Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout185-095MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Monday, January 22, 2024
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Brian Bixby
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
ConocoPhillips Alaska, Inc.
1R-09
KUPARUK RIV UNIT 1R-09
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 01/22/2024
1R-09
50-029-21350-00-00
185-095-0
W
SPT
6309
1850950 1577
2450 2450 2450 2450
400 500 500 500
INITAL P
Brian Bixby
12/13/2023
MITIA as per SUNDRY 323-442. Post RWO
30 MinPretestInitial15 Min
Well Name
Type Test
Notes:
Interval P/F
Well
Permit Number:
Type Inj TVD
PTD Test psi
API Well Number Inspector Name:KUPARUK RIV UNIT 1R-09
Inspection Date:
Tubing
OA
Packer Depth
840 1810 1770 1765IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitBDB231213111748
BBL Pumped:0.9 BBL Returned:0.9
Monday, January 22, 2024 Page 1 of 1
9
9
9
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7HVWGXH ZHOOVKXWLQVLQFH MEU
Post RWOSUNDRY 323-442.
James B. Regg Digitally signed by James B. Regg
Date: 2024.01.22 10:26:58 -09'00'
1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown
Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program
Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Replace Tubing
Development Exploratory
Stratigraphic Service 6. API Number:
7. Property Designation (Lease Number): 8. Well Name and Number:
9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s):
11. Present Well Condition Summary:
Total Depth measured 8225'feet None feet
true vertical 6752' feet 7986'feet
Effective Depth measured 7947'feet 7348', 7617'feet
true vertical 6548' feet 6118', 6309'feet
Perforation depth Measured depth
True Vertical depth
Tubing (size, grade, measured and true vertical depth) 2-7/8"
2-7/8"
J-55
L-80
7689'
7607'
6361'
6302'
Packers and SSSV (type, measured and true vertical depth)7348'
7617'
6118'
6309'
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure: N/A
13a.
Prior to well operation:
Subsequent to operation:
13b. Pools active after work: Kuparuk Oil Pool
15. Well Class after work:
Daily Report of Well Operations Exploratory Development Service Stratigraphic
Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL
Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG
Sundry Number or N/A if C.O. Exempt:
Authorized Name and
Digital Signature with Date: Contact Name:
Contact Email:
Authorized Title: Contact Phone:
4039' 3792'
Burst CollapseCasing
8162' 7" 8210' 6741'
3991'
115'Conductor
Surface
16"
9-5/8"
67'
Production
measured
TVD
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
185-072
50-029-21350-00-00
P.O. Box 100360
Anchorage, AK 99510
3. Address:
ConocoPhillips Alaska, Inc.
N/A
5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work:
ADL0025635
Kuparuk River Field/ Kuparuk Oil Pool
KRU 1R-09
Plugs
Junk measured
Length
measured
true vertical
Packer
Representative Daily Average Production or Injection Data
Casing Pressure Tubing Pressure
14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283)
Gas-Mcf
MDSize
115'
N/A
323-442
Sr Pet Eng: Sr Pet Geo: Sr Res Eng:
WINJ WAG
Water-BblOil-Bbl
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
N/A
Baker FH 47B2
CAMCO HRP-A-SP RETR
SSSV: None
Shane Germann
shane.germann@conocophillips.com
(907) 263-4597Staff RWO/CTD Engineer
7728-7768', 7896-7904', 7912-7944', 7975-7980'
6389-6418', 6511-6516', 6522-6546', 6568-6572'
Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov
By Samantha Carlisle at 10:11 am, Nov 14, 2023
Digitally signed by Shane Germann
DN: O=ConocoPhillips Alaska, CN=Shane
Germann, E=shane.germann@cop.com
Reason: I have reviewed this document
Location:
Date: 2023.11.09 11:23:50-09'00'
Foxit PDF Editor Version: 13.0.0
Page 1/4
1R-09
Report Printed: 11/9/2023
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/17/2023
12:00
10/17/2023
17:00
5.00 MIRU, MOVE MOB P Pull sub off of well. Clean up around
well. Move mats T/ 1R-09. Hang tree in
cellar. Spot sub over well.
0.0 0.0
10/17/2023
17:00
10/17/2023
20:00
3.00 MIRU, WELCTL RURD P Spot rig auxiliary equipment, Kill tank's,
cuttings tank, High Line trailer and mud
shack, hook up electric cables
Rig up circulating lines in cellar for well
kill and to hard lines to kill tanks
Rig accepted at 19:30 HRS
0.0 0.0
10/17/2023
20:00
10/17/2023
21:00
1.00 MIRU, WELCTL RURD P Bring on 8.5 PPG seawater to pits and
build deep clean pill
KDTH run hard line and hoses from kill
tanks to rig
Obtain RKB - 26.43'
Record pressures on TBG , IA and OA
0/0/0 PSI
0.0 0.0
10/17/2023
21:00
10/17/2023
22:45
1.75 MIRU, WELCTL SEQP P Double check all lines from tree to kill
tanks, blow air thru lines, test with air
Flood lines test to 400 PSI and 3500
PSI - good test
Bleed off pressure, blow down lines
Finish brining on seawater to pits
0.0 0.0
10/17/2023
22:45
10/18/2023
00:00
1.25 MIRU, WELCTL KLWL P PJSM - Circulate 8.5 PPG seawater
around
Pump 34 BBL Deep clean pill
Chase with 157 BBLS 8.5 PPG
seawater
Pump at 4 BPM
0.0 0.0
10/18/2023
00:00
10/18/2023
01:00
1.00 MIRU, WELCTL KLWL P Continue to circulate 8.5 PPG seawater
around
4 BPM
Pump a total of 368 BBLS
0.0 0.0
10/18/2023
01:00
10/18/2023
01:30
0.50 MIRU, WELCTL OWFF P Flow check - check for PSI no pressure,
open up TBG had slight flow then stop,
IA had slight flow and did not slow down
0.0 0.0
10/18/2023
01:30
10/18/2023
02:00
0.50 MIRU, WELCTL CIRC P Pump 50 more BBLS 8.5 PPG seawater
at 4 BPM
0.0 0.0
10/18/2023
02:00
10/18/2023
03:00
1.00 MIRU, WELCTL OWFF P Flow check, TBG have 15 PSI and IA
have 20 PSI, bleed off to tank
Shut in check for pressure, no pressure
watch for 10 min no pressure build up
Open to atmosphere, TBG no flow, IA
have slight flow then stop
Perform 30 min no flow check
0.0 0.0
10/18/2023
03:00
10/18/2023
04:00
1.00 MIRU, WELCTL MPSP P Set ISA BPV and test from below to
1000 PSI F/10 min
0.0 0.0
10/18/2023
04:00
10/18/2023
04:30
0.50 MIRU, WHDBOP RURD P Blow down lines, rig down lines 0.0 0.0
10/18/2023
04:30
10/18/2023
06:00
1.50 MIRU, WHDBOP NUND P N/D tree, inspect hanger threads.
Function LDS. Install FMC slip on
blanking plug
0.0 0.0
10/18/2023
06:00
10/18/2023
11:30
5.50 MIRU, WHDBOP NUND P N/U BOP's, hook up choke/kill line grey
locks Install riser and trip tank lines
0.0 0.0
10/18/2023
11:30
10/18/2023
13:30
2.00 MIRU, WHDBOP RURD P Grease HCR & Manual valves. R/U
testing equipment.
Obtain good shell test
0.0 0.0
Rig: NORDIC 3
RIG RELEASE DATE 10/21/2023
Page 2/4
1R-09
Report Printed: 11/9/2023
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/18/2023
13:30
10/18/2023
23:30
10.00 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE at
250/3500 PSI for 5 Min each, UVBR's,
LVBRs w/ 2 7/8" test joint. Test blinds
rams. Choke valves #1 to #12, upper
and lower top drive well control valves.
Test 3 1/2" IF FOSV and IBOP. Test 3
½ EUE FOSV. Test 2" rig floor Demco
kill valve MM #13. Test manual and
HCR kill valves. Test two ea 2 1/6" gate
auxiliary valves below LPR. Test gas
alarms. Witness waived by AOGCC rep
Sean Sullivan.
0.0 0.0
10/18/2023
23:30
10/19/2023
00:00
0.50 MIRU, WHDBOP BOPE T Initial BOPE test, Tested BOPE at
250/3500 PSI for 5 Min each, Tested
LVBRs W/3 1/2" test joint. Witness
waived by AOGCC rep Sean Sullivan.
0.0 0.0
10/19/2023
00:00
10/19/2023
01:00
1.00 MIRU, WHDBOP BOPE T Initial BOPE test, Tested BOPE at
250/3500 PSI for 5 Min each, Test
UVBR's W/ 3 1/2" test joint. Test
manual/HCR choke valves, Test
hydraulic and manual choke valves to
1500 PSI and demonstrate bleed off.
Test PVT G/L and flow paddle Witness
waived by AOGCC rep Sean Sullivan.
0.0 0.0
10/19/2023
01:00
10/19/2023
01:30
0.50 MIRU, WHDBOP RURD T Drain stack, rig down testing equipment 0.0 0.0
10/19/2023
01:30
10/19/2023
04:00
2.50 MIRU, WHDBOP RURD T PJSM, pull riser, pull flow nipple, remove
Dutch riser flange from top of annular
0.0 0.0
10/19/2023
04:00
10/19/2023
10:30
6.50 MIRU, WHDBOP RGRP T M/U 13 5/8" x 11" spool to top of
annular, break cap on top of annular and
remove
Change out annular element, reinstall
annular cap and remove 13 5/8" x 11"
spool
0.0 0.0
10/19/2023
10:30
10/19/2023
12:00
1.50 MIRU, WHDBOP RURD T Install Dutch riser flange on top of
annular, N/U flow nipple and install riser,
air up air boots, hook up trip tank line
0.0 0.0
10/19/2023
12:00
10/19/2023
13:30
1.50 MIRU, WHDBOP RURD T Install test joint, rig up testing
equipment, fill stack and lines with
water, purge air from system obtain
good shell test
0.0 0.0
10/19/2023
13:30
10/19/2023
15:00
1.50 MIRU, WHDBOP BOPE T Test annular with 2 7/8" and 3 1/2" test
joints to 250/3500 PSI 5 min each, Test
choke valve #13
Perform accumulator test. Initial
pressure=3000 PSI, after closure=1650
PSI, 200 PSI attained =19 sec, full
recovery attained =120 sec. UVBR's= 5
sec, LVBRs= 5 sec. Annular= 21 sec.
Simulated blinds= 5 sec. HCR choke &
kill= 1 sec each. 4 back up nitrogen
bottles average = 2000 PSI. Test gas
detectors Witness waived by AOGCC
rep Sean Sullivan.
0.0 0.0
10/19/2023
15:00
10/19/2023
16:00
1.00 MIRU, WHDBOP RURD P B/D, R/D testing equipment
Drain stack. Pull slip over blanking plug.
Pull ISA plug
0.0 0.0
10/19/2023
16:00
10/19/2023
16:30
0.50 MIRU, WHDBOP RURD P Rig up to pull 2 7/8" TBG, Make up
landing JT to hanger, set DN 10K
BOLDS
0.0 0.0
10/19/2023
16:30
10/19/2023
17:00
0.50 COMPZN, RPCOMP PULL P Pull hanger off seat, 80K up, Unlit seals
clear SBE 75K up after seals out
Pull hanger to floor F/7,312' T/7,286'
0.0 7,286.0
10/19/2023
17:00
10/19/2023
18:00
1.00 COMPZN, RPCOMP CIRC P CBU @ 5 BPM 700 PSI 7,286.0 7,286.0
Rig: NORDIC 3
RIG RELEASE DATE 10/21/2023
Page 3/4
1R-09
Report Printed: 11/9/2023
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/19/2023
18:00
10/19/2023
19:45
1.75 COMPZN, RPCOMP RURD P L/D landing JT and hanger, blow down
top drive, choke/kill lines
Change out elevators to 2 7/8", load 80-
32 seal assy in pipe shed
7,286.0 7,286.0
10/19/2023
19:45
10/20/2023
00:00
4.25 COMPZN, RPCOMP PULL P POOH L/D 2 7/8" TBG T/pipe shed
F/7,286' T/994'
Small pin holes in JTS # 95,92 and 89
as ran
7,286.0 994.0
10/20/2023
00:00
10/20/2023
01:15
1.25 COMPZN, RPCOMP PULL P POOH L/D 2 7/8" TBG T/pipe shed
F/994' T/surface
994.0 0.0
10/20/2023
01:15
10/20/2023
01:45
0.50 COMPZN, RPCOMP OTHR P Clean clear rig floor, kick out old
completion from shed, move spare joints
and jewelry for new completion to DS of
pipe shed
0.0 0.0
10/20/2023
01:45
10/20/2023
11:00
9.25 COMPZN, RPCOMP PUTB P PJSM run 2 7/8", 6.5 #, L-80, EUE-M
completion as per detail, change out
seal rings as needed. Run-n-seal dope
used. Torque T/ 1575 Ft/lbs T/ 7310',
wash seals into PBR @ 2 BPM, PSI
increase @7731', RIH fully locate
@7341', PUW=75K, SOW =65K.
0.0 7,341.0
10/20/2023
11:00
10/20/2023
12:30
1.50 COMPZN, RPCOMP HOSO P L/D joints # 231, 230 & 229. M/U space
out pups. M/U joint # 229. M/U hanger
and landing joint T/ 7308'
7,341.0 7,308.0
10/20/2023
12:30
10/20/2023
13:30
1.00 COMPZN, RPCOMP CRIH P Close UPR, reverse circ in 220 Bbls CI
seawater chased w/ 10 Bbls seawater
@ 4 BPM, 780 PSI. Open UPR.
7,308.0 7,308.0
10/20/2023
13:30
10/20/2023
13:45
0.25 COMPZN, RPCOMP PUTB P Suck out BOP stack. RIH & land hanger
w/ bottom of seals @ 7342' ORKB.
RILDS.
7,308.0 7,342.0
10/20/2023
13:45
10/20/2023
14:45
1.00 COMPZN, RPCOMP RURD P R/U testing equipment T/ TBG & IA. 7,342.0 7,342.0
10/20/2023
14:45
10/20/2023
15:00
0.25 COMPZN, RPCOMP SFTY P PJSM w/ rig crew on PT TBG & IA. 7,342.0 7,342.0
10/20/2023
15:00
10/20/2023
16:45
1.75 COMPZN, RPCOMP PRTS P PT TBG T/ 3500 PSI for 30 Min. Bleed
TBG T/ 2000 PSI. PT IA T/ 3000 PSI for
30 Min. Dump TBG pressure, shear
out SOV. Pump down IA @ 2 BPM, 665
PSI.
L/D landing joint
7,342.0 7,342.0
10/20/2023
16:45
10/20/2023
17:15
0.50 COMPZN, WHDBOP MPSP P Install BPV, test from below to 1000 PSI
F/10 Min
7,342.0 0.0
10/20/2023
17:15
10/20/2023
18:00
0.75 COMPZN, WHDBOP RURD P Blow down and rig down circulating lines 0.0 0.0
10/20/2023
18:00
10/20/2023
21:15
3.25 COMPZN, WHDBOP NUND P Pull riser, Disconnect trip tank hose, N/D
BOP and 7 1/16" x 13 5/8" DSA
0.0 0.0
10/20/2023
21:15
10/20/2023
22:45
1.50 COMPZN, WHDBOP NUND P Install test dart, N/U TBGhead adaptor,
test to 5,000 PSI F/10 min
0.0 0.0
10/20/2023
22:45
10/21/2023
00:00
1.25 COMPZN, WHDBOP NUND P N/U Tree, rig up circulating lines 0.0 0.0
10/21/2023
00:00
10/21/2023
00:45
0.75 COMPZN, WHDBOP RURD P Rig up circulating lines and LRS 0.0 0.0
10/21/2023
00:45
10/21/2023
01:30
0.75 COMPZN, WHDBOP PRTS P PJSM, Flood lines and test to 5000 PSI
Fluid pack tree and test to 5000 PSI
F/10 min
0.0 0.0
10/21/2023
01:30
10/21/2023
02:00
0.50 COMPZN, WHDBOP MPSP P Pull test dart and BPV 0.0 0.0
Rig: NORDIC 3
RIG RELEASE DATE 10/21/2023
Page 4/4
1R-09
Report Printed: 11/9/2023
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
10/21/2023
02:00
10/21/2023
03:30
1.50 COMPZN, WHDBOP FRZP P Freeze protect well
Pump 80 BBLS diesel with LRS at 3
BPM 700 PSI ICP, 3.25 BPM 1500 FCP
Shut down pump, shut in LRS and well,
blow down lines to outside
Open up well let diesel U tube
TBG= 125 PSI, IA = 110 PSI, OA = 0
PSI
0.0 0.0
10/21/2023
03:30
10/21/2023
12:00
8.50 DEMOB, MOVE RURD P B/D and R/D circulating lines. Secure
tree. Clean up in cellar and pad in prep
for move. Remove auxiliary equipment
from rig. Move office complex. Pull sub
off of well and clean up around well.
Rig released @12:00 Hrs
0.0 0.0
Rig: NORDIC 3
RIG RELEASE DATE 10/21/2023
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag: RKB 7,947.0 1R-09 10/31/2023 fergusp
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Replace SOV w/ DV. Pull catcher & plug. 1R-09 10/31/2023 fergusp
Casing Strings
Csg Des OD (in) ID (in) Top (ftKB)
Set Depth
(ftKB)
Set Depth
(TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread
CONDUCTOR 16 15.25 38.0 115.0 115.0 65.00 H-40 WELDED
SURFACE 9 5/8 8.92 37.0 4,039.4 3,792.3 36.00 J-55 BTC
PRODUCTION 7 6.28 35.5 8,210.4 6,741.1 26.00 J-55 BTC
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
34.5
Set Depth
7,342.0
Set Depth
6,113.6
String Max No
2 7/8
Tubing Description
Tubing Completion Upper
Wt (lb/ft)
6.50
Grade
L-80
Top Connection
EUE-M
ID (in)
2.44
Completion Details: excludes tubing, pup, space out, thread, RKB...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal
ID (in)
34.5 34.5 0.03 Hanger 6.990 3.5" x 7 1/16" FMC Tubing Hanger
Gen 4. Control Line Port: PLUGGED
FMC Gen 4 2.960
7,274.9 6,067.2 46.47 Mandrel - SOV 4.784 2 7/8" x 1" KBMG, GLM SLB KBMG 2.441
7,329.6 6,105.0 46.08 Locator 3.470 Baker locator sub Baker Locator 2.400
7,330.7 6,105.8 46.07 Seal Assembly 3.240 Baker GBH-22 80-32 seal assy - 2.0'
from fully located
Baker 80-32
Seal
Assembl
y
2.370
Top (ftKB)
7,332.9
Set Depth
7,607.2
Set Depth
6,301.5
String Max No
2 7/8
Tubing Description
Tubing Completion Lower
Wt (lb/ft)
6.50
Grade
L-80
Top Connection
EUE8RD
ID (in)
2.44
Completion Details: excludes tubing, pup, space out, thread, RKB...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal
ID (in)
7,332.9 6,107.3 46.05 PBR 5.860 BAKER PBR 3.250
7,348.3 6,118.0 45.94 PACKER 5.970 BAKER FH 47B2 PACKER 2.347
7,551.4 6,261.3 44.25 NIPPLE 3.668 CAMCO X PROFILE w/ 2.313" X
PROFILE
2.313
7,590.7 6,289.6 43.93 OVERSHOT 5.875 CAMCO OEJ SBR OVERSHOT 3.500
Top (ftKB)
7,599.8
Set Depth
7,689.3
Set Depth
6,360.7
String Max No
2 7/8
Tubing Description
TUBING Original
Wt (lb/ft)
6.50
Grade
J-55
Top Connection
EUE8RD
ID (in)
2.44
Completion Details: excludes tubing, pup, space out, thread, RKB...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal
ID (in)
7,599.8 6,296.1 43.85 SBR 3.000 SBR SHEARED @ WORKOVER 2.312
7,617.3 6,308.8 43.82 PACKER 6.140 CAMCO HRP-A-SP RETRIEVABLE
PACKER
2.297
7,656.0 6,336.7 43.77 NIPPLE 3.668 CAMCO D NO GO NIPPLE 2.250
7,688.6 6,360.2 43.72 SOS 3.750 CAMCO SHEAR OUT SUB 2.441
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top (ftKB)
Top (TVD)
(ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in)
7,986.0 6,576.3 42.90 FISH 1 1/2" DMY Empty Pocket; Fell
to Rathole
8/26/1985 0.000
Mandrel Inserts : excludes pulled inserts
Top (ftKB)
Top (TVD)
(ftKB)
Top
Incl (°)
St
ati
on
No
/S Serv
Valve
Type
Latch
Type
OD
(in)
TRO Run
(psi) Run Date Com Make Model
Port
Size (in)
7,274.9 6,067.2 46.47 1 GAS LIFT DMY BK 4.78
4
0.0 10/31/2023 SLB KBMG 0.000
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
7,728.0 7,768.0 6,388.7 6,417.7 C-1, UNIT B, 1R-
09
4/10/1989 4.0 APERF 2 1/8" EnerJet; 0 deg. ph; 17
shots of 80 failed to fire
7,896.0 7,904.0 6,510.6 6,516.4 A-4, 1R-09 8/4/1985 4.0 IPERF 4" HJ II Csg Gun; 90 deg. ph
7,912.0 7,944.0 6,522.3 6,545.6 A-3, 1R-09 8/4/1985 4.0 IPERF 4" HJ II Csg Gun; 90 deg. ph
7,975.0 7,980.0 6,568.3 6,571.9 A-2, 1R-09 8/4/1985 4.0 IPERF 4" HJ II Csg Gun; 90 deg. ph
1R-09, 11/1/2023 4:55:18 PM
Vertical schematic (actual)
PRODUCTION; 35.5-8,210.4
FISH; 7,986.0
IPERF; 7,975.0-7,980.0
IPERF; 7,912.0-7,944.0
IPERF; 7,896.0-7,904.0
APERF; 7,728.0-7,768.0
NIPPLE; 7,656.0
PACKER; 7,617.3
NIPPLE; 7,551.4
PACKER; 7,348.3
Seal Assembly; 7,330.7
Mandrel - SOV; 7,274.8
SURFACE; 37.0-4,039.4
CONDUCTOR; 38.0-115.0
Hanger; 34.5
KUP INJ
KB-Grd (ft)
37.20
RR Date
6/30/1985
Other Elev
1R-09
...
TD
Act Btm (ftKB)
8,225.0
Well Attributes
Field Name
KUPARUK RIVER UNIT
Wellbore API/UWI
500292135000
Wellbore Status
INJ
Max Angle & MD
Incl (°)
47.72
MD (ftKB)
7,000.00
WELLNAME WELLBORE1R-09
Annotation
Last WO:
End Date
11/30/2008
H2S (ppm) DateComment
SSSV: NIPPLE
CAUTION: This email originated from outside the State of Alaska mail system.
Do not click links or open attachments unless you recognize the sender and know
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Some people who received this message don't often get email from al.hansen@nordic-calista.com. Learn why this
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From:Brooks, Phoebe L (OGC)
To:Al Hansen
Cc:Regg, James B (OGC)
Subject:RE: KUP 1R-09 10-18-23 AOGCC
Date:Monday, November 27, 2023 4:12:30 PM
Attachments:Nordic 3 10-18-23 Revised.xlsx
Al,
Attached is a revised report changing the sundry # to reflect 323-442. Please update your copy or let
me know if you disagree.
Thank you,
Phoebe
Phoebe Brooks
Research Analyst
Alaska Oil and Gas Conservation Commission
Phone: 907-793-1242
CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the
Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended
recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or
disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail,
please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it
to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov.
From: Al Hansen <al.hansen@nordic-calista.com>
Sent: Friday, October 20, 2023 1:28 PM
To: Regg, James B (OGC) <jim.regg@alaska.gov>; Brooks, Phoebe L (OGC)
<phoebe.brooks@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>
Cc: Company Man, Nordic 3 <Nordic3.CompanyMan@conocophillips.com>
Subject: KUP 1R-09 10-18-23 AOGCC
Al Hansen
Rig Manager Rig 3
907-440-6928 Cell
.XSDUXN5LYHU8QLW5
37'
revised report sundry # to reflect 323-442
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
*All BOPE reports are due to the agency within 5 days of testing*
SSub m it to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov
Rig Owner: Rig No.:3 DATE: 10/18/23
Rig Rep.: Rig Email:
Operator:
Operator Rep.: Op. Rep Email:
Well Name:PTD #11850950 Sundry #323-442
Operation: Drilling: Workover: xxx Explor.:
Test: Initial: xxx Weekly: Bi-Weekly: Other:
Rams:250/3500 Annular:250/3500 Valves:250/3500 MASP:3022
MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES:
Test Result/Type Test Result Quantity Test Result
Housekeeping P Well Sign P Upper Kelly 1P
Permit On Location P Hazard Sec.P Lower Kelly 1P
Standing Order Posted P Misc.NA Ball Type 1P
Test Fluid Water Inside BOP 1P
FSV Misc 1P
BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm
Stripper NA Trip Tank PP
Annular Preventer 1 13 5/8"FP Pit Level Indicators PP
#1 Rams 1 2 7/8 x 5 1/2 P Flow Indicator PP
#2 Rams 1 CSO P Meth Gas Detector PP
#3 Rams 1 2 7/8 x 5 1/2 FP H2S Gas Detector PP
#4 Rams 0NAMS Misc 0NA
#5 Rams 0NA
#6 Rams 0NAACCUMULATOR SYSTEM:
Choke Ln. Valves 1 3 1/8"P Time/Pressure Test Result
HCR Valves 2 3 1/8"P System Pressure (psi)3000 P
Kill Line Valves 1 3 1/8"P Pressure After Closure (psi)1650 P
Check Valve 0NA200 psi Attained (sec)19 P
BOP Misc 2 2 1/16" 5000 P Full Pressure Attained (sec)120 P
Blind Switch Covers: All stations Yes
CHOKE MANIFOLD:Bottle Precharge:P
Quantity Test Result Nitgn. Bottles # & psi (Avg.): 4@ 2000 P
No. Valves 12 P ACC Misc 0NA
Manual Chokes 1P
Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result
CH Misc 1P Annular Preventer 21 P
#1 Rams 5 P
Coiled Tubing Only:#2 Rams 5 P
Inside Reel valves 0NA #3 Rams 5 P
#4 Rams 0 NA
Test Results #5 Rams 0 NA
#6 Rams 0 NA
Number of Failures:2 Test Time:25.5 HCR Choke 1 P
Repair or replacement of equipment will be made within days. HCR Kill 1 P
Remarks:
AOGCC Inspection
24 hr Notice Yes Date/Time 10-17-23 / 11:24
Waived By
Test Start Date/Time:10/18/2023 13:30
(date) (time)Witness
Test Finish Date/Time:10/19/2023 15:00
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Sully Sullivan
Nordic
Tested with 2 7/8" & 3 1/2" test joints Annular fail on 2 7/8" test joint change out annular element retest pass,LPR fail on 2 7/8"
test joint function rams retest pass.
Hansen / Twedt
CPAI
Barr / Pickworth
KRU 1R-09
Test Pressure (psi):
gmanager.rig3@nordic-calista.co
c3.Companyman@conocophillips
Form 10-424 (Revised 08/2022) 2023-1018_BOP_Nordic3_KRU_1R-09
9 9 9
9
9
9999
9
9
9
9
9
-5HJJ
1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown
Suspend Perforate Other Stimulate Pull Tubing Change Approved Program
Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing
2. Operator Name: 4.Current Well Class:5. Permit to Drill Number:
Exploratory Development
3. Address:Stratigraphic Service
6. API Number:
7. If perforating:8. Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool?N/A KRU 1R-09
Yes No
9. Property Designation (Lease Number): 10. Field:
Kuparuk Oil Pool Kuparuk Oil Pool
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD):
8225' 6752' 7655' 6336'3022 7655'
7986'
Casing Collapse
Conductor
Surface
Production
Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft):
12. Attachments: Proposal Summary Wellbore schematic 13. W ell Class after proposed work:
Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service
14. Estimated Date for 15. Well Status after proposed work:
Commencing Operations: OIL WINJ WDSPL Suspended
16. Verbal Approval: Date: GAS WAG GSTOR SPLUG
AOGCC Representative: GINJ Op Shutdown Abandoned
Contact Name:
Contact Email:
Contact Phone: 907-263-4597
Authorized Title:
Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number:
Plug Integrity BOP Test Mechanical Integrity Test Location Clearance
Other Conditions of Approval:
Post Initial Injection MIT Req'd? Yes No
APPROVED BY
Approved by: COMMISSIONER THE AOGCC Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
Kuparuk River Field
Shane Germann
shane.germann@conocophillips.com
CTD/RWO Engineer
Subsequent Form Required:
Suspension Expiration Date:
Will perfs require a spacing exception due to property boundaries?
Current Pools:
MPSP (psi): Plugs (MD):
17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval.
Authorized Name and
Digital Signature with Date:
Tubing Size:
PRESENT WELL CONDITION SUMMARY
AOGCC USE ONLY
Tubing Grade: Tubing MD (ft):
Packer: 7348'MD/6118'TVD
Packer: 7617'MD/6309'TVD
Perforation Depth TVD (ft):
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL0025635
185-095
P.O. Box 100360, Anchorage, AK 99510 50-02-92135-00-00
ConocoPhillips Alaska, Inc
Length Size
Proposed Pools:
L-80
J-55
TVD Burst
7607'
7689'
MD
115'
3792'
115'
4039'
6741'7"
16"
9-5/8"
67'
3991'
8210'
Perforation Depth MD (ft):
7728-7768'
7896-7904'
7912-7944'
7975-7980'
8162'
6389-6418'
6511-6516'
6522-6546'
6568-6572'
9/15/2023
2-7/8"
2-7/8"
Baker FH 47B2
CAMCO HRP-A-SP Retrievable
Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
By Grace Christianson at 8:38 am, Aug 04, 2023
323-442
Digitally signed by Shane Germann
DN: C=US, O=ConocoPhillips Alaska, CN=Shane
Germann, E=shane.germann@conocophillips.com
Reason: I have reviewed this document
Location:
Date: 2023.08.03 13:42:08-08'00'
Foxit PDF Editor Version: 12.1.2
MDG 8/23/2023 DSR-8/7/23VTL 9/15/2023
029-21350
X
X
BOP test to 3500 psig
Annular preventer test to 2500 psig
*&:
09/15/23
Brett W.
Huber, Sr.
Digitally signed by Brett
W. Huber, Sr.
Date: 2023.09.15 12:06:15
-08'00'
404
RBDMS JSB 091823
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
August 3, 2023
Commissioner
State of Alaska
Alaska Oil & Gas Conservation Commission
333 West 7th Avenue Suite 100
Anchorage, Alaska 99501
Dear Commissioner:
Shane Germann
Senior CTD/RWO Engineer
CPAI Drilling and Wells
ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Kuparuk Injector 1R-09
(PTD# 185-095).
Well 1R-09 was drilled and completed in August of 1985 as a water injector into the A-sands. The C-1 sands were
perforated in April 1989. The well was worked over in 2008 due to tubing leaks, and a new completion was ran with a
stacked packer. In 2020 the well failed an MIT-IA and was shut-in. A leak detect log revealed multiple tubing leaks in
the 2-7/8" completion.
If you have any questions or require any further information, please contact me at 406-670-1939.
In order to bring the well back online we request approval to proceed with a RWO to replace the tubing with new.
Digitally signed by Shane Germann
DN: C=US, O=ConocoPhillips Alaska,
CN=Shane Germann, E=shane.germann
@conocophillips.com
Reason: I have reviewed this document
Location:
Date: 2023.08.03 13:42:49-08'00'
Foxit PDF Editor Version: 12.1.2
1R-09 RWO Procedure
Kuparuk Injector
P&R Tubing
PTD #185-095
Page 1 of 3
Remaining Pre-Rig Work
1. T-PPPOT, T-POT, IC-PPPOT, and IC-POT tests.
2. Measure SBHP (Completed 4/26).
3. Set CA-2 plug in nipple at 7656’ RKB (Completed 4/26).
4. Perform CMIT-TxIA to 2500 psi (Completed 4/26) and CDDT.
5. Open lowest GLM in upper completion for circulation point.
6. Prepare well within 48-96 hrs of rig arrival. Confirm no gas in OA,IA, or tubing.
Rig Work
MIRU
1. MIRU Nordic 3 on 1R-09.
2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete
30-minute NFT. Verify well is dead. Circulate KWF as needed.
3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/3,500 psi. Test annular 250/3,500
psi.
Retrieve Tubing
4. Pull BPV, MU landing joint and BOLDS.
5. Pull 2-7/8” tubing down to seal assembly (~7332’ RKB).
Install New Tubing
6. MU 2-7/8” completion with seal assembly, nipples, and GLM’s. RIH to PBR.
a. Contingency plan if unable to pull from seals is to cut tubing and stack a packer. Packer would be
greater than 200’ MD from top of perforations, but below TOC of 7” casing estimated from cement
evaluation log from 7/17/1985.
b. May upsize new tubing string to 3-1/2” depending on equipment availability.
7. Once on depth, stab seals into PBR and space out as needed.
8. Pressure test tubing to 3000 psi for 30 minutes.
9. Pressure test inner annulus to 2500 psi for 30 minutes on chart.
ND BOP, NU Tree
10. Confirm pressure tests, then shear out SOV with pressure differential.
11. Install BPV.
12. ND BOPE. NU tree.
13. Pull BPV and freeze protect well.
14. RDMO.
Post-Rig Work
15. Remove SOV, install dummy valve.
1R-09 RWO Procedure
Kuparuk Injector
P&R Tubing
PTD #185-095
Page 2 of 3
General Well info:
Wellhead type/pressure rating: FMC Gen III, 5M psi top flange x 3M bottom flange
Production Engineer: Adam Becia
Reservoir Development Engineer: Jennifer McLeod
Estimated Start Date: 9/15/2023
Workover Engineer: Shane Germann (406-670-1939/ shane.germann@conocophillips.com)
Current Operations: This well is currently shut in.
Well Type: Injector
Scope of Work: Pull the existing 2-7/8” completion from seals at 7332’ RKB, install a new 2-7/8” completion
stabbing back into seals. If unable to pull from seals, plan is to stack packer above existing.
BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Ram / DSA (as needed)
1R-09 RWO Procedure
Kuparuk Injector
P&R Tubing
PTD #185-095
Page 3 of 3
Following subject to change/be updated with pre-rig work:
MIT results:
CMIT-TxIA Passed 4/26/2023
MIT-OA N/A
IC POT &PPPOT – TBD
TBG POT &PPPOT – TBD
MPSP: 3022 psi using 0.1 psi/ft gradient
Static BHP: 3652 psi / 6300’ TVD measured on 04/26/2023
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag: RKB 7,952.0 1R-09 4/25/2023 rogerba
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev reason: Pulled and set plug, SBHP, update tag 1R-09 4/26/2023 rogerba
Casing Strings
Csg Des OD (in) ID (in) Top (ftKB)
Set Depth
(ftKB)
Set Depth
(TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread
CONDUCTOR 16 15.25 38.0 115.0 115.0 65.00 H-40 WELDED
SURFACE 9 5/8 8.92 37.0 4,039.4 3,792.3 36.00 J-55 BTC
PRODUCTION 7 6.28 35.5 8,210.4 6,741.1 26.00 J-55 BTC
Tubing Strings: string max indicates LONGEST segment of string
Top (ftKB)
34.5
Set Depth …
7,607.2
Set Depth …
6,301.5
String Ma…
2 7/8
Tubing Description
TUBING WO
Wt (lb/ft)
6.50
Grade
L-80
Top Connection
EUE8RD
ID (in)
2.44
Completion Details: excludes tubing, pup, space out, thread, RKB...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal
ID (in)
34.5 34.5 0.03 HANGER 6.000 FMC 5M TUBING HANGER 2.875
494.1 494.1 0.09 NIPPLE 3.680 CAMCO DS NIPPLE NO GO 2.312
7,330.3 6,105.5 46.07 SEAL ASSY 3.460 BAKER LOCATOR SEAL
ASSEMBLY
3.000
7,332.9 6,107.3 46.05 PBR 5.860 BAKER PBR 3.250
7,348.3 6,118.0 45.94 PACKER 5.970 BAKER FH 47B2 PACKER 2.347
7,551.4 6,261.3 44.25 NIPPLE 3.668 CAMCO X PROFILE w/ 2.313" X
PROFILE
2.313
7,590.7 6,289.6 43.93 OVERSHOT 5.875 CAMCO OEJ SBR OVERSHOT 3.500
Top (ftKB)
7,599.8
Set Depth …
7,689.3
Set Depth …
6,360.7
String Ma…
2 7/8
Tubing Description
TUBING Original
Wt (lb/ft)
6.50
Grade
J-55
Top Connection
EUE8RD
ID (in)
2.44
Completion Details: excludes tubing, pup, space out, thread, RKB...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal
ID (in)
7,599.8 6,296.1 43.85 SBR 3.000 SBR SHEARED @ WORKOVER 2.312
7,617.3 6,308.8 43.82 PACKER 6.140 CAMCO HRP-A-SP RETRIEVABLE
PACKER
2.297
7,656.0 6,336.7 43.77 NIPPLE 3.668 CAMCO D NO GO NIPPLE 2.250
7,688.6 6,360.2 43.72 SOS 3.750 CAMCO SHEAR OUT SUB 2.441
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top (ftKB)
Top (TVD)
(ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in)
2,424.0 2,421.5 11.82 TUBING
LEAK
TUBING LEAK, IDENTIFIED
KNOWN LEAK AT 2424' RKB,
COMBINED LLR AT 0.75
BPM, 2100 PSI
4/5/2020 2.440
3,580.0 3,447.4 37.85 TUBING
LEAK
TUBING LEAK IDENTIFIED
AT 3580' RKB, COMBINED
LR AT 0.75 BPM, 2100 PSI
4/5/2020 2.440
7,655.3 6,336.2 43.77 PLUG Set CA-2 Plug OAL 27.5" 4/26/2023 0.000
7,986.0 6,576.3 42.90 FISH 1 1/2" DMY Empty Pocket; Fell
to Rathole
8/26/1985 0.000
Mandrel Inserts : excludes pulled inserts
Top (ftKB)
Top (TVD)
(ftKB)
Top
Incl (°)
St
ati
on
No
/S Serv
Valve
Type
Latch
Type
OD
(in)
TRO Run
(psi) Run Date Com Make Model
Port
Size (in)
7,274.8 6,067.1 46.47 1 INJ DMY BK 1 0.0 6/26/2018 0.000
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
7,728.0 7,768.0 6,388.7 6,417.7 C-1, UNIT B, 1R-
09
4/10/1989 4.0 APERF 2 1/8" EnerJet; 0 deg. ph; 17
shots of 80 failed to fire
7,896.0 7,904.0 6,510.6 6,516.4 A-4, 1R-09 8/4/1985 4.0 IPERF 4" HJ II Csg Gun; 90 deg. ph
7,912.0 7,944.0 6,522.3 6,545.6 A-3, 1R-09 8/4/1985 4.0 IPERF 4" HJ II Csg Gun; 90 deg. ph
7,975.0 7,980.0 6,568.3 6,571.9 A-2, 1R-09 8/4/1985 4.0 IPERF 4" HJ II Csg Gun; 90 deg. ph
1R-09, 4/27/2023 9:43:58 AM
Vertical schematic (actual)
PRODUCTION; 35.5-8,210.4
FLOAT SHOE; 8,208.7-8,210.4
FLOAT COLLAR; 8,120.0-
8,121.5
FISH; 7,986.0
IPERF; 7,975.0-7,980.0
IPERF; 7,912.0-7,944.0
IPERF; 7,896.0-7,904.0
APERF; 7,728.0-7,768.0
SOS; 7,688.6
NIPPLE; 7,656.0
PLUG; 7,655.3
PACKER; 7,617.3
SBR; 7,599.8
OVERSHOT; 7,590.7
NIPPLE; 7,551.4
PACKER; 7,348.3
PBR; 7,332.9
SEAL ASSY; 7,330.3
INJECTION; 7,274.8
SURFACE; 37.0-4,039.4
FLOAT SHOE; 4,037.7-4,039.4
FLOAT COLLAR; 3,949.0-
3,950.7
TUBING LEAK; 3,580.0
TUBING LEAK; 2,424.0
NIPPLE; 494.1
CONDUCTOR; 38.0-115.0
HANGER; 37.0-41.4
HANGER; 34.5
KUP INJ
KB-Grd (ft)
37.20
RR Date
6/30/1985
Other Elev…
1R-09
...
