 17 2 2.85 Shallow pitting. Lt. Deposits.
177 5473 0 0.02 9 2 2.89 Lt Deposits.
178 5504 0 0.03 13 2 2.91 Shallow pitting.
179 5535 0 0.03 11 2 2.91
180 5565 0 0.03 10 1 2.92 Lt. Deposits.
181 5595 0 0.02 9 1 2.90
182 5627 0 0.01 6 1 2.92
183 5658 0 0.02 9 2 2.91 Lt Deposits.
184 5689 0 0.02 6 1 2.92
185 5720 0 0.03 13 1 2.92 Shallow pitting.
185.1 5752 0 0.03 13 2 2.87 PUP Shallow pitting.
185.2 5757 0 0 0 0 N/A GLM 4 (Latch @ 3:00)
185.3 5768 0 0.05 19 6 2.93 PUP Shallow corrosion. Lt Deposits.
186 5772 0 0.04 14 2 2.92 Shallow pitting.
186.1 5801 0 0 0 0 2.75 D NIPPLE
186.2 5804 0 0.04 15 0 2.86 PUP Shallow pitting. Lt. Deposits.
186.3 5811 0 0 0 0 3.00 SEAL ASSEMBLY
186.4 5819 0 0 0 0 3.00 PACKER
186.5 5828 0 0.02 7 2 2.93 PUP
I Penetration Body
Metal Loss Body
Page 4
Pipe:
Body Waif:
Upset Waif:
Nominal 1.0.:
Joint I Depth
No. (Ft.)
186.6
PDS REPORT JOINT TABULATION SHEET
3.5 in 9.3 ppf L-80
0.254 in
0.254 in
2.992 in
5837
Pen. Pen.
Upset Body
(Ins.) (Ins.)
0 0
Well:
Field:
Company:
Country:
Survey Date:
Pen. Meta! Min.
% loss 1.0.
% (Ins.)
0 NI A TUBING TAIL
0
Page 5
3H-BA
Kuparuk
ConocoPhillips Alaska, Inc.
USA
April 9, 2004
Comments
Damage Profile i
(% wall)
0 50 100
I I ¡ ¡ ill 1 I I
I. Penetration Bodv
.. . Metal loss Bodv
-----
£5.
PDS Report Cross Sections
Well:
Field:
Company:
Country:
Tubing:
3H-13A
Kuparuk
ConocoPhillips Alaska, Inc.
USA
3,5 ins 9.3 ppf L-80
Survey Date:
Tool Type:
Tool Size:
No. of Fingers:
Analyst:
April 9,2004
MFC 24 No. 99628
1.69
24
M. Lawrence
Cross Section for Joint 158 at depth 4912.46 ft
Tool speed = 44
NominallD = 2.992
Nominal 00 = 3.500
Remaining wall area = 99 %
Tool deviation = 40 0
Finger 1 5 Penetration = 0.054 ins
Isolated Pitting
0.05 ins = 21 % Wall Penetration
HIGH SIDE = UP
Cross Sections page 1
.':. .... ConocoPhillips Alaska, Inc.
13H-13A
API: 501032008901
¡ I SSSV Type: Nipple
NIP (501-502,
00:3.500)
TUBING
(0-5836,
OD:3.500,
ID:2.992)
Gas Lift
MandrelNalve
1
(2720-2721,
GasUft
MandrelNalve
2
(4118-4119,
Gas Lift
MandrelNalve
3
(5107-5108,
Gas Lift
MandrelNalve
4
(5757-5758,
NIP
(5803-5804,
OD:3.500)
SEAL
(5810-5811.,
OD:3.500)
PKR
(5822-5823,
OD:6.151)
HANGER
(5822-5825,
OD:5.875)
TlL
(5836-5837,
OD:3.500)
PROD.
CASING
(0-5958.
OD:7.000,
Wt:26.00)
Perf
(7229-7249)
Perf
(7258-7308)
u
J l
Well Type: PROD
Orig 1/6/1997
Completion:
Annular Fluid: LastW/O: 1/6/1997
Reference Log: Ref Log Date:
Last Tag: 7266' ELM I TD: 7755 ftKB
Last Tag Date: 1118/2003 Max Hole Angle: 59 deg @ 6974
Casing Sbing - ALL STRINGS (SIDETRACK WINDOW @ 5958' IN PRODUCTION CSG'
Description Size Top Bottom I TVD Wt
CONDUCTOR 16.000 0 110 110 62.50
SUR. CASING 9.625 0 3072 2930 36.00
PROD. CASING 7.000 0 5958 5163 26.00
LINER 3.500 5808 7755 7755 9.30
Tubing String - TUBING
Size I Top
3.500 0
Perforations Summary
Interval TVD
7229 - 7249 5927 - 5938
KRU
Bottom
5836
TVD
5071
Wt
9.30
7258 - 7308
5943 - 5969
Zone
C-4,UNIT
B
A-3,A-2
Status Ft SPF Date Type Comment
20 4 5/9/2002 RPERF 2.5" HSD, PJ DP Chgs, 60
deg ph
50 4 1/21/1997 IPERF 180 deg. phasing; 2 1/2"
HSD Carrier
Gas Lift MandrelsNalves
St MD TVD Man Man Type V Mfr V Type V OD latch Port TRO
Mfr
1 2720 2651 Cameo KBUG
2 4118 3744 Cameo KBUG
3 5107 4511 Cameo KBUG
4 5757 5011 Cameo MMM
Other (plugs, equip., etc.) - JEWELRY
Depth TVD Type
501 501 NIP
5803 5046 NIP
5810 5051 SEAL
5822 5060 PKR
5822 5060 HANGER
5836 5071 TTL
5958 5163 WINDOW
General Notes
Date Note
1/6/1997 WELL SIDETRACKED - ORIGINAL COMPLETION DATE 114/1988
1/20/2004 WAIVERED WELL: IA x OA COMMUNICATION
GLV
GLV
GLV
OV
1.0
1.0
1.0
1.5
Description
Cameo 'DS' Nipple
Cameo 'D' Nipple NO GO
Baker'GBH-22' SEAL ASSY. wi 10' stroke
Baker 'C-2 ZXP' Liner Top
Baker 'HMC' Liner Hanger
Bottom of Seal Assy.
SIDETRACK CASING WINDOW
3H-13A
Angle (ã) TS: 158 deg @ 7226
Angle @ TD: 58 deg @ 7755
Rev Reason: Waivered Well
Last Update: 1/29/2004
I
Grade Thread
H-40
J-55
J-55
L-80
I Grade I
J-55
Thread
EUE8RD
BK
BK
BK
RK
Date
Run
0.156 1303 12/13/1999
0.156 1298 12/13/1999
0.188 1325 12/13/1999
0.188 0 12/13/1999
Vlv
Cmnt
ID
2.812
2.750
3.000
3.000
4.375
2.992
2.992
11/26/03
Scblumbepgep
NO. 3053
Schlumberger Technology Corporation, by and through is Geoquest Division
3940 Arctic Blvd, Suite 300 Company: Alaska Oil & Gas Cons Comm
Anchorage, AK 99503-5711 Attn: Lisa Weepie
ATTN: Beth 333 West 7th Ave, Suite 100
Anchorage, AK 99501
Field: Kuparuk
{
Well Job # Log Description Date BL Color CD .
3H-13A . c,~ (0 -¡err PRODUCTION PROFILE 11/08/03 1
3A-09 ~S \ ... '~L\ PRODUCTION PROFILE 11/09/03 1
2K-24 <» c¡ ... I ~ SBHP SURVEY 11/10/03 1
2K-25 qn -t){:=2 SBHP SURVEY 11/10/03 1
10-12 . q9 ~ 08L) ['pLUG SET & SBHP SURVEY 09/11/03 1
,
(
"""""hnlon..-. --- ,--
Kt;l;t:IV't:.tJ
~ \' ~:--- i)EC 2 2 200."
SIGNED: "~ C"''\ '\. l J¥'\. .,.\..-::-J'~ ~^'~ DATE::11. "',' J
'-
Alaska 011 & Gas lNll:).~vmltl¡~Of~
Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Anchorage
Sl"/\\!Ñ\~~ÝW=¡í') (I f~ ¡;'II 0) 1m ~nnti
'.- ~¡1"'\)\\1D'\1¡ç;U>" dHil"ð (h IilJ LlHJ ij
~~~.,',~
~ ~~(\\'-.¿~
1. Operations performed:
2. Name of Operator
Phillips Alaska, lnc.
