Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout195-101Originated: Delivered to:7-Mar-25
Halliburton Alaska Oil and Gas Conservation Comm.
Wireline & Perforating Attn.: Natural Resource Technician
Attn: Fanny Haroun 333 West 7th Avenue, Suite 100
6900 Arctic Blvd.Anchorage, Alaska 99501
Anchorage, Alaska 99518
Office: 907-275-2605
FRS_ANC@halliburton.com
The technical data listed below is being submitted herewith. Please address any problems or
concerns to the attention of the sender above
WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#
1 2N-310 50-103-20549-00 909873379 Kuparuk River 3-Phases Saturation Analysis Field & Processed 27-Feb-25 0 1
2 2T-37 50-103-20227-00 909890550 Kuparuk River Multi Finger Caliper Field & Processed 25-Feb-25 0 1
3 2W-01 50-029-21273-00 9097400015 Kuparuk River Multi Finger Caliper Field- Final 1-Feb-25 0 1
4 3C-10A 50-029-21356-01 909890673 Kuparuk River Packer Setting Record Field- Final 4-Mar-25 0 1
5 3M-22 50-029-21740-00 909747918 Kuparuk River Leak Detect Log with ACX Field & Processed 8-Dec-24 0 1
6
7
8
9
10
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:
207-090
195-101
185-010
213-083
187-067
T40197
T40198
T40199
T40200
T40201
3/7/2025 Gavin Gluyas
Digitally signed by Gavin
Gluyas
Date: 2025.03.07
10:31:59 -09'00'
2T-37 50-103-20227-00 909890550 Kuparuk River Multi Finger Caliper Field & Processed 25-Feb-25 0 1
0 090
195-101
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By Samantha Carlisle at 8:48 am, Mar 30, 2021
Digitally signed by Roger Mouser
DN: O=Conocophillips, CN=Roger
Mouser, E=N1927@conocophilllips.com
Reason: I am the author of this document
Location: your signing location here
Date: 2021.03.27 06:40:14-08'00'
Foxit PhantomPDF Version: 10.1.0
Roger
Mouser
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1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown
Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program
Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well SC Repair
ConocoPhillips Alaska, Inc.Development Exploratory
3. Address:Stratigraphic Service 6. API Number:
7. Property Designation (Lease Number):8. Well Name and Number:
9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s):
11. Present Well Condition Summary:
Total Depth measured 11080'feet feet
true vertical 6070'feet feet
Effective Depth measured 10984'feet 10597'feet
true vertical 6006'feet 5763'feet
Perforation depth Measured depth 10675'-10720' feet
True Vertical depth 5811'-5840' feet
Tubing (size, grade, measured and true vertical depth)3.5" L-80 10625' 5780'
Packers and SSSV (type, measured and true vertical depth) Baker SAB-3 packer/Camco DS landing nipple PKR 10597', SSsV 505'PKR 5763', SSSV 505'
12. Stimulation or cement squeeze summary:N/A
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure:N/A
13.
Prior to well operation:
Subsequent to operation:
15. Well Class after work:
Daily Report of Well Operations Exploratory Development Service Stratigraphic
Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL
Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG
Sundry Number or N/A if C.O. Exempt:
Contact Name:
Authorized Title:
Contact Email:
10/26/2020 Contact Phone:
320-247
Authorized Name:
Authorized Signature with date:
Senior Engineer:Senior Res. Engineer:
14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283
WINJ WAG
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Roger Mouser / Roger Winter
n1927@conocophillips.com
659-7506
Well Integrity Field Supervisor
NA NA NA NA NA
NA NA NA NA NA
N/A
Representative Daily Average Production or Injection Data
Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure
Liner
Production 11035'7"11074'6066'
Conductor 80'16"121'121'
Intermediate
Surface 4104'9 5/8"5145'2890'
Packer measured
true vertical
Casing Length Size MD TVD
N/A Kuparuk River Field/ Kuparuk Oil Pool
Plugs measured
Junk measured
Burst Collapse
195-101
50-103-20227-00-00
ADL0025568, ADL0025569 KRU 2T-37
P.O. Box 100630, Anchorage, Alaska 99508
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
2. Operator Name 4. Well Class Before Work:5. Permit to Drill Number:
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AAC 25
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Form 10-404 Revised 3/2020 Submit Within 30 days of Operations
By Samantha Carlisle at 8:28 am, Oct 26, 2020
Digitally signed by Roger Winter
DN: CN=Roger Winter, E=n1927@conocophillips.com, C=US
Reason: I am the author of this document
Location: your signing location here
Date: 2020-10-26 07:40:39
Foxit PhantomPDF Version: 10.0.0
Roger Winter
DSR-10/27/2020 SFD 10/26/2020RBDMS HEW 11/2/2020
VTL 11/03/20
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
26th day of October, 2020
Commissioner Jessie Chmielowski
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, AK 99501
Commissioner Chmielowski,
Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for surface casing repair KRU
2T-37 (PTD 195-101).
Please contact Roger Mouser or myself at 659-7506 if you have any questions.
Sincerely,
Roger Winter
Well Integrity Field Supervisor
ConocoPhillips Alaska, Inc.
Digitally signed by Roger Winter
DN: CN=Roger Winter,
E=n1927@conocophillips.com, C=US
Reason: I am the author of this document
Location: your signing location here
Date: 2020-10-26 07:39:51
Foxit PhantomPDF Version: 10.0.0
Roger Winter
Date Event Summary
Executive
Summary SC Repair
08/02/20 Confirm leak area in SC - drill & tap - verify no other leaks.
10/19/20 Repair SC w/X65 .375" x 22" sleeve.
10/20'20 Mitoa to 1800 psi passed.
Originated:Delivered to:19-Aug-20
Halliburton Alaska Oil and Gas Conservation Comm.
Wireline & Perforating Attn.: Natural Resource Technician
Attn: Fanny Sari 333 West 7th Avenue, Suite 100
6900 Arctic Blvd.Anchorage, Alaska 99501
Anchorage, Alaska 99518
Office: 907-275-2605
FRS_ANC@halliburton.com
The technical data listed below is being submitted herewith. Please address any problems or
concerns to the attention of the sender above
WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #Digital #
1 Leak Detect Log
2 Plug Setting Record
3 2L-310 50-103-20616-00 906449149 Tarn Packer Setting Record Field-Final 13-Apr-20 0 1
4 2T-37 50-103-20227-00 906480199 Kuparuk Plug Setting Record Field-Final 30-Apr-20 0 1
5 3A-08 50-029-21445-00 906499970 Kuparuk Plug Setting Record Field-Final 17-May-20 0 1
6 Multi Finger Caliper Field-Processed 26-May-20
7 Packer Setting Record Field-Final 27-May-20
8 3H-14B 50-103-20092-02 906486722 Kuparuk Packer Setting Record Field-Final 7-May-20 0 1
9 3K-03 50-029-21602-00 906531280 Kuparuk Plug Setting Record Field-Final 29-May-20 0 1
10 3A-08 50-029-21445-00 906499689 Kuparuk Multi Finger Caliper Field-Processed 16-May-20 0 1
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:
Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518
FRS_ANC@halliburton.com
Date:Signed:
1
3H-03 50-103-20085-00 n/a Kuparuk 0 1
Transmittal Date:
2H-09 50-103-20050-00 906426492 Kuparuk Field-Final 5-Apr-20 0
08/26/2020 Abby Bell
Received by the AOGCC 08/26/2020
PTD: 1951010
E-Set: 33689
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Digitally signed by Roger Mouser
DN: O=Conocophillips, CN=Roger Mouser,
E=N1927@conocophilllips.com
Reason: I am the author of this document
Location: your signing location here
Date: 2020-06-08 16:12:51
Foxit PhantomPDF Version: 9.7.0
Roger Mouser
By Samantha Carlisle at 4:57 pm, Jun 08, 2020
320-247
X
Photo document all steps in repair
DSR-6/8/2020
10-404
SFD 6/9/2020VTL 6/15/20"
6/16/2020
dts 6/16/2020 JLC 6/16/2020
RBDMS HEW 6/18/2020
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Digitally signed by Roger Mouser
DN: O=Conocophillips, CN=Roger
Mouser, E=N1927@conocophilllips.com
Reason: I am the author of this
document
Location: your signing location here
Date: 2020-06-08 16:11:26
Foxit PhantomPDF Version: 9.7.0
Roger
Mouser
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Photo document
Photo document
Last Tag
Annotation Depth (ftKB) End Date Last Mod By Wellbore
Last Tag: RKB (Est. 15' of Fill, Leaving 5' of Open Perfs) 7/6/2018 zembaej 2T-37
Last Rev Reason
Annotation End Date Last Mod By Wellbore
Rev Reason: Set RBP, Pull OV, circ out 4/30/2020 famaj 2T-37
Casing Strings
Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB)
Set Depth (TVD)
(ftKB)
Wt/Len
(lb/ft) Grade Top Thread Wellbore
CONDUCTOR 16 15.06 41.0 121.0 121.0 62.58 H-40 WELDED 2T-37
SURFACE 9 5/8 8.83 41.4 4,145.3 2,889.7 40.00 L-80 BTC 2T-37
PRODUCTION 7 6.28 38.7 11,073.6 6,065.9 26.00 L-80 BTC-MOD 2T-37
L1-01 LATERAL 2 3/8 1.99 10,619.9 14,777.0 5,879.6 4.60 L-80 STL 2T-37L1-01
L1 LATERAL 2 3/8 1.99 10,704.8 10,768.0 5,870.0 4.60 L-80 STL 2T-37
L1 LATERAL 2 3/8 1.99 10,704.8 13,012.0 5,893.8 4.60 L-80 STL 2T-37L1
Tubing Strings
Des
String
Max
Nominal
OD (in)ID (in) Top (ftKB)
Set Depth
(ftKB)
Set Depth (TVD)
(ftKB) Wt (lb/ft) Grade Top Thread Wellbore
TUBING 3 1/2 2.99 36.6 10,625.6 5,780.3 9.30 L-80 ABM-EUE 2T-37
Completion Details
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des Com
Nominal
ID (in) Wellbore
36.6 36.6 0.00 HANGER FMC GEN IN TUBING HANGER 3.500 2T-37
505.0 504.8 1.61 NIPPLE CAMCO DS LANDING NIPPLE, 2.856" NO GO 2.812 2T-37
10,588.3 5,757.4 52.54 NIPPLE CAMCO W-1 SELECTIVE LANDING NIPPLE 2.812 2T-37
10,596.4 5,762.4 52.36 ANCHOR K ANCHOR, RUN WITH PACKER 2.992 2T-37
10,597.3 5,762.9 52.34 PACKER BAKER SAB-3 PERMANENT PACKER (SEAL ATTACHED) 3.250 2T-37
10,613.4 5,772.8 51.99 NIPPLE CAMCO D LANDING NIPPLE, 2.795" NO GO ( MILLED OUT TO
2.80")
2.800 2T-37
10,624.7 5,779.8 51.74 SOS BAKER SHEAR OUT SUB, ELMD TTL @ 10620' during SWS
PERF on 09/26/95
3.015 2T-37
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top (ftKB)
Top (TVD)
(ftKB) Top Incl (°) Des Com Run Date ID (in) Wellbore
9,720.0 5,296.1 63.06 Catcher 3.5" AVA Catcher. OAl 34". 4/30/2020 0.000 2T-37
9,723.0 5,297.5 63.03 RBP 2.72" P2P Packer CPP35200 w/ Equalizing
valve CPEQ35031 and 2' Debris Extension.
OAL 7' Max OD 2.725"
4/30/2020 0.000 2T-37
9,734.0 5,302.5 62.95 Patch P2P Packer CPP35211 2w/ 16.5' of Spacer
Pipe and Anchor Latch CPAL35073. OAL 22'
Max OD 2.72"
5/11/2019 1.625 2T-37
9,737.0 5,303.8 62.93 Spacer Pipe P-110 Spacer Pipe 5/11/2019 1.600 2T-37
9,755.0 5,312.0 62.80 Patch P2P Packer CPP35156 OAL 4' Max OD 2.72 5/11/2019 1.625 2T-37
10,517.0 5,714.6 53.39 Patch P2P Packer CPP351971 w/ 23' of spcer pipe
and Anchor Latch CPAL35108 4800# Shear.
28.5' OAL. Max OD 2.725.
4/8/2019 1.590 2T-37
10,521.0 5,717.0 53.37 Spacer Pipe P-110 Spacer Pipe 4/8/2019 1.590 2T-37
10,545.0 5,731.4 53.27 Spacer Pipe 2.70" PBR CPBR35015 w/ 29' of Spacer Pipe
and Anchor Latch CPAL35099, 7200#
SHEAR. OAL 31.5' Max OD 2.7"
4/7/2019 1.620 2T-37
10,560.0 5,740.3 53.15 TBG LEAK LEAK IDENTIFIED BY LDL 3/28/2019 2T-37
10,575.0 5,749.4 52.83 Patch P2P Packer CPP35073 OAL 4' Max OD 2.72 4/7/2019 1.625 2T-37
10,620.0 5,776.9 51.84 CTD 2 3/8" LINER
TOP
L1-01 liner lined up into 3.5" tbg. Liner Top @
10,620.
12/13/2018 1.992 2T-37
10,982.0 6,007.0 49.95 FISH 1 1/2 " DMY on RK Latch Dropped in Rathole
9/23/1995
9/23/1995 2T-37
Liner Details
Top (ftKB)
Top (TVD)
(ftKB) Top Incl (°) Item Des Com
Nominal ID
(in) Wellbore
41.0 41.0 0.00 CONDUCTOR 15.062 2T-37
41.4 41.4 0.00 HANGER 8.835 2T-37
10,619.9 5,776.8 51.85 DEPLOYMENT
SLEEVE
Shorty Deployment Sleeve 1.920 2T-37L1-01
10,704.8 5,830.0 50.87 DEPLOYMENT
SLEEVE
Shorty Deployment Sleeve - BHA # 19 1.920 2T-37L1
10,704.8 5,830.0 50.91 DEPLOYMENT
SLEEVE
Shorty Deployment Sleeve 1.000 2T-37
10,768.0 5,863.0 69.80 ALUMINUM BILLET OH Anchor & Aluminum Billet - BHA # 17 1.920 2T-37L1
10,780.0 5,866.7 74.79 ALUMINUM BILLET OH Anchor & Aluminum Billet - BHA #13 1.920 2T-37L1
10,794.6 5,869.8 80.78 ALUMINUM BILLET OH Anchor & Aluminum Billet - BHA #8 1.920 2T-37L1
10,806.3 5,871.1 85.72 DEPLOYMENT
SLEEVE
Shorty Deployment Sleeve - BHA # 7 1.920 2T-37L1
11,766.6 5,878.3 85.83 DEPLOYMENT
SLEEVE
Shorty Deployment Sleeve - BHA # 6 1.920 2T-37L1
13,064.0 5,867.8 85.57 DEPLOYMENT
SLEEVE
Shorty Deployment Sleeve 1.920 2T-37L1-01
14,071.0 5,850.0 91.05 DEPLOYMENT
SLEEVE
Shorty Deployment Sleeve 1.920 2T-37L1-01
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft
)Type Com Wellbore
10,675.0 10,698.0 5,811.2 5,825.7 C-4, 2T-37 7/6/2001 4.0 APERF SQUEEZED CLOSED
6/30/2007
2T-37
10,680.0 14,777.0 5,814.4 C-4, 2T-37 12/12/2018 Slotted
liner
2T-37
10,720.0 10,740.0 5,839.6 5,852.2 A-3, 2T-37 9/26/1995 4.0 IPERF Oriented 90 deg. 270 deg.
f/ lowside of hole
2T-37
Comment
SSSV: NIPPLE
2T-37, 5/3/2020 6:53:05 AM
Vertical schematic (actual)
Slotted liner; 10,680.0-
14,777.0
CTD 2 3/8" LINER TOP;
10,620.0
PRODUCTION; 38.7-
11,073.6
FISH; 10,982.0
L1 LATERAL; 10,704.8-
13,012.0
L1 LATERAL; 10,704.8-
10,768.0
IPERF; 10,720.0-
10,740.0
C-SAND SQUEEZE;
10,675.0 ftKB
APERF; 10,675.0-
10,698.0
L1-01 LATERAL;
10,619.9-14,777.0
SOS; 10,624.7
NIPPLE; 10,613.4
PACKER; 10,597.3
ANCHOR; 10,596.4
NIPPLE; 10,588.3
Patch; 10,575.0
TBG LEAK; 10,560.0
Spacer Pipe; 10,545.0
GAS LIFT; 10,542.8
Spacer Pipe; 10,521.0
Patch; 10,517.0
Patch; 9,755.0
Spacer Pipe; 9,737.0
GAS LIFT; 9,737.3
Patch; 9,734.0
RBP; 9,723.0
Catcher; 9,720.0
GAS LIFT; 8,712.5
GAS LIFT; 7,406.3
GAS LIFT; 5,347.7
Annular Fluid - natural
gas; 0.0-9,737.0
SURFACE; 41.4-4,145.3
GAS LIFT; 2,194.3
NIPPLE; 505.0
CONDUCTOR; 41.0-
121.0
HANGER; 36.6
KUP PROD
KB-Grd (ft) Rig Release Date
8/13/1995
Annotation
Last WO:
End DateH2S (ppm)
50
Date
11/11/2014...
TD
Act Btm (ftKB)
11,080.0
Well Attributes
Field Name
KUPARUK RIVER UNIT
Wellbore API/UWI
501032022700
Wellbore Status
PROD
Max Angle & MD
Incl (°)
67.34
MD (ftKB)
3,400.00
Legal Wellname 2T-37 Common Wellname2T-37
AK All Wellbores Schem
Mandrel Inserts
St
ati
on
No
/S Top (ftKB)
Top (TVD)
(ftKB) Make Model OD (in) Serv
Valve
Type
Latch
Type
Port
Size
(in)
TRO Run
(psi) Run Date Com Wellbore
1 2,194.3 2,006.3 CAMCO MMM 1 1/2 GAS LIFT GLV RK 0.188 1,193.0 12/23/2018 4:00 2T-37
2 5,347.7 3,401.0 CAMCO MMM 1 1/2 GAS LIFT GLV RK 0.188 1,217.0 3/10/2019 1:00 2T-37
3 7,406.3 4,306.7 CAMCO MMM 1 1/2 GAS LIFT OPEN RK 4/30/2020 2T-37
4 8,712.5 4,855.5 CAMCO MMM 1 1/2 GAS LIFT DMY RK 0.000 0.0 12/26/2018 12:30
Note:
Lite
body
DV
2T-37
5 9,737.3 5,303.9 CAMCO MMM 1 1/2 GAS LIFT OV RK 0.188 0.0 1/23/1997 6:30 2T-37
6 10,542.8 5,730.1 CAMCO MMM 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/28/2019 12:00 2T-37
Cement Squeezes
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Des Type Start Date Com Wellbore
10,675.0 10,698.0 5,811.2 5,825.7 CEMENT
SQUEEZE
Squeeze 6/30/2007 C-4 SAND SQUEEZE -
MILLED TO 10788' W2.74"
BIT
2T-37
2T-37, 5/3/2020 6:53:05 AM
Vertical schematic (actual)
Slotted liner; 10,680.0-
14,777.0
CTD 2 3/8" LINER TOP;
10,620.0
PRODUCTION; 38.7-
11,073.6
FISH; 10,982.0
L1 LATERAL; 10,704.8-
13,012.0
L1 LATERAL; 10,704.8-
10,768.0
IPERF; 10,720.0-
10,740.0
C-SAND SQUEEZE;
10,675.0 ftKB
APERF; 10,675.0-
10,698.0
L1-01 LATERAL;
10,619.9-14,777.0
SOS; 10,624.7
NIPPLE; 10,613.4
PACKER; 10,597.3
ANCHOR; 10,596.4
NIPPLE; 10,588.3
Patch; 10,575.0
TBG LEAK; 10,560.0
Spacer Pipe; 10,545.0
GAS LIFT; 10,542.8
Spacer Pipe; 10,521.0
Patch; 10,517.0
Patch; 9,755.0
Spacer Pipe; 9,737.0
GAS LIFT; 9,737.3
Patch; 9,734.0
RBP; 9,723.0
Catcher; 9,720.0
GAS LIFT; 8,712.5
GAS LIFT; 7,406.3
GAS LIFT; 5,347.7
Annular Fluid - natural
gas; 0.0-9,737.0
SURFACE; 41.4-4,145.3
GAS LIFT; 2,194.3
NIPPLE; 505.0
CONDUCTOR; 41.0-
121.0
HANGER; 36.6
KUP PROD
...
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195101
WELL LOG TRANSMITTAL #905665559 30 93 1
To: Alaska Oil and Gas Conservation Comm. June 3, 2019
Atm.: Natural Resource Technician �j
333 West 7th Avenue, Suite 100 4='
Anchorage, Alaska 99501 JUN 2 7 201
AOGCC
RE: Multi Finger Caliper (MFC), Leak Detect Log, Plug, Packer, and Patch Setting Records:
Run Date: 03/26/2019, 04/07/2019, and 05/11/2019
The technical data listed below is being submitted herewith. Please address any problems or
concerns to the attention o£
Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518
FRS_ANC@halliburton.com
2T-37
Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom
50-103-20227-00
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
0
FRS_ANC@halliburton.com
Date: l.,C o "il" q Signed:
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
MAY 2 2 7n10
1. Operations Abandon ❑ Plug Perforations ❑
Fracture Stimulate ❑
Pull Tubing ❑ Operations shutdown ❑
Performed: Suspend ❑ Perforate ❑
Other Stimulate ❑
Alter Casing �`
g ❑ Change Approved Program ❑
Plug for Redrill ❑ 'erforate New Pool ❑
Repair Well ❑D
Re-enter Susp Well ❑ Other: Tubing Patch Q
2. Operator
ConocoPhillips Alaska, Inc.
4. Well Class Before Work:
5. Permit to Drill Number:
Name:
Development Q
Stratigraphic ❑
Exploratory ❑
Service ❑
195-101
3. Address: P. O. Box 100360, Anchorage, Alaska
6. API Number:
99510
50-103-20227-00
7. Property Designation (Lease Number):
8. Well Name and Number: KRl-I 2T-37
ADL0025568, ADL0025569
9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s):
N/A
Ku aruk River Field / Ku aruk River Oil Pool
11. Present Well Condition Summary:
Total Depth measured 11,080 feet
Plugs
measured None feet
true vertical 6,070 feet
Junk
measured 10982 feet
Effective Depth measured 10,984 feet
Packer
measured 10,597 feet
true vertical 6,006 feet
true vertical 5,763 feet
Casing Length Size
MD
TVD Burst Collapse
CONDUCTOR 80 feet 16
121' MD
121' TVD
SURFACE 4,104 feet 9 5/8 "
4,145' MD
2890' TVD
PRODUCTION 11,035 feet 7
11,074' MD
6066' TVD
Lt LATERAL 4,097 feet 2 3/8 "
14,777' MD
5880' TVD
Perforation depths Measured depth 10675-10698, 10680-14777,
10720-10740
True Vertical depth
Tubing (size, grade, measured and true vertical depth)
3.5"
L-80 10,625' MD 5,780' TVD
Packers and SSSV (type, measured and true vertical depth) PACKER - BAKER SAB -3
PERMANENT 10,597' MD 5,763' TVD
NIPPLE
- CAMCO DS LANDING NIPPL 505' MD
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
NA
Treatment descriptions including volumes used and final pressure:
NA
13.