TD
Act Btm (ftKB)
8,225.0
Well Attributes
Field Name
KUPARUK RIVER UNIT
Wellbore API/UWI
500292135000
Wellbore Status
INJ
Max Angle & MD
Incl (°)
47.72
MD (ftKB)
7,000.00
WELLNAME WELLBORE1R-09
Annotation
Last WO:
End Date
11/30/2008
H2S (ppm) DateComment
SSSV: NIPPLE
1R-09 Proposed RWO Completion
COMPLETION
INFO
MD
(ft RKB)
TVD
(ft RKB)
OD
(in)
Nom. ID
(in)
Weight
(lb/ft)Grade Thread
(top)
Thread
(btm)
Conductor 115 115 16 15.25 65 H-40 Welded
Surface 4039 3792 9.625 8.92 36 J-55 BTC
Production/
Intermediate 8210 6741 7 6.28 26 J-55 BTC
Tubing 7688 6360 2.875 2.441 6.5 J-55 EUE8rd
PROPOSED COMPLETION
2-7/8" X nipple @ TBD (2.313" ID)
2-7/8" 6.5# L-80 EUE 8rd Tubing to surface
2-7/8" GLM @ TBD
2-7/8" Seal Assembly
REMAINING COMPLETION LEFT IN HOLE
Baker PBR @ 7332' RKB (3.25" ID)
Baker FH Packer @ 7348' RKB (2.347" ID)
Camco X Nipple @ 7551' RKB (2.313" ID)
2-7/8" Poorboy Overshot @ 7590' RKB
Camco OEJ @ 7600' RKB
Camco HRP-A-SP Retrievable Packer @ 7617' RKB
(2.297" ID)
Surface Casing
Production/Intermediate
Casing
Conductor
A-sand perfs
7896' - 7980' RKB
C-sand perfs
7728' - 7768' RKB
https://readcasedhole-my.sharepoint.com/personal/diane_williams_readcasedhole_com/Documents/D
Drive/Achives/MasterTemplateFiles/Templates/Distribution/TransmittalSheets/ConocoPhillips_Transmit.docx
Well Log Transmittal
To: AOGCC
Natural Resources Technician
333 West 7th Avenue
Suite 100
Anchorage, Alaska 99501
RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT)
The technical data listed below is being submitted herewith. Please acknowledge receipt by
returning a signed copy of this transmittal letter to the attention of :
READ Cased Hole, Inc.
Attn: Diane Williams
4141 B Street
Suite 308
Anchorage, AK 99503
Diane.Williams@readcasedhole.com
1) Caliper Report 06-Apr-20 1R-09 1 Report / CD 50-029-21350-00
2)
Signed : ______________________________________ Date : ___________________
Print Name: ______________________________________
READ CASED HOLE, INC, 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503
PHONE: (907)245-8951
E-MAIL : READ-ANCHORAGE@READCASEDHOLE.COM WEBSITE : WWW.READCASEDHOLE.COM
Abby Bell 04/22/2020
Abby Bell
Received by the AOGCC on 04/22/2020
PTD: 1850950
E-Set: 32775
Wallace, Chris D (CED)
From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com>
Sent: Friday, March 20, 2020 6:39 PM
To: Wallace, Chris D (CED)
Cc: CPA Wells Supt; Well Integrity Compliance Specialist CPF1 & 2
Subject: RE: KRU 1 R-09 (PTD 185-095) Report of high IA pressure
Attachments: 1 R-09 90 Day TIO plot.PNG
Chris,
KRU injector 1R-09 (PTD 185-095) failed the diagnostics MIT -IA today. The well was shut in and the TIOs have stabilized
around 1775/1800/20 psi. As previously communicated diagnostics will continue and the proper paperwork for
continued injection or repair will be submitted as required. Attached is the current 90 day TIO trend. Please let me
know if you have any questions or disagree with the plan.
Dusty Freeborn/Jan Byrne
Wells Integrity & Compliance Specialist
ConocoPhillips Alaska, Inc.
Office phone: (907) 659-7224
Cell phone: (907) 830-9777
WELLS TEAM
Canoca`p+IDips
From:N7 I Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com>
Sent: Wedn sday, March 18, 2020 5:29 PM
To: Wallace, ChN D (CED) <chris.waIlace@alaska.gov>
Cc: CPA Wells Supt 1030@conocophillips.com>; Well Integrity Compliance Specialist CPF1 & 2
<n1617C@conocoohilliD . om>
Subject: KRU 1R-09 (PTD 1-095) Report of high IA pressure
Chris,
KRU injector 1R-09 (PTD 185-095) was relobded by operations with the IA pressure at 2500 psi. The operator
attempted to bleed the IA pressure, but the I -pressurized quickly. The well will be shut in and freeze protected as
soon as reasonably possible. CPAI intends to perfbrsn diagnostics to determine the failure mechanism. At the
completion of diagnostics, CPAI will submit proper
a 90 -day TIO plot and a wellbore schematic.
Please let me know if you disagree with this plan.
Regards,
Paul Duffy
for Jan Byrne/Dusty Freeborn
Wells Integrity & Compliance Specialist
ConocoPhillips Alaska, Inc.
Office phone: (907) 659-7224
for continued injection or repair as required. Attached is
Wallace, Chris D (CED)
From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophil1ips.com>
Sent: Wednesday, March 18, 2020 5:29 PM
To: Wallace, Chris D (CED)
Cc: CPA Wells Supt; Well Integrity Compliance Specialist CPF1 & 2
Subject: KRU 111-09 (PTD 185-095) Report of high IA pressure
Attachments: 1 R-09.pdf; 1 R-09 90day TIO plot 3-18-20.pdf
Chris,
KRU injector 111-09 (PTD 185-095) was reported by operations with the IA pressure at 2500 psi. The operator
attempted to bleed the IA pressure, but the IA re -pressurized quickly. The well will be shut in and freeze protected as
soon as reasonably possible. CPA] intends to perform diagnostics to determine the failure mechanism. At the
completion of diagnostics, CPAI will submit proper paperwork for continued injection or repair as required. Attached is
a 90 -day TIO plot and a wellbore schematic.
Please let me know if you disagree with this plan.
Rega rds,
Paul Duffy
for Jan Byrne/Dusty Freeborn
Wells Integrity & Compliance Specialist
ConocoPhillips Alaska, Inc.
Office phone: (907) 659-7224
WELLS owo' TEAM
4xwccHgips
MEMORANDUM
State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Jim Regg �Kj S /G
P.I. Supervisor {{
DATE: Monday, May 20, 2019
SUBJECT: Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA, INC.
IR -09
FROM: Adam Earl
KUPARUK RIV UNIT IR -09
Petroleum Inspector
Sre: Inspector
Reviewed By:
P.I. Suprv.�
NON -CONFIDENTIAL
Comm
Well Name KUPARUK RIV UNIT IR -09
Insp Num: mitAGE190510090114
Rel Insp Num:
API Well Number 50-029-21350-00-00 Inspector Name: Adam Earl
Permit Number: 185-095-0 Inspection Date: 5/8/2019 �
Packer Depth
Well - IR -09 " Type Inj W, TVD 6117
PTD 1850950 - Type Test sPr Test psi 1529
BBL Pumped: -i BBL Returned: I
Interval - 4vRTSI Ip/F P
Notes: MIT IA -
Pretest Initial 15 Min 30 Min 45 Min 60 Min
Tubing '400 '� 2420 2400 2400
IA 670 186060 11825 - 1810 --
OA 440 560 560 560
Monday, May 20, 2019 Page I of I
OF TjJ� •
4.04 I ��,4. THE STATE Alaska Oil and Gas
of T c�`T e Conservation Commission
- ALAV �1
`• t itt _;= _ 333 West Seventh Avenue
I GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572
0 ITh, Main: 907.279.1433
ALAS Fax: 907.276.7542
www.aogcc.alaska.gov
Kelly Lyons
Well Integrity Supervisor SCANNED
ConocoPhillips Alaska, Inc.
PO Box 100360
Anchorage, AK 99510
Re: Kuparuk River Field,Kuparuk River Oil Pool, KRU 1R-09
Permit to Drill Number: 185-095
Sundry Number: 318-187
Dear Mr. Lyons:
Enclosed is the approved application for sundry approval relating to the above referenced well.
Please note the conditions of approval set out in the enclosed form.
As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further
time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC
an application for reconsideration. A request for reconsideration is considered timely if it is
received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if
the 23rd day falls on a holiday or weekend.
Sincerely,
Hollis S. French
Chair
DATED this day of May, 2018.
RE
IDM
08251
•
RECEIVED
• • a
STATE OF ALASKA MAY 0 3 01
ALASKA OIL AND GAS CONSERVATION COMMISSION ( TS 5 �3 /cF'
APPLICATION FOR SUNDRY APPROVALS G C
20 AAC 25.280
1.Type of Request Abandon LI Plug Perforations U Fracture Stimulate LI Repair Well U Operations shutdown U
Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑
Plug for Redrill El Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ tbg patch Other: Q
2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number:
ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑ ' 185-095 •
3.Address: Stratigraphic ❑ Service Q " 6.API Number:
P. 0. Box 100360,Anchorage,Alaska 99510 500292135000 •
7.If perforating: 8.Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool? N/A
•
Will planned perforations require a spacing exception? Yes ❑ No ElKRU 1R-09
9.Property Designation(Lease Number): 10.Field/Pool(s):
ADL 25635' Kuparuk River Field/Kuparuk River Oil Pool
11. PRESENT WELL CONDITION SUMMARY
Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD):
8,225' - 6,752' " 7951 6551 3000 7656' N/A
Casing Length Size MD TVD Burst Collapse
Structural
Conductor 77' 16" 115' 115'
Surface 4,002' 9-5/8" 4,039' 3,792'
Intermediate
Production 8,175' 7" 8,210' 6,741'
Liner
Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft):
7728'-7768',7896-7980' 6389'-6418',6511'-6572' 2.875" J-55 7,689'
Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft):
NO SSSV PACKER-CAMCO DS NIPPLE MD=494 TVD=494
BAKER FH 4762 PACKER. MD=7348 TVD=6118
PACKER-CAMCO HRP-A-SP RETRIEVABLE PACKER MD=7617 TVD=6309
12.Attachments: Proposal Summary ❑ Wellbore schematic ❑ 13.Well Class after proposed work:
Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service E •
14.Estimated Date for 5/9/2018 15.Well Status after proposed work:
Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑
16.Verbal Approval: Date: GAS ❑ WAG 0 • GSTOR ❑ SPLUG
Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned
17. I hereby certify that the foregoing is true and the procedure approved herein will not
be deviated from without prior written approval.
Authorized Name: Kelly Lyons Contact Name: Kelly Lyons/Jan Byrne
Authorized Title: e tegrity Supervi Contact Email: N1617@conocophillips.com
Contact Phone: 907-659-7224
Authorized Signature: Date:4-27-18
COMMISSION USE ONLY
Conditions of approval: Notify Commission so that a representative may witness Sundry Number:
312- IP
Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test tr. Location Clearance ❑
Other:
RBOM-\ MAY gat
Initial Injection MIT Req'd? Yes o ❑
Spacing Exception Required? Yes ❑ No J. Subsequent Form Required: / 0 4-(2 4-
�l APPROVED BY
Approved by: �.. COMMISSIONER THE COMMISSION Date: S 3 i 6
,..,,
(� p� r�Tt- 5/3/!8 ..4f/ ,-,-... 5:
C�� \W Submit Form an
(�Jf� M7 Form 10-403 Revised 4/2017 Approved application is li fRln(Jhl 1I t�d t2 of approval. Attachments in Duplicate
. • •
IIIIIV • •
ConocoPh i l ps
Alaska
P.O. BOX 100360
ANCHORAGE,ALASKA 99510-0360
April 27, 2018
1 Mr. Hollis French
Alaska Oil & Gas Commission
333 West 7th Avenue, Suite 100
Anchorage,AK 99501
Dear Commissioner French,
Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips
Alaska, Inc. Kuparuk River Unit well 1R-09 (PTD 185-095). The request is for approval
to patch a tubing leak above the top packer.
Please call Jan Byrne or myself at 659-7224 if you have any questions.
Sincerely,
/ . ........___________
Kelly Lyons
Well Integrity Supervisor
Attachments
• •
ConocoPhillips Alaska,Inc.
Kuparuk Well 1R-09 (PTD 185-095)
SUNDRY NOTICE 10-403 TUBING REPAIR
04/27/18
This Sundry is a request for approval to repair ConocoPhillips (CPA)Kuparuk Well 1R-09 (PTD
185-095)with a retrievable tubing patch. On November 4, 2016, the AOGCC was initially
notified of suspected TxIA communication. Diagnostics have identified a tubing to IA leak at
2424'. The plan is to set a retrievable patch across the leak point, conduct an MITIA, and return
the well to normal WAG injection.
REPAIR PLAN
1. Set 30' 2-7/8"TTS retrievable tbg patch over the leak at 2424'.
2. MIT as per AOGCC requirements (0.25 x TVD to packer).
3. Submit 10-404 post-repair.
KUP INJ • IR-09
- ConocoPhillips - . Well Attributes Max Angle&MD TD
Alaska,Inc. R Wellbore APuuwl Field Name Wellbore Status ncl C) MD(ftKB) Act Btm(ftKB)
cv,,,,,,aps 500292135000 KUPARUK RIVER UNIT INJ 47.72 7,000.00 8,225.0
--- Comment 92S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date
1R-09,11/920167:01:05 PM SSSV:NIPPLE Last WO: 11/30/2008 37.20 6/30/1985
Vertical schematic(actua0
Annotation Depth(ftKB) End Date Annotation Last Mod By End Date
Last Tag:SLM 7,951.0 12/12/2012 Rev Reason:SET CA-2 PLUG pproven 11/9/2016
•'•i
` Casing Strings
HANGER;34.5
en
SURFACE sngDes p (i 9 5/8 (i 8 921 Top(6K)37.0 Set Depthp (ftKB)
Set DepthpXD(...WVLen(DO Grade Top Thread
H-40 WELDED
3
3
Cas nD Description DO m)1610 15.250rTo (ftKB)
Set Depth 115.0
Set Depth NDS.o Wt/Len(01.o Grade Top Thread
J-55 BTC
1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...,Grade Top Thread
I PRODUCTION 7 6.276 35.5 8,210.4 6,741.1 26.00 J-55 BTC
L Tubing Strings
Tubing Description String Ma...ID lin) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ibttt) Grade Top Connection I
TUBING WO 2 7/8 2.441 34.5 7,607.2 6,301.5 6.50 L-80 EUEBRD
-
Completion Details
Nominal ID
Top(ftKB) Top(ND)(ftKB) Top Incl(`) Item Des Com (in)
./... 34.5 34.5 0.03 HANGER FMC 5M TUBING HANGER 2.875
CONDUCTOR;30.0-1180 494.1 494.1 0.09 NIPPLE CAMCO DS NIPPLE NO GO 2.312
� 7,330.3 6,105.5 46.07 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 3.000
3
NIPPLE:494.1 7,332.9 6,107.3 46.05 PBR BAKER PBR 3.250
7,348.3 6,118.0 45.94 PACKER BAKER FH 47B2 PACKER 2.347
I 7,551.4 6,261.3 44.25 NIPPLE CAMCO X PROFILE wl2.313"X PROFILE 2.313
7,590.7 6,289.6 43.93 OVERSHOT CAMCO 0E.)SBR OVERSHOT 3.500
Tubing Description 'String Ma...I ID(in) Top(ftKB) Set Depth(ft..1 Set Depth('NO)(...IWt(Ib/ft) (Grade (Top Connection
TUBING Original 27/8 2.441 7,599.8 7,689.3( 6,360.7 6.50 J-55 EUEBRD
SURFACE;37.0-4.039.4-< I' Completion Details
Nominal 10
Top(ftKB) Top(TVD)(ftKB) Top Inel(') Item Des Corn (in)
7,599.8 6,296.1 43.85 SBR SBR SHEARED(d)WORKOVER 2.312
INJECTION;7,274.8 7,617.3 6,308.8 43.82 PACKER CAMCO HRP-A-SP RETRIEVABLE PACKER 2297
7,656.0 6,336,7 43.77 NIPPLE CAMCO D NO GO NIPPLE 2.250
7,688.6 6,360.2 43.72 SOS CAMCO SHEAR OUT SUB 2.441
Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.)
Top(TVD) Top Incl
Top(ftKB) (ftKB) (-) Des Com Run Date 1 ID(in)
SEAL ASSY;7,330.3 7,656.0 6,336.7 43.77 CA-2 PLUG 2.25"CA-2 PLUG 11/4/2016 0.000
PBR;7,3329 7,986.0 6,576.3 42.90 FISH 1 1/2"DMY Empty Pocket;Fell to Rathole 8/26/1985 0.000
I I
II Perforations&Slots
Shot
PACKER;7,348.3 ' ' Dens
" �• Top(ND) Btm(ND) (shots/f
Top(ttKO) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com
7,728.0 7,768.0 6,388.7 6,417.7 C-1,UNIT B, 4/10/1989 4.0 APERF 2 1/8"EnerJet;0 deg.
1R-09 ph;17 shots of 80 failed
to tire
NIPPLE;7,551.4 7,896.0 7,904.0 6,510.6 6,516.4 A-4,1R-09 8/4/1985 4.0 IPERF 4"HJ II Csg Gun;90
deg.ph
7,912.0 7,944.0 6,522.3 6,545.6 A-3,1R-09 8!4/1985 4.0 (PERF 4"HJ II Csg Gun;90
deg.ph
! 7,975.0- 7,980.0 6,568.3 6,571.9 A-2,1R-09 8/4/1985 4.0 (PERF 4"HJ 11 Cog Gun;90
OVERSHOT;7,590.7 f$ ' deg.ph
Mandrel Inserts
•
SBR;7,599.8 '(M' st
ati
PACKER;7,617.3 •L" on Top(ND) Valve Latch Port Size TRO Run
N Top(ftKB) (ftKB) Make Mode) OD(In) Sery Type Type (in) (psi) Run Date Corn
1 7,274.8 6,067.1 CAMCO KBG-2- - 1 INJ DMY BK 0.000 0.0 11/30/2008
08-1
Notes:General&Safety
NIPPLE;7,656.0-. End Date Annotation
CA-2 PLUG;7,656.0 11/29/2010 NOTE:View Schematic w/Alaska Schematic9.0
1
SOS;7,688.6 li
APERF;7,728.0.7,768.0 I
I I
I I
(PERF;7,896.0-7,904.0 I
I
(PERF;7,912.0-7,944.0- I
I
IPERF;7,975.0.7,980.0 I I '
FISH;7,986.0
10
PRODUCTION;35.5-8,210.4
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• •
Wallace, Chris D (DOA)
From: NSK Problem Well Supv <n1617@conocophillips.com>
Sent: Friday, November 04, 2016 8:54 AM
To: Wallace, Chris D (DOA)
Cc: Senden, R. Tyler
Subject: KRU WAG injector 1R-09 (PTD 185-095) Report of IA pressure spike 11-4-16
Attachments: 1R-09 90 day TIO 11-4-16.PNG; 1R-09 schematic.pdf
Chris,
KRU WAG injector 1R-09 (PTD 185-095) experienced an IA pressure spike yesterday afternoon, "equalizing with the
wellhead pressure at 2700psi. Multiple attempts to bleed the pressure off were unsuccessful. Therefore the well was
shut in and freeze protected yesterday. It had been online water injection since July 2016. We plan to obtain an MITIA
and packoff testing today using DHD and then mobilize a slickline unit as soon as possible to secure the well with a
tubing plug to hopefully knock the pressure off and set up for leak detection. The well is completed with J-55 26#7"
production casing which has a burst rating of 4980psi. 2700psi represents 54%of burst pressure. We will update you
with results at the conclusion at the testing and submit the proper paperwork as appropriate. Please let me know if you
disagree with the plan.
Attached are the 90 day TIO plot and schematic.
Kelly Lyons/ Brent Rogers
Problem Wells Supervisor
ConocoPhillips Alaska, Inc.
Desk Phone (907) 659-7224 SCANNED MAY 2 6201Z
Mobile Phone (907) 943-0170
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know
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Jim Regg / DATE: Wednesday,May 13,2015
P.I.Supervisor '1�� �'64lts SUBJECT: Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA INC
1R-09
FROM: Lou Grimaldi KUPARUK RIV UNIT IR-09
Petroleum Inspector
Src: Inspector
Reviewed By:
P.I.Supry ;
NON-CONFIDENTIAL Comm
Well Name KUPARUK RIV UNIT 1R-09 API Well Number 50-029-21350-00-00 Inspector Name: Lou Grimaldi
Permit Number: 185-095-0 Inspection Date: 5/8/2015
Insp Num: mitLG150508171402
Rel Insp Num:
Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min
-__
Well 1R-09 V
'Type Inj W ]TD_... I 6117 Tubing 2225 - 2225 • 2240 - 2240 .
4 •—
PTD 1850950 'Type Testi SPT'Test psi' 1529 - IA 200 3000 2920 - 2895
Interval I4YRTST P/F P OA 70 265- 270 - 275
Notes: 2.6 bbl's diesel pumped,2.8 bbl's returned.Good test.All required paperwork supplied prior to test. -
tcri-
1) (wre -weiL l5cl 1
SCANNED JUL 1 0 2015
Wednesday,May 13,2015 Page 1 of 1
•
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KUP 1R-09
" ConocoPhillips Well Attributes Max Angle&MD TD
A61tihd.IIA;. Wellbore API/UWI Field Nana Well Status Incl(") MD(NKMtn Act n(ftKB)
L.o0n00Nu9,ps 500292135000 KUPARUK RIVER UNIT INJ 47.72 7,000.00 8,225.0
Canm.M H2S(ppm) Dab Annotation End Dab KB-Ord(N) Rig Release Dab
••• WallCarlfip -10-09,524/20139:95:50AM SSSV:NIPPLE Last WO: 11/30/2008 37.20 6/30/1985
Sch 0.00-Actual Annotation Depth(NKR) End Date Annotation Last Mod...End Dab
Last Tag:SLM 7,951.0 12/122012 Rev Reason:WELL REVIEW osborl 5/24/2013
Casing Strings
Casing Description String 0... String ID...Top(ftKB) S.t Depth(f...8.1 Depth(TVD)...String WL..String...String Top Thrd
1 lir
RANGER,3s4,,f CONDUCTOR 16 15.250 38.0 115.0 115.0 65.00 H-40 WELDED
_ Casing Description String 0... String ID...Top(ftKB) S.t Depth(f...Set Depth(TVD)...String WL..String...String Top Thrd
SURFACE 95/8 8.921 37.0 4,039.4 3,792.1 36.00 J-55 BTC
Casing Description String 0... Shinn .ng ID.. Top(11KB) -Set Depth(f...Set Depth(TVD)...String WL..String...String Top mrd
PRODUCTION 7 6.276 35.5 8,210.4 6,741.1 26.00 J-55 BTC
Tubing Strings
Tubing Description string 0... String ID...Top(ftKB) Sot Depth(f...Sat Depth(TVD)...String Wt...String...string Top mrd
TUBING WO 2 7/8 2.441 34.5 7,607.2 6,301.6 6.50 L-80 EUE8RD
Completion Details
Top Depth(TVD) Top Incl Bond...
Top(ftKB) (MB) r) Item Description Comm.M ID tin)
34.5 34.5 0.05 HANGER FMC 5M TUBING HANGER 2.875
494.1 494.1 0.08 NIPPLE CAMCO DS NIPPLE NO GO 2.312
CONDUCTOR,
-115 7,330.3 6,105.5 46.07 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 3.000
`■ 7,332.9 6,107.3 46.05 PBR BAKER PBR 3.250
NIPPLE,494 L-- 7,348.3 6,118.1 45.94 PACKER BAKER FH 4762 PACKER 2.347
p 7,551.4 6,261.4 44.25 NIPPLE CAMCO X PROFILE w/2.313"X PROFILE 2.313
I 7,590.7 6,289.6 43.93 OVERSHOT CAMCO OEJ SBR OVERSHOT 3.500
Tubing Description String 0... String ID...Top(ftKB) Set Depth If...Set Depth(TVD)...String WL..String...String Top Thrd
TUBING Original 2 7/8 2.441 7,599.8 7,689.3 6,360.7 6.50 J-55 EUE8RD
Completion Details
SURFACE, � Top Depth
37-4,039 (TVD) Top Intl Nond...
Top(ftKB) (NKB) CI Item De.oriplion Comment ID(in)
7,599.8 6,296.1 43.85 SBR SBR SHEARED @ WORKOVER 2.312
-- � 7,617.3 6,308.8 43.84 PACKER CAMCO HRP-A-SP RETRIEVABLE PACKER 2.297
INJECTION,
71275 7,656.0 6,336.7 43.77 NIPPLE CAMCO D NO GO NIPPLE 2.250
7,688.6 6,360.2 43.72 SOS CAMCO SHEAR OUT SUB 2.441
Other In Hole ireline retrievable plugs,valves,pumps,fish,etc.)
Top Depth
-- (TVD) Top Incl
Top.NKB) (MB) )") D.seripebn Comment Run Date ID(inl
SEAL A'SY. 7,986.0 6,576.3 42.85 FISH 1 1/2"DMY Empty Pocket;Fell to Rathole 8/26/1985 0.000
PBR.7,333 - Perforations&Slots
-17:1
"�+� Shot
!L:■ Top(TVD) Bbn(TVD) Dery
Top(NCB) Bt n.ftKB) MB) (5)58) Zone pate (sh... TYp. Comment
PACKER,7.348 11.1.M10. 7,728.0 7,768.0 6,388.7 6,417.7 C-1,UNIT B, 4/10/1989 4.0 APERF 2 1/8"EnerJeC 0 deg.ph;17 shots of
NIPPLE,.7,551
1R-09 80 failed to fire
7,896.0 7,904.0 6,510.6 6,516.3 A-4,1R-09 8/4/1985 4.0(PERF 4"HJ II Csg Gun;90 deg.ph
7,912.0 7,944.0 6,522.2 6,545.6 A-3,1R-09 8/4/1985 4.0(PERF 4"HJ II Csg Gun;90 deg.ph
7,975.0 7,980.0 6,568.3 6,571.9 A-2,1R-09 8/4/1985 4.0(PERF 4"HJ II Csg Gun;90 deg.ph
Notes:General&Safety
End Date Annotation
11/29/2010 NOTE:View Schematic w/Alaska Schematic9.0
OVERSHOT, Ilii
7,501
SBR.7,000
PACKER,7,017
NIPPLE,7,060
SOS,7.600 -- ---J
APER,700F,
7,]20-7 --. •
IPERF,
],088-],904
111
.PERF, iiiL Mandrel Details
7,912-7944_111Top Depth Top Port
(TVD) Incl OD Vale. Latch Site TRO Run
N...Top(ftKB) (NKB) P) Mak. Model (in) Sem Type Type OM (pal) Run Dab Com...
(PERF. III 1 7,274.8 6,067.2 46.49 CAMCO KBG-2-08-1 1 INJ DMY BK 0.000 0.0 11/302008
7975-7,980
FISH,7.988
PRODUCTION.
36-8,210\
a '
TD,8,225
` STATE OF ALASKA
ALASKA IL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
1. Operations Performed: Abandon [ Repair w ell 0 Plug Perforations [I Stimulate [ Other r Starting head
Alter Casing fl Pull Tubing [ Perforate New Pool [ Waiver [ � Tim Extensio [j weld
Change Approved Program [ Operat. Shutdown [ Perforate [j Re -enter Suspended Well [
2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number:
ConocoPhillips Alaska, Inc. Development [j Exploratory [ 185 -095 _
3. Address: 6. API Number:
P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic ❑ Service p - 50 029 - 21350 - 00"° 00
7. Property Designation (Lease Number): 8. Well Name and Number:
ADL0025635 . — 1R-09 4, 4,,�4s
9. Field /Pool(s): "" kw f
Kuparuk River Field / Kuparuk River Oil Pool ii,, : ^ z , 1
10. Present Well Condition Summary: 443 ;�C. J r '/ ,,, },
// A .
Cap
Total Depth measured 8225 feet Plugs (measured) None t
true vertical 6752 feet Junk (measured) 7986 ' � S ' t+v /s ,
•
Effective Depth measured 0 feet Packer (measured) 7348, 7617
true vertical 0 feet (true vertucal) 6118, 6309
Casing Length Size MD TVD Burst Collapse
CONDUCTOR 77 16 115 115 0 0
SURFACE 4002 12 4039 3792 0 0
PRODUCTION 8175 7 8210 6741 0 0
Perforation depth: Measured depth: 7728' - 7768', 7896' 7904', 7912' 7944', 7975' -7980'
True Vertical Depth: 6389' 6418', 6511' 6517', 6523' 6546', 6569' -6572' *.44801E0 JUN 1 4 ZO1'l
Tubing (size, grade, MD, and TVD) 2.875, J - 55, 7689 MD, 6360 TVD
Packers & SSSV (type, MD, and ND) PACKER - BAKER FH PACKER 7348 MD nd 6118 TVD
PACKER - CAMCO HRP - - RETRIEVABLE PACKER @ 7617 MD and 6309 TVD
NIPPLE - CAMCO DS NIPPLE NO GO @ 494 MD and 494 ND
11. Stimulation or cement squeeze summary:
Intervals treated (measured): NA
Treatment descriptions including volumes used and final pressure:
12. Representative Daily Average Production or Injection Data
Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure
Prior to well operation NA NA NA NA NA
Subsequent to operation NA NA NA NA NA
13. Attachments - 14. Well Class after work:
Copies of Logs and Surveys run Exploratory r Development (l Service r Stratigraphic [
X 15. Well Status after work: oil 0 Gas 0 WDSPL 0
Daily Report of Well Operations
GSTOR 0 WINJ 0 WAG p GINJ [ SUSP [ SPLUG
16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt
NA
Contact MJ Loveland /Per KI -i
Printed Name MJ Lovel., d / Title Well Integrity Project Supervisor
Signature one: 659 -7043 Date 6 -7 -11 „/ /0
RBD JU N 09 201ta C.. /OW
Form 1g 404 Revised 10/2010 6ay/i Submit Original Only
• •
1R-09
DESCRIPTION OF WORK COMPLETED
SUMMARY
Date Event Summary
05/16/11 TAG @ 7939' SLM. EST. 13' OF FILL. SET 2.25" CA -2 PLUG @ 7656' RKB. MITT TO 2500
PSI, PASSED. DRAWDOWN TBG TO 0 PSI, PASSED.
06/03/11 Pre heat and weld thread leak between casing head and casing mandrel hanger (Braden
head).
06/06/11 MITOA - (Passed), Post BH Weld. Initial T /I /O= si 0/0/0. OA FL AS. Pressured up OA to 1796
Start MITOA, T /I /O= 0/0/1796
15 min T /I /O= 0/0/1728
30 min T /I /O= 0/0/1708
Final T /I /O= si 0/0/0
■
. . ... • ' 1.'"* . !! :.' ' ''' - - . '-' '„
..'.„,.,74.. ' • L.,,...f - ei, ( .,,,,,A., .
,
rte:`
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•
7,*--: 4 a /' 1 fxN ‘4:. '.4
OC orocoPh F illi sAlaska,
3
"� his s c lyr '°
Con Alaska
o cannot: be rele =
`published 111 lout
,,,,,
written il � - ,off : "�°
ona o' ps Ata'ska
• •
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE: Wednesday, May 25, 2011
TO: Jim Regg „ 5'2
P.I. Supervisor SUBJECT: Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA INC
1R -09
FROM: Chuck Scheve KUPARUK RIV UNIT 1R -09
Petroleum Inspector
Src: Inspector
Reviewed By:
P.I. Supry .J1
NON CONFIDENTIAL Comm
Well Name: KUPARUK RIV UNIT 1R - 09 API Well Number: 50 029 - 21350 - 00 - 00 Inspector Name: Chuck Scheve
Insp Num: mitCS 1 10522084842 Permit Number: 185 - 095 - Inspection Date: 5/21/2011
Rel Insp Num:
Packer Depth Pretest Initial 15 Min. 30 Min. 1 45 Min. 60 Min.
Well IR-09 ' Type Inj. N TVD 6117 T IA 0 2180 - 2120 2110 1
P.T.D. 1850950 - ITypeTest SPT Test psi 1529 - OA I 20 20 20 1 20
Interval 4YRTST - p/F P Tubing o 0 0 1 0 1
Notes:
Wednesday, May 25, 2011 Page 1 of 1
•
COI'1 / . .
ocoPh ~ I I i ps
Alaska
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
August 31, 2009
Mr. Tom Maunder
Alaska Oil & Gas Commission
333 West 7th Avenue, Suite 100
Anchorage, AK 99501
., ,,
t1~` '
k. _~.- w a.~, -. "
Dear Mr. Maunder:
s,oq~~
~~
!~~` d~
Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRt~. Each of
these wells was found to have a void in the conductor. These voids were filled with 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 August 15~' and 23`d 2009, and the corrosion inhibitor/sealant was
pumped August 27~', 28;h and 29th 2009. The atta.ched spreadsheet presents the well name, top
of cement depth prior to filling, and volumes used on each conductor.
Please ca11 Perry Klein or MJ Loveland at 907-659-7043, if you have any questions.
Sincerely,
.~' ~~
MJ Loveland
•
w I
~EP 0 2 2009
AL~~k~ A~I ~ G#s Cgna..~ocnrnission
Anc~or~
ConocoPhillips Well Integrity Projects Supervisor
t. ~ - - . .- .t
•;~ ~, ~
• ~ (, s°'i% ~>' ~
E> ~ ~ ~ ~ ` .~
.. r . . ~._., ~. m._ ~
ConocoPhillips Alaska Inc.
Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off
RepoR of Sundry Operations (10-404)
Kuparuk Field
Date 8/29/09 1 R PAD
Well Name
API #
PTD #
Initial top o
cement
Vol. of cement
um ed
Final top of
cement
Cement top off
date
Corrosion
inhibitor Corrosion
inhibitor/
sealant date
ft bbls ft al
1 R-01 B 50029214040200 . 2001560 13'7" 2.0 26" S/15/2U09 5.1 8/27/2009
1 R-02 50029214050000 1851760 80' 13.30 23" 8/23/2009 4.7 8/28f2009
1 R-03A 50029214060100 2000210 15' 3.00 27" 8/15/2009 5.3 8/28/2009
1 R-04 50029214070000 1851780 15'2" 3.00 26" 8/15/2009 5.1 8/28/2009
1 R-05 50029213300000 1850700 20'9" 2.20 23" 8/15/2009 3.8 8/28/2009
1 R-O6 50029213310000 1850710 14' 2.00 23" 8/15/2009 3.8 8/28/2009
1 R-07 50029213320000 1850720 44' 5.00 24" 8/15/2009 4 8/28/2009
1R-08 50029213330000 1850730 8' 1.00 21" 8/15/2009 13.7 8/28/2009
1 R-09 50029213500000 1850950 9' 1.20 25" 8/15/2009 4.3 8/28/2009
1 R-10 50029213510000 1850960 32' 5.40 22" 8l15l2009 3.4 8i28i2009
1 R-11 50029213520000 1850970 47' 6.00 38" 8/15/2009 13.9 8/28/2009
1 R-12 50029213530000 1850980 38' 6.00 24" 8/15/2009 4 8/28/2009
1 R-13 50029213850000 1851500 10' 0.50 25" 8/15/2009 4.3 8/29/2009
1 R-15 50029213870000 1851520 21'4" 4.00 35" 8115l2009 12 8/29/2009
1R-16 50029213880000 1851530 12'6" 9.00 21" 8/23/2009 3.8 8/29/2009
1 R-17 50029222120000 1911140 20" N/A 20" N/A 4.4 8/28/2009
1R-18 50029221880000 1910870 9'4" 1.20 21" 8/15/2009 3.7 8/28/2009
1R-19A 50029221850100 1910850 18" N/A 18" N/A 10.2 S/29/2009
1 R-20 50029222070000 1911080 S'4" 2.00 19" S/15/2009 11.3 8/29/2009
1R-22A 50029222060100 1990490 16" N/A 16" N/A 9 8/29l2009
1 R-23 50029222000000 1911010 18'8" 2.30 39" 8/15/2009 13.9 8/29/2009
1 R-25 50029221530000 1910470 7'4" 1.50 26" 8/15/2009 5.1 8/27/2009
1 R-26 50029221930000 1910920 7' 3.50 38" 8/23/2009 13.9 8/28/2009
1 R-27 50029222010000 1911020 18" N/A 18" N/A 5.1 8/28/2009
1 R-29 50029221950000 1910940 18" N/A 18" N/A 4.1 8/28/2009
1R-35 50029230500000 2012100 18" N/A 18" N/A 5.3 8/29/2009
1R-36 50029230570000 2012270 19" N/A 19" N/A 5.3 S/29/2009
From: Ennis, J J [J.J.Ennis@conocophillips.com]
Sent: Wednesday, January 07, 2009 9:00 AM
To: Maunder, Thomas E (DOA)
Cc: Regg, James B (DOA)
Subject: RE: 1 R-09 (PTD# 185-095)
Good morning Tom;
My apologies for delayed response due to my absence during holidays. For cased hole work, we don't have a
standard practice to circ prior to pulling tubing. In this situation whether we circ or not would depend on freeze
temperature of fluids, whether exposed to formation and observed wellbare behavior. At 1 R-09, 9.6 ppg brine
was utilized so freezing wasn't an issue, the formation was isolated via a CA-2 plug in the tailpipe and the well
was standing full. In this situation there was no reason to spend time circulating again. The 11126 comment
"continue to flow from tbg" was indeed a slight fluid imbalance probably instigated by the CI brine added to the
fluid system earlier that day. Mistakenly thinking they were about done with the well most likely resulted in an
abrupt stop to pit cleanup and a need to take on "new" brine.
