Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout186-090Originated:Delivered to:3-Dec-20
Halliburton Alaska Oil and Gas Conservation Comm.
Wireline & Perforating Attn.: Natural Resource Technician
Attn: Fanny Haroun 333 West 7th Avenue, Suite 100
6900 Arctic Blvd.Anchorage, Alaska 99501
Anchorage, Alaska 99518
Office: 907-275-2605
FRS_ANC@halliburton.com
The technical data listed below is being submitted herewith. Please address any problems or
concerns to the attention of the sender above
WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #Digital #
1 3B-14 50-029-21287-00 906717380 Kuparuk River Leak Detect Log Field- Final 17-Sep-20 0 1
2 3B-14 50-029-21287-00 906717380 Kuparuk River Leak Detect Log Field- Final 18-Sep-20 0 1
3 3B-14 50-029-21287-00 906717380 Kuparuk River Leak Detect Log Field- Final 19-Sep-20 0 1
4 3B-14 50-029-21287-00 906717380 Kuparuk River Packer Setting Record Field- Final 18-Sep-20 0 1
5 3H-26 50-103-20208-00 906703718 Kuparuk River Multi Finger Caliper Field & Processed 11-Sep-20 0 1
6 3K-23 50-029-22771-00 n/a Kuparuk River Radial Bond Log Field- Final 7-Sep-20 0 1
7 3K-23 50-029-22771-00 n/a Kuparuk River Tubing Punch Record Field- Final 7-Sep-20 0 1
8 3N-15 50-029-21592-00 n/a Kuparuk River Leak Detect Log Field- Final 30-Aug-20 0 1
9 3N-15 50-029-21592-00 906726591 Kuparuk River Packer Setting Record Field- Final 24-Sep-20 0 1
10 3O-15 50-029-21797-00 906722930 Kuparuk River Leak Detect Log Field- Final 24-Sep-20 0 1
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:
Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518
FRS_ANC@halliburton.com
Date:Signed:
Transmittal Date:
Received by the AOGCC 12/04/2020
PTD: 1860900
E-Set: 34349
12/04/2020 Abby Bell
Originated:Delivered to:3-Dec-20
Halliburton Alaska Oil and Gas Conservation Comm.
Wireline & Perforating Attn.: Natural Resource Technician
Attn: Fanny Haroun 333 West 7th Avenue, Suite 100
6900 Arctic Blvd.Anchorage, Alaska 99501
Anchorage, Alaska 99518
Office: 907-275-2605
FRS_ANC@halliburton.com
The technical data listed below is being submitted herewith. Please address any problems or
concerns to the attention of the sender above
WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #Digital #
1 3B-14 50-029-21287-00 906717380 Kuparuk River Leak Detect Log Field- Final 17-Sep-20 0 1
2 3B-14 50-029-21287-00 906717380 Kuparuk River Leak Detect Log Field- Final 18-Sep-20 0 1
3 3B-14 50-029-21287-00 906717380 Kuparuk River Leak Detect Log Field- Final 19-Sep-20 0 1
4 3B-14 50-029-21287-00 906717380 Kuparuk River Packer Setting Record Field- Final 18-Sep-20 0 1
5 3H-26 50-103-20208-00 906703718 Kuparuk River Multi Finger Caliper Field & Processed 11-Sep-20 0 1
6 3K-23 50-029-22771-00 n/a Kuparuk River Radial Bond Log Field- Final 7-Sep-20 0 1
7 3K-23 50-029-22771-00 n/a Kuparuk River Tubing Punch Record Field- Final 7-Sep-20 0 1
8 3N-15 50-029-21592-00 n/a Kuparuk River Leak Detect Log Field- Final 30-Aug-20 0 1
9 3N-15 50-029-21592-00 906726591 Kuparuk River Packer Setting Record Field- Final 24-Sep-20 0 1
10 3O-15 50-029-21797-00 906722930 Kuparuk River Leak Detect Log Field- Final 24-Sep-20 0 1
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:
Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518
FRS_ANC@halliburton.com
Date:Signed:
Transmittal Date:
Received by the AOGCC 12/04/2020
PTD: 1860900
E-Set: 34348
12/08/2020 Abby Bell
1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown
Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program
Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Tubing Patch
ConocoPhillips Alaska, Inc.Development Exploratory
3. Address:Stratigraphic Service 6. API Number:
7. Property Designation (Lease Number):8. Well Name and Number:
9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s):
11. Present Well Condition Summary:
Total Depth measured 8,508' feet None feet
true vertical 6,713' feet None feet
Effective Depth measured 8,255 feet 7,973 feet
true vertical 6,517 feet 6,299 feet
Perforation depth Measured depth 8,221' - 8,270' feet
True Vertical depth 6,491' - 6,540' feet
Tubing (size, grade, measured and true vertical depth)2.875" J-55 8,044' 6,353'
Packers and SSSV (type, measured and true vertical depth)Safety Valve Baker FVL 1,777' 1,757'
Packer Brown HB 7,973' 6,299'
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:
Contact Phone:
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:
Junk measured
Burst Collapse
186-090
50-029-21592-00-00
ADL0025520 / ALK2556 KRU 3N-15
P.O. Box 100630, Anchorage, Alaska 99508
N/A Kuparuk River Field / Kuparuk River Oil Pool
Plugs measured
Packer measured
true vertical
Casing Length Size MD TVD
N/A N/A
N/ASurface4,284'9.625"4,321 3,637'N/A
Conductor 77'16"115'115'
N/AProduction8,459'7"8,497 6,705'N/A
Representative Daily Average Production or Injection Data
Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure
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.
Sara Carlisle / Stephanie Pilch
n2549@conocophillips.com
659-7126
Well Integrity & Compliance Specialist
Authorized Name:
Authorized Signature with date:
-----
-----
N/A
t
Fra
O
O
6. A
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L
PG
R
Form 10-404 Revised 3/2020 Submit Within 30 days of Operations
By Samantha Carlisle at 8:31 am, Sep 30, 2020
Matthew J Miller Digitally signed by Matthew J Miller
Date: 2020.09.30 08:02:25 -08'00'
SFD 9/30/2020
DSR-10/1/2020VTL 11/03/20 RBDMS HEW 10/27/2020
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
September 30, 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 the two retrievable tubing
patches set across two known tubing leaks in producer KRU 3N-15 (PTD 186-090).
Please contact Stephanie Pilch/Sara Carlisle or myself at 659-7126 if you have any questions.
Sincerely,
Matt Miller
Well Integrity & Compliance Specialist
ConocoPhillips Alaska, Inc.
Matthew J
Miller
Digitally signed by
Matthew J Miller
Date: 2020.09.30
08:01:48 -08'00'
Event Summary
Executive
Summary
3N-15 Failed a TIFL in May of 2020. A tubing leak was found @ 7962' md below a previously set
tubing patch. The upper tubing patch was pulled & a new tubing patch was installed from 7983' md to
7952' md to cover this new leak. And a 2nd tubing patch was installed from 7592' md to 7963' md to
cover the old leak. The integrity of the tubing & both patches was confirmed w/ CMIT-TxIA, MIT-T &
DDT-IA.
05/29/20 TIFL Failed.
08/30/20 PERFORM LEAK DETECTION LOG AND FIND LEAK AT 7962'.
09/24/20
PULLED 2.28" UPPER PATCH ASSEMBLY @ 7562' RKB (ALL PARTS RECOVERED FROM UPPER & LOWER PACKER);
BRUSH n' FLUSH TBG & PATCH INTERVALS DOWN TO D-NIPPLE @ 8011' RKB; DRIFT W/ DMY PATCH (36' OAL)
DOWN TO 7995' RKB; SET LOWER 2.28" P2P W/ ME @ 7983' RKB (3.55' OAL); SET TTS TEST TOOL @ 7983' RKB
& LEFT LRS TO CMIT TBG X IA TO 3000 PSI (PASS). IN PROGRESS. PRE CMIT
T/I/O=2120/2110/540, PRESSURE UP INITIAL T/I/O= 3000/3050/575, 15 MIN T/I/O= FINAL
T/I/O=2900/2950/575. 30 MIN. T/I/O= 2850/2900/575 (PASS).
09/25/20
PULLED TTS TEST TOOL @ 7983' RKB; SET UPPER 2.28" P2P, SPACER PIPE, & ANCHOR LATCH (30.81' OAL /
CPAL287017) @ 7952' RKB; SET 2 7/8 TTS TEST TOOL @ 7952' RKB; LRS CMIT TBG X IA TO 3000 PSI (PASS). IN
PROGRESS.
CMIT TBG x IA 3000 INITIAL T/I/O=2050/2125/580, PRESSURE UP T/I/O= 3000/3075/610, 15 MIN
T/I/O=2900/2975/610. 30 MIN. T/I/O= 2875/2950/610 (PASS).
06/26/20
PULLED TTS TEST TOOL @ 7952' RKB; SET LOWER 2.28" P2P W/ ME @ 7592' RKB (3.57' OAL); RAN TTS TEST
TOOL & CMIT TBG X IA TO 3000 PSI (PASS); SET UPPER 2.28" P2P, SPACER, ANCHOR LATCH W/ ME @ 7562.97'
(29.81' OAL); MITT TO 3000 PSI (PASS); OBTAIN GOOD IA DDT AND ATTEMPT TO CMT TBG X IA TO 3000 PSI. IN
PROGRESS.
PRE CMIT TBG x IA T/I/O= 2175/2125/600 PRESSURE UP (2.3 BBLS) T/I/O= 3000/3075/620, 15 MIN T/I/O=
2950/3000/620, 30 MIN T/I/O= 2925/2975/620 ****PASS****
PRE MITT T/I/O= 2050/950/580, PRESSURE UP (.1 BBL) T/I/O= 3025/975/580, 15 MIN T/I/O= 2975/975/580, 30
MIN T/I/O= 2975/975/580 ****PASS****
06/27/20
RAN TTS TEST TOOL TO UPPER P2P @ 7562' RKB & CMIT TBG x IA W/ TEST TOOL IN UPPER PACKER @ 7563'
RKB (PASS), DRAW DOWN IA (PASS). COMPLETE.
PRE CMIT TBG x IA T/I/O= 2075/2050/600, PRESSURE UP T/I/O= 3000/3000/620, 15 MIN T/I/O=
2950/2925/620, 30 MIN T/I/O= 2940/2900/620 ****PASS****
Annular Communication Surveillance
1-Well Name:33N-15
Start Date:1-Jul-2020
29 Days:90
End Date:29-Sep-2020
50
60
70
80
90
100
110
120
130
140
150
0
500
1000
1500
2000
2500
1-Jul-204-Jul-207-Jul-2010-Jul-2013-Jul-2016-Jul-2019-Jul-2022-Jul-2025-Jul-2028-Jul-2031-Jul-203-Aug-206-Aug-209-Aug-2012-Aug-2015-Aug-2018-Aug-2021-Aug-2024-Aug-2027-Aug-2030-Aug-202-Sep-205-Sep-208-Sep-2011-Sep-2014-Sep-2017-Sep-2020-Sep-2023-Sep-2026-Sep-2029-Sep-20Temperature (degF)Pressure (PSI)Pressure Summary
WHP IAP OAP WHT
0
0.1
0.2
0.3
0.4
0.5
0.6
0.7
0.8
0.9
1
1-Jul-20Injection Rate (BPD or MSCFD)Injection Rate Summary
DGI MGI PWI SWI BLPD
Annular Communication Surveillance
3N-15 90-Day Bleed History
WELL_ID TIME STR-PRES END-PRES DIF-PRES CASING SERVICE
3N-15 9/28/20 575 340 235 OUTER GLO
3N-15 9/28/20 340 600 -260 OUTER GLO
3N-15 9/28/20 980 540 440 OUTER GLO
3N-15 7/28/20 1910 1830 80 INNER GLO
Originated:
Halliburton
Wireline & Perforating
Attn: Fanny Sari
6900 Arctic Blvd.
Anchorage, Alaska 99518
Office: 907-275-2605
FRS—ANC@halliburton.com
Delivered to:
Alaska Oil and Gas Conservation Comm.
Attn.: Natural Resource Technician
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
The technical data listed below is being submitted herewith. Please address any problems or
concerns to the attention of the sender above
Transmittal Date:
RECEIVED
/
APR 2 3 2020
A0G fC1_`
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
r
Date: L
186090
32 80 7
LOGGING DATE I PRINTS #
15 -Feb -20
18 -Feb -20
21 -Jan -20
2 -Feb -20
3 -Feb -20
30 -Dec -19
1 -Feb -20
LO -Feb -20
L8 -Jan -20
_9 -Feb -20
Signed ,.;
-J
23 -Apr -20
CD #
1
WELL NAME
API #
JOB TYPE
DATA TYPE
1
2
3A-08
3K-23
50-029-21445-00
50-029-22771-00
50-029-22751-00
50-029-21541-00
ESERVICE0jRDER#FFIELDNAME
Kuparuk
Kuparuk
Multi Finger Caliper
Radial Cement Bond Log
Final -Field
Final -Field
Final -Field
Final -Field
SBHP and Plug Setting Record
4
906290370String
Shot Record
5
7
6gN-15
906290370
905268412
Tubing Punch Record
Packer Set Record
Packer Set Record
8
9
10
50-029-21592-00
50-029-21729-00
906251137
906236139
Kuparuk
Kuparuk
Packer Set Record
Packer Set Record
Final -Field
Final -Field
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
r
Date: L
186090
32 80 7
LOGGING DATE I PRINTS #
15 -Feb -20
18 -Feb -20
21 -Jan -20
2 -Feb -20
3 -Feb -20
30 -Dec -19
1 -Feb -20
LO -Feb -20
L8 -Jan -20
_9 -Feb -20
Signed ,.;
-J
23 -Apr -20
CD #
1
ALASKA OIL AND GAS CONSERVATION COMMISSION rl Cu C I V C V
REPORT OF SUNDRY WELL OPERATIONS
1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑
Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ >irhe p e rogram ❑❑
Plug for Redrill ❑ 'erforate New Pool ❑ Repair Well ❑Q Re-enter Susp Well ❑
2. Operator
4. Well Class Before Work:
5. Permit to Drill Number: yN
Name: ConocoPhlllips Alaska, Inc.
Development ❑� Exploratory ❑
Stratigraphic ❑ Service ❑
186-090
3. Address: P. 0. Box 100360, Anchorage, Alaska
6. API Number:
99510
50-029-21592-00
7. Property Designation (Lease Number):
8. Well Name and Number: KRU 3N-15
ADL 25520, ALK 2556
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 8,508 feet Plugs measured None feet
true vertical 6,713 feet Junk measured None feet
Effective Depth measured 0 feet Packer measured 7,973 feet
true vertical 0 feet true vertical 6,299 feet
Casing Length Size MD TVD Burst Collapse
CONDUCTOR 77 feet 16" 115' MD 115' MD
SURFACE 4,284 feet 9-5/8" 4,321' MD 3637' MD
PRODUCTION 8,459 feet 7" 8,497' MD 6704' MD
Perforation depth: Measured depth: 8221-8270 feet
True Vertical depth: 8237 - 8248 feet
Tubing (size, grade, measured and true vertical depth) 2-7/8" J-55 8,043' MD 6,353' TVD
Packers and SSSV (type, measured and true vertical depth) SAFETY VLV - BAKER FVL SAFETY VI 1,777' MD 6,299' TVD
P2P UPPER PATCH PKR 7,568' MD 5,989' TVD
P2P LOWER PATCH PKR 7,575' MD 6,006' TVD
PACKER - BROWN HB PACKER 7,973' MD 6,299' TVD
12. Stimulation or cement squeeze summary:
Intervals treated (measured): N/A
Treatment descriptions including volumes used and final pressure: N/A
13. Daily Average Production or Injection Data
Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure
r��Representative
Prior to well operation:
Subsequent to operation: - - - - -
14. Attachments (required per20AAC 25.070, 25.071, x 25.283)
15. Well Class after work:
Daily Report of Well Operations 0
Exploratory ❑ Development Service ❑ Stratigraphic Q
16. Well Status after work: Oil p Gas ❑ WDSPL ❑
Copies of Logs and Surveys Run n
Printed and Electronic Fracture Stimulation Data ❑
GSTOR ❑ WINJ Q WAG GINJ [] SUSP El 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:
Contact Name: Sara Carlisle
Authorized Name: Sara Carlisle
Contact Email: Sara.E.Carlisle@conocophillips.com
Authorized Title: Well Integrity & Compliance Specialist
_ Z Contact Phone: (907) 659-7126
Date:
Authorized Signature: ev
V 7-L 7/0/,z0
'4 Form 10-404 Revised 4/2017 RBDMS!� FEB 10 2020 Submit Original Only
3N-15
DESCRIPTION OF WORK COMPLETED
Event Summary: 3N-15 failed a TIFL in August of 2019. A leak detect log identified a
Date tubing leak at 7,575' MD. A tubing patch was installed from 7,590' MD to 7,568' MD. The
integrity of the tubing and patch was confirmed via a passing TIFL performed 1124/20.