Representative Daily Average Production or Injection Data
Oil -Bbl
Gas-Mcf I
Water -Bbl I Casing Pressure Tubing Pressure
Prior to well operation:NA
NA INA
INA INA
Subsequent to operation: INA
NA INA
INA INA
14. Attachments (required per20 MC 25.070, 25071, s 25.283)
15. Well Class after work:
Daily Report of Well Operations Q
Exploratory ❑
Development Q Service ❑ Stratigraphic ❑
Copies of Logs and Surveys Run ❑
16. Well Status after work:
Oil ❑✓ Gas ❑ WDSPL ❑
Printed and Electronic Fracture Stimulation Data ❑
GSTOR ❑ WINJ
❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑
17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge.
Sundry Number or N/A if C.O. Exempt:
N/A
contact Name: Dusty Freeborn/Jan Byrne
Authorized Name: Dusty Freeborn
Contact Email: N1617@conocophillips.com
Authorized Title: Problem Wells Supervisor
Contact Phone: 907-659-7224
Authorized Signature:
Dale:
l/TL 6/�/l9
Form 10-404 Revised 4/2017 RBDMS L`�MAy 2 3 2019 Submit Original Only
ConocoPhillips
Alaska
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
19th day of May, 2019
Commissioner Jessie Chmielowski
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, AK 99501
Commissioner Chmielowski,
Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for the retrievable tubing
patches set across known tubing leaks in producer KRU 2T-37 (PTD 195-101).
Please contact Jan Byrne or myself at 659-7224 if you have any questions.
Sincerely,
Dusty Freeborn
Well Integrity Supervisor
ConocoPhillips Alaska, Inc.
2T-37
DESCRIPTION OF WORK COMPLETED
SUMMARY
Date Event Summary
05/16/191 RE TIFL (PASSED)
05/12/19 MITT TO 2500 (PASS). CMIT IA x T TO 2500 (PASS). PULLED TEST TOOL @ 9734' RKB. �
05/11/19
05/03/19
04/29/1
SET 2.725" P2P (#CPP35156) MID ELEM @ 9755' RKB. CORRELATED TO TBG DETAIL
9/19/95. CMIT T x IA TO 2500 (PASS) AGAINST TEST TOOL (LOST TWO SEALS). RAN
BRUSH THRU P2P; NO SEALS RECOVERED. SET 2.725" P2P (#CPP35211), SPACER PIPE,
ANCHOR LATCH (#CPAL35073) MID-ELEM @ 9734' RKB. SET TEST TOOL IN P2P @ 9734'
RKB. LRS ON LOCATION TO PERFORM MITS. IN PROGRESS.
SET 3.5" TTS TEST TOOL IN TOP OF PACKER @ 10,517' RKB; ATTEMPT TO MITT
(FAILED) DHD SHOOTING F/L SHOTS ON IA AND SHOWING INFLOW; SET HOLEFINDER
ON TOP OFF TTS TEST TOOL AND TBG FAILED TO TEST. MOVE UP HOLE AND OBTAIN
TBG TEST @ 9731' RKB (APPEARS LEAK IS @-NEAR GLM # 5 @ 9737' RKB); PULLED
TEST TOOL @ 10,517' RKB; BRUSH n' FLUSH PROJECTED PATCH INTERVAL FROM 9600'
9800' RKB. JOB COMPLETE & READY FOR PLAN FORWARD.
D LOAD WELL WITH 70 BBLS DIESEL SET 3 1/2 TTS TEST TOOL IN PATCH @ 10517' RKB
MIT TBG TO 2500 PASS, DHD PREFORMED TIFL WITH TEST TOOL IN PATCH & 2500 PSI
ON TBG PASS, PULLED 3 1/2 TTS TEST TOOL @ 10517' RKB. COMPLETE, GIVE WELL TO
DSO FOR PRODUCTION
04/07/19
03/27/19
ANCHOR LATCH (#CPAL35108) MID-ELEM @ 10,517' RKB. MITT & CMIT TO 2500
(PASSED) W/ TEST TOOL IN P2P. JOB COMPLETE.
SET 2.72" P2P (#CPP35073) MID-ELEM @ 10,575' RKB, CORRELATE TO HES LDL 27 -MAR -
2019. CMIT TO 2500 PASSED W/ TEST TOOL IN P2P. SET PBR (#CPBR35015), SPACER
PIPE, ANCHOR LATCH (#CPAL35099) @ 10,544' RKB. SET TEST TOOL IN PBR @ 10,544'
RKB. LRS ON LOCATION TO CMIT. IN PROGRESS.
RAN LDL TOOLS FROM 2.78" WRP @ 10610' RKB TO 9750' RKB FOUND LEAK @ —10560'
RKB, SET 3 1/2 AVA CATCHER @ 10610' RKB, RAN 3 1/2 SLIP STOP HOLE FINDER
TESTING INCONCLUSIVE, JOB IN PROGRESS.
03/13/19 Re-TIFL FAILED DUE TO PRESSURE INCREASE AND INFLOW
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
JAN 14 21119
1. Operations Abandon[-] Plug Perforation❑ Fracture Stimulate ❑
Pull Tubing ❑ O ra s u wrt. f-1
Performed: Suspend❑ Perforates Other Stimulate ❑
Alter Casing ❑ Chang /C�/*�L�J
Plug for Redrill❑ Perforate New Poo❑ Repair Well ❑
Re-enter Susp Well ❑ Other: WHIPSTOCK ❑'
2. Operator
4. Well Class Before Work:
5. Permit to Drill Number:
Name: ConocoPhillips Alaska, Inc.
Development ❑
Stratigraphic ❑
Exploratory ❑
Service ❑
195-101
3. Address: P. 0. Box 100360, Anchorage, Alaska
6. API Number:
99510
50-103-20227-00
7. Property Designation (Lease Number):
B. Well Name and Number. KRU 2T-37
ADL 25568, ADL 25569
9. Logs (List logs and submit electronic and printed data per 20AAC25.071):
10.
Field/Pool(s):
N/A
Kuparuk River Field / Kuparuk River Oil Pool
11. Present Well Condition Summary:
Total Depth measured 11,080
feet Plugs
measured None feet
true vertical 6,067
feet Junk
measured 10982 feet
Effective Depth measured 10,984
feet Packer
measured 10,597 feet
true vertical 6,006
feet
true vertical 5,763 feet
Casing Length Size
MD
TVD Burst Collapse
CONDUCTOR 80 feet 16
121' MD
121' TVD
SURFACE 4,104 feet 9 5/8"
4,145' MD
2890' TVD
PRODUCTION 11,035 feet 7
11,074' MD
6066' TVD
Perforation depth: Measured depth:
10675-10698,10720-10740 feet
True Vertical depth:
5811-5826, 5830-5852 feet
Tubing (size, grade, measured and true vertical depth)
3.5"
L-80 10,625' MD 5,780' TVD
Packers and SSSV (type, measured and true vertical depth)
PACKER- BAKER SAB -3 PERMANENT PACKER 10,597' MD 5,763' TVD
SSSV -NONE
12. Stimulation or cement squeeze summary:
Intervals treated (measured): N/A
Treatment descriptions including volumes used and final pressure:
13.
Representative Daily Average Production or Injection Data
Oil -Bbl
Gas-Mcf
Water -Bbl Casing Pressure Tubing Pressure
Prior to well operation: Shut -In
-
- - -
Subsequenttooperation: IShut-In
-
- - -
14. Attachments (required per 20 AAC 25.070, 25.071, 825283)
15. Well Class after work:
Daily Report of Well Operations ❑'
Exploratory ❑
Development I] Service ❑ Stratigraphic ❑
Copies of Logs and Surveys Run ❑
16. Well Status after work:
Oil 0 Gas ❑ WDSPL ❑
Printed and Electronic Fracture Stimulation Data ❑
GSTOR ❑ WINJ
❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑
17. 1 hereby certify that the foregoing Is true and correct to the best of my knowledge.
Sundry Number or N/A if C.O. Exempt:
318-457
Contact Name: Ryan McLaughlin
Authorized Name: James Ohlinger
contact Email: Ryan. McLaughlin@cop.com
Authorized Title: Staff CTD Engineer
Authorized Signature
/ /y Contact Phone: (907) 265-6218
:
Date:
Form 10-404 Revised 4/2017 v rl- z /s// y RBEIMS-1// i N 15 2019 Submit Original Only
__vr1_ KUP PROD WELLNAME 2T-37 WELLBORE 2T-37
GonoaftilI(ps wall Attr butes Max MgleB MD TD
WUIIrore APOUWI WNIM,e3mlus ,^cl (^) MOn11Ka) Mid. A 85kB.IIIC. KUPARUK RIVER UNIT I5010320J»00 IPRII IV,
'en I
na.Ina"e+zsz3o PM
Lest Tag
VeMlNvretlo(=4b11
AnnWNbn
Depen mK B) Iran, Wellbem
Ualmou By
Iast Tag:RKB(Es1. 15' of Fill, Leaving 5' of Open FARE)
]1621118 ZT-31
zembael
HANGER. xe
Last Rev Reason
Ann.ho.
End Dm vMIMrt weL MoO Br
Rev Reason: Installed OLD. Added Liner Top Depth
I&Z/] 01 0 1,T-11 liarguse
Casing Strings
M CONDUCTOR'. tl.P+210
NVPLE; YA.O I
camp Deunpnon OD On) IDIm) rop0IXa1 SeLDeptn MKB) Sed Depth ErVOl... vWLen U... GrMe Top rmeaf
CONDUCTOR i6 15.116 41.0 121.0 1210 62.58 Hd0 WELDED
Gai,p DeudlpWn OD (H) ID llp TopIKKBI Stl DepM marl SN Dep"IrVDL.. WOLen(I GHRW Tap Tama
SURFACE 95M 8.83 41.4 4,145.3 2,889] 4000 L-00 BTC
ODlin) ID (Inl TOP lfdKel SN Dusth MKIM Set Dep"(TVO)... VHMn p... Grae Top Tlldea
Causing PRODUCTION
PRODUCTION J 628 38.] 11,073.6 6,065.9 260) L-80 BTC -MOD
CASUFTZW1.0
07.11 Oexripron OD lin) ID Dn) TapmKel Set MIROU"Bl BN Delta I.I.. vidden(I Dude Top Threat
L1 Lateral 2318 1.99 10,704.8 10,759.0 5,870.0 460 1A0 STL
Tubing Strings
(ml Tap mKFH Set Dep" m... d"PA (TVI)L . M nM10 Orae Top Con -don
Tubmp Deenipnan soma Me... 1'111
TUBING 31/2 2.99 3fifi 10,6256 5,780.3 9.30 L-80 ABM-EUE
ComplaUcn Details
SURFACE; <1 H,1L'.9
Armin Flub-"w'nl aw, .a�
IF RVm Toplrc xom"el
Top MISS) (HAS) 1°l Mm Dee Co. ID fin)
36.6 36U 000 HANGER FMC GEN IN TUBING HANGER 3.500
5050 504.8 1.61 NIPPLE CAMCOOSIANDING NIPPLE, 2856"NO 0 2.812
GASUFT, SN77
10,588.3 5,]574 5254 NIPPLE CAMEO W-1 SELECTIVE IANDING NIPPLE 2,812
10,596.4 5,7112A 52.36 ANCHOR K ANCHOR, RUN WITH PACKER 2,992
10.597.3 5,762.9 52.34 PACKER BAKER SAB -3 PERMANENT PACKER (SEAL ATTACHED) ]250
Dns UET.]AL5.3
10,613.4 5,7Y2.8 51.99 NIPPLE IANOINGN L ]5"NO ILLED UT 2.800
2RE)
10,6243 5,779.8 51.74 506 BAKER SHEAR OUT U ,ELMO TTL dudl,g 3.015
PERE on 0926195
GAS Urr; Arias
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
mP(rv.r Tap mal
Tap mKBl
com
Ran Dem
ID du
10,620.0 5776.9 51.84
"liner L1-0iliner lined up inro 3.5"tbg. Liner Top@10,620.
1.992
00
8
GOB UFT; 9,Ta].a
10,982.0 6.00> 0 4995
FISH 111 MY on RK Latch Moro in R.H ole 92311995
912311995
Perforations 8 Slots
Snod
G43 uFT: +Dsaza
rppKS)
eMKB1)
Dene
l•Nat."
TOPMKIU
atm ml8,0
mpe)
(5.82
Lm3edzone
Date
)
ryce
Com
10,675.0
10,698.0
5,811.2
5,025.7
G4, 2T-3]
7IN2001
4.0
APERF
SOUE ZED LOSED
NIPPLE; IO.Y93
6130/200]
10,680.0
143]].7
.8144
C4, 2T87
12/122018
Sloffed
Axcx0a;1aaw.4
liner
PACKER,+othea
1072oo
10,740.
5.8396
5,8522
AJ, 2T-37
912&1995
AR
IPERF
Oriented 90 deg -27-0 eg.1
Invader, of bole
I
NIPPLE; 10.134-
08134
Cement
Squeezes
Top RVD) atm Irv.)
RIFUK9) S1m MHS) MKS) (me)
.eF Sb,t.ale Co.
10, 75.0 10,698.0 5,811.2 5,825.]
ement 6/30200] C-4 UEEZE- IL DT 10788w2.
Squeeze BIT
x'10.1
Mandrel Inserts
an
AN
LIQ LITERAL; WAHIS,
µm0 \
APPRF1+0676O- 0 we.0
c.9gND sgUEElf:faWUO
Me
N Top mKe)
Top Vi
IKKBI MaFe
Model
M)did Sery
VWe IeRb
Typ Type
Porl Slee
(b)
TRO Ron
1psq
pun Mh
Com
1 2,1943
2,006.3
11 GAS LIFT
GLV RK
OARS
1193.0
1223/2018
400
2 5,34].1
3,401.0
1112 SLIFT
OV RK
0.250
00
1&262018
1M
3 7,406.3
4, J
--4T55-5
12 LIFT
DMV RK
0.000
00
12/2]12018
11:00
4 8,712.5
ZMMM
112 GAB LIFT
DAY RK
0.000
00
122612018
1
NOW
Lite
body
DV
5 9,137.3
5,30.9
112 GAS LIFT
OV RK
0.188
00
12311997
6'80
6 10,592.6
S,J30.1
112 GAB LIFT DMV
RK
0.000
00
ll1]2010
1200
IPERF. 10,7200,10,7O O
Notes: General By Safety
Eno PHW Anna"dion
211 W2003 NOTEUNABLE TO GET GUNS DOWNHOLE -4140 -MAX DEPTH
u wmnl; 10.7wa10.73a0
9/13/2011 NOTE: View SChemaSC w/ Alaska ScbemadiCR0
7232012 NOTE: NOT ABLE TO PULL VAT 973T AFTER MANY ATTEMPTS
LI LATERAL: 10,ra
13.0120
FISH: 10.20
PRCOUCTION', 3a,r-+1,0RE
CTD 2aur Livr, l0.MD
alas wr, m,43o.u,7n.0
Operations Summary (with Timelog Depths)
_l.
Z.
2T-37
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Tlme
End Time
Dur (hd
Phase
Op Code
Activity Cotle
Time P -T -X
Operation
Start Depth
(MKB)
End Depth (MB)
11/20/2018
11/20/2018
3.50
MIRU
MOVE
RURD
P
Raise stairs & landings, lift &secure
0.0
0.0
12:00
15:30
beaver slide, disconnect PUTZ,
disconnet hi -/line, check tree bolts,
continue RD checklist
11/20/2018
11/20/2018
1.50
MIRU
MOVE
RURD
P
Complete RD check list, trucks arrive
0.0
0.0
15:30
17:00
1 at 16:30, pre job.
11/20/2018
11/20/2018
2.30
MIRU
MOVE
RURD
P
Jack and pull service mod to edge of
0.0
0.0
17:00
19:18
pad, install jeep.
Jack and pull sub mod forward - 5',
Replace tree cap, pull sub completely
off well, stage at edge of pad, install
jeep. Perform environmental walk
down with DSO.
11/20/2018
11/20/2018
1.90
MIRU
MOVE
MOB
P
Roll off pad, Peak Crew change on the
0.0
0.0
19:18
21:12
access road - 10 min, continue on to
CPF3
11/20/2018
11/21/2018
2.80
MIRU
MOVE
MOB
P
Enter main spine from CPF3 an rout to
0.0
0.0
21:12
00:00
2T-37
11/21/2018
11/21/2018
3.30
MIRU
MOVE
MOB
P
Arrive at 2T -Pad
0.0
0.0
00:00
03:18
11/21/2018
11/21/2018
0.40
MIRU
MOVE
MOB
P
Drop off sub jeep, lay pit liner, drop
0.0
0.0
03:18
03:42
1 dozer
11/21/2018
11/21/2018
0.80
MIRU
MOVE
MOB
P
Spot sub over well & lay mats
0.0
0.0
03:42
04:30
11/21/2018
11/21/2018
2.00
MIRU
MOVE
MOB
P
Crew change, tum pits around, hook
0.0
0.0
04:30
06:30
1 up cat to sow, spot pits, lay mats
11/21/2018
11/21/2018
2.50
MIRU
WHDBOP
MOB
P
Drop stairs & landings, connect PUTZ,
0.0
0.0
06:30
09:00
begin RU, NU BOPE
I**
Rig Accept 9:00 AM
11/21/2018
11/21/2018
1.00
MIRU
WHDBOP
RURD
P
Change out annular preventer
0.0
0.0
09:00
10:00
11/21/2018
11/21/2018
1.00
MIRU
WHDBOP
RURD
P
Energize Koomey, MU tiger tank hard
0.0
0.0
10:00
11:00
1
line, spot half -way house & shop
11/21/2018
11/21/2018
1.60
MIRU
WHDBOP
RURD
P
Complete RU, grease master, swab, &
0.0
0.0
11:00
12:36
tango valves, fluid pack lines & stack,
clear Boor, place barricades
11/21/2018
11/21/2018
0.40
MIRU
WHDBOP
BOPE
P
Shell test, good, PJSM
0.0
0.0
12:36
13:00
11/21/2018
11/21/2018
3.00
MIRU
WHDBOP
BOPE
P
Testing BOP's, Test witnessed by
0.0
0.0
13:00
16:00
AOGCC Adam Earl, test to 3500 psi /
2500 psi
Upper 2" Fail Pass
11/21/2018
11/21/2018
2.50
MIRU
WHDBOP
BOPE
P
Install test joint, continue BOP test
0.0
0.0
16:00
18:30
1
completeBOP test - 5:30 hrs
11/21/2018
11/21/2018
2.50
SLOT
WELLPR
CTOP
P
Adjust tree and stack, struggle a bit
0.0
0.0
18:30
21:00
with leaning tree. Make up nozzle,
stab on and line up to reverse circ,
test inner reel iron / stripper- good.
11/21/2018
11/21/2018
0.60
SLOT
WELLPR
CTOP
P
Test DS PDL/ tiger tank line,
0.0
0.0
21:00
21:36
11/21/2018
11/22/2018
2.40
SLOT
WELL
CTOP
P
Instal night cap, lock out and cut e-
0.0
0.0
21:36
00:00
line, boot, stab on, pump slack, ramp
up pump rate 3 times, unstabed, cut
coil, found wire @ 1 ft back. Cut 20' of
coil. rehead.
11/22/2018
11/22/2018
SLOT0.0
00:00
00:00
Page 1127 ReportPrinted: 11712019
Operations Summary (with Timelog Depths)
- I,
2T-37
.
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
StartTiime
11/22/2018
End Time
11/22/2018
Oar(hr)
2.20
Phase
SLOT
Op Code
WELLPR
Activity Cotle
CTOP
Tme P -T -X
Operation
Start Dept
MKS)
End Depth (N(B)
00:00
02:12
P
Complete instil of CC, pull test good,
0.0
0.0
rehead, test wire 2000/66, PT - good,
Pumped open SSV and installed
fusible cap. Measure coil thickness
per SOP 0.208, 0.201, 0.206, &
0.204"
11/22/2018
11/22/2018
3.40
SLOT
WELLPR
PULD
P
PJSM, Tubing pressure 1646
0.0
55.0
02:12
05:36
1584 psi. Line up dow, the tubing with
seawate, bullhead 97 bbls @ 3 bpm,
circ pressure 1700 psi fell to 750 psi.
Bled Ato 1360 psi. PU & PD BHA#1,
clean out assembly w D331 ridge set -
2.80" go / 2.79" no go.
11/22/2018
11/22/2018
2.40
SLOT
WELLPR
TRIP
P
RIH w/BHA#1 Cleanout Assembly,
55.0
10,510.0
05:36
08:00
1.2 bpm, erratic returns (gas), 80 fpm
PUW = 18K @ 3030', PUW = 28K Q
6000', PUW = 38K (a3 9000'
11/22/2018
11/22/2018
0.20
SLOT
WELLPR
DLOG
P
Log K1 for +6' correction, close EDC
10,510.0
10,545.0
08:00
08:12
11/22/2018
11/22/2018
0.30
SLOT
WELLPR
TRIP
P
Continue RIH, pumping 1.8 bpm FS =
10,545.0
10,765.0
08:12
08:30
331 psi, CWT=15K, PUW=42K@
10,627' (just past D -nipple),
11/22/2018
11/22/2018
0.10
SLOT
WELLPR
TRIP
P
PUH, PUW =48K @ 10,765', 1.85
10,765.0
10,510.0
08:30
08:36
bpm, still circulating out gas & well
bore fluids
11/22/2018
11/22/2018
0.10
SLOT
WELLPR
DLOG
LogKIfor 0' correction, prep tool for
10,510.0
10,546.0
08:36
08:42
11/22/2018
11/22/2018
0.30
SLOT
WELLPR
DLOG
P
Perform CCL (10,510 to 10,725)
10,546.0
10,765.0
08:42
09:00
11/22/2018
11/22/2018
2.30
SLOT
WELLPR
TRIP
P
POOH, PUW =40K, displacing to
10,765.0
55.0
09:00
11:18
used PowerPro, losing -0.4 bpm,
open EDC, PJSM
11/22/2018
11/22/2018
1.30
SLOT
WELLPR
PULD
P
PUD BRA -#J, stripped alien head on
55.0
0.0
11:18
12:36
bleed port (resolve)
11/22/2018
11/22/2018
1.00
SLOT
WELLPR
RGRP
T
Adjust riser alignment, swap out 3'-f-
0.0
0.0
12:36
13:36
T riser for one 4' riser.