Please let me know if any additional questions.
Jim Ennis
j j.ennis@conocophillips.com
(907)265-1544 (VV)
(907)632-7281 (C)
i~ i. c7 ~J~i,3'
Fro • Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov]
Sent: day, December 23, 2008 11:20 AM
To: Ennis, J
Cc: Regg, James DOA)
Subject: RE: 1R-09 # 185-095)
Jim.
I am reviewing the 404 submitted fo a recent workover on this well an ve some questions.
1. After unlanding the hanger, the well s observed for flow and th he tubing was POOH and laid down.
There is no record of the well being circulat after unlanding th anger. Is there a standard practice to circulate
prior to pulling tubing? The well had last been c lated so 34 hours previously.
2. On 11/26 while POOH, it is noted "Continue to
the fluids. Do you have any further information?
Thanks in advance. /
Tom Maunder, PE
AOGCC
From: Ennis, J J [mailt • ..Ennis@conocophillips.com]
Sent: Tuesday, No ber 25, 2008 2:42 PM
To: Maunder, omas E (DOA)
Cc: Nordi Company Man
Sub' : RE: 1R-09 packer depth (PTD# 185-095)
Tom.
tubing". It appears that there was some imbalance of
1/27/2009
MEMORANDUM
To: Jim Regg
P.I. Supervisor ~~n, (JZ' ~~'
FROM: Lou Grimaldi
Petroleum Inspector
State of Alaska
Alaska Oil and Gas Conservation Commission
DATE: Monday, December 29, 2008
SUBJECT: Mechanical Integrity Tests
CONOCOPHILL[PS ALASKA INC
1 R-09
KUPARUK RIV UNIT 1R-09
Src: Inspector
Well Name: KUPARUK RIV UNIT 1 R-09
Insp Num: mitLG081218105734
Rel Insp Num:
NON-CONFIDENTIAL
API Well Number: s0-029-213s0-00-00
Permit Number 185-09s-0 ,~
Reviewed By:
P.I. Suprv~-
Comm
Inspector Name: Lou Grimaldi
Inspection Date: 12i17i2oo8
- ,_ -..,
Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
r - ---
Well , 1R-o9 ,T a In', w _ t IA Is6o ~ sooo
. YP J TVD ~ esox ; ~ - - _ _
. 29s0 29s0 /~ __ _
p T ,, Isso9so fT3,peTest sPT Test psi ts77 ~' OA szo 9so . _
:_. 980 _ . 970 _
.Interval wRxovR p/F P ~ _ Tubing ; ,oso ~ .
-- - ° _ _ zoso I 2oso ~ zoso _ ,
NOteS: Bled IA prior to test, fluid at surface. 1.2 bbl pumped. Good test. -
Monday, December 29, 2008
Page I of I
C~
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
1. Operations Performed: Abandon ^ Repair Well 0 - Plug Pertorations ^ Stimulate ^ Other ^
Alter Casing ^ Pull Tubing ^~ ~ Perforate New Pool ^ Waiver ^ Time Extension ^
Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^
2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number:
ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 185-095 /
3. Address: Stratigraphic ^ Service ^~ ~ 6. API Number:
P. O. Box 100360, Anchora e, Alaska 99510 50-029-21350-00 '
7. KB Elevation (ft): 9. Well Name and Number:
RKB 83' 1 R-09 '
8. Property Designation: 10. Field/Pool(s):
ADL 25635 Kuparuk River Field /Kuparuk River Oil Pool
11. Present Well Condition Summary:
Total Depth measured 8225' ~ feet
true vertical 6752' , feet Plugs (measured)
Effective Depth measured 8120' feet Junk (measured) 7986'
true vertical 6674' feet
Casing Length Size MD ND Burst Collapse
Structural
CONDUCTOR 80' 16" 112' 112'
SURFACE 3998' 9-5/8" 4039' 3792'
PRODUCTION 8175' 7" 8210' 6740'
.. ~ ~ l .-.. ` ~ ~ t
3 s
.
Perforation depth: Measured depth: 7728'-7768', 7896'-7904', 7912'-7944', 7975'-7980'
true vertical depth: 6389'-6418', 6511'-6516', 6522'-6546', 6568'-6572'
Tubing (size, grade, and measured depth) 2-7/8", L-80, 7343' MD.
Packers & SSSV (type & measured depth) pkr- Baker pkr, CAMCO'HRP-I-SP' pkr- 7348', 7617'
DS' nipple @ 526'
12. Stimulation or cement squeeze summary:
Intervals treated (measured) not applicable
Treatment descriptions including volumes used and final pressure :
13. Representative Daily Average Production or Injection Data
Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure
Prior to well operation SI --
Subsequent to operation 623 ~ --
14. Attachments 15. Well Class after work:
Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service 0
Daily Report of Well Operations _X 16. Well Status after work:
Oil^ Gas ^ WAG ^ GINJ ^ WINJ ~ . WDSPL ^
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:
308-364
Contact Cody Gauer @ 263-4802
Printed Name r Title WeIIs Group Engineer
Signature ~'"' Phone: 263-4802
! r ~' P
Date /.~ t ~~ f ~~~~
~.C
Pre aced b haron Allsu -Drake 263-4612
Form 10-404 Revised 04/2006
.~,,t~Il~~~
J~'ala~ ~~ /Zr2.'Z+G~
~~ ~aN ~ J 200 ~'J ` Submit Original Only
~/~~/Q~'
~dRUCOP~'11~F1~35
~,.. ~. ~~. hx;.
Tubing Hanger.
CONDUCTOR,-
0-t 15
NIPPLE, 526-
suRFACE._
0-6.039
INJECTION, _
].275
LOCATOR.
],330
SEAL ASSV.
],333
SBR, 7,600 -
PACKER, 7,617
NIPPLE. 7.656
TTL, 7,fi99
SOS, 7,699 ~ +++yyy+++
APERF,
],728-7,768 -
IPERF. _ -.~
7.as6.7.so. ~
IPERF_
7.912-7,960
IPERF,
],975-7,980 -~~-'~'
FISH. 7.986
PRODUCTION,
a-8,210
TD, 8,225
\• KU P • 1 R-09_
1 Well Attributes Max Anale & MD ' TD
Wellbore APVU WI Field Name Well Status Prod/Inj Typo Incl (°) MD (ttKB) Act Ben (ttKB)
500292135000 KUPARUK RIVER UNIT INJ PWI 47.72 7,000.00 8,225.0
Comment ~H25 (ppm) (Date Annotation 'End Date '~iKB-Grtl (ft) Rig Release Date
SSSV: NIPPLE ~ 0 7/1/2008 (Last WO: ~ 1 1/3 0120 08 i, 3J-20 6/30/1985
Annotation Depth (ftKB) End Date Annotation End Date
Last Tag' SLM 7 977.0 11/3/2008 Rev Reason WORKOVER, PULL PLUG, RHC BALUROD i 12/4/2008 __
Casin Strin s
casin Desnri
g ption
String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd
-_
,CONDUCTOR 16 15.062 0.0 115.0 1150 65.00 H-00
~iCasing Description String 0... String ID ... Top (ftKB) Set Deplh (t... Set Depth (ND) ... String Wt... String ... ~, String Top Thrd
SURFACE 95/8 8.765 0.0 4,039.0 3,7918 I 36.00 J-55 _
~
Casing Description -Sling Top Thrd
IString 0... String ID ... Top (ftKB) Set Depth (t... Sat Depth (ND) ...'.String Wl_.'String ...
PRODUC110N 7 I 6.151 OA 8,210.0 6,740.9 26.00 J-65 ~~
Tubing Strings
'Tubing Description
String 0... IString ID ... Top (HKB) Set Depth (f... Sat Depth (ND) ... String W[... String ... String Top Thrd
TUBING 2 7/8 2.441 00 7,342.6 6,114.1 6.50 L-80 8rd Mod
Com letion De tails
Top oept n
(ND) Top Intl
Top (HKB) . (ftKB) (°) li Item Description Comment _ _ _ _ _
_ _ ID (in)
37J ' 37.7'. 0.06 ', XO -Reducing 3 1/2 EUE 8rd Box x 2 7/8 EUE 8rd Pin cross over sub 2.441
526-1'~. 526.1 ' 0.08 NIPPLE 2 7/8" "DS" Nipple w/ 2.313" Profile 2.312
7.330.31 6,105.5 46.07!LOCATOR Locator wl 2'space out on Seal assy 2.400
7,332.8 6,107.3 46.OSjSEAL ASSY '' 2.400
I
in Descri ~
g piton Strin 0... IStrin ID ... T
g g
o ftKB Set De M f... Set De ih D IStrin W[... Strin Strin To Thrd
P( 1 P ( P fN I~~~ 9 9- 9 P
I
FH Packer and OS
run 2 7/8 2.441 7,332.8 7,607.2 6,301.5 6.50 L-80 8rd Motl
Com letion De tails
Top Depth
(ND) Top Incl
Top (HKB) ittKel- (°) Item Description CommaM.. ID (in)
7,332.8 6,107.3 4605 PBR BAKER 80-32 PBR 3.250]
7,348.2 6,118.1 45.94 PACKER iBAKER GH 4782 PACKER 2.441
7,551.3 6,261.4 44.25 NIPPLE CAMCO NO GO NIPPLE 2.313
7,590.7
i~ 6,289.5
4393 3500
~OVERSHOT
g
T I
cri
p sa
g
8
Set Depth(f...
Set Depth(NDI...''String Wl...jString ... IString Top Thrd
.. str2n~D... r
g
op (HKB)
UBING O ri
nal
gl t / I
I
I
7,607.0 7.689.0 6,360.5 it 6.50 'i J-56 ~ EUE 8RD
Other I n Hole ( W"irelin e retrievable plugs, valves, pumps, fish, etc.).
i Top Depth 1, i
(TVD) I Top Incl
Top (ftKB) (ftKB)
1 (°) Description Comment Run Date ID (in)
7,600.0 6,296.3 43.861 SBR Camco'OEJ' 8/4/1985 ! 2.297
7 617.0 1
6,308.6
43.84 ~._
PACKER Camco'HRP-I-SP' 8/4/1985 12.347
7,656-0 6,33671 43.77 NIPPLE Camco'D'Nipple NO GO 8/4/1985 ~ 2.250
7,689.0 6,360.51 43.72 SOS .,Cameo 8/4/1985 2.441
7,689.0 6,360.5 43.72 TTl I 8/4/1985 2.441
7,986.0 6,576.3 42.85 FISH 1 112" DMY Empty Pocket; Fell to Rathole 8/2611985
,Perforations
snot I
Top (TVD) Bim (TVD) Dens
'Top (HKB) B1m (ftKB) /ftKB/ (HKB) Zone Date lsh... Type _ Comment
7,728.0 7,768.0 6,388.1 6,417.7 C-1, UNIT B, 4/10/1989 4.0 APERF 2 U8" EnerJet, 0 deg. ph; 17 shots of
' 1 R-09 80 failetl to (ire
7,896.0 7,904.0 6,510.6 6,516.3 A-0, 1R-09 8/4/1985 4.0 IPERF 4" HJ II Csg Gun; 90 deg. ph
7,912.0 7,944.0 6,522.2 6,546.6'~A-3, iR-09 8/4/1985 4.0 IPERF 4" HJ II Csg Gun; 90 deg. ph
7,975.OI 7,980.0 6,568.3 6,571.91 A-2, 1R-09 8/4/1985 4 0 IPERF 4" HJ II Csg Gun; 90 deg. ph
Mandrel Details
_-_ - _ - _'
Top Depth Top ~ Port
(7VD) Incl OD Valve Latch 5¢e TRO Run
F (n) Serv Type Type (in) (psi) Run Date I Comm...
~, Sin Top (HKB) (HKBI (°) Maka Motlel
l
ii 1 7,274] 60621 46.49 CAMCO KBG-2-08-1 i INJ DMY BK 0~~ 00 11/30/2008
~R-09 Pre and Post Workover Summary
DATE SUMMARY
10/17/08 PRE- RWO, T POT'S (PASSED), IC POT'S (PASSED), FUNCTION TEST L
11/3/08 TAGGED @ 7977' SLM. MEASURE SBHP @ 7854' RKB (3735 PSI) PULLED DMY
@ 7553' RKB. SET 2.25" CA-2 PLUG Cad 7656' RKB. POSITIVE TEST ON PLUG
LOOKED GOOD, IN PROGRESS.
11/4/08 PERFORMED 30 CMIT PASSED 15 MIN DRAW DOWN TEST PASSED. DUMP
BAILED ~ 5' CaCO3 ON 2.25" CA-2 PLUG Cad 7656' RKB. READY FOR E/L.
11/5/08 SHOT STRINGSHOT FROM 7566'-7578'. CUT TUBING AT 7575' WITH 2 1/8"
CHEMICAL CUTTER FOR 2 7/8" TUBING.
11/25/08 RAN 5.52" LIB TO 7570' SLM. OBTAINED IMPRESSION 1" X 1/4" X 1/4"
(CIRCULAR SHAPE). MAY INDICATE DAMAGE TO TBG STUB. JOB COMPLETE.
11/30/08 ASSIST IN PULLING BPV. PULLED BALL & ROD Cc~ 7551' RKB. PULLED SOV @
7275' RKB AND SET DGLV. LRS MITIA TO 2500 PSI. IN PROGRESS
12/1/08 PULLED RHC PLUG BODY (2.313 X-LOCK) Cad 7551' RKB. BAILED FILL FROM
7626' SLM TO 7635' SLM (REOVERED 3" PIECE OF CHAIN IN BAILER ). (( IN
PROGRESS )).
12/2/08 PULLED 2.25 CA-2 PLUG @ 7656' RKB (RECOVERED 2 LINKS FROM A CHAIN
AND SOME HARD TEFLON FROM TOP OF PLUG) JOB COMPLETE.
12/15/08 POST RWO, PRE INITIAL STATE WITNESSED MIT-IA (PASSED)
l ~
~onoc~-Phillips Time Log & Summary
1NelWiew Web RePOrting Report
Well Name: 1R-09 Rig Name: NORDIC 3
Job Type: RECOMPLETION Rig Accept: 11/22/2008 6:30:00 AM
Rig Release: 11/30/2008 1:30:00 AM
Ti em Logs
Date From To Dur S. Depth E Depth Ph,~e Code 5ubcode T Comment
11/21/2008 2a hrSummarv
Move Nordic Rig 3 from 2L-Pad to 2Z-Pad access.
09:00 10:30 1.50 COMPZ MOVE WOEQ P Waiting for Dozers to assist in rig
move
10:30 00:00 13.50 COMPZ MOVE MOB P Move rig off 2L pad to 2Z Pad
access.
1 /22/2008
Continue to move from 2Z-Pad access to 1 R-Pad. PU 11"BOP Stack and set back in cellar on rig. MIRU on
1 R-09 & set down. Berm up and RU to Kill tank. Open up well. Circ and kill well w! 9.6 ppg Brine. ND Tree
and NU BOP.
00:00 05:30 5.50 COMPZ MOVE MOB P Move rig from 2Z Pad access to
1 R-Pad
05:30 06:00 0.50 COMPZ MOVE OTHR P PJSM, hung tree in cellar.
06:00 08:00 2.00 COMPZ MOVE RURD P Pull rig over 11" BOP, pick up and
secure. Changed out riser adaptor.
Acce ted Nordic 3 ri 06:30 hrs
11 /22/2008.
08:00 09:30 1.50 COMPZ MOVE RURD P Pull rig over well, spot and level.
09:30 11:00 1.50 COMPZ WELCTI CIRC P Rig up circulating lines, and hard
lines to kill tank. Load pits with 580
bbls 9.6 brine.
11:00 13:00 2.00 COMPZ WELCTL NUND P Pulled BPV with lubricator. Record
tubin ress 370 si and IA 650 si.
13:00 15:00 2.00 COMPZ WELCTI CIRC P Pressure test circulating and hard
lines to 1000 si. Bled press. off
tubing to 0, IA to 250 psi.
Established circulation at 3 BPM @
320 psi. Circulated 9.6 ppg brine
around and diesel out to kill tank.
Pumped 342 bbls total. Shut down
um ,monitor well, static 0 .
15:00 15:30 0.50 COMPZ WELCTI OWFF P Monitor well. Blow down lines to kill
tank. Witnessing of BOPE test
waved by AOGCC (Chuck Scheve)
3:00 m, 11-22-2008.
15:30 19:00 3.50 COMPZ WELCTI OTHR P Set BPV. RD circulating lines. Take
pictures of tree for orientation. ND
tree.
19:00 20:00 1.00 COMPZ WELCTL OTHR P Check lifting 3 1/2 8rd Lifting threads
in hanger, install Blanking plug.
Remove old tree from cellar.
20:00 00:00 4.00 COMPZ WELCTL NUND NU 7 1/16" 5M x 11" 5M DSA and
install Triple ram Class 3 stack w/ 2
7/8 rams in UPR and LPR's.
11 /23/2008
Contiinue to install 2 7/8 Rams in UPR's. Test BOPE 250/3,500 psi. Pull blanking plug and BPV. RU
Landin ~t.
P~c~~a 1 a~# 7
Time Logs
_ _
Date From To Dur S De th E. De th Phase Code Subcode T Comment
00:00 01:00 1.00 COMPZ WELCTt OTHR P Continue to install 2 7/8 Rams in
BOP
01:00 15:00 14.00 COMPZ WELCTt BOPE P Test BOPE @ 250/3,500 psi. Leak
on flan a between annular preventer
and double gate. ND and change out
API ring.Remove test jt with donut.
Installed test jt in blanking plug. NU
and test annular 250/3500 si. OK.
15:00 23:00 8.00 COMPZ WELCTL BOPE T Attem t to test lower i r
failed. Pull test jt. Install 3 1/2 Test
jt and Change over to 3 1/2 Rams -
good test. Swap to the 2 7/8 Rams
and test -failed. Remove 2 7/8 rams
and inspect carriers, found that
carriers were mismatched due to
altering of 2 3/8 ram carrier to 2 7/8
carrier -enough tolerance to prevent
full closure of ram blocks. Install
new matchin set of 2 7/8 rams in
LPR's and test to 250/3 500 si.
Preform draw test. 3,000 before,
1,800 after. 200 psi in 18 sec.;
3,000 psi in 1 min. 32 sec. 4-N2 @
2,000 si. RD Test a ui ment.
23:00 00:00 1.00 COMPZ WELCTL OTHR P Pull Blankin plug, BPV, and RU
Landin ~t.
11 /24/2008
MU Landing jt, BOLDS and Unland TBG hanger. POOH w/ 2 7/8 Decompletion. MU and RIH w/ Dress off
ass to 4,835'
00:00 02:00 2.00 7,575 7,525 COMPZ RPCOM OTHR P PJSM, BOLDS, and unland hanger
and ull cut free @ 75k up wt and
65k do wt. Pull hanger to floor and
la down same. Monitor well, static.
02:00 03:00 1.00 7,525 5,785 COMPZ RPCOM PULD P Continue to POOH w/ 2 7/8 TBG,
spooling control line for SSSV.
Laydown SSSV. and RD Spooling
e ui 29 SS bands recovered.
03:00 09:30 6.50 5,785 COMPZ RPCOM PULD P Continue to POOH f/ 2 7/8 TBG.
Examined end of cut off. Flared out
to 3 1/16" and out of round.
Discission made to make a clean out
dress u run on 2 7/8' tubin .
09:30 12:00 2.50 COMPZ FISH OTHR P Unload pipe shed, clean rig floor. RU
tools for clean out run dress o
12:00 15:00 3.00 COMPZ FISH OTHR P PJSM for new crew. Service Eckels,
RIH with 45 jts 2 7/8" tubing. POOH
standing back in triples in derrick
while waitin on fishin tools.
15:00 17:00 2.00 0 54 COMPZ FISH PULD P Load fishing tools for clean out run.
MU BHA #1.
--
~~~
P~g~ 2 of 7
•
l ~
i Time Logs _ __
Date From 'fo Dur S. De th E. De th Phase Code Subcode T Comment
17:00
00:00
7.00
54
4,835
COMPZ
FISH
TRIP
P __
RIH w/ 45 jts 2 7/8 6.5# EUE 8 rd
Mod L-80 tubing from derrick and
begin picking up same from pipe
shed to 4,835' MD 57k up wt, 55k do
wt.
Pressure Test Casing Pack off @
3,000 psi for 10 minutes and
Passed.
11 /25/2008
Continue to RIH f/ 4,835' to TOF @ 7,567'. Dress off stub. POOH and LD BHA #1. RU Slickline and RIH w/
LIB and POOH.
00:00 04:30 4.50 4,835 7,578 COMPZ FISH TRIP P Continue to RIH PU 2 7/8 6.5# EUE
8 rd L-80 Tubing to 7,521' w/ jt # 235.
70k up wt, 63k do wt. T` OF @ 21' in
't# 236. = 7,578'
04:30 05:00 0.50 COMPZ FISH OTHR P MU TD and Obtain Parameters.
SPR Pump 1 @ 1 bpm @ 230 psi, 2
bpm @ 550 psi. Pump 2 @ 1 bpm
200 si, 2 b m 530 si.
05:00 08:30 3.50 7,521 7,577 COMPZ FISH MILL P Slide down, pumping @ 2.5 bpm @
790 psi and Tag TOF @ 7,567' +/-.
Pressure increased to 830 psi and
dressed off w/ Outer mill. Continue
to slide over for 9' to 7,576' and tag
up w/inner mill. PU off TOF and
work back over, unable to dress off 1'
w/ inside mill as OEJ shows to be
rotatin w/mill: Max pump pressure
seen was 1040 psi. PU off TOF and
attempt to slide over w/ out rotating
w/ no luck. Had to rotate over.
08:30 10:30 2.00 7,577 7,521 COMPZ FISH CIRC P BO TD and drop ball to open POS.
Blow down TD. Install head pin and
Pressure up to 340 psi and shear
out. Pump hi visc sweep and
circulate swee around.
10:30 13:00 2.50 7,521 0 COMPZ FISH TRIP P POOH from 7521', standing back the
2-7/8" tubing. PU wt = 70 K#, down
wt = 65 K#.
13:00 14:30 1.50 0 0 COMPZ FISH PULD P Lay down BHA.
Wear on mill shows that the 2-7/8"
tubing stub ma be s lit_. Planning
to run LIB on slickline.
14:30 15:30 1.00 0 COMPZ FISH WOEQ X Waiting on equipment for slickline
LIB run.
15:30 20:30 5.00 COMPZ FISH OTHR X ND Riser, Load Slick line Lubricator,
WL BOP's, and WL Tools.
20:30 22:30 2.00 COMPZ FISH OTHR X PJSM, PT lubricator to 1,200 psi.
22:30 00:00 1.50 COMPZ FISH SLKL X Rih w/ LIB on slickline to TOF, Set
Down and POOH.
COMPZ FISH
11 /26/2008
Continue to POOH, inspect LIB. RD Slickline. RU and RIH w/ 2 7/8 Completion.
Wage 3 ~~fi 7
j Time Logs
I Date From To Dur S. De th E
.
De th Phase Code Subcode
Comment ~
T
00:00 00:30 0.50 _
_ COMPZ FISH SLKL _
_
X POOH w/ 5.5" LIB had 2 marks (1"
long x 7/32" wide and 1!2" long x
7/32" wide) but did not show any
attern of TBG stub.
00:30 03:00 2.50 COMPZ FISH OTHR X RD HES Slickline unit, ND Shooting
flan a and NU Riser
03:00 04:00 1.00 0 396 COMPZ RPCOM PULD P RU to RIH w/ Completion. RIH to
396'
04:00 06:00 2.00 396 396 COMPZ RIGMNT SVRG P Hang blocks. Cut and slip drill line.
Check brake links e.
06:00 11:30 5.50 396 7,560 COMPZ RPCOM RCST P RIH with 2-7/8" completion to 7496';
Up wt = 73 K#, down wt = 65 K#.
MU head pin, establish circulation 3
b m 550 si, wash down to 7560'.
11:30 13:30 2.00 7,560 7,560 COMPZ RPCOM CIRC P Circulate 229 bbl of corrsion inhibited
brine (1 % CRW-132) into the IA.
Underdisplace to allow pumping to
confirm overshot has engaged tubing
stub.
13:30 14:30 1.00 7,560 7,562 COMPZ RPCOM RCST P RIH and to ed tubin stub with
bottom of the overshot at 7562', sit
down 5 K#, no pump pressure
increase, PU tubing.. Pumping 1
bpm @ 60 psi.
RIH sit down 10 K#, no pump
pressure increase, PU tubing.
Rotate tubing, RIH sit down 10 K#,
no pump pressure increase, PU
tubing.
Rotate tubing, RIH sit down 15 K#,
no pump pressure increase, PU
tubing.
Rotate tubing, RIH sit down 20 K#,
no pump pressure increase, PU
tubing. Repeat this step several
times and made about 2' of depth.
but never saw an um res
increase.
14:30 16:30 2.00 7,562 7,555 COMPZ RPCOM CIRC X Pull up hole to 7555'. Circulate out
inhibited brine @ 3 bpm 550 psi.
Monitor well (Static) Rig down circ
lines.
16:30 18:00 1.50 7,555 7,002 COMPZ RPCOM PULD X POOH with 2-7/8" com letion f/
7,555' to 7,002'. 70k up wt, 63k do
wt. Continue to flow fro
18:00 18:30 0.50 7,002 7,002 COMPZ RPCOM CIRC X RU Lines to circ. and pump TBG vol.
18:30 18:45 0.25 7,002 7,002 COMPZ RPCOM OWFF X Monitor well -TBG still flowing back.
18:45 19:15 0.50 7,002 7,002 COMPZ RPCOM CIRC X Circulate @ 3 bpm and stage pump
down slowl
19:15 19:30 0.25 7,002 7,002 COMPZ RPCOM OWFF X Monitor well -Static
Page ~€ ~rP 7
•
Time Lis _ ___ __ __ __ _~
I Date From To Dur S. De th E. De th Phase Code Subcode T Comm
ent
19:30
23:00
3.50
7,002
0
COMPZ
RPCOM
TRIP
X _
_
POOH f/ 7,002', lay down completion
components. Mule shoe was
rou hed u on face.
23:00 00:00 1.00 0 0 COMPZ RPCOM OTHR X Wash stack
11 /27/2008
Set Test plug and change rams to 3.5. Test BOP UPR, LPR's and Annular @ 250/3,500. Pull test plug. MU
and Rih w/ 3 1/2 x 2 7/8 sizing BHA assy on 3 1/2 DP PU and RIH. Dress TBG stub and recover OEJ OS.
POOH and La down fish
00:00 01:00 1.00 0 0 COMPZ WELCTL OTHR X Set test plug
01:00 03:30 2.50 0 0 COMPZ WELCTL EORP X Chan a out 2 7/8 UPR and LPR's w/
3 1/2
03:30 05:30 2.00 0 0 COMPZ WELCTL BOPE X PJSM, Test LPR, UPR and Annular
250/3,500 si and chart same.
05:30 06:00 0.50 0 0 COMPZ WELCTL OTHR X Pull Test plug
06:00 07:30 1.50 0 230 COMPZ FISH PULD X PU and MU fishing BHA #2 (3-1/2"
sizing shoe, 2-7/8" hollow mill and
ra le
07:30 16:00 8.50 230 7,538 COMPZ FISH TRIP X PJSM. RIH with 3-1 /2" DP to 7538'.
Up wt = 130 K#, down wt =105 K#.
Establish pump rates and pressures.
45 RPM @ 2600 ft# and a ROT wt of
120 K#.
16:00 16:30 0.50 7,538 7,568 COMPZ FISH FISH X RIH pumping 4 bpm @ 560 psi, 45
rpm @ 2600 ft#.
Torque increased to 3000 ft# @
7567'. Worked down 2 ft and torque
dropped to 2400 ft# and pressure
increased to 610 psi.
Stop rotating and RIH to 7584'. Pick
up to 175 K# (45 K# overpull), waited
forjars to go off and weight dropped
off. Pulled up hole with 125 K# and
pump pressure dropped off to 560 psi
at 7568' len th of OEJ slick stick .
16:30 17:30 1.00 7,568 7,564 COMPZ FISH CIRC X PU to 7564', circ BU, monitor well,
blow down to drive.
17:30 23:30 6.00 7,564 240 COMPZ FISH TRIP X POOH standing back 76 stands of
3-1/2" DP.
23:30 00:00 0.50 240 0 COMPZ FISH PULD X Break down and Lay down DC's,
remove fish f/ OS. Recovered 18.68'
of 2 7/8 TBG stub, 6' x 2 7/8 Pup jt_
and 16.5' of Camco OEJ OS = 41.30'
of fish. Top of Polished stub is
7 600'. Stub is 8.58' long by
drawin .
11 /28/2008
MU OS and FH Packer assy and RIH on DP. Locate Polished stem of OEJ and engage. PU and spot 10
bbls of corrosion inhibited 9.6 brine. Slide over stem and drop bal and rod. Set FH Packer, shear out of PBR
and PT IA to 2,500 si. Pooh la in down DP.
00:00 01:30 1.50 0 0 COMPZ FISH PULD X Continue to break out and lay down
BHA and Fishin tools.
01:30 02:30 1.00 0 0 COMPZ FISH OTHR X Send out fishing tools.
•
•
Time Logs __ __ _
Date ___ From 7o Dur S._D_ epth E. De th Phase Code Subcode T_ __Comment _
02:30 04:00 1.50 0 0 COMPZ RPCOM PULD P PJSM, Attempt to RIH w/ OEJ and
set down @ wear ring. Drain stack
and found a piece of metal laying
across the top of wear ring. Lay
down OEJ OS and PU 1 jt 3 1/2 DP.
MU Bit sub for fishin ma net.
04:00 05:30 1.50 0 0 COMPZ FISH WOEQ X Fishing magnet coming from
Deadhorse.
05:30 07:00 1.50 0 0 COMPZ FISH FISH X MU magnet RIH to wear ring and
catch fish. Make two more trips to
ensure all debris is clear. RD
ma net tools.
07:00 08:30 1.50 0 282 COMPZ RPCOM PULD P MU OEJ overshot with FHL packer
assembl . Swa floor a ui ment.
08:30 14:30 6.00 282 7,590 COMPZ RPCOM TRIP P RIH with FHL acker assembl on
3-1l2" DP
14:30 17:30 3.00 7,590 7,608 COMPZ RPCOM PACK P Up wt = 120 K#, down wt = 105 K#.
RIH pumping 1 bpm @ 60 psi. DP
pressure u at 7597', shut down
um .
RIH to 7607' and sit down 5 K#. PU
125 K# to 7603'.
RIH to 7608' and sit down 10 K#. PU
125 K# to 7596, PU wt dropped to
120 K#, pull up hole to 7594'.
Circulate 10 bbl of corrosion inhibited
brine down around the OEJ overshot
up to the PBR.
RIH to 7607', drop ball and rod.
Pressure up to 2500 psi (indication of
packer set at 1700 psi), hold for 10
min. Pull up 140 K# to release from
PBR. Bleed off pressure.
Pull up 20', close pipe rams, pump
down DP and pressure test casing to
3000 si for 15 min.
17:30 00:00 6.50 7,320 0 COMPZ RPCOM TRIP P POOH laying down the 3-1/2" DP.
11 /29/2008
Pull wear ring, set test plug. Change 3 1/2 rams to 2 7/8. Test LPR, UPR and Annular to 250/3,500 psi. RIH
w/ 2 7/8 Compl. Space out. Load IA w/ 1 % CRW-132 Brine. Land hanger, RILDS. PT TBG and IA. Set BPV.
ND BOPE and NU Tree. FP IA and TBG.
00:00 03:30 3.50 0 0 COMPZ WELCTI EQRP P Pull Wear ring and set Test Plug.
Chan a out 3 1/2 rams in LPR and
UPR's to 2 7/8.
03:30 05:00 1.50 0 0 COMPZ WELCTI BOPE P Test LPR, UPR and Annular to
250/3,500 psi. Notice was given to
AOGCC @ 17:15 hrs on 11-28-08
and Witness of test waived by Bob
Noble @ 17:20 hrs on 11-28-08. RD
test a ui ment and Pull Test lu .
05:00 08:30 3.50 0 7,290 COMPZ RPCOM RCST P MU and RIH w/ seal assy, 1 jt, GLM,
and 2-7/8" tubin to 7290'.
P~c~~ ~i o3 7
Time Logs
Date
From
To
Dur _
SDepth
E_,_Dept_h
Phase
Code
Subcode
T
Comment
08:30 12:00 3.50 7,290 7,349 COMPZ RPCOM HOSO P RIH pumping 1 bpm @ 60 psi.
Pressure increased at 7337'. Stop
pumping, RIH, sit down 5K# no go at
7349'. PU 5', RIH sit down 10 K# no
go at 7349'. Pressure test tubing to
500 psi/ 5 min.
Space out tubing hanger. Rev circ
150 bbl of inhibited brine (9.6 ppg +
1 % CRW-132). Land hanger and
RILDS.
12:00 14:00 2.00 0 0 COMPZ RPCOM DHEQ P Pressure test tubing to 2500 psi / 15
min. Bleed tubing down to 1750 psi.
Pressure test IA to 3000 si / 30
min. Bleed down IA, bleed down
tubing. Pressure up IA, sheared
SOV at 1950 si.
14:00 17:00 3.00 0 0 COMPZ RPCOM NUND P Set BPV. ND BOPE /change upper
and lower i e rams to 3.5".
17:00 19:30 2.50 0 0 COMPZ RPCOM NUND P NU Tree
19:30 20:00 0.50 0 0 COMPZ RPCOM SFEQ P Test Void to 250/5,000 psi and hold
for 15 minutes. Good test.
20:00 20:30 0.50 0 0 COMPZ RPCOM OTHR P Pull BPV Set TTP
20:30 22:00 1.50 0 0 COMPZ RPCOM SFEQ P RU and Test Tree 250 / 5,000 psi
ood test
22:00 23:00 1.00 0 0 COMPZ RPCOM FRZP P PJSM, RU LRS. PT Lines @ 2,000
psi. Pump 90 bbls diesel down IA @
2 b m. RD LRS.
23:00 00:00 1.00 0 0 COMPZ RPCOM OTHR P Tie TBG to IA and allow to swap.
11 /30/2008
Set BPV, Secure well, Clean cellar and dress Tree. RDMO of 1 R-09
00:00 02:00 2.00 0 0 COMPZ RPCOM OTHR P Install BPV, Secure well, Clean
Cellar and Dress tree.
0 TBG si, 0 IA si, 25 OA si.
0 COMPZ RPCOM Nordic Rig 3 Released @ 0130 hrs
on 11-30-08
~~cJ~ 7 of 7
1R-09 packer depth (PTD# 1855) Page 1 of 2
Maunder, Thomas E (DOA)
From: Maunder, Thomas E (DOA)
Sent: Tuesday, December 23, 2008 11:20 AM
To: 'Ennis, J J'
Cc: Regg, James B (DOA)
Subject: RE: 1 R-09 (PTD# 185-095j
Jim,
1 am reviewing the 404 submitted for the recent workover on this well and have some questions.
1. After unlanding the hanger, the well was observed for flow and then the tubing was POOH and laid down.
There is no record of the well being circulated after unlanding the hanger. Is there a standard practice to circulate
prior to pulling tubing? The well had last been circulated some 34 hours previously.
2. On 11/26 while POOH, it is noted "Continue to flow from tubing". It appears that there was some imbalance of
the fluids. Do you have any further information?
Thanks in advance.
Tom Maunder, PE
AOGCC
From: Ennis, J J [mailto:J.J.Ennis@conocophillips.com]
Sent: Tuesday, November 25, 2008 2:42 PM
To: Maunder, Thomas E (DOA)
Cc: Nordic 3 Company Man
Subject: RE: 1R-09 packer depth (PTD# 185-095)
Tom,
During pre-rig diagnostics, that section of casing was successfully MIT'd to 2500 psi so I don't have any concerns
about it withstanding injection pressure in the short term. Longer term, surveillance IPROF's should detect any
fluid lost to this section.
Jim Ennis
j j.ennis@conocophillips.com
(907)265-1544 (N1~
(907)632-72$1 (C)
From: Maunder, Thomas E (DOA) [maittoaom.maunder@alaska.gov]
Sent: Tuesday, November 25, 2008 2:15 PM
To: Ennis, J J
Subject: RE: 1R-09 packer depth (PTD# 185-095)
Jim,
There is not an issue with setting the packer more than 200' and above the top pertoration. One question though,
if you assume the casing is similarly corroded will it be able to withstand the injection pressure? The perforations
should provide the "pressure relief', however there still could be a substantial head at depth. I look forward to
your reply.
Tom Maunder, PE
AOGCC
12/23/2008
1R-09 packer depth (PTD# 1855) Page 2 of 2
From: Ennis, J J [mailto:J.J.Ennis@conocophillips.rnm]
Sent: Tuesday, November 25, 2008 1:39 PM
To: Maunder, Thomas E (DOA)
Subject: 1R-09 packer depth (PTD# 185-095)
Tom,
Upon pulling the chemically cut tbg from this well, we found the btm four joints to be externally corroded.
Assuming the casing is a mirror image, we would like to set the stack packer 5 joints higher than planned ~ 7354'
MD to help ensure a good packer seal. Top pert is at 7728' MD. Please tet me know if you see any problem with
this change. Thanks.
Jim Ennis
j j.ennis@conocophillips.com
(907)265-1544 (V{~
(907)632-7289 (C)
12/23!2008
Page 1 of 1
• •
Maunder, Thomas E (DOA)
From: Maunder, Thomas E (DOA)
Sent; Wednesday, October 29, 2008 4:50 PM
To: Gauer, Cody
Subject: RE: 1R-09 ~~5 _OC
Hi Cody,
No need to resubmit. I will include a copy of this message in the file.