10/30/19
01/16/20
01/17120
01/18/20
01/19/20
01/20/20
RIH W/ LEAK DETECT TOOLS. LLR ESTABISH AT 0.6 BBL/MIN AT 1700 PSI LEAK FOUND
AT 7575.5 RKB. LRS U -TUBE FREEZE PROTECT.
BRUSH n' FLUSH & GAUGE TBG TO 2.28" TO TAG D -NIP @ 801 1'RKB; DEPLOY 2.29"
CATCHER ASSEMBLY; PULLED OV @ 7916' RKB & SET DMY; PULLED EXT PKG DMY @
7575' RKB; PULLED CATCHER @ 8007' RKB; ATTEMPT TO RUN 2.25" x 20' DMY PATCH
BUT UNABLE TO PASS 6980' RKB; BRUSH n' FLUSH TBG AGAIN W/ 2.28" GAUGE RING.
DRIFTED TBG W/ MUTIPLE TANDEM 2.29" BROACH RUNS OF VARIOUS LENGTHS TO
7650' RKB; W/ 2.29" x 24' DMY P2P PATCH DRIFTED TO 7650' RKB.
SET LOWER 2.29" P2P @ 7590' RKB; SET 2.5" TTS TEST TOOL @ 7588' RKB & LRS
PERFORM CIRC -OUT 180 BBLS CISW FOLLOWED BY 85 BBLS DIESEL OWN TBG UP IA;
U TUBE; CMIT TO 2500 (PASS); PULL TTS TEST TOOL (a) 7588' RKB.
SET UPPER 2.29" P2P & SPACER PIPE ANCHOR LATCH ASSEMBLY @ 7568' RKB; SET
2.5" TTS TEST TOOL @ 7566' RKB (UNABLE TO MITT, IA SLOWLY TRACKING); W/ 2.5"
HOLEFINDER DETERMINE GLV #5 @ 6665' RKB (10-31-19 LOG) LEAKING; PULLED DMY
O 7168' RKB & SET OV; PULLED GLV 6665' RKB.
TOOL @ 7566' RKB. JOB COMPLETE.
MIT -T TO 2500 (PASS)
PRE-TEST T/I/O = 1950/1925/7
PUMP 0.10 BBLS TO TEST PRESSURE
INITIAL T/110 = 2575/1925/860
15 MIN T/I/O = 2550/1925/860
30 MIN T/1/0 = 2550/1925/860
CMIT TO 2500 (PASS)
PRE-TEST T/I/O = 2550/1850/860
PUMP 0.8 BBLS TO TEST PRESSURE
INITIAL T/I/O = 2625/2500/860
15 MIN T/I/O = 2610/2480/860
01/24/20
3N-15
DESCRIPTION OF WORK COMPLETED
RE-TIFL (PASSED)
SI WELLHEAD @ WV, DOUBLE BLOCK AL LINE.
STACKED WHP'S TO T/I/O = 1215/1205/510 IN 60 MIN. IA FL @ 6339' (716' OUTFLOW).
BLED AL LINE TO 300 PSI.
BLED IA TO 700 PSI IN 45 MIN.
STARTING T/I/O = 1250/700/500. IA FL @ SAME LOCATION.
15 MIN T/I/O = 1270/700/500.
30 MIN T/I/O = 1280/700/500. IA FL @ SAME LOCATION.
45 MIN T/I/O = 1290/700/500
60 MIN T/I/O = 1300/700/500. IA FL @ SAME LOCATION.
FINAL T/I/O = SI 1300/700/500.
KUP PROD WELLNAME 311 WELLBORE 3N-15
Well Attributes Max Angle & Mu I L,
Conoeol'hillips dela Name We11Eae APINVA WeIIWre Stawz cl pl MD (xKR1 Act Bim (ttKB)
Alaska, DC. KUPARUK R V R NII' 2921 PROD 5.80 3,600.00 8.508.0
Comment Has Hong Wh minulm Era Dee KBGra am Rig Release 0rte
SSSM Locked 0ut 150 12/182014 Lem WO: 39.49 511111986
awls.lrzvmm++:anza AM Last Tag
VMIW aNemaf (acme
Mmmenon
Depth MKB)Ena
Da[<
WellEwe
Dust MM ay
last Teg: RKB: (Est. 39' of Fill, Leaving 34' of Open
8.255.0
N282019
314-15
asirmal
_. ......._.
..........
Peds)
Last Rev Reason
1v rvGCR;-0
Armature Ena Gae walM1nre Lear Moa By
Rev Reason Set Patch, do GLVS 1/20/2020 3N-15 famaj
Casing Strings
casing Dezcaptlon Do Irm in pp Top MKR set Depthri set Depih"T"m WOLen O... Grnae roprM1reaa
CONDUCTOR 16 15.06 3H0 115.0 1150 6250 H-40 WELDED
LONDVCTOF: 3eorls.
jouda.
Casing Deaniplim OD(inl IDlinl Top IRKS) sN DgAh IXKB Set Depih(N0--W1ILen II... Gratle Top TM1reaa
SURFACE 9518 8.92 37.0 4,321.4 3.6768 76.00 J-55 BTC
GAFETY'vLvi. rd
...Pubn ODarm iabill Top MKB) seupurp.-I Set OepiM1 jNDL_W1iLen iL.. Gmtle TopTM1reatl
PRODUCTION 7 6.28 37.6 8.4965 6.7015 26.00 J-55 BTC
Tubing Strings
.as LIFT:$355.]
Tubing D........ String M a... ID( in) ToppMBl sa+Depfh (X.. is TLmd (1W)(,. Wt11hM1 Graae Top Cmeluon
TUBING 27/8 244 35.0 8043.9 6,353.4 6.50 J-55 EUEBrdABMod
Completion Details
1P1TVDl Top Incl Nominal
Trip(XKBf MKS) PI Ile. Des Lam uhn)
35.0 35.0 006 HANGER FMC TUBI NG HAN ER 2441
SURFACE: 37.64.aH.4-
1,777.1 1,79.1 22.40 SAFETY VLV BAKER FVL SAFEWVALVE(LOCKED OUT 6126189) 2,310
GAS UFr: 1.4.0
7,955.6 6285.1 3943 PBR BROWN PER 2.500
7.973.3 6,298.8 39.35 PACKER EROWNHBPACKER 3.000
GAS LIFT: 57250
8.011.4 6,328.2 39.20 NIPPLE CAMCO D NIPPLE -NO GO 2.250
8.043.1 6,3529 39.14 SOS BROWN SHEAR OUT SUB 2.441
GAS UFT�S3SS5
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top1..,
rop m0)
IxNBI
Taplod
111
Des Com Run Oate ID (int
GIS UFT B.Sfi5.0
7,568.0
5,989.0
40.83
Patch P2P(CPP29047) Wl Spacer Pipe and Anchor Latch 11192020 1.380
(CPAM7024) OAL 22' Max OD 2.285
GAS OFT, 7161
7,572.0
5,992.01
40.82
Spacer Pipe P-110 pacer Pipe 111&2020 1.360
PalMJ.Saso
7,5]5.0
5.994.2
40.2
TUBING LEAK BING LEAKIDENTIFIED WI LINE LDL, 0.68PM, 101 201 2.440
1'00 PSI, HOLDING 1200 PSI BACKPRESSURE ON A 9
"LNG LEA.0 7.5/SO
7.590.0
6,005.6
40.H1
Parch P21(CPP28J048)O AL 4' Max OD 2285" 11182020 1.380
GAS LIU 7`GSb
sPeeerom.7.D
Perforations &Slots
shin
Den
Pect, 7.Gle.0
GASOU.. TGR6
Top MISh
I atm RKB) I
TIP DRA1
MKa)
atm IND)
MKB)
MnkeJIDne
Dab
(shoesm
1
TYFe
�^
3WId
8.23>.0
6,491.0
6,503.4
A -3.3N45
11Y1969
B.
RPERF
BOOeg. phasing; 118
EnerJet
Fat.79
8,229.0
8,231.0
6,49'.2
6498.8
A.3,3N-15
]/1511986
1.0 IPERF
SINGLE SHOT; 123 deg.
phasing, 4- Jumbo Jet II Cad
PACKER 700,3
8231.0
8,237.0
6,/98.8
6,500.
A-3, 3N-15
7/15/1986
1.0 IP
RF
Sit NGLESH ;120deg.
phasing; 4'Jumbo Jel 11 Csg
xIPPLE e.p0.4
8,233.0
8,234.0
6,500.]
8.501.1
A-3, 3N-15
7115/1986
1.0 /PERF
SINGLE SOOT; 120 deg.
phasing; 4" Jumbo Jet 11 Csg
GPGAGPSI
8,247.0
8,268.0
6,511.2
6.52>.5
A-2,314-15
1/311989
8.0
RPERF
60 deg. phasing; 2118'
EnerJet
8.257.0
8,258.0
6,518.9
6.519.7
A -2,3N-15
7115/1986
1.0
IPERF
SINGLE SHOT; 120 deg.
phasing; d" Jumbo Jet 11 Csg
8,260.0
$261.
6521.3
6522.1
A-2, N-1
711511986
1.
/PERF
SINGLESHOT;1 deg.
phasing; 4" Jumbo Jet 11 CM
-RF
$262.0
6263.0
6522.8
6,U3.6
A-2,314-15
7/151198
to
TRE
SINGLE HOP 120deg.
phasing; 4 -Jumbo Jet 11 Cap
gvEaF: s.azl.oa.2a.a
IREBF: s.l..'2ar.
8265.0
8,266.0
6,95.2
65259
A-2, 3N-15
7/191986
1.0
/PERF
deg.
SINGLE a Jumbo
phasing; 4- Jumbo Jet II Csg
(PERF: 9.a31.Od.Z 10-
IPERP.6.M3 vs4o-
600.0
8,284.0
6,529.0
6.539.9
M2,3N-15
7115005
1.0
/PERF
120 deg. phasing; 4- Jumbo
Jet 11 Cag
Mandrel Inserts
st
RPERF; S247.O9.aaAp
mi
Top(IVD) Velve mhM1 Portshe TRO ftun
N Top MKB) (ttKB) Make MWeI OD pn) Sery Type Type (int IPz9 Run Date Com
I 2,385) 2,267.7 Meda TMPD 1 1 GAS LIF I GLV BK 0.156 1,30.0 10201 ll
2 4,490.0 3256.0 Marla TMPD 1 GAS LI GLV BK 0.156 ,29>.0 101 2011
PERF:6,...1 e-
3 5725.0 6,631.1 Marla TMPD 1 GAS LIFT GLV BK 0.188 1 1,329.011202020
4 6,353.5 5,081 Meda TMPD 1 GAS LIFT DMY BK0.000 1012012011
IPERF:S.,GA2Gi.o-
5 6,565.0 5.241.9 Merl. TMPD 1 GASLIFT GLV BK 0.168 1,313.0 1202020
IPERF;alss.oa.zaso-
6 7,168.5 5,888.2 MI TMPD 1 GAS LIFT OV BK 0.250 0.0 11192020
7 7,575.6 5,994.7 MarlaTMPD 1 GAS LIFT OPEN BK 11167020
8 7916.2 6254.7 MMP FMHO 112 1 GAS LIFT I DMY RK 0000 1/1612020
Notes: General & Safety
1PERR e,rmoe.2c4.D-
Ere Dae Ar
6117/2012 NOTE: IA. OA COMMUNICATION
101302008 NOTE UNKNOWN OBSTRUCTION@ 43M'
PRODUCTION 37.aaA9S5
ConocoPhillips
Alaska
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
February 4, 2020
Commissioner Jessie Chmielowski
Alaska Oil and Gas Conservation Commission
333 West 7ch Avenue, Suite 100
Anchorage, AK 99501
Commissioner Chmielowski,
Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for the retrievable tubing
patch set across a known tubing leak in producer KRU 3N-15 (PTD 186-090).
Please contact Stephanie Pilch or me at 659-7126 if you have any questions.
Sincerely,
S, CS'
Sara Carlisle
Well Integrity & Compliance Specialist
ConocoPhillips Alaska, Inc.
RECEIVED
FEB 0 5 2020
AOGCC
Originated:
Schlumberger
PTS - PRINT CENTER
6411 A Street
Anchorage, AK 99518
(907)273-1700 main (907)273-4760fax
Print
1F-17
2N-341
50.1
3N-15
TD -02
smittal
592.00
RIVER
RIVER
E5C2.00019 I KUPARUK RIVER
ESC2-00020 I KUPARUK RIVER
re
return via courier or sign/scan and email a copy
Delivered to:
./ AOGCC
:.t ATTN: Natural Resources Technician II
Alaska Oil & Gas Conservation Commision
333 W. 7th Ave, Suite 100
-,� Anchorage, AK 99501
WL
PPROF
WL
WL
WL
;.11
TRANSMITTALDATE ..-
TRANSMITTAL#
FIELD
FINALFIELD 22 -Nov -19
FINAL FIELD 23 -Nov -19
FINAL FIELD 24 -Nov -19
0
0
0
7
' A Transmittal Receipt signature confirms that a package (box,
9 envelope, etc.) has been received and the contents of the
package have been verified to match the media noted above. The
Date specific content of the CDs and/or hardcopy prints may or may
not have been verified for correctness or quality level at this
and OPAL point.
Schlumberger -Private
Originated:
Schlumberger
PTS - PRINT CENTER
6411 A Street
Anchorage, AK 99518
(907) 273-1700 main (907)273-4760fax
Delivered to:
y% AOGCC
�. ATTN: Natural Resources Technician If
1
Alaska Oil & Gas Conservation Commision
333 W. 7th Ave, Suite 100
—. Anchorage, AK 99501
3 147 6
TRANSMMALDATE'15-Nov-t9
TRANSMITTAL #
MI 5Nov19-JW 03
Schlumberger -Private
• •
WELL LOG TRANSMITTAL
To: Alaska Oil and Gas Conservation Comm. August 23, 2011
Attn.: Howard Okland
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
RE: Bottom Hole Pressure Survey: 3N -15
Run Date: 8/22/2011
The technical data listed below is being submitted herewith. Please address any problems or
concerns to the attention of:
Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518
3N -15
Digital Data in LAS format, Digital Log Image file ) 1 1 CD Rom -
50- 029 - 21592 -00 1 /
l
Bottom Hole Pressure Survey Log 1 Color Log
50- 029 - 21592 -00
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE
TRANSMITTAL LETTER TO THE ATTENTION OF:
Halliburton
Wireline & Perforating?, s
Attn: Klinton Wood
6900 Arctic Blvd.
Anchorage, Alaska 99518
Office: 907 - 273 -3527
Fax: 907 - 273 -3535
klinton.wood@halliburton.com
Date: a„� �.. LI Signed: i,k0i/A.4
)8 O?
• •
y/
ConocoPhillips
Alaska
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
October 23, 2008
Mr. Tom Maunder
Alaska Oil & Gas Commission
333 West 7~' Avenue, Suite 100
Anchorage, AK 99501 Q t _ ~ ~ ~ d
~ O 1~7 ~ 5
3~"
Dear Mr. Maunder:
Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRLn. Each of
these wells was found to have a void in the conductor. These voids were filled with cement if
needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As
per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that
the treatments took place and meets the requirements of form 10-404, Report of Sundry
Operations.