11/22/2018
11/22/2018
1.20
PROD1
RPEQPT
PULD
P
PJSM, PU & begiin PD BHA70 HEW
0.0
73.0
13:36
14:48
11/22/2018
11/22/2018
1.00
PROD1
RPEQPT
PULD
T
Unable to raise mast, trouble -shoot,
73.0
73.0
14:48
15:48
combinatioin of wind & hanging weight
of PDL was not allowing raising of
mast. Raised PDL's & mast raised
11/22/2018
11/22/2018
0.60
PROD1
D
P
Complete PD BHA #2, slide in can,
73.0
73.0
15:48
1624
MU to coil, tag up, set counters
11/22/2018
11/22/2018
2.30
PROD1
P
RIH w/ BHA W2, EDC open, density
73.0
10,540.0
16:24
18:42
q
out erratic, taking returns to TT,
Bullhead 30 bbl 150K LSRV pill
11/22/2018
11/22/2018
0.20
PROD1
G
P
Tie into he K1 fora +5' correction
10,540.0
10,587.018:42
18:54
11/22/2018
11/222018
0.30
PROD1
QWPST
P
WH, 123 psi, IA 1136 psi, OA 82 psi.
10,587.0
10,718.8
18:54
19:12
RIH to 10,718'. PU, 45 k lbs.
RBIH to WS setting depth 10718.781,
PU to neautral weight, CT 36.9 k lbs,
zero WOB,
Stage pump up, sheared at 3900
paLS/D 4.5 k lbs WOB, PU 44 k lbs.
HEW set, TOW Q 10,710'
Page 2127 ReportPrinted: 1/7/2019
Operations Summary (with Timelog Depths)
-
2T-37
Conocolehillips
Rig: NABORS CDR3-AC
Job: DRILLING SIDETRACK
Time Log -
StartTme
11/22/2018
End Time
11/22/2018
Der (hr)
2.00
Phase
PROD1
Op Code
RPEQPT
ACGviy Cade
TRIP
Tnna P -T -X
operation
Start Depth
(N(B)
End Depth(ftKB)
19:12
21:12
P
PU, bullhead 30 bbl -100 k SRV, open
10,718.8
80.0
EDC, Circulate bottoms up to the tiger
tank.
Pumping 2 bpm, loses 0.75 bpm,
Bleed IA from 1140 psi to 962 psi over
an hr.
POOH losses @- 0.25 bpm.
11/2212018
21:12
11/22/2018
1.50
PROD1
RPEQPT
PULD
P
PJSM, bump up, PUD BHA#2 while
80.0
0.0
22:42
pumping managed pressure.
11/2212018
11/23/2018
1.30
PROD1
WHPST
PULD
P
PU & PD BHA#3, window milling
0.0
80.0
22:42
00:00
asssembly, WFD V foxed bend motor.
2.80" No go
11/23/2018
11/23/2018
0.70
PROD-
WHPST
PULD
P
PU & PD BHA#3, bump up, set
0.0
82.0
00:00
00:42
counters.
11/23/2018
00:42
11/23/2018
2.30
PR0D1
WHPST
TRIP
P
RIH W BHA# 3.
82.0
10,550.0
03:00
S/D @ 9223',9285',9566', PUS 37 k
lbs.
Close EDC, Pumps @ 0.8 bpm,
continue in his withou issue
11/23/2018
03:00
11/23/2018
03:12
0.20
TROD1
DLOG
P
Tie into K1 for a +co correction.
10,550.0
10,576.0
11/23/2018
03:12
11/23/2018
03:24
0.20
PR0D1
WHPST
WPST
P
PU Wt 44 k lbs. RIH ad dtatag TOB
10,576.0
10,714.2
@ 10,714.9'
PU, 41k lbs,
CT 3976 psi, @ 1.89 bpm in, 1.29
bpm out - full open choke, WH 5 psi,
IA 957 psi, OA 80 psi.
Free spin diff 764 psi, CT Wt 14.4 k
lbs, see motor work at 10,714.22
Ti
03:24
11/23/2018
04:18
0.90
PROD1
WHPST
WPST
P
CT 3976 psi, @ 1.89 bpm in, 1.29
10,714.2
10,715.2
bpm out - full open choke, Free spin
diff 764 psi,
CT Wt 14.4 k lbs, WOB 0.94 k lbs
11/23/2018
04:18
11/23/2018
06:00
1.70
PROD1
-
WHPST
WPST
P
Engage auto drill10,715.2
10,716.7
CT4053 psi @ 1.88 bpm in, 1.42 bpm
out.
CT Wt 13.2 k lbs, WOB 1.35 k lbs -
ROP = 1 ft/hr
11/23/2018
06:00
11/23/2018
07:42
1.70
PROD1
WHPST
WPST
P
CWT= 11.6K, WOB = 1.5K,
10,716.7
10,718.5
in, 1.5 bpm out, dp = 887 psi,
own IA to 757 psi
=psi
7" casing, call BOW @',
TOW @ 10,714.2' pumpad
PDL (Build BHA)11/23/2018
07:42
11/23/2018
09:30
1.80
PROD1
WHPST
WPST
P
gat -hole, CWT= 13.8K, WOB =
10,718.5
10,739.0
2K, 1.9 bpm in, 1.57 bmp out, dip =
808 psi, circ = 4051 psi, TD rat -hole =
10,739' (29' from TOWS)
11/23/2018
09:30
11/23/2018
10:30
1.00
3R0D1
WH PST
REAM
P
Perform reaming passes, PUW =40K,
-0,739.0
10,739.0
HS', 30"R, 30°L (all down passes at
HS), sand in samples from rat -hole
TD,
Dry drift up & down, clean, tag bottom,
PUW
= 40K
11/23/2018 11/23/2018
10:30 10:48
0.30
PRODi
WHPST TRIP
P Begin
POOH, lose hi -line power, shut
10,739.0
10,739.0
in
choke, MP5 8, Mpg
Page 3127 Report Printed: 117/2019
Operations Summary (with Timelog Depths)
2T-37
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Star[Time
End Tme
Dur(hr)
Phase
Op Cotle
Activity Cotle
Time P -T -X
Operation
start DBPM
(MB)
End Depth (M)
11/23/2018
11123/2018
1.10
PROM
WHPST
WAIT
T
Work to resolve issue, unable to pump
10,739.0
10,548.0
10:48
11:54
with power down, HMI screens down,
etc, fire up generators, difficulty
getting on gen power, reaquire hi -line
powerm, EMW dropped to 9.7 ppg
with pumps off line
11/23/2018
11/23/2018
0.50
PROM
WHPST
WAIT
T
RBIH to 10,690', begin circulating
10,548.0
10,690.0
11:54
12:24
bottoms up, 18 bbl above bit, again
lose hi -line, successfully get on
generator power
At second power failure: BHP = 3430
psi, WHP = 522 psi, MD = 10,585',
time = 12:15
11/23/2018
11/23/2018
2.60
PROM
WHPST
TRIP
P
POOH, circulating bottoms up, tag up,
10,690.0
77.0
12:24
15:00
j PJSM
11/23/2018
11/23/2018
1.30
PROD1
WHPST
PULD
P
PUD BHA #3, worked to pull down
77.0
0.0
15:00
16:18
weight bar in PDL (frozen shieve),
string reamer & mill came out 2.80" no
-go, LD tools
11/23/2018
11/23/2018
0.70
PROD1
DRILL
CIRC
P
MU nozzle & jet stack, unstab, break-
0.0
0.0
16:18
17:00
off nozzle
11/23/2018
11/23/2018
1.40
PROD1
DRILL
PULD
P
PD BHA #4 Build/Turn Assembly (2.4°
0.0
72.0
17:00
18:24
AKO motor, RS P104 bit), slid in cart,
MU to coil, tag up, set counters, check
pack offs - good.
11/23/2018
11/23/2018
1.90
PROD1
DRILL
TRIP
P
RIH
72.0
10,531.0
18:24
20:18
11/23/2018
11/23/2618
0.20
PROD1
DRILL
DLOG
P
Tie into the K1 for+ 5.5' correction
10,531.0
10,559.1
20:18
20:30
11/23/2018
11/23/2018
0.20
PROM
DRILL
TRIP
P
Close EDC, PU Wt 48 k Ibs, contiune
10,559.1
10,739.0
20:30
20:42
in hole. Slight WOB bobble as we
transited the window, 10,721'.
11/23/2018
11/23/2018
1.80
PROD1
DRILL
DRLG
P
CT 3846 psi, 1.85 bpm in, 1.61 bpm
10,739.0
10,920.0
20:42
22:30
out, free spin diff 568 psi. Annular
3486 psi, 11.46 ppg at the window.
CT Wt 11.5 k lbs, WOB 2.0 k lbs, ROP
140-100 ft, hr. Pump 5 x5 sweep timed
out to TO
Losses @ 0.2 bpm while holding 11.47
pPg
11/23/2018
11/24/2018
1.50
PROM
DRILL
TRIP
P
PU Wt 51 k lbs. POOH chasing
10,920.0
3,252.0
22:30
00:00
sweeps to surface, jog 7", pull out of
hole. -1 k WOB tug and motor work
@ 10,538-
11/2412018
11124/2018
0.60
PROM
DRILL
TRIP
P
PU Wt 51 k lbs. POOH chasing
3,252.0
' 72.0
00:00
00:36
sweeps to surface, jog 7", pull out of
hole. -1 k WOB lug and motor work
@ 10,538'. Holdig 11.5 ppg EMW.
11/24/2018
11/24/2018
1.90
PROD1
DRILL
PULD
P
Bump up, PUD and LD BHA#4,
72.0
0.0
00:36
02:30
holding 11.5 ppg EMW. Reset crown
saver and floor saver post power
outage. Lower section of BHA hung
up in tree, worked wire, tried pumping
and worked wire, no luck. 5x5 PJSM
for change of scope, pressure un
deploy, plug into too) and rotate HOT
180'. Stab PDL, pull with no luck,
prep to pump again, had not pumped
and BHA pulled free with no overfull.
Continued to PUD / LD. Bit came out
2/4, chipped reamers from swinging
bit with high bend out of hole.
Page 4127 Report Printed: 1/7/2019
THE STATE
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 2T-37
Permit to Drill Number: 195-101
Sundry Number: 318-457
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.
k�
DATED this day of October, 2018.
Sincerely,
Hollis S. French
Chair
A
RBDMS OCT' 9 2018
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
o ar � �..' �Lv y` E. E.��. 3
0 C T 0 9 "'Cls
G C'C
1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑
Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑
Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: -Whipstock 12
2. Operator Name:
4. Current Well Class:
5. Permit to Drill Number:
ConocoPhillips Alaska Inc
Exploratory ❑ Development 0 •
Stratigraphic Service
L1❑
195-101 '
3. Address:
6. API Number:
PO Box 100360, Anchorage AK 99510
50-103-20227-00 +46%
7. If perforating:
8. Well Name and Number: �O
What Regulation or Conservation Order governs well spacing in this pool? N/A
KRU 2T-37 '
Will planned perforations require a spacing exception? Yes ❑ No ❑�
9. Property Designation (Lease Number):
10. Field/Pool(s):
')
ADL 25568 /rDL Z S 1 <
Kupamk River Field / Kuparuk River Oil Pool
PRESENT WELL CONDITION SUMMARY
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):
Plugs (MD):
Junk (MD):
11080' 6067' 10984' 6006' 2808
N/A
10982'
Casing Length Size MD TVD
Burst
Collapse
Structural
Conductor 80' 16" 121' 121'
Surface 4104' 9-5/8" 4145' 2890'
Intermediate
Production 11035' 7" 11074' 6066'
Liner
Perforation Depth MD (ft):
Perforation Depth TVD (ft):
Tubing Size:
Tubing Grade:
Tubing MD (ft):
10675'- 10698'
5811' - 5826'
10720'-1074
5839'- 5852'
3-1/2"
L-80
10626'
Packers and SSSV Type: Baker SAB -3 Permanent Packer
Packers and SSSV MD (ft) and TVD (ft): 1059T MD / 5763' TVD
12. Attachments: Proposal Summary �j 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: 11/5/2018
OIL ❑� • 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: O O
COMMISSION USE ONLY
Conditions of approval: Notify Commission that a representative may witness Sundry Number
,,so
Plug Integrity ❑ BOP Test E Mechanical Integrity Test ❑ Location Clearance ❑
Other: 301P ff,5 %- f� 1?SO62 / 6` 5 5`�
�>rfr� to ;Z5_00
It)
/'7 vLa�1, �r'Y f/fn tZ✓
Post Initial Injection MIT Req'd? Yes ❑ No
Spacing Exception Required? Yes ❑ No Subsequent Form Required: it —
APPROVED BY
I 1 I rPi
Approved by: COMMISSIONER THE COMMISSION Date: t o
rT/' �U�/Z��� D //''�� �jjQi111A�` 11C/QCT f n 2018 Submit Form and
�orm lb 3Revised 4/2077 Approved applicati(��d�¢g2� t s Prov JiL ,�U/Attac mems in Duplicate
/0_1; �I 1 ` 11 VV �'�Y7 AIII i_�
ConocoPhillips
Alaska
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
October 04, 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 High Expansion Wedge in KRU
2T-37 (PTD #195-101) in order to drill two CTD laterals using the coiled tubing drilling rig, Nabors CDR3-AC.
Attached to this application are the following documents:
— 10-403 Sundry Application for KRU 2T-37
— Operations Summary in support of the 10-403 sundry application
— Proposed CTD Schematic
— Current Well Bore Schematic
If you have any questions or require additional information, please contact me at 907-263-4321.
Sincerely,
4th Herring
ConocoPhillips Alaska
Coiled Tubing Drilling Engineer
KRU 2T-37 (PTD #195-101) CTD Summary for Sundry
Summary of Operations:
KRU well 2T-37 is a Kuparuk A -Sand producer equipped with 3-1/2" tubing and 7" production
casing. The CTD sidetrack will utilize two laterals to target the A -sands to the south and west
of 2T-37. The laterals will recover resource to the south that has been hydraulically
suppressed and recover production to the west from the long-term shut-in producer 2T -38A.
CDR3-AC will set a mechanical whipstock (High Expansion Wedge) inside the 7" casing at
the planned kick off point of 10,720' MD. The 2T-371_1 lateral will exit through the 7" casing at
10,720' MD and TD at 13,600' MD, targeting the A sand to the south. It will be completed
with 2-3/8" slotted liner from TD up to 10,800' MD with an aluminum billet for kicking off the
2T-371-1-01 lateral.
The 2T-371-1-01 lateral will drill to a TD of 14,900' MD targeting the A sand to the west. It will
be completed with 2-3/8" slotted liner from TD up into the 3-1/2" tubing at 10,620' MD with a
deployment sleeve.
CTD Drill and Complete 2T-37 Laterals: November 2018
Pre -CTD Work
1. RU Service Coil: Mill out "D" nipple and conduct fill cleanout.
2. RU Slick -line: Obtain SBHP and conduct dummy whipstock drift.
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. 2T-371_1 Lateral (A3 sand - South)
a. Set top of high expansion wedge at 10,720' MD ) y
b. Mill 2.80" window at 10,720' MD.
c. Drill 3" bi-center lateral to TD of 13,600' MD.
'^'
d. Run 2%" slotted liner with an aluminum billet from TD up to 10,800' MD. ? T�
3. 2T-371_1-01 Lateral (A4 sand -West)
a. Kick off of the aluminum billet at 10,800' MD.
b. Drill 3" bi-center lateral to TD of 14,900' MD.
c. Run 2%" slotted liner with deployment sleeve from TD up to 10,620' MD.
4. Obtain SBHP, freeze protect, ND BOPE, and RDMO Nabors CRD3-AC.
Post -Rig
1. Return to production
Page 1 of 1 10/4/2018
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KUP PROD 2T-37
Alaska. Inc.KUPARUK
COflOCOPhillipsW01S-SSV!NIPPLE
Well gttribuis6 Max An Io&MD TD
Fee Name WelWore P%IUYA We11W Status x11'1 NO'Hd, Acl Sea THE01
RIVERUNR 501032022100 P00D 7.30 3,400.00 11,080.0
cWbn EM Date KB�GN InI RqRekarotae
50 1111112014 last WO: 811311995
ZT-37.A7OO 70N37AM
Last Tag
Vedialedisse. caul)
App.ionEnd DNe neplb(NI(BI IaatMW By
Last Tag: RKB(Eat. 15' of Fill, LeaNng 5' of Open Pads) 91612018 zembaej
RANGER, aha
CONDJCTOR: e10,111 o
NIPPLE. bap
.AEOPT 2.181.3
SURPACE;,tU1Raa
GAaUR:a.30.7
Gets LIFT: 7 e0a3
UPr; SE12.s
CAS UFT Saari
wa UR lo,vze
NIPPLE: IO.Wa
AxcxoR. 10.59Aa
PACKER', m.5n.3
MPPLB'. ma13.4
SOS, maN T
PPPRE 10,a15010,e9R0
GBAIJ.rap EEE', IO.iiiS0
aha
IPEXF; 1072D.6IOYNO.0-
FISH; meaz.p
PROMOTION SSFET UdEse
--
Last Rev Reason
lDale
E16
ReVR leE1MM By
Rev Reotason: Updated Tag Depth >/62018 zembaej
Casing Strings
Casing11-nini OD frit ID (int TOP(NKDI $el De DhMKBI aN Dr, 'r RVpH, WHlan(I... Grade Top Thread
CONDUCTOR 16 1506 41.0 1210 121.0 62.58 H-00 WELDED
Casing 0eecrieion - I IDpnI Top@KBI SM--l.KBI ael Oeprt-I._-11 g...Gmda In"Trieed
SURFACE 9518 8.83 41.4 4,145.3 24889.7 40.00 L410 BTC
Casing Description OB(in) IOlinj TOp Inst, Sd.pron Mo.) ael Lsi 0 MILY., WOLen B...Grad¢ rep Thread
PRODUCTION 7 6.20 387 11073,6 6.065.9 2600 L-80 BTCMi
Tubing Strings
Tnbmg Desanpnnn String Ma... ID lm1 Top(i set Idi ln..set DeP11121011-. Wlnblll) Greae Top Connection
TUBING 3112 2A9 36.fi 10,625.6 5780.3 930 L-80 ABM-EUE
Completion Details
IDplNol Topina Nomtom
Top(nxal (nxD 1'I uem Dee Cam NO(in)
36.6 36. 0.00 HANGER EMC GEN IN TUBING HANGER 3.500
505.0 504.8 1.61 NIPPLE CANDO DS LANDING NIPPLE, 2.856' NO GO 2,812
10,588.3 5,757.4 52.50 NIPPLE CANDO W-1 SELECTIVE LANDING NIPPLE 2.812
10,596.4 5,762.0 $2.36 AN H R KANCHOR, RUN WITH PACKER 2.992
10,597.3 5,762.9 52.3 A ER BAKER SABI PERMANENT PACKER (SEAL ATTACHED) 3.250
10,613.0 5,712.8 51.99 NIPPLE CASCO D LANDING NIPPLE, 2.795- NO GO 2750
10,6243 5779.8 5170 SOS BAKER SHEAR OUT SUB, ELMD TTL @10620'during SINS 3.015
PERE on 09126/95
Other In ole (Niireline retrievable plugs, valves, pumps, fish, etc.)
Tap(ND
Top(FEE) TIKE)
Top Incl
N
Dee Com
Run dale
ID(in)
10982.0 6.UtJ
49.95
FISH 1112" DMY00RKLadh Dropped In Ratbole9/2311995
9/23/1995
Perforations & Slots
Tn Ma.,
eM(nion
Btirf"N
fees)
unxedzone
Data
aba
Oen
Proper
I
Type
Com
lci
10,6900
EIftKrBj
5.825)
C -42T-37
Wago1
4.0
APERF
SQUEEZED CLOSED
6I3000mGAS
1 .-7M0
107400
5,852.2
A -G, 2T-3]
9,1611995
4.0
[PERE
Orientedof h leg.2]D deg. f/
lowsitle of hole
Frac Summary
End, OMe proppanl designetl lib) Prop pant In Forma11an 1101
Slgp Stan Date Top Oaplb Epto I ponoal I LNklo n a.ci System VOI Clean (bbl VOI Slurryfbbll
Cement Squeezes
T,7 -,.T.-.-,.,7 mI T(Hin DI
DIm fNO)
InKBI
Des TZ"DeM
Gam
146750 Teti 5,8172
5,825.1Cement5queeze
6130200]
C,bANDSOUEEZE-MILLEDTO10788'W2./C
BIT
Mandrel Inserts
.0
Tap(1VOI Wait Won Port Stu TRO Run
N TOP MKS) MKS) Mahe Spot dollar Sent Tyce Type III (peg Run Order Can
2,ISO 3 2. CASINO MMM 1112 GAS LIFT GL RK 0.250 1.295.0 412012004
5,347.7 3,401.0 CANDO MMM 112 GAS LIFT GLV RK 0.250 1,2940 4/2012004
3 7406 4,306.7 CASINO MMM 1112 GAS LIFT GLV RK 0.250 1.2870 4/2012004
4 8,712.5 SK5,5 CASING MMM 112 GAS LIFT GLV RK 0. 50 1,276.6 4/2012004
5 9,737.3 5.303.9 CAMCO MMM l 12 GAS LIFT OV RK 0.188 0.0 11201997
6 10,542.8 5,7301 CAMCO MMM 1112 GAS LIFT DMY RK 0000 00 1117/2010
Notes: General & Safety
End Ogre Momanan
211412003 NOTE: UNABLE TO GE -GUNS DOWNH LE-4140"MAX DEPTH
911312011 NOTE: View ScnemaliC wl Alaska SChematri
71232012 NOTE: NOT ABLE TO PULL OV AT 9737 AFTER MANY ATTEMPTS
Pages NOT Scanned in this Well History File
XHVZE
This page identifies those items that were not scanned during the initial scanning project.
They are available in the original file and viewable by direct inspection.
/~----~'"'/(~/ File Number of Well History File
PAGES TO DELETE
RESCAN
Complete
Color items - Pages:
Grayscale, halftones, pictures, graphs, charts -
Pages:
Poor Quality Original - Pages:
[] Other- Pages:
DIGITAL DATA
[] Diskettes, No.
[] Other, No/Type
OVERSIZED
[] Logs of various kinds
[] Other
COMMENTS:
Scanned by: Beverly Diann~than Lowell
TO RE-SCAN
Notes:
~si
Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: Isl
•
ConocoPhillips
a
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
•
July 16~, 2010
Commissioner Dan Seamount
Alaska Oil & Gas Commission
333 West 7~ Avenue, Suite 100
Anchorage, AK 99501
Commissioner Dan Seamount:
pM~ska Ui! & 68s Cam. C~mssion
Anctra~age
q5-log
a7-37
Enclosed please fmd a spreadsheet with a list of wells from the Kuparuk field (KRL~. 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 11~', 12~', 13~` 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,
~~
Perry Klein
ConocoPhillips Well Integrity Projects Supervisor
• •
ConocoPhillips Alaska Inc.
Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off
Report of Sundry Operations (10-404)
Kuparuk Field
Date 7116110 2T_ 3H PAD
Well Name
API #
PTD #
Initial top o
cement
Vol. of cement
um ed
Final top of
cement
Cement top off
date
Corrosion
inhibitor Corrosion
inhibitor/
sealant date
ft bbls ft al
2T-22 50103202240000 1950860 8" Na 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" Na 22" Na 2.5 7M1/2010
2T-38A 50103202290100 1972050 8" n/a 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" n/a 5.1 7/12/2010
2T-217A 50103203340100 2000740 8" n/a 8" Na 1.7 7/12/2010
3H-13A 50103200890100 1961970 SF n/a 22" n/a 3.8 7/11/2010
Message
.
.
Page 1 of 1
Maunder, Thomas E (DOA)
From: Maunder, Thomas E (DOA)
Sent: Tuesday, August 28, 20074:21 PM
To: 'Peirce, John W
Cc: Allsup-Drake. Sharon K
Subject: RE: 404 2T -37 (195-101)
Thanks John. The new requirement in the statute is now 45 or 60 days (I can't remember which) on getting
reports in after work is completed. We haven't gotten this incorporated in the regulations yet, but the time
extension should help situations like this. I think it is most important to be as accurate as possible, so waiting on
the drawing should not be a problem.
Call or message with any questions.
Tom Maunder, PE
AOGCC
From: Peirce, John W [mailto:John.W.Peirce@conocophillips.com]
Sent: Tuesday, August 28, 2007 9:05 AM
To: Maunder, Thomas E (DOA)
Cc: Allsup-Drake, Sharon K
Subject: RE: 404 2T-37 (195-101)
Tom,
Attached is an updated post-squeeze well schematic for 2T-37 showing the C sand perf interval has been
squeezed off. The schematic was recently revised but probable not available when we started putting the Report
Sundry together. In the future we can either delay sending Report Sundries until we have the updated schematics
from the Slope, or we can send a Sundry soon as possible and follow up with an updated schematic when we get
it. Schematic update timing is hard to predict but we usually get our updates within a few weeks of work being
done on a well. The upper C-4 perfs are squeezed off (not A-4), and the lower A-3 perf interval remains open as
reported on the 10-404 form.
Regards,
John Peirce
Wells Engineer
CPAI Drilling & Wells
(907)-265-6471
-----Original Message-----
From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov]
Sent: Monday, August 27, 2007 4:52 PM
To: Peirce, John W
Subject: 404 2T-37 (195-101)
SCANNED AUG 2 9 2007
John,
I am reviewing the 404 you submitted for squeezing perforations. Based on the operations summary and
the RKB depths given. does the drawing need revision? Based on the RKB depths given, aren't the upper
set of perforations (A-4) now squeezed off?
Call or message with any questions. look forward to your reply.
Tom Maunder, PE
AOGCC
8/28/2007
· RECEIVED
STATE OF ALASKA. AUG 2 0 2007
ALASKA Oil AND GAS CONSERVATION COMMISSION . . n
REPORT OF SUNDRY WELL OPERA TIONiøska Oi\ & Gas Cons. commlsSlO
1. Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 , Stimulate 0 Other ~\I"'Lj' ..~-
Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0
Change Approved Program 0 Operat. ShutdownD Perforate 0 Re-enter Suspended Well 0
2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number:
ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 195-1011
3. Address: Stratigraphic 0 Service 0 6. API Number:
P. O. Box 100360, Anchorage, Alaska 99510 50-103-20227-00
7. KB Elevation (ft): 9. Well Name and Number:
RKB 41', Pad 81' 2T-37 /
8. Property Designation: 10. Field/Pool(s):
ADL 25568,' ALK 2666 Kuparuk River Field 1 Kuparuk Oil Pool /
11. Present Well Condition Summary:
Total Depth measured 11 080' / feet
true vertical 6067' / feet Plugs (measured)
Effective Depth measured 1 0940' feet Junk (measured) dummy @ 10982'
true vertical feet
Casing Length Size MD TVD Burst Collapse
Structural
CONDUCTOR 121' 16" 121' 121'
SUR. CASING 4023' 9-5/8" 4145' 2887'
PROD. CASING 10952' 7" 11074' 6063'
Perforation depth: Measured depth: 10720'-10740' 5CANNED AUG 2 1) 2007
true vertical depth: 5837'-5850'
Tubing (size, grade, and measured depth) 3-1/2" , L-80, 10625' MD.
Packers & SSSV (type & measured depth) pkr= BAKER SAB-3 PERM. @ 10597'
Cameo 'OS' nipple @ 505'
12. Stimulation or cement squeeze summary:
Intervals treated (measured) 10675'-10698' MD
Treatment descriptions including volumes used and final pressure: 25 bbls total pumped 1 2 bbl behind pipe /
13. Representative Daily Average Production or Injection Data
Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubina Pressure
Prior to well operation SI --
Subsequent to operation SI --
14. Attachments 15. Well Class after work:
Copies of Logs and Surveys run _ Exploratory D Development o ./ Service 0
Daily Report of Well Operations _X 16. Well Status after work:
Oil0 ' GasD WAG 0 GINJD WINJD WDSPL 0
17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt:
none
Contact John Peirce @ 265-6471
Printed Name John peirce~.. Title Wells Group Engineer g{z..o/o 7
Signature 4' ~ tJ': .___ -- Phone: 265-6471 Date
Prenared bv Sharon AI/sun-Drake 263-4612
Form 10to4 Revised 04116 RBDMS BFL Ave 2 9 2 /ß' 8'. z.'f.C'7
Submit Ori inal Onl
ORIGINAL
~1~
g y
~..K ~~7'¡{,/
.
2T-37 Well Events Summary
.
DATE Summary
06/03/07 Pump 25 slurry containing 5,310 Ibs 20/40 sand, 33 bbls S/W & 32 bbls Diesel. Attempt to
put TOS at 10,709 ft.
06/05/07 TAGGED SAND PLUG @ 10720' RKB (UNABLE TO lOCATE JEWELRY FOR
CORRECTION, USED 30' CORRECTION FROM 4/21 CAL lOG).
06/09/07 JOB SHUT DOWN FOR HIGH WINDS
06/10/07 BRUSH & FLUSH TBG FROM 9083' WLM, TAGGED SAND PLUG @ 10683' WlM, IN
PROGRESS
06/11/07 TAGGED TOP OF SAND PLUG @ 10731' RKB
06/27/07 RIH with 2.79 Nozzle, Tagged D-nipple @ 10572 CTMD, Obtained corrected measured
depth of TOS goal of 10668 CTMD. POOH switch to 2.2 Sand dump nozzle, Tagged TOS
@ 10676 CTMD, Pumped 250 Ibs sand, Tagged TOS @ 10673 CTMD ( RKB 10714).
RDMO.
06/28/07 RIH to 10663 CTMD, Pumped 25 bbl cement batch, Squeezed Well @ 3000 psi, Held
steady for 30 min, RIH with Biozan to flush out leftover cement, Tagged hard @ 10656
CTMD, POOH, Will run underreamer in A.M.
06/29/07 RIH with down jet nozzle, Attempt to clean out mandrels & remaining cement. POOH,
Install Baker Under-reamer, Tagged hard @ 10675 CTMD (10713 RKB), Drilled out 4 ft
with 30 stalls, POOH, under-reamer in good condition, Will attempt again in A.M.
06/30/07 RIH with Baker under-reamer, 25 stalls drilled 1ft, POOH, Installed 2.74 Junk Mill, Milled
through cement/sand interface, Cleaned out Well to 10788 RKB, F/P Well with 45 diesel.
(Job Complete)
07/17/07 DRIFTED TBG WITH 10' x 2-1/8" STEM. TAGGED @ 10758' RKB, EST. 48' RATHOLE.
.
.
KRU
2T -37
ConocoPhillips Alaska, Inc.
~
Well TVDe: PROD
Orig 8/13/1m5
Comoletion:
Last W/O:
!
Reference Loa: : Ref Loa Date:
Last Taa: 10774 : TO: 11080ftKB
~ 7/1712007 I Max HOle,-3434
.: . ~ Size Ton Rnrtnm TVD WI Gorade ",read I
:' , CONDUCTOR 16.000 0 121 121 62.58 I H-40 --1
SUR. CASING 9.625 0 4145 2887 40.00 I L-80 .
PROD. CASING 7.000 0 11074 6063 26.00 T L-BO !
¡ ;jj '; " ;Jih . ·~~~:gh1ffmi5ij]~IªUUl:jffifu.J~t~mrr:1¡mfl!;'~:~:!;~~¡~~~:mm:~;::~~h1:1ii~¡:~:;þ'1::~:!;::!i;:f~¡~!~ ~~~ªg1=~~:.~:~:¡:~~::)~!~:~~~1
.. Size I Tno Bottom TVD WI Grada Thread --J
:. . .:. 3.500 I 0 I 10625 I 5777 9.30! L-BO I ABM-EUE !
'1 . !" ,.. "I"'~' .~ ..- ':......-...... . _.. ,...,. .",.. .... ~ t. ~m.':·. ".~.."... ... - ........ ....... . .:::::'0:,':::::''1. ',:::1 .¡:I.U "I' ,-, ~~. . .::::.
0' . , ~, .., _. . .~ ',. ...;~*:::,..:.::.., ..... . ... ",........ __.._ .. , . .~. ..·.:.¡r.¡I, ':'" "-r"" ......., ..... ..0 "',
I IntaIVal TVD Zone Status I FI SPF Date Tv.... Comment ,
I 10675 - 10698 5809 .. 5823 C-4 C: 23 0 6/30/2007 Soz
10720-10740 5837-5850 A·3 120 4 9/26/1m5 ¡PERF Oriented 90 deg. 270deg fl
¡, .þ 1~!ï~1 ......; 1 '~8'" -¡¡i!~~¡fJ~;;~;;i!,¡¡¡~::¡;'F~;¡I:j¡;\rj~¡~¡¡:¡¡¡:ë '~-:;:~H¡:f,~!þ'¡¡¡:!J¡ii!~~W~~:;::~~¡~¡~;;;~¡~:~l::=~:~¡.:ü.q¡þ'~:~
~ 6/30/2007 IC-SAND SOU T
~ I Man Mfr Man Type fr ype Lateh T e un VIv
Gas lIft Cmnl
,ndrellDummy ii 1 2194 2008 Cameo MMM GLV 1.5 RK 0.250 1295 412012004
(871;~~34 ., . 2 5348 3398 Cameo MMM GLV 1.5 RK 0.250 1294 412012004
0(6018) 3 7406 4303 Cameo MMM GLV 1.5 RK 0.250 1287 412012004
4 8712 4852 Cameo MMM GLV 1.5 RK 0.250 1276 4/2012004
5 9737 5301 Cameo MMM OV 15 RK 0.188 0 4/2012004
M:::~-- ,III ,:-:0543 ~7,¡~~=~1¡J¡:MM ~ ,gJ¡~~Ji¡¡:~~~~!¡;¡~~df~;~~¡;;~:¡t~l¡~~~~~l~¡¡¡¡!~J¡~~::m:"~~~~i~::~,fu:'::I~~;::;
. 505 505 NIP Cameo'DS' NiDDle NO GO 2.812
10588 5755 NIP Cameo W-1' Selective Larlding Npple 2.812
10597 5760 PKR Baker SAB-3 Delm. 3.250
.. 10613 5770 NIP Cameo '0' Nioole NO GO 2.750
: 10625 5777 SOS Baker 2.992
.' ., 10626 5778 TTL ~
IIDj~: ~
~.; . DescrlDtlon Comment
1 0982 [ 1 1/2· DMY on RK Letch I DreoDed in Ralhole 9/23/1995
API: 501032022700
SSSV Type: Nipple
I
I
I
Anole /â) TS: 51 dea (iiJ 10672
Angle @ TO: 50 deg @ 11080
NIP (505-506,
OD:3.5(0)
[]
Annular Fluid:
Rev Reason: TAG. C-SAND
saz & MILL
Last Uooele: 8/1412007
Gas l~
MandmWah...
1
(2194·2195.
Gas un
MandreWalva
2
(5348-5349,
Goslin
MandreWalva
3
(7406-7407.
GosLin
1 ndreUDumm'l
Valva 6
10543·10544,
OD6016)
NIP
10586-105119
00 3 500)
PKR
10597·10596.
00:6.151)
....,.,.,.
,;: "
!:. no
."" ...;,
NIP U
10613·10614,
O(3500)
'TUBING
jO-IOB25. ..
00:3.500,
D2.992)
50S
'10625-10626. '---
00:3.5(0)
G-SANO I' .. ~1
SQUEEZE
10675-10698) -. -
Perf ""--
10720-10740) _._~. -- '--
- .. ---
".-.-- ._-~.
0
-_...
__H__'
jC,:s- -IOf
ScbllulI~epgep
NO. 4343
1\/EfJ
Schlumberger -DCS
2525 Gambell Street, Suite 400
Anchorage, AK 99503-2838
A TTN: Beth
dUL 3 0 2007
Company:
Alaska Oil & Gas Cons Comm
Attn: Christine Mahnken
333 West 7th Ave, Suite 100
Anchorage, AK 99501
Alaska Oil &. Gas Coos. Commission
Anchorag(~ sCANNED AU G 0 1 2DD7
Field:
Kuparuk
Well
Job#
Log Description
BL
Color
CD
Date
1H·08 11850414 INJECTION PROFILE 07/23/07 1
2L-327 11665460 SBHP SURVEY 07/21/07 1
2M-28 11850413 PRODUCTION PROFILE 07/22/07 1
2M-32 11850415 GLS 07/24/07 1
2P-448A 11850403 SBHP SURVEY 07/21/07 1
1 H-03 11632739 INJECTION PROFILE 07/23/07 1
2T-37 11632740 PRODUCTION PROFILE 07/24/07 1
2H-14 11632738 PRODUCTION PROFILE 07/22/07 1
.
t6 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you.
07/27/07
.
.
.
.
WELL LOG
TRANSMITTAL
--.-.--, ¡.
ProActive Diagnostic Services, Inc.
To: AOGCC
Howard Okland
333 West 7th Avenue
Suite 100
Anchorage. Alaska 99501
(907) 659-5102
RE : Cased Hole/Open Hole/Mechanical Logs and / or Tubing Inspection(Caliper / MTT)
The technical data listed below is being submitted herewith. Please acknowledge receipt by
returning a signed copy of this transmittal letter to the attention of :
ProActive Diagnostic Services, Inc.
Attn: Robert A. Richey
130 West International Airport Road SCANNED APR 2 5 2007
Suite C
Anchorage, AK 99518
Fax: (907) 245-8952
1 )
2)
3)
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1 Report / EDE2T - 37
Caliper Report
22-AprD7
I C?S--/ of
.:tt ( Sõ0 ;;;)
RECEI\/ED
Signed:
_C,.J)~
~h ~e.. V\1l~1A.1,Lpp\"
Date :
~ Oil & Gas COOs. Commission
A~
APR 2 5 2007
Print Name:
PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518
PHONE: (907)245-8951 FAX: (907)245-8952
E-MAIL: ?DSANCHORßI.GE@MEMCRYLOG.COM
WEBSITE : 1NtI\iW.MEMORYLOG.COM
D:lMaster _Copy _00 ]DSANC-2OxxIZ _ W ordlDistribution\Transmittal_ Sheets\Transmit_ OriginaL doc
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Memory Multi-Finger Caliper
Log Results Summary [Revised)
Company:
Log Date:
Log No. :
Run No.:
Pipe1 Desc.:
Pipe1 Use:
ConocoPhillips Alaska, Inc.
April 22, 2007
6166
1
3.5" 9.3 lb. L-80 EUE
Tubing
Well:
Field:
State:
API No.:
Top Log Intvl1.:
Bot. Log I ntvl1.:
2T -37
Kuparuk
Alaska
50-103-20227-00
Surface
10,605 Ft. (MD)
Inspection Type:
COMMENTS:
Co«osive & Mechanical Damage Inspection
This caliper data is tied into the Hanger @ 0' (Drillers Depth).
This log was run to assess the condition of the 3.5" tubing with respect to internal corrosive and mechanical
damage.
The recordings indicate the 3.5" tubing is in good to fair condition with respect to corrosive damage, with a
recorded maximum wall penetration of 33% in joint 305 at 9,650'. Penetrations ranging 20% to 33% are
recorded in 6 of the 349 joints logged. The damage appears mainly in the form of isolated pitting. No
significant areas of cross-sectional wall loss or 10 restrictions are recorded.
The recordings indicate a slight buckling ofthe tubing in the interval between 8,250' and 10,450'. No
significant 10 restrictions are recorded in this interval.
Cross-sectional drawings of the most significant events recorded are included in this report. The distribution
of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. A graph
illustrating the correlation of recorded damage to borehole profile is included in this report.
MAXIMUM RECORDED WALL PENETRATIONS:
Isolated Pitting
Isolated Pitting
Isolated Pitting
Isolated Pitting
Isolated Pitting
305 @
234.1 @
77 @
291 @
247 @
( 33%)
( 26%)
( 24%)
( 22%)
( 21%)
Jt.
Jt.
Jt.
Jt.
Jt.
MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS:
No areas of significant cross-sectional wall loss (> 9%) are recorded.
MAXIMUM RECORDED ID RESTRICTIONS:
No significant 1.0. restrictions are recorded.
9,650 Ft (MD)
7,390 Ft (MD)
2,433 Ft (MD)
9,214 Ft. (MD)
7,795 Ft. (MD)
I Field Engineer: D. Cain
Analyst: M. Tahtouh
Witness: C. Kennedy I
ProActive Diaonostic Services. P.O. Box 13691 Stafford. T)( 77497 0E C· EIVED
Phone: (281) or (888) 565-9085 Fax: 565-1369 E-mail: PDS@memorylog.cc:lñ'-
Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314
10 -S--IOf
tf-
/5ó0d
APR 2 5 Z007
~ 0/1 & Gas Cons. Commission
Anchorage
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PDS Repo Overview
Body Region Analysis
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Well:
Field:
Company:
Country:
2T-37
Kuparuk
ConocoPhìllìps Alaska, Inc.
USA
April 22, 2007
MFC 24 No. 21119
1.69
24
M. Tahtouh
Survey Date:
Tool Type:
Tool Size:
No. of Fingers:
Anal sl:
Nom.ID
2.992 ins
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Tubing: Nom.OD
3.5 ins
Weight
9.3 f
Grade & Thread
1.-80
Upper len.
6.0 ins
Nom. Upset
3.5 ins
Lower len.
6.0 ins
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Penetration and Metal Loss ('Yo wall)
Damage Profile ('Yo wall)
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penetration body
o
o
metal loss body
50
penetration body
metal loss body
100
300
250
200
150
100
50
o
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GLM 1
o to
1%
1 to
10%
10 to 20 to 40 to over
20% 40% 85% 85%
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o
o
pene.
loss
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GLM2
Damage Configuration ( body)
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40
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30
GLM 3
20
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10
GLM4
o
isolated general line ring hole / pass
pitting corrosion corrosion corrosion íble hole
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GLM 5
GLM6
Bottom of Survey 333.6
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Analysis Overview page 2
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Correlation of Recorded Damage to Borehole Profile
Pipe 1
3.5in (4.4'-10601.1')
Well:
Field:
Company:
Country:
Survey Date:
2T-37
Kuparuk
ConocoPhillips Alaska, Ine.
USA
April 22, 2007
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Approx. Tool Deviation
Approx. Borehole Profile
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50
11
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1539
GlM 1
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100
3125
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150 4694
Õ
GlM 2 ~
(l)
...0 .,..;
E LL
:;;¡ .£::
Z 200 6288 J::
..... 15.
c
0 (l)
0
GlM 3
250 7877
GlM 4
300 9470
GlM 5
GlM 6
333.6 10601
0 50 100
Damage Profile (0;., wall) / Tool Deviation (degrees)
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Bottom of Survey = 333.6
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PDS REPORT JOINT TABULATION SHEET
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Pipe:
Body Wall:
Upset Wail:
NominaILD.:
3.5 in 9.3 ppf L-80
0.254 in
0.254 in
2.992 in
Weil:
Field:
Company:
Country:
Survey Date:
2T-37
Kuparuk
ConocoPhí!lips Alaska, Inc.
USA
April 22, 2007
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Joint JL Depth F'en Pen. Pen ::,'¡;::Ial Min. Damag e Profile
No. (Ft.) Body LD. Comments (% wail)
Or) (Ins.) (Ins.) 0 50 100
.1 4 0 0.02 2.91 PUP
1 11 0 0.03 CJ 2.92
2 42 0 0.02 2.94
3 74 0 0.02 2.94
4 105 n 0.02 7 I ;; 2.93
5 136 0.02 ) 2.92
6 166 í 0.02 2.92
7 198 í 0.02 2.94
8 229 I 0.ü1 2.92
9 260 I 0.02 2.93
10 292 0 0.02 2.94
11 323 ( 0.02 2.93
12 354 1 0.02 9 ) 2.94
13 386 1 0.02 C) ) 2.94
14 415 i 0.02 q 2 2.92
15 446 i 0.03 n ) 2.93 Shallow nittino.
15.1 477 0 n N/A Nioole
16 479 0.ü1 I 2.95
17 510 0 0.02 I ) 2.93
18 541 0 0.02 1'1 I 2.95
19 570 0 0.03 1) ) 2.91
20 602 I 0.02 H ) 2.94
21 634 0.02 ) 2.94
22 665 0.02 2 2.93
23 696 1 0.02 ) 2.92
24 727 0.Q2 1 2.94
25 759 I 0.02 1 2.93
26 790 0 0.02 ) 2.94
27 821 0 0.03 11 1 2.94
28 852 I) 0.02 I) ) 2.93
29 884 ( 0.02 ) 2.94
30 915 ( 0.02 2 2.93
31 946 1 0.02 2.94
32 978 0 0.02 2.93
33 1009 0 0.03 2.93
34 1040 0 0.02 2.94
35 1069 0.02 2.93
36 1100 0.03 1 1 2.91
37 1132 0.Q2 q ) 2.94
38 1163 0.03 I) 1 2.93
39 1195 0.02 2.94
40 1226 í 0.02 2.93
41 1258 í 0.02 2.92
42 1289 í 0.02 2.92
43 1320 0 I n.o3 n 2.92 Lt. Denosi ts.
44 1352 0 0.02 2.92
45 1383 0 0.02 2.94
46 1414 0 0.02 ) 2.93
47 1446 n 0.02 ) 2.93
48 1477 0 0.02 ) 2.93
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Body
Metal Loss Body
Page 1
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PDS REPORT JOINT TABULATION SHEET
Pipe:
Body Wall:
Upset Wall:
NominaII.D.:
3.5 in 9.3 ppf L-80
0.254 in
0.254 in
2.992 in
Well:
Field:
Company:
Country:
Survey Date:
2T-37
Kuparuk
ConocoPhillips Alaska, Inc.