Tom Maunder, PE
AOGCC -
Prom: Gauer, Cody [mailto:Cody.Gauer@conocophillips.com~
Sent: Wed 1OJ29/2008 4:39 PM
To: Maunder, Thomas E (DOA) ~-~~~ ~~~, t~ ~ G{
Subject: RE: iR-09 ~`'`~~ ' ~ ~ ~~~~
Hi Tom,
Howard just pointed out to me that on my pre-rig procedure for 1 R-09 I had listed a caliper log be run. I
overlooked the fact that it is j-55 and we will be junking it, therefore no need for a caliper. Would you like me to
resubmit this for the sundry? Thanks.
Cody Gauer
Wells Engineer
ConocoPhillips Alaska,Inc.
907-263-4802 -office
907-575-5407 -mobile
Cody. Gauer@ConocoPh 1] ps, com
10/30/2008
•
SARAH PALIN, GOVERNOR
333 W. 7th AVENUE, SUITE 100
ANCHORAGE, ALASKA 99501-3539
PHONE (907) 279-1433
FAX (907) 276-7542
Cody Gauer
Wells Group Engineer
ConocoPhillips Alaska Inc
PO Box 100360 ~ , . ~ ,~ ., , ,~ ~~, ,
Anchorage, AK 99510 5~~~~ ?~`~'~~' ~ ~' ~`~~ `~5.~
V
Re: Kuparuk River Field, Kuparuk River Oil Pool, 1 R-09
Sundry Number: 308-364
Dear Mr. Gauer:
Enclosed is the approved Application for Sundry Approval relating to the
above referenced well. Please note the conditions of approval set out in the
enclosed form.
When providing notice for a representative of the Commission to witness any
required test, contact the Commission's petroleum field inspector at (907)
~r/^ ,~,. .~ ,rQri,
~.~,~-,~v0;, ~
As provided in AS 31.05.080; within 20 days after written notice of this
decision, or such further time as the Commission grants for good cause
shown, a person affected by it may file with the Commission an application
for rehearing. A request for rehearing is considered timely if it is received by
4:30 PM on the 23rd day following the date of this letter, or the next working
day if the 23rd day falls on a holiday or weekend. A person may not appeal
a Commission decision to Superior Court unless rehearing has been
requested.
Sincerely,
Daniel T. Seamount, Jr.
Chair
DATED this ~ day of October, 2008
Encl.
• ~
~~ • •
ConocoPh~ll~ps
Alaska
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
October 9, 2008
Commissioner
State of Alaska
Alaska Oil & Gas Conservation Commission
333 West 7'h Avenue Suite 100
Anchorage, Alaska 99501
Dear Commissioner:
ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the
Kuparuk Injection well 1 R-09 (PTD# 185-095).
Injecting well R-09 was drilled and completed in 1985. The well operated on water-alternating
gas injection until August 1995, and on water injection until May 2007 when it failed an MITIA.
Tubing by Inner Annulus communication was suspected and a caliper survey was run to identify
leaks. A caliper PDS log was run showing wall penetrations in excess of 71 % due to isolated
pitting at 5,232',2,906', and 3,012'. Based on this, the tubing will be replaced with the same
diameter tubing to turn the well back on injection.
The purpose of the proposed workover will be to pull the existing 2 7/8" tubing string and replace
it with a new 2-7/8" tubing. Attached is a proposed schematic along with a general workover
procedure.
MASP is 2,950 psi based on a SBHP of 3,596 psi @ 7,930'MD (6,532'TVD) and a Gradient of
0.1 psi/ft.
If you have any questions or require any further information, please contact me at 263-4802
Regards,
C G
Wells Engineer
CPAI Drilling and Wells
~?'A ~-~ ~~~ RECEIVED
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION ` `~ OCT ~ 3 2008
APPLICATION FOR SUNDRY APPRO+II~i~.pii & Gas Cons Commissia~a
20 AAC 25.280 n _ _
1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver Other ^
Alter casing ^ Repair well ^~ Plug Perforations ^ Stimulate ^ Time Extension ^
Change approved program ^ Pull Tubing ^/ • Perforate New Pool ^ Re-enter Suspended Well ^
2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number:
ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 185-095 .
3. Address: Stratigraphic ^ Service Q 6. API Number:
P. O. Box 100360, Anchora e, Alaska 99510 50-029-21350-00 '
7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number:
where ownership or landownership changes:
Spacing Exception Requires? Y2S ^ NO Q 1 R-09 '
9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ZZi~1~CC"
ADL 25635 RKB 83' Kuparuk River Field / Kuparuk Oil Pool
12. PRESENT WELL CONDITION SUMMARY
Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured):
8225' ' 6752' 8120' 6674' 7986'
Casing Length Size MD TVD Burst Collapse
CONDUCTOR g0' 16" 112' 112'
SURFACE 3998' 9-5/8" 4039' 3792'
PRODUCTION 8175' 7" 8210' 6740'
Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft):
7728'-7768', 7896'-7904', 7912'-7944', 7975'-7980' 6389'-6418', 6511'-6516', 6522'-6546', 6568'-6572' 2-7~8" J-55 7689'
Packers and SSSV Type: Packers and SSSV MD (ft)
pkr= CAMCO'HRP-1-SP' pkr= 7617'
Camco'TRDP-1A-SSA' SSSV= 1790'
13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work:
Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service Q
15. Estimated Date for 16. Well Status after proposed work:
Commencing Operat November 24, 2008 Oil ^ Gas ^ Plugged ^ Abandoned ^
17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ~ WDSPL ^
Commission Representative:
18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Cody Gauer @ 263-4802
Printed Name Gauer Title: Wells Group Engineer
Signature Phone 263-4802 Date /6 ~d/
Commission Use Onl
Sundry Number:
Conditions of approval: Notify Commission so that a representative may witness
Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ~ Location Clearance ^ ~~ ~ 1~`l-tJ~
yy ~
Other. ~~l®~~S ~ ~~ ~ TCS~
Subsequent Form Required: ~~~
APPROVED BY /~I Z O /~
Approved by: SS ONER THE COMMISSION Date: `~
Form 10-403 Revised 06/20 6 t k `~~` - --- ~- Ori ~`~ ~, ~~Q~ Submit in Duplicate~ro.tt~lb
• •
~' . .
ConocoPh~ll~ps
Alaska
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
Pre Rig Work:
1. Apply for Sundry
2. Tag Fill. Obtain SBHP & Caliper log
3. Pull DV @ 7,553'
4. Set Plug in "D" Nipple @ 7,656'
5. Chemical Cut Tubing @ 7,575'
6. Set BPV
Rig Workover:
1. Verify Sundry Approval
2. MIRU Nordic 3. ~~`P-~ ~~~
3. Pull BPV. Verify Well is Dead.
4. ND tree, NU & test 11" SM BOPE w/ 2.875" rams to 250/~si. ~~! ~
5. Pull and Lay down tubing
6. Run in w/ new completion. Land Poorboy overshot & space out.
7. Spot corrosion inhibitor. Land tubing. Pressure test IA to 2000 psi
8. ND BOPE. NU existing tree. Freeze protect well.
9. RDMO Nordic 3.
Post Rig Work:
1. MIRU SL. Pull SOV
2. RDMO SL
Well Name: 1R-09 API: 50-l1Z~~-' 1350-~0
Field: Ktiparuk ~ P'I'D:1.85-Uy5 ~I1C~CC1Phiftip5
PiiTD: 7,965' MD TD: 8,225' MD
Co~r-ments: Proposed Schematic far 1R-09_T_ubin~ Changeout
Conductor Ni ~c
Size: l6 " 115 TVD
to 2.875" Weight: 65 #iFt 115 MD
;over Sub Grade H-40
Surface Casing
5" Size: 9.625 " 3792 TVD
3" Weight: 36 #/Ft 4039 MD
Grade J-55
'I'tibin Strin
Size: 2.875 " 0 to 6361 TVD
Weight: 6.5 #/Ft 0 to 7689 MD
Grade J-55 EUE 8rd MOD
er @ 7,510'
.75"Nipple
Profile Production Casio
Size: 7.000 " 6,741 TVD
Y Overshot Weight: 26 #/Ft 8,210 MD
' MD Grade J-55
75" Nipple
Profile
Perfs
Ct 7728 to 7768 MD
W S A4 7896 to 7904 MD
W S A3 7912 to 7944 MD
WS A2 7975 to 7980 MD
Production Liner - NON1!
Size: to TVD
Weight: #/Ft to MD
Grade
•
,ELL LlJ
___ .
T~4'AN~'MITTAL
___ ,I~
ProActive Diagnostic Services, Inc.
To: AOGCC
Christine Mahnken
333 West 7th Avenue
Suite 100
Anchorage, Alaska 99501
(907) 659-5102
RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Catiper/ MTT)
The technical data listed below is being submitted herewith. Please acknowledge receipt by returning
a signed copy of this transmittal letter to the following
ProActive Diagnostic Services, Inc.
Attn: Robert A. Richey
130 West International Airport Road
Suite c ~~N~ APR 0 4 2008
Anchorage, AK 99518
Fax (907) 245-8952
1) Caliper Report
2) Caliper Report
Signed
Print Name:
22-Mart08 1 R-09 1 Report / EDE
22-Mar-08 1 E04 Caliper Report
50-029-21350.00
50-029-20478.00
r..:_, ~ ~
_ ~ ~. ~,~~ i~,.
Date : ~"If ~~°' ~~ t'1~l~'t
PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518
PHONE: (907)246-8951 FAX: (907)245-88852
E-MAIL : ~dsancharage(a7meenor~tlag.cam WEBSITE : v~rtw.rrlernorylap com
Use Igo-tS3 ~ llmv~ l
iJ~~ 1~5 -~5 ~~~~~a
C:\Documents and Settings\Owner\Desktop\Transmit_BP.doc
II
1
S
• •
Memory Mutta~Finger Caliper
Log Results Summary
Company: ConocoPhi'ilips Alaska, Inc. WeN: 1 R-09
Log Date: March 22, 2008 Field: Kuparuk
Log No.: 8669 State: Alaska
Run No.: 1 API No.: 50-029-21350-00
Pipet Desc.: 2.875" 6.5 Ib. J-55 EUE 8RD Top Log Intv11.: Surface
Pipet Use: Tubing Bot. Log Intvll.: 7,692 Ft. (MD)
Inspection Type : Corrosive & Mechanical Damage Inspection
COMMENTS:
^ This log is tied into the end of the tubing tail ~ 7,689' (Driller's Depth).
' This log was run to assess the condition of the 2.875" tubing with respect to corrosive and mechanics!
damages. This is the first time a PDS caliper has been run in this well.
The 2.875" tubing appears to be in good to poor condition, with wall penetrations from 20% to 71% recorded
throughout the tubing. The damage appears predominantly as isolated pitting, with scattered areas of
general corrosion and lines of corrosion. No significant areas of cross-sectional wall loss or I.D. restrictions
are recorded.
The caliper recordings indicate slight buckling from 4,700' to 5,300' and buckling from 5,300' to 7,575'
MAXIMUM RECORDED WALL PENETRATIONS
'
Isolated Pitting (71°~) Jt. 165 ~ 5,232 Ft. {MD)
Isolated Pitting { 61°~) Jt. 92 ~ 2,906 Ft. (MD)
Isolated Pitting (53%) Jt. 95 (aZ 3,012 Ft. (Mb)
'
Isolated Pitting (51°~) Jt. 128 ~ 4,050 Ft (MD)
Isolated Pitting (48%) Jt. 85 @ 2,690 Ft. {MD)
MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS
No significant areas ofcross-sectional waH loss (> 5%) are recorded.
MAXIMUM RECORDED ID RESTRICTIONS :
No significant I.D. restrictions are recorded.
~~ r~i~ AP's ~ ~ 20Q8
Field Engineer: K. Mi/Ier Analyst: M. Lawrence Witness: C. Kennedy
ProActive Diagnostic Services, Inc. ( P.,O. Box 1369, Stafford, TX 77497
Phon~_: (Z81} or (8:38} 565-9085 Fax: (Z81} 565-1369 E-mail: PDS~d>memorylog.cam
Prudhoe Bay Field Office Phone: (907} 659-2307 Fax: (907) 659-2314
i 1
~ u.~~- - 5
• •
Correlation of Recorded Damage to Borehole Profile
Pipe 1 2.875 in (32.0' - 7688.9')
Well: 1 R-09
Field: Kuparuk
Company: ConocoPhillips Alaska, Inc.
Country: USA
Survey Date: March 22, 2008
^ A pprox. Tool De viation ^ A pprox. Borehol e Profil e
786
1567
GLM 1
2368
GLM 2 3152
3941 ~
GLM 3 s
O
4727
GLM 4
GLM 5
5524
GLM 6
GLM 7
6320
GLM 8
GLM 9 7110
GLM 10
241.1 7689
0 5 0 1 00
Da mage Pr ofile (% wall) / Tool D eviatio n (degr ees)
Bottom of Survey = 241.1
25
50
75
a`,
~ 125 '~.
Y.,,?
Y
~
150 ~,
l
175 ._... .,,
200
•
•
PDS Report Overview
~ ~. Body Region Analysis
Well: 1 R-09 Survey Date: March 22, 2008
Field: Kuparuk Tool Type: UW MFC 24 No. 214320
Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69
Country: USA No. of Fingers: 24
Anal st: M. Lawrence
Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len.
2.875 ins 6.5 f -55 El1F 8RD 2.441 ins 2.875 ins 6.0 ins 6.0 ins
Penetration and Metal Loss (% wall)
~ penetration body ~ metal loss body
200 -
150
100
50
0 0 to 1 to 10 to 20 to 40 to over
1% 10% 20% 40% 85% 85%
Number of'oints anal sed total = 243
pene. 38 78 35 61 31 0
loss 156 87 0 0 0 0
Damage Configuration (body )
100
80
60
40
2i)
0
isolated general line ring hole /pons
pitting corrosion corrosion corrosion iblehole
Number of 'oints dama ed total = 106
93 6 7 0 0
Damage Profile (9'o wall)
I~ penetration body „ ,; metal loss body
0 50 100
n
GLM 1
GLM 2
CLM 3
GLM 4
GLM 5
GLM 6
GLM 7
GLM 3
GLM 9
GLM 10
Bottom of Survey = 241.1
Analysis Overview page 2
• •
PDS REPORT JOINT TABULATION SHEET
Pipe: 2.875 in 6.5 ppf J-55 EUE SRD Well: 1 R-09
Body Wall: 0.217 in Field: Kuparuk
Upset Wall: 0.322 in Company: ConocoPhillips Alaska, Inc.
Nominal I.D.: 2.441 in Country: USA
Survey Date: March 22, 2008
Joint
No. Jt. Depth
(Ft.) Pc~n.
111xc~i
Iln~.) Pen.
Body
(Ins.) Pen.
% Metal
I~~s~
°~~~ Min.
LD•
(Ins.)
Comments Damage Profile
(%wall)
0 50 100
.1 32 t~ 0.02 Fi I .39 PUP
0 36 ~t 0.02 1 U .' 2.41
2 68 t. 0.01 5 1 2.40
3 99 It 0.01 ~ 2.41
4 130 ~ ~ 0.02 10 _' 2.40
5 161 a 0.02 11 t :' 2.38
6 192 ~ 0. 12 .40
7 224 n 0.01 4 ~' 2.38 Lt. De osits.
8 255 ~~ 0.0 10 I 2.38 t. De osits.
9 286 It 0.01 ~ I 2.40
10 316 U 0.03 12 - 2.41
11 348 ! t 0.01 4 I 2.39
12 380 U 0.0 1 1 I 2.38 Lt. De osits.
13 411 U 0. 1 3 1 2.38 Lt. De sits.
14 44 U 0.02 10 1 2.38 Lt. De osits.
15 473 U 0 0 I 2.38
16 504 U 0.01 -1 1 2.38 Lt. De osits.
17 536 t t 0.03 1 l 2.40
18 567 I t 0.01 6 I 2.38
19 598 It 0.02 11 I 2.39
20 629 O 0.03 12 1 2.38
21 6 0 U 0.0 11 ~' 2.38 Lt. De osits.
22 69 a 0.02 10 2.39
23 724 a 0.02 11 ~' 2.38
24 7 5 (t 0.04 1 t3 1 2.40 hallow corrosi n.
25 786 t) 0.04 19 I 2.40 Shallow ittin .
26 817 a 0.01 3 I 2.41
27 848 I? 0.00 I I i 2.39
28 880 a 0.02 I t 2.40
29 911 ~~ 0.01 5 I 240
30 942 t.1 0. 1 5 2.40
31 973 U 0.01 5 I 2.40
32 1004 a 0.01 6 I 2.40
33 1035 it 0.02 i (1 2.38
34 1066 t) 0.05 Z i I 2.40 I lated ittin .
35 1098 t~ .02 I 2.40
6 1129 U 0.01 i 1 .40
37 1160 tt 0.02 10 1 2.40
8 1191 ~l 0.03 12 ~ 2.41
39 1222 U 0.02 1 ~ I 2.40
40 1253 a 0.02 10 ~ 2.40
41 1285 l1 0.00 ~' ~' 2.40
42 1316 I t 0.00 I I 2.41
43 1347 !1 0.00 I 2.40
44 1378 It 0 (t 1 2.39
45 1409 ~ ~ 0.00 ~' I 2.40
46 1441 ~ ~ 0.02 t3 I 2.39
47 1472 ~ ? 0.01 -1 I 2.39
48 1504 t1 0. 2 I U I 2.39
49 1536 U 0.01 2.40
Penetration Body
Metal Loss Body
Page 1
• •
PDS REPORT JOINT TABULATION SHEET
Pipe: 2.875 in 6.5 ppf J-55 EUE 8RD Well: 1 R-09
Body Wall: 0.217 in Field: Kuparuk
Upset Wall: 0.322 in Company: ConocoPhillips Alaska, Inc.
Nominal I.D.: 2.441 in Country: USA
Survey Date: March 22, 2008
Joint
No. Jt. Depth
(Ft.) I'~~n.
UI~~E t
(In,.) Pen.
Body
(Ins.) Peen.
% Medal
I os~
",'~~ Min.
LD•
(Ins.)
Comments Damage Profile
(% wall)
0 50 100
50 1567 t~ 0.01 5 I 2.39
51 1598 t) .01 d I 2.40
52 1629 (t 0.01 6 I ' .39
53 1660 t t 0.01 3 (~ 2.39
54 1692 a 0.01 3 I 2.39
55 1723 a 0.01 ; i a 2.39
56 1755 t) 0.10 a5 .39 Isolated ittin .
56.1 1786 u 0 U n 2.31 S SV
57 1795 tt.U; .07 33 I 2.36 Lt. De osits. Pitt n in u
5 .1 1826 u 0 0 (~ N A GLM 1 No eviation
58 1833 U 0.01 3 i'~ 2.38
59 1864 l ~ 0.00 t ~ i i 2.39
60 1896 t) 0 0 i 2.39
61 1928 O 0.01 3 tt 2.39
62 1959 U 0 04 17 I 2.39 Shall w 'tti
63 1991 a 0.00 1 t I 2.38
64 2022 0 0.01 5 U 2.38
65 2053 a 0.0 I t3 1 2.39 Shallow it ~n .
66 2085 t) 0.09 43 -1 2.39 Line corm ion. Lt. De sits.
67 2 17 0 0.09 ~2 .39 Isolated ittin .
68 2148 t t 0.08 3~) 2. 7 Isolated ittin Lt. a osits.
69 2180 t~ 0.10 -!(~ 2.38 Line corrosion.
70 2 11 0 0.08 37 2.3 Isolated it'n .
71 2243 0 0.08 39 _' 2.39 Line corrosion.
74 a 0.06 29 ? .39 I I ted itti
73 2305 U 0.06 25 I 2.38 Isolated ittin .
74 337 a 0.06 2(i I .38 olated ittin Lt. De sits.
75 2368 a 0.08 36 2.38 Isolated ittin .
76 2399 U 0.08 35 _' 2.39 Isolated ittin .
77 2431 it 0.06 _'- i 2.39 Isolated ittin .
78 2462 t t 0.07 ~ ~1 2.39 Isolated ittin .
79 2494 i ~ 0.06 29 _' 2.39 Isolated ittin .
80 2525 t) 0.04 I t3 I 2.39 Shallow ittin .
81 2557 tl 0.06 ?(i I 2.40 Isolated ittin .
82 2588 tt .O6 _'(i I 2.39 Isolated ittin .
83 2620 t) U(, 0.10 ~17 2.40 Line corrosion.
84 2651 t) 0.10 46 t 2.40 Line corrosior.
85 2682 (~ 0.10 4F3 ~ 2.40 Isolated ittin .
86 2714 a 0.05 2 3 ~' 2.40 Isolated ittin .
87 2745 (~ 0.06 2S) _' 2.40 Isolated ittin .
88 2776 U 0.09 43 _' 2.40 Isolated i ti
89 2807 0 0.03 12 I 2.39
90 2839 ~~ 0.08 36 2.40 Is late ittin .
91 2870 t) 0.07 31 2.40 Isolated ittin .
92 2901 U 0.13 61 4 2.40 Isolated ittin .
93 2932 U 0.02 11 t 2.40
94 2964 U 0.04 1 t3 1 2.40 Sh~ Ilow ittin .
95 2995 t~.U6 0.12 i3 4 2.41 Isolated ittin .
96 302 7 ~ ~ 0.03 12 I 2 41
97 3058 0.03 16 ~' 2.41 Shallow ittin .
Penetration Body
Metal Loss Body
Page 2
•
PDS REPORT JOINT TABULATION SHEET
Pipe: 2.875 in 6.5 ppf J-55 EUE 8RD Well: 1 R-09
Body Wall: 0.217 in Field: Kuparuk
Upset Wall: 0.322 in Company: Conoco Phillips Alaska, Inc.
Nominal I.D.: 2.441 in Country: USA
Survey Date: March 22, 2008
Joint
No. )t. Depth
(Ft.) I'c~n.
I ll~set
(Ins.) Pen.
Body
(Ins.) Pen.
% Mc•lal
I oss
"r~~ Min.
LD•
(Ins.)
Comments Damage Profile
(% wall)
0 50 100
98 3090 O 0.03 14 1 2.40
99 3121 U.U' 0.09 43 ? 2.41 Isolated ittin .
100 3152 t) 0.05 a i _' 2.41 Isolated ittin .
100.1 3183 t) 0 U tt N GLM 2 Latc ~ 9:30
101 3190 U 0.07 92 2.39 Isolated ittin .
102 3221 O 0.10 44 2.41 Isola ed ittin .
103 3253 U.t)5 0.06 2F3 2.41 Isolated itUn .
104 3284 l) 0.07 ;t) 2.40 Isolated ittin .
105 3315 t) 0.09 4U 2.38 Isolated ittin .
106 3347 U 0.08 37 2.40 Isolated ittin .
107 3378 U 0.10 -1-t 2.41 Isolated ittin .
108 3409 i) 0.05 _' 1 I 2.39 Isolated ittin .
109 3440 (~ 0.08 ;' -l 2.39 Isolated ittin .
110 3471 t) 0.07 34 ~ 2.38 Corrosion.
111 3503 u.Ub 0.03 12 1 2.39 Pittin in u set.
11 3534 U 2 ti i) 2.40
113 3565 t) 0.01 I 2.39
114 3596 ! 1.1 i ~ 0.10 ~4' ~ t 2.39 Pittin in u set.
115 3627 U 0.10 -1' 2.40 Isolated i tin .
116 3658 U 0.09 41 -: 2.40 Lin corrosion.
117 3690 t).tu~ 007 3Z .40 Isolated i tin .
118 3721 E) 0.01 4 I 2.40
119 3752 t ).t )6 0.04 I Ei I 2.39 Sha low corrosi n.
120 3784 U 0.02 1 U I 2.40
1 3815 l).O5 0.0 ~t~ I .37 I I' e it i
122 3847 U 0.06 2E~ I 2.39 Isolated ittin .
123 3878 U 0.03 1.5 I 2.40 Shallow ittin .
124 3910 t).t)`) 0.09 43 Z 2.40 Shallow ittin .
125 3941 U 0.04 ~O 1 2.41 Isolate ittin .
126 3972 t) 0.07 ; ~ 2.40 Isolated ittin .
127 4003 t).UP3 0.05 ~3 2.39 Isolated ittin .
128 4034 t) 0.11 5 f 2 2.39 Isolated ittin .
129 4065 U 0.10 ~16 _' 2.39 Isolated ittin .
130 4096 E) 0.08 ,5 2.39 Isolated ittin .
1 1 4127 U 0.07 al 2.40 Isolated itti
132 4158 t) 0.06 2~) _' 2.38 Isolated ittin .
32.1 4189 U 0 E) E) N A GLM 3 Latch ®11:30
133 4195 a 0.07 ;U ~' 2.38 Isolated itti
134 4226 a 0.08 t5 _' 2.39 Isolated ittin .
135 4258 a 0.03 13 1 2.41 Sli ht Bucklin .
1 6 4289 t) 0.10 46 ; 2.39 Isolated ittin .
137 4320 t ).U6 0.04 21 1 2.39 Isolated ittin .
138 4351 U 0.06 26 1 2.39 solate ittin .
139 4382 !) 0.02 1 U I 2.39
140 4414 tt 0.01 6 1 2.39 Sli ht Bucklin .
141 4445 t~ 0.05 '~' _' 2.39 Isolated ittin .
142 4476 U 0.10 47 ~ 2.39 Corrosion.
143 4508 U 0.10 4i ~ 2.39 Isolated ittin .
144 4539 a 0.06 16 I 2.39 Isolated ittin .
145 4571 ! ~ 0.10 46 2.40 Isolated ittin .
_ Penetration Body
Metal Loss Body
Page 3
•
PDS REPORT JOINT TABULATION SHEET
Pipe: 2.875 in 6.5 ppf )-55 EUE 8RD Well: 1 R-09
Body Wall: 0.217 in Field: Kuparuk
Upset Wall: 0.322 in Company: ConocoPhillips Alaska, Inc.
Nominal I.D.: 2.441 in Country: USA
Survey Date: March 22, 2008
Joint
No. Jt. Depth
(Ft.) I'en.
ulsel
(Irn.l Pen.
Body
(Ins.) Pen.
% Nlctal
I<s~
,~~ Min.
LD•
(Ins.)
Comments Damage Profile
(%wall)
0 50 100
146 4602 tl 0.08 3 Z 2.38 Isolated ittin .
147 4 3 tl.Ut, 0.07 31 2.39 Isolated ittin .
148 4665 U 0.10 45 ! 2.39 Is lated ittin .
149 4697 l1 0.10 4ti ~' 2.39 Isolated ittin .
150 4727 t) 0.09 ~12 Z 2.40 Isolated ittin .
151 4759 l) 0.07 4 ~' .39 I olated ittin .
15 4790 t~ 0.07 3_' ~' 2.39 Isolated ittin .
153 4822 t? 0.07 35 ~' 2.41 Isolated ittin .
154 485 tl 0.10 47 3 2.38 Isolate ittin .
154.1 4884 l1 0 U tl N A GLM 4 Latch ®12:30
155 4891 a 0.08 t<) ~' .39 Sli ht Bucklin .Isolated ittin .
156 492 t) 0.05 ~'S ~' .38 Isolated ittin .
157 4953 U 0.09 4t1 _' 2.39 Isolated ittin .
158 4984 tl 0.06 ?(~ I 2.37 Isolated ittin Lt. De sits.
159 5016 a 0.06 2v I 2.38 Isolated ittin .
160 5046 a 0.09 4Z ~' 2.40 Isolated itti Lt De sits.
161 5078 U 0.04 I?3 I 2.37 Shallow it i Lt. De sits.
162 5110 tl 0.0 L3 I 2 38 I olated ittin t De sits.
163 5141 tl 0.03 16 I 2.39 Shallow ittin .
164 5172 U 0.05 22 1 2.39 Isolated ittin .
165 5204 t) .16 71 ; 2.39 Isolated ittin .
166 523 tl 0.05 21 I .38 Isolated ittin .
167 5266 U 0.05 11 I 2.38 Isolated itti
168 5297 l1 0 O U 2.39 Sli ht Bucklin .
68.1 53 t? 0 ) U N A M 5 at 1:3
169 5335 tl 0.00 1 I) 2.38 Bucklin .
170 5367 a 0.07 3U 2.3 I olated ittin .
171 5398 (1 0.00 Z U 2.38
172 5430 O 0.00 ? t~ .38 Lt. De osits.
173 5462 (1 0.00 2 u 2.39 Bucklin .
174 5493 U 0.01 4 I 2.39
175 5524 t? 0.04 1') I 2.40 Shallow corrosion.
176 5556 ~? 0 U t? 2.36 Lt De osits.
177 5587 u 0 O a 2.39 Bucklin .
178 5618 a 0.09 41 2.37 Corrosion.
179 5649 t? 0.04 I ~) I 2.38 Shallow ittin .
180 5681 a 0.00 1 l) 2.39 Bucklin .
181 5712 t) 0.00 1 i) 2.38
181.1 5744 (I 0 U u N A GLM 6 Latch Ca3 3:00
182 5750 tl 0.01 7 u 2.38 Bucklin .
183 5782 tl 0 u u 2.37
184 5814 U 0.01 3 ! ? 2.39
185 5845 U 0 tl t? 2.38 Bucklin .
186 5877 tl 0.01 ~ n 2.40
187 5907 U 0.01 4 t I 2.38
188 5939 U 0.01 2 t? 2.37 Bucklin .
189 5971 (t 0 tl t? 2.37
190 6002 U 0 U u 2.37 Lt. D osits.
191 6033 tl 0 tl 2. 8 B cklin .
192 6064 ! ? 0.01 i 2.40
Penetration Body
Metal Loss Body
Page 4
PDS REPORT JOINT TABULATION SHEET
Pipe: 2.875 in 6.5 ppf J-55 EUE 8RD Well: 1 R-09
Body Wall: 0.217 in field: Kuparuk
Upset Wall: 0.322 in Company: ConocoPhillips Alaska, Inc.
Nominal I.D.: 2.441 in Country: USA
Survey Date: March 22, 2008
Joint
No. Jt. Depth
(Ft.) P~~n.
Ul,tii,l
Iln~.) Pen.
Body
(Ins.) I'~~n.
% Mc~l,il
I o~:~
°~~, Min.
LD•
(Ins.)
Comments Damage Profile
(%wall)
0 50 100
193 095 t) 0.01 ~ t) 2.38
194 6126 a 0.01 S tl 2.39 Bucklin .
195 6157 U 0 U u 2.38 Lt. De osi
196 6189 u.uts 0.01 (~ ~ ~ 2.38 Lt De osits. Pi tin in u et.
196.1 6219 t~ 0 U ~) N A GLM 7 L tch 9:00
197 6226 l~ 0.05 '2 I 2.35 Isolated ittin I_t. De sits.
198 6257 i~ 0.00 1 ~~ 2.38 Bucklin .
199 6288 tt 0.04 1 i I 2.38 Line shallow corrosion.
200 6320 tt 0.00 2 ~? 2.38
201 6350 U 0 0 U .38 Buckl~n .
202 6381 t) 0.01 ; n 2.37
203 6413 t) 0.01 .3 a 2.37
204 6444 tt 0.03 12 a 2.38 Bucklin .
205 6476 U 0 U U 2. 8 Lt. De osits.
206 6507 t ~ 0.01 1 2.37
207 6538 O 0. 8 5 I .38 Iso aced i in .
208 6570 U 0.01 U 2.38 Bucklin .
09 6601 U 0.03 1 ~ U 2.37
210 663 u 0 l) tl .36 t. De osits.
21 6664 t~ 0.00 1 t~ 2.37 Bucklin Lt. De sits.
11.1 6694 t) 0 tl U N A GLM 8 Latch ~ 5:30
212 6701 U 0.01 ~ ~ 2.34 Lt. De osits.
213 6733 tt 0 t> t! 2.35 Bu klin .
214 6764 U 0.01 ~ U 2.38 Lt. De osits.
2 679 U 0 ) U 2.37 Lt. a sits.
216 6826 (~ 0.01 4 tl 2. 7 Bucklin .
217 6858 t~ 0.02 7 tl 2.39 Bucklin .
218 6889 (~ 0 U U 2.37 Lt. De osits.
219 6921 t~ 0.01 6 tt .37 ucklin .
22 6952 t~ 0 u ~ i 2.35 Lt. De osits.
221 6984 t~ 0.01 -i t i 2.37 Bucklin .
222 7016 a 0.01 - u 2.38 Bucklin .
223 7047 l) 0.04 1 f3 I 2.39 Shallow ~ttin .
224 7078 It 0 l) t~ 2.37 Lt. De osits.
225 7110 l) 0.01 4 t) 2 36 t. e osi
226 7141 tt 0 U ti 231 Lt. De osits.
26.1 7171 t ~ 0 t ~ ~ ~ N A GLM 9 Latch ~ 2:00
227 7179 U 0.09 41 2.36 Isolated itti Lt. De sits.
228 7210 t~ 0.02 I i ~ ~ ~ 2.38 Bucklin Lt. De sits.
229 7241 tl 0.05 11 I 2.36 Isolated ittin Lt. De sits.
230 7273 U 0 U tt 2.37 Bucklin .
231 7304 U 0 It U 2.36 Bucklin Lt. De sits.
232 7334 0 0 U U 2.34 Bucklin Lt. De sits.
233 7366 U 0.03 12 t) 2.36 Bucklin Lt. De sits.
23 7397 t) 0.02 IU t) 2.38 B cklin Lt. De sits.
235 7428 tt 0.00 ? t) 2.37 Bucklin Lt. De sits.
236 7460 ~~ 0 t) i~ 2.36 Bucklin Lt. D sits.
237 7491 t i 0 U t! 2.38 Bucklin .
238 7522 ~ ~ 0 0 27 I 2.33 Isolated ittin . L . De sits.
238.1 7551 t~ 0 t) +'~ N A GLM 10 Latch @ 7:30
i Penetration Body
Metal Loss Body
Page 5
• •
PDS REPORT JOINT TABUL ATION SHEET
Pipe: 2.875 in 6.5 ppf J-55 EUE 8RD Well: 1 R-09
Body Wall: 0.217 in Field: Kuparuk
Upset Wall: 0.322 in Company: ConocoPhillips Alaska, Inc.
Nominal I.D.: 2.441 in Country: USA
Survey Date: March 22, 2008
Joint
No. Jt. Depth
(FtJ Pen.
lJpset
Iln~.) Pen.
Body
(Ins.) Pen.
%> Metal
Loss
"'~~ Min.
LD•
(Ins.)
Comments Damage Profile
(%wall)
0 50 100
239 7562 U 0 t1 U 2.33 Bucklin Lt. De sits.
39.1 7594 c1 0.01 ~ I 2.40 PUP
239.2 7599 It 0 U U 2.30 'OE' SBR
2 9.3 7619 t) 0 (> t t 2.35 HRP-I-SP Packer
240 7627 U 0.00 t1 a 2.38
240.1 7 58 c ~ 0 t t U 2.25 D Ni le With No Go
241 7659 t t 0 0 u 2.39
241.1 7689 (~ 0 O tt 2.39 Tubin Tail
Penetration Body
Metal Loss Body
Page 6
~ ~ ~ ~ ~ ~ ~ ~ ~ i ~ ~ ~ ~ ~ ~ ~ ~ ~
~~ _ ~`'~ PDS Report Cross Sections
Well: 1 R-09 Survey Date: March 22, 2008
Field: Kuparuk Tool Type: UW MFC 24 No. 214320
Company: ConocoPhillips Alaska, Inc, Tool Size: 1.69
Country: USA ,tiro. of Fingers: 24
Tubin 2.875 ins 6.5 f 55 EUE 8RD Analyst: M. Lawrence
Cross Section for Joint 165 at depth 5232.013 ft
Tool speed = 43
Nominal ID = 2.441
Nominal OD = 2.875
Remaining wall area = 97
Tool deviation = 50 °
Finger 10 Penetration = 0.155 ins
Isolated Pitting 0.16 ins = 71% Wall Penetration HIGH SIDE = UP
•i
Cross Sections page 1
~1V _ ~~ PDS Report Cross Sections
b1/ell: 1 R-09 Survey Date: March 22, 2008
Field: Kuparuk Tool Type: UW MFC 24 No. 214320
Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69
Country: USA No. of Fingers: 24
Tubin 2.875 ins 6.5 f •55 EUE 8RD Anal st: M. Lawrence
Cross Section for Joint 92 at depth 2905.943 ft
Tool speed = 43
Nominal ID = 2.441
Nominal OD = 2.875
Remaining wall area = 97 °!°
Tool deviation = 23 °
Finger 3 Penetration = 0.133 ins
Isolated Pitting 0.13 ins = 61% Wall Penetration HIGH SIDE = UP
•
•
Cross Sections page 2
°"-"~ PHILLIPS Alaska, Inc. KRU 1R-os
1R-04 (PTD 185-178) & 1R-09~TD 185-095) Failed MIT diagnostics update Page 1 of 1
Maunder, Thomas E (DOA)
From: NSK Problem Well Supv [n1617@conocophillips.com]
Sent: Monday, May 14, 2007 8:01 PM
To: Thomas Maunder; James Regg
Subject: 1 R-04 (PTD 185-178) & 1 R-09 (PTD 185-095) Failed MIT diagnostics update
Tom & Jim,
Initial diagnostics were completed on 1 R-04 (PTD 185-178) & 1 R-09 (PTD 185-095) on 5/11/07. Tbg and inner
casing packoff testing passed for both wells, ruling out the packoffs as the leak path. The IA leak rate for 1 R-04
was estimated at 9 gpm @ 2200 psi. The IA leak rate for 1 R-09 was estimated at 9 gpm @ 2460 psi. 1 R-04 was
SI and freeze protected on 5/12/07.
Additional wellwork will be completed to attempt to locate the leak fpr repair. If repair is not possible and 2
barriers are confirmed, a request for administrative approval will be submitted. Both wells will remain SI until
repaired or an AA is obtained.
Please let me know if there are any questions.
Marie McConnell
Problem Well Supervisor
(907) 659-7224
n 1617 @conocoph i l l i ps. com
From: NSK Problem WeII Supv
Sent: Friday, May 11, 2007 8:28 AM
To: Thomas Maunder'; James Regg; 'Robert Fleckenstein'
Subject: 1R pad MITs 5-9-07
Tom, Jim, & Bob,
Attached are Injector MITs for 1 R pad witnessed by Bob Noble on 5-9-07.
All MITs passed except for 1 R-04 & 1 R-09. Both wells have been added to the failed MIT report for May. 90 day
TIO plots and schematics for both wells are attached. Diagnostics are planned this morning for both wells to test
the tbg packoffs and measure the leak rates. There is a chance that leak is in the packoff off and tightening the
packoff may result in a passing MIT. 1 R-09 has been SI since last fall waiting for flowline repair. 1 R-04 is on
water injection. I'll send an update on the plan forward for these wells after today's testing/repair attempt is
complete.