The cement was pumped October 19, 2008 and the corrosion inhibitor/sealant;_was pumped
October 21, 2008. The attached spreadsheet presents the well name, top of cement depth prior to
filling, and volumes used on each conductor.
Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions.
t~
Sincerely,
G~
;~
MJ L eland
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
natR± 10/22/2008
..~~',
Well Name
PTD #
Initial top of
cement
Vol. of cement
um ed
Final top of
cement
Cement top off
date
Corrosion
inhibitor Corrosion
inhibitor/
sealant date
ft bbls ft al
3N-01 185-313 32' 5.00 21" 10/19/2008 3.4 10/21/2008
3N-02A 186-032 66' 10.00 4" 2" 10/19/2008 10.2 10/21/2008
3N-03 186-016 43' 6.00 22" 10/19/2008 5.1 10/21/2008
3N-04 186-017 83' 9.00 24" 10/19/2008 10.2 10/21/2008
3N-05 186-026 21" NA 21" NA 2.55 10/21/2008
3N-07 186-028 20' 3.50 21" 10/19/2008 3.4 10/21/2008
3N-08A 186-068 8' 1.50 21" 10/19/2008 5.1 10/21/2008
3N-09 186-030 14' 2.50 21" 10/19/2008 4.25 10/21/2008
3N-10 186-072 97' 12.00 5'8" 10/19/2008 15.3 10/21/2008
3N-12 186-079 62' 9.50 4'7" 10/19/2008 17 10/21/2008
3N-13 186-081 17' 2.00 35" 10/19/2008 4.25 10/21/2008
3N-14A 207-119 21" NA 21" NA 3.4 10/21/2008
3N-15 186-090 64' 8.00 20" 10/19/2008 6.8 10/21/2008
3N-16 186-091 71' 8.50 30" 10/19/2008 3.75 10/21/2008
3N-17 186-092 59' 6.00 22" 10/19/2008 5.1 10/21/2008
3N-18 186-093 49' 6.40 28" 10/19/2008 5.95 10/21/2008
3N-19 201-225 16" NA 16" NA 3.4 10/21/2008
ARCO AIaska, Inc.
Date:
February 17, 1989
Transmittal #: 7429
RETURN TO:
ARCO Alaska, Inc.
Attn: Brenda K. Miernyk
Kuparuk Records Clerk
ATO-1119
P.O. Box 100360
Anchorage, AK 99510-0360
Transmitted herewith are the following items. Please acknowledge receipt and return
one signed copy of this transmittal.
3 F- 1 I Sub-Surface Pressure Survey I 0 o 06 - 88
3 H - 12 Kuparuk Well Pressure Report 8 - 29 - 88
30-07 Kuparuk Well Pressure Report 12-20-88
3 F- 10 Kuparuk Well Pressure Report 8 - 29 - 87
3 F- 06 Kuparuk Well Pressure Report 8 o 29 - 87
3 F- 02 Kuparuk Well Pressure Report 8 - 29 - 89
3 F- 16 Kuparuk Well Pressure Report 8 - 17- 87
3 F- 16 Kuparuk Well Pressure Report 8 - 17- 87
3 F- 11 Kuparuk Well Pressure Report 8 o 29 - 87
3 F- 04 Kuparuk Well Pressure Report 6 - 26 - 87
3 F- 05 - Kuparuk Well Pressure Report I 2- 12- 88
3 F- 13 Kuparuk Well Pressure Report 12- 31 - 88
3 N - 10 Kuparuk Well Pressure Report 6 - 1 I - 87
3 N- 10 Kuparuk Well Pressure Report 6 - 11 - 87
3 N - 04 Kuparuk Well Pressure Report 9 - 01 - 87
3 N - 09 Kuapruk Fluid Level Report 5 - 04 - 87
3 O-14 Kuparuk Fluid Level Report 2- 13 - 89
3 O- 14 Kuparuk Fluid Level Report ' 2- 10 - 89
3 M - 18 Kuparuk Fluid Level Report 2 - 10 - 89
3 F- 16 Kuparuk Fluid Level Report 6 - 05 - 87
3 F- 13 Kuparuk Fluid Level Report 6 - 09 - 87
3 F- 13 Kuparuk Fluid Level Report 6 - 18 - 87
3 F- 13 Kuparuk Fluid Level Report 6 - 16 - 87
3 F- 13 Kuparuk Fluid Level Report 6 - 21 o 87
3 F - 08 Kuparuk Fluid Level' Report 5 - 08 - 87
3 F- 16 Kuparuk Fluid Level Report 8 - 18 - 87
3 F- 16 Kuparuk Fluid Level Report 8 - 24 - 87
3 F- 13 Kuparuk Fluid Level Report 6 - 05 - 87
3 F - 16 Kuparuk Fluid Level Report 6 - 2 / 3 - 87
3 F- 16 Kuparuk Fluid Level Report 8 - 5 - 87
3 F- 16 Kuparuk Fluid Level Report 6 - 5 - 87
3 F- 14 Kuparuk Fluid Level Report 9 - 8 - 87
#7-889
Amerada
Sand 'A'
Amerada
Amerada
Amerada
Sand 'A'
Sand 'A'
Amerada
Sand 'A'
Both Sands
Both Sands
Sand 'A'
Casing
Casing
Casing
Casing
Tubing
Casing
Casing
Casing Ancti0rage
Tubing
Casing
Casing
3F-14
3F-06
3F-1-4
3F-08
3F-14
3F-09
3F-05
3F-09
3F-06
3F-05
3N-10
3N-10
3N-11
3N-10
3N-05
3N-04
3N-13
3N-11
3N-18
3N-17
3N-07
3N-15
3N-05
3N-09
3N-04
3N-14
3N-08
3N-06
3N-02
3N-10
3N-10
3N-10
· 3N-10
3N-10
3N-10
3N-10
3N-07
3N-01
3N-04
3N-04
3N-09
3N-10
Receipt
Kuparuk Fluid
Kuparuk Fluid
Kuparuk Fluid
Kuparuk Fluid
Ku ~aruk Fluid
Ku ~aruk Fluid
Ku ~aruk Fluid
Ku ~aruk Fluid
Ku ~aruk Fluid
Ku ~aruk Fluid
Ku~aruk Fluid
Ku ~aruk Fluid
Ku ~aruk Fluid
Kuoaruk Fluid
Kuoaruk Fluid
Ku ~aruk Fluid
Ku ~aruk Fluid
Ku ~aruk Fluid
Kuoaruk FlUid
Ku~aruk Fluid
Ku ~aruk Fluid
Ku ~aruk Fluid
Ku~aruk Fluid
Ku ~aruk Fluid
Ku~aruk Fluid
Ku ~aruk Fluid
Ku ~aruk Fluid
Ku 3aruk Fluid
Ku 3aruk Fluid
Ku ~aruk Fluid
Ku 3aruk Fluid
Ku ~aruk Fluid
Ku ~aruk Fluid
Ku ~aruk Fluid
Ku ~aruk Fluid
Ku ~aruk Fluid
Ku ~aruk Fluid
Ku ~aruk Fluid
Ku ~aruk Fluid
Ku ~aruk Fluid
Ku ~aruk Fluid
Ku ~aruk Fluid
Acknowledged:
Level Report
Level Report
Level Report
Level Report
Level Report
Level Report
Level Report
Leyel Report
Level Report
Level Report
Level Report
Level Report
Level Report
Level Report
Level Report
Level Report
Level Report
Level Report
Level Report
Level Report
Level Report
Level Report
Level Report
Level Report
Level Report
Level Report
Level Report
Level Report
Level Report
Level Report
Level Report
Level Report
Level Report
Level Report
Level Report
Level Report
Level Report
Level Report
Level Report
Level Report
Level Report
Level Report
9-11-87
12-06-86
9-1 I-87
10-11-87
9-16-87
4-11-88
4-08-88
4-01 -88
3-26-88
1 -30-88
10-12-87
10-15-87
10-28-87
10-28-87
10-28-87
10-28-87
3-19-87
9-12-87
9-10-98
9-10-87
9-10-87
9-12-87
9-08-87
9-0'1 -87
9-01 -87
9-06-87
9-06-87
9-06-87
9-06-87
6-01 -87
5-31 -87
6-03-87
6-06-87
.6-08-87
6-09-87
6-25-87
4-17-87
4-18-87
6-17-87
6-20-87
5-07-87
8-24-87
Date'
Casing
Tubing
Casing
Tubing
Casing
Casing
Casing
Casing
Casing
Casing
Casing
Casing
Tubing
Tubing
Tubing
Tubing
Tubing
Tubing
Tubing
Tubing
Tubing
Tubing
Tubing
Tubing
Tubing
Tubing
Tubing
Tubing
Tubing
Casing
Casinc~
Casinc.
Casinc~
Casinc~
Casinc~
Casinc~
Casinc~
Casino.
Casing -~,-- ~..
Alaska Oil &
....... ¢rn~orage
DISTRIBUTION-
D&M State of Alaska - Mobil Chevron Unocal SAPC
ARCO Alaska, Inc.
?~:~',z ~ ~fi:%~
April 21, 1988
Mr. C. V. Chatterton
Commissioner
State of Alaska
Alaska Oil and Gas Conservation Commission
3001 Porcupine Drive
Anchorage, Alaska 99501
Subject' 3N-15 Well Completion Report
Dear Mr. Chatterton'
The 3N-15 Well Completion Report, dated 3/2/87, incorrectly lists the depth
of the 7" casing as 8296'. The correct depth is 8496'. Please note this
change in your files.
If you have any questions, please call me at 263-4944.
Sincerely,
~/J. Gruber
Associate Engineer
JG'pk
GRU13/9
cc' 3N-15 Well File
Alasl.',~ 0il & Gas Cons. Commisslo~i
A~chorage
STATE OF ALASKA
ALASKA'ulL AND GAS CONSERVATION Ct,,,~MISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
!
1. Status of Well Classification of Service Well
OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE []
2. Name of Operator 7. Permit Number
ARCO Alaska, Inc. 86-90
3. Address 8. APl Number
P. 0. Box 100360, Anchorage, AK 99510 50- 029-21592
4. Location of well at surface 9. Unit or Lease Name
1561' FSL, 54' FEL, Sec.29, T13N, RDE, UM Kuparuk River Unit
At Top Producing Interval 10. Well Number
1288' FSL, 965' FEL, Sec.28, T13N, RDE, UM 3N-15
At Total Depth 11. Field and Pool
1338' FSL, 701' FEL, Sec.28, T13N, RDE,-UM Kuparuk River Field
5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk Ri ver 0i 1 Pool
RKB 68' ADL 25520, ALK 2556
·
12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions
05/06/86 05/1 0/86 09/06/86* N/A feet MSL 1
17. Total Depth (MD+TVD) 18. Plug Back Depth (ME)+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost
8508'MD 6710'TVD 8409'MD 6636'TVD YES~ NO[]I 1777' feetMD 1700' (Approx)
22. Type Electric or Other Logs Run
DIL/GR/SP/SFL, FDC/CNL, Cal, CET, GCT (Gyro)
~3. CASING, LINER AND CEMENTING RECORD
SETTING DEPTH MD
CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED
16" 62.5# H-40 Surf 115' 24" 255 sx CS II
9-5/8" 36.0# J-55 Surf 4321' 12-1/4" 1250 sx AS III & 350 sx Cla,s~ (~
7" 26.0# J-55 Surf 8296' 8-1/2" 235 sx Class G & 175 ,sx AS I
24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD
interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD)
2-7/8" 8044' 7973'
8229'MD 6496'1VD~ 8270'-8284'MD
8231 'MD 6498'TVD( 6528'-6539'TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
8233'MD 6499'TVD ~kw/1 spf, w/1 spf, DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED
8257'HD 6518'TVDr90° phasing 120° phasing
8260'MD
6520'TVDI See attached Adden]um; dated 02/17/87,
8262'MD 6522'TVD for Fracture.
8265'MD 6524'TVD,)
27. N/A PRODUCTION TEST
Date First Production I Method of Operation (Flowing, gas lift, etc.)
Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE 1GAS-OILRATIO
TEST PERIOD I~
Flow Tubing Casing Pressure CALCULATED,,~ OIL-BBL GAS-MCF WATER-BBL OILGRAVITY-API (corr)
Press. 24-HOUR RATE q~
28. COP E DATA
Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips.
None
*Note: Drilled RR 05/11/86. Perforated well & tubing run 07/16/86.
Form 10-407
Rev. 7-1-80
WC2: 045: DAN I
CONTINUED ON REVERSE SIDE
Submit in duplic~.~
29. ,:~
j ,. 30.
GEOLOGIC MARinERS FORMATION TESTS
,-
'NAME Include interval tested, pressure data, all fluids recovered and gravity,
MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase.
Top Kuparuk C 8079' 6380' N/A
Base Kuparuk C 8136' 6424'
Top Kuparuk A 8206' 6478,
Base Kuparuk A 8353' 6592'
31. LIST OF ATTACHMENTS
Addendum (dated 02/17/87).
32. I hereby certify that the foregoing is true and correct to the best of my knowledge
_
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.
Item 28: If no cores taken, indicate "none".
Form 10-407
ADDENDUM
WELL:
5/19/86
6/08/86
9/01/86
9/06/86
3N-15
Arctic Pak well w/175 sx AS I, followed by 60 bbls Arctic
Pak.
Rn 6-1/8" gage ring/JB to 8401'. Rn CET log
f/8395'-6942'. Rn gyro f/8336'-52'.
Att to frac Kuparuk "A" sand perfs 8229', 8231', 3233',
3257', 8260', 8262', 8265' & 8270'-8284' in 7 stages per
8/26/86 procedure using gelled diesel, 100 mesh & 20/40
mesh. Pressured ann to 2460 psi w/diesel. Tst ins to
8000 psi; OK.
Stage #1: Pmp 63 bbls gelled diesel pre-pad @ 13.8 BPM,
6400-6650 psi
Stage #2: 17 bbls gelled diesel w/1 ppg 100 mesh @ 13.8
BPM, 6650-6400 psi
Stage #3: 24 bbls gelled diesel @ 12.5 BPM, 6400 psi
Stage #4: 40 bbls gelled diesel flush @ 12.5 BPM - 20
BPM, press dropped to 5300 psi. Decided to
att to pmp job instead of flush to top perf
Stage #5: 44 bbls gelled diesel pad @ 20 BPM, 5300-6500
psi. Pressure too high. Decided to pmp vol
to top perf to put gelled diesel w/low
temperature breaker in tbg & csg
Stage #6: 54 bbls gelled diesel flush @ 19 BPM, 6500 -
4980 psi. Pressure dropped to 4900 during
flush & was slowly rising at the end
Pmp'd 630# of 100 mesh into formation, leaving no sand in
csg.
Load to recover 242 bbls of diesel. Job complete @ 1200
hfs, 9/1/86.
Frac Kuparuk "A" sand perfs (as listed above) in 7 stages
per 9/2/86 (revised) procedure using gelled diesel, 100
mesh & 20/40 mesh. Pressured ann to 2470 psi w/diesel.
Tst lns to 8300 psi; OK. Pmp'd 20 bbls 5% Musol,
followed by 51 bbls cln diesel @ 1.5 BPM, 2200 psi.
Stage #1: Pmp'd 64 bbls gelled diesel pre-pad @ 11-20
BPM, 6000-5200 psi
Stage #2: Pmp'd 22 bbls gelled diesel w/1 ppg, 100 mesh @
20 BPM, 5030 psi
Stage #3: Pmp'd 187 bbls ~elled diesel pad @ 20 BPM, 4800
psi
Stage #4: Pmp'd 38 bbls gelled diesel w/3 ppg 20/40 mesh
@ 20 BPM, 4600 psi
A D D E N D U M (cont'd)
WELL:
3N-15
1/25/87
Stage #5: Pmp'd 50 bbls gelled diesel w/6 ppg 20/40 mesh
@ 18.5-20 BPM, 5000-6200 psi
Stage #6: Pmp'd 58 bbls gelled diesel w/8 ppg 20/40 mesh
@ 15-13 BPM, 6300-6700 psi
Stage #7: Pmp'd 51 bbls gelled diesel flush @ 13-16 BPM,
6500-6300 psi.