USA
April 22, 2007
Joint J1. Depth ¡'en. Pen. Pen. Me·¡al Min. Dam age Profile
No. (Ft.) e¡ Body 1.0. Comments (%wall)
) (Ins.) (Ins.) 0 50 100
49 1508 U 0.02 2 2.92
50 1539 U 0.02 2 2.92
51 1571 0 0.02 1 2.93
¡
52 1602 I 0.01 2 2.91
53 1633 0.ü3 2 ¡ 2.93
54 1664 0.03 II 2 2.91
55 1694 ( 0.02 U 2 2.94
56 1726 I 0.03 10 I 2.92
57 1757 0 0.ü3 0 I 2.91
58 1789 0 0.02 2 2.93
59 1819 0 0.03 I 2 2.91
60 1851 0 0.02 2 2.92
61 1882 0 0.03 0 I 2.93
62 1913 0 0.03 0 2.92
63 1945 I 0.01 6 2.91
64 1977 ¡ 0.01 5 2.92
65 2008 0.02 7 2.92
66 2039 0.02 7 2.91
67 2071 U 0.02 9 I 2.93
68 2102 0 0.02 7 2.92 ÆIß
69 2132 0 0.02 B 2 2.92 r
69.1 2163 0.03 II 5 2.89 PUP Lt. Deoosits. r
69.2 2169 0 0 0 N/A GLM 1 (Latch @ 4:00\
69.3 2178 0.02 9 2 2.83 PUP Lt. Deoosits.
70 2184 0.01 5 I 2.91
71 2215 0 0.02 8 2 2.91
72 2247 0 0.02 7 I 2.92
73 2278 0 0.03 12 2 2.92 Shallow oittinQ.
74 2309 0 0.02 2.90
75 2340 0 0.03 13 2.89 Shallow pittinQ.
76 2372 0 0.02 2.93
77 2403 0 0.06 24 2.90 Isolated oittinQ. Lt. Deoosits.
78 2434 0 0.02 ') 2.91
79 2466 0 0.03 I 2 2.90
80 2497 0 0.03 2.91
81 2529 () 0.ü3 2 2.92
82 2559 0 0.04 2 2.92 Shallow oitting.
83 2591 I 0.02 1 2.90
84 2623 0 0.01 2 2.92
85 2654 () 0.04 14 2 2.90 Shallow pittim<. L1. Deoosits. II
86 2686 U 0.03 10 I 2.89
87 2717 () 0.02 8 2 2.91
88 2748 C 0.02 I 2.90
89 2779 () 0.01 I I 2.93
90 2811 () 0.02 2 2.90
91 2842 0 0.04 1'> 2 2.84 Shallow pittim:!. Lt. Denosits.
92 2874 () 0.02 8 2 2.92
93 2905 0 0.03 12 2 2.89
94 2936 [) 0.02 a I 2.93
95 2968 0 0.02 7 2 2.90
Penetration Body
Metal Loss Body
Page 2
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PDS REPORT JOINT TABULATION SH
Pipe:
Body Wall:
Upset Wall:
NominaII.D.:
3.5 in 9.3 ppf l-80
0.254 in
0.254 in
2.992 in
Well:
Field:
Company:
Country:
Survey Date:
2T-37
Kuparuk
ConocoPhillips Alaska, Inc.
USA
April 22, 2007
joint jt. Depth Pen Pen. Pen. Vleíal Min. Dam age Profile
No. (Ft.) Body 1.0. Comments (%wall)
) (Ins.) (Ins.) 0 50 100
96 2999 U 0.01 2 2.90
97 3030 0.02 2 2.89 I. t. Deposi is.
98 3061 0.01 1 2.92
99 3093 0.03 ¡ ;; 2.91
100 3125 0.03 10 ., 2.85
j
101 3157 I 0.02 II 2 2.91
102 3187 0 0.03 12 I 2.84
103 3219 U 0.02 2 2.90
104 3250 0 0.03 2 2.87
105 3282 ( 0.02 -¡ 2.90
106 3313 I 0.02 1 2.91
107 3344 0.02 ;; 2.88
108 3376 0.02 2 2.92
109 3407 0.02 1 2.92
110 3438 0.02 ß 2 2.88
111 3470 0 0.02 9 1 2.90
112 3501 0 0.02 q 2.92
113 3533 0 0.03 10 2 2.89
114 3564 0 0.01 2 2.86
115 3596 0 0.02 2 2.90
116 3627 () 0.03 I) ;; 2.89
117 3659 0 0.02 ß 1 2.92
118 3688 0 0.03 2 2.89
119 3721 0 0.02 1 2.92
120 3752 0 0.02 2 2.92 :
121 3783 0 0.02 2 2.93
122 3814 0 0.02 I 2.89
123 3847 0 0.03 12 i 2.91
124 3878 ( 0.02 B I 2.92
125 3908 0 0.02 9 2.87
126 3940 0 0.01 6 2.90
127 3972 0 0.02 6 2.89
128 4003 0 0.02 6 2.88
129 4035 ( 0.03 0 ;; 2.89 Lt. Deposits.
130 4066 0 0.02 2 2.89
131 4098 0 0.02 2 2.91
132 4128 0 0.02 2.86 Lt. Deposits.
133 4160 0 0.02 2.91
134 4191 0 0.02 2.91
135 4222 0 0.03 11 2.86
136 4254 0 0.03 10 2.87
137 4286 0 0.02 I 2.93
138 4316 0 0.03 2 2.90
139 4348 0 0.02 2 2.91
140 4380 0 0.02 I 2.88
141 4412 () 0.02 ¡ 2.92
142 4442 0 0.02 2 2.89
143 4474 0 0.02 ß ;; 2.91
144 4505 0 0.02 ß 2 2.90
145 4536 ( 0.01 6 1 2.87
Body
Metal Loss Body
Page 3
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PDS REPORT JOINT TABULATION SHEET
Pipe:
Body Wall:
Upset Wall:
NominaIID.:
3.5 in 9.3 ppf L-80
0.254 in
0.254 in
2.992 in
Well:
Field:
Company:
Country:
Survey Date:
2T-37
Kuparuk
ConocoPhillíps Alaska, Ine.
USA
April 22, 2007
Joint JL Depth Ppli. Pen. ¡'eli. Meidl Min. Damag e Profile
No. (Ft.) psel Body LD. Comments (% wall)
0:) (Ins.) (Ins.) 0 50 100
146 4568 0 0.02 9 2.90
147 4600 0 0.02 9 ) 2.89
148 4632 0 0.02 ß ) 2.81
149 4663 0 0.ü2 I 2.87
150 4694 0 0.02 1 2.86 11II
1
151 4725 I 0.ü2 ( ;: 2.88 I"
152 4757 t) 0.02 2 2.87 II!!
153 4789 0 0.02 ;: 2.89 !II!
154 4820 0 0.02 ;: 2.89 II!!
155 4851 0 0.02 4 2.89
156 4883 0.02 1 2.87
157 4915 0.03 ¡ 'I 2.87 Shallow pittirm.
158 4946 I 0.ü3 ' I) 2.90
159 4977 ( 0.02 ß 2.90
160 5009 0 0.02 ß 2.89
161 5040 () 0.02 2.89
162 5072 0 0.03 10 ¡ 2.91
163 5103 0 0.02 ( ) 2.89
164 5135 0 0.02 ( 2.90
165 5167 0 0.02 ß 2.92 II!!
166 5198 0 0.ü2 9 2.88 Lt. Deoosits. II!!
167 5229 0 0.03 2.90 IfII
168 5261 0 0.02 2.91 II!!
169 5292 0 0.ü2 ;: 2.92 II!!
169.1 5324 0.02 ., 2.92 PUP I
1
169.2 5330 ( 0 0 N/A GlM 2 (Latch @ 1 :00)
169.3 5338 ( 0.02 ( 2.92 PUP
170 5344 ( 0.02 ß 1 2.89
171 5376 ( 0.03 11 I 2.88
172 5407 0 0.02 1 2.88
173 5438 ( 0.02 ;: 2.87 :III
174 5470 0 0.03 ) , 2.88 IfII
¡
175 5502 0 0.02 ;: 2.83 Lt. Deoosits. III
176 5533 U 0.02 1 2.87 11II
177 5565 I 0.02 1 2.88 !!II
178 5596 0.03 ) 3 2.86 !II!
179 5627 0.02 ( 2.88
180 5659 0.02 7 2 2.82 Lt. Deposits.
181 5690 0.03 II I 2.88
182 5722 () 0.02 ;: 2.85
183 5753 0 0.02 ;: 2.83 Lt. Deoosits.
184 5784 ( 0.02 2.87 !!II
185 5816 ( 0.02 2.88 !II!
186 5847 I 0.Q1 2.89 II!!
187 5879 ( 0.02 2.87 1!11'
188 5909 0 0.03 U 2.88 1!11'
189 5941 0 0.02 q 2.90 II!!
190 5973 U 0.03 1 ;: 2.90 !II!
191 6004 U 0.02 I 2.89 !II!
192 6035 0 0.02 ;: 2.89 IfII
Body
Metal Loss Body
Page 4
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PDS REPORT JOINT TABULATION SHEET
Pipe:
Body Wall:
Upset Wall:
NorninaILD.:
3.5 in 9.3 ppf L-80
0.254 in
0.254 in
2.992 in
Well:
Field:
Company:
Country:
Survey Date:
2T-37
Kuparuk
ConocoPhìllips Alaska, Ine.
USA
April 22, 2007
Joint Jt. Depth Pen Pen. Pen Melal Min. D amage Profile
No. (Ft.) Body !.D. Comments (%wall)
) (Ins.) (Ins.) 0 50 100
193 6067 0 0.02 (I 2.88
194 6098 0 0.03 11 2.86
195 6130 0 0.ü3 IJ 2.86 Shallow Díttínll.
196 6161 0 0.03 ~J 2.86 Shallowpi tting.
197 6193 0 0.02 [) 2.87
198 6224 0 0.03 12 2.84
199 6256 0 0.01 t 2 2.88
200 6288 0 0.02 I 2.90
201 6319 0 0.02 4 2.89
202 6351 [) 0.01 I 2.90
203 6382 (I 0.03 11 2.89 ,
204 6414 0 0.02 (I 2.89
205 6445 0.02 (1 ) 2.89
206 6477 0.03 10 2.89
207 6508 0.02 (I 1 2.89
208 6540 ( 0.03 í2 2 2.84 Lt. Deposits.
209 6571 0 0.03 II 2 2.86 Slight bend lower body.
210 6603 0.02 q 2 2.82 Lt. Deposi ts.
211 6634 0.03 J2 ~¡ 2.84 Lt DePosits.
212 6666 0.03 1 2 2.87 Lt. DePosits.
213 6697 ( 0.02 2 2.82 Lt. DeDosits.
214 6728 ( 0.02 2 2.87
215 6760 0 0.03 2.85
216 6791 0 0.03 10 2.84
217 6822 0 0.03 I 2.89
218 6854 0 0.02 !3 2.90
219 6886 ( 0.ü3 I 2.90
220 6917 ( 0.03 ) 2.89 Lt Deposits.
221 6949 I 0.02 1 2.83
,
222 6980 0.02 2 2.87
223 7012 I 0.02 2 2.86
224 7043 0 0.03 2 2.84
225 7075 0 0.03 2.86
226 7106 0 0.02 B 2.85
227 7137 0 0.02 [) 2.87
228 7169 0 0.03 10 2.88
229 7200 0 0.03 11 2.89
230 7231 JL 0.03 11 2 2.88
231 7263 0 0.02 ( 2 2.85
232 7295 0 0.02 1 2.84 II
233 7325 0 0.05 HI I 2.88 Shallow Ditting.
234 7355 0 0.04 15 2 2.86 Shallow pitting. M
234.1 7386 .0 16 0.07 )6 5 2.92 PUP Isolated píttirm.
234.2 7391 0 0 N/A GlM 3 (Latch @ 11 :00)
234.3 7401 0.02 (I ! 2.93 PUP
235 7407 ( 0.02 2 2.89 "
236 7438 I 0.02 2 2.85 "
237 7470 0 0.02 2 2.85 L t Deposi ts. II
238 7501 0 0.03 11 2 2.83 U. Deposits.
239 7532 0 0.04 5 I 2.88 Shallow pitting.
Body
Metal loss Body
Page 5
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PDS REPORT JOINT TABULATION S EET
Pipe:
Body Wall:
Upset Wall:
NominaIID.:
3.5 in 9.3 ppf 1.-80
0.254 in
0.254 in
2.992 in
Well:
Field:
Company:
Country:
Survey Date:
2T-37
Kuparuk
ConocoPhíllips Alaska, Ine.
USA
April 22, 2007
Joint Jt. Depth Pi" Pen. Ppre \,,1e[711 Min. Damage Profile
No. (Ft) ;~;~(;¡ Body ID. Comments (%wall)
(Ins.) (Ins.) 0 50 100
240 7564 0 0.01 6 2.89
241 7595 () 0.03 11 2.86
242 7627 0 0.03 ]2 2.87
243 7658 0 0.02 a 2.85
244 7690 0 0.03 10 2.85
245 7721 0 0.03 ]1 2.85 Lt Denosits.
246 7752 0 0.ü2 a 2.88
247 7784 0 0.05 ))1 2.88 Isolated nittin¡:t. Lt Denosits.
248 7816 0 0.03 1.3 J 2.91 Shallow oittimr. Lt. Deoosits.
249 7846 0 0.ü3 12 2.90 Shallow oittim,.
250 7877 0 0.02 9 2.92
251 7909 0 0.ü3 P 2.87
252 7940 0 0.03 10 2.87 I t Denosi ts.
253 7972 0 0.02 7 2.85 Lt. Denosi ts.
254 8003 () 0.ü3 ) ) I 2.85
255 8034 () 0.02 ;> 2.83 Lt. Denosits.
256 8066 0 0.02 .2 2.86
257 8097 () 0.02 1 2.87
258 8129 0 0.03 I 3 2.85
259 8160 0 0.02 8 4 2.89
260 8191 () 0.03 11 "I 2.89
261 8223 U 0.02 9 4 2.89
262 8254 0 0.03 0 1 2.85 Lt. Denosi ts.
263 8286 0 0.02 ') ;> 2.87
264 8317 () 0.ü3 7 2.84
265 8349 () 0.03 .2 2.87
266 8380 () 0.03 J ') 2.87
267 8411 () 0.03 .2 2.91
268 8443 () 0.02 .5 2.90
269 8475 0 0.02 6 .2 2.90 Lt. Deoosits.
270 8506 0 0.01 6 r 2.91
¡
271 8538 ( 0.ü3 11 4 2.89
272 8569 ( 0.02 I ) 2.91
273 8601 ( 0.03 11 .2 2.89
274 8632 ( 0.03 13 2.84 Shallow oittinQ. Lt. Deoosits.
275 8664 ( 0.01 5 2.89
275.1 8694 ( 0.02 I ! 2.89 PUP Lt Deoosits.
275.2 8701 0 0 0 ( N/A GLM 4 (Latch @ 12:30)
275.3 8709 0 0.03 1 ( 2.92 PUP
276 8715 0 0.03 I ;> 2.86 Lt Denosits.
277 8746 0 0.02 ;> 2.90
278 8777 0.03 " 2.87 I. t. Deoosi ts.
279 8809 0.02 ) 2.86 Lt Deoosits.
280 8840 0.02 3 2.91
281 8872 I 0.03 3 2.85 Shallow oittinQ. Lt Denosits.
282 8903 I 0.03 II .) 2.88
283 8935 0 0.03 10 2.91 Lt. Denosits.
284 8967 0 0.02 ') ( 2.86
285 8998 I) 0.03 11 2.83 U. Denosits.
286 9029 0 0.ü3 13 2.85 Shallow oittinQ. Lt. DeDosits.
Body
Metal Loss Body
Page 6
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I
I
I
I
PDS REPORT JOINT TABULATION SHEET
Pipe:
Body Wall:
Upset Wall:
NominaII.D.:
3.5 in 93 ppf 1.-80
0.254 in
0.254 in
2.992 in
Well:
Field:
Company:
Country:
Survey Date:
2T-37
Kuparuk
ConocoPhillips Alaska, Inc.
USA
April 22, 2007
Joint Jt. Depth F'en. Pen. Pen. Melal Min. Damag e Profile
No. (Ft.) '¡PSt;1 Body I.D. Comments (% wall)
(Ins.) (Ins.) 0 50 100
287 9061 0 0.03 13 3 2.84 Shallow oittim~. It. Deoosits.
288 9092 0 0.03 13 2 2.84 Shallow oittino. It DelJOsits.
289 9124 0 0.02 4 2.85 It. Deoosits.
290 9155 0 0.04 2.86 Shallow oittinQ. Lt. Denosits. iii
291 9187 I) 0.06 ) 2.81 Isolated pittin2:. It. Deoosits.
292 9218 0 0.03 ) 2.82 It. Deposits.
293 9250 0 0.02 (I 2.86 It. Deoosi ts.
294 9281 0 0.02 q 2.86
295 9313 0 0.03 I. 2.84 Shallow oittimL
296 9344 0 0.03 I 2.84
297 9375 0 0.03 4 2.88
298 9407 0 0.04 2.84 Shallow pittinQ.
299 9438 0 0.02 2.84
300 9470 0 0.02 2.86 Lt. Deposits.
301 9501 0 0.04 I ( 2.84 Shallow oittins;;:. Lt. Deoosits.
302 9533 0 0.03 ¡ 2.79 Shallow oittim;;:. Lt. Deoosits.
303 9564 0 0.02 B 2.84 Lt. Deoosits.
304 9595 ( 0.02 (I 2.85 i11
305 9626 0 0.09 33 I) 2.90 Isolated oitting. Lt. DelJOsits.
306 9658 0 0.04 I I) 2.88 Shallow oitting.
307 9689 I) 0.03 1 4 2.89
307.1 9722 ( 0.04 II (I 2.91 PUP Shallow nittinQ.
307.1 9724 0 I) I) N/A GLM 5 (Latch @ 6:301
307.3 9738 0.01 5 I) 2.92 PUP
308 9742 0.03 Ie) 4 2.90
309 9773 0 0.03 10 j 2.88 Lt. Deoosits.
310 9804 0 0.01 2 2.90
311 9836 0 0.02 2 2.88
312 9867 0.02 2.87
313 9899 0.02 2.83
314 9929 0.02 2.82 Lt. Denosits.
315 9961 0.02 B 2.89
316 9992 D.03 13 2.83 Shallow oittinQ..
317 10024 0 0.02 I) 2.86
318 10055 0 0.01 I) 2.87
319 10086 0 0.02 I) 2.87
320 10118 0.02 2.88
321 10150 0.02 2.86
322 10181 0.02 i 2.84
323 10212 0.03 11 2.88
324 10244 0.01 6 2.91
325 10275 0.02 7 2.88
326 10306 0.03 10 2.88
327 10338 0 0.03 11 2.91
328 10369 0 0.ü2 I) 2.87
329 10400 ( 0.04 4 4 2.84 Shallow oittinQ.. Lt. Deposits.
330 10432 0 0.03 13 2.84 Shallow oittinQ.
331 10463 I) 0.03 1) 2.90 Shallow pittin2:.
332 10494 0 0.02 2.87
332.1 10524 0 0.02 B 2.94 PUP
Body
Metal Loss Body
Page 7
I
I
PDS REPORT JOINT TABULATION SH
I
Pipe:
Body Wall:
Upset Wall:
NominaII.D.:
3.5 in 9.3 ppf L·80
0.254 in
0.254 in
2.992 in
Well:
Field:
Company:
Country:
Survey Date:
2T-37
Kuparuk
ConocoPhillips Alaska, Inc.
USA
April 22, 2007
I
Joint Jt. Depth Pen Pen. Pen I ¡!Aelal Min. Damage Profile
No. (Ft.) Body ID. Comments (%wall)
(Ii (Ins.) (Ins.) 0 50 100
332.2 10532 0 0 0 N/A GlM 6 (Latch @ 12:001 i
332.3 10540 ! 0.05 2 2.92 PUP Isolated oittimi!.
333 10546 0.04 ¡ 2.88 Line shallow corrosion. Lt. Deoosi ts.
333.1 10574 0 0 ( N/A NIPPLF
333.2 10576 0 0.00 2.89 PUP
333.3 10584 n 0 í N/A PACKER
333.4 10592 n 0.03 ¡ ). 2.88 PUP III
333.5 10599 () 0 () N/A NIPPLE
333.6 10601 ( 0.00 2 2.93 PUP IT
I
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Penetration Body
Metal loss Body
I
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Page 8
I
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------
Well:
Field:
Company:
Country:
Tubin :
.. -....
2T-37
Kuparuk
ConocoPhillips Alaska, Inc
USA
3.5 ins 9.3 f L-80
Cross Section for Joint 305
Tool speed = 55
NominallD = 2.992
.I''¡ominal OD = 3.500
Remaining wall area = 96 %
Tool deviation = 700
......
.. ..
P S Report
ross Sections
Survey Date:
Tool Type:
Tool Size:
No, of Fingers:
Anal st:
April 22, 2007
MFC 24 No, 21119
1.69
24
M. Tahtouh
depth 9649.89 ft
Finger 22 Penetration = 0.085 ins
Isolated Pitting 0.09 ins = 33% Wall Penetration HIGH SIDE = UP
Cross Sections page 1
.. ..
..
..
------
-----
..
-
P S Report
ross Sections
Well:
Field:
Company:
Country:
Tubin :
2T-37
Kuparuk
ConocoPhillips Alaska, Inc.
USA
3.5 ins 9.3 f L-80
Survey Date:
Tool Type:
Tool Size:
¡\)o. of Fingers:
Anal st:
April 22, 2007
MFC 24 No. 21119
1.69
24
M. Tahtouh
Cross Section for Joint 234.1 at depth 7390.187 ft
Tool speed = 58
NominallD 2.992
Nominal 00 = 3.500
Remaining wall area 96 %
Tool deviation = 90 ú
Finger 18 Penetration = 0.067 ins
Isolated Pitting 0.07 ins = 26% Wall Penetration HIGH SIDE = UP
Cross Sections page 2
- -
- ..
PHIS'LIPS 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
July 30, 2001
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 2T-37 (195-101)
Dear Ms. Commissioner:
Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent
perforation activity on the KRU well 2T-37.
If there are any questions, please contact me at 263-4574.