Please let me know if there are any questions.
Marie McConnell
Problem WeII Supervisor
(907) 659-7224
n 1617@conocophillips.com
« File: MIT KRU 1 R 05-09-07.x1s »
« File: 1 R-04 90 day TIO plot 5-10-07.gif » « Fite: 1 R-04.pdf » « File: 1 R-09 90 day TIO plot 5-10-07.gif
» « File: 1 R-09.pdf »
12/23/2008
.
.
MEMORANDUM
State of Alaska
Alaska Oil and Gas Conservation Commission
TO:
Jim Regg ~ '
P.I. Supervisor I~êff 0{4( 07
DATE: Fnday. May 11. 2007
SUBJECT: Mechanical Integrity Tests
CONOCOPHILUPS ALASKA []\;C
IR-09
KUPARUK RlV UNIT I R-09
Src: Inspector
Pl~
S·-,. 0-,
\16
FROM: Bob Noble
Petroleum Inspector
NON-CONFIDENTIAL
Reviewed By:
P.I. Suprv 58f2-
Comm
Permit Number:
185-095-0
Inspector Name: Bob Noble
Inspection Date: 5/9/2007
Well Name: KUPARUK RIV UNIT IR-09
Insp Num: mitRCN07051 0204728
Rei Insp Num:
API Well Number: 50-029-21350-00-00
Packer
Depth
Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
TIAi--~ì- 1970 I 1870 T" 1780 r I
,_~_~__~---'--------- ~ __~_ --------L-_~__
I OA I 0 I. ~~~_.:"..~ I . ~_~__~_..
Tubin-gr-"~~-;' 1100 1100 I 1100 I I
i ____~_.~_~_____._____~<_
Well I lR-09 !Type Inj. 'N! TVD I 6309
, I: I
P.T.D¡ 1850950 ITypeTest I s~~ I Test ~L_ 1577.25
Interval 4YRTST P/F F./
-===.c _.~.
Notes: We]] was shut in
LoSJ- IOc¿t;> d¿{/ì¡ry 3D .\-tvt:v-k-bs,+, ~('(('¡ti'€.
-to shf,.ÝI'~ )
sCANNED JUN 0 6 2007
Friday, May II, 2007
Page I of I
lR pad MITs 5-9-07
.
Tom, Jim, & Bob,
Krl« J 1Z -0 c¡
PrO tì- fibS - VCt5
Attached are Injector MITs for 1R pad witnessed by Bob Noble on 5-9-07.
All MITs passed except for 1R-04 & 1R-09. Both wells have been added to
the failed MIT report for May. 90 day TIO plots and schematics for both
wells are attached. Diagnostics are planned this morning for both wells
to test the tbg packoffs and measure the leak rates. There is a chance
that leak is in the packoff off and tightening the packoff may result in
a passing MIT. 1R-09 has been SI since last fall waiting for flowline
repair. 1R-04 is on water injection. I'll send an update on the plan
forward for these wells after today's testing/repair attempt is
complete.
Please let me know if there are any questions.
Marie McConnell
Problem Well Supervisor
(907) 659-7224
n1617@conocophillips.com
SCANNED MAY 1 6 2007
«MIT KRU 1R 05-09-07.xls»
«lR-04 90 day TIO plot 5-10-07.gif» «lR-04.pdf» «lR-09 90 day
TIO plot 5-10-07.gif» «lR-09.pdf»
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5/11/2007 1 :48 PM
234x776
TIO
90
R-09
.
KRU 1 R-09
SSSV API: 500292135000 w~1'! INJ Anç¡le @ TS: '44 de¡:¡ @ 7671
(1790-1791, SSSV Type: TRDP Oriç¡ Completion: 6/30/85 . --------- Angle @ TD: . 43 deç¡ @ 8225
00:2.875) Annular Fluid: Last W/O: Rey Reason: Taç¡ fill by ImO
Reference Log: Ref Log Date: --- ._. Last Update: 5/9/01
Last Taa: 7932 TD: 8225 ftKB
~ate: 5/3/01 -- MaXHole~
Description Size Top Bottom I TVD Wt Grade Thread
16.000 0 115 ! 115 65.00 H-40
SUR. :;ASING 9.625 0 ! 4039 I 3792 36.00 J-55
PRnn (''''''','''''' 7.000 0 I 8210 I 6741 26.00 J-55
I Size Top I Bottom I TVD I Wt I Grade I Thread
I 2.875 0 I 7689 I 6361 I 6.50 I J-55 I EUE 8RD
Interval I TVD ! Zone Sta!~. Ft SPF Date ' Type Comment
7728 - 7768 I 6389 - 6418 I C-1 ,UNIT B , 40 4 4/10/89 APERF 21/8" EnerJet; 0 deg. ph; 17
i I shots of 80 failed to fire
I-a -,
7896-7904_L 6511-6516 i A-4 4 8/4/85 IPERF 4" HJ 11 Csç¡ Gun; 90 deç¡. ph
7912 - 7944 r 6522 - 6546 1 A-3 I 32 4 8/4/85 IPERF-- 4" HJ 11 Csa Gun; 90 dea. oh
7'?i75 - 7980 -¡--656a:--6572 I A-2 5 4 8/4/85 IPERF 4"HJ II~
St MD TVD Man Man YMfr Y Type Y OD I Latch Port TRO Date Ylv
Mfr Type Run Cmnt
1 1830 183Ó- ---=-----.- - KBMG DMY 1.0 BK O.ÓOO 0 6/3/88
Cameo i
2 3185 3122 Cameo KBMG DMY l _ 1.~----t_BK_ 0.000 0 6/3/88
3 4189 3900 Cameo KBMG DMY I 1.0 L_B_IS__. 0.000 0 6/3/88
4 4884 4396 Cameo KBMG DMY 1.0 BK 0.000 0 6/3/88
5 I 5328 4712 Cameo KBMG DMY 1.0 BK I 0.000 0 I 6/3/88
6 5743 5008 Cameo KBMG DMY 1.0 BK '--0.000 - 0 6/3/88
7 6219 5345' Cameo KBMG DMY 1.0 BK lO.ooo 0 6/3/88
8 6694 56711 Cameo KBMG DMY 1.0 BK 0.000 0 6/2/88
9 7172 . CC~ KBMG DMY 1.0 BK 0.000 0 6/2/88
599Li_ ame,o..
10 7553 6263 , Merla .- ,GPD DMY 1.5 RK I 0:'000 0 6/11/93
<IEU'IEf !>v)(
º.!œ!!1. TVD __'!y~ Description _. I ID
1790 1790- SSSV Cameo'TRDP-1A-SSA' , 2.312
Failed Closure Tests (2/7/95)
Failed to LockOut ßL9I..9§L
7600 6296 SBR I Cameo 'OEJ' 2.297
7617 6309 PKR ! Cameo 'HRP-1-SP' 2.347
7656 6337 NIP Cameo 'D' Nipple Nº_~º_ 2.250
7689 6361 TTL ! 2.441
7689 6361 SOS I Cameo 2.441
Depth I ...-º~s~ri'p~___ I Comment
7986 11 1/2" DMY____. .J Empty Pocket; Fell to Rathole
SBR
(7600-7601,
00:2.875)
PKR
(7617-7618,
00:6.156)
NIP
(7656-7657,
00:2.875)
TUBING
(0-7689,
00:2.875,
10:2.441)
mmm ..--.
Perf ..m.
(7728-7768) ..----
Perf = =
(7896-7904) .- -----.
::::.:.::. -.:::
Perf - -
(7912-7944) -----
Perf :::::
(7975-7980) mmm
- -
,
.
.
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
Mechanical Integrity Test
Email to:Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us
OPERATOR:
FIELD I UNIT I PAD:
DATE:
OPERATOR REP:
AOGCC REP:
ConocoPhillips Alaska Inc.
Kuparuk/KRU/1 R
05/09/07
Greenwod-Rogers Ilvesl Bates
Bob Noble
0\ Il \ 01
íZ-aíJ
-?
Packer Oepth Pretest Initial 15 Min. 30 Min.
Well!1 R-03A I Type Ini. I W TVO I 6,403' Tubinq 2240 2240 2240 2240 Interval I 4
p.T.o.1200021 0 ! Type test ! P Test psi! 1601 Casing 770 1650 1650 1650 P/F! P
Notes: OA 800 830 830 830
Well!1 R-04 I Type Inj.1 W TVO I 6,384' Tubing 1900 1900 1900 1900 Interval 4
p.T.o.11851780 I Typetestl P Test psi! 1596 Casing 825 2500 2060 2010 PtF F
Notes: OA 700 700 700 700
Well!1 R-06 Type Inj. N TVO I 6,266' Tubing 1190 1190 1190 1190 Interval 4
P.T.O.!1850710 Type test P Test psi 1567 Casing 530 1950 1910 1900 PtF P
Notes: Sllong term since 5/7/07 for flowline repair OA 20 20 20 20
Well!1 R-08 Type Ini. W TVO 6,380' Tubing 2075 2075 2075 2075 Interval I 4
P.T.O.11850730 Type test P Test psi 1595 Casing 1100 2600 2600 2600 PtF P
Notes: OA 750 810 810 810
We1l11R-09 Type Ini. N TVO 6,309' Tubing 1100 1100 1100 1100 Interval 4
P.T.O.!1850950 Type test P Test psi! 1577 Casing 1210 1970 1870 1780 P/F F
Notes: Sllong term since 9/26/06 for flowline repair OA 0 0 0 0
Weill 1R-1 0 Type Ini. N TVO 6,257' Tubing 1300 1300 1300 1300 Interval 4
p.T.o.11850960 Type test P Test psi 1564 Casing 860 2075 2060 2055 P/F P
Notes: Sllong term since 9/26/06 for flowline repair OA 220 220 220 220
We1l11R-13 ! Type Inj.! W TVO ! 6,420' Tubing 2150 2150 2150 2150 Interval I 4
p.T.o.11851500 ! Type test! P Test psi! 1605 Casing 1060 1650 1620 1620 P/F! P
Notes: Bled OA to 500 psi for start of test. OA 1000 500 500 500
We1l11R-15 I Type Inj.! W TVO ! 6,317' Tubing 1750 1750 1750 1750 Interval 4
p.T.o.11851520 ! Type test I P Test psi! 1579 Casing 1280 2500 2450 2440 P/FI P
Notes: OA 650 650 650 650
We1l11R-17 I Type Inj.1 G TVO ! 6,462' Tubing 3400 3400 3400 3400 Interval 4
P.T.O.11911140 I Type test I P Test psi! 1616 Casing 1470 2500 2440 2420 P/F P
Notes: OA 760 760 760 760
We1l11R-18 I Type Inj.1 N TVO ! 3,182' Tubing 660 660 660 660 I nterval 4
p.T.o.11910870 I Type test! P Test psi! 1500 Casing 40 1500 1500 1500 P/FI P
Notes: IA&OA are common due to circulation string. OA 40 1500 1500 1500
Class" disposal well. Injection SI during test.
MIT Report Form
BFL 9/1/05
MIT KRU 1 R 05-09-07-1.xls
We1l11R-19A I Type Inj. ~TVO I 6,548' Tubing 1950 195-'950 1950 Interval! 4
p.T.o.11910850 I Type test I P I Test psil 1637 CasinQ 750 2590 2590 2590 P/FI P
Notes: OA 450 610 610 610
Weill 1 R-23 I Type Inj. W I TVO I 6,713' TubinQ 2100 2100 2100 2100 Interval 4
p,T.o,11911010 I Type test P I Test psil 1678 Casing 1030 2650 2580 2560 P/FI P
Notes: OA 360 500 500 500
We1l11R-26 I Type Ini.1 W I TVO I 6,535' Tubing 2150 2150 2150 2150 Interval I 4
p.T.o.11910920 Type testl P I Test psi 1634 Casing 1360 2650 2650 2650 P/FI P
Notes: OA 690 690 690 690
We1l11R-32 I Type Ini.1 W I TVO I 6,253' Tubing 2075 2075 2075 2075 Interval! 4
P.T.O. 1941460 I Type test I P I Test psi I 1563 Casing 660 2610 2590 2580 P/F P
Notes: OA 380 610 610 610
We1l11R-33 I Type Ini.1 W I TVO I 6,596' Tubing 1900 1900 1900 1900 Interval! 4
PTO, 1941560 I Type test I P I Test psi I 1649 Casing 680 2800 2780 2780 P/FI P
Notes: OA 0 225 225 225
D = Drilling Waste
G=Gas
I = Industrial Wastewater
N = Not Injecting
W = Water
M = Annulus Monitoring
P = Standard Pressure Test
R = Internal Radioactive Tracer Survey
A = Temperature Anomaly Survey
D = Differential Temperature Test
I = Initial Test
4 = Four Year Cycle
V = Required by Variance
T = Test during Workover
0= Other (describe in notes)
MIT Report Form
BFL 9/1105
MIT KRU 1 R 05-09-07 -1.xls
RECL,VED
STATE OF ALASKA
ALASKA Oil. AND GA~ COMSERVATION COMMISSION
NOV 28 199~
AJaska 011 & Gas Cons. Commission
Anchorage
FIELD ! UMT t PAD:. KR, F - KRU - CPF ~ DATE:.
i I i II 1111 ] ,1 , , 1. :
1 _.1 l ........... l-,*.Om ! .... r,~ ~ 14,. ]-_{a I '~..o
THIS W~.L ~ USa3 FO~ D~i=OSAL OF 0~~ FLU~ .... ' ....
11~.~7 $ I DIESEL' ~ 7" 2725
IMEHT~: PRETEST ~E ~ED FOR 30 M~ PFilORI"(3 TEST. - ........
, i i -- - i i i _ _ k _ -- i i,ll : il -: iijii __ iii i iii i - , ii i i I ii iiii
· l'UallO ~ON FLUID:
IDW.~ wR'rER t1~1.
~ALT WATER
MISCIBLE INJ.
~=iN.~~ SCANNED DEC ! 9 213D2
~ NOT ~TII~
ANNUl. AR FLUID: P.P.G. Grad, WELL 'FEET:
DIE~=L ~.7J ~.35 Initial
GLYCOL j _ ~.t~0- 4 - Yea~ X
SALT WATER 6 00 Wo~r
DRILLING ~ - 0-00 Other
OT~ER ,, O.~ '"
c
AOG(X:;:-REP SIGNATURE BOS~YD.
.1 · iii, i IIIii II I i
OPERATOR REP S;GI~TURE
JATIF2EX).XL$
~EMORAF'r)UM
A;~,ASi~(A OIir;~,~,;D G,
C. V. Chatterton
Chairman
TH RU:
Stat~ of..,.Alaska'
m,.. mscovA .. ,-.
DATE: November-'20, 1986
FILE NO.: D.ADA. 63 ._ ' ' '
.·
·
Lonnie C. Smith TELEPHONE NO.: ...
.Commissioner ' '" ".' ' "'.-
.SUBJECT: Mech Integrity Test "
ARCO KRU 1R-9,& 2U-5 ' , .
Doug Amos '" ' Kuparuk River Field ' "
Petroleum Inspector . : ---
· :
.
Satur, day~ November 8. 1986: After witnessing the.BOP test at
ARCO s PBU L3-22 well I traveled to ARCO KRU to witness the MIT on
1R-9 & 2U-5 injection wells. Both wells were successfully tested
in accordance with AOGCC regulations 20 AAC 25.030(g), 25.412(c)
and 25.252(d), and Area Injection Order No. 2.
·
I filled out an AOGCC mechanical integrity test form for both
wells. These two forms are attached. .. ' .~
·
In summary, I witnessed the successful mechanical integrity test at
ARCO's KRU 1R-9 & 2U-5 water injectS, on wells.
FROM:
Attachments
"sCANNED DE d:-! ~' 20'~2
02-001 A ( Rev 10-84)
AIASKA OIL AND C..a,S CONSERVATION ~SSlOI'I
PRESS PRESS 'PRESS
I~TT].TNG ~ " 20 AAC 25.030(a)
~ 20 AA~ 25.412(c)
~ 20 AAg 25.252(d)
SCANNED DEC 1 ~ 2002
OIL AND GAS ~ ZRVATION ODM~SSION
MECHANICAL IlqrFLI~TY TEST
' pREtEST · STARI 15 MIN 30 MIN "
,p ,I TYPE OF PKR CASING TBG REQ '" TBG TIME TIME TIME -
W~II. *S __. ~ TVD SIZE/WT/GRADE SIZE TEST CSG TBG TBG TBG CflvlqEN~
~! *N FLIIID MD PRESS PRESS CSG CSG CSG
:.. PRESS PRESS PRESS
,&la~ ,, , 4-:~t¢ ~'..~ ~-: 4~' ....
_ .
I
I I II I1 I I I II I II
__ Illll I I I I I la
i I I I I I I I II II I I Illlll I ·
I Illl I
_
[ I ~ I II
I II II I I II I
II I I
I 11 I II
,a i i
..
I Ill II II I I II I I I
Ill III I
Ill Ill II I I I , II
' ' I I
II Ill II II II Illl II
*TUB~ INJE~ON FLUID:.
P - PRDI)UCE WATER IN3
S - SALT WATER IRJ
M -' MISC~ IR3ECTION
DR'ri I,ING ~
SCANNED DEC 1 9 2002,
~C WITNESS SIGNATURE
CGqPANY REP SIGNATURE
20 AAC ~.030 (a)
20 AAC 25.412(¢)
20 AAC 25.252(d)
STATE OF ALASKA
~ OIL AND ~ CONSERVATION ~MISSION
REPORT OF SUNDRY WELL OPERATIONS
1. Operations Performed: Operation Shutdown ~ Stimulate ~X Plugging
Pull tubing Alter casing Repair well
Perforate
Other
2, Name of Operator
ARCO Alaska. Inc.
3. Address
P. O. Box 100360, Anchorage, AK 99510
5. Type of Well:
Development
Exploratory
Stratigraphic
4. Location of well at surface
389' FSL, 216' FEL, Sec. 18, T12N, R10E, UM
At top of productive interval
1320' FSL, 1769' FWL, Sec. 18, T12N, R10E, UM
At effective depth
1338' FSL, 1561' FWL, Sec. 18, T12N, R10E, UM
At total depth
1408' FSL, 1400' FWL, Sec. 18~ T12N~ R10Ep UM
12. Present well condition summary
Total Depth: measured 8 2 2 5 feet
true vertical 6571 feet
6. Datum elevation (DF or KB)
RKB 83
7. Unit or Property name
Kuparuk River Unit
8. Well number
1 R-09
9. Permit number/approval number
85-95
10. APl number
50-029-21350
11. Field/Pool
Kuparuk River Oil Pool
feet
Plugs (measured) None
Effective depth: measured 81 2 0 feet
true vertical 6674 feet
Junk (measured) None
Casing Length Size
Structural
Conductor I 1 2' I 6"
Surface 3 9 9 8' - 9 5/8"
Intermediate
Production 81 7 5' 7"
Liner
Perforation depth: measured
7728'-7768',
true vertical
6388'-6417',
Cemented
230 SX CS II
1200 SX PF "E"&
375 PF "C"
300 SX Class G &
250 SX PF "C"
7896'-7904',
6510'-6516',
7912'-7944',
6522'-6545',
Measured depth
112'
4039'
8210'
7975'-7980'
6568'-6571'
Tubing (size, grade, and measured depth)
2.875", 6.5#, J-55 w/ tail @ 7689'
Packers and SSSV (type and measured depth)
PKR's: Camco HRP-1-SP ~ 7617'; SSSV: Camco TRDP-1A ~ 1790'
13. Stimulation or cement squeeze summary
Fracture stimulation of "A" Sands on 6/6/93.
Intervals treated (measured)
7896'-7904', 7912'-7944', 7975'-7980'
Treatment description including volumes used and final pressure
True vertical depth
112'
3792'
6740'
14.
R ¢ IV D
J LJ N _2 5 199,:3
,~laska Oil & Gas Cons. burnmission
Anchorage
Placed 200 MLBS of 16/20 and 12/18 ceramic proppant into formation~ fp was 7131 psi.
Representative Daily Average Production or In!ection Data
OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure
Prior to well operation
-0-
-0- 150 1300 2250
Subsequent to operation
-0-
-0- 1800 1400 2150
15. Attachments
Copies of Logs and Surveys run __
Daily Report of Well Operations X
16. Status of well classification as:
Oil Gas Suspended Service WAG Iniector
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Date
--orm 10-404 Rev 06/15/88
SUBMIT IN DUPLICATE
ARCO Alaska, In~-,~
WELL SERVICE REPORT
Subsidiary of Atlantic Richfield Compaq,.
' /'~- 2 I~'~'~,' . l'" =~':~~~
.
NGiNEER1NG
/
~1 CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK
Weather Temp. Chill Factor I Visibility J Wind Vel.
Report °F °FI~ miles
I
REPORT OF SUNDRY WELL OPERATIONS
1. Type of Request:
Operation Shutdown__ Stimulate __ Plugging Perforate _
Pull tubing Alter casing Repair well Pull tubing Other X
2. Name of Operator
ARCO Al~ke,, lng.
3. Address
P. O. Box 100360, Anchorage, AK 99510
4. Location of well at surface
5. Type of Well:
Development
Exploratory
Stratigraphic
Service
398' FSL, 216' FEL, Sec. 18, T12N, R10E, UM
At top of productive interval
1320' FSL, 3511' FEL, Sec. 18, T12N, R10E, UM
At effective depth
1338' FSL, 3719' FEL, Sec.18, T12N, R10E, UM
At total depth
1408' FSL, 3880' FEL, Sec. 18, T12N, R10E, UM
12.
Present well condition summary
Total Depth: measured 8 2 2 5' feet
true vertical 6571 ' feet
Plugs (measured)
6. Datum elevation (DF or KB)
RK$ 83 feet
7. Unit or Property name
Kuparuk River Unit
8. Well number
1 R-09
9. Permit number/approval number
85-9~/536
·
10. APl number
50-029-21350-00
11. Field/Pool
Kuparuk River Oil Pool
Effective depth: measured 81 20' feet
true vertical 6674' feet
Junk (measured)
Casing Length Size
Structural
Conductor 1 1 2' 1 6"
Surface 4039' 9 5/8"
Intermediate
Production 821 0' 7"
Liner
Perforation depth: measure
7896'-7904',
true vertical
6510'-6516',
Cemented
230 Sx CSII
1200 Sx PF"E"
375 Sx PF"C"
300 Sx Class G
250 Sx P F"C"
7912'-7944', 7975'-7980'
6522'-6545', 6568'-6571'
Tubing (size, grade, and measured depth)
2 7/8" J-55 6.5 #/FT @ 7689'
Packers and SSSV (type and measured depth)
Camco HRP-1-SP @ 7671', Camco TRDP-1A-SSSV @ 1790'
Measured depth
112'
4O39'
8210'
True vertical depth
112'
3792'
6740'
MD-RKB
TVD
-CEIVED
13.
Stimulation or cement squeeze summary
CONVERSION FROM OIL PRODUCER TO WATER INJECTOR.
Intervals treated (measured)
Treatment description including volumes used and final pressure
14.
Prior to well operation
, , Subsequent to operation
Reoresentative Daily Average Production or Injectign Data,
OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure
745 553 8
- 7264
Tubing Pressure
1171 180
1800 1970
15. Attachments
Copies of Logs and Surveys run
Daily Report of Well Operations
16. Status of well classification as:
Oil _ Gas Suspended
Service WATER INJ
17. I hereby.,~~4j, ~ ~~~~certify that the foregoing is true and correct to th~/~/~f. ~)/~ ~~~my knowledge.
Signed Title ~
Form 10-404 Et/er 06/15/88
SUBMIT1N DUPLICATE
pst~ , c~-F S'ATUS oEPORT DATE:
~. · LL~ ~ _ n
j .s.. .... s,~_.
J ? £ r-,...~
.~.
STATE OF ALASKA
ALASKA OILAND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
1. Type of Request:
12. Name of Operator
ARCO Alaska. In(~.
3. Address
Operation Shutdown__ Stimulate __ Plugging Perforate
Pull tubing Alter casing Repair well Pull tubing
P. O. Box 100360, Anchorage, AK 99510
x
Other
¸4.
5. Type of Well:
Development
Exploratory
Stratigraphic
Service
Location of well at surface
398' FSL, 216' FEL, Sec. 18, T12N, R10E, UM
At top of productive interval
1320' FSL, 3511' FEL, Sec. 18, T12N, R10E, UM
At effective depth
1338' FSL, 3719' FEL, Sec. 18, T12N, R10E, UM
At total depth
1408' FSL, 3880' FEL, Sec. 18, T12N, R10E, UM
12. Present well condition summary
Total Depth: measured
true vertical
6. Datum elevation (DF or KB)
RKB 83
7. Unit or Property name
Kuparuk River Unit
8. Well number
1 R-09
9. Permit number/approval number
{)5-95/9-261
10. APl number
50-029-21350-00
11. Field/Pool
Kuparuk River Oil Pool
feet
8 2 2 5' feet Plugs (measured)
6 5 71 ' feet
Effective depth: measured 81 2 0' feet Junk (measured)
true vertical 6674' feet
Casing Length Size Cemented
Structural
Conductor I 1 2' 1 6" 230 Sx CSII
Surface 4039' 9 5/8" 1200 Sx PF"E"
Intermediate 375 Sx PF"C"
Production 821 0' 7" 300 Sx Class G
Liner 250 Sx PF"C"
Measured depth
112'
4039'
8210'
True vertical depth
112'
3792'
6740'
Perforation depth: measure
7728'-7768', 7896'-7904', 7912'-7944',
true vertical
6388'-6418', 6510'-6516', 6522'-6545',
Tubing (size, grade, and measured depth)
2 7/8" J-55 6.5 #/FT @ 7689'
Packers and SSSV (type and measured depth)
Camco HRP-1-SP @ 7671', Camco TRDP-1A-SSSV @ 1790'
7975'-7980'
6568'-6571'
13. Stimulation or cement squeeze summary
MD-RKB
TVD
Perforated C Sands with 4 SPF and 0° phasing.
Intervals treated (measured)
7728' -7768'
Treatment description including volumes used and final pressure
14.
Representative Daily Average Production or Injection Data
OiI-Bbl Gas-Mcf water-Bbl Casing Pressure
Tubing Pressure
Prior to well operation
Subsequent to operation
602 1400 2475
3147 1460_ 2400
15. Attachments
Copies of Logs and Surveys run
Daily Report of Well Operations
16. Status of well classification as:
Oil Gas
Suspended
Service WAG INJ
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
S!gned//~.~ ~.~ Title Sr. Operations Engineer
Form 10-404 R/er 06/15/88
Date
SUBMIT IN DUPLICATE
ARCO Alaska,
SuC, sidiary of Atlantic Richfield Comb
_~,ONTRA~T(~,R'
HEMARKS
WELL SERVICE REPORT
/ 77~9~' ~o 27~ ~'
I-'J CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK
knots
ARCO~.Le~'-% Inc. ~) ~'~- '~- Orillsite Morning Report
CPF- /
Date ¢'-- ,- - g'? Time,2~4/¢'o Drillsite /¢
Status Production Well Status Gas Lift Status Shut-In
Well P.T. or TP Choke Temp Last H2S CSG Pressure PSI Gas Inj. Rate
# SI Zone PSI Bean °F WCO/0 PPM 7" 10" Temp MeterTotal MSCFD Hrs Reason
.
..
Total
Status Injection Well Status Shut-In
Well Gl, PW Inject. Pressure PSI reml~ Choke CSG Pressure PSI Meter Injection Rate
# orSW Zone Allowable Actual °F Bean 7" 10" Total BBLSIDay MMscFD Hrs. Reason
_ ~ .
_
Total ~0, ~& //2 AA
Swl Total ~'~ ~.2/. PWI Total
Drillsite Coil Temperature °F Coil Pressure PSI Bath Blanket
Heater Prod Test Prod .Test Temp. Gas PSI Run Time
In /,:,?(- /.~',~ ),~' ~ /PO .
Out /5'o )._~o /.?~ / ~ ~o 2' ,,?~) ~.4,'
Chemicals
Type Gal/Day
~3"- T' t
Headers Production Water Injection Gas Injection Gas Lift Drain
Pressure /' ..~ ,~ '¥.5"'~:2 Z ~ G.5" 1-8:
Temperature //bO 9-16:
JTank: MeohlDiesel
Level/...,, I Temp. ~
Comments Operater's Signature
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
1. Type of Request:
Operation Shutdown
Pull tubing Alter casing
Stimulate __ Plugging Perforate
Repair well Pull tubing
Other
2. Name of Operator
ARCO Alaska, Inc.
3. Address
P. O. Box 100360, Anchorage, AK 99510
5. Type of Well:
Development X
Exploratory _
Stratigraphic _
Service
4. Location of well at surface
398' FSL, 216' FEL, Sec. 18, T12N, R10E, UM
At top of productive interval
1320' FSL, 3511' FEL, Sec. 18, T12N, R10E, UM
At effective depth
1338' FSL, 3719' FEL, Sec. 18, T12N, R10E, UM
At total depth
1408' FSL, 3880' FEL, Sec.18, T12N, R10E, UM
12.
Present well condition summary
Total Depth: measured
true vertical
8 2 2 5' feet Plugs (meaSured)
6 5 71 ' feet
6. Datum elevation (DF or KB)
RKB 83
7. Unit or Property name
Kuparuk River Unit
8. Well number
1R-0~)
9, Permit number/approval number
85-95/8-270
10, APl number
50-029-21350-00
11. Field/Pool
Kuparuk River Oil Pool
feet
Effective depth: measured 81 2 0' feet Junk (measured)
true vertical 6674' feet
Casing Length Size Cemented
Structural
Conductor 1 1 2' 1 6" 230 Sx CSII
Surface 4039' 9 5/8" 1200 Sx PF"E"
Intermediate 375 Sx P F"C"
Production 821 0' 7" 300 Sx Class G
Liner 250 Sx PF"C"
Measured depth
112'
4039'
8210'
True vertical depth
112'
3792'
6740'
Perforation depth: measure
7896'-7904', 7912'-7944',
true vertical
6510'-6516', 6522'-6545',
Tubing (size, grade, and measured depth)
2 7/8" J-55 6.5 #/FT @ 7689'
Packers and SSSV (type and measured depth)
Camco HRP-1-SP @ 7671', Camco TRDP-1A-SSSV @ 1790'
7975'-7980'
6568'-6571'
MD-RKB
TVD
RECEIVED
Stimulation or cement squeeze summary
Conversion from water injection to water and gas injection.
Intervals treated (measured)
Treatment description including volumes used and final pressure
FEB 1
Oi! & Gas Cons,
Anchorage
14.
Representative Daily Average Production or In!ection Data
OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure
Tubing Pressure
Prior to well operation
Subsequent to operation
882 470 2400
1074 - 470 3900
15. Attachments
Copies of Logs and Surveys run
Daily Report of Well Operations X
16. Status of well classification as:
Oil __ Gas Suspended Service WAG INJ
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
FormSi~ned 10.~40~ ~06/1~)~~~5/88 Title Sr. Operations Engineer
SUBMIT IN DUPLICATE
Weft P.T.~ TP C~m T~ ~et HS[¢~OPrei~PSl ~ _ ~.Rati
SWI Total IL~. ~/,..~"~ PWl Total
Orillll~e ~._C~)II T~n~ratureq:~ ~ Pre~. ,re p6'l Bath ~t~nke{ -
Heater Pi..Od ' Teat.. Prod Te~ .., Temp: GalPSI Run Time
_ Chemicals
Type' "J G~.~
ARCO~.t~"-~, Inc.
Date .~/~--./~
_ Time_ ~'-~ ~ Orillsite [" ~
Drlll~lte Morning Report
CPF
Status ' ' Produ.cfion Well Status ' Gas Lift ~l~tu~ ' .S. hut-ln
Well P.T, or TP Choke Temp Last H;S CSG Pressure PSI Gas Inj. Rate
# SI [one PSI Bean OF WC% PPM 7" 10" Temp Met_er Total MSCFD Hrs Reason
i
, .F _8 i,~5'2~ ~ .~ ~o //5"~)~ __~. ~o~-~ ~1~ !~
. ,
'j · ,
, ,
.....
,, .
.... I ~
I
,, i
To~ IO~
Status Injec!ion Well Status Shut-In
WelllGI, PW Inject. Pre.ssure PSI Temp Choke ~CSG Pressure PSI Meter Inje .ction Rate
{orSw Zone _Allowable, Actual OF Bean 7" 10" Total BBLS/Day MMSCF.D. Hrs. Reason
Tota~ !.la, q?i ~,./-/,.~ '
SWI Total /o~ q79,; PWI Total
Orillsit~ Coil TemPerature OF Coil Pressure PSI Bath Blanket
.. Heater .prod Test Prod Test Temp. Gas PSI Run Time
·
In 129. "1~ ~ 1"7~
Chemicals
Gal/Day
~11
I .Headers {Production] 'Wateilnje:ction Gaslnjection GasLilt '] Drai.n. ~
[,....u..i I1~ . ,e,.qao I,-/,~
~TemperatureI I ~L j "-- 9-16:
-.
Tank: Meoh/Diesel
Level ] Temp.
Comments ,'T~ 0.zL 0~'~ ~J '~t'"') Operater's Signatureq~~
ALA,~. ~.~ OIL AND GAS CONSERVATION COMMI~.,ON
APPLICATION FOR SUNDRY APPROVALS
1. Type of Request: Abandon _ Suspend _
Alter casing _ Repair well
Change approved program _
2. Name of Operator
ARCO Alaska, Inc.
3. Address
P. O. Box 100360, Anchorage, AK
99510
4. Location of well at surface
Operation Shutdown _ Re-enter suspended well_
_ Plugging _ Time extension _ Stimulate _
Pull tubing _ Variance _ Perforate X Other
5. Type of Well:
Development
Exploratory
Stratigraphic
Service
398' FSL, 216' FEL, Sec. 18, T12N, R10E, UM
At top of productive interval
1320' FSL, 3511' FEL, Sec. 18, T12N, R10E, UM
At effective depth
1338' FSL, 3719' FEL, Sec.18, T12N, R10E, UM
At total depth
1408' FSL, 3880' FEL, Sec.18, T12N, R10E, UM
12.
Present well condition summary
Total Depth: measured
true vertical
8225' feet Plugs (measured)
6 5 71 ' feet '
6. Datum elevation (DF or KB)
RKB 83
7. Unit or Property name
Kuparuk River Unit
8. Well number
1R-09
9. Permit number
85-95
10. APl number
50-029-21 350
11. Field/Pool Kuparuk River Field
Kuparuk River Oil Pool
Effective depth: measured
true vertical
81 20' feet Junk (measured)
6 6 7 4' feet
Casing Length
Structural
Conductor 1 1 2'
Surface 4 0 3 9'
Intermediate
Production 8 21 0'
Liner
Perforation depth: measured
7896'-7904',
true vertical
6510'-6516',
Size Cemented
1 6" 230 Sx CSII
9 5/8" 1200 Sx PF"E"
375 Sx PF"C"
7" 300 Sx Class G
250 Sx PF"C"
7912'-7944', 7975'-7980'
6522'-6545' 6568'-6571'
!
Tubing (size, grade, and measured depth
2 7/8" J-55 6.5 #/FT @ 7689'
Packers and SSSV (type and measured depth)
Camco HRP-1-SP @ 7671', Camco TRDP-1A-SSSV @ 1790'
Measured depth True vertical depth
112' 112'
4O39' 3792'
821 0' 6740'
MD-RKB
TVD
RECEIVED
APR u 7
Alaska.0ii .& Gas Cons. C0mmlssl0.n
".,~, ~chorage
13.
Attachments Description summary of proposal ~ Detailed operation program _
PROPOSED PERFORATIONS AND PROCEDURE A'FI'ACHED
BOP sketch
14. Estimated date for commencing operation
APRIL 15,1989
16. If proposal was verbally approved
Name of approver
Date approved
15.
Status of well classification as:
Oil Gas
Service WAG Injector
Suspended
17. I hereby certify that the foregoing is true and correct to/t~e best of my knowledge.
Signed //~_ ~:.~ /¢~ ~'~-¢4t~_,.¢.4~.,~Title .,J/)v~ //.~/~.~-" ~/--q...... ~'.)
- FOR COI~IMISSION"USE ONLY '~
Conditions of approval: Notify Commission so representative may witness
Plug integrity_ BOP Test__ Location clearance__
Mechanical Integrity Test__ Subsequent form require
Approved by the order of the Commission
Form 10-403 Rev 06/15/88
ORIGINAL SIGNED BY
LONNIE C. SMITH
10-~ 00[3¥
~ .,~SSloner
IApproval No~'}. ~,~, /
I
Date
SUBMIT IN TRIPLICATE
Well 1 R-09
Application for Sundry Approval
April 3, 1989
It is proposed to perforate Well 1R-09's C1 Sand in the following interval:
7728-7768 MD-RKB. The well will be perforated with through tubing
perforating guns, and no workover fluid will be used. A wireline BOP will be
used during the perforating procedure. The expected bottom hole pressure of the
perforated sand is 2500 psi.
RECE]VED
APR u 7 ~gg~
.0ii .& Gas Cons. Comrnis~ior~
, ~,.~, ~nchorage
Procedure
Well 1 R-09
SPFO/PERFORATE./SPFO
CC 230DS10RL
·
Contact Operations Engineering to perform pre-perforating
SPFO/SRT. Obtain a 24 hour maximum shut-in time on the SPFO,
weather permitting.
2. MIRU E-line.
t
Perforate following interval at 4 SPF with Atlas 2 1/8" Silver Jet
Strip Gun or equivalent charge. Minimum ID is 2.25" at 7656 MD-
RKB (Camco NOGO 'D' nipple). Reference log is DIL 6/28/85.
Measured De.oth(RKB_~
7728-7768
Interval
C1/B
4. Return well to header pressure and allow rate to stabilize for several
days.
5. Contact Operations Engineering to perform post-perforating
SPFO/SRT.