Pmp'd 840# 100 mesh, 23,100# 20/40 mesh in formation
leaving 840# 20/40 mesh in csg.
Load to recover 450 bbls of gelled diesel, 20 bbls 5%
Musol & 51 bbls cln diesel. Job complete @ 1147 hrs,
9/6/86.
CO well w/CTU f/8200' - 8409', POH. RD, secure well &
turn well over to Production.
r D~iliing Supervisor
ARCO Alaska, In¢
Post Office vox 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
Date: February 9, 1987
Transmittal # 5914
RETURN TO: --
ARCO Alaska, Inc.
Attn: Kuparuk Records Clerk
ATO-1119
P.O. Box 100360
Anchorage, AK 99510-0360
Transmitted herewith are the following items. Please acknowledge receipt
and return one signed copy of this transmittal.
1H-6'
3N-16
3N-15
CET 7-26-86 4700-6818
CET 6-7-86 7498-9090
CET 6-6-86 6942-8395
Receipt Acknowledged:.
DISTRIBUTION:
NSK Drilling
Mobil Chevron
Alaska 0JJ ~ (~a$ COILS.
Anchorage
SAPC Unocal Vault
ARCO Alaska, Inc. is a Subsidiary of AllanlicRIchfieldCompany
ARCO Alaska, Inc.
Post Office Box 100360
Anchorage. Alaska 99510-0360
Telephone 907' 276 1215
RETURN TO:
ARCO ALASKA, INC.
ATTN: Kuparuk Records Clerk
ATO 1119
P. O. Box 100360
Anchorage AK 99510-0360
DATE 10-20-86
TRANSMITTAL # 5802
Transmitted herewith are the following items. Please acknowledge receipt and
return one signed copy of this transmittal.
FinalxPrints: Schl: Open Hole Logs: One * of each
2T-~5" DIL/SFL-GR 05-11-86 Run H1 2978-7844~
~2" DIL/SFL-GR 05-11-86 Run H1 2978-7844
~5"~ Den/Neu (poro) 05-11-86 Run Hi 3340-7818
~2" Den/Neu (poro) 05-11-86 Run H1 3340-7818
~5" Den/Neu (raw) 05-11-86 Run H1 3340-7818
~2" Den/Neu (raw) ~ 05-11-86 Run H1 3340-7818
~--Cyberlook 05-11-86 Run Hi 7300-7800
3N-1~5" DIL/SFL-GR 05-10-86 Run Hi 4319-8498
~2" DIL/SFL-GR 05-10-86 Run HI 4319-8498
"5" Den/Neu-GR (poro) 05-10-86 Run Hi 7600-8471
~2" Den/Neu-GR (poro) 05-10-86 Run Hi 7600-8471
~"'5" Den/Neu-GR (raw) 05-10-86 Run #1 7600-8471
~"~2'" Den/Neu-GR (raw) 05-10-86 Run H1 7600-8471
""'Cyberlook 05-10-86 Run #1 7600-8460
3N-1~'~5'' DIL/SFL-GR 05-18-86 Run #1 4796-9236
'r"~2" DIL/SFL-GR 05-18-86 Run Hi 4796-9236
"25" Den/Neu (poro) 05-18-86 Run H1 8400-9210
""-2" Den/Neu (poro) 05-18-86 Run #1 8400-9210
~"-5" Den/Neu (raw) 05-18-86 Run Hi 8400-9210
'~-2" Den/Neu (raw) 05-18-86 Run #1 8400-9210
~-Cyberlook 05-18-86 Run #1 8400-9180
3N-17'~5" DIL/SFL-GR 05-25-86 Run H1 4607-8998
'~2" DIL/SFL-GR 05-25-86 Run H1 4607-8998
'"'-5" Den/Neu (poro) 05-25-86 Run Hi 8200-8972
~2" Den/Neu (poro) 05-25-86 Run Hi 8200-8972
"~'5" Den/Neu (raw) 05-25-86 Run #1 8200-8972
'"'-2" Den/Neu (raw) 05-25-86 Run Hi 8200-8972
~Cyberlook 05-25-86 Run H1 8350-8950
The API#is incorrect
on these logs.
It should be
50-029-20067.
Receipt Acknowledged:
NSK Files*bl
D & M*bl
Drilling*bi
OcT 2 2
Rathmel~i~ y Alaska 0ii & Gas Cons. Commissior
Vaul t*f/]ms/ Anchorage
ARCO Alaska. Inc. is · Subsidiary of AllanlicRichfieldComp·nY
STATE OF ALASKA
ALASK~ OIL AND GAS CONSERVATION ~,,~MMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
1. Status of Well Classification of Service Well~/,.~,
.
O,L ~ GAS [] SUSPENDED [] ABANDONED [] SERV,CE []
2. ^Sac~e X~askaOperat°~',, nc. 7. 86-90Permit Number
3.Address 8. APl Number
P; O. Box '100360, ^nchorage, ^K 99510-0360 50- 029-21592
4. Location of well at surface 0. Unit or Lease Name
1561' FSL, 54' FEL, Sec.29, T13N, RgE, UM Kuparuk River Unit
~F~I~ Producin0 Interval 10. Well Number
FSL, 965' FEL, Sec.28, T13N, R9E, UM 3N-15
At Total Depth 11. Field and Pool
1338' FSE, 701' FEL, 5ec.28, T13N, R9E, UN Kuparuk River Field
5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kupaurk River 0i 1 Pool
68' RKB ADL 25520 ALK 2556
12. Date Spudded 13. Date T.D. Reached .1'4. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions
05/06/86 05/10/86 "09/06/86* N/A feet MSL 1
17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD)''19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost
8508 'MD ,6710 'TVD 8409 'MD ,6636 'TVD YESJY~ NO []I 1777 feet MD 1700' (approx)
22. Type Elect.tic or Other Logs Run
D
IL/GR/SP/SFL, FDC/CNL, Cal, CET, GCT (gyro)
23. CASING, LINER AND CEMENTING RECORD
SETTING DEPTH MD
CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED
16:: 62.5# H-40 Surf '1 '15 ' Z~,'' 255 sx CS I I
~-b/~~' ~6.O# J-55 Surf 4321' 12-1/4" 1250 sx AS III & 350 sx.Class G
/" 26.0# J-55 Surf 8296' 8-1/2" 325 sx Class G & 175 sx AS I
24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD
interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD)
8229'MD 6496'TVD/1 spf, 90~ phasing 2-7/8" 8044' 7973'
8231 'MD 6498'TVD " "
8233'MD 6499'TVD " "
26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
8257'MD 6518'TVD " "
DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED
8260'MD 6520'TVD " " See attached adden, ium, dated 9/10/86, for fracture data.
8262 'MD 6522'TVD " "
8265 'MD 6524'TVD " "
8270'-8284'MD 6528'-6539'TVD/1 spf, 120~ phasing
N/A
27. PRODUCTION TEST
Date First Production I Method of Operation (Flowing, gas lift, etc.)
Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO
TEST PERIOD I~
I
Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr)
Press. 24-HOUR RATE ~
28. CORE DATA
Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips.
None
~ -
Form 10-407 * NOTE: Drilled RR 5/11/86. Perf'd well & ran tubing 7/16/86. WCl/123
Rev. 7-1-80 CONTINUED ON REVERSE SIDE
Submit in duplicate~
GEOLOGIC MARKeRs ' '-FORMATION TESTS
NAME Include interval tested, pressure data, all fluids recovered and gravity,
MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase.
Top Kuparuk C 8079' 6380' NA
Base Kuparuk C 8136' 6424'
Top Kuparuk A 8206' 6478'
Base Kuparuk A 8353' 6592'
31. LIST OF ATTACHMENTS
Addendum (dated 9-10-86)
32. I hereby certify that the foregoing is true and correct to the best of my knowledge
Engineer /0' ~ '~_~
Signed (~ ~'~ . /JL)~_ Title Associate 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-
ing and the location of the cementing tool.
Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In-
jection, Gas Injection, Shut-in, Other-explain.
Item 28' If no cores taken, indicate "none".
Form 10-407
ADDENDUM
WELL:
5/19/86
6/08/86
9/01/86
9/06/86
3N-15
Arctic Pak well w/175 sx AS I, followed by 60 bbls Arctic
Pak.
Rn 6-1/8" gage ring/JB to 8401'. Rn CET log
f/8395'-6942'. Rn gyro f/8336'-52'.
Att to frac Kuparuk "A" sand perfs 8229', 8231', 3233',
3257', 8260', 8262', 8265' & 8270'-8284' in 7 stages per
8/26/86 procedure using gelled diesel, 100 mesh & 20/40
mesh. Pressured ann to 2460 psi w/diesel. Tst ins to
8000 psi; OK.
Stage #1: Pmp 63 bbls gelled diesel pre-pad @ 13.8 BPM,
6400-6650 psi
Stage #2: 17 bbls gelled diesel w/1 ppg 100 mesh @ 13.8
BPM, 6650-6400 psi
Stage #3: 24 bbls gelled diesel @ 12.5 BPM, 6400 psi
Stage #4: 40 bbls gelled diesel flush @ 12.5 BPM - 20
BPM, press dropped to 5300 psi. Decided to
att to pmp job instead of flush to top perf
Stage #5: 44 bbls gelled diesel pad @ 20 BPM, 5300-6500
psi. Pressure too high. Decided to pmp vol
to top perf to put gelled diesel w/low
temperature breaker in tbg & csg
Stage #6: 54 bbls gelled diesel flush @ 19 BPM, 6500 -
4980 psi. Pressure dropped to 4900 during
flush & was slowly rising at the end
Pmp'd 630# of 100 mesh into formation, leaving no sand in
csg.
Load to recover 242 bbls of diesel. Job complete @ 1200
hfs, 9/1/86.
Frac Kuparuk "A" sand perfs (as listed above) in 7 stages
per 9/2/86 (revised) procedure using gelled diesel, 100
mesh & 20/40 mesh. Pressured ann to 2470 psi w/diesel.
Tst ins to 8300 psi; OK. Pmp'd 20 bbls 5% Musol,
followed by 51 bbls cln diesel @ 1.5 BPM, 2200 psi.
Stage #1: Pmp'd 64 bbls gelled diesel pre-pad @ 11-20
BPM, 6000-5200 psi
Stage #2: Pmp'd 22 bbls gelled diesel w/1 ppg, 100 mesh @
20 BPM, 5030 psi
Stage #3: Pmp'd 187 bbls gelled diesel pad @ 20 BPM, 4800
psi
Stage #4: Pmp'd 38 bbls gelled diesel w/3 ppg 20/40 mesh
@ 20 BPM, 4600 psi
~ELL :
3N-15
(cont ' cl)
g' mat/on
Load to recover 450 bbls of
~Usol & 5i bbls gelled d~esel ~-
~. cln d~esel. ~m;~ ,_20 bbls 5~
~UB.~URFACE
DIRECTIONAL
~URVEY
[~] UIDANCE
r~ONTINUOUS
[~OOL
q/l
Alaska Oil & Gas Oons. C;ommi~sJ,on
~qnchomrj. ~
Company- ARCq ALASKA, INC .......
Well Name , 3N-15,,I156,1'F,SL,5,5'F,EL. ,S,EC.,29~T13N.RgE'UM)
Field/Location ~:U~A~U..~, N0~ ~]~0~[. ALASKA
Jol~ Reference N.o. .Date
Lo_gjljLe~[~~ Comput.ed By:.
WARNER S I NES
GCT DIRECTIONAL SURVEY
CUSTOMER LISTING
FOR
ARCO ALASKA~ INC.
3N-15
KUPARUK
NORTH SLOPE,ALaSKA
SURVEY DATE: 6-JUN-B6
ENGINEER: WARNER
METHODS OF COMPUTATION
TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION,,A.ND AZIMUTH
~ ,,
INTERPOLATION: LINEAR '
VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO~A,TARG,ET AZIMUTH OF SOUTH 86 DEG 58 MIN EAST~
SCHLUMBERGER
GCT DIRECTIONAL SURVEY
CUSTOMER LISTING
FOR
ARCO ALASKA, INC.
3N-15
KUPARUK
NOR'TH SLOPE,ALASKA
SURVEY DATE: 6-JUN-86
ENGINEER: WARNER
METHODS OF COMPUTATION '
TOOL LOCATION: TANGENTIAL~ AVERAGED DEVIATION AND AZIMUTH
,
INTERPOLATION: LINEAR ·
'.
VERTICAL SECTION: HORIZo DIS'T. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 86 DEG 58 MIN EAST
,
~:,
·
ARCO ALASKA9 INC.
3N-15
KUPARUK
NORTH SLOPEgALASKA
COMPUTATION DATE: 30-JUN-86
DATE OF SURVEY: 6-JUN-86
KELLY BUSHING ELEVATION:
ENGINEER: WARNER
INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH
TRUE SUB-SEA COURSE
MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH
DEPTH DEPTH DEPTH DEG MIN DEG MIN
0.00 0.00 -68.00. 0 0 N 0 0 E
100.00 100,00 32.00 0 10 S 43 47 E
200.00 200.00 132.00 0 25 S 80 53 E
300.00 300.00 232.00 0 28 N 89 0 E
400.00 399,99 331.99 0 30 N 76 58 E
'00o00 499.99 431.99 0 28 N 68 44 E
~00.00 599.98 531.98 0 23 N 60 41 E
700.00 699.98 631.98 0 16 N 57 43 E
800.00 799.98 731.98 0 15 N 64 36 E
900.00 899.98 831.98 0 16 N 83 39 E
PAGE
1000.00 999.98 931.98 0 45
1100.00, 1099.91 1031.91 3 38
1200-00 1199.51 1131.51 6 4
1300,00 1298.75 1230.75 8 33
1400'00 1397.08 1329.08 11 56
1500'00 1494.53 1426.53 14 13
1600.00 1590.74 1522.74 17 17
1700.00 1685.31 1617.31 20 33
1800.'00 1778.18 1710.18 22 57
1900.00 1869.20 1801.20 26 5
2000,00 1957..43 1889.43 29 59
2100.00 2042.43 1974.43 33 33
oo.oo
2300 O0
· 2202.71 2134.71 39 26
2400.00 2278.26 2210,26 42 36
~00.00 2349.97 2281.97 45 3
)0.00 2420.54 2352.54 44 58
~,00.00 2491.51 2423.51 44 41
2800.00 2562.47 2494.47 44 46
2900.00 2633.51 2565.51 44 43
3000:~00 2704.69 2636.69 44 23
3100.00 2776.44 2708.44 43 55
3200.00 2848.53 2780.53 44 0
3300.00 2920.34 2852.34 44 14
3400.00 2991.26 2923.26 45 16
3500.00 3061.50 2993.50 45 26
3600.00 3131.51 3063.51 45 48
'3700.00 3201.16 3133.16 45 47
3800.00 3270.90 3202.90 45 47
3900.00 3340.64 3272.64 45 45
VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZe,DEPARTURE'i
SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST.
FEET DEG/IO0 FEET FEET
0.00 0.00 0.00 N 0.00 E
-0.02 0.73 0.03 S 0.02 W
0.51 0.09 0.22 S 0.50 E
1.31 0.14 0.27 S 1.30 E
2.15 0.14 0.17 S 2.14 E
2.97 0.21 0.i0 N 2.98 E
3.64 0.17 0.42 N 3.67 E
4.12 0.11 0.73 N 4.16 E
4.52 0.18 0.94 N 4.58 E
4.93 0.19 1.08 N 4.99 E
S 72 34 E 5.64 0.62
S 87 49 E 9.02 3.17
S 88 30 E 17.84 0.96
S 85 44 E 30,08 3.53
S 85 14 E 48.16 2,73
S 85 54 E 70.58 2.14
S 85 52 E 97.78 3.38
S 85 28 E 130.24 2.59
S 85 5 E 167.28 2.55
S 84 33 E 208.63 3.78
S 83 54 E 255.59
S 83 55 E ' 308.17
S 83 31E 365.86
S 82 36 E 427.42
S 81 18 E 492.65
S 80 44 E 561.95
S 80 19 E 632.35
S 80 10 E 702.32
S 79 47 E 772.26
S 79 49 E 842.10
S 79 27 E 911.77
S 79 4 E 980.78
S 78 59 E 1049.43
S 78 29 E 1118.32
S 77 57 E 1187.98
S 77 52 E 1258.27
S 77 39 E 1328.77
S 77 30 E 1399.56
S 77 30 E 1470.24
S 77 23 E 1540.94
0.96 N
0.52 N
0.33 N
0.25 S
1.96 S
3.53 S
O. 04, ';::~'S':'i'3616 W.'~
O. 55.,. ,'"S.'.66 30 E '
1.33" S' 78 19 E.