Sincerely,
Staff Engineer
Phillips Drilling
MM/skad
RECEIVED
AU~ 0 1 2001
A/aska 0il ~ Gas Cons,
Anchorage Commission
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate _X
Pull tubing _ Alter casing _ Repair well _ Other_
2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet)
Phillips Alaska, Inc. Development_X RKB 122 feet
3. Address Exploratory __ 7. Unit or Property name
P. O. Box 100360 Stratigraphic__
Anchorage, AK 99510-0360 service__ Kuparuk Unit
4. Location of well at surface 8. Well number
94' FNL, 4724' FEL, Sec. 12, T11 N, RSE, UM (asp's 498945, 5969886) 2T-37
At top of productive interval 9. Permit number / approval number
195-101 /
At effective depth 10. APl number
50-103-20227
At total depth 11. Field / Pool
3921' FNL, 1781' FEL, Sec. 10, T11N, RSE, UM (asp's491330, 5966062) Kuparuk Oil Pool
12. Present well condition summary
Total depth: measured 11080 feet Plugs (measured)
true vertical 6067 feet
Effective depth: measured 10725 feet Junk (measured) 1.5" DMY on RK latch @ 10982'
true vertical 5840 feet
Casing Length Size Cemented Measured Depth True vertical Depth
CONDUCTOR 121' 16" ~o3 sx AS ~ 121' 121'
SUR. CASING 4023' 9-5/8" 860 sx ASIII, 400 sx Class G, 240 4145' 2887'
PROD. CASING 10952' 7" 240 sx C~ass G 1 1074' 6063'
Perforation depth: measured 10675' - 10698', 10720' - 10740'
true vertical 5809'- 5823', 5837'- 5850'~"~ECEIvE~"D
Tubing(size, grade, and measured depth) 3-1/2",9.3#,L-80Tbg@ 10625'MD. ~UG 0 1
(type & measured depth) BAKER SAB-3 PERM. @ 10597' MD. Alaska Oil & Gas Cons. Commission
Packers
&
SSSV
CAMCO 'DS' NIPPLE NO GO @ 505' MD. Anchorage
13. Stimulation or cement squeeze summary
Intervals treated (measured) N/A
Treatment description including volumes used and final pressure
14. Representative Daily Average Production or Injection Data
OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure
Prior to well operation 184 858 518 291
Subsequent to operation 330 1646 1088 - 303
15. Attachments
Copies of Logs and Surveys run __
Daily Report of Well Operations __X Oil__ X Gas __ Suspended _ Service _Water Injector
17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Mike Mooney263-4574
Signed ~ //~ Title Staff Engineer Date
Michael Mooney ~ Prepared by Sharon AIIsup-Drake 263-4612
Form 10-404 Rev 06/15/88 ·
ORIGINAL
SUBMIT IN DUPLICA~~~
Date
Comment
2T-37 Event History
07/06/01
07/07/01
ATTEMPT TO RIH, UNABLE TO GET 6500'. CALL LRS, PUMP AT 2BPM RIH TO 7500', UNABLE TO GET
FURTHER. TALK W/DSO, TRANSFER WELL TO INJECTION AT 3 BPM, GOT TO TD. PERFORATE 10,675'
TO 10,698'.
PERFORATE 10675-10698' (23') WITH 2.5" HSC 4 SPF, 180 DEG/+-90 PHASED, HSD POWER JET
CHARGES. 23 FT GUN HDS 4 SPF. PENT: 25.2 INCHES, HOLE DIAM: 0.32 INCHES. [PERF]
Page 1 of 1 7/30/01
03 .
C:t.O~MJDOc ·
PERMIT
95 .... i0i
95~--i01
A,3, GCC Individual Wei'i
Geological Hater'~ais inventor"y
DATA T DATA._.PL..US
6888 L...T/~-I080 ....4434
,CDR ,P,/~730 ..... 1i080
CDR ~_~
D ,:::i L e; 0 '?/"0 8//'9 '?
F..' LIN D A T E .._R E C V D
i '10/20/'95
., /.,
'i0/' z0/95
i2/27/'95
i 0-~-~0 7 -~,~/~C Oki F' L E T I ON DATE
DAZLY WELL OPS R
A r" e d r' y ,:J 'i .. ,..; h s a rr, p '1 e s r" e q u
Was !:he ,,^~eil cor'ed? yes i'~Analys'is & descr"'¥pt'i'on r"ece'ived? ~o
~ . 1~ ~ ~ Kuparuk Well Pressure Report
Well~ ~F'~ ,.?, 7
Key Well
i:::] Yes r-] No
,. .
· '_, ~/,~ -.
·
Service Company
Date //-//- 7'~""
Satisfies
State
ReqUirement
. -
ED Yes
:.Pressure Measurement Device- '
.~_:~:;~~}:Hp ~AME~DA U LYNES ~-Torque TUrn
:lmmmea Identification No
(Up~r Bomb) 7~3Y
.. _~ .... ~ ..... ~. :: ';~;:~:;...~.~.._;::~ ..... '~_:-%:.
~ ~:-'~:~-~M.~-~ ~ -.. .::~
Type of Test: I:~'Static '~~$~nd':' [~'A/--!. C r-i Both '~~i'..
WL I MD- I TVD-":r~~r:LO,~r:'~'I::'~- YvD:S:S:~ 11
Maximum Recorded Temperature:
Well $1 Prior to Pressure Measurement (Date/Time):
Chart Quality:
Operations/Engineering.
Reprnsenta~ve ~,~c,,'~ /~, ~.~~
ARCO Alaska, Inc.
Date' December 27, 1995
RETURN TO:
ARCO Alaska, inc.
Attn: Julie Nash
ITRANSMITTAL #9313
Kuparuk Operations File Clerk
ATO-1119B
P.O. Box 100360
Anchorage, AK 99510-0360
Transmitted below are the following pressure items. Please acknowledge
receipt and return one signed copy of this transmittal.
2W-05 ~-I r-'l;! Well Pressure Report 11/09/95
2X-08 ~ ~'' J~ '1 Well Pressure Report 11/09/95
2T-38 Well Pressure Report 11/11/95
2W-06 ~q-I~i~ Well Pressure Report 11/11/95
2T-37 ~/,~"-Jol Well Pressure Report 11/11/95
2T-31 ~T-q~ Well Pressure Report 11/12/95
2T-30 ~'"- 3'7 Well Pressure Report 11/13/95
2T-38 Well Pressure~port / _ 11/26/95
Receipt Ack, nowle~/_~--'2~~~~
DISTRIBUTION:
Petrotechnical Data Center
BP Exploration (Alaska) Inc.
MB 3-3 P.O. Box 196612
Anchorage, AK 99519-6612
AMERADA
AMERADA
AMERADA
AMERADA
AMERADA
AMERADA
AMERADA
AMERADA
Date: ~ ~ ,.. _
I VED
OEC 9 1995
Holly Fuller 41~,~k~ 0i/& Gas Cons.
cio Chevron U.S.A., Inc
~.0. Box ~ ~aS, ~m aOO8
Houston, IX
Barbara Sullivan
Mobil Oil Corporation
12450 Greenspoint Drive
Houston, TX 77060
Mr. Vernon E. Pringle, Jr.
DeGIoyer and MacNaughton
One Energy Square
Dallas, TX 75206
Debra Childers
UNOCAL
P.O. Box 196247
Anchorage, AK 99519-6247
~~_~, Grant
$001 Porcupine Drive
Anchorage, AK 99501
ARCO Alaska, inc.
Date: December 27, 1995
TRANSMITTAL #9313
RETURN TO:
ARCO Alaska, Inc.
Attn: Julie Hash
Kuparuk Operations File Clerk
ATO-1119B
P.O. Box 100360
Anchorage, AK 99510-0360
;mitted below are the following pressure items.
receipt and return one signed copy of this transmittal.
Please acknowledge
2W-05 ~R-[~[ Well Pressure Report
i~H Well Pressure Report
s-- ~l"z. Well Pressure Report
~H-[SH Well Pressure Report
2%37 c~¢_~ Well Pressure Report
2T-31 ~ ~'-~ Well Pressure Report
11/09/95
11/09/95
11/11/95
11/11/95
11/11/95
11/12/95
2T-30 5~-os'7 Well Pressure Report 11/13/95
~ Well Pressu~~(~rt/~ .11/26/95
Receipt Acknowteged:
DISTRIBUTION:
Petmtechnical Data Center
BP Exploration (Alaska)Inc.
MB 3-3 P.O. Box 196612
Anchorage, AK 99519-6612
AMERADA
AMERADA
AMERADA
AMERADA
AMERADA
AMERADA
AMERADA
AMERADA
Date:
"'/'g,¢. ' ~' ,9 z "'~
Holly Fuller
cio Chevron U.S.A., Inc
P.O. Box 1635, Rm 3008 We ~o¢~..
Houston, TX ~251
Barbara Sullivan
Mobil Oil Corporation
12450 Greenspoint Drive
Houston, TX 77060
Mr. Vernon E. Pdngle, Jr.
DeGioyer and MacNaughton
One Energy Square
Dallas, TX 75206
Debra Chiiders
UNOCAL
P.O. Box 196247
Anchorage, AK 99519-6247
;.i.:arry Gr~ _...
AOGCC
3001 Porcupine Drive
Anchorage, AK 99501
ARCO Alaska, Inc.
Date' December 26, 1995
Transmittal #: 9310
RETURN TO'
ARCO Alaska, Inc.
Attn.: Julie Nash
Kuparuk Operations File Clerk
ATO-1119 B
P.O. Box 100360
Anchorage, AK 99510-0360
Transmitted below are the following open hole items. Please acknowledge
receipt and return one signed copy of this transmittal.
'fP-)~ 2T-27 CDR 04/17/95 REF #50-103-20217
r 2T-32 CDN 04/30/95 REF #50-103-20218-00
¢¢--.,4 q' ~2T-32 CDR 04/30/95 REF #50-103-20218-00
,-? 2T-30 CDR 05/12/95 REF #50-103-20219-00
~_,(,~.c~ 2V-06 TDTP 06/11/95 REF #95219
2T-31 CDR 0713/95 REF #50-103-20226-00
~- 2T-36 CDR 07/25/95 REF #50-103-20228-00
~-2T-36 CDN 07/25/95 REF #50-103-20228-00
/-2%38 CDR 08/03/95 REF #50-103-20229-00
)_2%38 CDN 08/03/95 REF #50-103-20229-00
2T-37 CDR 08/10/95 REF #50-103-20227-00
1 Q-24 ARC5 Array Resistivity Comp. 08/30/95 4206-7270
~- ~3~,- 1Q-26 ARC5 Array Resistivity Comp. 09/22/95 3820-7010
1 Q-23 ARC5 Array Resistivity Comp. 09/30/95 5156-9982
Acknowledged:
DISTRIBUTION'
Mr. Vernon E. Pringle Jr.
DeGIoyler and MacNaughton
One Energy Square
Dallas, TX 75206
Erickson/Zuspan
NSK Central Files
NSK 69
Sharon AIIsup-Drake
DS Development
ATO - 1205
Larry Grant
AOGCC '-?
3001 Porcupine Drive
Anchorage, AK 9950!~,
Date'
RECEIVED
DEC 2 7 1995
Ancbor~,ge
Clifton Posey
Geology
ATO - 1251
Alaska, Inc.
Post Office Box 10036~
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
December 12, 1995
Mr. David J. Johnston
Commissioner
State of Alaska
Alaska Oil & Gas Conservation Commission
3001 Porcupine Drive
Anchorage, Alaska 99501
Subject: 2T-37 (Permit No. 95-101) Well Completion Report
Dear Mr. Commissioner:
Enclosed is the well completion report for the recent operations on KRU 2T-
37.
If there are any questions, please call 265-6206.
Sincerely,
Superwsor
Kuparuk Drill Site Development
MZ/skad
STATE OF ALASKA
,~',,_,~,SKA OIL AND GAS CONSERVATION CL ¢IISSION
WELL COMPLETION OR REOOMPLETION REPORT AND LOG
~ Status of Well Classification of Service Well
OIL r~ GAS E~ SUSPENDED F~ ABANDONED E~ SERVICE
2 Name of Operator 7 P~rMt ~u~ber
ARCO Alaska, Inc ~"-~i~0'1.,' .'~ '
3 Address 8 APl Numar { , -'
~..: /'/j / .
~'-'~ , / ~ .,:
P.O. Box 100360, Anchorage, AK 9951¢0360
4 Location of well al sudace ~ .....................
~.~, ~ . 11 Field and Pool
1358' FSL, 1781' FEL Sec. 10, T11 N, R8E, UM''~ ..... < KUPARUK RIVER
5 Elevation in feet (indicate KB, DF, etc.) ~ 6 Le~e ~signation and Serial No. Ku~ruk River Oil Pool
RKB41' Pad 81'~ ADL25568 A~2666-
12 Dale Spudded 13 Date T.D. Rea~ed 14 Date ~mp., Susp. or A~nd. 15 Water ~pth, if o~hore ~16 No. of Completions
August 5, 1995 August 10, 1995 2~Se~95 (~dd) NA feet MSL~ 1
10984' M D & 6006' WD YES ~ NO ~ NA feet MD = 1380' ss APPROX
22 Ty~ Electric or Olher Logs Run
GR/CDR
23 CASING, LINER AND CEMENTING RECORD
i SETTING DEPTH MD
CASING SIZE ~ ~ GRADE TOP ~ H~E SIZE
16" ~ 151.5¢ X-65 Surf. 121' 36" 103 sx AS I
9.625"~ 40.0¢ L-80 Surf. 4145' 12.25" 860 sx AS III Lea~, 400 sx of Class G and 240 sx AS I Tail
7" ~ 26.0¢ L-80 Surf. 11074' 8.5" 240 sx Class G
I
24 Pedorations o~n to Production (MD+TVD of Top and Bo~om and 25 TUBING RE.RD
inte~al, size and numar) SIZE DEPTH SET (MD) PACKER SET (MD)
3.5" 10625' 10597'
10720'- 10740' MD 4 spf 5837'- 5850'TVD
26 ACID, F~CTURE, CEMENT SQUEEZE. ETC
DEP~ INTERVAL (MD) AM~NT & KIND OF MATERIAL USED
10720' - 10740' 206679¢ in formation (20/40:12792¢,
12/18' 155998~, 10/14:37889
27 PRODUCTION TEST
Date First Production ~Method of ~eration (Flowing, g~ li~, etc.)
~to~r, 1995J Flowing
Date of Test Houm Tested PRODUCTION F~ OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~ GAS-OIL RATIO
~ 1/30/95 11.9 TEST PERIOD ~ 712 992 289 0~ 1659
Flow Tubing Casing Pressure CALCU~TED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr)
Press 361 61 1 24-HOUR RATEE 1 294 2146 582
28 CORE DATA
Brier description of liihology, ~rosiiy, ~actures, apparent dips and presen~ of oil, g~ or water. Submit core chips.
Form 10-407 Submit in duplicate
Rev. 7-1-80 CONTINUED ON REVERSE SIDE
GEOLOGIC MARKERS FORMATION TESTS
I
NAME I Include interval tested, pressure data, all fluids recovered and gravity,
MEAS DEPTH TRUE VERT. DEPTH I GOR, and time of each phase.
!
I
I
Top Kuparuk C 10672' 5806'
Bottom Kuparuk C 10699' 5823'
Top Kuparuk A 10699' 5823"
Bottom Kuparuk A 10909' 5957'
31. LIST OF ATTACHMENTS
Daily Drilling History, Directional Survey
32. I hereby certify that the foregoing is true and correct to the best of my knowlege.
Signed . , Title DATE
INSTRUCTIONS
General: This form is designed for submitting a complete and correct well completion report and log on
all types of lands and leases in Alaska.
Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt
water disposal, water supply for injection, observation, injection for in-situ combustion.
Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements
given in other spaces on this form and in any attachments.
Item 16 and 24: If this well is completed for separate production from more than one interval (multiple
completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported
in item 27. Submit a separate form for each additional interval to be separately produced, showing the
data pertinent to such interval.
Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.).
Item 23: Attached supplemental records for this well should show the details of any multiple stage cement-
lng and the location of the cementing tool.
Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In-
jection, Gas Injection, Shut-in, Other-explain. ~.;:~; ~ ;;:;;.: i- -'' :"::':' !'~ "~:.? il.'~-~i~.-'?
~ .~ '::.~,~ - :.. 5' :---: '-" '
Item 28: If no cores taken, indicate "none".
Form 10-407
Date:il/02/95
Page: !
ARCO Alaska Inc.
DAILY DRILLING REPORT
~LL:2T-37 RIG:PARKER 245 WI: 55% SECURITY:0
WELLID: AK8087 AFE: AK8087 TYPE:DEV AFE EST:$ 1477M/ 1920M
AREA/CNTY:NORTH SLOPE STATE:AK API NUMBER:50-103-20227
FIELD: KUPARUK RIVER
SPUD:08/06/95 START COMP: FINAL:
08/05/95 (1)
TD: 121'(121)
SUPV:RLM
08/06/95 (2)
TD: 2640'(2519)
SUPV:RLM
08/07/95 (3)
TD: 4156' (1516)
SUPV:RLM
08/08/95 (4)
TD: 4732'(576)
SUPV:RLM
08/09/95 (5)
TD: 8112' (3380)
SUPV: DWG
08/10/95 (6)
TD:10130' (2018)
SUPV:DWG
08/11/95 (7)
TD:ll080' (950)
SUPV:DWG
08/12/95 (8)
TD:ll080' ( 0)
SUPV:DWG
08/13/95 (9)
TD:ll080' ( 0)
SUPV:DWG
MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0
NIPPLE UP DIVERTER
Move rig 118' from 2t-38 to 2T-37. Accept rig at 0500 hrs
8/5/95.
DAILY:S40,340 CUM:$40,340 ETD:SO EFC:$1,517,440
MW: 10.0 PV/YP: 32/29 APIWL: 7.2
DRILLING
Function test diverter system. Clean out conductor and
drill from 121' to 467'. Directional drill 12.25" hole from
467' to 2640'
DAILY:S73,681 CUM:$114,021 ETD:SO EFC:$1,591,121
MW: 10.1 PV/YP: 25/22 APIWL: 6.4
MAKE UP SPEED HEAD
Directional drill 12.25" hole from 2640' to 4156'. Run
9-5/8" casing. Cement casing. CIP @ 0420 hrs. 8/7/95.
DAILY:S205,903 CUM:$319,924 ETD:SO EFC:$1,797,024
MW: 9.7 ?V/YP: 22/23 APIWL: 7.2
RIH
Directional drill 8.5" hole from 4166' to 4732'.
DAILY:S117,175 CUM:$437,099 ETD:SO EFC:$1,914,199
MW: 9.4
DRILLING
Drilling 4732' to 8112'.
DAILY:S74,617 CUM:$511,716
PV/YP: 15/13
ETD:SO
APIWL: 6.8
EFC: $1,988,816
MW: 9.7
DRILLING
Drilling 8112' to 10130'
DAILY:S74,767 CUM:$586,483
PV/YP: 24/16
ETD:SO
APIWL: 5.5
EFC: $2,063,583
MW: 10.8 PV/YP: 28/20 APIWL: 3.6
CIRC AND CONDITION
Drilling from 10130' to 11080'. Drop single shot survey -
pump pill ( while pumping pill noticed bubbles to surface -
no cut - air probably - will pump out to check. Circulate
out - no gas to surface - no cut mud.
DAILY:S96,592 CUM:$683,075 ETD:SO EFC:$2,160,175
MW: 10.8
N/D BOP
Run 7" casing to 11074'
DAILY: $219,976 CUM: $903,051
PV/YP: 28/18
ETD:SO
APIWL: 3.8
EFC: $2,380,151
MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0
RELEASE RIG
Nipple down BOP. Freeze protect annulus. Release rig @ 1600
Date' 11/02/95
Page: 2
ARCO Alaska Inc.
DAILY DRILLING REPORT
hrs. 8/12/95.
DAILY:S71,923 CUM:$974,974
REMEDIAL AND COMPLETION OPERATIONS
ETD:SO
EFC: $2,452,074
WELL:
WELLID: AK8087
AREA/CNTY:
FIELD:
SPUD:
RIG:NORDIC WI: 0% SECURITY:0
AFE: Y~8087 TYPE:DEV AFE EST:$ 1477M/ 1920M
STATE: API NUMBER:
START COMP' FINAL:
09/19/95 (10)
TD:i!080'
PB:10984'
SUPV'N~DD
RIH WITH 3-1/2" COMPLETIO MW: 0.0
Move rig from 2T-36 to 2T-37. Rig accept at 1730 hrs.
9/18/95. NU BOP. Test casing. Load, strap and drift 3-1/2"
completion tubing.
DAILY:S30,150 CUM:$1,005,124 ETD:SO EFC:$2,482,224
09/20/95 (11)
TD:ll080'
PB:10984'
SUPV:MDD
RIG RELEASED MW: 0.0
Run in hole with packer assembly on 3-1/2" tubing with
GLMs. Set packer. Freeze protect well. Test packoff and
tree. Secure well. Released rig at 0100 hfs 9/20/95.
DAILY:S130,424 CUM:$1,135,548 ETD:SO EFC:$2,612,648
9/28/95
Perforate well from 10720'-10740' with 2-1/8" enerjet guns @ 4 spf, oriented 90°
and 270° from the iow side of the hole. Guns moved in and out of hole smoothly,
no pumping required.
End of WellSummary for Well:AK8087
I SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-70518 Sidetrack No. _____ Page __1 ........ of ....
· _= [1[~.'.~.::~..--~ Company ARCO ALASKA, INC. Rig Contractor & No. Parker Drilling Co. - Rig: ~245 Field KUPARUK RIVER UNIT
~~ Well Name & No. PAD 2T/37 Suwey Section Name Defin~ive Su~ey BHI Rep. CHIP MILCHAK
I II I I
WELL DATA
Target ~D (~ Target Coord. N/S Slot C~rd. N/S -~.~ Grid Corre~ioh.~.,,/.?~,.,.0.~ Depths Measured From: RKB ~ MSL~ SSc
Target Description Target Coord. ~ Slot Coord. ~ 5~.~ Magn. Declination '~ ,/'38~. , Calculation Method MINIMUM CURVATURE
Target Direction (~) Buil~Walk~DL per: 1~ ~m~ 10m~ Ve~. Sec. ~im. 2~.~ Magn. to Map Corr. 28~/~ ,;,,Map No~h to: OTHER
~ ' ~"~ ~f" i'~' I~
SURVEY DATA ,~- /'
Su~ey Su~ey Incl. Hole Course Ve~ical Total Coordinate Build Rate Walk Rate
Date Tool Build (+) Right (+) Comment
Depth Angle Dire~ion Len~h ~D Section N(+) / S(-) E(+) / W(-) DL
Type ~ (DD) (DD) (~ (~ ~ (~ Per ~ ~ Drop (-) Left (-)
0.~ 0.~ 0.~ 0.~ 0.~ 0.~ 0.~ TIE IN POI~
.........................................
05-AUG-95 GSS 121 .~ 0.~ 0.~ 121.~ 121 .~ 0,~ 0.~ 0.~ 0.~ 0.~ 9 1/2" M1C 1.2 DEG AKO
................