1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE
2. 5000 PSI WIRELINE RAMS (VARIABLE SIZE)
3. 5000 PSI 4 1/6" LUBRICATOR
4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF
2
I,I:IRELINE BOP EOU~IPMENT
STATE OF ALASKA
ALAS~,.. OIL AND GAS CONSERVATION COMN....,SION
APPLICATION FOR SUNDRY APPROVALS
1. Type o.f Reques{: Abandon Suspend ' ' Operation shutdown i Re-enter suspended well [-J Alter casing [7;
Time extension Change approved program ~' Plugging .~ Stimulate 27 Pull tubing Amend order r' Perforate ,."' Other ~
2. 1':4amd ~f.,Op~rator,. R~BD§t~m elevation (DF or KB)
ARCO ~I asKa, inc feet
3. Address 6. Unit or Property name
PO Box 100360, Anchorage, AK 99510 Kuparuk River Unit
4. Location of well at surface
398' FSL, 216' FEL, Sec.18, T12N, RiOE, UM
At top of productive interval
1320' FSL, 3511' FEL, Sec.18, T12N, RIOE, UM
'~'3~ctFCLd, epJl)19' FEL, Sec.18, T12N, R10E, UM
At total depth
1408' FSL, 3880' FEL, Sec. 18, T12N, RIOE, UM
7. Well number
1R-9 ll~; '-~ ~ ~' '~' '"'" ""~'~ ~
,~. I~ersrmit number
8-
9. APl number 029-21350
50--
10. Pool
Kuparuk River 0il Pool
· Present well condition summary
Total depth: measured 8225'
true vertical 6571'
feet Plugs (measured)
feet
Effective depth:
measured 8120'
true vertical 6674'
Casing Length
XX X$~i~Vd~IXXXXX
Conductor 112'
Surface 4039'
Production 8210'
xxxk~,,ekxxxx
Perforation depth: measured 7896'
Size
feet Junk (measured)
feet
Cemented
Measured depth
16" 230 SX CSlI 112'
9-5/8" 1200 SX PF"E" & 4039'
375 SX PF"C"
7" 300 SX CS G & 8210'
250 SX PF"C"
-7904', 7912 '-7944', 7975'-7980' MD
True Vertical depth
112'
3792'
6740'
true vertical 6510'-6516' 6522'-6545' 6568'-6571' TVD
,
Tubing (size, grade and measured depth)
2 7/8" ~]-55 6.5 #/ft @ 7689'.
Packers and SSSV (type and measured depth)
Camcn HRP-!-SP Pkr ¢ 7671', EamcQ TRDP-]A SSSV (8 ]790'
12.Attachments Description summary of proposal ~' Detailed operations program
Propose conversion from water injector to water and .(:las injector.
13. Estimated date for commencing operation
April 13, 1988
BOP sketch,~.
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 /-<"-)<'~'~..¢ '~ ,.:'~'..'q.,v..i .~ ~:-.";.,.~----~...i'/ Title Sr. Operations Engineer
Commission Use Only
Date .,L/". ,/.~ ..,)
Conditions of approval
L~ Plug integrity
~ ,/~.~/" . ~., ~ , . .:
Notify commission so representative may witness
~'~ BOP Test ¢ Location clearance
ORIGINAL SIGNED BY
Approved by LONNIE C. SMITH
Form 10-403 Rev 12-1-85
~pproved Copy
Returned
./-' ~
Commissioner
IApproval No. ~..;._ ~27 4~
by order of , //,.
_the commission Date ?;'"' /' , '
") Submit in triplicate
Well 1R-09
Application for Sundry Approval
April 4, 1988
1. Propose conversion from water injector to water alternating gas
injector.
2. No BOP equipment will be required.
3. The estimated static BHP is 3600 psi at 6200' SS based on data taken on
1/28/87.
4. No workover fluids will be required.
·
Oil & Gas Cons. comn,~ .......
STATE OF ALASKA
ALAS~,.-, OIL AND GAS CONSERVATION COMN,,,sSION
APPLICATION FOR SUNDRY APPROVALS
1. Type of Request: Abandon [] Suspend ~ Operation Shutdown [] Re-enter suspended well [] Alter casing []
Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other
2. Name of Operator
ARCO Alaska, Inc
3. Address
PO Box 100360, Anchoraae. AK 99510
4. Location of well at surface
398' FSL, 216' FEL, Sec 18 T12N R10E UM
At top of productive interval ' ' ' '
1320' FSL, 3511' FEL, Sec.18, T12N, RIOE, UN
At effective depth
1338' FSL, 3719' FEL, Sec.18, T12N, RIOE, UM
At total depth
1408' FSL, 3880' FEL. Sec. 18_. T12N: RIOE. UM
11. Present well condition summary
Total depth:
5. Datum elevation (DF or KB)
RKB 83
6. Unit or Property name
Kuparuk River Unit
7. Well number
1R-9
8. Permit number
Permit #85-95
9. APl number
50-- 029-21350
10. Pool
Kuparuk River Oil Pool
measured 8225' MD
true vertical 6571' MD
feet
feet
Plugs (measured) None
feet
Effective depth: measured 8120' MD feet
true vertical 6674' MD feet
Junk (measured) None
Casing Length Size Cemented Measured depth True Vertical depth
Structural
112' 16" 230 SX CSII 112' MD 112' TVD
Conductor 4039' 9-5/8" 1200 SX PF E 4039' MD 3792' TVD
xxxS~f~xxx & 375 SX PFC
Intermediate
8210' 7" 300 SX Class G 8210' MD 6740' TVD
xxxP>~$(~~Px & 250 SX PFC
Liner
Perforation depth: measured 7896' -7904' MD, 7912' -7944' MD, 7975' -7980' MD
Tubing (size, grade and measured depth)
2-7/8", , J-SS, 6.5# w/tail @ 7689' MD OCT 3 1 198~
Packers and SSSV (type and measured depth)
Camcr~ HRP-I-SP Pkr fa 7G17'/£nmrn TI~ riP-!6 SSSV @ !790' M_n"--"'~m~Oil&GasC°ns'C°mml~ioII
12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch []
6onvert well from production service to A $~rid only water in_iection
13. Estimated date for commencing operation
October 31, 1986
14. If proposal was verbally approved
Name of approver Mr. R. Douglas
Date approved 10 / 28/86
15. I hereby certify that the_foregoing is true and correct to the best of my knowledge
' ~ -: Sr Operations Engineer
Signed .,..~.--~)¢f~.~ F~)_./..~'~.FZ_~J~_~_~,2F&;-r_~ Title ·
Commission Use Only
DatelO/29/86
Conditions of approval
Notify commission so representative may witness
[] Plug integrity [] BOP Test [] Location clearance
,,......~1---/ /
Form 10-403 Rev":l'2'~-85 '" --'
Commissioner
by order of
the oommission Dat
Submit in triplioate
ARCO Alaska, Inc.
Post Office Box 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
October 31, 1985
Mr. C. V. Chatterton
Commissioner
State of Alaska
Alaska Oil & Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, AK 99501
SUBJECT: 1R-9
Dear Mr. Chatterton'
Enclosed is a copy of the revised Well History (completion details)
to include with the Well Completion Report, dated 9/18/85. If you
have any questions, please call me at 263-4944.
Sincerely,
Gruber
Associate Engineer
J G/tw
GRU12/L55
Enclosure
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany
ARCO Oil and Gas Company
Daily W e'i'l 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.
- --'~"~' IAcc°unting cost center code
Alaska North Slope Borough J Alaska
Field ILease or Unit IWell no.
Kuparuk River I ADL 25635 I 1R-9
Auth. or W.O. no. I Title
AFE 604593 I Completion
Nordic # 1
Operator A.R.Co.
ARCO Alaska, Inc.
Spudded OrcompleteW.O. begun Date
Date and depth
as of 8:00 a.m.
Old TO
8/o3/85
thru
8/o5/85
Released rig
Complete record for each day reported
API 50-029-21350
W.I. J'rotal number of wells (active or inactive) on this
i
Icost center prior to plugging and I
56 · 24~ labandonment of this well
i
IHour I Prior status If e W.O,
8/3/85 ! 1430 hrs.
I
7" @ 8210'
8120' PBTD, RR
Crude/Diesel
Accept Rig @ 1430 hrs, 8-3-85. ND tree, NU & tst BOPE. RU WL,
RIH w/4" csg guns 4 SPF, 90° & perf f/7980'-7975',
7944'-7912', 79041-7896,. RIH w/2-7/8" compl string. Ran 241
its of 2-7/8", 6.5#, J-55, 8RD EUE IPC tbg. Set SSSV @ 1790',
pkr @ 7617', "D" nipple @ 7656', TT @ 7689'. Land tbg, set
pkr, shear SBR, Set BPV. ND BOPE, NU tree & tst. Displ well
to crude/diesel.
Release Rig @ 2130 hrs, 8-4-85. Prepare to move f/1R-9 to
IR-10.
2136 hrs.
New TD
Date
8120'
PB Depth
Knd of rg
Rotary
8/4/85
Classifications (oil, gas, etc.)
Oil
Type completion (single, dual, etc.)
Single
Producing method Official reservoir name(s)
Flowing Kuparuk Sands
Potential test data
Well no. Date Reservoir Producing Interval Oil or gas Test time u : ~ ~ ~ ~
Pump size, SPM X length :Choke size T.P. C.P. Water % GOR Gravi~j . Allowable '~;' ]~f)~(~tlve date
The above is correct
Si~ll~r~'* '~J~ '~' J"~ i*/' '~'~ :~'~'~'~!'---'~--~ ~ ~ IDate
10/10/85 ITit'e
Drillin~ Superintendent
For form preparation and distribution,
ARCO Alaska, Inc.
· -~ Post Office Box 100360
_ Anchorage, Alaska 99510-0360
'~ Telephone 907 276 1215
.... . ~ -..- - ~..%.- . -
R~TURN TO: ARCO - ALASKA, INC.
KUPARUK OPERATIONS ~ENGIN~URING _
RECORDS' CLERK
ATO-1115B
P.Oo BOX 100360
ANCHORAGE, AK 99510
DATE: 10-31-85
TRANSMITTAL NO: 5421
TRANSMITTED HEPJ~WITH ARE THE FOLLOWING ITEMS.
RECEIPT AND RETURN ONU SIGNED COPY OF T~IS TRANSMITTAL.
FINALS/ SCHL/ CEMENT
<ONE * OF EACh>
~lA-3 / CEMENT. EVALUATION TOOL
-lB-4~ .CEMENT UVALdATION TOOL
-'~lR-9 / CET LOG
iR-10~ CET LOG
-~iR- 11 / CET/CEL
1R-12" CET LOG
~2A- 13 CBL/VDL
2A-13 '/ CE~/CEL
~2U-3--- CEMENT EVALUATION TOOL
~2U-10/ CEMENT EVALUATION TOOL
-~2Z-13/ CET LOG
~2Z-14~ C~T LOG
~2Z-15~ CUT LOG
~2z-16-~ CET LOG
~3B-4"7 CEMENT EVALUATION TOOL
~'3B-12-- CET LOG
~3B-12/ CEMENT EVALUATION LOG W/ AC
~3B-16 /'' CEMUNT ~VALUATION TOOL
-3C-9/ CUT LOG
~3C-10~' CET LOG
PLEASE ACKNOWLEDGE
05-04-85 RUN #1 7468-8287
05-28-85' RUN #1 7200-7995
07-17-85 RUN #1 5990-8084
07-16-85 RUN #1 7500-8632
07-25-85 RUN #1 5744-7129
07-26-85 RUN #1 4992-8144
07-13-85 RUN #1 6388-7554
07-24-85 RUN #1 6382-8032
03-26-85 RUN #2 6100-6600
05-19-85 RUN #1 5450-6950
07-09-85 RUN ~1 6000-8411
07-09-85 RUN #1 5500-8173
07-01-85 RUN #1 2700-6617
07-01-85 RUN #1 6100-8011
05-31-85 RUN #'1 6000-7743
07-14-85 RUN #2 6139-8089
07-06-85 RUN #1 5500-8096
05-09-85 RUN #1 6186-7762
07-14-85 kUN #1 7485-8210
07-14-85 RUN #1 8190-8805
RECEIPT ACKNOWLEDGED:
DIST~{ISUTION:
BPAE DRILLING*BL W. PASHER
B. CURKIE~ L. JOHNSTON ,- bXXON
CHEVRON MOBIL PHILLIPS OIL
D & M NSK CLURK*BL J. RATbiMELL
--DATE :'.~s~;~ o . -=' ~ ~,~
so~o /ss
UNION
VAULT/~0' FIL~IS
ARCO Alaska, Inc.
Post Office Box 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
October 9, 1985
Mr. C. V. Chatterton
Commissioner
State of Alaska
Alaska Oil & Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, AK 99501
SUBJECT: 1R-9
Dear Mr. Chatterton'
Enclosed is a copy of the 1R-9 Well History (Completion Details) to
include with the Well Completion Report, dated 9/18/85. If you
have any questions, please call me at 263-4944.
Sincerely,
d. Gruber
Associate Engineer
JG/lt
GRU12/L21
Enclosure
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany
ARCO OI, 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 it space is available.
I Accounting cost center code
District County or Parish I State
Alaska North Slope Borough J Alaska
Field Lease or Unit Well no,
Kuparuk River ADL 25635 IR-9
Auth. or W.O. no. Tit e
AFE 604593 Completion
Nordic #1
Operator A.R.Co. W.I.
ARCO Alaska, Inc. 56.24%
Spudded or W.O. begun Date
Complete 8/3/85
Date and depth Complete record for each day reported
as of 8:00 a.m.
8/03/85
thru
8/05/85
AP1 50-029-21350
otal number of wells (active or inactive) on this
Dst center prior to plugging and ~
banclonment of this well
I
I Prlor if
I Hour status a W.O.
/ 1430 hrs.
7" @ 8210'
8120' PBTD, RR
Crude/Diesel
Accept Rig @ 1430 hrs, 8-3~5--ND BOPE & tst, RU WL, RIH w/4"
asp guns, 4 SPF, 90° & V~-~rf f/7980'-7975's
7904'-7896'. RIH w/2-~/8" compl strng. Ran 241 its of 2-7/8"
6.5#, J-55, 8rd EUE, ~ tbg. Set SSSV @ 1790', pkr @ 7617',
"D" nipple @ 7656', .~F 0 7689'. Land tbg, set pkr, shear SBR,
Set BPV. ND BOPE, NU tree & tst. Displ well to crude.
Release Rig @ ~ hfs, 8-4-85. Prepare to move f/1R-9 to IR-10.
Did TD
Released rig
hrs.
Classifications (oil, gas, etc.)
Oil
New TD PB Depth 8120 PBTD
Date Kind of r g
8/4/85 Rotary
Type completion (single, dual, etc.)
Single
Producing method Official reservoir name(s)
Flowing Kuparuk Sands
Potential test data
Well no. Date Reservoir Producing Interval Oil or gasTesl time Production
Oil on test Gas per day
Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gr~'~lt~'- ' AIIo~'abl~' }:' ~
~ :,~' Effective date
The above is correct . i ~ ~.,~ ~...
Signature Dale ITille
For form preparatiOn ani distribution, j'~!'
see Procedures Manual, Section 10.
Drilling, Pages 86 and 87.
AR3B-459-3-C
Number all daily well history forms consecutively
as they are prepared for each well,
Pa]ge no.
Dlvl~Jo~ of AtllntlcRIchfleldCompa~y
ARCO Alaska, Inc.
Post Office BOx 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
September 25, 1985
Mr. C. V. Chatterton
Commissioner
State of Alaska
Alaska Oil & Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, AK 99501
SUBJECT: 1R-9
Dear Mr. Chatterton'
Enclosed is a copy of the 1R-9 Well History to include with the
Well Completion Report, dated 8/12/85.
If you have any questions, please call me at 263-4944.
Sincerely,
d. Gruber
Associate Engineer
JG/tw
GRU11/L129
Enclosure
cc' 1R-9 Well File
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany
I<ECE VED
!..., ~_.- 1 ~ ' J.;~.~,,,,.,,
Alaska Oil & Gas Cores.
ARCO Oil and Gas Company
Well History- Initial Report- Dally
Inlb'tlGt~al: Prelate and submit the "lellilt I{llielT' on the flret Wednesday liter · well ii spudded or workovlr oplrlllonl ire Itlttld.
Dally worl~ prior tO mid.ling lltould bi .ummlrlzm:l on the form giving Inclullvl dltll only.
Dlltrlct
Alaska
Kuparuk River
Auth. or W.O. no.
AFE 604593
ICounty. pari~ or Ix~rougtt
North Slope Borough
Leale or Unit
ADL 25635
Title
Drill
lSt&ta
Alaska
ell no.
1R-9
Doyen 9
AP1 50-029-21350
Operetor
ARCO Alaska, Inc.
Spudded or W.O. b~un
Spudded
Date and depth
a, of 8:0~ a.m.
6/16/85
thru
/6/21/85
6/22/85
thru
6/24/85
6/25185
6/22/85 ]Nour
Complete record for each day reported
0600 hrs.
ARCO w,I.
Prior ltetUl if I W.O.
56.24%
16" @ 115'
Accept rig @ 0330 hfs, 6/16/85. Perfom am~ual mintenance.
6,, @aa.
060'~~'~Pmp Sweep
Wt. 9.7, PV 26, YP 22, PH 9.0, WL 0, Sol 8
Spud @ 0600 hr,, 6-22-85. Drl f/117'-2100', Drop srvy, pmp
pill, TOH, LD 7 DC's & 3 ,tab's. PU Nevi Dril & Orient to
MWD. RIH, Orient & kick-off @ 2100'. Dy~a Drl 2100'-4060'.
C&C mud, pmp pill, POOH, LD M~D, ND. MU B~A & RIH. Tight @
3000', work pipe. PU Kelly, rem 3400'-3500'. RIH, tight spot,
PU Kelly, rem 3656'-3790'. RIH, rem 3940'-4060'. CBU. Pmp
Hi-Via, sweep.
2241', 6°, N74.75W, 2240 TVD, 2 VS, N2, IV
2588', 17°, N73.75W, 2580 TVD, 67 VS, N18, 65W
2900', 24~°, N66.75{, 2872 TVD, 176 VS, N63, 166
3181', 33°, N69.75W, ~"275~"~, ~~~~
3558', 37°, N71.74~, 3428 TVD, 522 VS, NI91, 489 //
4010's 45°, N76.75~, 3769 TVD, 818 VS, N265, 777W
4060'(0') ~est BOPE
Wg. 8.6, PV 2s YP 3, PH 9.0, ~L 0, Sol 2
POOH, LD BHA RU & rn 93 3t~ of 9-5/8", 36#/ft J-55 BTC csg w/FS
@ 4039' & FC @ 3949'. C&C n~d. Howco pmp 5 bbls wtr,
lines to 2000#; OK. Pmp 35 bbls ~cr, drop bom plug. Drop midl
plug.~ Pmp 375 ax of PF "C" @ 15.8 ppg. Drop top pig. Pmp &
displ w/300 bbls mud, bmp blug w/1500#; flt$ held. ¢I? @ 1700
hfs, 6-24-85. ND riser, install c~g head. PU BO?E, bTU choke
ln. RU, tat BOPE.
· k)o-r~: C,~c~ ,.~/~2_0o s~ PF "6' ':
i< EC E i'? E D
Tho above is correct ~
For form preparation and distribution,
see Proceduree Manual, Section 10,
Drilling, Pages 86 and 87.
Data
AR3B-459-1-D
Number all daily well hlllOl¥ fermi conlecutivlly ,ge no.
a, th,y are pr, plred f ..... h w,ll. ] IPai
ARCO Oil and Gas Company
Daily Well History--Interim
Inltructienl: This form is used during drilling or workover operations. If lasting, coring, or perforating, show formation name in de,cr;bing work performed.
Number all drill stem tests sequentially. Attach description of all cores. Work perlormed by Producing Section will be reported on "Interim" sheets until hnal
complelion. Rel3ort official or represenlalive test on "Flnll" form. 1) Submit "Interim" sheets when lilled out but nol less Irequently Ihan every 30 days. or (2)
on Wednesday of the week in which oil string is set. Submit weekly for workovers and Iollowlng setting el oil strinG unhl completion.
District
Field
Date and depth
as of 8:00 a.m.
AlaskaCounty or Far~sh North Slope Borough
ILease or Unit
Kuparuk River ' ADL 25635
Complete record for each day while drilling or workover in progress
6/26/85
6/27/85
6/28/85
IStale
Alaska
IWell no,
1R-9
5820'(1760') Navi Drl'g @ 5820'
Wt. 9.1, PV 7, YP 2, PH 9.5, WL 6.8, Sol 5
Tst BOPE. Install wear ring, PU MWD & serv. PU BHA. RIH, tst
csg to 1500 psi, Drl flts + 10'. Displ to non dispersd polymer.
PU & orient ND to MWD. RIH. Navi Drl, srvy f/4070'-5820'.
4123', 44°, N73.75W, 3859 TVD, 898 VS, N285, 853W
4626', 45°, N73.75W, 4209 TVD, 1250 VS, N380, 1192W
5253', 45°, N74.75W, 4655 TVD, 1691VS, N498, 1617W
5568', 44°, N74.75W, 4880 TVD, 1911VS, N556, 1829W
7549'(1729') DILLO
Wt. 10.4, ?V 21, YP 14, PH 9, WL 5.4, Sol 12
Dr1 & srvy f/5820'-5945'. Core rn f/5945'-6072'. Drl
f/6072'-7549'.
5885', 44.2°, N75-3/4W, 5107 TVD, 2133 VS, N612, 2044W
6325', 45.9°, N77-3/4W, 5214 TVD, 2447 VS, N680, 2351W
6988', 47.8e, N78-3/4W, 5866 TVD, 2981VS, N777, 2826W
9-5/8" @ 4039'
8127'(578') Circ
Wt. 10.4, PV 19, YP 13, PH 9.5, WL 6.2, Sol 13
Drl f/7549'-8127'. Circ btms up, short trip to 4043'. CBU.
7495', 44.7°, N78-3/4W, 6217 TVD, 3296 VS, N848.8, E3185
7807', 43.5°, N78-3/4W, 6441TVD, 3513 VS, N891.2, E3398
T~e above is cor,~e,~t
For form pre~)'aration and distribution
see Procedures Manual Section 10,
Drilling, Pages 86 and 87
Date
Drilling Superintendent
AR3B-459-2-B
Number all da,ly well h(sIory forms consecuhvely
las lhey are prepared or each well Page
ARCO Oil and Gas Company
Daily Well History-Final Report
Instructions: Prepare and submit the "Final Rel)ert" on the first Wednesday after allowable has been ass~cjned or well is Plugged. Abandoned. or Sold.
"Final Report" should be submitted also when operations are suspended for an indefimte or appreciable length of time. On workovers when an officral test is not
recluired upon completion, re~ort completion and representative test data in blocks provided. The "Final Report" form may Pe used for reporting the ant*re
operation il space is evadable.
District lCounty or Parish
Alaska Ii
Field Lease or Unit
Kuparuk River
Auth. or W.O. no. ~Title
AFE 604593
I
North Slope Borough
ADL 25635
Drill
IAccounting cost center code
state Alaska
Iwe,, nlOR_9
Doyon 9
API 50-029-21350
Operator I AR.Co. W.I.
ARCO Alaska, Inc. I 56.24%
Spudded or W.O. begun ~ Date
Spudded [ 6/22/85
Date. and depth Complete record for each day reported
as of 8:00 a.m.
Old TD
Released rig
6/29/85
thru .
7/01/85
0100 hrs.
Classdications (oil, gas, etc.)
Oil
Producing method
Flowing
Potential test data
Iotal number of wells (active or inactive) on this
ost center prior to plugging and I
bandonment of this well
I
our I Prlor slalus if a W.O.
0600 hrs.
I
7" @ 8210'
8120' PBTD'(0') RR
10.4 Brine
Circ, POOH. Log'd DIL/SFL/SP/CAL/GR f/St20'-4032'. Log
w/FDC/CNL f/8120'-7500', 6950'-6250', & 4750'-4032'. RIH, Drl
to 8225', circ, short trip. POOH LDDP. Rn 188 jts 7" 26#,
J-55 csg to 8210'. Cml w/300 sx CL "G". Displ w/10.4 ppg.
Tst csg to 3000 psi. Set slips & lower pckoff. NU lower tree
assy. Tst pckoff to 3000 psi. RR @ 0100 hfs, 6-30-85.
8061', 42.4°, N74-3/4W, 6627 TVD, 3686 VS, N930.8, 3566.4W
8127', 42.4°, N74-3/4W, 6676 TVD, 3730 VS, N942.6, 3609.4W
New TD
Date
PB Depth
j~< nd of .g
6/30/85
I
IType completion {single dual. etc,)
Single
Oil c al reservoir namers)
KuparUk Sands
8120' PBTD
Rotary
Well no. Date Reservoir Producing Interval Oil or gasTest time Production
(~il on test Gas per day
Pump size. SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Etlective dale
corrected
Signal "\ ~'~- '~, Date\ Title
S. COi~.,. '~ ~
For form preparation and distribution, ~
see P .... u .... M .... I, Section 10, ,. --
Drilling. Pages 86 an~ 87.
AR3B-459-3-C
Alaska Oil &
Number all daily well history forms consecutively I Pag%no,
as they are prepared fOr eactl 'Well.
Olvldo~l et Alll~tlcRtchfleldCompa~y
ARCO Alaska, Inc.
Post Office Box 100360
Anchorage, Alaska 99510
Telephone 907 276 1215
September 20, 1985
Mr. C. V. Chatterton
Commi ssi oner
State of Alaska
Alaska Oil & Gas Conservation
Commi s s i on
3001 Porcupine Drive
Anchorage, AK 99501
SUBJECT: 1R-9
Dear Mr. Chatterton:
Enclosed is the Well Completion Report for 1R-9. I have not yet
received a copy of the Well History (completion details). When I
do, I will forward a copy to you.
If you have any questions, please call me at 263-4944.
Sincerely,
J. Gruber
Associate Engineer
JG/tw
GRUll/L96
Enclosure
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany
STATE OF ALASKA -~
ALASKA ~ .~ AND GAS CONSERVATION CE ,qlISSlON
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
1. Status of Well Classification of Service Well
OIL [~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE []
2. Name of Operator 7. Permit Number
ARCO Alaska, Inc. 85-95
3. Address 8. APl Number
P. 0. Box 100360, Anchorage, AK 99510 50- 029-21350
4. Location of well at surface 9. Unit or Lease Name
398' FSL, 216' FEL, Sec. 18, T12N, R10E, UM Kuparuk River Unit
At Top Producing Interval 10. Well Number
1320' FSL, 3511' FEL, Sec.18, T12N, R10E, UM 1R-9
At Total Depth 11. Field and Pool
1408' FSL, 3880' FEL, Sec.18, T12N, R10E, UM Kuparuk River Field
,
5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool
83' RKBI ADL 25635 ALK 2568
'-12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions
06/22/85 06/28/85 06/30/85*I N/A feet MS LI N/A
17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost
8225'MD,6751 'TVD 8120'MD,6674'TVD YES I~X NO [] 1790 feet MDI 1600' (Approx)
22. Type Electric or Other Logs Run
DIL/SFL/SP/Cal/GR, FDC/CNL, 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 112' 24" 230 sx CS II
9-5/8" 36.0# J-55 Surf 4039' 12-1/4" 1200 sx PF "E" & 375 s; PF "C"
7" 26.0# J-55 Surf 8210' 8-1/2" 300 sx Class G & 250 s: PF "C"
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)
7980' - 7975' 2-7/8" 7689' 7617'
7944' - 7912' w/4 spf, 90° phasing
7904' - 7896' 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC.
DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED
N/A
27. N/A PRODUCTION TEST
Date First Production I Method of Operation (Flowing, gas lift, etc.)
I
'lDate of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO
TEST PERIOD
Flow Tubing Casing Pressure CALCULATED=~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr)
Press. 24-ROUR RATE Im~
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: Tubing was run and the well perforated 8/4/85. TEHP2/WC15 Submit in duplicate
Rev. 7-1-80 CONTINUED ON REVERSE SIDE
· - ' ' '. GEOIZOGIC'M~,RK-ERs'
·
NAME Include interval tested, pressure data, all fluids recovered and gravity,
MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase.
Top Upper Sand 7669' 6345' N/A
Base Upper Sand 7737' 6394'
Top Lower Sand 7876' 6495'
Base Lower Sand 8032' 6609'
.
31. LIST OF ATTACHMENTS
32. I hereby certify that the foregoing is true and correct to the best of my knowledge
Signed/7
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".
ARCO Alaska, Ir/'-~
Post Office ¢3ox 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
DATE: 09-17-85
TkANSMITTAL N0:5357
RETURN TO:
ARCO ALASKA, INC.
KUPARUK OPERATIONS ENGINEERING
RECORDS (JLa: RK
ATO-1115B
P.O. BOX 100360
ANCHORAGE, AK 9~510
TRANSMITTED
lv, EC~ I PT AND
OPEN HOLE FINALS/ SCHL
(ONE * OF EACH)
1R-13 ~5'~. DIL/SFL-GR
%~,~/ DIL/SFL-GR
- DEN/NEU
'~~. "~-2 "-"' DEN / NEU
~ ~ 5'''/ DEN/NEU
'~,~2 "---- DEN/NEU
~',4 CYBE RL OOK
HER~.WITH ARE THE FOLLOWING ITEblS. PLEASE ACKNOWLEDGE
K~TUKN ONE SIGNED COPY OF T~tIS TRANSMITTAL.
PO RO
PORO
RAW
07-27-85 RUN 91 3944-8550
07-27-85 RUN #1 3944-8550
07-27-85 RUN #1 6900-8524
07-27-85 RUN #1 6900-8524
07-27-85 t~UN #1 6900-8524"
07-27-85 RUN #1 6900-8524
07-27-85 ~UN ~1 6900-~501
1R-12-'~-5''"-- DIL/SFL-GR
'"--2~'- DIL/MFL-GR
-'5"~'' DEN/NEU
'~" ~ 'DE N/N
~ -"5" ~" DEN/Ni~U
"~'2~'' D~.'N/NEU
1K-10
"~5" / DIL/SFL-GR
~"-2" DIL/SFL-GR
~"~5" '/ DEN/NEU
~2"'/ DEN/NEU
"~5"F'' DEN/NEU
~2 ".~DE N / N E U
~JJ YB E KL OOK
PORO
PO KO
RAW
PO ~O
PORO
kA~
RAW
07-20-85 RUN ~1 3950-8242
07-20-~ 5 tt0N #1 3950-8242
07-20-85 ~UN #1 3950-8219
07-2U-8 5 RUN ~1 3950-8219
07-20-85 RUN #1 3950-8219
07-2 0-~5 RUN #1 3950-8219
07-20-85 RUN #1 7600-8220
07-06-~5 RUN #1 4633-8702
07-06-85 liUN #1 4633-8702
07-0 b-85 RUN ~1 6500-8671
07-06-85 RUN #1 6500-8671
07-06-~5 I<UN ~1 6500-8671
07-06-85 ~UN #1 6500-8671
07-06-85 RUN #1 8000-8700
1R-9 ~'5~ DIL/SFL-GR
-~,,2 "~-"' DIL/SFL-GR
,,% ~-,~2 ''~_ D~N/N kU-GR
~ .~'~5 "/DEN/N ~:U-GR
} ~ 2",---" D~'.N/NEU-GR
'~'"'~ CYuERLOOK
PORO
PO R(J
RAW
RECEIPT ACKNOWLEDGED:
BPAE
CURRIER
CHEVRON
M*BL
06-28-85 RUN #1 4032-8114
06-28-85 RUN #1 4032-8114
06-28-85 RUN #1 4032-8088
06-28-85 RUN ~1 4032-80~8
06-2~-85 RUN #1 4032-8088
06-28-~ 5 RUN ~1 4032-808~
06-28-85 RUN
DISTRIBUTION:
DRILL1NG*BL W. PASHk'K
L. JOHNSTON EXXON
MOBIL PHIL|.IPS OIL
N~K CLEttK*BL J. RATH/v]]JLL*BL
4032-,81%.4 ..
UNION
K . TULIN / VAULT* FILM
ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany
ARCO Alaska. In,c_.;
Post Offi( ox 100360
Anchorage. Alaska 99510-0360
Telephone 907 276 1215
DAT~: 09-05-85
TRANSMITTAL NO: 5332
K]~TURN TO: ARCO ALASKA, INC.
KUPARUK OPERATIONS ENGINEERING
RECORDS CLERK
ATO- 1115B
P.O. BOX 100360
ANC~URAGE, AK 99510
·
TRANSMITTED HERkSqITH ARE THE FOLLOWING ITEHS. PLEASE ACKNOWLEDGE
tcECEIPT AND kETUR/~ ONE SIGNED COPY OF THIS TRANSMITTAL.
SEQUENCE OF EVENTS PRESSURE DATA
lB-3 -/ PBU
2A-i-~ 'C' SAND PBU
2B-13-' 'C' SAND PBU
2C-U 'A' SAND PBU
2V-2 - 'A' SAND PBU
2V-5 ~ 'A' SAND PBU
03-07-85
08-03-85
08-01-85
08-16-85
07-27-85
06-25-85
SEi-:UENCE OF EVENTS FROI,I WELL SERVICE REPORTS/PRESSURE' DATA
lA-8 ~ bBHP & I~]ISC.
lA-5 PBU & MISC.
lA-3'''~ PBU
lA-3-- PBU
lB-2-~ 'C' SaND P~U
1B-2~ 'C' SAND PBU
lB-5 ~ ~TATIC TEMP.LOG
08-22'-85
08-14-85
08-12-~5
08-11-85
0~-05-~5
08-06-85
0~-15-~5
1E-21-' RUN BHP & MISC. 08-03-85
1F-5 / PBU 'A' & 'C' bAND (ISLTD) U8-18-~5
1F-5// PBU 08-17-85
1G-15/ 'C' SAND PBU
1G-15'~ 'A' 5AND PBU & MISC.
iG-15/ 'C'_ SAND PBU
iR-10.--" BHP & MISC.
1R-9/ BHP & MIbC.
1R-12 ? BHP & MISC.
2A-1/ 'C' SAND PBU
2A-1'/ 'A' SAND BHP
2A-1~ 'C' SAND PBU
2A-13..- Blip & MISC.
2B-13/- 'A' SAND
2B-13-- 'C' SAND PBU
2B-13-~ DATA FROM BHP SURVEY
2B-13~ 'C' SAND PBU
2C- 8" PBU
2G-16" PBB
2G-16/ PBU
RECEIPT ACKNOWLEDGED:
0~-10-8b
0U-06-85
08-09-85
0~-15-~5
08-15-85
0~-19-85
08-04-85
08-04-85
08-03-85
0~-25-85
08-02-85
08-02-85
08-03-85
08-01-85
08-17-85
08-17-85
08-1~-85
DIST~ilBUTION:
BPAE D~xILLING W . PASTIER
B. CURRIER L. JOHNSTON EXXON
CHEVRON £'I~DIL PHILLIPS OIL
D & 51 NbK CLERK J. ix~T'HI,IELL
*PLEASE NOTE--DISTRIB-
UTION CONTINUED ON
NEXT PAGE. /~
DATE:
STAT~; OF4/AL&SKA'"' .-/
U N I 0 N
. .'...,..,. '~.
K. TULIN/VAULT -.: .- '7'~-,,':., ..,,., ...,~..,,
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany
ARCO Alaska, Inc.
Post Office L ~ 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
DATE: 09-10-85
TRANSMITTAL NO: 5341
RETURN TO:
ARCO ALASKA' INC.
KUPARUK OPERATIONS ENGINEERING
KECOP. DS CLEkK
ATO-1115B
P.O. BOX 100360
ANCHORAGE, AK 99510
TRANSMITTED HEREWITH ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE
RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL.
CASED HOLE LOGS (FINALS):
~'~lQ-15/ 'CBL 6/12/85 8000-8745
~ 1Q-i-~ CCL & PERFORATING RECORD 4/16/85
~2V-9--~ COMPLETION RECOtcD 4/25/85 7525-7800
~2H-15-C. COMPLETION RECORD 4/13/85 6998-7438
-v2H_2_~ CCL & PERFORATING RECORD 4/24/85
'~ 2H-14~ CCL & PERFORATING RECORD 4/23/85
~2H-16-- CCL & PERFORATING RECORD 4/19/85
~lR-9~ PERFORATING RECORD 8/3/85 7800-8000
~lB-2 --- PACKER SETTING RECORD 6/5/85 7290-7820
~lA-9~ PACKER SETTING RECORD 8/15/85 6700-6950
-~2H-13-- COMPLETION RECORD 4/17/85 7434-7650
~IR-10 ~ PERFORATING B/~CORD 8/5/85 8300-8550
~2Z-8'~' COMPLETION RECORD 4/27/85 8920-9030
~ 3B-11-- CET 7/5/85 65~0-9100
RECEIPT ACKNOWLEDGED:
· DISTRIBUTION:
BPAE DRILLING* W. PASHER
B. CURRIER L. JOHNSTON EXXON
CHEVRON HOBIL PHILLIPS OIL
D &~M NSK CLERK* J. RATHMELL
E)H-I-C
UNION
K. TULIN/VAULT
R~TUKN TO:
ARCO Alaska, Inc.
Post Offi?---'.ox 100360
Anchorage. Alaska 99510-0360
Telephone 907 276 1215
DATn: 09-05-85
-
TRANSMITTAL NO:5332A
* *CONTINUATION
,,
ARCO ALASKA, INC.
KUPARUK OPERATIONS ENGINEERING
RECORDS CLERK
ATO-1115B
P.O. BOX 100360
ANCHORAGE, AK 99510
TRANSMITTED HER5%~ITH ARE THE FOLLOWING ITEMS.
RECEIPT AND RETUR/~
SEQUENCE OF EVENTS
2G-9 ~- PBU 08-22-85
2G-9~- PBU 08-21-85
2G-11j PBU 08-19-85
2G-16 ~ SB~P 0~-19-85
2h-l-- PBU 08-25-85
2h-l.-' PBU 08-24-85
2U-l'~ 'C' SAND PBU 08-23-85
2U-l'~ END 'C' SAND PBU & ~]ISC. 08-24-85
2W-7 "' 'C' SA~qD PBU 08-17-85
2W-7/ 'C' SAND PSU . 08-23-85
2W-7/~ 'C' SAND PDU 08-22-85
2X-11/~- PBU 01:t-24-85
2X-11 / 'C' SAND PBU 0~-25-85
2X-11~ 'C' SAND PBU 08-26-85
3C-5 / BhP & M1SC. 08-29-85
3C-7~'~ BHP & ~ISC. 08-30-85
3C-8 / BHP & MISC. 08-31-85
3C-9/- BHP & MISC. 08-09-85
3C-10 f'BHP & MISC. 08-10-85
PLEASE ACKNOWLEDGE
ONE SIGNED COPY OF THIS TRANSS~ITTAL.