2'15 'S 85 28
2.'98'.' N 88 3 E
3.69.' N 83 30 E
4.23: "N 80 5 E
4.68 N 78 20 E
5.11 N 77 4.8 E
5.70 E 5.78 N 80 25
9.06 E 9.08 N 86 44 EE'.,.
17.88 E 17.88 N 88 56
30.10 E 30.11 S 89
48.13 E 48.17 S 87 40
70.49 E 70.58 S 87 8 E
5.30 S 97,63 E 97.78 S 86 53
7.88 S 130.00 E 130.24 S 86 31 E"
10.86 S 166.93 E 167.29 S 86 16 E
14.62 S 208.15 E 208.66 S 85 58 E
3.84
3.53
2.83
2.92
3.81
0.80
0.33
0.28
0.40
0.28
19.35 S 254.92 E 255.66 S 85 39
24.98 S 307.27 E 308°29 S 85 21
31.16 S 364.72 E 366.05 S 85 6
38.55 S 425.97 E 427.71 S 84 49. E,
47.81 S 490.81 E 493.13 S 84 26
58.75 S 559.62 E 562.69 S 84 0
70.41 S 629.50 E 633.43 S 83 37E
82.36 S 698.93 E 703.77 S 83 16
94.63 S 768.32 E 774.13 S 82 58
107.05 S 837'.60 E 844.41
0.83 119.62 S 906.70 E 9.14.56 S 82 29 ,E
0.31 132.70 S 975.12 E 984.10 S 82 15 .E
0.61 145.83 S 1043.17 E'1053.31
1.05 159.36 S 1111.43 E 1122.80 S 81 50 '
0.46 173.79 S 1180.43 E 1193.15 S 81 37 E
· 0.20 188,74 S 1250.02 E 1264.19 S 81 24 E
0.48,' 203.83 S 1319.82 E 1335.47 S 81 13 E
0.17'
0.04, '
O.ZS,
·
,,
,,
· ,
, ,
219.30 S 1389.89 E 1407.08 S 81 2 E ',~,.~
234.83 S 1459.84 E 1478.61 S
250.37 S 1529.81 E 1550.17
COMPUTATION DATE: 30-JUN-86
ARCO ALASKA, INC.
DATE OF SURVEY: 6-JUN-86
3N-15
KUPARUK
NORTH SLOPEsALASKA
INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH
TRUE SUB-SEA COURSE
MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH
OEPTH DEPTH DEPTH DEG MIN DEG MIN
VERTICAL DOGLEG
SECTION SEVERITY
FEET DEG/IO0
4000.00 3410.41 3342.41 45 45
4100.00 3480.25 3412.25 45 33
4200.00 3550.56 3482.56 45 14
4300.00 3620.90 3552.90 45 17
4400.00 3691.53 3623.53 44 58
'00.00 3762.38 3694.38 44 54
00.00 3833.31 3765.31 44 43
.?00.00 3904.08 3836.08 45 16
4800.00 3974.18 3906.18 45 29
4900.00 4044.25 3976.25 45 29
S 77 9 E 1611.55
S 76 44 E 1682.03
S 76 31 E 1752.00
S 75 58 E 1821.82
S 76 10 E 1891.32
S 76 17 E 1960.67
S 76 38 E 2029.98
S 79 29 E 2099.68
S 82 13 E 2170.64
S 84 59 E 2241.83
0.46
0.30
0.66
0.81
0.92
0.19
0.40
3.55
0.75
2.17
KELLY BUSHING ELEVATION: 68.00
ENGINEER: WARNER
RECTANGULAR COORDINATES HORIZ, 'DEPARTUR~.:~}
NORTH/SOUTH EAST/WEST D~ST," .AZIHUTH
FEET FEET FEET':
266.~4 S ~59~.69 E 1621e'&8.~'~'S ~'80 33
282,36 S ~669.40 E 1693,11.'~:~S ~ 2~
2~8.73 S ~738.60 E 1~6~,08"L S.80 15
315,72 S 1807.62 E 1834,.98
332.81 S ~876.3~ E ~905,60 S"79 56
349.58 S ~94~.87 E 1976,04 S 79 48
366,09 S 2013.39 E 2046,~1
381,23 S 2082,~0 E 2~17,00'.. S '79 37
3~2,05 S 2152,88 E 2~88,28 S 79 40
400.32 S 2223,73 E 2259,~7 S .79 47
5000.00 4114.42 4046.42 45 17
5100.00 4185.09 4117.09 44 53
5200.00 4256.01 4188.01 44 42
5300.00 4327.19 4259.19 44 36
5400.00 4398.32 4330.32 44 45
5500.00 4469.33 4401.33 44 39
5600,00 4540.61 4472.61 44 25
5700.00 4612.29 4544.29 44 5
5800.00 4684.21 4616.21 43 55
5900.00 4756.35 4688.35 43 43
6000.00 4828.69 4760.69 43 34
6100.00 4901.26 4833.26 43 21
6200.00 4974.03 4906.03 43 13
6300.00 5046.94 4978.94 43 7
6400.00 5120.04 5052.04 42 59
6~00.00 5193.30 5125.30 42 53
~' ~0.00 5266.62 5198.62 42 48
JO,O0 5340.05 5272.05 42 40
~800.00 5413.66 5345.66 42 33
69'00.00 5487.48 5419.48 42 15
7000.00 5561.56 5493.56 42 1
7100.00 5635.99 5567.99 41 43
7200.00 5710,76 5642.76 41 32
7300.00 5785.72 5717.72 41 21
7400'00 5860.94 5792.94 4i 5
7500.00 5936.42 5868.42 40 53
7600.00 6012.04 5944.04 40 48
7700.00 6087.99 6019.99 40 23
7800.00 6164.38 6096.38 40 3
7900.00 6241.08 6173.08 39 42
S 86 22 E 2313.07
S 86 54 E 2383.82
S 87 34 E 2454.31
S 88 15 E 2524.53
S 88 55 E 2594.80
S 89 21 E 2665.15
S 89 52 E 2735.22
N 89 45 E 2804.84
N 89 23 E 2874.21
N 88 55 E 2943.29
N 88 32 E 3012.14
N 88 8 E 3080.72
N 87 36 E 3149.02
N 87 11 E 3217.14
N 86 48 E 3284.99
N 86 ZO E 3352.63
N 85 48 E 3420.14
N 85 35 E 3487.45
N 85 12 E 3554.55
N 84 55 E 3621.35
N 84 25 E 3687.81
N 84 0 E 3753.80
N 83 36 E 3819.33
N 83 0 E 3884.57
N 82 27 E 3949.40
N 82 6 E 4013.84
N 8I 28 E 4078.00
N 81 9 E 4141.72
N 80 13 E 4204.76
N 79 42 E 4267.24
0.70
0.31
0.85
0.49
0.48
0.40
0.31
0.34
0.42
0.44
0.30
0.39
0.58
0.34
0.39
0.41
0.25
0.22
0.28
0.38
0.36
0.71
0.39
.0.69
0.55
O. 63
0.44
0'73
0.68:
0.56
'
405.41 S 2294.80 E 2330.33 S 79 58
409.51 S 2365.43 E 2400.61 S 80 10 E. ,',!',
412.94 S 2435.84 E 2470.59 S 80 22 E .~.....,.
415.46 S 2506.03 E 2540.23 S 80 35 E
417.19 S 2576.30 E 2609.86 S 80 48 E'
418.24 S 2646.70 E 2679.54 S 81 1E
418.79 S 2716.83 E 2748.92 S 81 14 E
418.73 S 2786.56 E 2817.84 S 81 27 ',
418.20 S 2856.05 E 2886.50 S 81 40
417.20 S 2925.29 E 2954.89 S 81 53
415.65 S 2994.31 E 3023'03 S 82 $ E"
413.72 S 3063.09 E 3090.90 S 82 18 E
411.19 S 3131.62 E 3158.50 S 82 31
408.10 S 3200.00 E 3225.91 S 82 43 E
404.51 S 3268.14 E 3293.08 S 82 56
400.48 S 3336.09 E 3360.04 S 83 9
395.82 S 3403.93 E 3426.87 S 83 22 E
390.72 S 3471.61 E 3493.53 S 83 34 E :':','::?,"i'
385.33 S 3539.10 E 3560.01 S 83 47 E ",,,"
379.56 S 3606'29 E 3626.21 S 83 59 E
373.29 S 3673.18 E 369,2.10 $ 84 11 E
366.54 S 3739.62 E 3757.54 S 84 24
359.34 S 3805.63 E 3822.56 S 84 36 E
351.68 S 3871.37 E 3887.31 S 84 48 E
343.27 S 3936.73 E 3951.67 S 85 0 E
334.52 S 4001.73 E 4015.69 S 85 13
325.10 S 4066.49 E 4079.46 S 85 25 E,,
315.34 S 4130.81 E 4142.83 S 85 38 E
304.92 S 4194.49 E 4205.56 S 85 50 E
293.62 S 4257.66 E 4267.77 S 86 3 E
ARCO ALASKA9 INC.
COMPUTATION DATE: 30-JUN-86
DATE OF SURVEY: 6-JUN-86
PAGE
3N-15
KUPARUK
NORTH SLDPE~ALASKA
TRUE SUB-SEA COURSE
MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH
DEPTH DEPTH DEPTH DEG MIN DEG MIN
KELLY BUSHING ELEVATION: 68.00
ENGINEER: WARNER
INTERPOLATED VALUES FOR EVEN 100 FEET DF MEASURED DEPTH
VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ.. 'Q_EPARTUR~.'!"?
SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST,"..'.
FEET DEG/IO0 FEET FEET FEET"'. ' i~-.~EG
' ":'?'!!, :".:'~L!'~,. ]~'. ',
N 79 31 E ~329.06 0.30 282.18 S ~320.17 E 43'~g~.~:8~."~.~':-86 E:'~"
N 79 33 E ~390.~5 0.26 270.7~ S ~382.26 E 4390."~J/',.S:~8~ 27 E
N T9 30 E ~51.63 0.67 259.28 S ~444.13 E 4~51.6g'"~:.'~S.'.8~ 39 E
N 79 7 E 4512.83 0.86 2~7.57 S ~506.05 E ~512,8~..-',:.S:86 ~1 E"
N 79 2 E ~574.18 0.00 235.54 S 4568.12 E 4574.J9' S 87 2 E
N 79 2 E ~635.5g 0.00 223.51 S 4630 25 E ~635..6~. ~...,87 1~ E
N 79 2 E 4640.50 0.00 222.54 S 4635~22 E 46~0~"56,,~ 87 1S E:
~ ,.
.4. ~. ' .
8000.00 6318.28 6250.28 39 13
8100.00 6395.83 6327.83 39 2
8200.00 6473.55 6405.55 39 2
8300.00 6551.20 6483.20 39 6
R400.O0 6628.68 6560.68 39 15
$00.00 6706.10 6638.10 39 15
.508.00 6712.30 6644.30 39 15
ARCO ALASKA. INC.
3N-15
KUPARUK
NORTH SLOPE,ALASKA
COMPUTATION DATE: 30-JUN-86
DATE DF SURVEY: 6-JUN-86
KELLY BUSHING ELEVATION:
ENGINEER: WARNER
INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPT
TRUE SUB-SEA COURSE . VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE '
MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST,., "AZIMUTH
DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET OEO/lO0 FEET FEET FEET c.~,::.'..~EG MIN ,~
0.00 0.00 -68.00 0 0
1000.00 999.98 931.98 0 45
2000.00 1957.43 1889.43 29 59
3000.00 2704.69 2636.69 44 23
4000.00 3410.41 3342.41 45 45
~00.00 4114.42 4046.42 45 17
,00.00 4828.69 4760.69 43 34
TO00.O0 5561.56 5493.56 42 1
8000.00 6318.28 6250.28 39 13
8508.00 6712.30 6644.30 39 15
N 0 0 E 0.00
S 72 34 E 5.64
S 83 54 E 255.59
S 79 27 E 911.77
S 77 9 E 1611.55
S 86 22 E 2313.07
N 88 32 E 3012.14
N 84 25 E 3687.81
N 79 31 E 4329.06
N 79 2 E 4640.50
0.00
0.62
3.84
0.83
0.46
0.70
0.30
0.36
0.30
0.00
· .
0.00 N 0.00 E O.O0":i~:'''~'N ' 0 O-E
0.96 N 5.70 E 5.78 .,':N 80 25 E
19.35 S 254.92 E 255.66', S'-85 39 E
119.62 S 906.70 E 914.56 ' S'82 29 E
266.14 S 1599.69 E 1621.68 '"S .80 33 E
405.41 S 2294 80 E 2330. ': 82 5 E
415.65 S 2994:31 E 3023~ '
373.29 S 3673.18 E 3692.10 S 84 11 E "
282.18 S 4320.17 E 4329.38 S 86 15 E
222.54 S 4635.22 E 4640.56 S 87 15 E
ARCO ALASKA~ INC.
3N-15
KUPARUK
NORTH SLOPE~ALASKA
COMPUTATION DATE: 30-JUN-86
TRUE SUB-SEA COURSE
MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH
DEPTH DEPTH DEPTH DEG MIN DEG MIN
DATE OF SURVEY: 6-JUN-86
KELLY BUSHING ELEVATION:
PAGE
E.NGINEER: WARNER
INTERPOLATED VALUES FOR EVEN 100 FEET DF SUB-SEA DEPTH
VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE.'~'~
SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST,' AZIMUTH · ..:
FEET DEG/iO0. FEET FEET FEET--::DEG
0.00 0.00 -68.00 0 0 N 0 0 E 0.00 0.00 0.00 N 0.00 E
68.00 68.00 0.00 0 4 S 83 7 W -0.03 0.66 0.00 N 0.03 W
168.00 168.00 100.00 0 21 S 75 22 E 0.29 0.45 0.17 S 0.28 E
268.00 268.00 200.00 0 28 S 89 2 E 1.04 0.07 0.27 S 1.03 E
368.01 368.00 300.00 0 29 N 81 18 E 1.88 0.14 0.22 S 1.87 E
;68.01 468.00 400.00 0 30 N 70 38 E 2.71 0.16 0.01 N 2.72 E
J68.01 568.00 500.00 0 25 N 64 12 E 3.45 0.10 0.31 N 3.47 E
668.02 668.00 600.00 0 18 N 55 27 E 3.99 0.17 0.64 N 4.03 E
768.02 768.00 700.00 0 16 N 64 28 E 4.39 0.09 0.88 N 4.44 E
868.02 868.00 800.00 0 15 N 76 7 E 4.79 0.19 1.05 N 4.85 E
0'00:""N :,'0 0 E'
0.03:. N 85 41 W'
'0.33." $ 58 28 E
1,07' S 75 22 E
1.88 S',-83 11 E
2.72~ N 89 53 E
3.48 'N 84 49 E
4.08 N 81 1 E
4.53 N 78 47 E
4.96 N 77 47 E
968.02 968.00 900.00 0 26
1068.04 1068.00 1000.00 2 29
1168.33 1168.00 1100.00 5 37
1268.95 1268.00 1200.00 7 25
1370.32 1368.00 1300.00 11 12
1472'68 1468.00 1400.00 13 .24
1576.21 1568.00 1500.00 16 29
1681,53 1668.00 1600.00 20 0
1788.97 1768.00 1700.00 22 40
1898'67 1868.00 1800'00 26 2
S 77 57 E 5.31 0.67
S 83 25 E 7.29 4.08
S 88 35 E 14.60 1.73
S 86 51E 25.75 3.70
S 84 16 E 42.22 2.50
S 85 58 E 64.04 3.36
S 86 11 E 90.80 3.27
S 85 22 E 123.81 3.34
S 85 9 E 163.02 2.45
S 84 33 E 208.04 3.75
1.05 N 5.38 E 5.48 N 78 54 E
0.63 N 7.34 E 7.36 N 85 3 E
0.41N 14.65 E 14.65 N 88 22 E
0.03 N 25.79 E 25.79 N 89 55 E
1.41 S 42.21E 42.23 S 88 5 E
3.06 S 63.97 E 64.04 S 87 15 E
4.81 S 90.67 E 90.80 S 86 57 E
7.37 S 123.59 E [23..81 S 86 35 E
10.50 S 162.69 E 163.03 S 86 18 E
14.57 S 207.56 E 208.07 S 85 59 E
2012.22 1968.00 1900.00 30 27
2130..90 2068.00 2000.00 34 40
2255.45 2168.00 2100.00 38 15
2386.14 2268.00 2200.00 42 6
2525.57 2368.00 2300.00 45 9
'~66.94 2468.00 2400.00 44 42
]7.80 2568.00 2500.00 44 44
.J48.,52 2668.00 2600.00 44 39
3088.28 2768.00 2700.00 43 58
3227.10 2868.00 2800.00 44 6
3366.96 2968.00 2900.00 45 2
3509;26 3068.00 3000.00 45 27
3652.45 3168.00 3100.00 45 52
3795.84 3268.00 3200.00 45 46
3939.20 3368.00 3300.00 45 45
4082.50 3468.00 3400.00 45 36
4224.80 3568.00 3500.00 45 14
4366.67 3668.00 3600.00 44 59
4507.94 3768.00 3700.00 44 54
4668.88 3868.00 3800.00 44 56
S 83 51 E 261.70 3.80
S 83 59 E 325.48 3.68
S 83 5 E 399.56 2.61
S 81 26 E 483.38 3.69
S 80 39 E 579.97 0.55
S 80 12 E 679.24 0.46
S 79 47 E 777.71 0.45
S 79 43 E 875.95 0.38
S 79 4 E '972.72 0.49
S 78 54 E 1068.10 0.35
S 78 4 E 1164.82
S 77 52 E 1264.78
S 77 31 E 1365.94
S 77 30 E 1467.31
S 77 17 E 1568.62
S 76 46 E 1669.72
S 76 19 E 1769.33
S 76 3 E 1868.14
S 76 18 E 1966.18
S 77 2~ E 2063.87
1.11
0.21
0.62
0.06
0.27
0.26
0.66''
0.89
0.21
.2-o7 ,
20.01 S 261.01 E 261.77 S 85 36 E .
26.80 S 324.51 E 325.62 S 85 16 E~
35.10 S 398.26 E 399,80 S 84 57 E
46.41 S 481.59 E 483.83 S 84 29 E
61.68 S 577.51 E 580.80 S 83 54 E
78.40 S 676.04 E 680.57 S 83 23 E
95.60 S 773.73 E 779.62 S 82 57 e
113.11 S 871.18 E 878.49 S 82 36 E ~--
131.15 S 967.13 E 975.98 S 82 16 E
149.44 S 1061.67 E 1072.14 S 81 59 E .....
168.92 S 1157.49 E 1169.75 S 81 41 E
190.12 S 1256.46 E 1270.77 S
211.94 S 1356.61 E 1373.06 · S 81 7 E
234.19 S 1456.94 E 1475.64 S 80 52 E
256.53 S 1557.21 E 1578.20 S 80 38 E
279.50 S 1657.23 E 1680.63 S 80 25 E
302.87 S 1755.73 E 1781.67 S 80 12 E
327.14 S 1853.40 E 1882.05 S 79 59 E
350.9'1 S 1950.31 E 1981.63 S 79 48 E
373.92 S 2046.92 E 2080.79
BBNBVM :B~]NIONB
:NOI~VABg~ ONIHSnB A99~
9B-N~r-9 :XBABnS ~0 ~IVO
59'5£99 O0'60~B
B6'60Z9 O0'BOSB
6Z'Z6~9 00'£5£B
IZ'BZ99 O0°gOZB
6L'£Z~9 o0'gcTB
E~'6LE9 O0'6ZOB
B~ WOB~
SNOZIBOH N3SOHO ~0~ S~RqVA O~£VgOdB3£NI
9B-Nflr-OE :~iVO NOIIVlfldWO3
O£gd
V ~n~vdn~ dO~
3 ~n~vdn~ ]SVg
3 ~n~vdn~ dO~
B~BVW
V~SVqV*~dO~S H~ON
~n~vdn~
'3NI *V~svgv OOU~
ARCO ALASKA~ INC.
3N-15
KUPARUK
NORTH SLOPE~ALASKA
MARKER
TOP KUPARUK C
BASE KUPARUK C
TOP KUPARUK A
BASE KUPARUK A
TD
PBTD
COMPUTATION DATE: 30-JUN-86
DATE OF SURVEY: 6-JUN-86 ~:,
~~~ STRATIGRAPMIC
MEASURED DEPTH
BELOW KB
8079.00
8136.00
8206.00
8353.00
8508.00
8409.00
KELLY BUSHING ELEVATION:
ENGINEER: WARNER
FROM KB
6379.53
6423.79
6478.21
6592.29
6709.98
6635.65
SURFACE LOCATION
AT
ORIGIN= 2561 FSL~ 54 FEL~ SEC 29,'TI3N~',:RgE-
TVD RECTANGULAR COO.RDXNATES
SUB-SEA NORTH/SOUTH'.:::'
6311.53 273.13 S ,436g,24 E
6355.79 Z66.6,1. S :'." 4404.56 E
6410.21 258.59 S ~4;~7,85 E
6524.29 241.19 S ' 4538.92 E
6641.98 222.91 S 4633.36 E
6567.65 234.45 S-:.. 457'3.71 E
FINAL WELL LDCATION AT TD:
TRUE SUB-SEA
MEASURED VERTICAL VERTICAL
DEPTH DEPTH DEPTH
8409.00 6635.65 6567.65
HORIZONTAL DEPARTURE
DISTANCE AZIMUTH
FEET DEG MIN
4579.72 S 87 3 E
SCHLUMBEROER
D I REC T I ONAL SURVEY
COMPANY ARCO ALASKA INC
WELL 3N- 1S
F I ELD KUPARUK
COUNTRY USA
RUN 1
DATE LOOOED 0'7 - JUN - S6
REFERENCE
000071SS6
(1561 'L, 55 ' FEL, SEC. 29,T13N, R9E'U~
HORIZONTAL PROJECTION"'?{
SOUTN -4000
-2000
~EST
- l OOO 0 1000 2000 3000 4000 SO00
VERTICAL. PROJECTION:'
~ -?-7~'?-~-'f-7-7~~-~"'
PROJECTION ON VERTICAL PLANE
93. - 273.
SCALED IN VERTICPL OEPTHS
HORIZ SCALE = l/lO00 IN/FT
./.'~.-~. :¢ -" :-?
601, hll,~,.:.,i,. ,'
A_tasl¢, Oil & 6as lions. -o"
Anchorage
STATE OF ALASKA
ALASr, A OIL AND GAS CONSERVATION COM, ..... iON
REPORT OF SUNDRY WELL OPERATIONS
1. Operations performed: Operation shutdown C Stimulate ~ Plugging ~ Perforate:~ Pull tubing
Alter Casing ~ Other ~ Comp'lete
2. Name of Operator
ARCO Alaska, Inc.
3. Address
P.O. Box 100360 Anchoraqe~ AK 99510
4. Location of well at surface
1561'FSL, 54'FEL, 5ec.29, T13N, RgE, UM
At top of productive interval
1288' FSL, 965'FEL, Sec.28, T13N, RgE, UH
At effective depth
1327'FSL, 760'FEL, Sec.28, T13N, R9E, UM
At total depth
1338'FSL, 701'FEL, Sec.28, T13N, R9E, UM
11. Present well condition summary
Total depth: measured 8508
true vertical 6710
Effective depth: measured
8409
true vertical
6636
Casing
Conductor'
Surface
Length
80'
4284'
8496'
Production
Size
16"
9-5/8"
7"
feet
feet
feet
feet
5. Datum elevation (DF or KB)
RKB 68' Feet
6. Unit or Property name
~ll[~arlJ[~ [?~v~_f' Ilnit-
7. VVell number
3N-15
8. Approval number 153
9. APl number
50-- 029-21592
10. Pool
Kuparuk River 0il Pool
Plugs (measured) None
Junk (measured)
Cemented
255 sx CS II
1250 sx AS I11 &
350 sx Class G
325 sx Class G &
175 sx AS I
None
Measured depth
115'MD
4321'MD
8496'HD
~ue Vertical depth
115'TVD
3636'TVD
6703'TVD
Perforation depth: measured 8229'MD
8231 ' MD
true vertical 6496'TVD
6498 ' TVD
Tubing (size, grade and measured depth)
2-7/8", J-55, tbg w/tail ~ 8044'
Packers and SS.SV (type and measured depth)
HB pkr ~ 7973 & FVL SSSV ¢ 1777'
8233'MD
8257'MD
6499'TVD
6518'TVD
8260'MD
8262'MD
6520'TVD
6522'TVD
8265'MD
8270'MD-8284'MD
6524'TVD
6528'-6539'TVD
RECEIVED
12. Stimulation or cement squeeze summary
N/A
Intervals treated (measured)
Treatment description including volumes used and final pressure
/W(':; 1986
Alaska Oil & Gas Oons. Commission
Anchorage
13.
Representative Daily Average Production or Injection Data
N/A OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure
Prior to well operation
Subsequent to operation
Tubing Pressure
14. Attachments (Completion Well History w/Addendum, dated 6/11/86)
Daily Report of Well Operations ~ Copies of Logs and Surveys Run
15. I hereby certify that the foregoing is true and correct to the best of my knowledge
Gyro
Form 10-404 Rev. 12-1-85
Title Associ ate Engineer
Date
Submit in Duplicate
(DAM) SWO/080
ARCO Oil and Gas Company
Daily Well History-Final Report
Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned. or Sold.
"Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not
required Upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire
operation if space is available.
District
Accounting cost center code
State
Alaska
Well no.
3N-15
Field
Alaska
Kuparuk River
County or Parish
North Slope Borough
ILease or Unit
ITitle ADL 25520
I Completion
Auth. or W.O. no.
AFE AK1223
Nordic 4
Operator
ARCO Alaska, Inc.
Spudded or W.O. begun
Complete
Date and depth
as of 8:00 a.m.
7/16/86
7/17/86
A.R.Co. W.I.
Date 56.24%
7/16/86
Complete record for each day reported
Old TD
Released rig
OgO0 hrs.
Classifications (oil, gas, etc.)
Producing method
Flowing
Potential test data
API 50-029-21592
I otal number of wells (active or inactive) on this
Dst center prior to plugging and
bandonrnent of this well
our I Prior status if a W.O,
I
1230 hrs.
7" @ 8496'
8409' PBTD, NU & tst tree
9.9+ ppg NaC1/NaBr
Accept rig @ 1230 hrs, 7/16/86. ND tree, NU & tst BOPE. RU
DA, perf 8270'-8284', 8257', 8260', 8262', 8265', 8229', 8231'
& 8233' @ 1SPF, 120° phasing. RU & rn 256 jts, 2-7/8", J-55,
6.5# EUE 8RD AB Mod tbg w/SSSV @ 1777', HB pkr @ 7973', D
nipple @ 8011', TT @ 8044'. ND BOPE, NU & tst tree.
7" @ 8496'
8409' PBTD, RR
Diesel
Displ well w/diesel.
RR @ 0900 hrs, 7/16/86.
RECEIVED
AUG- 5 1986
Alaska Oil & Gas Cons. Oommission
Anchorage
New TD PB Depth
Date Kind of r g
7/16/86
IType completion (single, dual, etc.)
Single
Official reservoir name(s)
Kuparuk Sands
Rotary
Well no. Date Reservoir Producing Interval Oil or gas Test time Production
Oil on test Gas per day
Pump size, SPM X length Choke size T.P. C,P. Water % GOR Gravity Allowable Effective date
corrected
The above is correct
Si g n at u re ,~~~.._~..~ _~,
For form preparation and distribution,
see Procedures Manual, Section 10,
Drilling, Pages 86 and 87.
Drilling Supervisor
ADDENDUM
WELL:
3N-15
5/19/86
Arctic Pak well w/175 sx AS I, followed by 60 bbls Arctic
Pak.
6/08/86
Rn 6-1/8" gage ring/JB to 8401'. Rn CET log
f/8395'-6942'. Rn gyro f/8336'-52'.
RECEIVED
AUG ,~-5 198~
Alaska Oil & Gas Cons. Commission
Anchorage
Drilling Supervisor
Date
ARCO Alaska. in
Post Office Box 100360
Anchorage. Alaska 99510-0360
Telephone 907 276 1215
RETURN TO:
ARCO ALASKA, INC.
ATTN: Kuparuk Records Clerk
ATO 1119
P. O. Box 100360
Anchorage AK 99510-0360
DATE 05-27-86
TRANSMITTAL # 5676
Transmitted herewith are the following items. Please acknowledge receipt and
return one signed copy of this transmittal.
~ 3N-16
---- 3N-15
--- 2T-14
----- 2T-13
05-18-86 Run #1 1'990.5-9269.0
05-10-86--Run #1 2186.5-8523.0
05-03-86 Run #1 7600.0-8215.5
05-11-86 Run #1 1491.0-7878.0
Open Hole LIS Iape plus Listing: Schl: One copy of each
Anch0mge
Receipt Acknowledged:
~State-of 'Alaska*~ .....
Date:
ARCO Ahllki, I.C. aS 4 Su0l~Ohlry o! Atlal~t~cRac~fl/ic~Comolm¥
STATE OF ALASKA
ALAS;~-~ ,.)IL AND GAS CONSERVATION COMtv,,.,$1ON
APPLICATION FOR SUNDRY APPROVALS
1. Type of Request: Abandon ~ Suspend ~ Operation Shutdown .~ Re-enter suspended well C Alter casing ~
Time extension ~ Change approved program ~ Plugging ~ Stimulate ~ Pull tubing ~ Amend order ~ Perforate- Other
2. Name of Operator
ARCO Alaska, Inc. 68' RKB
3. Address 6. Unit or Property name
P. O. Box 100360 Anchorage. AK 99510 K~pari,b, l~iver Ilnit
4. Location of well at surface 7. Well number
1561'FSL, 54'FEL, Sec.29, T13N, R9E, UM 3N-1,5
At top of productive interval 8. Permit number
1323'FSL, 844'FEL, Sec.28, T13N, R9E, UM (approx) 86-90
At effective depth 9. APl number
1402'FSL, 755'FEL, Sec.28, T13N, R9E, UM (approx) 50--029-21592
At total depth 10. Pool
1415'FSL, 694'FWL, Sec.28, T13N, R9E, UM (approx) Kuparuk River Oil
5. Datum elevation (DF or KB)
Pool
feet
11. Present well condition summary
Total depth: measured 8508
true vertical 6700
Effective depth: measured
true vertical 8409
6623
Casing Length Size
Cond'ucto r ~ 80 ' 1 6"
Surface
4284' 9-5/8"
8496' 7"
Production
feet Plugs (measured) None
feet
feet Junk (measured)
feet N o n e
Cemented Measured depth
255 sx CS I I 115'MD
1250 sx AS III
350 sx Class G
325 sx Class G
& 4321 'MD
8496'MD
~ue Verticaldepth
115'TVD
3639'TVD
6690'TVD
Perforation depth: measured None
true vertical N o n e
Tubing (size, grade and measured depth) None
Packers and SSSV (type and measured depth) No n e
12.Attachments
Well Hi story
Description summary of proposal [] Detailed operations program [] BOP sketch
13. Estimated date for commencing operation
July, 1986
14.
If proposal was verbally approved
Name of approver
Date approved
15. I hereby certify that the foregoing is true and correct to the best of my knowledge
Signed ~--~(~ ~oLL~'L~,,' Title Associate Engineer
~ Commission Use Only ( DAM ) SA/043
Conditions of approval Notify commission so representative may witness I
[] Plug integrity ~ BOP Test [] Location clearance
I
Date
Approved by
Approval No.
Commissioner
by order of
the commission Date
Form 10-403 Rev 12-1-85 Submit in triplicate
ARCO Oil and Gas Company
Well History- Initial Report- Daily
Instructions: Prepare and submit the "initial Report" o. the first Wednesday after a well is spudded or workover operations are slarted.
Daily work prior to spudding should be summarized on the form giving inclusive dates only.
District
Field
Alaska
County. parish or
Lease or Unit
ITte
borough
North Slope Borough
ADL 25520
Drill
IState
Alaska
Kuparuk River
Well no.
3N-15
Auth. or W.O. no.
AFE AK1223
Doyon 9
API 50-029-21592
Operator
ARCO Alaska, Inc.
Spudded or w.O.spuddedbegun JDate 5/6/86 JHour
Date and depth
as of 8:00 a.m.
5/06/86
5/07/86
5/o8/86
5/09/86
Complete record for each day reporled
0230 hrs.
ARCO W.I.
Pr or status if a W.O.
56.24%
16" @ 115'
575', (460'), Drlg
Wt. 9.2, PV 23, YP 21, PH 9.0, WL NC, Sol 6
Accept rig @ 2400 hrs, 5/05/86. NU diverter.
5/6/86. Drl 12¼" hole to 575'.
Spud well @ 0230 hrs,
16" @ 115'
3345', (2770'), Drlg
Wt. 9.8, PV 22, YP 24, PH 8.5, WL 11.6, Sol 10
Drl & surv 12¼" hole to 3345'.
950', .4°, S35.7E, 949.97 TVD, 3.82 VS, .15S, 3.82E
1254', 6.9°, S85.4E, 1253.28 TVD, 18.88 VS, 4.53S, 18.67E
1595', 16.7°, S85.2E, 1586.71TVD, 88.29 VS, 9.86S, 87.89E
9-5/8" @ 4321'
4340', (995'), Wsh out diverter
Wt. 9.6, PV 24, YP 18, PH 9.0, WL 10.8, Sol 10
Drl 12¼" hole to 4340', short trip, C&C, POH. RU & rn 108 jts,
9-5/8", 36#, J-55 BTC csg.w/FC @ 4239', FS @ 4321'. Cmt w/1250
sx AS III w/10#/sx Gilsonite. Tail in w/350 sx Cl "G" w/2% S-1
& .2% D-46. CIP @ 0520 hrs, 5/8/86.
2797', 44.8°, S81.0E, 2562.65 TVD, 759.99 VS, 104.47S, 755.33E
3623', 45.6°, S78.3E, 3150.83 TVD, 1333.99 VS, 215.33S, 1324.46E
4269', 45.4°, S76.7E, 3602.99 TVD, 1788.69 VS, 317.35S, 1774.39E
9-5/8" @ 4321'
6538', (2198'), Drlg
Wt. 9.5, PV 12, YP 5, PH 9.5, WL 6.4, Sol 8
ND diverter. NU & tst BOPE. TIH w/8½" BHA, tst csg to 2000
psi. DO flt equip &cmt + 10' new hole. Conduct formation tst
to 12.5 ppg EMW. Drl & surv 8½" hole to 6538'.
4767', 45.9°, S83.7E, 3951.11TVD 2142.11VS, 377.93S, 2125.11E
5046', 45.2°, S89.5E, 4146.49 TVD, 2341.19 VS, 389.73S, 2323.84E
5643', 44.4°, N88.9E, 4570.10 TVD, 2761.13 VS, 387.53S, 2744.48E
6115', 43.7°, N86.3E, 4909.34 TVD, 3087.80 VS, 373.79S, 3072.34E
The above is correct
For form preparation and di~ ribution,
see Procedures Manual, Section 10,
Drilling, Pages 86 and 87.
IDate Title
I
Drilling Supervisor
ARCO Oil and Gas Company
Daily Well History-Final Report
Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold.
"Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not
required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire
operation if space is available.
DistrictAlaska County or Parish
Field Lease or Unit
Kuparuk River
Auth. or W.O. no. J T t e
AFE AK1223
I
Doyon 9
Operator I A.R.Co. W.I.
ARCO Alaska, Inc.
I
Spudded or W.O. begun Date
Spudded
Date and depth Complete record for each day reported
as of 8:00 a.m.
5/10/86
thru
5/12/86
Accounting cost center code
State
North Slope Borough Alaska
ADL 25520
Drill
JWell no.
3N-15
API 50-029-21592
rTotal number of wells (active or inactive) on this
56 24% Jcost center prior to plugging and
· Jabandonment of this well
IHour I Prior status if a W.O.
5/6/86 / 0230 hrs.
I
/
7" @ 8496'
8508' TD, (8409' PBTD), RR
10.0 ppg Brine
Drl & surv 8½" hole to 8508', 25 std short trip, CBU, POOH. RU
SOS. Ran DIL/GR/SP/SFL f/8506'-4321', FDC/CNL f/8506'-7600', &
Cal f/8506'-4321'. Rd SOS. RU & rn 206 its, 7", 26#, J-55 BTC
csg & 1 mkr jt set @ 8496'. Cmt w/100 sx 50/50 Poz & 225 sx Cl
"G" w/3% KCl, .9% D-127, .3% D-13 & .2% D-46. Displ w/brine
using rig pmps, bump plug. ND BOPE, instl pack-off, NU 3" 5M x
7-1/16" tbg head. Tst pack-off to 3000 psi. RR @ 2030 hrs,
5/11/86.
FC @ 8410', FS @ 8496'
6590',43.2°, N85.1E,5254.18 TVD,3411.79 VS, 349.30S,3398.08E
7569',41.2°, N81.2E,5979.22 TVD,4058.79 VS, 265.88S,4050.88E
8041',39.7°, N77.2E,6338.39 TVD,4356.07 VS, 208.52S,4351.13E
8433',38.9°, N79.5E,6641.84 TVD,4595.52 VS, 156.21S,4593.68E
Old TO New TD
8508' TD 8409' PBTD
Released rig Date
2030 hrs.
Classifications (oil, gas, etc.)
Oil
Producing method
Flowing
Potential test data
I PB Depth
IKind of rig
5/11/86
I
Type completion (single, dual, etc.)
Single
JOfficial reservoir name(s)
J Kuparuk Sands
Rotary
Well no. Date Reservoir Producing Interval Oil or gas Test time Production
Oil on test Gas per day
Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date
corrected
The above is correct
For form preparation and distribution,
see Procedures Manual, Section 10,
Drilling, Pages 86 and 87.
Drilling Supervisor
.,EMORAN. UM
TH RU:
FROM:
State of Alaska
ALASKA OIL ~,~D GAS CONSERVATION COP~.IISS~ON
Chairma~Vk.~
Lonnie C, Smith
Commissioner
Bobby D. Foster
Petroleum Inspector
DATE:
FILE NO.:
'~' TELEPHONE NO.:
May 15, 1986
D.BDF.39
SUBJECT:
BOP Test
ARCO KRU 3N- 15
Permit #86-90
Kuparuk River Field
.Thursday, May 8, 1986: The BOP test began at 9:45 a.m. and was
¢OnCluded"-at 10:4'~ ~7. m. As the attached BOP test report shows, there
were no failures.
In summary, I witnessed the BOP test on ARCO's 3N-15.
102-O01A(Rev 10-84) - _ .... .'
STATE OF AL;3KA
ALASKA 0IL & GAS CONSERVATION C0~"2MISSION
B.0.P.E. Inspection Report
Operato
Lo=ation: Sec ~ T/3/~Ri~_M iJ
Location, General (P ~ Well Sign
General Housekeeping. ~/~Rig.. ~'
~eserve ~tt ~ ~
Mud Systems Visual Audio
Trip Tank
Pit Cauge ~'~
Flow Monitor ~-~
Gas Detectors
·
BOPE S tack
Annular ?reventer
Pipe Rams
Blind Rams
Choke Line Valves
H. C.R. Valve
Kill Line Valves
Check Valve
Test pressure
Date
Representative l ) ,' ~Cc~ ~J
ACCUgVLATOR SYSTE~
Full Charge Pressure ~ ~ao
Pressure After Closure /~/~
Pump incr. c2os. pres. 200 psig
Full Charge Pressure Attained:
q !
Representative ~'~
psig
psig.
- ~ln~?,sec.
·
N~.~ .~. ~~., /~/~
Controls: M~er ~~
R~ote~ Blinds switch
. Kelly and Floor Safety Valves '
Upper Kelly / Test Pressure ~
Lower Kelly / Test Pressure ~
Ball Type ~ Test Pressure
Inside BOP / Test Pressure ~
Choke Manifold ~~ Test Pressure~o~
No. flanges ~ ~
Adjustable Crookes. ~
Hvdrauica!lv operated choke
Test Results: Failures 0 Test Time /
Repair or Replacement of failed equipmen: to be made ~-ithin
·
Commission office notified. -'
Remarks:' '
hfs.
day~ and Inspector/
Distribution
orig. - AO&GCC
cc - Operator
CC - Supervisor
May 5, 1986
Mr. J. Bo Kewin
Regional Drilling Engineer
ARCO Alaska, Inc.
P. O. Box 100360
~chorage, Alaska 99510-0360
Telecopy:
(907) 276-7542
Re: 3N-15
ARCO Alaska, Inc,
Permit No. 86-90
Sur. Loc. !561!FSL, 54'FEL, Sec. 29, T13N, RgE, UM.
Btmhole Loc. t3!0'FSL, 602'FEL, Sec. 28, T13N, R9E, U~.
Dear Mr. Kewin:
Enclosed is the approved application for permit to drill the
above referenced well.
The permit to drill does not indemnify you from the probable need
to obtain additional permits required by law from other
governmental agencies prior to comanencing operations at the well
site.
To aid us in scheduling field work, please notify this office 24
hours prior to commencing installation of the blowout prevention
equipment so that a representative of the Commission may be
present to witness testing of the equipment before the surface
casing shoe is drilled. Where a diverter system is required,
please also notify this office 24 hours prior to commencing
equipment installation so that the Commission may witness testing
before drilling below ~the shoe of the conductor pipe.
Ver~ tr~ll~]~our s,
C. V. C~-t'terton
Chairman o f
Alaska Oil and Gas Conservation Comission
BY ORDER OF THE COI~-iISSION
d!f
Enclosure
cc: Department of Fish & Game, Habitat Section w/o enc!.
Department of Environmental Conservation w/o encl.
Mr. Doug L. Lowery
STATE OF ALASKA
ALASKA L,.,_ AND GAS CONSERVATION CO,.,,vllSSlON
PERMIT TO DRILL
20 AAC 25.OO5
la. Type of work Drill i~ Redrill I-ql lb. Type of well. Exploratory ~ Stratigraphic Test D Development Oil
Re-Entry ?i Deepen~1 Service ~ Developement Gas D Single Zone ~, Multiple Zone ['~
2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool
ARCO Alaska, Inc. RKB 68', PAD 34' feet Kuparuk River Field
3. Address 6. Property Designation Kuparuk River Oi 1 Pool
P.O. Box 100360 Anchorage, AK 99510 ADL 25520 ALI< 2556
4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025)
1561'FSL, 54'FEL, 5ec.29, T13N, R9E, UM Kuparuk River Unit 5tatewide
At top of productive interval 8. Well nu .tuber Number
1323'FSL, 844'FEL, Sec.28, T13N, R9E, UM 3N-15 #8088-26-27
At total depth 9. Approximate spud date Amount
1310'FSL, 602'FEL, Sec.28, T13N, R9E, UM 05/06/86 $500,000
12. Distance to nearest 13. Distance to nearest well 14. Number of acres in prOperty 15. Proposed depthIMDandTVB)
property line 8533 'MD
54' ~ surface feet 3N-14 25'~ surface feet 2560 (6701 'TVD) feet
16. To be completed for deviated wells 17. Anticipated pressure Isee 20 AAC 25.035
Kickoff depth1 000 feet Maximum hole angle 44 0 Maximum surface 291 6 psig At total depth (-rVD) 3348 psig
18. Casing program Setting Depth
size Specifications Top Bottom Quantity of cement
Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data)
24" .!6" 62.5# H-~.O w'~d 80' !35' 35' !!5' !!5' ±200 cf
12~," 9-5/8" .%6.0# .I-gq RT¢. a97~' ;qK~ qS' /~%11 ~ %GRT' 1200
HF-EBiW 310 sx Class G blend
8~" 7" 26.0# J-55 BTC 8499' 34' 34' 8533' 6701' 200 sx Class G(minimum
HF-EI~W TOC 50( ' above top of 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
Conductor
Surface
Intermediate
Production
Liner
Perforation depth: measured
true vertical
20. Attachments Filing fee ~ Property plat ~ BOP Sketch ~ DiverterSketch '~' Drilling program
Drilling fluid program ~ Time vs depth plot .rq, Refraction analysis ~r Seabed report ,%1 20 AAC 25.050 requirements
21. I hereby certif.~that the foregoing is true and correct to the best of my knowledge
,~"/'/-' . . .-.~/' .~ Regional Drilling Eng
ineer ..//
Signed / //..-~v~?ju~/ ...., :;,.)..,(¢r/~.~...c/k~.. T,tle Date%,~.//~'C.'.
76, ~ / ~ m ~ n nl ( HRE
/'~'~; '/" "' Co miss'o Use O y ) PD/PD255
Permit Numlb~er .-~ - ¢: ~ J APl number J Approval date See cover letter
~L~'--7~' J 50--E:,-L.~7-L./'.,C~;% J 05/05/86 I for other requirements
Conditions of approval Samples required [] Yes ',~¢¢---qXlo Mud Icg required ~ Yes "~ No
Hydrogen sulfide measures ~ Yes ~ No Directional survey required .,~u~.Yes ~ No
Other: Required ~~~ s~' ' · 3M; ~ 5M; ~ 1OM; ~ 15M by order of
Approved Commissioner the commission Date
Form 10-401 Rev. 12-1-85
Sub~i' ~ triplicate
/
~ ...........
I
......... ~ ...... L i '- - ~ .................. ~- ' ' ' ' : "
: ' ' - - ~ -'-t - ", ......
' I : ~ ' ~ I '. ; ' . .......
- ~ - ~ ................ ~ ........ ~- · .
i
: -~::';- _.t-_~'._:-::i:-'.:::::::::::::::::::::::::::::::: ::-:-: :'_ ' ' ' ~::::;
_---' ~'._.:,_~--4-3-' 'DEO-:'~'t :H~:-- ( - - ~ .... :, .... ~ ............... ' ............... :J~." -_
..... ! ~ - - ~"~' -' ~~ TM~.~ ~C~i~ ~': ..... : .................... ' ........... {
::: ~:: :::::-: [._:: ::::::::::::::::::::::::'::~:~~:. ~--:~. : .... ~ ·
-- ; ....... ~ ~ ..... F ................. ~~~~ ..... ~ ...... ...... ~'" .... ' .... ~ ....
I
T
_ 3::; : ;; T: ~10~-:.:;;;;:-~;;7 -: :L' ~O~.~:;_: ' 4000 5000.
: _ ~. .... ~ - ~ ~ . . _ _ ~ -
.~ .... ~ . -~ .... . .... ~ - ; .....
- ~ ..... : - i ........ ~ .... 4
-~ · ~- .: ..... ~__ . ~ ..... 4 ....
~ . . ~ ~ . ~ . _ . ~ - ._: .... ~ ..... , -
i
'- ' :-- -~ ' ''
..................................
100.0
SURE/tI::~E LOC/IT IO~ ~
1561' FSL. 54' FEL
SEC. 2g. T13N. RglE
L '
· i
KUPRRUK R ! VER UN I T
20" D I VERTER SCHEMRT I C
DESCR I PT I ON
1. 16" CONDUCTOR.
2. TANKO STARTER HEAD.
3. TANKO SAVER SUB.
4. TANKO LONER QUICK-CONNECT ASSY.
S. TANKO UPPER QUICK-CONNECT ASSY.
6. 20" 2000 PSI DRILLING SPOOL
N/lO" OUTLETS,
7. 10" HCA BALL VALVES N/lO"
DIVERTER LINES, A SINGLE
VALVE OPENS AUTOMATICALLY UPON
CLOSURE OF ANNULAR PREVENTER.
VALVES CAN BE REMOTELY CONTROLLED
TO ACHIEVE DONNNIND DIVERSION.
8. 20" 2000 PSI ANNULAR PREVENTER.
is
%%%
ARCO ALASKA, INC., REQUESTS
APPROVAL OF THIS DIVERTER
SYSTEM AS A VARIANCE FROM
20 AAC2E;. 035 (b)
MAI NTENANCE & OPERAT I ON
1. UPON INITIAL INSTALLATION, CLOSE
PREVENTER AND VERIFY THAT VALVE
OPENS PROPERLY.
CLOSE ANNULAR PREVENTER AND BLON
AIR THROUGH DIVERTER LINES
EVERY 12 HOURS.
3. CLOSE ANNULAR PREVENTER IN THE
EVENT THAT AN INFLUX OF NELLBORE
FLUIDS OR GAS IS DETECTED. OPEN
APPROPRIATE VALVE TO ACHIEVE
DONNNIND DIVERSION.
DO NOT SHUT IN NELL
UNDER ANY C I RCUMSTANCE$,.,
510084O02 RI0
<
<,
I I
b
ACC~TOR C~PAC~TY TEST
I, Q-E.O< ~ FILL ACCLI~TCR RF_S~OIR TO. PRC~
LEVEL WITH ~IC ~UID.
~ ~T A~T~ ~~ IS ~ ~I WI~
3. ~ TI~, ~ ~ ~ ~ITS SIXThlY
4. ~~ ~ ~ ~T, ~ A~T~E L~ LIMIT
IS 45 ~~ ~I~ TI~ ~ 12~ PSI ~INI~
4
13-5/8" BOP STACK TEST
I. FILL BCP STACX AhD ~ N~IFOLD WITH ARCTIC
DIESEL.
2. O-ECX TN~.? ALL LOSX ~ SCRE'MS IN ~L.U-F. AD A~E
F'LI..LY RETRACT'E~. SF,.AT TEST PLUG IN ~ELLJ..F_A~
WITH RLt,~iNG JT Ah/3 RLN IN L~ S~.
LZh~ VALVES AOJACE:NT TO BOm STAOQ ALL 0TFF_R
_ 4. ~ u~ TO Z..~ ~~og~ FC~ ~0 M~N. ~--
BL~ PAE:~ TO O-PSI.
S. CPE:N AN',LJLAR PREVENTER AN3 MANJAL KILL AN:) O-O<E
LI~E VALVES. CLOSE TOm PIPE RAMS AN] NCR VALVES
CN K.ILL AN~ CHCKE
6. TEST TO 250 PSI AhD,~~~AS IN STEP 4.
'T. COVTINUE TESTING ALL "VALVES, LI~ES, Ah/20-O<ES
WITH A ~ PSI LC~ Aha) 3000 PSI HIG;.~. TEST AS iN
STEP 4, CO NOT A:~~ TE.~T ANY O-.O<E ,'~4AT ~S
NOT A FULL CLOSING PC~ITIYE SEAL (~K:~KI~. CN..Y.
F'Lt~.CTICIN IF_ST CNO<~$ TNAT DO NOT F'LI_LY CLOSE.
8. CPEN TC~ PIPE RAN~ AN:) CLOSE BOTTO~ PIPE RA~.
I .. TEST BOTTO~ PIPE RAN~ TO 250 PSI AN:) 3000 PSI.
9. ~ BOTTCI~ PIPE RAMS, BACK OUT RUNNING JT AN2
· -PULL gJT CF HOLE,
I0, CLOSE BLII~D RAMS AI~ TEST T0'250 PS]: At~ 3000
II, ~ .BLII~) ~ ~ I:~'TR~:EVE 'TEST PLU~, MAKE-SURE
' _' -. · MAN~FOLD AI~ LIliES ARE FULL 6F I~N-C~:EZING '
' FLUID, SE"T ALL VALVES IN DRILLING POSIT]:ON,
12~' TEST STAJ~I]PIPE VALVES, KF~ LY, KELLY CO~$, DRILL
· PIPE SAFETY 'VALVE, AAD INSIDE BCP TO 250 PSI AJ~D
3OOO PSI.
13. PECCI;O 'TEST IAFCI~TIC~ CN BL(~ F~ENTER TEST
FCI~o SIGN, AND ~ TO DRILLING SU~ISCR.
14. PERFCI~ CC~ BCF~ TEST AFTER NIPPLING UP AAD
Y~IEEi<LY THERF_AFTER F1J~ICtqALLY CPIERATE BCPE DAILY.
II
510084001 REV. 2
MAY 15, 1985
DRILLING FLUID PROGRAM
Density
PV
Spud to
9-5/8" Surface Casing
9.6-9 8
15-30 ~
Drill out
to Weigh~ Up
8.7-9.2
5-15
YP 20-40 8-12
Viscosity 50-100
Initial Gel 5-15
10 Minute Gel 15-30
FiLtrate API 20
pH 9-10
% Solids 10±
35-40
2-4
4-8
10-20
9.5-10.5
4-7'
Weight Up to TD
10.3
9-13
8-12
35-45
3-5
5-12
9.5-10.5
9-12
Drilling Fluid System:
- Triple Tandem Shale Shaker
- 2 Mud Cleaners
- Centrifuge
- Degasser
- Pit Level Indicator (Visual & Audio Alarm)
- Trip Tank
- Fluid Flow Sensor
- Fluid Agitators
Notes:
Drilling fluid practices will be in accordance with the
appropriate regulations stated in 20 AAC 25.033.
Maximum anticipated surface pressure is calculated with
an unexpanded gas bubble at Surface, including temperature
effects.
After 200' of departure, there are no well bores within 200'
of this proposed well ·
LWK5 / ih
GENERAL DRILLING PROCEDUk-
KUPARUK RIVER FIELD
DEVELOPMENT WELLS
1. Move in rig.
2. Install Tankco diverter system.
Drilt 12¼'' hole to/9,5/8" surface casing point according to directional
plan.
RUn and cement 9-5/8" casing.
5. Install and test blow out-preventer° Test casing to 2000 psig.
6. Drill out cement and 10' new hole. Perform leakoff test.
7. Drill 8½" ho. le to logging point according to directional plan.
8. Run open hole logs.
9. Continue drilling 8½,, hole to provide 100' between plug back total depth
and bottom of Kuparuk sands..
10o Run and cement 7" casing. Pressure test to 3500 psig.
1t. Downsqueeze Arctic Pack and cement in 7" x 9-5/8" annulus.
12. Nipple down blow out preventer and install temporary Xmas tree.
13. Secure well and release rig.
14. Run cased hole logs.
15. Move in workover rig. Nipple up blow out preventer.
16. Pick up 7" casing scraper and tubing, trip in hole to plug back total
depth. Circulate hole with clean brine and trip out of hole standing
tubing back.
17o Perforate and run completion assembly.
18. Nipple down blow out preventer and install Xmas tree.
19. Change over to diesel and set packer.
20. Flow well to tanks. Shut in.
21. Secure well and release rig.
22. Fracture stimulate.
m~D
·
ST! P, ~
E
*--
C. ENTR I F LI6fi---}
LWK4 / ih
T'y'PIC~/_ Ir'iuD 5¥$T~r'3 5C..I-IEr,3~TI¢
ARCO Alaska, Inc.
Post Office Box 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
January 31, 1986
Mr. C. V. Chatterton
Commissioner
State of Alaska
Alaska Oil & Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, AK 99501
SUBJECT' Conductor As-Built Location Plat - 3N Pad
(Wells 1- 18)
Dear Mr. Chatterton'
Enclosed is an as-built location plat for the subject wells.
you have any questions, please call me at 263-4944.
Sincerely,
· Gruber
Associate Engineer
JG/tw
GRU13/L45
Enclosure
If
ARCO Alaska. inc. is ~ Subsidiary of AtlanticRichfieldCompeny
iml . i
. ,~ 20~21
..,CATED IN PROTRACTED SEC's 28 & ,.,%TI~ N, R 9E,U.M.
.,. ,
THIS SURVE~ ~
LOCATED IN PROTRACTED LOCATED IN PROTRACTED
SEC. 29, TISN~ RgE~ U.M. SEC. 29, TISN,RgE, U.M.
1 - Y = 6,013,799.67 LAT. 70°26'55.9615`' 10 - Y = 6,013,799.37 LAT. 7~°26 ' 55. 9519''
X - 517,946.19 LONG. 149°51 ' 12. 938" X = 518,221.07 LONG.~9°51'04.865''
454' FEL, 156~' FSL 0G = 28.2 PAD = 33.7 179' FEL, 1561' FSL 0G
2 - ~ - 6,013,799.65 LAT. ?0026'55.9606" I1 - Y = 6,0!3,799.32 LAT. ~0°26'55.9508"
X = 517,971.21 LONG.149°51'12.203" X - 518,246.03 LONG.L~9°51'04.132"
429' FEL, 1562' FSL 0G = 28.2 PAD = 33.8 155' FEL, i561' FSL 0G - ~.5 PAD = 33.~
3 - Y = 6,013,799.54 LAT. 70026'55.9590" 12 - 'f = 6,013,799.45 LAT. ;0°26'55.9515"
X = 517,996 25 LONG.149°51'll.468'' x = 5i8,270 89 LONG.[~9°51'03.403''
· '
404' FEL, 1562' FSL 0G = 28.4 PAD = 33.9 130' FEL, 1561' FSL 0G = ~.5 PAD '= 34.0
4 - Y = 6,013,799.50 LAT. 70026'55.9580" I3 - Y = 6,013,799.41 LAT. ~°26' 55. 9505"
X~= 518,021.16 LONG. 149°51'10.736'' X = 518,295.97 LONG.[~9~51'02.666"
379' FEL, 1562' FSL 0G = 28.4 PAD = 33 7 ~ 105' FEL, 1561' FSL OG ' ~.5 PAD ~ 34.1
5 - Y ' 6,013,799.~ LAT. 70026'55.9572" ~ 14 - Y - 6,013,799.33 LAT. 7~°26'55.9491"
X = 518,046.18 LONG. 149°51'i0.002" '~ X = 518,320.91 LONG. iag~51'01-93
354' FEL, 1562' FSL 0G = 28.5 PAD = 33.7 ~ ~ 80' FEL, [561' FSL OG ' ~.5 PAD ~ 34.0
6 - Y = 6,013,799.44 LAT. 70026'55.9562" ~ CO ~ 15 - Y = 6,013,799.28 LAT. 70026'55.9480"
X = 518,071.24 LONG.149°51'09.266" ~ X = 518,345.77 LONG.img°51'01.204''
~ m 55' FEL, 1561' FSL OG - ~.5 PAD : 34.0
7 - Y : 6,013,799.44 LAT. 70026'55.9556'' ~ ~ ~ ~ 16 - Y = 6,013.799.25 LAT. ~D°26'55.9471"
X = 518,096.21 LONG'149°51' 08' 533" ~ 0 ~ ~ X = 518,370.74 LONG.I~9°51'O0.470"
304' FEL, 1561' FSL OG = 28.5 PAD = 33.9 ~ ~ 0 ~ 30' FEL, 1561' FSL OG = ~.5 PAD = 34.1
8 - Y : 6,013,799.45 LAT. 70°26'55.9551'' ~ ~ ~ 17 - Y : 6,013,799.26 LAT. 70°26'55.9466''
X = 518,121.15 LONG. 149°51'07.800" -- X : 518,395.63 LONG.ZZ9o50'59.739"
279' FEL, 1561' FSL OG : 28.6 PAD : 33.9 ~ ~ ~ 5' FEL, 1561' FSL OG = ~.5 PAD = 34.1
9 Y = 6,013,799.42 LAT. 70~26'55.9542"
-
X : 518,146.15 LONG. 149°51'07.066'' c~ SEC. 28,TI3N, RgE, U.M.
254' FEL, 1561' FSL OG = 28.6 PAD = 34.0 ~ 18 - Y = 6,013,799.15 LAT. 7~°26'55.9449"
X = 518,420.80 LONG.!ZP°50'Sg. O00''
NOTES ~0' FWL, i56i' FSL OG : ~..5 PAD = 34.0
I. ALL COORDINATES ARE A.S.P.,ZONE4.
2. SECTION LINE DISTANCES ARE TRUE.
3. HORIZONTAL POSITIONS BASED ON ON-PAD PILING CONTROL PER LHD & ASSOC.
4. VERTICAL POSITIONS BASED ON MODULE PILES 3JOI -8 ~ 3J01-4.
5.O.G. ELEVATIONS INTERPOLATED FROM S/C DRAWING CED-RIXX-3OgO rev. .
CERTIFICATE 0¢ SURVEYOR; i mE~EBY CERT:FY THAT I AM PROPERLY
j m ....
.... ~- ' ' I]~ =~E CORRE:~ AS OF 14 JAN 86 ~
AS-BUILT LOCATIONS
....... 11~o~
i
C~ECK LIST FOR NEW WELL PERMITS
ITEM APPROVE DATE
Fee </z'.--~ ~"~ I.~-~ 6
....
( hru 8)
(9- thru 13) 10.
(10 and 13) / " 12.
13.
(4)
(14 thru 22)
(5) BOPE
(23 thru 28)
Company ~
YES
1. Is the permit fee attached .......................................... ~--~-
Lease & Well No.
NO
2. Is well to be located in a defined pool ............................
3. Is well located proper distance from property line ....
4. Is well located proper distance from other wells ..... ~ '.'....
5. Is sufficient undedicated acreage, available in this pool ............
6. Is well to be deviated and is wellbore plat included ................
7. Is operator the only affected party .................................
8. Can permit be approved before ten-day wait ..........................
Does operator have a bond in force ...................................
Is a conservation order needed ......................................
Is administrative approval needed ...................................
Is the lease number appropriate
eeeeeeeeeeeeeeeeeeeeee.eeeeeeeeeeeee,
Does the well have a unique name and number .........................
·
14.
15.
16.
17.
18.
19.
20.
21.
22.
Is conductor string provided ........................................ ~
Will surface casing protect fresh water zones .......................
Is enough cement used to circulate on conductor and surface .........
Will cement tie in surface and intermediate or production strings ...
Will cement cover all known productive horizons .....................
Will all casing give adequate safety in collapse, tension and burst..
Is this well to be kicked off from an existing wellbore .............
Is old wellbore abandonment procedure included on 10-403 ............
Is adequate wellbore separation proposed ............................
23.
24.
25.
26.
27.
28.
Is a diverter system required ......................................
Is the drilling fluid program, schematic and list of ;quipment adequate
Are necessary diagrams and descriptions of diverter and BOPE attached.
Does BOPE have sufficient pressure rating - Test to ~OO~) psig ..
Does the choke manifold comply w/API RP-53 (Feb.78) ..................
Is the presence of H2S gas probable .................................
REMARKS
(6) OTHER
(29 thru 31)
(6) Add:
For
29.
30.
31.
exploratory and Stratigraphic wells:
Are data presented on potential overpressure zones? .................
Are seismic analysis data presented on shallow gas zones ............
If an offshore loc., are survey results of seabed conditions presented
32. Additional requirements .............................................
0
Geology:
WVA
JAL
.
Engj~keering:
.CS EW
MTM'/r4~' HJH .~r,
rev: 04/03/86
6.011
POOL
INITIAL
CLASS STATUS
GEO.
AREA
,y .-.' j
UNIT
NO.
ON/OFF
SHORE
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 APPENDIXi
..
No special'effort has been made to chronologically
organize this category of information.
~':~' .... $ C H L J M 8 E R G E R .... ~;¢
LIS 'FAP,E
V~E~i;ICATIJN LIST'iNG
:~:= =iLE ME&DER
!LE N&qf :EDIT
ERVICE NA~E :
ATE :
AXIMUM LENGTH :
IW~ TYPE :
REViJJS FILE
· 0 01
-':','~ iNF3RNATiON REC,3:,'3:5 <-'
lNEq CONTENTS OI4ZT TYPE C&TE ':SIZE C,3DE
'N : ARCO ALASK,t, IN'. ,300 000 018 055
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~Aqg: 9 'E OOO 009 004 065
FSWN: 13 N 000 000 OO& 065
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