3. Address
P. O. Box 100360
Anchora~ le, AK 99510-0360 '
4. Location of well at surface
1177' FNL, 4999' FEL, Sec. 12, T12N, RSE, UM
At top of productive interval
1888' FSL, 499' FEL, Sec. 2, T12N, R8E, UM
At effective depth
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
Operation shutdown_ Plugging _ Perforate _X
Pull tubing _ Repair well _ Other _
6. Datum elevation (DF or KB feet)
RKB 71 feet
7. Unit or Property name
At total depth
3122' FNL, 330' FEL, Sec. 2, T12N, RSE, UM
12. Present well condition summary
Total depth: measured
true vertical
Stimulate _
Alter casing _
5. Type of Well:
Development __X
Exploratory __
Stratigraphic __
Service__
(asp's 498653, 60004 78)
(asp's 498041, 6003812)
Kuparuk Unit
8. Welt number
3H-13A
9. Permit number / approval number
196-197 /
10. APl number
50-103-20089-01
11. Field / Pool
Kuparuk Oil Pool
7755 feet
6202 feet
Plugs (measured)
Effective depth' measured 7276 feet
true vertical 5952 feet
Junk (measured)
Casing Length Size
CONDUCTOR 110' 16"
SUR. CASING 3001' 9-5/8"
PROD. CASING 5887' 7"
LINER 1947' 3-1/2"
LINER
Cemented
245 sx AS 1
1300 sx AS I!1,400 sx Class G, 70
300 sx Class G, 175 sx AS I
311 sx Class G
Measured Depth
110'
3072'
5958'
7755'
True vertical Depth
110'
2930'
5163'
6202'
Perforation depth:
measured 7229'- 7249', 7258'- 7308'
true vertical 5927' - 5938', 5943' - 5969'
(size, grade, and measured depth) 3-1/2", 9.3#, J-55 Tbg @ 5836' MD.
Packers & SSSV (type & measured depth) BAKER 'C-2 ZXP' LINER TOP @ 5822' MD.
CAMCO 'DS'@ 501' MD.
13. Stimulation or cement squeeze summary
Intervals treated (measured) N/A
Treatment description including volumes used and final pressure
14.
OiI-Bbl
160
160
Prior to well operation
Subsequent to operation 1043
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
Michael Mooney
RECEIVED
Form 10-404 Rev 06/15/88 ·
Representative Daily Average Production or Injection Data
Gas-Mcf Water-Bbl
85O 55O
Title: Wells Team Leader
Casing Pressure Tubing Pressure
- 100
608 - 1 O2
Suspended __ Service. _
QuestiOns? Cai~ Mike Mooney 263-4574
Prepared b~V Sharon Altsup-Drake 263-4612
CANNED JUN 2 20D2
SUBMIT IN DUPLICATE
Date
,,
05/03/02
05/09/02
3H-13A Event History
Comment
DRIFTED TBG & TAGGED FILL W/23.5' OF 2.60" DUMMY GUN @ 7276' RKB. [TAG]
PERFORATED C4 SAND INTERVAL 7229'- 7249', W/20' OF 2-1/2" HSD, 4 SPF, POWER JET DP
CHARGES, 60 DEG PHASING. NO WHTP CHANGE WHEN GUNS FIRED.[PERF]
Page I of 1
,~GANNED JUN P. z~~;~oo2
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
June 4, 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 3H-13A (196-197)
Dear Commissioner:
Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations :for the reccnt
perforation operations on the KRU well 3H-13A.
If there are any questions, please contact me at 263-4574.
Sincerely,
M. Mooney .~,~
Wells Team Leader
Phillips Drilling
MM/skad
RECEIVED
JUN 1 2 2002
Alaska 0it &, ~'' ,"~ .....
Gas (,~r,s, O~)mm~ss~o~',
Aneharage
JUN ~, 4 2002
PERMIT
AOGCC Individual Well
Geological Materials Inventory
DATA T'DATA PLUS
--.
96-197 MWD SRVY '~5894-7755
96-197 7970
96-197 SRVY CALC ~R~BH 5958-7755
Page: 1
Date: 01/21/99
RUN RECVD
04/09/97
04/30/97
06/20/97
lO-~O7 ~'~Pn~TIO~ O~T~ /1~11~
o~mnY wfnn o~s ~ /ll~:l{&/ TO //~1¢~
Are dry ditch samples required? yes ~.And received?
Was the well cored? yes ~_~_~Analysis & description received?
Are well tests required? yes '~!.Received?
Well is in compliance
Initial
COMMENTS
c:/ /,t ,)! '~ ?
ARCO Alaska, Inc.
Post Office Box 1
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
June 19,1997
Mr. David J. Johnston
Commissioner
State of Alaska
Alaska Oil & Gas Conservation Commission
3001 Porcupine Drive
Anchorage, Alaska 99501
Subject: 3H-13A (Permit No. 96-197) Well Completion Report
Dear Mr. Commissioner:
Enclosed is the well completion report to cover any changes made to the
completion during the recent operations to sidetrack KRU 3H-13. If there are
any questions, please call 263-4622.
Sincerely,
W. S. Isaacson
Drilling Engineer
Kuparuk Drill Site Development
WSI/skad
ORI61NAL
,.ii. jr,,! 2 0 19,9o7
4._/a.~_F,a' Oil ,& Gas Cons, '"' ,,
'' gnch0rag0
STATE OF ALASKA ' ~
ALAS,.A OIL AND GAS CONSERVATION ~ _~MMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
1. Status of Well ClassifiCatiOn of Service Well
[] Oil [] Gas [] Suspended [] Abandoned [] Service
2. Name of Operator 7. Permit Number
ARCO Alaska Inc. 96-197
i3. Address .............. 8. APl Number
P. O. Box 100360, Anchorage, Alaska 99510 50-103-20089-01
4. Location of well at surface 9. Unit or Lease Name
1182' FNL, 281' FWL, Sec. 12, T12N, RBE, UM ?~.~?~-~x.¥~.!. ,1¢1~,,~'~t¢1~.~ Kuparuk River Unit
Attop of productive interval ' ~ ..... ~'~'"; ~ ~ ' 10. Well Number
1888' FSL, 499' FEE, Sec. 2, T12N, R8E, UM { //?!~T~.,~.~, i '!~_ 3H-13A
At total depth ' i 'Z~Z~-'~-- ! ~ ~' 11~ Field a'nd POol .....
2147' FSL, 338' FEL, Sec. 2, T12N, R8E, UM
Kuparuk
River
5. Elevation in feet (indicate KB, DF, etc.) 16. Le~ase--Des~-gnation and Serial No.
RKB 71'I ADb 25531 ,ALK 2567
12. Date Spudded i13. DateT. D. Reached !14. Date Comp., Susp., or Aband.115. Water depth, ifoffshore ~16. No. of Completions
12/30/96 i 1/2/97! !1/21/97 N/A MSLI One
17. Total Depth (MD+T,VD) 'i'18. I51ug Back Depth (MD+TVD)]19. DirectiOnal SUrveYl20. Depth where sssv Set121. Thickness of Permafro'sl
7755' 6203 FT] 7653' 6150' FTl I~Yes E]Uo ! N/A MD[ 1465' (Approx.)
122. Type Electric or Other Logs Run
23. cAsiNG, LINER AND CEMENTING RECORD
,
CAsiNG '" SI~'I:TING DEPTH HOLI~ ..........
...... S_!.Z__E ...... W-[__._ PER FT. _. GRADE ToP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED
16" 62.5# H-40 Surf. 115' 24" 245 sx AS I
9-5/8" 36.0# J-55 Surf. 3072' 12.25" 1300 sx ASIII, 400 sx Class G
.......... , , ............. ~ ......... ........ T~-~-)-66-~-6-~-~-~S-i ............................................. i .................................................. ~_ _ ~ _ ·
7" 26.0# J-55 Surf. 5958' 8.5" 300 sx Class G & 175 sx AS I
..~
3.5" 9.3# L-80 5808' 7755' 311 sx Class G
24. P~rforations open to'production (MD+TVD of Top and B0~'tom 2~;. TUBING ........ RECORD
and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD)
3.5' 5836' 5822'
MD TVD MD TVD ..........................................................................................................................
7258'-7308' 5944'-5970'
4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
., .
DEpTH INTERVAL (MD) i AMOUNT & KIND OF MATERIAL USED
7258'-7308' pumped total of 1915 bbls fluids including
10090# 20/40, 228910# 12/18 and
13576# 10/14 proppant
'~:~. pRODuc~-'ioN TEsT ......................
Date First Productibn jMeth~J~! of"OPe'~atio~ (Flowing, ga~ lift, etC.) '"
1/27/97 i Gas Lift
Date of Test jHours Tested PRODUCTION FO~ OIL-BBb GAS-MCF WATER-BBb ~,'HOKI~-,~IZE ........ j-~.~---~-~.'-I~l-~:l:i~ .....................
5~27/97 j 20 TEST PERIOD ° 525 1051 451 176I~ 671
FiB-~/-Tu5ia~jcaB-ia~ P-~e~-¢a~ox~--cu~--xfEb---; ....... OiE:-B-~L ........ ~-:f~-a~ ................ w-~fai~:B-a-L ........ -oiE G-~,V,~;L-AF~-i~(-C~5~) ............................
Press. 14~ 862 ~24-Ho..uR RATE 485 852 376 25.1°
~9. ' ............ CORE 'DATA .............
Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips.
4laska Oil & ~;as O0r'~So O0mrniss.
Anchorage
Form 10-407 Rev. 07-01-80 Submit In Duplicate
Measured True Vertical Include interval tested, pressure data, all fluids recovered
Marker Name Depth Depth and gravity, GOR, and time of each phase.
Top Kuparuk C 7226'
Bottom Kuparuk C
Top Kuparuk A 7252'
Bottom Kuparuk A
Annulus left open - Freeze protected well with diesel.
~31. List of Attachments .......
Summary of Daily Drilling Reports, Surveys
32. I hereby certify that the foregoing is true and correct to the best of my knowledge
Signed L ~' ~- ~.- Title P~t,L't.-~ I~'~.~'1~{. Date (,~' Ici '9~
Prepared By Name/Number:
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 cementing and the location of
the cementing tool.
ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In,
Other-explain.
ITEM 28: If no cores taken, indicate 'none'.
Form 10-407 Rev. 07-01-$0
KUPARUK RIVER UNIT
WELL SERVICE REPORT
Kl(3H-13A(W4-6))
W~ I. JOB SCOPE JOB NUMBER
3H- 13A PERFORATE, PERF SUPPORT 0114971714.4
UNIT NUMBER
DATE
01/21/97
DAY
1
DAILY WORK
PERFORATE 2 1/2" HSD--4 SPF--BH CHGS--W/GUN GAMMA RAY
OPERATION COMPLEFE I SUCCESSFUL ] KEYPERSON
YES YES SWS-BAILEY
SUPERVISOR
JORDAN
0 PSI 1200 PSI 0 PSI 0 PSI 0 PSI 0 PSI
DAILY SUMMARY
] PERFORATED FROM 7258' TO 7308' WTH 2 1/2"HSD CARRIER GUNS AT4SPFWITHBHCHARGES. A3 & A2SANDS PERFORATED. [
SHOT W1TH 180 Dm. PHASING AND20 Dm. CCW ORIENTATION. USED PETROLINE ROLLERS SO ORIENTATION IS NOT GUARANTEED.
TIME LOG ENTRY
11:30 MIRU SWS #8337 W/BAILEY-LEVY-STAATS
13: 00 P/T TO 2500 PSI
13: 3 0 R1H W/GUN OR--20' HSD @ 1/2" CARRIER GUNS W/4SPF B.H. CHARGES.
14:15 TIED INTO SPERRY SUND DGR/EWR4 LOG DATED 2-JAN-97.
15:45 PERFORATE FROM 7288' TO 7308' AT 4 SPF, BH CHARGES. 820 PSI BEFORE PERFORATING AND 920 PSI AFTER SHOT.
17: 00 AT SFC---ARM GUN #2---RIH W/GUN-CCL
18:15 TIE-IN AND PERFORATE FROM 7268' TO 7288' AT 4 SPF, BH CHARGES. BEFORE PERFORATION PRESSURE WAS 1250
PSI AND DROPPED TO 920 PSI AFTER PERFORATING
19: 3 0 AT SFC---ARM GUN #3---RIH W/GUN-CCL
20:45 TIE-II AND PERFORATE FROM 7258' TO 7268' AT 4 SPF, BH CHARGES. BEFORE PERFORATING PRESSURE WAS 1250
PSI AND DROPPED TO 970 AFTER PERFORATING.
22:00 AT SFC---START R/D. FINAL TUBING PRESSURE WAS 1200 PSI.
23:00 FINISH R/D---LEAVE LOC.
Date: 2/11/97
ARCO ALASKA INC.
WELL SUMMARY REPORT
Page: 1
WELL:3H-13A RIG:NORDIC WI: 0% SECURITY:0
WELL ID: AK8701 TYPE:
AFC: AK8701 AFC EST/UL:$ 925M/ 1075M
STATE:ALASKA API NUMBER: 50-103-20089-01
AREA/CNTY: NORTH SLOPE WEST
FIELD: KUPARUK RIVER UNIT BLOCK:
SPUD:12/30/96 START COMP: FINAL:01/07/97
12/27/96 (D1)
TD: 6300' (6300)
SUPV:DLW
DAILY:$
12/28/96 (D2)
TD: 6300' (
SUPV: DLW
0)
DAILY:$
12/29/96 (D3)
TD: 5986' ( 0)
SUPV:DLW
DAILY: $
12/30/96 (D4)
TD: 5988' ( 2}
SUPV: DLW
DAILY: $
12/31/96 (D5)
TD: 6179' (191)
SUPV: DLW
DAILY:$
01/01/97 (D6)
TD: 7040' (861)
SUPV:DLW
DAILY:$
01/02/97 (D7)
TD: 7715' (675)
SUPV:DLW
DAILY:$
MW: 0.0 VISC' 0 PV/YP'
HOOK UP HARD LINES
Accept rig @ 0500 hrs. 12/27/96.
13,872 CUM:$ 13,872 ETD:$
O/ 0 APIWL: 0.0
0 EFC:$ 938,872
MW: 9.4 VISC: 45 PV/YP: 13/15 APIWL: 6.0
PULL TBG STAND IN DERRICK
N/D tree and N/U BOPE'and function test. Test BOPE and
manifold to 250/3500 psi, Hydril to 250/3000 psi. Pull
tubing and stand back in derrick.
38,151 CUM:$ 52,023 ETD:$ 0 EFC:$ 977,023
MW: 9.5 VISC: 45 PV/YP: 12/15 APIWL: 6.0
M/U WHIPSTOCK BHA
Continue to pull tubing and stand back in derrick. Test 7"
casing and P&A cement plug @ 6718' to 2500 psi for 15 min.
OK. Run and set 7" Baker N-1 bridge plug @ 5986' Test 7"
casing and 7" Baker bridge plug to 3500 psi for 30 min. OK.
48,494 CUM:$ 100,517 ETD:$ 0 EFC:$ 1,025,517
MW: 9.5 rISC: 80 PV/YP: 19/60 APIWL: 5.8
POOH W/WHIPSTOCK MILL
P/U kelly orient Whipstock to 21 degrees right of highside
of hole, tag bridge plug @ 5978' Nordic RKB. Set Whipstock.
Shear off Whipstock, start cut out @ 5957' Mill casing
from 5963' to 5988' FIT test w/9.5 ppg mud. Monitor well.
Well dead.
47,362 CUM:$ 147,879 ETD:$ 0 EFC:$ 1,072,879
MW: 9.4 VISC: 55 PV/YP: 12/21 APIWL: 7.0
DRILLING 6.125" @ 6179'
RIH with BHA %2. Circulate and orient MWD, slide through
window, ream open hole to 5988'. Directionally drill 6.125"
hole slide from 5988' to 6179'
89,613 CUM:$ 237,492 ETD:$ 0 EFC:$ 1,162,492
MW: 9.8 VISC: 43 PV/YP: 9/18 APIWL: 6.8
DRILLING AHEAD @ 7040'
Continue to directionally drill 6.125" hole from 6179' to
7040'
53,969 CUM:$ 291,461 ETD:$ 0 EFC:$ 1,216,461
MW: 11.9 VISC' 49 PV/YP: 19/20 APIWL: 4.5
DRILLING AHEAD @ 7715'
Continue directional drill 6.125" hole from 7040' to 7715'.
62,713 CUM:$ 354,174 ETD'$ 0 EFC'$ 1,279,174
Date: 2/11/97
ARCO ALASKA INC.
WELL SUMMARY REPORT
Page: 2
01/03/97 (D8)
TD: 7755' ( 40)
SUPV: DLW
DAILY:$
01/04/97 (D9)
TD: 7755'(
SUPV:DLW
0)
DAILY:$
01/05/97 (D10)
TD: 7755' ( 0)
SUPV:DLW
DAILY:$
01/06/97 (Dll)
TD: 7755' ( 0)
SUPV:DLW
DAILY:$
01/07/97 (D12)
TD: 7755' ( 0)
SUPV:DLW
DAILY:$
MW: 12.0 VISC: 48 PV/YP: 18/25 APIWL: 4.0
RUN 3.5" LINER
Continue drilling 6.125" hole from 7715' to 7755' TD. Run
3.5" liner.
51,073 CUM:$ 405,247 ETD:$ 0 EFC:$ 1,330,247
MW: 8.5 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0
MIX MUD FOR PARKER 245
Finish running in hole with 3.5" liner. Pump cement. CIP @
2009 hrs. 1/3/97.
105,421 CUM:$ 510,668 ETD:$ 0 EFC:$ 1,435,668
MW: 8.5 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0
MIX MUD FOR PARKER 245
Continue to mix 12.5 ppg mud for Parker 245.
0 CUM:$ 510,668 ETD:$ 0 EFC:$ 1,435,668
MW: 8.5 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0
SPACE OUT TBG HANGER R/U CIRC
R/U and re-run 3.5" tubing with jewelry.
30,222 CUM:$ 540,890 ETD:$ 0 EFC:$ 1,465,890
MW: 8.5 VlSC: 0 PV/YP: 0/ 0 APIWL: 0.0
RIG MOVE
Test 7" casing and 3.5" liner to 3500 psi for 30 min., OK.
Test tubing and annulus to 3500 psi for 15 min, OK. N/U
tree. Test tree. Move rig off hole. Release rig @ 2400 hrs.
1/6/96.
44,054 CUM:$ 584,944 ETD:$ 0 EFC:$ 1,509,944
End of WellSummary for Well:AK8701
SPF~Y-SUN DRILLING SERVICES
ANCHORAGE ALASKA
ARCO ALASKA INC
KUPARUK RIVER UNIT / 3H-13A ·
501032008901
NORTH SLOPE BOROUGH
COMPUTATION DATE: 3/24/97
DATE OF SURVEY: 122996
MWD SURVEY
JOB NUMBER: AK-MM-60212
KELLY BUSHING ELEV. = 70.39 FT.