05-AUG-95 GSS 358.~ 2.25 310.~ 237.~ 357.94 1.85 2.~ -3.~ 0,95 0.95
05-AUG-95 GSS 448.~ 2.75 319.~ ~.~ 447.85 3.09 5.76 -6.33 0,70 0.56
......................
05-AUG-95 GSS 542.~ 1.25 ~5.~ 94.~ 541.80 3.44 8.45 -8.~ 1,82 -1,60
.....................................................
05-AUG-95 MWD 650.72 1.23 ~5.28 108.72 650.50 4.31 8.77 -9.~ 1.97 ~.02
05-AU G-95 MWD 740.22 4.49 217.04 89.~ 739.88 8.36 5.30 -12.01 3.66 3.~
.............................................
05-AUG-95 MWD 831.16 7.89 216.84 ~.94 830.28 17.14 -2.54 -17.~ 3.74 3.74 -0.~
~ -, ~. ~ ~ ...................................
05-AUG-95 MWD 919.84 12.48 221.35 88.~ 917.54 31.47 -14.61 -27.~ 5.25 5.18 5.~
05-AUG-95 MWD 1011.21 15.27 ~6.56 91.37 1 ~6.23 52.14 -~.~ -43.14 3.34 3.05 5.70
..................................
05-AUG-95 MWD 1196.52 22.~ 232.92 94.12 1182.12 108.76 ~.83 -88.17 4.46 4.43 1.42
.....
05-~G-~5 MW~ 12~0.45 25.03 234.74 03.03 12~.24 145.71 ~.~1 -118.44 3.32 ~.~ 1.04
....................
05-A~G-O5 MWD 1383.~ 27.14 237.2g 03.51 1352.22 1 ~.48 -111 .~ -1 $2.54 2.55 2.2~ 2.72
.......
~-~HG-O5 MW~ 147~.~3 27.77 23~.43 ~5.~7 1437.~0 230.44 -1 ~.~ -1 ~0.5~ 0.77 0.~ -0.~
..... ~ .......................
~-AHG-~5 MW~ 1572.41 28.~1 232.40 ~2.40 1510.~2 27~.71 -1 ~1 .~ -~5.~ 2.~1 1.12 4.2~
~-AUG-95 MWD 1 ~7.20 30.37 236.19 94.79 1 ~1.25 319.~ -1 ~.79 -263.25 2.~ 1 .~ 3.~
...............
~AUG-95 MWD 17~.23 33.17 237.87 93.03 1 ~.~ ~.59 -215.41 -304.35 3.16 3.01 1 .~
..............
~-AUG-95 MWD 18~.72 36.~ 240.61 ~.49 1754.80 419.~ -241 .~ -~8.~ 3.65 3.~ 3.03
~-AU G-95 MWD 1945.~ 40.04 242.22 94.82 1829.44 478.26 -269.59 -399.~ 4.30 4.18 1.70
............
~-AUG-95 MWD 2037.95 43.04 242.98 92.41 1898.60 ~9.~ -~7.78 -454.28 3.~ 3.25 0.82
.....................
~-AUG-95 MWD 2132.~ 45.~ 244.65 94.71 1 ~6.40 ~5.65 -3~.94 -513.~ 2.91 2.~ 1.76
...................
~-AUG-95 MWD 2225.65 48.42 246.44 92.99 20~.84 673.~ ~55.~ -575.51 3.40 3.10 1.92
.............................
~AUG-95 MWD 2317.77 51 .~ 245.85 92.12 20~.89 744.18 ~.65 ~0.16 3.73 3.70
r SURVEY CALCULATION AND FIELD WORKSHEET
I i Job No. 0450-70518 Sidetrack No. Page____2 of ~ .~ ...... .... ......
I1· -= |! [4 ~'i::~'"'~ Company ARCO ALASKA, INC. Rig Contractor & No. Parker Drilling Co. - Rig: #245 Field KUPARUK RIVER UNIT
Well Name & No. PAD 2T/37 Sun/ey Section Name Definitive Survey BHI Rep. CHIP MILCHAK
WELL DATA
Target TVD (F-r) Target Coord. N/S Slot Coord. N/S -98.00 Grid Correction 0.000 Depths Measured From: RKB
Target Description Target Coord. E/W Slot Coord. E/W 556.00 Magn. Declination 28.460 Calculation Method MINIMUM CURVATURE
Target Direction (DD) Build\Walk\DL per: 100ff~ 30m~ lomE] Vert. Sec. Azim. 243.40 Magn. to Map Corr. 28.460 Map North to: OTHER
SURVEY DATA
Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate
Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment
Type (F-D _(DD) (DD) (FI) (Fi') {FI') (FT) (Per 100 IT) Drop (-) Left (-)
06-AU G-95 MWD 2409.56 54.61 245.86 91.79 2143.84 817.63 -413.72 -707.24 3.03 3.03 0.01
·
06-AUG-95 MWD 2501.42 57.67 246.07 91.86 2195.01 893.82 -444.78 -776.90 3.34 3.33 0.23
06-AUG-95 MWD 2593.25 60.56 246.97 91.83 2242.15 972.50 -476.17 -849.18 3.26 3.15 0.98
,,,
06-AUG-95 MWD 2685.64 63.58 242.67 92.39 2285.43 1054.07 -510.92 -923.00 5.25 3.27 -4.65
06-AUG-95 MWD 2873.49 64.08 241.03 187.85 2368.29 1222.59 -590.46 -1071.64 0.83 0.27 -0.87
, ,
06-AU G-95 MWD 3155.75 65.88 243.00 282.26 2487.67 1478.26 -710.44 -1297.49 0.90 0.64 0.70
06-AUG-95 MWD 3434.36 67.39 242.39 278.61 2598.16 1734.00 -827.77 -1524.75 0.58 0.54 -0.22
06-AUG-95 MWD 3712.72 66.24 242.91 278.3~ 2707.75 1989.85 -945.33 -1752.02 0.45 -0.41 0.19
06-AUG-95 MWD 4068.86 65.12 241.40 356.14 2854.42 2314.29 -1096.89 -2038.97 0.50 -0.31 -0.42
07-AUG-95 MWD 4185.73 64.43 241.49 116.87 2904.23 2419.96 -1147.42 -2131.83 0.59 -0.59 0.08 6 3/4" M1C 1 DEG AKO
07-AUG-95 MWD 4372.33 66.05 244.31 186.60 2982.39 2589.37 -1 224.58 -2282.66 1.62 0.87 1.51
08-A UG-95 MWD 4560.52 65.60 242.67 188.19 3059.47 2761.04 -1301.20 -2436.29 0.83 -0.24 -0.87
08-AUG-95 MWD 4655.92 64.98 243.17 95.40 3099.35 2847.71 -1 340.66 -2513.45 0.80 -0.65 0.52
08-AUG-95 MWD 5028.05 64.12 242.51 372.13 3259.26 3183.70 -1494.03 -2812.42 0.28 -0.23 -0.18 7 1/4" NEYRFORTurbine
08-AUG-95 MWD 5402.88 64.42 245.15 374.83 3422.01 3521.32 -1642.93 -3115.44 0.64 0.08 0.70
08-AUG-95 MWD 5776.55 63.40 245.67 373.67 3586.34 3856.70 -1782.56 -3420.59 0.30 -0.27 0.14
08-AU G-95 MWD 6152.55 62.62 245.55 376.00 3756.98 4191.50 -1920.93 -3725.73 0.21 -0.21 -0.03
08-AUG-95 MWD 6338.55 63.39 246.73 186.00 3841.41 4357.04 -1 987.97 -3877.30 0.70 0.41 0.63
08-AUG-95 MWD 6526.93 65.66 247.32 188.38 3922.43 4526.75 -2054.34 -4033.87 1.24 1.20 0.31
08-AUG-95 MWD 6899.65 63.34 244.76 372.72 4082.90 4862.74 -2190.86 -4341.26 0.88 -0.62 -0.69
08-AUG-95 MWD 7086.42 64.11 249,10 186.77 4165.61 5029.83 -2256.45 -4495.30 2.12 0.41 2.32
09-AUG-95 MWD 7275.46 64.32 248.65 189.04 4247.84 5199.27 -2317.79 -4654.08 0.24 0.11 -0.24
-- _
09-AU G-95 MWD 7559.28 65.79 246.44 283.82 4367.55 5455.92 -2416.10 -4891.87 0.88 0.52 -0.78
--
09-AUG-95 MWD 7934.14 65.57 243.72 374.86 4521.96 5797.32 -2560.01 -5201.63 0.66 -0.06 -0.72
SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-70518 Sidetrack No. Page 3 o! ...... 3_ ....
Company ARCO ALASKA, INC. Rig Contractor & No. Parker Drilling Co. - Rig: #245 Field KUPARUK RIVER UNIT
~ Well Name & No. PAD 2T/37 Survey Section Name Definitive Survey BHI Rep. CHIP MILCHAK
~FL/=~I~ WELL DATA
Target TVD (ET) Target Coord. N/S Slot Coord. N/S -98.00 Grid Correction 0.000 Depths Measured From: RKB
Target Description Target Coord. E/W Slot Coord. EJW 556.00 Magn. Declination 28.460 Calculation Method MINIMUM CURVATURE
Target Direction (DD) Builc~Walk\DL per: 10Oft[~ 30m0 10m0 VerL Sec. Azim. 243.40 Magn. to Map Corr. 28.460 Map North to: OTHER
SURVEY DATA
Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate
Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment
Type (FT) (DD) (DD) (F'D (FT) (FT) (FT) (Per mO FT) Drop (-) Left (-)
09-AUG-95 MWD 8308.67 65.67 241.55 374.53 4676.57 6138,40 -2716.80 -5504.56 0.53 0.03 -0.58
09-AUG-95 MWD 8683.97 62.79 240.78 375.30 4839.72 6476.08 -2879.76 -5800.61 0.79 -0.77 -0.20
' 09-AUG-95 MWD 8965.46 64.44 243.09 281.49 4964.83 6728.13 -2998.35 -6023.11 0.94 0.59 0.82
09-AUG-95 MWD 9151.83 64.29 240.90 186.37 5045.46 6896.09 -3077.24 -6171.45 1.06 -0.08 -1.1 8
09-AUG-95 MWD 9335.74 64.27 243.15 183.91 5125.29 7061.72 -3154.96 -6317.77 1.10 -0.01 1.22
09-AUG-95 MWD 9525.44 64.49 243.41 189.70 5207.31 7232.77 -3231.87 -6470.55 0.17 0.12 0.14
10-AUG-95 MWD 9712.59 63.11 244.28 187.15 5289.94 7400.68 -3305.89 -6621.27 0.85 -0.74 0.46
1 O-AUG-95 MWD 9901.04 61.72 242.46 188.45 5377.21 7567.69 -3380.74 -6770.57 1.13 -0.74 -0.96
10-AUG-95 MWD 10085.91 58.95 241.63 184.87 5468.70 7728.27 -3456.02 -6912.46 1.55 -1.50 -0.45
1 O-AUG-95 MWD 10183.16 57.40 241.92 97.25 5519.98 7810.86 -3495.10 -6985.26 1.61 -1.59 0.30
10-AUG-95 MWD 10277.02 55.94 241.55 93.86 5571.55 7889.25 -3532.23 -7054.33 1.59 -1.56 -0.39
1 O-AUG-95 MWD 10370.63 53.99 242.02 93.61 5625.29 7965.86 -3568.47 -7121.87 2.12 -2.08 0.50
1 O-AUG-95 MWD 10464.06 53.63 242.30 93.43 5680.45 8041.25 -3603.68 -7188.54 0.45 -0.38 0.30
10-AUG-95 MWD 10557.44 53.21 241.77 93.38 5736.10 8116.21 -3638.85 -7254.77 0.64 -0.45 -0.57
10-AUG-95 MWD 1 0849.52 51.20 241.98 92.08 5792.53 8188.94 -3673.15 -7318.94 2.19 -2.18 0.23 "
lO-AUG-95 MWD 10835.84 50.24 242.43 186.32 5910.49 8333.13 -3740.40 -7446.52 0.55 -0.52 0.24
lO-AUG-95 MWD 10969.71 49.95 242.64 133.87 5996.37 6435.82 -3787.76 -7537.64 0.25 -0.22 0.16
lO-AUG-95 MWD 11080.00 49.95 242.64 110.29 6067.34 8520.23 -3826.56 -7612.62 0.00 0.00 0.00 Projected Data - NO SURVEY
GeoQuest
500 w. International Airport Road
Anchorage, AK 99518-1199
A'I'TN: Sherrie
NO. 9830
Company:
1 0't20/95
Alaska Oil & Gas Cons Comm
Attn: Larry Grant
3001 Porcupine Drive
Anchorage, AK 99501
Field: Kuparuk (Open Hole)
Well Job # Log Description Date BL
LIS
RF Sepia DIR MWD Tape
2T-36 ~'_~-,,- 1(5 '*Z---~ 95269 CDPJCDN ,~,~ .~ .~ C]. 950725 1 1 1
2T-37 ~-I~ 95310 ~ (~~ 950810 1 1 1
,,,
;
SIGNED:
Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you.
RECEIVED
OCT 2 0 1995
Cornmissior
"Anchorage
MEMORANDUM
TO:
State of Alaska
Alaska Oil and Gas Conservation Commission
David John,
Chairma'¢
Blair Wondzell,
P. I. Supervisor
FROM: Doug Amos,(~~ SUBJECT:
Petroleum Inspector
DATE: August 5, 1995
;F]]_,E ;NO: ebxhhecd.doc
Diverter Inspection Parker 245
Arco KRU 2T-37
Kuparuk Rv. Field
PTD No.- 95-101
Saturday, August 5, 1995: i traveled to Arco's KRU 2T-37 well to witness the
Function Test and Inspect the Diverter System.
Arco's Drillsite 2T has a small footprint and Parker 245 is a large rig. Despite
this limitation i found the location well organized and the Diverter System in
compliance. The 90' wheel mounted vent line was angled approximately 30° so
that in the event of a divert scenario the gas would be vented away from the rig,
personnel camp and wellheads. The vent line was anchored and chained to a
pipe saddle to prevent movement during diverting operations. In addition a sign
had been installed warning personnel to stay back 50'.
An AOGCC Diverter Inspection Form with Location Schematic is attached for
reference.
Parker Rig 245 remains the Standard for excellence of all North Slope drilling
rigs.
SUMMARY: Witnessed the Diverter Function Test at Arco's KRU 2T-37 well on
Parker Rig 245.
Attachment: EBXHHECD.XLS
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COM MISSION
Diverter Systems Inspection Report
Operation:
Drlg Contractor: Parker Drilling Rig No.
Operator: Arco KRU Open Rep.:
Well Name: KRU 2%37 Rig Rep.:
Location: Sec. 12 T. 11 N. R. 8 E.
Development
245 PTD #
Date: 8/5/95
X Exploratory:
95-101 Rig Ph. # 659 - 7670
Bobby Morrison
John
Merdian Umiat
MISC. INSPECTIONS: ACCUMULATOR SYSTEM:
Location Gen.: OK Well Sign: Yes Systems Pressure: 3,000 psig
Housekeeping: OK (Gen.) Drlg. Rig: OK Pressure After Closure: 1,700 psig
Reserve Pit: OK Flare Pit: N/A 200 psi Attained After Closure: ~min- 34 sec.
Systems Pressure Attained: 2 min. 52 sec.
Nitrogen Bottles: 5 ~ 2,250 Avg.
DIVERTER SYSTEM INSPECTION:
Diverter Size: 20 in.
Divert Valve(s) Full Opening: YES
Valve(s) Auto & Simultaneous: YES
Vent Line(s) Size: 16" in.
Vent Line(s) Length: 90 ft.
Line(s) Bifurcated: NO
Line(s) Down Wind: YES
Line(s) Anchored: YES
Turns Targeted / Long Radius: N/A
MUD SYSTEM INSPECTION: Light Alarm
Trip Tank: OK OK
Mud Pits: OK OK
Flow Monitor: OK OK
GAS DETECTORS: Light Alarm
Methane OK OK
Hydrogen Sulfide: OK OK
psig
MUD I
PAD
ACCESS
I I. , ^ 6 O 4)
I ~hl ..................... ~ ...... ,-,~,,_ __ . ¢ 90'e 16" Vent Line
h Opb Wh~l Mount~ & Anchored
PIPE
SHED
' % /' WELLH~DS & FLO~INES
MUD PUMPS ~ ~ DRY CEMENT STOOGE TANKS
MOTORS ~ 20" Annular With 16" HIO Full O~ning
CAMP
Knife Valve
Non Compliance Items 0 Repair Items Withi, 0 Day (s) And contact the Inspector @ 659-3607
Remarks: Good System. The end of the vent line was anchored with chains and a pipe saddle
Distribution
odg.- Well File
c - Oper/Rep
c - Database
c - Trip Rpt File
c - Inspector
AOGCC REP.'
OPERATOR REP.'
FI-022 (Rev. 7/93 EBXHHECD.XLS
LASKA OIL AND GAS
CONSERVATION COMMISSION
TONY KNOWI_ESo GOVERNOR
3001 PORCUPINE DRIVE
ANCHORAGE, ALASKA 99501-3192
PHONE: (907) 279-1433
FAX: (907) 276-7542
July 11, 1995
.
Michael Zanghi, Drill Site Develop. Supv.
ARCO Alaska, Inc.
P O Box 100360
Anchorage, AK 99510-0360
Kuparuk River Unit 2T-37
ARCO Alaska, Inc.
Permit No 95-101
Surf Loc 98'FNL, 556'FWL, Sec 12, TllN, R8E, UM
Btmhole Loc 1324'FSL, 1877'FEL, Sec 10, T11N, R8E, UM
Dear Mr Zanghi: '
Enclosed is the approved application for permit to drill the above referenced well.
The permit to drill does not exempt you frOm obtaining additional permits required by law from other
governmenlal agencies, and does not authorize conducting drilling operations until all other required
permitting determinations are made.
Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient
notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing
shoe must be given so that a representative of the Commission may witness the lest. Notice may be
inspector 659-3607.
,
David W. Jol~nston ~ :-'- ~
BY ORDER OF TH MISSION
/enci
c: Dept of Fish & Game, Habilat Section - w/o encl
Dept of Environmental Conservation - w/o encl
STATE OF ~
ALA~r~A OIL AND GAS CONSERVATION COMMISSioN
PERMIT TO DRILL
20 AAC 25.005
la. Type of Work Drill X Redrill D lb Type of Well Exploratory D Stratigraphic Test D Development Oil X
Re-Entry El Deepen J~J Service r-~ Development Gas D Single Zone X Multiple Zone El
2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool
ARCO Alaska, Inc. RKB 41', Pad 81' feet Kuparuk River Field
3. Address 6. Property Designation Kuparuk River Oil Pool
P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25568, ALK 2666
4. Location of well at surface 7. Unit or property Name 1 I. Type Bond (see 2o AAC 25.O25)
98' FNL, 556' FWL, Sec. 12, T11N, R8E, UM Kuparuk River Unit Statewide
At top of productive interval (@ TARGET) 8. Well number Number
1484' FSL, 1549' FEL, Sec. 10, T11N, RSE, UM 2T-37 #U-630610
At total depth 9. Approximate spud date Amount
1324' FSL, 1877' FEL, Sec. 10, T11N, RSE, UM 7/1 2/95 $200,000
12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and 'rVD)
property line 2T-21 11205' MD
1484 ~ TD feet 13.0' ~ 400' MD feet 2560 6151' TVD feet
16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2))
Kickoff depth 500' feet Maximum hole angle 64.3° Maximum surface 1700 pslg At total depth (TVD) 3120 psis
18. Casing program Setting Depth
size Specifications Top Bottom Quantity of cement
Hole Casin~l Weic, lht Grade Couplin~l Len~lth MD TVD MD 'rVD (include sta~le data)
24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +_200 CF
12.25" 9.625" 40.0# L-80 BTC 4016' 41' 41' 4057' 2872' 860 Sx Arcticset III &
HF-ERW 630 Sx Class G
8.5" 7" 26.0# L-80 BTCMOC 11164 41' 41' 11205' 6151' 240SxClassG
HF-ERW Top 500' above Kuparuk
19. To be completed for Redrill, Re-entry, and Deepen Operations.
Present well condition summary
Total depth: measured feet Plugs (measured)
true vertical feet
Effective depth: measured feet Junk (measured)
true vertical feet
Casing Length Size Cemented Measured depth True Vertical depth
Structural
sCu°~fdacUeCt°r R E C E IV E D
Intermediate
Production
Liner ,Ill{ 0 6 1995
Perforation depth: measured
true vertical A~Ski~ 0ii & Gas Cons. Commission
Anchoi'~.~
20. Attachments F'iling fee X Property plat ["1 BOP Sketch X Diverter Sketch X Drilling program X
Drilling fluid program X Time vs depth plot D Refraction analysis El Seabed report ~] 20 AAC 25.050 requirements X
!
21 ."q, hereby certify tha~t the foregoing is true and correct to the best of my knowledge
Signed'~~,~~ ~ ~/['~-I~' Title Drill Site Develop. Supv. Date "~/~/~'
I i ~ Commission Use Only '
Permit Number ] ~1 number __ _ ._.. ~ Approval date_.., ~j.,~ .~-'~ ~ cover letter for
?J'-/o/ 150-/o. - zz_/ I Isee
other recluirements
Conditions of approval Samples required ~] Yes 1~ No Mud Icg required [~ Yes [] No
Hydrogen sulfide measures [~ Yes D No DirecUonal survey required 1~ Yes ~] No
Required working pressure foraOPE r-~ 2M D 3M [--] 5M El 1OM [~] 15M
Other: Original Signed By
David W. Johnston by order of
Approved by Commissioner the commission Date 7-"'/ /'~
Form 10-401 Rev. 7-24-89 Submit in triplicate
GENERAL DRIllING PROCEDURE
KUPARUK RIVER FIELD
2T-37
.
.
.
.
.
.
.
.
.
10.
11.
12.
13.
14.
15.
16.
17.
Move in and rig up Parker #245.
Install diverter system.
Drill 12-1/4" hole to 9-5/8" surface casing point (4,057')according to directional
plan.
Run and cement 9-5/8" casing.
Install and test BOPE to 3000 psi. Test casing to 2000 psi.
Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW.
Drill 8-1/2" hole to total depth (11,205') according to directional plan.
Run open hole evaluation logs or LWD tools as needed.
Run and cement 7" casing. (If significant hydrocarbon zones are present above the
Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20
AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD
of the surface casing shoe, cement will be down squeezed in the annular space between
the surface and production casing after the primary cement job is completed.)
ND BOPE. NU tubinghead & either full opening valve (if logging planned) or master
valve and upper tree assembly (if no logging planned). Note: As a dedicated producer,
no cased hole cement bond logs will be run unless there are problems with the cement
job.
Secure well and release rig.
Move in and rig up Nordic #1.