FROM WELL SEKVICE i<EPOKTS/PRESSUR~.' DATA
KUPARUK WELL PRESSURE REPORT ENVELOPE FACES:
3C-12/ STATIC 'A' SAND 07-24-85 CA/4C 0
3C-10~- STATIC 'A' SAND 08-10-85 OTIS
~ STATIC 'A' SAND 08-09-85 OTIS
2Z-16-- 07-21-85 OTIS
2Z-15'- STATIC 'A' SAND 07-17-85 OTIS
2Z-14.~ STATIC 07-20-85 OTIS
2Z-13'~ STATIC 'A' SAND 07-17-85 OTIS
2X-4~ PBU 08-12- 85 CANCO
2X-4~' PBU 08-13- 85 CAMCO
2U-1~ ' 08-24-85 OTIS
2A- 13'~ STATIC 08-25- 85 CAMCO
1R-10-~ STATIC 'A' SAND U8-15-85 CA~iCO
1R-9 -~ STATIC 'A' SAND 0~-14-85
i{ECEIPT ACKNOWLEDGED:
sPAE*
B. CURRIER
CHEVRON*
~ & M*
DISTRIBUTION:
DRILLING W. PAShE~
L. JOHNSTON EXXON
~OBIL* PHILLIPS OIL*
NSK CLERK J. RAT~MELL*
·
~';[. ?, .-., _
'~/a~..., '"' '~' ?~.,.o~.-
DATE ~ -,,:..
_ /~.
,,rJ,S ..'..
~'A~D OF ~SKA* ..... :. ...... ;r..
SO~ZO*
UNION*
K.TULIN/VAULT
ARCO Alaska. Inc. is a Subsidiary of AtlanlicRichfieldCompany
ARCO Alaska, Inc.
Post Office E 00360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
September 10, 1985
Mr. C. V. Chatterton, Chairman
Alaska Oil and Gas Conservation Commission
3001 Porcupine Drive
Anchorage, AK 99501
Dear Mr. Chatterton'
Attached in duplicate are subsequent notices
following wells at the Kuparuk River Field:
Well Action Date Performed
1Q-2 Fracture 9/1/85
1Q-3 Fracture 9/1/85
1R-5 Acidize 8/23/85
1R-6 Acidize 8/24/85
1R-9 Fracture 8/27/85
1R-10 Fracture 8/26/85
1R-11 Fracture 8/26/85
1R-12 Fracture 8/27/85
2C-9 Perforate 8/26/85
2Z-1 Fracture 8/19/85
2Z-2 Perforate 8/25/85
2Z-2 Fracture 9/2/85
2Z-3 Fracture 8/19/85
on
the
If you have any questions, please
~ M. Drumm
Kuparuk Operations Coordinator
TMD/kmc
Attachment (Duplicate)
call me at 263-4212.
RECEIVED
Alaska 0il & Gas Cons. Commission
Anchorage
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany
STATE OF ALASKA
ALASKA ~JIL AND GAS CONSERVATION CU~v~MISSION
SUNDRY NOTICES AND REPORTS ON WELLS
1. DRILLING WELL [] COMPLETED WELL
2. Na~i~c~P~rai~SKA, INC.
3. Address
P. O. BOX 100360, ANCHORAGE, ALASKA 99510
OTHER []
4. Location of Well
SURFACE LOCATION' 398' FSL, 216' FEL, SEC. 18,
T12N, R10E, UM
5. Elevation in feet (indicate KB, DF, etc.)
12.
83'
6. Lease Designation and Serial No.
7. Permit No.
85-95
8. APl Number
50- 029-21 350
9. Unit or Lease Name
KU.PARUK RIVER UNIT
10. Well Number
1R-9
11. Field and Pool
KUPARUK RIVER FI ELD
KUPARUK RIVER OIL
(RKB) ADL 25635, ALK 2568 POOL
Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data
NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF'
(Submit in Triplicate}
Perforate [] Alter Casing [] Perforations
Stimulate [] Abandon [] Stimulation
Repair Well [] Change Plans [] Repairs Made
Pull Tubing [] Other [] Pulling Tubing
(Note: Report multiple completions on Form 10-407 with a submitted Form 10407 for each completion.)
(Submit in Duplicate)
[] Altering Casing []
~ Abandonment []
[] Other []
13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any
proposed work, for Abandonment see 20 AAC 25.105-170).
On August 27, 1985, the "A" sands of Kuparuk well 1R-9 were
hydraulically fractured and propped to improve production.
treatment consisted of 263 BBLS of gelled diesel as pad and
fluid and 750 LBS of 100 mesh and 14,280 LBS of 20/40 sand
proppant. 50 BBLS of gelled diesel was used as a flush.
The
carrying
as
Prior to pumping, equipment and lines were tested to 7000 psi.
RECEIVED
Alaska 0ii & Gas Cons. O0mrnissJ0n
Anch0rar~
14. I hereby certify that the foregoing is true and correct to the best of ~j ~n~.j~.
Sig ........ Title OPERAT ! ON.g COO)RD ! NATOR
The space-b/~low for Commission use
9/10/85
Date
Conditions of Approval, if any:
Approved by
By Order of
COMMISSIONER the Commission
Date
Form 10403
Rev. 7-1-80
Submit "Intentions" in Triplicate
and "Subsequent Reports" in Duplicate
ARCO Alaska, Inc. "-'"'
Post Office B~,_ ~00360
Anchorage, Alaska 99510
Telephone 907 276 1215
August 13, 1985
Mr. C. V. Chatterton
Commissioner
State of Alaska
Alaska Oil & Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, AK 99501
SUBJECT: 1R-9
Dear Mr. Chatterton:
Enclosed are the Well Completion Report and gyroscopic survey for
1R-9. I have not yet received the Well History. When I do, I will
forward a copy to you. Also, tubing details will be submitted when
the well is completed.
If you have any questions, please call me at 263-4944.
Sincerely,
Gruber
Associate Engineer
JG/tw
GRUlO/L117
Enclosures
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany
STATE OF ALASKA .... ,
ALASKA~_. _ AND GAS CONSERVATION CC vllSSlON
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
1. Status of Well Classification of Service Well
OIL [] GAS [] SUSPENDED I-~X ABANDONED [] SERVICE []
2. Name of Operator 7. Permit Number
ARCO Alaska, Inc. 85-95
-3. Address ~" $. APl Number
100360, Anchorage, AK 99510 1| VERIFI~ 50- 029-21350
P.
0.
Box
4. Location of well at surface ~ Sur~.~ 9. Unit or Lease Name
398' FSL, 216' FEL, Sec.18, T12N, R10E, UM/B'H'~ Kuparuk River Unit
At Top Producing Interval 10. Well Number
1320' FSL, 3511' FEL, Sec.18, T12N, R10E, UM 1R-9
At Total Depth 11. Field and Pool
1408' FSL, 3880' FEL, Sec.18, T12N, R10E, UM Kuparuk River Field
5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool
83' RKB ADL 25635 ALK 2568
12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions
06/22/85 06/28/85 06/30/85 N/A feet MS LI N/A
"17. TotalDepth(MD+TVD) 18. PiugBackDepth(MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set J 21. Thickness of Permafrost
8225'MD,6751 'TVD 8120'MD,6674'TVD YES I~X NO [] N/A feet MD 1600' (Approx)
22. Type Electric or Other Logs Run
D IL/SFL/SP/Ca]/GR, FDC/CNL, Gyro
23. CASING, LINER AND CEMENTING RECORD
SETTING DEPTH MD
CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED
,_
16" 62.5# H-40 Surf 112' 24" 230 sx CS II
9-5/8" 36.0# J-55 Surf 4039' 12-1/4" 1200 sx PF "E" &.375 s; PF "C"
7" 26.0# J-55 Surf 8210' 8-1/2" 300 sx Class G
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)
None N/A
26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED
N/A
27. N/A PRODUCTION TEST
Date First Production I Method of Operation (Flowing, gas lift, etc.)
I
Date of Test Hours Tested iPRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAs-OILRATIO
TEST PERIOD I~
Flow Tubing Casing Pressure CALCULATED.1~ OIL-BBL GAS~MCF WATER-BBL OIL GRAVITY-APl (corr}
Press. 24-HOUR RATE ~1~
28. CORE DATA
Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips.
NONE
RECEIVED
Alaska Oil & G~s Cons. Gem
Anchor~g9
Form 10-407 TEHP/WC82 Submit in duplicate
Rev. 7-1-80 CONTINUED ON REVERSE SIDE
29. ' ' ~ 30..
- :: : ',' 'G'EOLOGiC'MARKERS ;!' ::" "': :' : " ':':.i ~" FORM/~TiONYE~Ts
·
NAME Include interval tested, pressure data, all fluids recovered and gravity,
MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase.
Top Upper Sand 7669' 6345' ~I/A
Base Upper Sand 77:37' 6:394'
Top Lower Sand .7876' 6495'
Base Lower Sand 8032' 6609'
.
. _
31. LIST OF ATTACHMENTS
Gyroscopic Survey (2 copie~)
32. I hereby certify that the foregoing is true and correct to the best of my knowledge
Signed (~ ~ .~~.--' Title Associate Engineer Date, 8-/~-~'
~/ _
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".
ARCO Alaska, Inc.
Post Otlice Box 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
DATE: 08-08-85
TRANSHITTAL NO: 5285
RETURN TO:
ARCO ALASKA, INC.
KUPAIiUK OPERATIONS ENGINEEkING
t~ECO~d3S CLEkK
ATO-1115B
P.O. BOX 100360
ANCHORAGE, AK 99510
!'KANSMITTED
~ECEIPT AND RETUI{N ONE
BOX 1 OF 2:
3PEN H~,OLE LIS TAPES PLUS
3C-11 06-23.-85 RUN #
HEREWITH ARE THE FOLLOWING ITL~4S.
3C-10" 07-02-85 RUN
3C-9 ~' 07-10-85 I{UN #
3C-7~ 07-31-85 RUN #
3B-14 -- 03-20-85 RUN
3B-12-- 07-03-85 RUN
3B-11~ 06-26-85 RUN #1
3B-10~ 06-17-85 RUN
3B-9/ 06-10-85 RUN #1
2Z-15" 06-19-85 RUN #1
2Z-14-' 06-28-85 RUN #1
2Z-13' 07-05-85 RUN
2Z-12-- 07-20-85 RUN ~-I
2Z-11,~ 07-27-85 RUN #1
~ ACKNOWLEDGE
SIGNED COPY OF THIS TRANSMITTAL.
LISWINGS (ONE
1 4427.5-8881.
1 1785.0-8987.
1 3920.0-8332.
1 4617.5-8747.
2 3280.0-6003.
1 4021.5-8261.
2190.5-9257.
3273.0-7270.
2092.0-8415.
2658.0-6620.
3876.0-8334.
4180.0-8538.
4409.0-9412.
3531.5-7534.
COPY OF EACh)
5 REF #70597
5 REF ~ 70620
5 REF # 70642
5 REF # 70706
5 RI.:F #70229
5 REF # 70641
0 REF #70598
5 t{EF #70555
0 REF #70634
0 REF # 70562
0 REF #70600
5 REF # 70639
5 REF #70661
0 RSF # 70704
BOX 2 OF 2:
;PJ~HOLE LIS TAPES PLUS LISTINGS (ONE COPY OF
lW-16~/ 01-28-85 RUN #1 3116.0-7038.5 REF
~V-14'/ 05-16-85 RUN #1 3047.0-7086.5 REF
!V-12~/ 04-22-85 RUN #1 3960.0-9265.0 REF
~U-10~// 04-11-85 RUN ~1 2972.0-7063.0 REF
~U-7~¥~ 03-1-9-85 RUN #1 3594.b-8179.5 REF
A-13~'-.~ 07-16-85 RUN ~1 7649.5-8160.0
_R-13''/ 07-27-85 RUN #1 3940.0-8578.0 REF
~R-12'~''~ 07-20-85 RUN 91 3935.0-8277.5 R~:F
.R-11'~'' 07-13-85 RUN #1 3810.0-7213.5 REF
~R-10~''~ 07-06-85 }<UN #1 2991.0-8738.0 REF
_R-9// 06-28-85 RUN #1 3991.5-8131.0 REF
R-7// 06-04-8b RUN #l&3 0045.5-7103.0
EACH)
# 70436---REVISED
~ 70614---REVI S£D
# 70613---REVISED
# 70612---REVI
# 70505---REVISED
#70645
#70702
#70660
#70643
#70640
970601
#70509
ECEIPT ACKNO~LEDGED:
DISTRIBUTION:
PA~ Dt~IbLING W. PASHE~{
· CURRIER L. JOHNSTON EXXON
HEVRON HOBIL PHILLIPS OIL
& M NSK CLERK J. P, ATHMELL
DATE: ~J~':'~ D!' 3.~.~ ..... Cons. Commissio~
STATk OF ALASKA'*-'~'~
SOHIO
UNION
K.TULIN/VAULT
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
3001 Porcupine Drive
Anchorage, Alaska 99501
(907) 279-1433
TO:
A]aslm 0~] anc] Ca~ Con~erva*Jon Commission
Anchorage, ' ~-~--
RE:
Receipt of the following material which was
transmitted via
is hereby acknowledged:
QUANTITY
DESCRIPTION
9-
· ' . ,--7. - ~ -~--,.~., '---
/~.~
DATED:
Copy sent to sender
YES NO ~/
, ~
i ·
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
3001 Porcupine Drive
Anchorage, Alaska 99501
(907) 279-1433
TO: State of .~aslm
Alaska Oil and Gas Consem,-ation Commission
3001 Porcupine Drive
Anchorage, Alaska 99S01
RE:
Receipt of the following material whiCh was transmitted via
.,/~,,~ // is hereby acknowledged:
QUANTITY DESCRIPTION
·
// '
,
Copy sent
YES
to
sender
ARCO Alaska, Inc. ~
Post Office B~,.. i00360
Anchorage, Alaska 99510
Telephone 907 276 1215
August 2, 1985
Mr. C. V. Chatterton
Commi s s i oner
State of Alaska
Alaska Oil & Gas Conservation
Commi ss i on
3001 Porcupine Drive
Anchorage, AK. 99501
SUBJECT: 1R-9
Dear Mr. Chatterton:
Enclosed is a Well Completion Report for 1R-9. The bottomhole
location, geologic markers, TVDs, and tubing details will be
submitted after the gyroscopic survey is run and the well
completed. Also, I have not yet received the 1R-9 Well History.
When I do, I will forward a copy to you.
If you have any questions, please call me at 263-4944.
Sincerely,
. Gruber
Associate Engineer
JG/tw
GRU10/L98
Enclosure
RECEIVED
AUG 0
Alaska Oil & Gas Cons, Commission
Anchorage
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany
STATE Of ALASKA
ALASKA ~ . AND GAS CONSERVATION CC MISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
1. Status of Well Classification of Service Well
OIL [] GAS [] SUSPENDED FXiX ABANDONED [] SERVICE []
2. Name of Operator 7. Permit Number
ARCO Alaska, Inc. 85-95
3. Address 8. APl Number
P. 0. Box 100360, Anchorage, AK 99510 50- 029-21:350
4. Location of well at surface 9. Unit or Lease Name
398' FSL, 216' FEL, Sec.18, T12N, R10E, UM Kuparuk River Unit
At Top Producing Interval 10. Well Number
To be submitted when gyro is run. 1R-9
At Total Depth 11. Field and Pool
To be submitted when gyro is run. Kuparuk River Field
5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River Oi 1 Pool
84' RKBI ADL 25635 ALK 2568
12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore I 16. No. of Completions
06/22/85 06/28/85 06/30/85I N/A feet MS LI N/A
17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+I-VD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost
2,~' ,J~l-2-7-'lvlD 8120'MD YES [] NO DIX N/A feet MDI 1600' (Approx)
~2. Type Electric or Other Logs Run
D I L/SFL/SP/Cal/GR, FDC/CNL
23. CASING, LINER AND CEMENTING RECORD
SETTING DEPTH MD
CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED
16" 62.5# H-40 Surf 112' 24" 230 sx CS II
9-5/8" 36.0# J-55 Surf 4039' 12-1/4" 1200 sx PF "E" & 375 s: PF "C"
7" 26.0# J-55 Surf 8210' 8-1/2" 300 sx Class G
~'4. 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)
None N/A
26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED
N/A
27. N/A PRODUCTION TEST
Date First Production J Method of Operation (Flowing, gas lift, etc.)
I
Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO
TEST PERIOD I~
Flow Tubing Casing Pressure CALCULATED.1~ 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
~,laska OjJ & Gas Co~s. CommissJor~
Form 10407 TEMP/WC62 Submit in duplicate
Rev. 7-1-80 CONTINUED ON REVERSE SIDE
- .
29. ' ~ ::' I ': ':' ' ~ ' ' ' ' '' ~': . ' ' ::7' *" .:' ~: ' -- ' F'ORMATION '~'
· :'GEOLOGIC MARKERS ....... TESTS '
·
NAME Include interval tested, pressure data, all fluids recovered and gravity,
MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase.
N/A N/A
.
31. LIST OF ATTACHMENTS
None ..
32. I hereby certify that the foregoing is true and correct to the best of my knowledge
Signed //~ ~ ~J.~~ Title Ass°elate Engi neet Date
INSTRUCTIONS
General: This form is designed for submitting a complete and correct well completion report and Icg 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".
SUB.SURFACE
DIRECTIONAL
SURVEY
[G~ UIDANCE'
[C-]ONTINUOUS
[TZloo,
-o .
Company
Well Name
Field/Location
SATLANTIC RICHF_ I~_E=L_D__..~OMPAbrf_ -
1R-9 (3~]~' FSL,. 216' FF.T,. S18. T12N.
.~[,T[:)_.4~Tj-~. NORT~ RLOPP.., AT.AR~'A -
Job Reference No.
70685
Loaaed By;
JOHNSON
II
Date.
R E'C £1V E D ~_~_~
/~UG i 6 1~1~5 C~mput~ S~
Alaska 0~ & Gas Corm. Comm~ssior,
Ge? DIRKC?IONA[J SURVEY
FOR
ARCO ALASKA, INC,
1. R-9
KUPARUK
SURVEY DATF~ 7-17-85
~NGINE~R) G. JOHNSON
TOmb LnCRTTON: rANGKNTIA[,- averaqed deviation and azimuth
)NTEPPOLaq'~UN: T,INEAH
VFRTICAT, SECTTON: HORTZ, DIST, PROdECTED ONTO A TARGET AZIMUTH OF NORTH 74 PEG 30 MXN W~ST
ARCO ALASKA, INC,
1R"q
KtlPARIIK
NORTH SLOPE,ALASKA
ENG~N~ER; Ge dOHNSON
INTERPOLATED VA[,UE$ FO~ EVEn 100 FEET OF MEASI.IRE'D DEPTH
PAGE 't
83000
TRUE ~[JR-SEA CDUR$~
qEA$11EED VEETICAL VERT[CAb DEVIATION AZIMUTH
DEPTH D~PTH DEPTH DEG. M[N DFG MTN
100 O0
~00.00
30~,00
400,00
500.00
600'00
700.00
800.00
~00.00
1000 O0
llO0
1~00
1300
1400
1500
1600
1700
lqO0
0 O0
100 O0
2OO 00
3OO O0
4OO O0
5OO O0
60O O0
7OO O0
8O0 O0
899 9~
999 99
O0 1009
O0 1.199
O0 1299
O0 1.399
O0 1499
O0 1599
O0 1699
O0 1799
O0 1899
-@3,00 0
17 O0 0 6
117 O0 0 10
417
51'/
617
717
816
O0 0 13
O0 0 10
O0 0 5
O0 0 5
O0 0 q
O0 0 2~
09 0 37
~16,99
9R 1016.08
1~16 97
07
98 1~16 06
96 I 16,06
95 1716,95
95 1816,95
2000.00 1999 95 1016.95
2100.00 ~009 94 2016.04
2200.00 2109 87 2116,87
2300 O0 ~299
2400'00 ~307
2~00~00 ~405
2600.00 ~591
2700,00 2686
2800.00 2779
2900.00 2871
0 41
0 36
0 31
0 26
0 26
0 27
0 29
0 30
0 3O
0 3O
0 26
0 21
3 44
34 2~16.34 7 47
98 2314.08 10 54
53 2412'83 t4 45
55 250~,55 17 11
26 2603.26 19 5~
80 2696.~0 ~1
95 2788,95 24 17
3000.00 2961 97 2878.07 27 lq
3100 oO 3049 47 2966,47 30 40
3200 O0 3134 04 3051,04 33 18
3300 O0 3217 53 3134,53 33 34
3400 O0 3300 50 3~17,59 33 53
3~00 O0 3382 97 3~99,97 35 3~
3600 ~0 3462 85 3379,85 38 26
3700 O0 3540 44 3457,44 39 17
3800,00 3616 90 3533,99 41 11
3qO0.OO 3691,21 3608.21 42 46
l'J 0 0 E
N 39 14 W
N 24 12 E
N ~1 13 E
IV 1..5 5l w
N 43 27 W
S 56 2 W
S 30 48 W
S 8 55W
$ 3 10 E
$ 3 18 E
S 1 16 W
S 5 8 W
S 7 2~ W
S 12 38 W
S 17 24 W
$ 1,6 37 W
S 14 55 W
S 11 8 w
S 2 39 W
S 24 37 w
N 68 59 W
N 64 4 w
N 69 51 W
~ 72 2; W
N 74 32 W
N 67 29 W
N 6! 46 W
N 65 2 w
N 66 34 W
N 66 47 W
N 66 50 W
N 67 41W
N 70 5~ W
N 71 13 W
N 71 32 w
N 7~ 41 W
~! 76 0 w
N 75 31~ W
SECTION SEVERITY NORTH/SOU~H EAST/WEST OlSI',' AZIMUTH
FEET DEG/tO0 FEET FEET FEET', ' OEO MXN
0,00
O,OB
0,1.6
0,09
0.04
0,04
0.15
0.30
0,48
0,52
0.25
-0.13
-0.40
79
-0. 5
'0.80
'0.91
'1.08
2.06
12.12
8.31
20.25
~8.13
110.09
144.01
182,82
~25.92
273.85
326.71
381.37
436.85
493.42
553.49
616,51
680.81
747,81
0 O0
0 33
0 08
0 09
011
0 20
0 08
0 28
0 45
0 53
0 22
0 05
0 08
010
0 O4
0
o[o
0 03
0,~3
O. ?
0 63
2 19
4 53
2 95
3 85
69
2 91
412
Il I
74
12
6t 44
ARCO AbASKA, IbC.
1R-9
KIIPAEI{K
CDHPUTATION DATEI 30-dUb-85
DATE Or SUR
ENGINEERS Ge dQHNSON
I~TERPOLATED VALUFS FOR EVEN 2,00 FEET UF HER&tIRED DEPTH
TRUE 5UR-SEA COUPGF
MEA$IIRED VERTICAL VERTYCAb DEVIATION AZIMUTH
DEPTH DEPTH DEPTH' DEG MIN DEG M~N
4000 O0 3763 61 3680 61 44 28
:
4200'00 3895 59
23 375?
96 3823
59
06 396~
47 40~
8~ 41.09
08 4181
26 425~
33 4323
23 44 9
96 44 12
44 0
06 44 ~2
47 44 29
82 44 29
08 44 35
26 44 38
33 44 43
VERTICAL
SECTION
FEET
N 73 30 w 816.77
~ 73 14 W 886 53
~ 73 27 W 956 20
~ 73 27 W 1025 98
~ 73 3~ W 1095 90
~ 73 30 W 1165 90
N 73 37 W 1235 96
~ 73 35 W 1306,1.1
N 73 33 W 1376,33
N 73 38 W 1446,68
N 73 42 W 1517,02
,, 73 38 W 1587.38
, 73 37 W 1657 67
N 73 41. W 1727 82
N 73 43 W 1797 83
e;74 2 w [867 79
N 74 9 W 1937 79
g 74 ~2 W 2007 70
N 74 23 W 2077 43
N 74 20 W 2~47 14
4100 O0 3835
O0 3906
4300 3978
4400,o0 4050
4500,00 4121
4600.00 4192
4700,00 4264
4800.00 4335
4900.00 4406
5000 O0 4477 39 4394,39 44 40
'5100'00 4548:44 4465,44 44 44
5200 O0 4619'56 4536,56 44 38
5300 O0 4690 83 4607,83 44 26
5400 O0 4.762:22 4679 44 24
5500 O0 4833,b7 4750,67 44 25
5600,00 4905,09 4822,08 44 25
5700,00 4976,59 4893,59 44 17
5800,00 504~.26 4~65,26 44 11
5900,00 5119.96 5036,9b 44 12
6000.00 5191 31 51.08.31 45 9
6100,00 5261 42 517R.¢2 45 34
6200,00
6300,00
99 5~47,08 46 2
48 5317,48 45 55
06 5387,06 46 10
57 5455,57 47 12
34 5523,34 47 14
41 5591,41 47 2
76 5659,76 46 45
41 572~,41 46 28
~330
5400
6400,00 5470
650O O0 5538
6600:00 5606
6700.00 5674
6800.00 5742
6900.00 5811
7000 O0 5879 49 5796,49 47 43
7100 O0 5947 O~ 5864,02 47 21
5931,07
6n00,71
97 46 59
71 46 IR
29 6070.29 45 33
72 6140.72 44 41
51 6712.51 43 51
70 6284,70 43 42
03 6357.03 43 32
69 6429.69 43 18
7200 O0 6014
7300 O0 60~3
7400 00 6153
7500 O0 6223
7600 O0 6295
77OO oO 6367
7800 00 6440
7900,00 6512
~i 75 29 W 2217 20
~ 76 t W 2288
N 76 a W 2360
~] 76 7 W 2432
~{ 76 13 w 2503
~ 77 2 ~ 2576
~ 77 44 W 2650
N 77 33 ~ 2723
N 77 31 W 2796
~ 77 31 W 2868
49
30
t7
96
76
t9
34
23
84
N 77 50 W 2941,96
N 77 44 W 3015.59
N 77 48 W 3088,84
N 77 43 W 3161.35
~ 77 44 W 3233.06
N 77 24 W 3303,94
h~ 76 56 W 3373.48
~ 76 55 W 344~.6~
~J 7b 44 W 3511,61
f~ 76 47 W 3580,26
PAGg 2
83'00
DOGLEG RgCTANGULRR COORD!HA.TTS HnJR~Z?EPARTURE
~IMUTH
2 43
0 58
0 57
0 18
0 15
011.
0 20
0 23
0 8
0,09
05
0,50
0,70
39
2 11
0 91
0 58
0 44
1 91
0 57
0 46
0 3¢
1 04
0 35
0 69
0 68
0 94
I 52
0
o II
0 35
1 O7
2
302
322
342
362
382
401
421
441
461
481
501
520
540
559
579
598
6
~54
71
88
O6
.o
71
87
30 N 774
75 N 841
68 N 908
97
60 N 10452
45 ~;
34 N 1109
6 ~ 1176
4 N 1243
81 N 13tl
70 N 1378
47 N 't. 446
O6 N 15
8O N 1648
04 N ! 850
94 N 19
74 N 2051
24 21~9
63 ~ 2188
09 ~ 2258
2328
29 2397
17 ~ 2468
05 2540
74 ~ 2612
48 ~ 268{
i8 N 2754
818,77 2825
834,32 ~ 2898
849,88 2969
865,28 ~ 3040
880,52 31!0
895,77 ~ 3180
921,27 3248
926,93 ~ 3315
942.67 3382
958,$9 ~ 3449
8 6 W 8il
W 86:
34 W 961
42 W 1
62 W 123~
93 W 130~
29 W 137'
78 W 1447
N 7, i5 W
Ui 4W
'9.N , 0'"
80 N 7 4, W
30 W 154~
83 W 15
W 1728
79 W I 9
o, .
34 W 1938
87 W
44 ~ 22i8
60 2289
34 236t
15 ~ 2432
88 ~ 2504
5410 ~ 2723
38 2796
37 ~ 2869
ARCO AI~ASKA,
KLIPARIIK
NORTH St, OPE,ALASKA
COMPUTATION DAT£;'
'0r suRvEY~
BUSHING ff:L, ICVATZONi
PAGE '
ENGINEERI G' OOHNSON
INTF,,RPOT~ATED VAbUES FOR EVEN lO0 FEET OF MEAMURED DEPTH
r
93.00 r!
DEPTH D~PTH DEPTH DEG,MIN DKG M~N
VERTTCAi~ DOGhEG RECTANGULAR COORDINATES
SEC?IOH SEVERITY NORTH/SOUTH EAST/NfS!
FEET DEG/IO0 FEET FEET
8nO0.O0 6585 75 b502.~5 42 50
8,00,00 6659i1~. 6576,~ 42 4!
8900.00 6732 6] 664q. 42 41
8225.00 6751,00 6668,00 42 42
N 76 34 W 3648,50
N 76 17 W 3716.41
~ 76 17 W 3784.18
N 76 17 W 380{,12
, Di~N
F[I[T,,",'
O0
O0
APC~ AbASKA, ~HC,
KUPAEI!K
N~RTH SLOPE,ALASKA
COMPUTATION DATE: 30-JUb-85
DATE
KEb[,,¥ BUSH]:NC,¥1~L,~VATZONI
TaU~ SUR-SEA
DEPTH DEPTtt DEPTH DEG
0.00 0 O0 =83 O0 0 0
1000 O0 999 99 916:99 0 4~
2000:.~0 ~999 9~ ~916,95 0 26
]000 O0 ~96~ 97 2~78,97 27 19
4000:00 ]7~ 61 3680,61 44
5000~00 4477 ~9 4~94'~9 44 40
6000,00 5191 31 510R.31 45 9
7000.00 5879.49 5?96,49 47 43
8000.00 6585,75 6~0~,75 42 50
8225.00 6751,00 6668,00 42 4!
ENGTNEERI G,. JOHNSON
0 O0
0:22
0 6~
2 26
2 4}
0 09
t 04
[ 42
0 O0
,52
: I 0,
654,24
818.77
3664,
lOlOe
N 0 0 g 0,00
S 3 10 g 0,25
S 2 39 W -0 91
N 66 34 W ~25 92
N 73 30 W 816 77
N 73 42 W 1517 02
N 75 29 w 2217 ~0
F 77 5~ W 2941 96
~ 76 34 W 3648 50
N 76 17 W
INTERPObATED VALUES FOE EVEN ~000 FFET OF MEASURED DEPT
VERTTCAb DOC, bEG RECTANGUEAR COORDINATES HORZZ,, DEpARTuRE
~ECTXON SEVERITY NORTH/SOUTH EAST/WEST DISUSe: AZXMUTH
FEET DES/1 O0 FEET FEET FEE]~,, ", DEG. MXN
ARCO AbASKA, 1'NC.
1R"9
KI.IPARI1K
NORTH ,St, OPE,ALASKA
~RU~ SUR-SEA COURSE
[EASURFD VERTICAL VERT~CAb DEVIATION AZIMUTH
DEPTH DEPTH DEPTH DEG
0.00
83.00
183 oO
283 oO
38] O0
483 O0
583 00
783,O0
883,01
000
83 O0
183 O0
283 OO
383 O0
483 O0
5R3 O0
683 O0
783 O0
883 O0
COMPUTATION.DATE~ 30-JUb-85
,.
ENGINEERt G,'JOHN$ON
ZNTERPOCATED VAI, UE$ FOR EVEN ~00 FEET OF SUB-SEA DEPTH
VERTICAD DOGLEG RECTANGUbAR coORDiNATES HOR~,, DEPARTURE
SECTION SEVERITY NORTH/SOUTH EAST/NEST DIST..: AZINU~H
FEET DEG/~O0 FEET FEET r~E~:: 'DE~ N~N
98],01
108~ 02 tO03
02 1183
118~ 03 1283
128
1383
168~
178;
03 1383
03 1483
04 15R3
O4 1683
04 17R3
05 !883
-8t O0 0 0 m 0 0 ~
0:00, 0 5 N 66 4 W
100,00 0 g N 17 18 E
200,00 0 13 N ~5 3~ E
300,00 0 11 N 20 1~ $
40n,O0 0 6 N 2 0 E
500,00 0 5 N 39 10 W
600,00 0 7 S 68 q W
700,00 0 18 S 35 2t W
800,00 0 35 S 12 I0 W
gOO O0 0 42
$ 0 45 E
O0 0 36 8 3 39 E
O0 0 30 S 0 13 E
O0 0 26 S 4 33 W
O0 0 26 S 7 21 W
nO 0 26 S 11 25 W
O0 0 29 S 17 25 w
O0 0 29 ~ {6 43 w
O0 0 30 $ 15 35 w
oO 0 29 S 10 23 W
983 O0
O0 1000
O0 1100
O0
GO
OO 1400
O0 1500
O0 1600
O0 1700
O0 1800
S 6 27 w
$ 6 3 E
N 71 46 W
N 69 50 W
N 72 41. W
N 75 3 W
N 67 45 W
N 61 37 W
N 65 52 W
108],05 ~.983 O0 lO00,00 0 29
2083,05 2083 O0 2000'00 0 14
2183,09 2183 O0 2100,00 3 2
2783,52 2283 O0 2~00.00 7
2384,75 2383 O0 2300,00 10 27
2487,07 ~4~3
2591,o6 ~583 O0 2500,00 17 0
2696,53 ~6R3 O0 2600,00 19 48
2803,44 ~7~3 O0 2?00,00 ~1 36
2912,14 2883 O0 2800,00 2439
3023,72 2983 O0 2000,00 27 5T
313q,25 3083
3~58,63 1183
3378,83 3283 O0 3~00.00 33 51
O0 3000,00 11 50
O0 3i00,00 33 22
O0 3300.00 35 32
O0 3400.00 38 59
O0 3500,n0 40 2
O0 3600,00 42 36
O0 3~00,00 44 28
O0 3800,00 44 13
N 65 45 W
N 66 53 W
~' 68 4 W
N 70 44 W
~ 71 13 w
N 71 40 W
N 76 37 W
N 75 44 W
N 72 55 W
N 73 22 W
3~00,n4 3383
3625.85 3483
3755.21 3583
3888,~1 3683
4027.24 3783
4i66.58 3883
0,00
0.06
0 16
OilO
0 O4
0,02
0,13
0,27
0,45
0,54
0,31
-0.07
'0,37
-0,57
-0,70
'0,79
-0 80
,
-0.77
-0,75
'0.79
-0,89
-1.07
1,06
10,01
25,49
47,01
75,50
108,92
146,14
187.77
236,80
294.08
358,75
425,08
493.45
569,66
651,67
740,22
835.90
932.91
0 O0
0 28
0 17
0 05
0 35
0 26
0 07
0 27
0 35
0 43
0 09
0 0.t
0 18
0 005
0 ~
5
00 oO7.
0 07
0 0
0 14
o
4
~ 3O
4 O6
2 27
3 86
2 70
3 35
3 63
2 O0
0 15
3 O3
1 65
2 30
0 $~
0 O0 N
00i N
0 23 N
o
0 N
1 20 N
133 N
I 39 N
I 12 N
0 39 N
0748
8
3688
44 S
~,20 S
5998
6,84 S'
698
56 $
9466
1004 S
9938
6 ,59 S
0478
0 O0 E
O06W
0 10 W
0 04E
0 22 E
031 'g
024£
0 10£
0 16W
045W
0,53 W
044W'
040W
043W
0 51 W
0 63 W
084W
0 ~
1 70 W
I 68 W
3 86W
12 2! W
26 58 W
PAGE 5
83,00 trT
,i
24
40
60
2333 ~ 14(
10 W 161
25
47,N 82 l~ W
75 ,N, 79 ~'
O~ '~'~ ,)
76,74 295,13 . 69
127,82 36 85 , ~ 69
4~6.49
151.92 ~ '
98,99 94 69
174.22, 463.75
220,74 04
. 74
267.84 793.17 8 ~'~ 71
ARCO
1R..q
KIIPa, RtlK
NORTH SI, OPE,ALASKA
TRUE SUB-SEA COURSE
MEASURED VFRTICAL VERTZCAb DEviATION AZIMUTH
DEPTH DEPTH DEPTH DEG NTN PEG MTN
KEbbY BUSHING EbEVATZONi
ENGXNEERI Ge~dOHN$ON
ZNTERPOLATED VAbUE5 FOR EVEN 100 FEET OF SUB-SEA DEPTH
VERTICAb DO,bEG
FEET DE~/[O0
4306,17 3983
4446,10 4083
4586,24 4183
4726,58 4283
4se7 3'93
5007:89 44'8'3
5148,~2 4583
5~89 04 4593
5429:07 47~3
5569.0b 4883
O0 3900,.00 44 20
O0 4000.00 44 25
O0 4~00~00 44 28
O0 4200,00 44 36
oo" oo.oo
oo 400;00 40
oo4soo.oo
O0 460o~00 44 26
OO 4700,00 44 22
O0 4~00~00 44 26
5988 ~1 51~3
6130 91 5283
6~74 ~7 538]
6418 75 548
656~ 59 5583
67t ,62 5683
6858.73 ~783
7005,23 5883
O0 4900.00 44 17
O0 5000.00 44 11
O0 5100.00 44 58
O0 5~00.00 45 50
O0 5300.00 45 56
O0 5400.00 46 20
O0 5500,00 47 lq
O0 5600.00 47 2
O0 5?00,0o 46 37
O0 5900,00 47 44
7153 03 5983 On 590o.o0 47 10
7298:07 6083 O0 6000.00 46 19
744~.36 6183 O0 6100.00 45 20
7582,66 6283 O0 6200.00 43 51
7721.17 6383 O0 6300.00 43 43
7~59,15 6493 O0 6400°00 43 20
7996,24 6583 O0 bson.o0 42 52
8~32,48 66~3 O0 6600,00 42 41
8225.00 675i O0 6668,00 42 41
N 73 29 W 1030,29
N 73 29 w 1128.15
N 73 36 W 1226.32
N 73 34, W 1324.77
N 73 35 W 1423 59
N 73 42 W 1522:57
N 73 37 W 1621.58
N 73 40 W 1720.15
N 73 52 W 1818.16
N 74 6 W 1916.12
N 74 13 W 2013.q7
N 74 20 W 21111.20
N 75 17 W 2208 84
N 76 6 W 23
~0
60
N 76 8 W 2414
i2
N ~6 21 W 2517 52
N 77 42 N 2624 95
N 77 32 N 2732 57
N 77 34 N 2838 94
N 77 50.N 29~5 83
N 77 46 W 3054 48
N 77 43 W 3160 60
N 77 39 W 3263 21
N 76 58 W 3361 47
N 76 53 W 3457 24
N 76 46 W 3552.22
N 76 35 W 3645,q4
N 76 17 W 3738,42
N 76 17 W 3801.12
0.16
0 19
0 17
0 14
0 3
o
0 21
0 49
0 42
0 49
72
47
2 70
0 82
0 38
1 49
0 41
0 57
0 71
0 95
0 25
13
0 4¢
0 ~!
0 95
0 O0
0 O0
PAGE 6
RECTANGUbRR COORDINATES HORX~,~'~DEPAR?URE
NORTH/SOUTH ER&T/WEST DXST~ A. ZXMUTH
FEET FEET FEET,, OgG Mia
463.546e,6 ~ '735.32'451'63 ~ ~
490e89 1546 65
518,65 ~ '
N 72 36 W
573,12 . 1829,50 W 191
20t4 98
35
o,. "'ii
62 W 24t~ 3
05
68 2625
2732
70 28~19
59 W
842,58 2936.10 6~:60 3
865,12 ~ 3039.97 ~ 105 7
3422 28
,,s,,,
1010,31N 3664.40 W 3001,12 N
ARCO
KI, IPARIIK
N~IRTH
BA$~, [.,0t~Ela ~A~D
PRTI~
CDNPUTATION DATE~ 30=JU~-85
INT£RPOLATED YAI, U~$ FOR CHOSEN HORIZONS
M~ASURBD DEPTH
7669 O0
7737 O0
7876 O0
8032 O0
81,20 O0
8225 O0
PAGE
DA?g or SURV~¥~
KEL, L¥ BUSHZNG
ENG]:NEER~ G, JOHNSON
7
B3,00 FT
SURFACE LOCATXON
AT ' R 0
~R~G~N= 398
TVD R£C~ANGUbAR?'COO~O~NAT~$
FROM KB SUB-SEA NORTH/SOUTH'EAST/NEST
;:,,,'
6345.2g 6262,29
6394 43 6311,43
6495.~5 64~2~25 9 4 55
6673.82 6590,8~ ~93.43 N 24
6751,00 6668,00 ~0~0,3~ N $&64 40
ARCO AEASKA,
1R-9
KIIPARIIK
NOETH $I,,OPE v AI, ASKA
MARKER
TOP UPPER S~Nn
BASE IIPPER SAND
TOP bOWER SAND
BAST t, OWER SAND
PRTD
TO
COMPUTATION DATE~ 30-dU[~-85
MEASURED DEPTH
BEbDW KB
7669 O0
7737 O0
7876 O0
g032 O0
g120 On
8225 OO
KEI,,b¥ BUSHI'NG E~EVATZONi
EN(;ZNEERI G. JOHNSON
SURFACE,~OcA?[ON
?V~ ' ANGUbAR"CDDRD~NAT£S
FRO~ KB SUB-SEA THt$OU~H:gAi~IWEST
6609 25 6526
6673 ~2 659 82
F'INA[, WE[.,6 L~OCAT~[ON ~T TD:
TRUE SUR-$EA
MEASURED VERTICAL VERTTCAE
DEPTH DEPTH DEPTH
8225,00 6751.00 6666,00
HORIZONTAL DEPARTURE
DISTANCE AZIMUTH
PEET DEG ~ZN
3801.t2 N 74 35 W
SCHLUMBEROER
O I RECT I ONAL SURVEY
COMPANY
ARCO ALASKA INC
WELL
1R-9
FIE'LO
KUPARUK
COUNTRY
USA
RUN ONE
DATE LOOOEO 7-17-8S
REFERENCE 00007068S
w..,.,. L~m-,..; -m-~
SURFACE LOCATION: 398' FSL, 216' FEL. S18, T12N, R10E. UM
HORIZONTAL PROJECTION
NORTH ~000 REF 00007058S
4000
9OOO
2000
1000
-1ooo
-ZOO0
SOUTH -9000
WEST
SCP, LE : 1/1000 IN/FT
tlJl t'1 ~Ii
'Ii l~i' Iii ii i ~ ~ i i i'iii i :: ~:~ ~ .... ~ .........
i ! ii J i , ~ ~ i ; i ~l j j~ i - ' 'i ........
'-T"?-t'~ ...... ~?"?'"?""'"T'"T'"t"T'*','"T"W'T"*?'" "T-~'T"'T"*~-7-~ i i i [ [ i i i i ~ ~ ~ ~ ~ i:'~ ~--~-~ ~ ~ i
-4~"P4 ..... ~'-~*~ ..... ~'+~*'4~"~-+**~ ..... ~'"~-+-+-~-~-~ . ~ ~ l~-~&~ ! ~-~--~! ! j ~ .~14~
-.~_.L.i ..... ~...L.L.~ ....... L.L..L~ ...... L.L.L.,: ..... L-L.L..L-~.4-.LL.L-~ ~' ~ -.~LLJ444-A. i i~ ~ L~
J,&4.4-k~.;...;-~-.....L..~...;..~.J_L.;..~_L_ ,YZ~]..Z$% ~ ~ ~ ~ ~ ~ ~ ~ i ~ ~%~ ~ .!, ~~2~'-'-T%~ ~ ~ i i J ~ ¢
--*~ -~i++~-H-'+H-H+'H"?,f-'H-+Hff~i ~ ~ ~~ ~.ii~ ~;~ii~ 'i~~~"-
.,.L.i...i..,i...L.4..~..4,,i...4...L,.i...;...~.,.I...;...~...;.,~ ....... ;.-;-~...&.4..4-~. ~ ~ ~ ~ ~ ~ ! ! ~ ~ ~ ~ ] , ~ .~.i.-k,...i.44; ~.~.-~4 ..... i-g4...;.4-;~;_ 4..g;-.i4..~-.~..; ....
...~,4...k~..Pk~.~--~ ....... ~---~...k~---~-;.--~-.-~.--~ ..... ~--.g.-~---~-.-PkLil !~ ! !~ ~ !~ ~4~~ ~.~..;_._.~.~~_k~z.~.~..~ ....
-+..¢..i-.k~.6.4..+.~...{..+.++-~-.i-~...¢..+..~ ....... ~...~-.~...g.~4-g¢ ~ ~ ~ ~ ~ ~ ~ ~ ~ f ~ f ! ~ ;.~pp~4.~~&..44..4_~4~..~ ,; !; ~_~.~_;_.~_,
'+?~+"bf'+'++" .+..64-6-~--+.+-+.-,-+-.H-++-+-k~--~ i ~:: ~ ~ ~: ~ ~ ~ ~ ~ ~; ~ ~ , ~ ~N ! ~ ~ ~ ~ ',
i
4...J...~-..J...;...:.-.i...J...J ...... LLL,..~...~...~.,.j,..~ ..... ~-.J...J...J...LL.LL.L._~_,L..~...~..~LLL.L_ ~-.J...J...~..L!..LL. 44-LL.i..~...J.. J.. J...: ..J.,4...J...~._.~_J...J...~....~ ...... ~,.-~..-~--.J..-~,.-J-4-.J.-. ;..1
-"f-'-~'"f--'~-'~"'f"f'"~'"~ ...... ~'-??"f-?--Y-t4 ...... ~--'f-?~'-t'--f-'H--f-~ ~ f~f-~-~ff4d-D,~ff-ff-k,-i+Df+-DDt-fl-f--D6-k~f--f.-f--~ .... ~--+++4.++-~-~-4
· -~'--!'"~'-'t'" "'~-~"'?'t'" -~-'~"~"'~'"t-t"~-~-T ..... ?'T"'w'~'~-~ -'~~ t i ~ ~"~-~?-~'-~---~-?'~-?~'~-~-w"~-~?'-t-t-~ ..... ~-.?-~.~-~-~--~---?-~
-SO00 -4000 -9000 -2000 - 1000 0 ] 000 2000 9000
EAST
WELL NAME: 1R-9
SURFACE LOCATION: 398' FSL, 216' FEL, S18, T12N, R10E, UM
VERTICAL PROJECTION
-~000 - 10~ 0 0 10~ ~000 ~0~ 4000 $0~
sooo
28S.
PROJECTION ON VERTICAL PLANE 28S. - 10S. SCi:)LEO IN VER'tICi:IL DEP'rHS
HORIZ SCALE = 1/1000 IN/FT
Suggested form to be inserted in each "Active" well folder to check
for timely compliance with our regulations.
OPERATOR, WELL~Ablg AND NUMBER
Reports and Materials to be received by:
Date
Required Date Received Remarks
Completign Report
Samples
Core Chips ~/~ '~'~ .- .~ .
Core Description
Inclination Survey .......
~ D irecti°nal Suru¢~
Drill Stem Test Reports
V oauction test ports
L6g~ Run
~ ~ , , / ' ,
.- ..... STATE OF ALASKA ~
ALASKA ~..- AND GAS CONSERVATION CO,.,MISSION
MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS
· Drilling well E~ X Workover operation []
2. Name of operator 7. Permit No.
ARCO Alaska, Inc. 85-95
3. Address 8. APl Number
P. O. Box 100360, Anchorage, AK 99510 50- 029-21350
398'
4. Location of Well
at surface
FSL, 216' FEL, Sec.18, T12N, RIOE, UM
I6. Lease Designation and Serial No.
ADL 25635 ALK 2568
For the Month of June , 19 85
5. Elevation in feet (indicate KB, DF, etc.)
84' RKB
9. Unit or Lease Name
Kuparuk River Unit
10. Well No.
1R-9
11. Field and Pool
Kuparuk River Field
Kuparuk River 0il Pool
12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks
Spudded well @ 0600 hfs, 06/22/85, Drld 12-1/4" hole to 4060', Ran, cmtd & tstd 9-5/8"
csg, Drld 8-1/2" hole to 8127'TD (6/28/85). Ran logs· Ran, cmtd, & tstd 7" csg. P§TD
= 8120', Secured well & RR ~ 0100 hfs, 6/30/85.
13. Casing or liner ru.n and quantities of cement, results of pressure tests
16" 62.'5#/ft, H-40, weld conductor set ~ 112' Cmtd w/230 sx CS' I I
9-5/8" 36 0#/ft, J-55, BTC csg w/shoe ~ 4039' Cmtd w/1200 sx PF "E" & 375 sx PF "C"
7" 26 O#/ft, J-SS, BTC csg w/shoe ~ 8210' Cmtd w/300 sx Class "C"
14. Coring resume and brief description
NONE
15. Logs run and depth where run
DIL/SFL/SP/Cal/GR f/8120' - 4032'.
FDC/CNL f/8120' - 7500', 6950' - 6250', 4750'
- 40'32' .
16. DST data, perforating data, shows of H2S, miscellaneous data
NONE
'Alaska 0ii & Gas Cons.
Anchorage
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
SIGNED &~ ~~/ TITLE Associate Engineer DATE 7'¢-~
NOT[--Repo on this form is required for each calendar month, re§ardless of the status of operations, and must be filed in duplicate with the Alaska
Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed.
Form 10404 TEMP/MR68
Submit in duplicate
MEMORANDUM State of Alaska
~fLASKA OIL AND GAS CONSERVATION COMMISSION
T o~ C. V.~~ter ton
Cha~~-~
THRU: Lonnie C. Smith
Commissioner
FROM:
Bobby Foster ~
Petroleum Inspector
DATE:
FILE NO:
TELEPHONE NO:
SU BJ ECT:
July 1, 1985
D.BDF. 48
BOPE Test on
ARCO' s 1R-9,
Permit #85-95,
Kuparuk River Field.
Tuesday, June 25, 1985: ~ne BOPE test began at 5715 am and was
~0'nclu~ed ~at~6:45 am~ As the attached BOPE test report shows,
there was one failure which was repaired and tested.
In summary, I witnessed the BOPE test on ARCO's 1R-9.
Attachment
02-001A(Rev. !0/79)
O&G #4
5/84
STATE OF ALASKA
ALASKA OIL & GAS CONSERVATION COMMISSION
B.O.P.E. Inspection Report
Location: Sec ./8 Tt~/R /~>~7~'M cJ
Drilling Contractor ~_~,~P
Location, General
:~/~ Well S _.
ping ~__Rig
General Housekee
Reserve Pit
Mud Systems Visual Audio
Trip Tank
Pit Gauge
Flow Monitor
G~s Detectors
BOPE Stack
Annular Preventer
Pipe Rams
Blind Rams
Choke Line Valves
H.C.R. Valve
Kill Line Valves
Check Valve
Test Pressure
Test Results: Failures
Date
Well /,I~/
Representative
Permit
Casing Set @ ft.
Representative ~ ~'.,, ..
Ri~ # ~
ACCUMULATOR SYSTEM
Full Charge Pressure ,_~ D3 c.~ psig
/ ,
Pressure After' Closure ~' ,~-17~-:' psig
Pump incr. clos. pres. 200 psig ~
Full Charge Pressure Attained: ~
N2 ~'~ " ' .~ ,--~ psig.
Controls: Master ~ ~
/
Remote~ ~i,~ ~ Blinds switch cover
i
· Kelly and Floor Safety Valves / Test Pressure
Upper Kelly
Lower KellM
Ball Type
Inside BOP
/ Test Pressure
/ Test Pressure ~;-"~
/ Test Pressure , ~..-
Choke Manifold,'~,~ ~.,~ Test Pressure
No. Valves "<*
No. flanges
Adjustable Chokes
H_ydrauically operated choke
/ 1//
/' Test Time /.'7 ~--~' hfs.
Repair or Replacement of failed equipment to be made within ~ days and Inspector/
Commission office notified.
f .' ~ ~/ ~/~' //
/ -
min~ see.
min, '~'" sec.
Distribution
orig. - AO&GCC
cc Operator
cc - Supervisor Inspector i C;;;' ~2'~":' Y'':~''' '~ /' ' " .... " .'~"'
ARCO Alaska, In¢
Post Office ,.ox 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
May 20, 1985
Mrs. Elaine Johnson
State of Alaska
Alaska Oil & Gas Conservation
Commi s s i on
3001 Porcupine Drive
Anchorage, AK 99501
SUBJECT:
Conductor As-Built Location Plat - 1R Pad
Wells 1-16
Dear Elaine-
Enclosed is an as-built location plat for the subject wells. If
you have any questions, please call me at 263-4944.
Sincerely,
Gruber
Associate Engineer
JG/tw
GRU6/L115
Enclosure
ARCO Alaska, Inc. is a Subsidiary o! AtlanticRichfieldCompany
WELL I Y= 5,991,050.09 Lot. = 70°23'11.370"
x = 539,829.76 Long.= 149040'33.808"
N O R T H SEC. 20 -- 154'FNL, 139'FWL
I- WELL 2 Y= 5,990,990.16 Lot = 70°23'10.781"
I
X = 539,829.82 Long. = 149°40'$3.816"
i
I SEC. 20-- ?.I4'FNL, 138'FWL
r WELL 3 Y= 5,990,9:50.24 Lot. = 70°23'10.192"
. SEC. 20-- 274'FNL, 138'FWL
! - .~:~,-,2 WELL 4 ¥= 5,990,870.26 Lot. = 70°23'09.602''
I ~; x= 539,829.77 Long. = 149°40'33.836"
Ii SEC. 20-- 334' FNL, 137' FWL
~,~ I I WELL 5 Y= 5,990,870.21 Lot. = 70o23'09.620"
S ; il6-~ I X'- 539,469.75 Long.= 149°40'44.377"
SEC. 19- $$2'FNL, 223'FEL
~ : , WELL 6 Y=5,990,930.21 Let.= 70°23'10.210''
i i i
I ] i ~ X= 539,469.74 Long. = 149°40'44.368''
I ~ ~ SEC. 19 -- 272' FNL, 222'FEL
WELL 7 Y= 5,990,990.2:5 Lo,.. = 70°23'~0.800''
X = 539,469.76 Long. = 149o40'44.558"
SEC. 19 -- 212' FNL, 222'FEL
----~ss~0 WELL 8 Y= 5,991,050.20 Lot. = 70°23'll.390"
X= 539,469.73 Long. = 149°40'44.350"
, SEC. 19 -- 152' FNL,221'FEL
~~.~.~= ~ '~ WELL 9 ~= 5,991,600.16 Let. = 70°23'16.8~"
7 ~ ~ i ~ x = 5~9,~9.91 Lon~.= 149°4d44.259"
' ' . SEC. 18 -- 398' FSL~ 216'FEL
~ WELL 10 Y=5,991,660.11 L~t.= 70°23'17.389"
! X = 539~469.82 Long. = 149°40'~.~5~"
~ L~ WELL ii ~= 5,991,720.17 L~t. = 70023'17.980"
, X = 539~9.81 Long.= 149°~'44.244''
I ] ~ SEC. 18 -- 518' FSk,~15'FEL
: WELL 12 ~= 5,991,780.16 Lot. = 7~2~'18.570"
X = 539~469.78 Long. = 149°40'44.2~5"
SEC. 18 -- 578'FSL~215'FEL
DRILL SITE ,"=~oo' WELL 13 ~= 5,991,780.16 Lot. = 70°23'18.551"
· X = 539,829.73 Long. = 149°40'33.695"
AS-BUILT CONDUCTOR L~ATIONS s~c.~7 - 576'ESL, 145'F~
WITHIN SECTIONS 17,18,19 ~ 20, TI2N,EIOE, U.M. WELL 14 ~ = 5,991,720.13 L~t. = 70°23'17.961"
x = 539~829.71 Long.= 149°40'33.705''
NOTE: SEC.17 -- 516' FSL, 145'FWL
COORDINATES ARE ALASKA STATE PLANE~ Z0N[ 4. WELL 15 Y: 5,991,660.19 Let. = 70023' 17.~71"
SECTION LINE DISTANCES ARE TRUE. X= 539~829.71 Long.= 149°40'3~.715''
HORIZONTAL 6 VE~ICAL POSITIONS PER L.H.E SURVEYORS, SEC. 17 -- 456'FSL, 144'FWL
DOCUMENT NO. 129: N 19+69 N ~7+~5 WELL J6 Y = 5,991,600.20 Lat. = 70°23' 16.781"
E 9~6 ~ E 15+25 X = 539~829.77 Long.= 149°40'~.722''
EL.50.59 EL.38.75 SEC. 17-- 396~FSL~ 144'FWL
CERTIFICATE OF SURVEYOR: I HEREBY CERTIFY THAT I AM PROPERLY
' REGISTERED AND LICENSED TO PRACTICE LAND ~~~ ~
. SURVEYING IN THE STATE OF ALASKA ~D THAT ~ Off A/ ~tt
THIS PLAT REPRESENTS A LOCATION SURVEY ~~ -e~eee-~ ~-.
MADE aY ME OR UNDER MY SUPERVISION, AND ~~,''' ~''%, 02'1.
n ~ ~ ~J~ ' ARE caRREl. ' ~ .e ~ % -~
:' ~ ' · ~
,.11 FOR. ARCO Alaska, Inc. g
:: DATE MAYg~1985 ~ ~ % F ROBERT 8E~ : ~
,-~,,, -- ,,.. ,--,~ " ' PO-" I p -,,
CHECKED J HERMAN AO '~ 'o. Gorrut~; ~OFE~SION~L~~
3340ArcticBou/ovat~,Suite20,,Anchorsge, Alask, 99503 ]~ !
. . IlaOa ~. 85029 I "' ~~--
May 17, 1985
Mr. J. B. Kewin
Area Drilling Engineer
ARCO Alaska, Inc.
P. O. Box 100360
.~nchorage, Alaska 99510-0360
Re: Kuparuk River Unit 1R-9
ARCO Alaska, Inc.
Permit No. 85-95
Sur. LOc. 398'FSL, 216'FEL, Sec. 18, T12N, R10E, UM.
Btmhole Loc. 1400'FSL, 1040'~L, Sec. 18, T12N, R].0E, UM.
Dear Mr. Kewin:
Enclosed is the approved application for permit to drill the
above referenced well.
If coring is conducted, a brief description of each core and a
one cubic inch size chip from each foot of recovered core is
required. Samples of drill cuttings and a mud log are not
required. A continuous directional survey is required as per
20 AAC 25.050(b)(5). If available, a tape containing the
digitized log information shall be submitted on all logs for
copying except experimental logs, velocity surveys and dipmeter
surveys.
Many rivers in Alaska and their, drainage systems have been
classified as important for the spawning or migration of
anadromous fish. Operations in these areas are subject to
AS 16.05.870 and the regulations promulgated thereunder (Title 5,
Alaska Administrative Code). Prior to commencing operations you
may be contacted by the Habitat Coordinator's Office, Department
of Fish and Game.
Pollution of any waters of the State is prohibited by AS 46,
Chapter 3, Article 7 and the regulations promulgated thereunder
(Title 18, Alaska Administrative Code, Chapter 70) and by the
Federal Water Pollution Control Act, as amended. Prior to
commencing operations you may be contacted by a representative of
the Department of Environmental Conservation.
!~ir. Jeffrey B. Kewin
Kuparuk River Unit 1R-9
-2- May 17, 1985
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. ~ere a diverter system is required,
please also notify this office 24 hours prior to commencing
equipment installation so that the Com~_ission may witness testing
before drilling below the shoe of the conductor pipe.
In the event of suspension or abandonment, please give this
office adequate advance notification so that we may have a
witness present.
Very tru~ly yours, _
/
Chaiman of
Alaska Oil and Gas Conservation Co~ission
BY O~ER OF nE COMMISSION
be
Enclosure
CC:
Department of Fish & Game, Habitat Section w/o encl.
Department of Environmental Conservation w/o encl.
Mr. Doug L. Lowery
ARCO Alaska, Inc. :~'"
Post Office B~._. 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
May 9, 1985
Mr. C. V. Chatterton
Commi ssi oner
State of Alaska
Alaska Oil & Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, AK 99501
SUBJECT: Kuparuk 1R-9
Dear Mr. Chatterton:
Enclosed are:
° An application for Permit to Drill Kuparuk 1R-9, along with
a $100 application fee
° Diagrams showing the proposed horizontal and vertical
projections of the wellbore
° A proximity plat
° A diagram and description of the surface hole diverter
system
o A diagram and description of the BOP equipment
We estimate spudding this well on May 26, 1985. If you have any
questions, please call me at 263-4970.
Sincerely,
d. B. Kewin
Area Drilling Engineer
JBK/HRE/tw
PD/L83
Attachments
1 0
Alaska 0JJ & Gas Cons. Commission
Anchorage
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany
f ', STATE OF ALASKA ~-
ALASKA L.,L AND GAS CONSERVATION CO,,,MISSION
PERMIT TO DRILL
20 AAC 25.O05
la. Type of work.
DRILL [~]X
REDRILL []
DEEPEN []
lb. Type of well
2. Nameofoperator
ARCO Alaska, Inc.
3. Address
P. 0. Box 100360, Anchorage, Alaska 99510
4. Location of well at surface
398' FSL, 216' FEL, Sec.18, T12N, R10E, UH
At top of proposed producing interval
1290' FSL, 1312' FWL, Se¢.18, T12N, R10E, UH
At total depth
1400' FSL, 1040' FWL, Sec.18, T12N, R10E, UM
5. Elevation in feet (indicate KB, DF etc.)
RKB 84', PAD 47'
EXPLORATORY []
DEVELOPMENT OIL E~x
DEVE~PMENT GAS []
6. Lease designation and serial no.
ADL 25635 ALK 2568
SERVICE [] STRATIGRAPHIC []
SINGLE ZONE []
MULTIPLE ZONE E~X
9. Unit or lease name
Kuparuk River Unit
10. Well number
1R-9
11. Field and pool
Kuparuk River Field
Kuparuk River Oil Pool
12. Bond information (see 20 AAC 25.025) Federal Insurance Company
Type Statewide Surety and/or number #8088-26-27
13. Distance and direction from nearest town
30 mi. NW of Deadhorse miles
16. Proposed depth (MD & TVD)
8215' MD, 6705' TVD
feet
14. Distance to nearest property or lease line
1040' @ TD feet
17. Number of acres in lease
2560
Amount $500,000
t15. Distance to nearest drilling or completed
R-8 well 550' ~ surface feet
18. Approximate spud date
05/26/85
19. If deviated (see 20 AAC 25.050) 20. Anticipated pressures 2850 psig@ 80OF Surface
KICK OFF POINT 2100 feet. MAXIMUM HOLE ANGLE 45 o (see 20 AAC 25.035 (c) (2) 3276 psig@ 555¢4 ft. TD (TVD)
21
Proposed Casing, Liner and Cementing Program
SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT
Hole Casing Weight Grade CouplingI Length MD TOP TVD MD BOTTOM TVD (include stage data)
' / 115'
i24" 16" 62.5# H-40 Wel~ 80' 35' Ii 35' 115' + ?Nfl_ e.f Pnl ¢_.~f_ _
]12-1/4" 9-5/8" 36.0# J-55 BTC/ 4061' 35' I 35' 4096' I 3800' 1200 sx Permafrost "F"
/
" HF-ERW I I 375 sx Permafrost "C"
I
i8-1/2" 7" 26.0# J-55 BTC 8181' 34' I 34' 8215' I 6705' 270 sx Class G nea~;
I
HF-ERW / I
I
I
22. Describe proposed program:
ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 8215'MD (6705'TVD).
A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The
9-5/8" casing will be set through the West Sak Sands at approximately 4096'MD (3800'TVD). A 13-5/8", 5000 psi,
RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly
thereafter. Test pressure will be 3000 psig (3000 psi for annular). Expected maximum surface pressure is 2850
psi. Pressure calculations are based on latest reservoir pressure. Surface pressure is calculated with an
unexpanded gas bubble at surface, including temperature effects. Selected intervals will be logged. The well
will be completed, using the workover rig, with 2-7/8", 6/5#, J-55, EUE 8rd tbg. Non-freezing fluids will be
left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the
Kuparuk formation and reported on subsequent reports. A downhole safety valve will be (see attached sheet)
23. I hereby certify that the foregoing is true and correct to the best of my knowledge
The space below for CommIssIon use
CONDITIONS OF APPROVAL
Samples required
[]YES ~O
Permit number
APPROVED BY
Form 10-401
(HRE) PD/PD83
Mud Icg required
[]YES J~NO
Approval date
/////./
· 1//./,.,-_ I/
Directional Survey required
i E~:f._ES i-)NO
APl number
50- 0 ~-q --t.~
SEE COVER LETTER FOR OTHER REQUIREMENTS
,COMMISSIONER DATE Hay ]7, ]985
by order of the Commission
Submit in triplicate
PERMIT TO DRILL
1R-9
installed and tested upon completion of the job. 1R-9 will be the fifth well drilled on the pad. It is +550'
away from 1R-8 at surface. There are no other close wellbores anywhere downhole. Top of cement for the
production string will be placed at 6600'MD, approximately IO00'MD above the top of the Kuparuk Sands. Reserve
pit fluids will be disposed of down the 9-5/8" x 7" annulus. The 9-5/8" x ?" annulus will be left with a
non-freezing fluid during any interruptions in the disposal~ After the completion rig has moved off
location, the well will be fracture stimulated.
e£C£1V£D
] o
4/a~',~a. , ]905
~,:,~ 7`5 [:Ofl~,.
*', l~/lOl.o~¢
HORIZONTAL PROJECTION
SCALE 1 IN. = 1000 FEET
ARCO ALASKA. iNC. /1IX
PAD 1R. WELL NO, 9 PROPOSED
KUPARUK FIELD, NORTH SLOPE. ALASKA
EASTMAN WHIPSTOCK, INC.
SO00
3000 ~
2000 _
Z
0
~ 1000 _
C
1 000 _
TAR~E:T CE#TER
#O~T# ~
VEST 344)1
WEST-EAST
4000 3000 2000 1000
i I I .i ,I ..... I
TAR~T
1320' IrsL. I~0' FVL
SEC. 18. T121'1.
zC;24' (TOTARGET)
1 000
,I
SURFACE LOGATIO#.
· 1~' F~I.. 216' FEL
SEC. 18. T12N. RIOE
AROO ALASKA, INC.
PAD. TR. WELL NO,.9 PROPOSED
KUPARUK FIELD. NORTH SLOPE.
EASTI~H WH!PSTOCK, !HC.
ALASKA
BASE PERIIAFROST T~D,, ! 634
KOP T~D'21 O0 1~!B= 21(30' DEP=O
PER tOO IrT
lsa~ TOP UGNU .SNDS TVD-2684 TPID-2694 DEP-91
- X-ae tOP 14 SAK SNDS 1'VD-~59 r14D-34r$ DEP-474
~./_L_~ ..... ~ EOC TVD-3~454 Tm-3605 DEP-$63
:i:.'.'~ F:- X K-12 TVD-. :~ Tm=3g3L DEP=?94.
--' . '~x ese P~ ~v~-~.oo ~.o +o~ OEP .~
~-~ ~:~-~-' ~:~-- -: ~ AVERA~ ANGLE .....
sooo ~5 ~0 9 HIN
~ TVD-5534 T~6554 ~P 2654
6000_ ~
, ~ UPPR SNDS TVD-6284 T~-TGle ~P-3408
,~ ',TARGET ~TR TVD-6399 T~-7781 ~P-3524
TD (LO8 PT) TVD-6~O~ T~-821~ DEP-38~l
TO00 ,,,
0 1 000 2000 ~000 4000
VERTICAL SECTION
RECEIVED
MAY 1 o 198§
Alaska Oil & Gas Cons. Commission
Anchorage
9'00
30 _
00
O0
O0
800
NORTH
?00 6O0 SO0 400
34~
2O28
3,141
ARCO ALASKA. INC.
PAD IR. gEL. L NO. 9-10-11-12 PROPOSED
KUPMIt,I~ FIELD. NORTH SLOPE. ALASKA
EASTI"tN~ IMIPSTOCK, INC.
· ,
;
WELL PATHS EXTNED BEYOND THiS VIEWIHG.wI~DOM.~.
NOTE'
30O
200
1 O0
.__ 0 o~
1'0
7
I.
2.
3.
4.
.
Surface Diverter System
16" - 2000 psi Tankco starting head.
Tankco quick connect assy.
16" x 20" 2000 psi double studded adapter.
20' 2000 psi drilling, spool w/lO" side
outl el~. ·
10" ball valves, hydraulically actuated,
w/lO' lines to reserve pit. Valves t~ open
automal~ically upon closure of annular
preventer.
20' 2000 psi annular'preventer.
20" bell nipple.
·
.
Maintenance & operation
m
Upon initial installation close annular
preventer and verify that ball valves have
open~ properly.
Close annular preventer and blow air
through dive.er lines 'even 12 hours.
Close-'annular preventer in Me event. Mat
gas or fluid flow to su~ace is detected.
If necessa~, manually override and close
ball valve to u~nwind dive.er line. Oo not.
shut in well under any circumstances.
Conductor
RECEIVED
MAY i 0 1985
Alaska Oil & Gas Cons. C;ommission
Anchorage
T
6
5
3
2
!1.
Gas gons."
A~ hor~g
ACCIJIVkA_ATOR CAPACITY TI~$T
13-5/8' BOP STACK 'T'~$T
FILL BCP STACK AND ~ I~F~I.D W~TH A;~IC
~ ~T ~L L~ ~ ~ IN
~Y ~~ ~T TEST
~TH ~I~ JT ~ ~ IN L~
L~ V~ ~~ TO ~
~~ TO 0 ~.
L~ V~ ~ T~ PZ~ ~ ~ ~ V~
~ KI~ ~ ~ LI~.
~ A ~ ~ L~ ~ ~ ~I ~. ~T ~ IN
~ ~ ~L ~I~ ~~ SE~ ~, ~Y
F~]i~ }~] ~5 T~] ~ ~ F~Y ~.
~I.
~F~ ~ LI~ ~ F~
~UI~ ~ ~ V~ IN ~I~I~ ~ITI~
~ ~I.
~E~Y ~~ F~I~Y ~~ ~ ~ILY.
5100~4001
Iq~v I
CHECK LIST FOR NEW WELL PERMITS
Company
Lease & Well No.
ITEM APPROVE DATE
(1) Fee ~' ?"'~"L~ ~ ~'~ ......
,,'
( 2 ) g o c : ,/'--X_ ..... ii''I''/7
(2 thru 8)
(3) Admin
(9""t hru 1"2~ "~
-,:., ,~, ,:" ,~/ ,..-
(10 and 12)
le
me
3.
4.
5.
6.
7.
8.
e
10.
11.
12.
YES NO
Is the permit fee attached ............. .. .......................
ee · · · ., ~ ,
Is well to be located in a defined pool ............................. ~ ......
Is well located proper distance from property line ..................
Is ~ell .located proper distance from other wells ....................
Is sufficient undedicated acreage available in this pool ............
Is well to be deviated and is wellbore plat included
Is operator the only affected party .................................
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 ..................................... ~'
REMARKS
(4) iCas~ /J~
(13 thru ~21)
13.
14.
15.
16.
17.
18.
19.
20.
21.
Is conductor string provided ......................... , ..... , ........
.........
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 surface casing protect fresh water zones .......................
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 ........ ; ...................
(5) BOPE ~/~ ~,,//-~/...%'~
(22 thr~ 26)
22.
23.
24.
25.
26.
27.
Is a diverter system required ....................................... '~'~r~
Are necessary diagrams of diverter and BOP equipment attached .......
Does BOPE have sufficient pressure rating - Test to ~7¢;r~::.~ psig ..
Does the choke manifold comply w/API RP-53 (Feb.78) ..................
Is the presence of H2S gas probable .................................
Additional requirements .............................................
Additional Remarks:
rev: 03/13/85
6.011
INITIAL GEO. UNIT ON/OFF
POOL CLASS STATUS AREA NO. 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 APPENDIX. ,
No special effort has been made to chronologically
organize this category of information.
LiS T &P'E
VE~RiF.iCATION LiI ST lIN !,~
LVP OiO.HOZ VE,RIFISATi3N LiSTiNG PAGE
S,ERVZC: '.,N A ~ E
DATE :85/07/ 6
ORiGiN :OOgO
TAPE N&ME :0601
CO~TiN~ATZ~N m :01
PR~V~G~S T~P~ :
C~MMENTS :
FiLE N 2 M,,E :EDIT
SERVICE NA ~,~E :
V E R S I 0 ~ ~ :
DATE :
MAXIMU~ LENGTH : lOZ~
FILE TYP,~ :
INFORMATION R£C3RDS *$
MNEM CON'T~NTS
CN : ,aRCO AtASK4 iNC
W N : i R - 9
'F N : KU P A R U K
RANG: i0~
'TOWN: 12N
SE&T: 18
COUN: N. SLOP E
CT ~Y: US ~
M N E M ,..r' O ~ T ..': N T S
PR~ES: E
g N I T T Y P' ,E 'C A T E S I i E C 0 O E
000' 000 0i5 06:5
000 000 004 065
000 0'00 03'7
,000 0.00 00'3 065'
000 000 Og3 05~
000 0'00 002 065
OOO 000 007 0~5
000 0'00 00,6 0,65
000 OOO 003 065
TYPE CATE SIZE CODE
OOO OOO 001 065
LVP O!3.HOZ VE'RiFiSATISN CiSTiNG PA~2
JO3 NUMBER AT .&CC: 706'21
RUN ml~ DATE LOGGED: 25
LC'P: L. 5. CJONE¥
J U N 5 5
CASING
TYPE FLUID
~ENSZTY
VISCOSITY
PH
PLNIO LGSS
8iT SiZ]~
R~I
R~F
RMC
'B M 'T
TO
8127'~
: 4. ZOO
87.0 OF
14.2. DJ:
MATRIX S~NDSTONE
LV'? OlJ.dOZ VERZFi"ATi~N LZSTING PAGF'-' ~
SCrILJMSE~GER L,3C, S .INCLUDED W ZTM THIS MAGNETIC
DU.~L iN~CTI.ON ,SPMERZCALi. Y F]C~JSED L~G (Oi~)
FORMaTiON SENS.iTY C~MPENSATE2 LOG {FDN)
CDMPCNSATE2 NEUTRON LO~.~ (EDN)
i~NTRY
'TYPE SiZE REPR C ,~ D'E ENTRY
Z I 65 0
~ 1 6m5
8 ~ 7 ~
9 4 65 . lin
16 1 65 1
0 i 6~ 0
LV? OIO.H02 VERiFi'ATi,}N LISTING PA:3~ ,~
DATUM SF:CZFZCATZO;~ SLDCKS
~NEM S;RVi'E S~ZRVZSE JNiT APl
13 ORDER m L:.$ T
DEPT 813,1.0000 SFLU
SP -16. 04159 GR
RHOB -32768. 0000 ORHO
NPHI 52. 5320 NCNL
OEPT 8100.0000 .SFLb
SP -28.1875 GR
RHD5 2.0859 DR~O
NPHI 55.3ZZ3 NCNL
OEPT 8000.0000 SFLU
:SP -28. 1406 SR
RHgB 2.37:11 DR'HO
NPMI 3Z..B613 NC'NL
DEPT 7900..0000 SFLU
SP -46.531,3 ~R
RHDB ,Z.52'73 DRHD
NPHI 28.7109 NCNL
D~PT '7~00,0000 SFcU
SP -29.5625 GR
RHDB Z..398~ DRdD
NPHI ,31.0059 NCNL
DENT ?700,0000 SFLU
SP -35,4063 ~G,R
RHOB ,Z.,~609 DRHO
NPHI 30 Z734 NCNL
OE P'T ? 500. DO00 SFLO
S P - 36..Z 500 G R
APi APi
YPE CLASS
I.ZO ~6
.iZO ~
0i0 Ol
310 O1
310 Ol
280 Oi
358 gl
~20 O1
000 O0
890 O0
33~ 31
330 30
2.w199 ZL~
-Z3g. ZSOO 2R
-32758°0000 NRAT
-333,$.0000 FC~L
2. 5328 ,iL 3
-23'9. 2500 GR
O. 1.392 NR AT
-.3336, 0000 FC.'~L
7..15 Z 3 I L ~
O. 0~+10 NR ~T
2,350.0000 F C ~ L
23.8437 ,iLD
60,2~37 ~R
0.0220 NRAT
26.88.0000 FCNL
3.53,6'7 iL3
0.0259 NR,AT
2398.0000 FC~L
3.7754
111.8125
0.0~,25 NRAT
2~18.0000 FC~:L
Z . ,$1,13 ~ L 2
!41.25 O0 GR
SIZE
SPL REP~
COD~
~ I 68
~ 1 68
~ 1 88
~ I 58
~ i 88
.
· - Z.39.
2.
- 23 9.
91.
780.
! 6.
80.
2.
950.
37~.
111.
2 ~
141.
7168
0273
ZSO0
02'73
BO00
7500
5000
6777
0 '000
~375
3000
8125
5477
5000
2500
CALi
RNRA
,ZLM
CALi
RNRA
,ILM
C.ALI
RNRA
~LM
.CALt
RNRA
I ;L M
CALi
RNRA
! L M
C A L I
RN:RA
i ~L M
CALl
O0000OO
GO00000
0000030
OOO0000
0000000
OOO0000
0000000
O000OO0
0000000
0000000
0000000
0000000
OOO0000
O00OOOO
PR
O0
O0
O0
30
O0
O0
O0
O0
O0
O0
O0
O0
O0
O0
O0
O000O
0000~
0000~
00000
O00OO
00003
0000~
00000
00003
00000
0000~
2.36'7,2
8.3000
3.3062
2.36~4
6,.%922
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** FILE TRAIL.ER
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