OPERATOR: ARCO ALASKA INC
TRUE SUB-SEA
MEASD VERTICAL VERTICAL
DEPTH DEPTH DEPTH
COURS
INCLN
DG MN
COURSE DLS TOTAL
DIRECTION RECTANGULAR COORDINATES
DEGREES DG/100 NORTH/SOUTH EAST/WEST
VERT.
SECT.
5894.00 5120.61 5050.22 40 21 N 32.92 W .00 2018.91N 1137.25W
6113.56 5284.73 5214.34 43 11 N 18.23 W 4.63 2150.30N 1199.55W
6208.46 5353.90 5283.51 43 28 N 5.46 W 9.23 2213.76N 1212.85W
6303.77 5422.56 5352.17 44 33 N 6.50 E 8.79 2279.74N 1212.18W
6400.30 5488.67 5418.28 49 9 N 18.38 E 10.15 2348.20N 1196.79W
1208.57
1292.92
1341.86
1399.80
1467.08
6495.90 5548.00 5477.61 54 16 N 29.56 E 10.61 2416.45N 1166.17W
6591.68 5601.80 5531.41 57 22 N' 28.72 E 3.32 2485.66N 1127.60W
6687.28 5652.15 5581.75 59 5 N 31.86 E 3.32 2555.81N 1086.60W
6783.59 5701.71 5631.32 58 57 N 30.52 E 1.20 2626.44N 1043.84W
6879.18 5750.90 5680.51 59 5 N 30.11 E .40 2697.20N 1002.47W
1541.60
1620.82
1702.07
1784.58
1866.53'
6974.12 5799.49 5729.10 59 20 N 29.33 E .75 2768.04N 962.03W
7068.92 5848.16 5777.77 58 52 N 30.56 E 1.22 2838.52N 921.43W
7165.69 5899.13 5828.74 57 33 N 31.95 E 1.82 2908.83N 878.76W
7260.49 5949.76 5879.37 57 52 N 31.70 E .40 2976.93N 836.50W
7356.52 6000.39 5930.00 58 28 N 31.90 E .65 3046.28N 793.50W
1'948.09
2029.43
2111.62
2191.68
2273.19
7452.66 6050.47 5980.08 58 44 N 32.58 E .66 3115.69N 749.72W
7549.31 6100.45 6030.06 58 58 N 32.14 E .46 3185.57N 705.44W
7644.51 6149.96 6079.56 58 20 N 31.77 E .74 3254.56N 662.41W
7690.51 6174.08 6103.69 58 24 N 31.49 E .53 3287.91N 641.87W
7755.00 6207.87 6137.48 58 24 N 31.49 E .03 3334.75N 613.17W
2355.14
2437.73
2518.95
2558.08
2612.97
THE CALCULATION PROCEDURES ARE BASED ON THE USE OF
THREE-DIMENSION MINIMUM CURVATURE METHOD.
HORIZONTAL DISPLACEMENT = 3390.65 FEET
AT NORTH 10 DEG. 25 MIN. WEST AT MD = 7755
VERTICAL SECTION RELATIVE TO WELL HEAD
VERTICAL SECTION COMPUTED ALONG 29.17 DEG.
TIELIN SURVEY AT 5,894.00' MD
PROJECTED SURVEY AT 7,755.00' MD
ORIGINA['
RECE!VED
APR 0 9 1997
AjaAa Oil ~'' ,.,mi,,. Comrmssio~:
Anchorage
SP~
Y-SUN DRILLING SERVICES
ANCHORAGE ALASKA
PAGE 2
ARCO ALASKA INC
KUPARUK RIVER UNIT / 3H-13A
501032008901
NORTH SLOPE BOROUGH
COMPUTATION DATE: 3/24/97
DATE OF SURVEY: 122996
JOB NUMBER: AK-MM-60212
KELLY BUSHING ELEV. = 70.39 FT.
OPERATOR: ARCO ALASKA INC
INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH
TRUE SUB-SEA
MEASD VERTICAL VERTICAL
DEPTH DEPTH DEPTH
TOTAL
RECTANGULAR COORDINATES MD-TVD VERTICAL
NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION
5894.00
6894.00
7755.00
5120.61 5050.22
5758.51 5688.12
6207.87 6137.48
2018.91 N 1137.25 W 773.39
2708.20 N 996.09 W 1135.49 362.10
3334.75 N 613.17 W 1547.13 411.65
THE CALCULATION PROCEDURES ARE BASED ON THE USE OF
THREE-DIMENSION MINIMUM CURVATURE METHOD.
SP~.~~-· SUN DRILLING SERVICES
ANCHORAGE ALASKA
PAGE
ARCO ALASKA INC
KUPARUK RIVER UNIT / 3H-13A
501032008901
NORTH SLOPE BOROUGH
COMPUTATION DATE: 3/24/97
DATE OF SURVEY: 122996
JOB NUMBER: A_K-MM-60212
KELLY BUSHING ELEV. = 70.39 FT.
OPERATOR: ARCO ALASKA INC
INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH
TRUE SUB-SEA
MEASD VERTICAL VERTICAL
DEPTH DEPTH DEPTH
TOTAL
RECTANGULAR COORDINATES
NORTH/SOUTH EAST/WEST
MD-TVD VERTICAL
DIFFERENCE CORRECTION
5894.00 5120.61 5050.22 2018.91 N 1137.25 W 773.39
5959.64 5170.39 5100.00 2055.73 N 1159.01 W 789.25 15.86
6093.94 5270.39 5200.00 2137.63 N 1195.23 W 823.55 34.31
6231.21 5370.39 5300.00 2229.40 N 1213.91 W 860.82 37.27
6372.75 5470.39 5400.00 2328.48 N 1202.73 W 902.36 41.54
6534.84 5570.39 5500.00 2444.22 N 1150.54 W 964.45 62.09
6722.80 5670.39 5600.00 2581.69 N 1070.51 W 1052.41 87.95
6917.14 5770.39 5700.00 2725.38 N 986.14 W 1146.75 94.34
7111.91 5870.39 5800.00 2870.21 N 902.72 W 1241.52 94.78
7299.31 5970.39 5900.00 3004.91 N 819.21 W 1328.92 87.40
7491.05 6070.39 6000.00 3143.35 N 732.05 W 1420.66 91.74
7683.48 6170.39 6100.00 3282.80 N 644.99 W 1513.09 92.42
7755.00 6207.87 6137.48 3334.75 N 613.17 W 1547.13 34.05
THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN
THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS
i~][[1 i[i] [[[ [ [ [1[ ~ _ [[ [ [ [[11[[[[ 11 [[[[111[[ . [ [ [ [[
SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-82474 Sidetrack No.
[,
Page 1 of 1
Company rA_.R...C__Q .A_!~_S_.._K~_;.[.n_.c_: ............................ Rig Contractor & No..N__o_..r_d.!~_._W_e.!!._S_e_~!.?_e./_R_i~i.#_l! .............................................. Field ..K._u.[3_.a_r.,u_k__Ri_v_e_r_.?...n_.!t- .........................................
Well Name & No...P~d 3H[!.;~A ................................ survey Section Name _S.!.D_._E~.._~.A__C_K_.?_ ............................................ DUI Rep. _.K.!._R__T.__C__H._R/_S_.T_.E.N_~E_N ...................................
WELL DATA
Target TVD ............ 6_0.._2_6.:0..0_...!~t_) ................ Target Coord, N/S 305.0_:0_4 Slot Coord. N/S ...... -.1_1. .8. 2. _0~ ....... Grid Correction .......... _o.:_o..o_.0. ............ Depths Measured From: RKB Mt MSLI ! SSi
Target Description lO0'radius circle
Target Direction .................. ~_9.: 1_ _'_'_7_ .. _..(.d_ ~} .................
ii ii
Target Coord, E/W -780,07 Slot Coord, E/W 281,00 Magn. Declination
Build\Walk\DL per: lOOft[~ 30mL~j lOm[ij Vert. Sec. Azim, _ ...... 29:.1.7 ................. Magn. to Map Corr,
SURVEY DATA
I Total Coordinate
........................ I Survey Hole Course [Vertical
Date ..... Depth Direction Length TVD Section N(+)./S(-) E(+) / W(-)
............... (ft) (dd) .(fi) (fi) (fi) (fi)
5958.00 326.94 5163.87 1227.63 2052.84 -"1158.92
30~DEC;9(~-- '~ MWD 6113,56 341.77 155.56 ' 5279.95 1287.40 2146,06 -1203.30
31-DEC-96 6208.46 354.54 94.90 5349,12 1336,34 2209.53 -1216.59
31 -D EC-96 6303.77 6,50 95.31 5417.78 1394.28 2275.51 -1215.92
31 - DEC-96 6400.30 18.38 96.53 5483.89 1461.56
31 - D EC-96 6495.90 29.56 95.60 5543.22 1536,09
31 - D EC-96 6591.68 28.72 95.78 5597.02 1615.31
31 -DEC-96 6687.28 31.86 95.60 5647.36 1696.55
31 -DEC-96 6783.59
01-JAN-97 6879.18
01-JAN-97 6974.12
01-JAN-97 ~-~-- 7068.92
MWD 7549.31
.........................
MWD 7644.51
MWD 7690.51
02-JAN-97
02-JAN-97
02-JAN-97
02-JAN-97
--__
30.52 96.31 5696.93 1779.07
30,11 95,59 5746.12 1861.02
29.33 94,94 5794.71 1942,57
30,56 94,80 5843.39 2023,92
31,95 96.77 5894.36 2106.12
31,70 94.80 5944.99 2186,18
31,90 96,03 5995.62
32,58 96,14 6045.70
2267,69
2349.64
2432,23
2513,45
32.14 96,65 6095,68
31.77 95.20 6145,19
31.49 46.00 6169.31 2552,58
31.49 64.49 6203,10 2607,46
27,840
27,840
Build Rate
Build (+)
Drop (-)
Walk Rate
Right (+)
Left (-)
1,67 9,53
0.30 13.46
1,14 12,55
2343.98 -1200.54 4.77 12.31
2412,23 -1169,91 5,35 11,69
2481.43 -1131.34 3.24 -0.88
2551,58 -1090.34 1.80 3,28
2622.22 -1047.58 -0,13 -1.39
2692.97 -1006.21 0.15 -0.43
Calculation Method Minimum Curvature
Map North to: OTHER
2763.81 -965.77 0.25 -0,82
2834,30 -925,17 -0,50 1.30
2904.62 -882.50 -1.35 1.44
2972,72 -840,24 0.34 -0,26
3042,07 -797,24 0,62 0.21
3111,48 -753,46 0.27 0,71
3181.36 -709.18 0.25 -0,46
3250,35 -666.15 -0,66 -0,39
Tie In Point
3283,70 -645,61
3330,54 -616,91
Comment
0,11 -0,61
0,00 0,00
EXTRAPOLATED TO BIT
WELL LOG TRANSM1TFAL
To:
State of Alaska
Alaska Oil and Gas Conservation Comm.
Atm.: Loft Taylor
3 001 Porcupine Dr.
Anchorage, Alaska 99501
April30,1997
RE: MWD Formation Evaluation Logs DS 3H-13A, AK-MM-60212
The technical data listed below is being submitted herewith. Please address any problems or concerns
to the attention off
Ytrn Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, ~3, Anchorage, AK 99518
DS 3H-13A:
2" x 5" MD Resistivity & Gamma Ray Logs:
50-103-20089-01
2"x 5" TVD Resistivity & Gamma Ray Logs:
50-103-20089-01
1 Blueline
1 Folded Sepia
1 Blueline
1 Folded Sepia
,-.f'~'~. ~'"" ~;.-~-~ .; .... i.. .,,:-.--,, .U
5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (9.07) 563-3256 · Fax (907) 563-7252
A Dresser Industries, Inc, Company
WELL LOG TRANSMITTAL
To:
State of Alaska April 30, 1997
Alaska Oil and Gas Conservation Comm.
Atm.: Loft Taylor
3001 Porcupine Dr. \¼
Anchorage, Alaska 99501 0~ ~ ×
MWD Formation Evaluation Logs DS 3H-13A, AK-MM-60212
The technical data listed below is being submitted herewith. Please address any problems or concems
to the attention of.'
Jan Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518
1 LDWG formatted Disc with verification listing.
API#: 50-103-20089-01
5631 Silverado Way, Suite G · Anchorage, AJaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252
A Dresser Industries, Inc. Company
April 2, 1997
ARCO Alaska, Inc.
AOGCC, Lori Taylor
700 G Street
Anchorage, AK 99501
Re: MWD Survey 3H-13A
Dear Sir/Madam,
Enclosed is one hard copy of the above mentioned file(s).
Well 3H-13A
Tie in point 5,894.00' to interpolated depth at 7,755.00'
Please call me at 563-3256 if you have any questions or concerns.
Regards,
William T. Allen
Operations Support Engineer
Attachments.
REGE
APR 0 9 1991
An~,g~e
5631 Siiverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252
A Dresser Industries, Inc. Company
TONY KNOWLE$, GOVERNOR
ALASKA OIL AND GAS
CONSERVATION COMMISSION
3001 PORCUPINE DRIVE
ANCHORAGE, ALASKA 99501-3192
PHONE: (907) 279-1433
FAX: (907) 276-7542
December 19, 1996
Michael Zanghi, Drill Site Develop. Supv.
ARCO Alaska, Inc.
P O Box 100360
Anchorage, AK 99510-0360
Re;
Kuparuk River Unit 3H-13A
ARCO Alaska, Inc.
Permit No. 96-197
Sur. Loc. 1182'FNL. 281'FWL, Sec. 12, TI2N. R8E. UM
Btmnholc Loc. 2156'FSL, 350'FEL, Sec. 02, TI2N, R8E. UM
Dear Mr. Zanghi:
Enclosed is thc approvcd application for permit to rcdrill thc above refcrcnccd well.
The permit to rcdrill docs not cxcmpt you from obtaining additional permits required by law from
other govenm~ental agencies, and docs not authorize conducting drilling operations until all other
required pem~itting determinations arc made.
Blowout prevention equipment (BOPE) must bc tested in accordance with 20 AAC 25 035.
Sufficient notice (approximately 24 hours) must be given to allow a representative of the
Contrnission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by
,, tor on thc North Slope pager at 659-3607.
Da{ '_~w. J°hn~f0n ~ ~
Chairl%tll~~~
BY ORDER OF THE COMMISSION
dlf/Enclosures
CC~
Dcpartmcnt of Fish &Gamc, Habitat Section w/o cncl.
Dcpartmcnt of Environmental Conservation w/o cncl.
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
20 AAC 25.005
la. Type of Work Drill Redrill X i b Type of Well Exploratory [--] Stratigraphic Test [] Development Oil X
Re-Entry ri Deepen BI Service r'] Development Gas [~ Single Zone X Multiple Zone D
2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool
ARCO Alaska, Inc. RKB 71', Pad 39' feet Kuparuk River Field
3. Address 6. Property Designation Kuparuk River Oil Pool
P. O. Box 100360, Anchoracje, AK 99510-0360 ADL 25531, ALK 2657
4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025)
1182' FNL, 281' FWL, Sec. 12, T12N, R8E, UM Kuparuk River Unit Statewide
At top of productive interval (@ TARGET) 8. Well number Number
1888' FSL, 499' FEL, Sec. 02, T12N, R8E, UM 3H-13A #U-630610
At total depth 9. Approximate spud date Amount
2156' FSL, 350' FEL, Sec. 02, T12N, R8E, UM 12/25/96 $200,000
12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD)
property line 3H-14 7755' MD
3392' @ Tar~let feet 25' @ surface feet 2560 6226' TVD feet
16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2))
Kickoff depth 5961 ' feet Maximum hole angle 56.8° Maximum surface 2960 psig At total depth (TVD) 3625 psig
18. Casing program Setting Depth
size Specifications Top Bottom Quantity of cement
Hole Casing Weight Grade Coupling Length MD TVD MD -FVD (include stage data)
6-1/8' 3-1/2' 9.3# L-80 BTC-moc 1944' 5811' 5051' 7755' 6226' 364sxs Class G
19. To be completed for Redrill, Re-entry, and Deepen Operations.
Present well condition summary ~- ~.~
Total depth: measured 7370 feet Plugs (measured) ~! ~. ,('.~ '~ 0
true vertical 6269 feet
Alaska Oil & G~.s Cons. Comm[ssion
Effective depth: measured 7255 feet Junk (measured) Anchcrag0
true vertica 6179 feet
Casing Length Size Cemented Measured depth True Vertical depth
Structural
Conductor 8 O' 1 6" 245 Sx AS I I 15' 1 1 5'
Surface 3031' 9-5/8" 1300 sx ASIII, 400 sx Class G 3072' 2930'
Intermediate
Production 7301' 7" 100 sx 50/50 Poz, 200 sx Class G 7342' 6247'
Liner
Perforation depth: measured 6935'-6959', 6968'-6978', 6985'-7007', 7020'-7040' MD
true vertical 5927'-5946', 5953'-5961' 5966'-5984', 5994'-6010' TVD
20. Attachments Filing fee X Property plat BI BOPSketch X Diverter Sketch r-] Drilling program X
Drilling fluid program X Time vs depth plot [] Refraction analysis r'[ Seabed report [-[ 20 AAC 25.050 requirements X
21. I hereby certifY that ia f°r-eg°in/is true and c°rrect t° the best of mY kn°wledge~,/~ {/~r,~
Signed ~, ,,. Title Drill Site Develop. Supv. Date
Commission Use Only
Perl~Z~,~,~, 7 ,-APl ri, tUbber i date Isle cover letter for
15 e.,'/oj -.:z o o ? ? - o / other requirements
Conditions of approval Samples required r'l Yes ~ No Mud Iog required [--I Yes .,~ No
Hydrogen sulfide measures ~ Yes r'-I No Directional survey required ,~ Yes [] No
nequired working pressure for BOPE [--! 2M r"l 3M D 5M ~ 1OM D 15M
Other: ~ ~,...~1~
by order of
Approved by Commissioner the commission Date
Fnrm 1()-4C11 R~.v 7-P4-R.q ,Chlhmit in lrinlinnt~.
REDRILL PLAN SUMMARY
Well 3H-13A
Type of well (producer/injector):
Surface Location'
Target Location-
Bottom Hole Location:
MD:
TVD:
Rig:
Estimated Start Date:
Operation Days to Complete:
Producer
1182' FNL, 281' FWL, SEC 12, T12N, R8E, UM
1888' FSL, 499' FEL, SEC 02, T12N, R8E, UM
2156' FSL, 350' FEL, SEC 02, T12N, RSE, UM
7755'
6226'
Nordic Rig 2
12-25-96
13
Drill Fluids Program:
Density
PV
YP
Viscosity
Initial Gel
10 Minute Gel
APl Filtrate
pH
% Solids
Milling Window
in 7" casing
9.5
>25
15-35
85-95
20-30
30-40
8.5-9.5
Kick off to
weight up
9.5-9.6
5-15
5-8
30-40
2-4
4-8
8-10
9.5-10
4-7%
Weight up
to TD
11.9
10-18
8-12
35-50
2-4
4-8
4-5 through Kuparuk
9.5-10
<12%
Drilling Fluid System:
Swaco Geolograph Adjustable Linear Shaker
Brandt SMC-10 Mud Cleaner
Triflow 600 vacuum Degasser, Poor Boy Degasser
Pit Volume Totalizer (Visual and Audio Alarm)
Trip Tank
Fluid Flow Sensor
Fluid Agitators and Jetting Guns
Notes:
Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033.
Page 1
Casing/Tubing
Hole size
6-1/8"
Program:
Csg/'rbg
3-1/2", 9.3#, L-80, BTC-Mod
Tubing
3-1/2", 9.3~, J-55, EUE
Length Top (MD/'rVD) Btm (MD/TVD
1944' 5811'/5051' 7755'/6226'
5782' 29'/29' 5811 '/5051'
Cement Calculations:
Casino to be cemented:
--
3-1/2" in 6-1/8" open hole
Volume = 349 sxs of class G Blend @ 1.19 cu ft/sx
Based on: Shoe volume, open hole volume + 47%, & 150' liner lap.
Well Control:
Well control equipment consisting of 5000 psi working pressure pipe rams, blind rams, and annular
preventer will be installed.
Maximum anticipated surface pressure is estimated at 2,960 psi and is calculated using a gas column to
surface. The expected leak-off at the section cut in the 7" casing is estimated at 14.5 ppg EMW. With
an expected formation pressure in the Kuparuk of 3625 psi and a gas gradient of 0.11 psi/ft, this shows
that formation breakdown would not occur before a surface pressure of 2,960 psi could be reached.
Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3500 psi. See attached BOPE
schematic.
Drilling Hazards:
Lost Circulation:
Overpressured Intervals:
Other Hazards:
Directional:
KOP:
Max hole angle:
Close approach:
The suspect lost circulation zones throughout the Kuparuk field are the K-
10 and the K-5 intervals. The sidetrack 3H-13A, will kick off out of the 7"
casing below both the K-10 and K-5 intervals. The 7" casing has good
quality cement up to and above the planned kick-off window, which
should isolate the K-10 and K-5 from the sidetrack operations. If the
Formation Integrity Test shows that the K-10 and K-5 intervals are not
isolated and will not hold the desired equivalent mud weight, a cement
squeeze at the window could be performed to help isolate these
intervals. Off-set drilling data shows that wells in the area of 3H-13A
have been drilled to TD with 11.7 ppg mud and no loses.
The kick-off point in 3H-13A is below any zones which would be of
pressure concem prior to weighting up for the Kuparuk interval.
None
5961' MD / 5166' TVD
56.8° (in sidetrack portion)
No Hazards
Page 2
Logging Program-
Open Hole Logs: GR/Resistivity
Cased Hole Logs: GR/CCL
Notes:
All drill solids generated from the 3H-13A sidetrack will be hauled to CC-2A in Prudhoe Bay for grind and
inject. Incidental fluids developed from ddlling operations will be hauled to the nearest permitted
disposal well or to Parker 245 to be disposed by annular pumping into the permitted annulus Parker is
connected to at that time. The permitted well will be within the Kuparuk River Unit.
Page 3
KRU 3H-13A
GENERAL SIDETRACK PROCEDURE
PRE-RIG WORK:
.
RU CTU. RIH with inflatable cement retainer on CTU. Set inflatable in 3-1/2" tubing tail just below
production packer. Mix cement. Circulate the cement down coil to immediately above circulating
valve on top of retainer. Close circulation valve and down-squeeze cement below retainer into
perfs. Use sufficient volume to fill 7" casing from top of fill to retainer in tubing tail. Unsting and
circulate well clean on top of inflatable retainer. RDMO CTU.
2. RU slickline unit. RIH and dummy off all GLMs, leave deepest GLM open.
WORKOVER RIG WORK:
1. MIRU Nordic Rig. Lay hard-line to tree.
2. Verify well is dead. Load pits w/water. Circulate well to water.
3. Pressure test wellbore to 2500 psi testing cement squeeze and retainer, to ensure isolation from
perforations. Set BPV.
4. ND tree. NU and test BOPE.
5. Screw in landing joint. POOH standing back tubing and laying down all jewelry.
6. RU E-line unit. Run gauge ring through bridge plug setting depth. RIH and set permanent bridge
plug at 5986' MD-RKB.
7. MU and RIH with bottom trip whipstock and window milling assembly. Tag bridge plug and set
down weight to set whipstock. Shear free with milling assembly, circulate well to milling fluid, and
mill window in 7" casing. POOH LD milling assembly.
8. RIH w/6-1/8" bit, mud motor, MWD / LWD, and steerable drilling assembly. Slide out window,
kick-off well, and directionally drill to total depth as per directional plan. Short trip to window in
casing. POOH.
9. Run 3-1/2" liner to TD w/150' of ovedap to top of milled window.
10. Cement liner. Set liner hanger and liner top packer. POOH w/DP.
11. Pressure test casing and liner lap to 3500 psi for state test.
12. RIH w/completion assembly and sting into polished bore receptacle at top of liner. Space out.
Displace well to sea water at max rate. Test tubing and annulus.
13. ND BOPE. NU and test tree. Freeze protect well with diesel. RDMO Nordic.
14. Clean out well to PBTD w/coiled tubing. Perforate through tubing.
Lower Limit: 11 days
Expected Case: 13 days
Upper Limit: 20 days
No problems milling window, drilling new hole, or running completion.
Difficulties encountered milling window, or drilling new hole.
WSI 12/18/96
Page 4
ARCO ALASKA, Inc
Structure; Pad 3H Well : 13A
Field : Kuparuk River Unit Location : North Slope,
Creoted by jones For:
[ ~ot, ¢oued: ,7-D~c-Se [
] ~ordinotes are in f~t ~e
I ~~ I
29.17 De AZIMUTH
2:301' (TS TARGET)
***PJane of Proposole**
5000-
5100
5200
5300
54O0
5500
5600
5700
5800
5900
6000-
6100
6200
6300
6400
KOP / TIE-IN POINT
40.44 TVD=5166 TMD=5961 DEP=1229
41.18
45.47
DLS: 9.00 deg per 100 ft
47.09
<- West (feet)
1650 1500 1350 1200 1050 900 750 600 4-50
I I I I I I I I I I I I I I I I
3450
3500
TO LOCATION:
2156' FSL, 350' FEL
SEC. 2, T12N, RSE
Bose Kup Sands
TARGET LOCATION: /
1888' FSL, 499' FEL TARGET - T/ Unit A3
SEC. 2, T12N, RSE 3H-13A Rvsd 29-Aug-96\ Top Unit C
TARGET
TVD = 602 6
TMD=738g
OEP=2301 /K-1 Morker
NORTH 3070
WEST 780
/B~s, HRZ
'
C
C30
P / Tie-In Point
3150
3000
2850 I
Z
0
2700 ~--~
2550 ~+~
2400
2250
2100
1950
C-30 1VD=5446 TMD=6345 DEP=1434
51.74
EOC TVD=5536 TMD=5494 DEP=1552
SURFACE LOCATION;
1182' FNL, 281' FWL
SEC. 12, T12N, RSE
B/ HRZ TVD=5791 TMD=6960 DEP=1941
K-1 MARKER '[VD=5901 TMD=7161 DEP=2109
T/UNIT C TVD=5999 TMD=7340 DEP=2259
TARGET - T/ UNIT A3
TVI)=6026 TMD=7389 DEP=2301
B/ KUP SNDS TVD=6117 TMD=7555 DEP=2440
TD TVD=6226 TMD=7755 OEP=2607 ''~''''
AVERAGE ANGLE
56.82 DEG
i i i i i i i i i i i i i i i i i i i i i i i I i i i i I I i i i
1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800
Vertical Section (feet) ->
Azimuth 29.17 with reference 0.00 N, 0.00 E from slot #13A
7-1/16" 5000 PS! BOP STACK
ACCUMULATOR CAPACITY TEST
ANNULAR
PREVENTER
7
6 PIPE RAM
1
5 BLIND RAM~
I
MUD
CROSS
4
3 PIPE RAM
',
I
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 8TACK 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 5 MINUTES.
INCREASE PRESSURE TO 3500 PSI AND HOLD FOR 5 MINUTES.
BLEED TO ZERO PSI.
5. OPEN ANNULAR PREVENTOR AND INSIDE MANUAL KILL AND CHOKE LINE
VALVES. CLOSE TOP PiPE RAMS, HCR VALVE ON CHOKE LINE, AND
OUTSIDE MANUAL VALVE ON KILL LINE.
6. TEST TO 250 PSI AND 3500 PSI AS IN STEP 4.
7. CONTINUE TESTING AL VALVES, lINES, AND CHOKES WITH A 250 PSI LOW
AND 3500 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY
CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE.
$. OPEN TOP PIPE RAMS AND CLOSE BO3-1'OM PIPE RAMS. TEST BOTTOM
RAMS TO 250 PSI AND 3500 PSI.
9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE.
10. CLOSE BLIND RAMS AND TEST TO 3500 PSI FOR 5 MINUTES. BLEED TO
ZERO PSI.
11. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD
AND MNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE
DRILUNG POSITION.
12. TEST STANDPIPE VALVES TO 3500 PSI.
13. TEST KELLY COCKS AND INSIDE BOP TO 3500 PSI WITH KOOMEY PUMP.
14. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM.
SIGN AND SEND TO DRILLING SUPERVISOR.
15. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY
OPERATE BOPE DAILY.
1.11" - 3000 PSI CASING HEAD
2.11" - 3000 PSI x 7-1/16" 5000 PSI TUBING HEAD
3.7-1/16" - 5000PSI SINGLE GATE W/PIPE RAMS
4.7-1/16" - 5000 PSI DRLG SPOOL W/CHOKE & KILL LINES
5.7-1/16" - 5000 PSI SINGLE GATE W/ BLIND RAMS
6. 7-1/16" - 5000 PSI SINGLE GATE W/PIPE RAMS
7.7-1/16" - 5000 PSI ANNULAR PREVENTER
NORDIC RIG 92
LEVEL 1
12'-4'
--
z
12'-¢" -,
73'-0' , i~ 25'-0'
~'11RE~ 40-57
n*' STAIRS -
g rosco F-SOO (~
o TRIPLEX MUD .
n, PUMP .I
EMSCO F-800
TRIPLEX MUD
PUMP SPIRAL
STAIRS -
,s.-~ '!-
R~UOVABt. E
BOP ENCLOSURE
NORDIC RIG
LEVEL
1NORDIC RIG
LEVEL
]DRILLING
I UN~
ISPOOL
L"~
WATER TANK
/GLYCOL TANK
LISTER AIR HEATER
HYDRAULIC
MUD TANK
75O BBLS
24,.-o'
123'-.-0'
SPIRAL
STAIRS
· 15'-6"
RAI~P
7'-1
CHOKE:
I~ANIFOLD
DOGHOUSE OFFICE
STATE OF ALASKA
AL. ,._,,.,LA OIL AND GAS CONSERVATION COMM,._.o, ON
APPLICATION FOR SUNDRY APPROVALS
1. Type of Request: Abandon Suspend
Alter casing _ Repair well _
Change approved program_
Operation Shutdown__ Re-enter suspended well_
Plugging X~ Time extension Stimulate
Pull tubing_ Variance _ Perforate _ Other
Plugback for
Sidetrack
2. Name of Operator
Alaska Inc.
3. Address
P. O. Box 100360, Anchorage, AK 99510
5. Type of Well:
Development X
Exploratory _
Stratigraphic _
Service
--
4. Location of well at surface
1182' FNL, 281' FWL, Sec. 12, T12N, R8E, UM
At top of productive interval
1361' FSL, 1235' FEL, Sec 2, T12N, RSE, UM
At effective depth
At total depth
1571' FSL, 1404' FEL, Sec. 2, T12N, R8E. UM
6. Datum elevation (DF or KB)
RKB 76' feet
7. Unit or Property name
.Kuparuk River Unit
8. Well number
3H-13
9. Permit number
10. APl number
50-~ 03-20089
11. Field/Pool Kupurak River Field/
Kuparuk River Oil Pool
12. Present well condition summary
Total Depth: measured
(approx) true vertical
7370'
6269'
feet Plugs (measured)
feet
Effective depth:
Casing
Structural
Conductor
Surface
Intermediate
Production
Liner
Perforation depth:
measured.
(approx) true vertical
Length
80'
3031'
7301'
measured
6935'-6959',
7255' feet
61 79' feet
Size
16"
9-5/8"
11
Junk (measured)
None
true vertical
5927'-5946',
Tubing (size, grade, and measured depth)
3.5", J-55 tubing with tail @ 6847'
Cemented
Measured depth True vertical depth
245 sx AS i 115' 115'
1300 sx ASlll 3072' 2930'
400 sx Class G
300 sx Class G 7342' 6247'
175 sx AS I
6968'-6978', 6985'-7007', 7020'-7040'
5953'-5961', 5966'-5984', 5994'-6010'
RECEIVED
0;3 1996
Packers and SSSV (type and measured depth)
Baker FHL @ 6777' MD; Camco TRDP-1A SSSV @ 1801'
13. Attachments Description summary of proposal
Contact William Isaacson at 263-4622 with questions.
14. Estimated date for commencing operation
1~-07-96
16. If proposal was verbally approved
Detailed operation program__
Name of approver Date approved
17. I hereby certify ~at the fCregoing is true and correct to the best of my knowledge.
ned ~' ~L'/'/~..,. Title Drill Site Development Supv Date
FOR COMMISSION USE ONLY
Conditions of appro mmission so representative may witness
Alaska 0il & Gas Cons. Commission
BOP sketch
J15. Status of well classification as:
Oil X Gas __
Service
Suspended __
Plug integrity ~ BOP Test ~ Location Clearance __
Mechanical Integrity Test_ Subsequent form reqUire 10-1//O7'
Original Sign~ ~',
the order of the Commission [~.a, Vi~ W. Johnston Commissioner
IAp~o~a.I
Form 10-403 Rev 06/15/88
SUBMIT INq'RIPLICATE
'Approved Copy
~etu,.Ened ...... ..~!~
WELL PERMIT CHECKLIST COMPANY
FIELD & POOL
'ADMINISTR/~TION
INIT CLASS /~,~.Z.,,"
WELL NAME ,/~"A¢;'~/ X~-/X~ PROGRAM: exp [] dev, e,~ redrll~rv r-I wellbore seg [] ann. disposal para req []
GEOLAREA ~-"~ UNIT# ///~'~::3 ON/OFF SHORE o,,,t.2 _
ENGINEERING
1. Permit fee attached ....................... N
2. Lease number appropriate ...................
N
3. Unique well name and number ................. N
4. Well located in a defined pool ................. N
5. Well located proper distance from dflg unit boundary .....
N
6. Well located proper distance from other wells ......... N
7. Sufficient acreage available in drilling unit. .......... i' YIN
8. If deviated, is wellbore pl~t included .............. N
9. Operator only Affected party ................... N
10. Operator has appropriate bond in force ............
N
11. Permit can be issued wilbout conservation order ...... N
12. Permit can be issued without admini~e approval ....
13. Can permit be approved before 15-day waiL ........
REMARKS
~GEOLOGY
14. Conductor string provided ................... Y N
15. Surface ca~ng protects a/I known USDWs .......... Y N
16. CMT vol adequate to circu~.te on conductor & surf cscj .... Y N '"1
17. CMT vol adequate to tieqn long string to surf c...sg ....... Y N
/
18. CMT will c:~ver all known productive horizons ........ .(~N
19. Casing designs adequste for C, T, B & permaJTost. ..... ~N
20. Adequate tankage or reserve pit. ..............
21. Ifare<lrill, hasalO-403forabndnmntbeenappmved... (~.N
22. Adequate wellbore separa~on proposed ............
23. If divertmr required, is it adequate ................
24. Drilling fluid program scherr~tic & equip list adequate .... (..~N
25. BOPEs adequate .......................
26. BOPE press rating adequate; test to '~-'~ ~ psig.(~N
27. Choke manifold complies w/APl RP-53 (May 84) ...... ~ '~ V'"'
28. Work will occur without operation shutdown ......... .,4,~ N
29. Is presence of H2S gas probable ..............
30. Permit ~ be issued w/o hydrogen sulfide measures ..... Y ~'"",,,
_/2
31. DAta. presented on potenti=l overpressure zones ....... yN /~,/, 7"'/!
32_ Seismic analysis of shallow gas zones ............ //Y N
34. Contain name/phone for weekJy progress repo~ .. ...... Y N
le. XplOmtory antyJ
GEOLOGY: ENGINEERING: COMMISSION:
RP .¢~-, BEW SWJ
JDH ~ JDN~
TAB~F"~---~~
Comments/Instructions:
Well HistorY File
APPENDIX
Information of detailed nature that is not
particularly germane to the Well Permitting Process
but is part of the history file.
To improve the readability of the Well History file and to
simplify finding information, information of this
nature is accumulated at the end of the file under APPENDIX.
No special effort has been made to chronologically
organize this category of information.
Sperry-Sun Drilling Services
LIS Scan Utility
Wed Apr 23 11:22:06 1997
Reel Header
Service name ............. LISTPE
Date ..................... 97/04/23
Origin ................... STS
Reel Name ................ UNKNOWN
Continuation Number ...... 01
Previous Reel Name ....... UNKNOWN
Comments ................. STS LIS Writing
Services
Tape Header
Service name ............. LISTPE
Date ..................... 97/04/23
Origin ................... STS
Tape Name ................ UNKNOWN
Continuation Number ...... 01
Previous Tape Name ....... UNKNOWN
Comments ................. STS LIS Writing
Services
Library.
Library.
Scientific Technical
Scientific Technical
Physical EOF
Comment Record
TAPE HEADER
KUPARUK RIVER UNIT
MWD/MAD LOGS
WELL NAME:
API NUMBER:
OPERATOR:
LOGGING COMPANY:
TAPE CREATION DATE:
JOB DATA
JOB NUMBER:
LOGGING ENGINEER:
OPERATOR WITNESS:
SURFACE LOCATION
SECTION:
TOWNSHIP:
RANGE:
FNL:
FSL:
FEL:
FWL:
ELEVATION (FT
KELLY BUSHING:
DERRICK FLOOR:
GROUND LEVEL:
WELL CASING RECORD
1ST STRING
MWD RUN 2
AK-M~-60212
P. SMITH
D. WESTER
FROM MSL 0)
3H-13A
501032008901
ARCO ALASKA, INC.
SPERRY-SUN DRILLING SERVICES
23-APR-97
2
12N
08E
1182
281
70.40
68.90
38.80
OPEN HOLE CASING DRILLERS
BIT SIZE (IN) SIZE (IN) DEPTH (FT)
2ND STRING
3RD STRING ~
PRODUCTION STRING
REMARKS:
7.000 5957.0
6.125 7755.0
1. ]ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE
NOTED.
2. ANNULAR HYDRAULICS ARE CALCULATED USING THE POWER
LAW MODEL.
3. I~TD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED.
4. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMPtA RAY (DGR)
AND ELECTROMAGNETIC
WAVE RESISTIVITY PHASE-4 (EWR4).
5. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS
PER THE PHONE
CONVERSATION BETWEEN ALI TURKER OF SPERRY-SUN DRILLING
SERVICES AND
BILL ISAACSON OF ARCO ALASKA, INC ON MARCH 12, 1997.
6. THIS WELL REACHED A TOTAL DEPTH (TD) OF 7755'MD,
6203'TVD.
SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING.
SGRC = SMOOTHED GAMMA RAY COMBNINED.
SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA
SHALLOW SPACING).
SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY
(SHALLOW SPACING).
SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM
SPACING).
SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP
SPACING).
SFXE = SMOOTHED FORMATION EXPOSURE TIME.
$
File Header
Service name ............. STSLIB.001
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 97/04/23
Maximum Physical Record..65535
File Type ................ LO
Previous File Name ....... STSLIB.000
Comment Record
FILE HEADER
FILE NUMBER: 1
EDITED MERGED MWD
Depth shifted and clipped curves; all bit runs merged.
.5000
DEPTH INCREMENT:
FILE SUMMARY
PBU TOOL CODE
GR
FET
RPD
RPM
RPS
RPX
ROP
$
STA~RT DEPTH
5937.0
5944 0
5944 0
5944 0
5944 0
5944 0
5990 0
BASELINE CURVE FOR SHIFTS:
CURVE SHIFT DATA (MEASURED DEPTH)
BASELINE DEPTH
$
STOP DEPTH
7703.0
7710.5
7710.5
7710.5
7710.5
7710.5
7754.5
EQUIVALENT UNSHIFTED DEPTH
MERGED DATA~SOURdE
PBU TOOL CODE
MWD
$
REI¢~RK S:
BIT RUN NO MERGE TOP MERGE BASE
2 5990.0 7755.0
MERGED MAIN PASS.
$
Data Format Specification Record
Data Record Type .................. 0
Data Specification Block Type ..... 0
Logging Direction ................. Down
Optical log depth units ........... Feet
Data Reference Point .............. Undefined
Frame Spacing ..................... 60 .liN
Max frames per record ............. Undefined
Absent value ...................... -999.25
Depth Units .......................
Datum Specification Block sub-type...0
Name Service Order Units Size Nsam Rep
DEPT FT 4 1 68
GR MWD AAPI 4 1 68
RPM MWD OHMM 4 1 68
ROP MWD FT/H 4 1 68
RPX MWD Oh74M 4 1 68
RPS MWD OHMM 4 1 68
RPD MWD Oh74M 4 1 68
FET MWD HOUR 4 1 68
Code Offset Channel
0 1
4 2
8 3
12 4
16 5
20 6
24 7
28 8
Name Min Max Mean Nsam
DEPT 5937 7754.5 6845.75 3636
GR 38.4703 522.008 126.57 3533
RPM 0.0759 2000 21.4345 3534
ROP 9.8022 366.68 60.79 3530
RPX 0.0764 2000 7.06949 3534
RPS 0.0733 2000 8.40256 3534
RPD 0.05 2000 12.9666 3534
FET 0.7134 3.272 1.42287 3446
First
Reading
5937
5937
5944
5990
5944
5944
5944
5988
Last
Reading
7754.5
7703
7710.5
7754.5
7710.5
7710.5
7710.5
7710.5
First Reading For Entire File .......... 5937
Last Reading For Entire File ........... 7754.5
File Trailer
Service name ............. STSLIB.001
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 97/04/23
Maximum Physical Record..65535
File Type ................ LO
Next File Name ........... STSLIB.002
Physical EOF
File Header
Service name ............. STSLIB.002
Service Sub Level Na~e...
Version Number ........... 1.0.0
Date of Generation ....... 97/04/23
Maximum Physical Record..65535
File Type ................ LO
Previous File Name ....... STSLIB.001
Comment Record
FILE H~ADER
FILE NUMBER: 2
RAW MWD
Curves and log header data for each bit run in separate files.
BIT RUN NUMBER: 2
DEPTH INCREMENT: .5 0 0 0
FILE SUMMARY
VENDOR TOOL CODE START DEPTH
GR
FET
RPD
RPM
RPS
RPX
ROP
$
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
5937.0
5944 0
5944 0
5944 0
5944 0
5944 0
5990 0
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME):
TD DRILLER (FT):
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT):
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
MINIMUM ANGLE:
MAXIMUM ANGLE:
STOP DEPTH
7703 0
7710 5
7710 5
7710 5
7710 5
7710 5
7754.5
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE
DGR DUAL GAMMA RAY
EWR4 ELECTROMAG. RESIS. 4
$
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT):
BOREHOLE CONDITIONS MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S):
MUD PH:
MUD CHLORIDES (PPM) :
FLUID LOSS (C3) :
RESISTIVITY (OHMS4) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TERMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
NEUTRON TOOL
02-JAN-96
ISC 4.88
SP4 5.01 / DEPII 2.17F
MEMORY
7755.0
5990.0
7755.0
40.8
59.6
TOOL NUMBER
P0621SP4
P0621SP4
6.130
6.1
LSND
12.00
49.0
9.5
8OO
3.9
2.000
2.000
1.600
2. 000
146.0
F~TRIX:
~ATRIX DENSITY:
HOLE CORRECTION
(IN):
TOOL STANDOFF (IN) :
EWR FREQUENCY (HZ):
REF~RKS:
$
Data Format Specification Record
Data Record Type .................. 0
Data Specification Block Type ..... 0
Logging Direction ................. Down
Optical log depth units ........... Feet
Data Reference Point .............. Undefined
Frame Spacing ..................... 60 .liN
Max frames per record ............. Undefined
Absent value ...................... -999.25
Depth Units .......................
Datum Specification Block sub-type...0
.0
Name Service Order Units Size Nsam Rep
DEFT FT 4 1 68
GR MWD 2 AAPI 4 1 68
RPX MWD 2 OHMM 4 1 68
RPS MWD 2 OHMM 4 1 68
RPM MWD 2 OHMM 4 1 68
RPD MWD 2 OHMM 4 1 68
ROP MWD 2 FT/H 4 1 68
FET MWD 2 HOUR 4 1 68
Code Offset Channel
0 1
4 2
8 3
12 4
16 5
20 6
24 7
28 8
Name Min Max Mean Nsam
DEFT 5937 7754.5 6845.75 3636
GR 38.4703 522.008 126.57 3533
RPX 0.0764 2000 7.06949 3534
RPS 0.0733 2000 8.40256 3534
RPM 0.0759 2000 21.4345 3534
RPD 0.05 2000 12.9666 3534
ROP 9.8022 366.68 60.79 3530
FET 0.7134 3.272 1.42287 3446
First
Reading
5937
5937
5944
5944
5944
5944
5990
5988
Last
Reading
7754.5
7703
7710.5
7710.5
7710.5
7710.5
7754.5
7710.5
First Reading For Entire File .......... 5937
Last Reading For Entire File ........... 7754.5
File Trailer
Service name ............. STSLIB.002
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 97/04/23
Maximum Physical Record..65535
File Type ................ LO
Next File Name ........... STSLIB.003
Physical EOF
Tape Trailer
Service name ............. LISTPE
Date ..................... 97/04/23
Origin ................... STS
Tape Name ................ UNKNOWN
Continuation Number ...... 01
Next Tape Name ........... UNKNOWN
Comments ................. STS LIS Writing
Services
Reel Trailer
Service name ............. LISTPE
Date ..................... 97/04/23
Origin ................... STS
Reel Name ................ UNKNOWN
Continuation Number ...... 01
Next Reel Name ........... UNKNOWN
Comments ................. STS LIS Writing
Services
Library.
Library.
Scientific
Scientific
Technical
Technical
Physical EOF
Physical EOF
End Of LIS File