Install and test BOPE. Pressure test 7" casing to 3500 psi.
Perforate and run completion assembly. Set and pressure test packer.
ND BOPE and install production tree.
Shut in and secure well.
Clean location and release rig.
RECEIVED
.ltll 06 1995
Alaska Oil & Gas Cons. Commission
Ancho,"~..ie
DRILLING FLUID PROGRAM
Well 2T-37
Density
PV
YP
Viscosity
Initial Gel
10 Minute Gel
APl Filtrate
pH
% Solids
Spud to 9-5/8"
surface casing
9.0-10.0
15-25
15-35
50-80*
5-15
15-40
10-12
9.5-10
+10%
Drill out to
weight up
8.4-9.6
5-15
5-8
30-40
2-4
4-8
8-10
9.5-10
4-7%
Weight up
to TD
10.8
10-18
8-12
35-50
2-4
4-8
4-5 through Kuparuk
9.5-10
<12%
Drilling Fluid System:
Tandem Brandt Shale Shakers
Triple Derrick Shale Shakers
Solids Processing System to minimize drilling waste
Mud Cleaner, Centrifuges, Degasser
Pit Level Indicator (Visual and Audio Alarm)
Trip Tank
Fluid Flow Sensor
Fluid Agitators
Notes-
RECEIVED
0 6 1995
Alaska 0ii & Gas Cons. Commission
Anchor~..:.;~
Drilling fluid practices will be in accordance with the appropriate regulations stated in 20
AAC 25.033.
Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5
ppg EMW and a gas gradient of 0.11 psi/ff. This shows that formation breakdown would
occur before a surface pressure of 1,700 psi could be reached. Therefore, ARCO Alaska,
Inc. will test the BOP equipment to 3000 psi.
The nearest existing well to 2T-37 is 2T-21. As designed, the minimum distance between
the two wells would be 13.0' @ 400' MD.
Annular Pumping Activities:
Incidental fluids developed from ddlling operations will be hauled to the nearest permitted
disposal well or will be pumped down the surface/production casing annulus of an existing
well. That annulus will be left with a non-freezing fluid during any extended shut down (> 4
hr) in pumping operations. The 2T-37 surface/production casing annulus will be filled with
diesel after setting 7" and prior to the drilling rig moving off of the well. If isolation is
required per regulations on significant hydrocarbons, the annulus will later be sealed with
cement from the surface shoe to the base of the permafrost, with Arctic pack fluid or diesel
from the base of the permafrost to the surface.
It is requested that 2T-37 be permitted for annular pumping occurring as a result of the
drilling project on DS 2T, per proposed regulations 20 AAC 25.005 (k). Any zones
containing significant hydrocarbons will be isolated prior to initiating any annular pumping.
Surface casing will be set in the thick continuous shales below the base of the West Sak
Sands. There will be no USDW's open below the shoe or potable/industrial water wells
within one mile of the receiving zone.
Drilling Area Risks:
Risks in the 2T-37 drilling area include lost circulation and high pressures in the Kuparuk
formation. Lost circulation above the Kuparuk will be addressed with lost circulation
material (LCM) and reduced circulating rates as needed. The 7" casing will be topset
above the Kuparuk and a 5" liner run to TD if lost circulation cannot be controlled with LCM
and reduction of circulating pressure alone. Efforts to reduce Kuparuk geopressure at the
target location and careful analysis of pressure data from offset wells show that a mud
weight of 10.8 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement.
The 9-5/8" casing shoe will be tested to an equivalent mud weight of 12.5 ppg upon drilling
out of the surface casing.
*Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds.
Created by : jones For: D
iDate plotted : 6-Ju1-95
IPIot Reference is .37 Version #3.
iCoordinates are in feet reference slot #37.
!True Vertical Depths are reference RKB.
I
500 _
0
0
c; -
CXl 0 _
,.
~ 500
0
1000
1500_
_
2000_
_
iD 25oo_
0
3000_
-
3500_
J -
~- 400O_
J 4500
I
V
5000.
ARCO ALASKA,
I Structure : Pad 2T Well : 37
I
J Field : Kuparuk River Unit Location : North Slope, Alaska
< - - W e s f 1 ' 525.00
7800 7150 6500 5850 5200 4550 3900 3250 2600 1950 1300 650 0 650
5500_
_
6000_
_
65004
S 63.4 DE G W ~,n Turn [o TargetJ~
8259' TO TARGET
E~,~-/~p West Sok Sands
,'"'~Base West Sak Sands
.~/8 Casing Pt
1324' FSL, 1877' FEL SURFACE LOCATION:
SEC. 10, T11N, RSE 98' FNL, 556' FWL
/.~5 SEC. 12, T11N, RSE
RKB
ELEVATION:
122'
/~'eBegin Angle Drop
KOP TVD=500 TMD=500 DEP=O~se HRZ
5.64 Begin Turn to Torget~ TARGET LOCATION:
1484' FSL, 1549' FEL
10,66
16..353 DEC / 100' DLS
22.20
28.11 B/_?ERMAFROST TVD=1502 TMD=1546 DEP=247
.34.05 T/UGNU SNDS TVD=1547 TMD=1598 DEP--273
40.01
45.98
51.95
57.92
T/ W SAK SNDS TVD=2261 TMD=2652 DEP=1050
63.90
EOC TVD=2289 TMD=2714 DEP=1085
SEC.10,T11N,RSE
TARGET
TVD=5844
TMD:10728
DEP=8259
SOUTH 3698
WEST 7.385
B/ W SAK SNDS TVD=2672 TMD=5597 DER=lB81
9 5/8" CSG PT TVD=2872 TMD=4057 DEP=2296
K-la TVD=3049 TMD=4465 DEP=2663
MAXIMUM ANGLE
64.27 DEC
RECEIVED
65O
..
0 ~
650
1300
_1950
_
_2600
-
_3250
.3900
. .
K-5 TVD=4552 TMD=7881 DEP=5740 ,III1 06 1995
Oil & Gas Cons. Commission
ichorr.}P
BEGINANGLE DROP TVD=5458 TMD=lO014 DEP=7661 64.00
60.00
B/ HRZ TVD=5699 TMD=10490 DEP---8071 56.00
52.00
TARGET - T/ ZONE C (EOD) TVD=5844 TMD=10728 DEP=8259-
T/ ZONE A TVD:5885 TMD=10791
T/ A3 SNDS 'rVD=5g02 TMD=10818 DEP=8328
B/ KUP SNDS TV0:6022 TMD=11005 DEP=8471
TARGET ANGLE
50 DEG
500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000
Scale 1 : 250.00
Vertical Section on 24:5.40 azimuth with reference 0.00 N, 0.00 E from slot #37
Created by : jones For: D PETRAStt
IDate plotted : 6-Jul-95
iPIot Reference is $7 Version
~CoordMates are in feet reference slot
True Vertical Depths are reference RKB.
A CO ALASKA,
]['nC.
Structure : Pod 2T
Well : $7
Field : Kuparuk River Unit Location : North Slope, Alaska
<-- West
280 260 240 220 200 180 160 140 120 100 80 60
0
C; 80
..
~- 60
40
20
0
40 20 0
1800
)00
4O
I
I
V
1200
%
2100
%
1100
1900
Scale 1 · 10.00
2O 40 60
. I I I
BO0
1200
600
8O c~
60 "
40 0
40
60 0
80 ~
.100
I
I
160
0 6 1995
Oil & Gas Cons. Commission
Anchor~.:';~,
- 280 260 24-0 220 200 180 160 140 120 1 O0 80 60 40 20
' < West
,..
20 40 60
Scale 1 : 10.00
160
240
Created by : jones For: ])
Dote plotted ; 6-Ju~-95
Plot Reference is 37 Version
Coordinates ore tn fee[ reference sJot
True Vertical Depths ore reference RKB.
,
iARCO ALASKA
Sfrucfure : Pod 21 Well : 37
LField : Kuparuk River Un[f
Location : Norfh Slope, Alaska
o
o
I
V
360
400
440
480
520
560
6OO
120
760
240
280
880
88O
84O
840 800
1900
760
760
720
720
68O
68O 840 600
<-- Wesf
560 520 480
440 400
360
Scale I · 20.00
520 280 240
3400
%
%
5300
3200
3100
%
%
¢
80
8O
120
160
200
240
280
520
560
1800
640 600
RECEIVED
560
400
440
~ 06 1995
m/~i 480
Alaska 0il & Gas Cons. Co on
Anchors ;-- 520
600 560
600
$cole 1 : 20.00
40
0
I
I
V
UPARUK RIVER UNi
20" DIVERTER SCHEMATIC
DO NOT SHUT IN DIVERTER
AND VALVE AT SAME TIME
UNDER ANY CIRCUMSTANCES.
.
MAINTENANCE & OPERATION
UPON INITIAL INSTALLATION:
· CLOSE VALVE AND FILL PREVENTER WITH WATER TO
ENSURE NO LEAKS.
· CLOSE PREVENTER TO VERIFY OPERATION AND
THAT THE VALVE OPENS IMMEDIATELY.
CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN
INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED.
OPEN VALVE TO ACHIEVE DIVERSION.
ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS
DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b)
1. 16"CONDUCTOR.
2. SLIP-ON WELD STARTING HEAD.
3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE,
4. 20" - 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET,
5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON
CLOSUREOF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN
PREVAILING WIND CONDITIONS.
6. 20" - 2000 PSI ANNULAR PREVENTER.
DKP 11/9/94
7
, 6
5
f_
13 5/8" 5000 JOP STACK
ACCUMULATOR CAPACITY TEST
1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL
WITH HYDRAUUC 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 MMIT
IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING
PRESSURE.
BOP STACK TEST
1. FILL BOP STACK AND MANIFOLD WITH WATER.
2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED.
PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT
IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD.
3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES
ON THE MANIFOLD. ALL OTHERS OPEN.
4. TEST ALL ~PONENTS TO 250 PSI AND HOLD FOR 3 MINUTES.
INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES.
BLEED TO ZERO PSI.
5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE
VALVES.
~ CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES.
7. TEST TO 250 PSI AND 30(X) PSI AS IN STEP 4.
CONTINUE TESTING ALL VALVES, UNES, AND CHOKES WITH A 250 PSI
LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST
ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE.
8. OPEN TOP PIPE RAMS AND CLOSE BO3-~OM PIPE RAMS. TEST BOTTOM
RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES.
9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PUll OUT OF HOLE,
CLOSE BUND RAMS AND TEST TO 3000 PSI FOR 3 MINUTES. BLEED TO
ZERO PSI.
10. OPEN BUND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD
AND UNES ARE FUll OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE
DRILLING POSITION.
11. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES.
12. TEST KEllY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP.
13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM.
SIGN AND SEND TO DRILLING SUPERVISOR.
14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY
OPERATE BOPE DAILY.
1. 16" - 2000 PSI STARTING HEAD
:::) 11" - 3000 PSI CASING HEAD
3. 11" - 3(X)0 PSI X 13-5/8"- 5000 PSI
SPACER SPOOL
4. 13-5/8" - 5000 PSI PIPE RAMS
5. 13-5/8" - 5000 PSI DRLG SPOOL W/
CHOKE AND KILL UNES
~ 13-5/8" - 5000 PSI DOUBLE RAM W/
PIPE RAMS ON TOP, BUND RAMS ON BTM
7. 13-5/8"-5000 PSI ANNULAR
Oil & Gas Cons. Commission
WELL PERMIT CHECKLIST
COMPANY
WELL NAME
GEOL AREA
PROGRAM: exp [] dev~ redrll [] serv []
ADMINISTRATION
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 drlg unit boundary.. N
6. Well located proper distance from ~ther wells ..... N
' 7. Sufficient acreage available in drilling unit ..... N
8. If deviated, is wellbore plat included . . . , .... N
9. Operator only affected party .............. N
10. Operator has appropriate bond in force ......... N
11. Permit can be issued without conservation order .... N
12. Permit can be issued without administrative approval.. N
13. Can permit be approved before 15-day wait ....... N
ENGINEERING
APPR DATE
14. Conductor string provided ............... ~> N
15. Surface casing protects all known USDWs ........ ~ N
16. CMT vol adequate to circulate on conductor & surf csg..~ N
17. CMT vol adequate to tie-in long string to surf csg . . . Y ~
18. CMT will cover all known productive horizons ...... ~ N
19. Casing designs adequate for C, T, B & permafrost .... ~ N
20. Adequate tankage or reserve pit ............. ~ N
21. If a re-drill, has a 10-403 for abndnmnt been approved..~"~N
22. Adequate wellbore separation proposed .......... ~ N
23. If diverter required, is it adequate .......... ~ N
24. Drilling fluid program schematic & equip list adequate .~ N
25. BOPEs adequate ......... .' · ........... ~ N
26. BOPE press rating adequate; test to ~O ~ psig.~9 N
27. Choke manifold complies w/API RP-53 (May 84) ...... (~ N
28. Work will occur without operation shutdown ....... ~ N
29. Is presence of H2S gas probable ............ G N
GEOLOGY
30.
31.
32.
33.
34.
Permit can be issued w/o hydrogen sulfide measures
Data presented on potential overpressure zones .....
Seismic analysis 9f shallow gas zones ..........
Seabed condition survey (if off-shore) .........
Contact name/phone for weekly progress reports .... [exploratory only]
GEOLOGY:
ENGINEERING: COMMISSION:
TAB
Comments/Instructions:
z
HOW/jo - A:~:ORMS~,cheklist rev 03/94
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.
Date_.
ALASKA COMPUTING CENTER
· ....... SCHLUMBERGER ....... ·
COMPANY NAME : ARCO ALASKA~ INC.
WELL NAME : 2T-37
FIELD NAME : KUPARUK RIVER
BOROUGH : NORTH SLOPE
STATE : ALASKA
API NUMBER : 50-103-20227-00
REFERENCE NO : 95310
ALASKA COMPUTING CENTER
* ........ SCHLUMBERGER .......
COMPANY NAME : ARCO ALASKA, INC.
WELL NAME : 2T-37
FIELD NAME : KUPARUK RIVER
BOROUGH : NORTH SLOPE
STATE : ALASKA
AP1 NUMBER : 50-1e$-20227-00
REFERENCE NO : 95510
LIS Tape Veri~|cation Listing
Schlumberger Alaska Computing Center
15-0CT-1995 10:46
**** REEL HEADER
SERVICE NAME : EDIT
DATE :
ORIGIN : FLIC
REEL NAME : 95310
CONTINUATION # :
PREVIOUS REEL :
COMMENT : ARCO ALASKA, INC., KUPARUK 2T-37, API #5~-103-2~227-0~
**** TAPE HEADER
SERVICE NAME : EDIT
DATE : 95/~0/18
ORIGIN : FLIC
TAPE NAME : 953~0
CONTINUATION # : ~
PREVIOUS TAPE :
COMMENT : ARCO ALASKA, INC., KUPARUK 2T-37, API ~50-~e3-2e227-ee
TAPE HEADER
KUPARUK RIVER
MWD/MAD LOGS
WELL NAME:
API NUMBER:
OPERATOR:
LOGGING COMPANY:
TAPE CREATION DATE:
JOB DATA
2T-37
501032022700
ARCO ALASKA, INC.
SCHLUMBERGER WELL SERVICES
18-0CT-95
BIT RUN ~ BIT RUN 2 BlT RUN 3
JOB NUMBER: 95310
LOGGING ENGINEER: NICOLS
OPERATOR WITNESS:
SURFACE LOCATION
SECTION: ~2
TOWNSHIP: I~N
RANGE: BE
FNL:
FSL: 98
FEL:
FWL: 556
ELEVATION(FT FROM MSL 0)
KELLY BUSHING: [22.00
DERRICK FLOOR: [22.00
GROUND LEVEL: 80.79
WELL CASING RECORD
OPEN HOLE CASING DRILLERS
BIT SIZE (IN) SIZE (IN) DEPTH (FT)
1ST STRING 8.5e0 9.625 4145.3
2ND STRING
PAGE:
LIS Tape Verification List|rig
Schlumberger Alaska Computing Center
15-0¢T-1995 10:46
3RD STRING
PRODUCTION STRING
REMARKS:
Well drilled BS-AUG through ~O-AUG-95 with CDR only.
All data was collected in a single bit run. The merged
MWD data includes MAD data from 4434~ to 4732~. There
was no depth shifting performed a% ARCO request.
$
$
· ,** FILE HEADER ****
FILE NAME : EDIT .Oel
SERVICE : FLIC
VERSION : ~0~C01
DATE : 95/10/~8
MAX REC SIZE : ~24
FILE TYPE : LO
LAST FILE :
FILE HEADER
FILE NUMBER:
EDITED MERGED MWD
Depth shifted and clipped curves; all bi~ runs merged.
DEPTH INCREMENT:
FILE SUMMARY
LDWG TOOL CODE START DEPTH STOP DEPTH
MWD 4434.~
$
BASELINE CURVE FOR SHIFTS: NONE
CURVE SHIFT DATA (MEASURED DEPTH)
EQUIVALENT UNSHIFTED DEPTH
BASELINE DEPTH MWD
MERGED DATA SOURCE
LDWG TOOL CODE
BIT RUN NO, MERGE TOP
MERGE BASE
MAD 1 4434.0 4732,0
MWD 1 4732.0 11080.0
$
REMARKS: This file contains %he Very Enhanced qRO resisi%ivi~¥
wi~h 2' average ~ha~ was reprocessed at GeoQuest as
well as merged MAD/MWD files, No depth shifting was
done at ARCO request,
$
LIS FORMAT DATA
PAGE:
LIS Tape Verification Listing
Sch I umberger A I aska Comput| ng Center
18-0CT-1995 10:46
PAGE:
DATA FORMAT SPECIFICATION RECORD
SET TYPE - 64EB **
TYPE REPR CODE VALUE
1 66 0
2 66
3 73 36
4 66
5 66
6 73
7 65
8 68 0.5
9 65 FT
11 66 28
12 68
13 66 0
14 65 FT
15 66 68
16 66
0 66 0
** SET TYPE - CHAN **
NAME SERV UNIT SERVICE APl API APl API FILE NUMB NUMB SIZE REPR PROCESS
ID ORDER ~ LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX)
DEPT FT 619193 00 000 00 ~ 1 1 1 4 68 ~00000~00~
RA MWD OHMM 619193 00 000 0~ 0 1 1 1 4 68 0000000000
RP MWD OHMM 619193 ~0 000 0~ ~ 1 1 1 4 68 00~00~0000
VRA MWD OHMM 619193 00 000 00 0 1 1 1 4 68 000~00000
VRP MWD OHMM 619193 ~0 000 00 0 1 1 1 4 68 0~000~0000
DER MWD OHMM 619193 00 000 00 0 I I I 4 68 00000~000~
ROP MWD FPHR 619193 00 000 0~ ~ 1 1 1 4 68 0000000000
GR MWD GAPI 619193 00 000 00 0 1 I 1 4 68 00000~0000
FET MWD HR 619193 00 000 00 0 1 I 1 4 68 0000000000
DATA
DEPT. 11~79.5~0 RA.MWD -999.250 RP.MWD -999.250 VRA.MWD
VRP.MWD -999.250 DER,MWD -999,250 ROP.MWD 60,201 GR.MWD
FET,MWD -999,250
DEPT. 4430.000 RA.MWD -999.250 RP.MWD -999.250 VRA.MWD
VRP.MWD -999.250 DER,MWD -999.250 ROP.MWD -999.250 GR.MWD
FET,MWD -999.250
-999.250
-999.25~
-999.250
97.952
LIS Tape Verification Listing
Schlumberger Alaska Computing Center
18-0CT-~995 10:46
PAGE:
END OF DATA
**** FILE TRAILER ****
FILE NAME : EDIT .¢01
SERVICE : FLIC
VERSION : 001C01
DATE : 95/1~/18
MAX REC SIZE : 1~24
FILE TYPE : LO
LAST FILE :
**~* FILE HEADER
FILE NAME : EDIT .¢02
SERVICE : FLIC
VERSION : 001601
DATE :
MAX REC SIZE : 1024
FILE TYPE : LO
LAST FILE :
FILE HEADER
FILE NUMBER: 2
EDITED MERGED MAD
Depth shifted and clipped curves; all MAD runs merged using earliest passes.
DEPTH INCREMENT: ~.50~
FILE SUMMARY
LDWO TOOL CODE START DEPTH STOP DEPTH
MAD
$
MERGED DATA SOURCE
LDWG TOOL CODE
4434.9 4732.0
MAD RUN NO. MAD PASS NO. MERGE TOP
MERGE BASE
$
REMARKS: This file contains the MAD pass da~a from Bit Run 1.
No depth shi~tin9 was done at ARCO request.
$
LIS FORMAT DATA
LIS Tape Verification Listing
Schlumberger Alaska Computing Center
18-0¢T-1995 10:46
** DATA FORMAT SPECIFICATION RECORD
SET TYPE - 64EB **
TYPe REPR CODE VALUE
I 66 0
2 66
3 73 28
4 66
5 66
6 73
7 65
8 68 9.5
9 65 FT
11 66 36
12 68
13 66 9
14 65 FT
15 66 68
16 66
9 66 I
SET TYPE - CHAN **
NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS
ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX)
DEPT FT 619193 99 009 99 0 2 1 1 4
RA MAD OHMM 619193 99 990 99 0 2 1 1 4
RP MAD OHMM 619193 99 999 99 0 2 1 1 4
DER MAD OHMM 619193 99 999 99 9 2 1 1 4
ROP MAD FPHR 619193 99 990 99 9 2 1 1 4
GR MAD GAPI 6i9193 99 999 99 0 2 1 1 4
FET MAD HR 619193 99 099 99 9 2 1 1 4
** DATA **
DEPT. 4732.999 RA.MAD 3.459 RP.MAD
ROP.MAD 827.938 GR.MAD 1~1.184 FET.MAD
3.213 DER.MAD
0.393
PAGE: 5
3.287
** END OF DATA
LIS Tape Verification Lis~ing
Schlumberger Alaska Computing Cen~er
**** FILE TRAILER ****
FILE NAME : EDIT .~02
SERVICE : FLIC
VERSION : 001C01
DATE : 95/i0/15
MAX REC SIZE : [e24
FILE TYPE : LO
LAST FILE :
~8-0CT-~995 10:46
**** TAPE TRAILER
SERVICE NAME : EDIT
DATE : 95/10/[8
ORIGIN : FLIC
TAPE NAME : 95310
CONTINUATION ~ : l
PREVIOUS TAPE
COMMENT : ARCO ALASKA, INC., KUPARUK 2T-37, AP1 #50-103-20227-e~
**** REEL TRAILER
SERVICE NAME : EDIT
DATE : g5/10/18
ORIGIN : FLIC
REEL NAME .: 95310
CONTINUATION ~ :
PREVIOUS REEL :
COMMENT : ARCO ALASKA, INC., KUPARUK 2T-37, AP1 #se-103-2e227-00
PAGE:
