Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout195-1561. 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 7925'feet None feet
true vertical 6468'feet None feet
Effective Depth measured 7794'feet 6817', 6971'feet
true vertical 6370'feet 5656', 5767'feet
Perforation depth Measured depth
True Vertical depth
Tubing (size, grade, measured and true vertical depth)3-1/2"
3-1/2"
3-1/2"
L-80
L-80
L-80
6817'
6927'
6971'
5656'
5736'
5767'
Packers and SSSV (type, measured and true vertical depth)6817'
6971'
5656'
5767'
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure:
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:
Contact Name:
Contact Email:
Contact Phone:
4099'3688'
Burst Collapse
Liner
7140'
Casing
5920'7179'
7923'6465'
4058'
121'Conductor
Surface
Intermediate
16"
7-5/8"
80'
measured
TVD
5-1/2"
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
195-156
50-029-22589-01-00
P.O. Box 100360
Anchorage, AK 99510
3. Address:
ConocoPhillips Alaska, Inc.
N/A
5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work:
ADL0025641, ADL0025634
Kuparuk River Field/ Kuparuk Oil Pool
KRU 1Q-20A
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)
N/A
Gas-Mcf
MDSize
121'
Well Shut-In
325-009
Sr Pet Eng:Sr Pet Geo:Sr Res Eng:
WINJ WAG
Water-BblOil-Bbl
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
N/A
Packer: BAKER Packer Retainer
Packer: BAKER SABL LINER
SSSV: None
Cy Eller
cy.eller@conocophillips.com
(907) 265-6049
Authorized Name and
Digital Signature with Date:
Authorized Title: RWO/CTD Engineer
7560-7562', 7610-7640'
6198-6200', 6235-6257'
952'3-1/2"
Fra
O
s
6. A
PG
,
g
Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov
By Grace Christianson at 8:24 am, Apr 08, 2025
DSR-4/11/25
RBDMS JSB 041025
JJL 5/8/25
Page 1/5
1Q-20
Report Printed: 4/7/2025
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)
3/6/2025
12:00
3/6/2025
14:30
2.50 MIRU, MOVE WAIT T Standby for trucking support
Continue to cleanup location and load
out KDTH trucks
Get enviromental signed
0.0 0.0
3/6/2025
14:30
3/6/2025
17:30
3.00 MIRU, MOVE MOB P Trucks on location, PJSM,
Load Shop onto oilfield trailer
Hook up to halfway house and office
trailer.
0.0 0.0
3/6/2025
17:30
3/6/2025
19:30
2.00 MIRU, MOVE MOB P Mobilze Service modules F/1R-pad
T/1Q-pad
Spot in and set as per PFSR.
Dial in comms, place heater on camp
base.
0.0 0.0
3/6/2025
19:30
3/7/2025
00:00
4.50 MIRU, MOVE MOB P Mobilize Sub F/1R-pad towards 1Q-pad 0.0 0.0
3/7/2025
00:00
3/7/2025
01:00
1.00 MIRU, MOVE MOB P Continue moving Sub T/1Q-pad
Confirm prep is on 1Q-20.
0.0 0.0
3/7/2025
01:00
3/7/2025
02:00
1.00 MIRU, MOVE MOB P Arrive on location, verify all well casing
valves shut, and tree is closed in.
Confirm Prep around well and pre-line
up for spotting over well
Call Pad Op to witness backing over
well
0.0 0.0
3/7/2025
02:00
3/7/2025
04:00
2.00 MIRU, MOVE MOB P Spot in Sub over well 20, place mats,
set rig down.
Spot in Pit module, place mats, set
module down.
Raise derrick.
0.0 0.0
3/7/2025
04:00
3/7/2025
06:00
2.00 MIRU, MOVE MOB P Work post move checklist, securing all
stairs and landings.
Set up handy berm around front of rig
under fuel tanks
0.0 0.0
3/7/2025
06:00
3/7/2025
07:00
1.00 MIRU, MOVE RURD P Spot in kill tanks, cuttings tank, and RU
hardline
0.0 0.0
3/7/2025
07:00
3/7/2025
09:30
2.50 MIRU, WELCTL RURD P Rig Accepted at 07:00
Take on 8.5 ppg seawater to pits.
RU to kill the well.
0.0 0.0
3/7/2025
09:30
3/7/2025
11:30
2.00 MIRU, WELCTL KLWL P Initial pressures T/IA/OA = 200/0/0
PT circ lines to 2500 psi
Pump 262 bbls down IA taking returns
up T to tiger tank.
ICP 4BPM at 1900psi/FCP 4BPM at
1800 psi
0.0 0.0
3/7/2025
11:30
3/7/2025
12:00
0.50 MIRU, WELCTL OWFF P Flow check the well. No flow. 0.0 0.0
3/7/2025
12:00
3/7/2025
12:30
0.50 MIRU, WELCTL MPSP P Set the BPV and PT from below to 1000
psi. Good test.
0.0 0.0
3/7/2025
12:30
3/7/2025
14:30
2.00 MIRU, WHDBOP NUND P Function test the LDS. Call pad ops to
bleed SSSV.
Remove tree and adapter. Clean and
inspect hanger profile and threads.
Install left hand ACME blanking plug
10.5 turns.
0.0 0.0
3/7/2025
14:30
3/7/2025
17:00
2.50 MIRU, WHDBOP NUND P NU BOPE with 7-1/16" x 13-5/8" DSA,
TQ bolts on flanges. Install riser.
0.0 0.0
3/7/2025
17:00
3/7/2025
17:30
0.50 MIRU, WHDBOP BOPE P Obtain shell test 0.0 0.0
Rig: NABORS 7ES
RIG RELEASE DATE 3/12/2025
Page 2/5
1Q-20
Report Printed: 4/7/2025
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)
3/7/2025
17:30
3/8/2025
00:00
6.50 MIRU, WHDBOP BOPE P Start initial BOPE test 2-7/8" x 5", blinds,
annular. 250/2,500/2,500 Annular 1.)
Blind Rams, CMV, 1-2-3-16, Rig Floor
Kill, Outer Test Spool Valve, IBOP. 2.)
Blind Rams, CMV 4-5-6, HCR Kill, Inner
Test Spool Valve, Manual IBOP, PU 3.5"
Donut test joint, w/HT38 TIW, 3.) LPR,
HT-38, TIW, 4.) Annular, CMV 7-8-9.
Manual Kill. 5.) Hydraulic Super Choke
& Manual Adjustable Choke (1,500 psi
test). 6.) UPR, CMV 10-11. PU 2-7/8"
Dounut Test Joint w/3.5" EUE FOSV, 7.)
Annular, CMV 12-13-15, 2-7/8" Pac TIW,
3.5" FOSV. 8.) UPR, CMV 14, 2-7/8"
Pac Dart. 9.) HCR Choke. 10.) Manual
Choke. Perform accumulator test. Initial
pressure=1500 PSI, after closure=1500
PSI, 200 PSI attained =18 sec, full
recovery attained = 129 sec. UVBR's=
6 sec, Annular= 21 sec. Simulated
blinds= 6 sec. LVBR’s=6 sec. HCR
choke & kill= 1 sec each. 5 back up
nitrogen bottles average = 2,100 PSI.
Test gas detectors, PVT and flow show.
Test Witness Waived by AOGCC rep
Austin Mcleod
0.0 0.0
3/8/2025
00:00
3/8/2025
01:00
1.00 MIRU, WHDBOP NUND P RD testing equipment, equalize and pull
BPV and test dart
0.0 0.0
3/8/2025
01:00
3/8/2025
02:00
1.00 MIRU, WHDBOP PULL P MU 3-1/2" EUE landing joint, MU to
hanger 10-1/4" turns, pull hanger off
seat and to the RF, Hanger pulled free
at 120K, PUW= 93K
0.0 6,923.0
3/8/2025
02:00
3/8/2025
03:00
1.00 COMPZN, RPCOMP CIRC P Hanger at RF, circulate 40 bbl 8.5 ppg
Deep clean sweep, followed by 8.5 ppg
SW. Pumped SxS at 5 BPM/1800 psi.
6,923.0 6,923.0
3/8/2025
03:00
3/8/2025
04:30
1.50 COMPZN, RPCOMP TRIP P LD tubing hanger and pups.
Stand back 16 stands of tubing in
derrick.
PUW 70K
6,923.0 5,260.0
3/8/2025
04:30
3/8/2025
07:00
2.50 COMPZN, RPCOMP PUTB P LD 3.5 EUEM completion F/5260'
T/3650'
5,260.0 3,650.0
3/8/2025
07:00
3/8/2025
07:30
0.50 COMPZN, RPCOMP SVRG P Service Rig grease blocks and Blak
Jack.
3,650.0 3,650.0
3/8/2025
07:30
3/8/2025
11:00
3.50 COMPZN, RPCOMP PUTB P LD 3.5 EUEM completion F/3650'
T/Surface
UWT 52K
Pulled 213 joints and a cut joint 15.59'
3,650.0 0.0
3/8/2025
11:00
3/8/2025
13:00
2.00 COMPZN, WELLPR SLPC P Slip and cut 102' of drill line. 0.0 0.0
3/8/2025
13:00
3/8/2025
15:00
2.00 COMPZN, WELLPR BHAH P MU BHA #1 Clean out and tubing
dressoff.
2-7/8" HT PAC x 2-3/8" REG XO, 3-1/8"
drill collars x 6, 3-1/8" fishing jars, 3-1/8"
lub bumper sub, 2-3/8" REG x 2-3/8" x 2
-3/8" IF (BxP), 4-3/4" SOD string mill, 2-
3/8" IF x 4-1/2" FJWP top sub, 4-1/2"
WP estention, and 4-3/4" Crown Shoe
0.0 214.0
3/8/2025
15:00
3/8/2025
23:00
8.00 COMPZN, WELLPR TRIP P TIH, with BHA #1 F/surface T/6,850'' 214.0 6,750.0
3/8/2025
23:00
3/9/2025
00:00
1.00 COMPZN, WELLPR REAM P Rot-25 rpm, ROTQ=2,600 ft/lbs,
ROTW=91k,
Recep accross packer setting depth as
per Rep F/6,850-6,750'
6,750.0 6,922.0
Rig: NABORS 7ES
RIG RELEASE DATE 3/12/2025
Page 3/5
1Q-20
Report Printed: 4/7/2025
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)
3/9/2025
00:00
3/9/2025
03:30
3.50 COMPZN, WELLPR REAM P PUW=106k, SOW=75k
Ream down
Back ream 1 stand F/6,922' T/6,840'
Bring pump online 1.5 bpm/550 psi
TBIH, F/6,838' T/6,922'
ROT=60 rpm, ROTQ=2200 ft/lbs,
ROTW=90k
Dress off/wash 6,924', set down 5k,
PUH
Unable to get over stump, PUH, over
pull 10k, PUW=106k
6,922.0 6,922.0
3/9/2025
03:30
3/9/2025
04:30
1.00 COMPZN, WELLPR CIRC P Circulate BU w/high-vis sweep (40 bbls) 6,922.0 6,920.0
3/9/2025
04:30
3/9/2025
05:00
0.50 COMPZN, WELLPR SVRG P Grease power tongs 6,920.0 6,920.0
3/9/2025
05:00
3/9/2025
09:30
4.50 COMPZN, WELLPR TRIP P TOOH F/6905' T/213' 6,905.0 213.0
3/9/2025
09:30
3/9/2025
10:30
1.00 COMPZN, WELLPR BHAH P LD BHA #1 dress off BHA.
No indications mill engaged the stump.
213.0 0.0
3/9/2025
10:30
3/9/2025
11:00
0.50 COMPZN, WELLPR BHAH P MU BHA#2 with a cut lip.
2-7/8" HT PAC x 2-3/8" REG XO, 3-1/8"
drill collars x 6, 3-1/8" fishing jars, 3-1/8"
lub bumper sub, 2-3/8" REG x 2-3/8" x 2
-3/8" IF (BxP), 4-3/4" SOD string mill, 2-
3/8" IF x 4-1/2" FJWP top sub, 4-1/2"
WP estention, and 4-1/2" cut lip shoe.
0.0 212.2
3/9/2025
11:00
3/9/2025
14:00
3.00 COMPZN, WELLPR TRIP P TIH F/212' T/6922'
Tag at 6922' Work pipe and rotate up to
3K torque to get over
212.2 6,922.0
3/9/2025
14:00
3/9/2025
16:00
2.00 COMPZN, WELLPR MILL P Reaming and washing from tag at 6922'.
Work pipe and rotate up to 3K torque to
get over stump. MIlled a couple inches
after swallowing 10'.
6,922.0 6,932.3
3/9/2025
16:00
3/9/2025
16:45
0.75 COMPZN, WELLPR CIRC P Circulate a sweep SXS 6,932.3 6,930.0
3/9/2025
16:45
3/9/2025
20:45
4.00 COMPZN, WELLPR TRIP P TOOH, racking back DP. 6,930.0 212.2
3/9/2025
20:45
3/9/2025
22:15
1.50 COMPZN, WELLPR BHAH P LD collars to shed, BHA 212.2 0.0
3/9/2025
22:15
3/9/2025
22:45
0.50 COMPZN, WELLPR SVRG P Rig service 0.0
3/9/2025
22:45
3/9/2025
23:15
0.50 COMPZN, RPCOMP SFTY P PJSM w/crew 0.0 0.0
3/9/2025
23:15
3/10/2025
00:00
0.75 COMPZN, RPCOMP PUTB P MU lower 3.5" 9.3# L-80 completion 0.0 130.3
3/10/2025
00:00
3/10/2025
01:00
1.00 COMPZN, RPCOMP PUTB P Continue PU 3.5" completion w/Packer 101.8 126.3
3/10/2025
01:00
3/10/2025
01:30
0.50 COMPZN, RPCOMP SVRG P Service Rig 126.3 126.3
3/10/2025
01:30
3/10/2025
03:00
1.50 COMPZN, RPCOMP WAIT T Pull packer back out of hole, Pull above
rams,
Standby for XO
126.3 126.3
3/10/2025
03:00
3/10/2025
04:00
1.00 COMPZN, RPCOMP PUTB P MU Packer, and lower completion in
hole.
126.3 126.3
3/10/2025
04:00
3/10/2025
09:30
5.50 COMPZN, RPCOMP TRIP P TIH w/lower 3.5" lower completion on 2-
7/8" PAC DP F/126' T6900' at 60 FPM
UWT105K / SOW 74K
126.3 6,900.0
Rig: NABORS 7ES
RIG RELEASE DATE 3/12/2025
Page 4/5
1Q-20
Report Printed: 4/7/2025
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)
3/10/2025
09:30
3/10/2025
11:30
2.00 COMPZN, RPCOMP PACK P Dry tag stump at 6923'.
Set down 8K to shear overshot shear
screws then swallow down to 6930'.
Set down 20K to fully locate, PU 2' and
drop 1" ball.
Circulate 1BPM at 190 psi. See psi
increase to 1600 with ball on seat.
Pressure up to 3500 psi to set packer.
6,900.0 6,930.0
3/10/2025
11:30
3/10/2025
12:30
1.00 COMPZN, RPCOMP PRTS P Pressure test 5.5" IA above packer to
2500 psi for 15 minutes.
Good test.
Release from packer,
RD and BD testing equipment.
6,930.0 6,820.0
3/10/2025
12:30
3/10/2025
19:30
7.00 COMPZN, RPCOMP PULD P TOOH LD 2-7/8" HT PAC drill pipe.
UWT 103K/ SOW 74K
6,820.0 15.0
3/10/2025
19:30
3/10/2025
20:30
1.00 COMPZN, RPCOMP BHAH P LD BHA 15.0 0.0
3/10/2025
20:30
3/10/2025
22:00
1.50 COMPZN, RPCOMP TRIP P TIH with 3.5" old tubing out of derrick
F/surface T/1,500'
0.0 1,500.0
3/10/2025
22:00
3/10/2025
23:30
1.50 COMPZN, RPCOMP TRIP P TOOH, sideways laying down Old 3.5"
tubing to shed.
1,500.0 0.0
3/10/2025
23:30
3/11/2025
00:00
0.50 COMPZN, RPCOMP SVRG P Service Rig 0.0 0.0
3/11/2025
00:00
3/11/2025
01:00
1.00 COMPZN, RPCOMP PUTB P Pull wear ring
Prep to run tubing
0.0 0.0
3/11/2025
01:00
3/11/2025
01:30
0.50 COMPZN, RPCOMP PUTB P Verify tubing joint count, line up and
confirm jewelry running order.
PJSM w/crew Picking up Tubing
0.0 0.0
3/11/2025
01:30
3/11/2025
11:30
10.00 COMPZN, RPCOMP PUTB P Run 3.5" 9.3# L-80 EUE-M completion
per approved tally.
UWT 86K/SOW 69K
0.0 6,820.0
3/11/2025
11:30
3/11/2025
12:00
0.50 COMPZN, RPCOMP PACK P Set down 15K at 6922'.
PU to 125K and shear PBR at 39K over
string wt.
6,820.0 6,822.0
3/11/2025
12:00
3/11/2025
12:30
0.50 COMPZN, RPCOMP THGR P LD JTS 215,214 &213 and MU 4.18'
pup jt JT F and landing joint.
6,822.0 6,786.0
3/11/2025
12:30
3/11/2025
14:00
1.50 COMPZN, RPCOMP CIRC P RU head pin to circulate.
Reverse circulate 170 BBLs of 8.5 ppg
CI sea water @ 3.5 BBL/Min @ 1000
PSI.
6,786.0 6,786.0
3/11/2025
14:00
3/11/2025
16:30
2.50 COMPZN, RPCOMP PRTS P Land tubing hanger. RILDS. Drop 1
15/16" x 83" long ball and rod. Line up
on tubing and pressure test tubing to
3000 PSI for 30 min. Bleed tubing to
1500 PSI, and hold. Line up to pump
down annulus and pressure up to 2500
PSI for 30 min. Line up on tubing and
bleed pressure observe SOV shear, and
IA pressure drop off. Line up on IA and
reverse circulate @ 1.5 BBL/ min @
1600 PSI to verify circ path.
6,786.0 0.0
3/11/2025
16:30
3/11/2025
21:00
4.50 COMPZN, WHDBOP NUND P N/D riser, and turn buckles. Break bolts
on DSA. Change out LPR to 2 7/8" x 5"
VBR. Rack back BOP.
0.0 0.0
3/11/2025
21:00
3/11/2025
23:00
2.00 COMPZN, WHDBOP NUND P N/U Tree and adaptor flange. FMC rep
test hanger neck void to 5000 PSI for 10
min:
0.0 0.0
3/11/2025
23:00
3/12/2025
00:00
1.00 COMPZN, WHDBOP PRTS P Rig up test equipment. Fill tree with
diesel, and pressure test tree to 5000
PSI for 10 min: GOOD.
0.0 0.0
3/12/2025
00:00
3/12/2025
00:30
0.50 COMPZN, WHDBOP MPSP P FMC rep pull test dart and BPV. 0.0 0.0
Rig: NABORS 7ES
RIG RELEASE DATE 3/12/2025
Page 5/5
1Q-20
Report Printed: 4/7/2025
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)
3/12/2025
00:30
3/12/2025
02:30
2.00 COMPZN, WHDBOP FRZP P R/U and pressure test surface lines w/
LRS. Pump 50 BBLs Diesel freeze
protect down the IA @ 1.1 BBL/min @
1500 PSI.
0.0 0.0
3/12/2025
02:30
3/12/2025
03:30
1.00 DEMOB, MOVE FRZP P Line up tubing to IA and U-tube the well
for one hour.
RIG RELEASE @ 0330
0.0 0.0
Rig: NABORS 7ES
RIG RELEASE DATE 3/12/2025
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag: RKB 7,794.0 1Q-20A 12/2/2023 fergusp
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Pulled Lower Packer Assembly & Plug. Performed FCO 1Q-20A 3/29/2025 zembaej
Notes: General & Safety
Annotation End Date Last Mod By
NOTE: WELL SIDETRACKED 1/30/1996 osborl
NOTE: Original Well was P&A'd due to gas at surface & lost circulation. 6/23/1995 ninam
Casing Strings
Csg Des OD (in) ID (in) Top (ftKB)
Set Depth
(ftKB)
Set Depth
(TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread
CONDUCTOR 16 15.06 41.0 121.0 121.0 62.58 H-40 WELDED
SURFACE 7 5/8 6.87 40.9 4,099.0 3,688.4 29.70 L-80 LTC
INTERMEDIATE 5 1/2 4.95 39.1 7,179.5 5,919.6 15.50 L-80 LTC-MOD
LINER 3 1/2 2.99 6,970.7 7,923.0 9.30 L-80 BTC-MOD
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
25.3
Set Depth …
6,817.1
String Max No…
3 1/2
Set Depth …
5,656.1
Tubing Description
Tubing – Completion Upper
Wt (lb/ft)
9.30
Grade
L-80
Top Connection
EUE
ID (in)
2.99
Completion Details: excludes tubing, pup, space out, thread, RKB...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal
ID (in)
25.4 25.3 0.02 Hanger 10.860 FMC Gen 4 11" x 3-1/2" 5K EUE 8rd
x EUE 8rd tubing hanger
FMC TC1A-
EMS
2.900
2,700.4 2,595.0 35.66 Mandrel – GAS
LIFT
4.727 3.5" x 1" KBG2-9 GLM IBT x IBT S#
24410-05 (target 2709')
SLB KBG 2-9 2.818
4,508.1 3,986.4 44.06 Mandrel – GAS
LIFT
4.727 3.5" x 1" KBG2-9 GLM IBT x IBT S#
24410-03 (target 4525')
SLB KBG 2-9 2.818
5,629.0 4,800.3 46.74 Mandrel – GAS
LIFT
4.727 3.5" x 1" KBG2-9 GLM IBT x IBT S#
24410-04 (target 5627')
SLB KBG 2-9 2.818
6,748.4 5,606.3 43.54 Mandrel – GAS
LIFT
4.727 3.5" x 1" KBG2-9 GLM IBT x IBT S#
24410-02 // SOV 2000'
SLB KBG 2-9 2.818
6,801.4 5,644.7 43.52 PBR 4.780 Baker PBR, 3-1/2" EUE BxP Baker Baker 4.000
6,815.4 5,654.8 43.52 Anchor 3.980 KBH-22 Anchor Seal Assy (spaced
out 2.64')
Baker Baker 3.000
Top (ftKB)
6,817.1
Set Depth …
6,926.9
String Max No…
3 1/2
Set Depth …
5,735.7
Tubing Description
Tubing – Completion Lower
Wt (lb/ft)
9.30
Grade
L-80
Top Connection
EUE
ID (in)
2.99
Completion Details: excludes tubing, pup, space out, thread, RKB...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal
ID (in)
6,817.1 5,656.1 43.52 Packer 4.550 Packer, Retainer, 45FA36x30, 5-1/2"
x 3-1/2" (target 6830')
45FA36x
30
Baker 3.000
6,866.7 5,692.1 43.49 Nipple - X 4.500 X-Nipple w/2.813" Profile - With
RHC profile installed
HES X nipple 2.813
6,919.0 5,730.0 43.57 Overshot 4.550 3-1/2" Poor Boy Overshot - 4.55"OD
(6.90' swallow)
Baker Baker 3.750
Top (ftKB)
6,923.0
Set Depth …
6,970.7
String Max No…
3 1/2
Set Depth …
5,767.4
Tubing Description
Tubing – Completion Lower
Wt (lb/ft)
9.30
Grade
L-80
Top Connection
ABM-EUE
ID (in)
2.99
Completion Details: excludes tubing, pup, space out, thread, RKB...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal
ID (in)
6,942.7 5,747.2 43.68 NIPPLE 4.540 CAMCO D NIPPLE NO GO 2.750
6,956.0 5,756.8 43.74 PBR 4.000 BAKER 80-40 PBR w/ 10' STROKE 2.992
6,970.0 5,766.9 43.80 ANCHOR 4.500 BAKER ANCHOR (STAB INTO
SABL-3 PACKER)
2.992
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)
45.2 45.2 0.04 PATCH SURFACE CASING PATCH:
.375" Thickness; OAL 66" runs
from bottom of mandrel
hanger.
12/12/2008 7.625
Mandrel Inserts : excludes pulled inserts
Top (ftKB)
Top (TVD)
(ftKB)
Top
Incl (°)
St
ati
on
No
/S Serv
Valve
Type
Latch
Type
OD
(in)
TRO Run
(psi) Run Date Com Make Model
Port
Size (in)
2,700.4 2,595.0 35.66 1 GAS LIFT GLV BTM 1 1,300.0 3/19/2025 Camco KBG2-9 0.250
4,508.1 3,986.4 44.06 2 GAS LIFT DV BTM 1 3/11/2025 Camco KBG2-9
5,629.0 4,800.3 46.74 3 GAS LIFT GLV BTM 1 1,230.0 3/19/2025 Camco KBG2-9 0.313
6,748.4 5,606.3 43.54 4 GAS LIFT OV BTM 1 3/19/2025 Camco KBG2-9 0.250
Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal ID
(in)
6,970.7 5,767.4 43.81 PACKER 4.625 Baker 'SABL-3' LINER PACKER SABL-3 BAKER 2.815
6,974.9 5,770.4 43.82 XO THREAD 3.500 2.992
7,825.3 LANDING
COLLAR
3.500 2.992
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
7,560.0 7,562.0 UNIT B, 1Q-20A 3/22/1996 4.0 IPERF 2 1/2" Hollow Carrier; 90°
phasing
1Q-20A, 4/2/2025 11:08:36 AM
Vertical schematic (actual)
LINER; 6,970.6-7,923.0
APERF; 7,620.0-7,640.0
APERF; 7,610.0-7,620.0
IPERF; 7,560.0-7,562.0
INTERMEDIATE; 39.1-7,179.5
Nipple - X; 6,866.7
Packer; 6,817.1
Anchor; 6,815.4
Mandrel – GAS LIFT; 6,748.4
Mandrel – GAS LIFT; 5,629.0
Mandrel – GAS LIFT; 4,508.0
SURFACE; 40.9-4,099.0
Mandrel – GAS LIFT; 2,700.4
CONDUCTOR; 41.0-121.0
PATCH; 45.2
Hanger; 25.4
KUP PROD
KB-Grd (ft)
30.90
RR Date
9/17/1995
Other Elev…
1Q-20A
...
TD
Act Btm (ftKB)
7,925.0
Well Attributes
Field Name
KUPARUK RIVER UNIT
Wellbore API/UWI
500292258901
Wellbore Status
PROD
Max Angle & MD
Incl (°)
47.41
MD (ftKB)
5,518.18
WELLNAME WELLBORE1Q-20A
Annotation
Last WO:
End Date
3/12/2025
H2S (ppm)
129
Date
3/13/2022
Comment
SSSV: NIPPLE
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
7,610.0 7,620.0 A-3, 1Q-20A 4/5/1996 4.0 APERF 2 1/2" Hollow Carrier; 180°
phasing; Oriented 142° CCW
F/ High Si
7,620.0 7,640.0 A-3, 1Q-20A 4/5/1996 2.0 APERF 2 1/2" Hollow Carrier; 180°
phasing; One Side Not
Loaded
1Q-20A, 4/2/2025 11:08:37 AM
Vertical schematic (actual)
LINER; 6,970.6-7,923.0
APERF; 7,620.0-7,640.0
APERF; 7,610.0-7,620.0
IPERF; 7,560.0-7,562.0
INTERMEDIATE; 39.1-7,179.5
Nipple - X; 6,866.7
Packer; 6,817.1
Anchor; 6,815.4
Mandrel – GAS LIFT; 6,748.4
Mandrel – GAS LIFT; 5,629.0
Mandrel – GAS LIFT; 4,508.0
SURFACE; 40.9-4,099.0
Mandrel – GAS LIFT; 2,700.4
CONDUCTOR; 41.0-121.0
PATCH; 45.2
Hanger; 25.4
KUP PROD 1Q-20A
...
WELLNAME WELLBORE1Q-20A
ORIGINATED
TRANSMITTAL
DATE: 2/19/2025
ALASKA E-LINE SERVICES
TRANSMITTAL
#: 5267
42260 Kenai Spur Hwy
PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk
PH: (907) 283-7374 FAX: (907) 283-7378
DELIVERABLE DESCRIPTION
TICKET # WELL # API #
LOG
DESCRIPTION
DATE OF
LOG
5267 1Q-20A 50029225890100 Tubing Cut Record 26-Jan-2025
RECIPIENTS
Conoco
DIGITAL FILES PRINTS CD'S
1 FTP Transfer 0 0 USPS
Attn: NSK-69
Richard.E.Elgarico@conocophillips.com 700 G Street
Anchorage, AK 99503
Received
By: Received By:
Signature Signature
AOGCC
DIGITAL FILES PRINTS CD'S
1 ShareFile 0 0 USPS
Attn: Natural Resources Technician II
abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision
aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501
Received
By: Received By:
Signature Signature
195-156
T40100
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2025.02.19 15:18:34 -09'00'
DNR
DIGITAL FILES PRINTS CD'S
1 SharePoint
Link 0 0 USPS
Attn: Natural Resource Tech II
DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501
Delivery Method: USPS
Received
By: Received By:
Signature Signature
Please return via e-mail a copy to both:
AR@ake-
line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com
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
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):
7925'2104 None
Casing Collapse
Conductor
Surface
Production
Liner
Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft):
12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work:
Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service
14. Estimated Date for 15. Well Status after proposed work:
Commencing Operations:OIL WINJ WDSPL Suspended
16. Verbal Approval:Date: GAS WAG GSTOR SPLUG
AOGCC Representative: GINJ Op Shutdown Abandoned
Contact Name:
Contact Email:
Contact Phone: 907-265-6049
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
7015'
7-5/8"
80'
Baker ZXP Top Packer
Northern Solutions LWR Packer
SSSV: None
6468'7794'6370'
5-1/2"
16"
KRU 1Q-20A
7560-7562'
7610-7620'
7620-7640'
7140'
3-1/2"
6198-6200'
6235-6243'
6243-6257'
4058'
7179'
Perforation Depth MD (ft):
121'
2/15/2025
7923'952'
3-1/2"
6465'
121'
4099'
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL0025641, ADL0025634
195-156
P.O. Box 100360, Anchorage, AK 99510
ConocoPhillips Alaska, Inc
AOGCC USE ONLY
Tubing Grade:Tubing MD (ft):
6971'MD/5764'TVD
7015'MD/5799'TVD
6971'
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.
Proposed Pools:
3688'
Burst
Authorized Name and
Digital Signature with Date:
Tubing Size:
PRESENT WELL CONDITION SUMMARY
Length Size
Kuparuk River Field
TVD
Perforation Depth TVD (ft):
MD
5920'
Cy Eller
cy.eller@conocophillips.com
CTD/RWO Engineer
Subsequent Form Required:
Suspension Expiration Date:
L-80
m
n
P
s
1
66
t
g
N
Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
50-029-22589-01-00
-DQ
By Grace Christianson at 1:33 pm, Jan 10, 2025
325-009
10-404
DSR-1/16/25
AOGCC Witnessed BOP and Annular Test to 2500 psi
SFD 1/24/2025
X
JJL 1/14/25*&:
Jessie L.
Chmielowski
Digitally signed by Jessie L.
Chmielowski
Date: 2025.01.24 14:52:56 -09'00'01/24/25
RBDMS JSB 012925
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
January 9, 2025
Commissioner
State of Alaska
Alaska Oil & Gas Conservation Commission
333 West 7th Avenue Suite 100
Anchorage, Alaska 99501
Dear Commissioner:
ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over 1Q-20A (PTD# 195-
156).
Well 1Q-20A was drilled in October of 1995 by Parker 245 and completed in February of 1996 by Nordic #1 as a
Producer in the Kuparuk A sands. The well failed a TIFL on 2019 and subsequent diagnostics revealed multiple
tubing leaks between 5,490’ and 6,613’ RKB. A 2-3/8” jointed pipe patch was installed from 4,797’ to 7,014’ RKB
in 2021 and the well was brought online until 2024. The patch was preemptively pulled in September of 2024 for
the upcoming rig workover.
To return the well to production, we are requesting approval to proceed with a rig workover. We plan to pull the
3-1/2” completion from a pre-rig cut above the packer, then perform a casing cleanout run and tubing dress off
run based on tubing condition, then install a new 3-1/2” completion including a new gas lift design, a non-
sealing overshot and a stacked packer.
If you have any questions or require any further information, please contact me at 907-265-6049.
Cy Eller
Rig Workover Engineer
CPAI Drilling and Wells
1Q-20A Kuparuk Producer Pull and Replace Tubing Procedure PTD: 195-156
Page 1 of 2
PPre-Rig Work
1. Pull GLVs and install DVs. Leave lowest GLM open for circulation.
2. CMIT-TxIA to 2,500 psig.
3. DDT-TxIA.
4. Cut tubing at ~6,923’ RKB.
5. Prepare well for rig arrival.
Rig Work
MIRU
1. MIRU Nabors 7ES on 1Q-20A. No BPV set for MIRU due to N7ES internal risk assessment.
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. Circulate KWF as needed. Verify well is dead.
3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/2,500 psi. Test
annular 250/2,500 psi. Annular and pipe rams to be tested on 3-1/2” test joints.
Retrieve 3-1/2” Tubing
4. Pull BPV, MU landing joint and BOLDS.
5. Pull 3-1/2” tubing from pre-rig cut at ~6,923’ RKB.
Cleanout Run
6. PU DP and perform casing cleanout and tubing dress off runs if necessary based on tubing
condition.
Install new 3-1/2” Gas Lift Completion with Stacked Packer
7. MU non-sealing overshot, nipple profile, and 3-1/2” x 5-1/2” packer and RIH on DP.
8. Set packer and release setting tool. POOH LD DP.
9. MU and RIH with new 3-1/2” completion with GLMs, nipple, anchor and seal assembly.
10. Once on depth, space out as needed. Circulate corrosion inhibited fluid.
11. Land tubing hanger and RILDS.
12. Pressure test tubing to 3,000 PSI for 30 minutes.
13. Pressure test IA to 2,500 PSI for 30 minutes.
ND BOP, NU Tree
14. Confirm pressure tests, then shear out SOV.
15. Install BPV and test. ND BOPE. NU tree and PT packoffs.
16. Pull BPV and freeze protect well.
17. RDMO.
Post-Rig Work
1. Pull SOV and DVs
2. Pull ball and rod used for setting packer.
3. Install new GLD.
4. Pull pre-rig plug and catcher from liner.
1Q-20A Kuparuk Producer Pull and Replace Tubing Procedure PTD: 195-156
Page 2 of 2
GGeneral Well Information:
Estimated Start Date: 2/15/2025
Current Operations: Shut in
Well Type: Producer
Wellhead Type: FMC Gen IV. 11” 3M casing head top flange. 7-1/16” 5M tubing head top flange.
Scope of Work: Pull the existing 3-1/2” completion from pre-rig cut, perform tubing
cleanout/dress off run, install a new 3-1/2” gas lift completion with stacked
packer.
BOP Configuration: Annular / Pipe Rams / Blind Rams / Pipe Rams
Following subject to change with Pre-Rig Work:
MIT Results:
CMIT-TxIA: Passed (2,500 psi, 9/3/2024)
MIT-OA: Passed (1,800 psi, 1/5/2025)
Tubing POT & PPPOT: Passed (1/5/2025)
IC POT & PPPOT: Passed (1/5/2025)
Static BHP: 2,748 psi / 6,437’ TVD measured on 8/19/2024
MPSP: 2,104 psi using 0.1 psi/ft gradient
Personnel:
Workover Engineer: Cy Eller (907-265-6049 / Cy.Eller@conocophillips.com)
Reservoir Surveillance Engineer: Jennifer McLeod
Production Engineer: Banabas Dogah
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag: RKB 7,794.0 1Q-20A 12/2/2023 fergusp
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Pull NSAK upper patch packer and spacer pipe assembly 1Q-20A 9/20/2024 praffer
Notes: General & Safety
Annotation End Date Last Mod By
NOTE: WELL SIDETRACKED 1/30/1996 osborl
NOTE: Original Well was P&A'd due to gas at surface & lost circulation. 6/23/1995 ninam
Casing Strings
Csg Des OD (in) ID (in) Top (ftKB)
Set Depth
(ftKB)
Set Depth
(TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread
CONDUCTOR 16 15.06 41.0 121.0 121.0 62.58 H-40 WELDED
SURFACE 7 5/8 6.87 40.9 4,099.0 3,688.4 29.70 L-80 LTC
INTERMEDIATE 5 1/2 4.95 39.1 7,179.5 5,919.6 15.50 L-80 LTC-MOD
LINER 3 1/2 2.99 6,970.7 7,923.0 9.30 L-80 BTC-MOD
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
23.2
Set Depth …
6,970.7
String Max No…
3 1/2
Set Depth …
5,767.4
Tubing Description
TUBING
Wt (lb/ft)
9.30
Grade
L-80
Top Connection
ABM-EUE
ID (in)
2.99
Completion Details: excludes tubing, pup, space out, thread, RKB...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal
ID (in)
23.2 23.2 0.02 HANGER 8.000 FMC GEN IV TUBING HANGER 3.500
516.8 516.8 0.35 NIPPLE 3.800 CAMCO DS LANDING NIPPLE
2.856" NO GO w/2.812" ID
2.812
2,440.0 2,381.9 33.67 GAS LIFT 4.750 BST AXT 2.900
3,974.1 3,590.8 38.79 Mandrel - valve 4.750 BST AXT 2.900
5,165.0 4,473.7 42.21 GAS LIFT 4.750 BST AXT 2.900
6,168.2 5,187.0 43.02 GAS LIFT 4.750 BST AXT 2.900
6,888.5 5,707.9 43.48 GAS LIFT 4.750 BST AXT 2.900
6,942.7 5,747.2 43.68 NIPPLE 4.540 CAMCO D NIPPLE NO GO 2.750
6,956.0 5,756.8 43.74 PBR 4.000 BAKER 80-40 PBR w/ 10' STROKE 2.992
6,970.0 5,766.9 43.80 ANCHOR 4.500 BAKER ANCHOR (STAB INTO
SABL-3 PACKER)
2.992
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)
45.2 45.2 0.04 PATCH SURFACE CASING PATCH:
.375" Thickness; OAL 66" runs
from bottom of mandrel
hanger.
12/12/2008 7.625
5,490.0 4,705.7 46.95 TUBING
LEAK
leak identified W/Relay LDL
tools
10/5/2019 2.992
5,875.0 4,973.4 44.00 TUBING
LEAK
leak identified W/Relay LDL
tools
10/5/2019 2.992
6,611.5 5,507.3 44.03 TUBING
LEAK
leak identified W/Relay CCL &
SS HOLEFINDER, 6611 -
6613'
11/8/2019 2.992
6,728.0 5,591.5 43.55 TUBING
LEAK
leak identified W/Relay CCL &
SS HOLEFINDER
11/1/2019 2.992
7,014.9 5,799.3 43.73 TUBING
PLUG
Set 1.71" XR plug in bottom of
patch in 1.71" R Nipple. (2'
OAL) Actual depth 7031' RKB
9/3/2024 0.000
7,014.9 5,799.3 43.73 PACKER -
PATCH - LWR
NORTHERN SOLUTIONS 350
-272 LWR PKR MID-
ELEMENT @ 7022' W/ 225
SEAL BORE DEPLOYMENT
SLEEVE ABOVE PKR AND 2-
3/8" SPACER PIPE, 1.710" R-
NIPPLE AND 2-3/8" MULE
SHOE PUP BELOW PKR,
OAL 26.37', R-NIPPLE AT
~7031' RKB
A1812
7204,
A1352
7005
8/2/2021 1.710
Mandrel Inserts : excludes pulled inserts
Top (ftKB)
Top (TVD)
(ftKB)
Top
Incl (°)
St
ati
on
No
/S Serv
Valve
Type
Latch
Type
OD
(in)
TRO Run
(psi) Run Date Com Make Model
Port
Size (in)
2,440.0 2,381.9 33.67 1 GAS LIFT GLV T-1 1 1,339.0 8/9/2021 0.156
3,974.1 3,590.8 38.79 2 GAS LIFT OV T-1 1 0.0 8/9/2021 0.250
5,165.0 4,473.7 42.21 3 GAS LIFT DMY T-1 1 0.0 6/3/2021 0.000
6,168.2 5,187.0 43.02 4 GAS LIFT DMY T-1 1 0.0 12/24/2008 0.000
6,888.5 5,707.9 43.48 5 GAS LIFT OPEN OPEN 1 6/3/2021 Patch
ed
Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal ID
(in)
6,970.7 5,767.4 43.81 PACKER 4.625 Baker 'SABL-3' LINER PACKER 2.815
6,974.9 5,770.4 43.82 XO THREAD 3.500 2.992
7,825.3 LANDING
COLLAR
3.500 2.992
1Q-20A, 1/3/2025 10:16:20 AM
Vertical schematic (actual)
LINER; 6,970.6-7,923.0
GUIDE SHOE; 7,921.4-7,923.0
FLOAT COLLAR; 7,857.5-
7,858.3
LANDING COLLAR; 7,825.3-
7,826.3
APERF; 7,620.0-7,640.0
APERF; 7,610.0-7,620.0
IPERF; 7,560.0-7,562.0
INTERMEDIATE; 39.1-7,179.5
FLOAT SHOE; 7,178.2-7,179.5
FLOAT COLLAR; 7,097.9-
7,099.0
PACKER - PATCH - LWR;
7,014.9
TUBING PLUG; 7,014.9
PACKER; 6,970.6-6,974.9
ANCHOR; 6,970.0
PBR; 6,956.0
NIPPLE; 6,942.7
GAS LIFT; 6,888.5
TUBING LEAK; 6,728.0
TUBING LEAK; 6,611.5
GAS LIFT; 6,168.2
TUBING LEAK; 5,875.0
TUBING LEAK; 5,490.0
GAS LIFT; 5,165.0
SURFACE; 40.9-4,099.0
FLOAT SHOE; 4,097.5-4,099.0
FLOAT COLLAR; 4,008.2-
4,009.6
Mandrel - valve; 3,974.1
GAS LIFT; 2,440.0
NIPPLE; 516.8
CONDUCTOR; 41.0-121.0
PATCH; 45.2
HANGER; 23.2
KUP PROD
KB-Grd (ft)
22.50
RR Date
9/17/1995
Other Elev…
1Q-20A
...
TD
Act Btm (ftKB)
7,925.0
Well Attributes
Field Name
KUPARUK RIVER UNIT
Wellbore API/UWI
500292258901
Wellbore Status
PROD
Max Angle & MD
Incl (°)
47.41
MD (ftKB)
5,518.18
WELLNAME WELLBORE1Q-20A
Annotation
Last WO:
End Date
2/5/1996
H2S (ppm)
129
Date
3/13/2022
Comment
SSSV: NIPPLE
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
7,560.0 7,562.0 UNIT B, 1Q-20A 3/22/1996 4.0 IPERF 2 1/2" Hollow Carrier; 90°
phasing
7,610.0 7,620.0 A-3, 1Q-20A 4/5/1996 4.0 APERF 2 1/2" Hollow Carrier; 180°
phasing; Oriented 142° CCW
F/ High Si
7,620.0 7,640.0 A-3, 1Q-20A 4/5/1996 2.0 APERF 2 1/2" Hollow Carrier; 180°
phasing; One Side Not
Loaded
1Q-20A, 1/3/2025 10:16:20 AM
Vertical schematic (actual)
LINER; 6,970.6-7,923.0
GUIDE SHOE; 7,921.4-7,923.0
FLOAT COLLAR; 7,857.5-
7,858.3
LANDING COLLAR; 7,825.3-
7,826.3
APERF; 7,620.0-7,640.0
APERF; 7,610.0-7,620.0
IPERF; 7,560.0-7,562.0
INTERMEDIATE; 39.1-7,179.5
FLOAT SHOE; 7,178.2-7,179.5
FLOAT COLLAR; 7,097.9-
7,099.0
PACKER - PATCH - LWR;
7,014.9
TUBING PLUG; 7,014.9
PACKER; 6,970.6-6,974.9
ANCHOR; 6,970.0
PBR; 6,956.0
NIPPLE; 6,942.7
GAS LIFT; 6,888.5
TUBING LEAK; 6,728.0
TUBING LEAK; 6,611.5
GAS LIFT; 6,168.2
TUBING LEAK; 5,875.0
TUBING LEAK; 5,490.0
GAS LIFT; 5,165.0
SURFACE; 40.9-4,099.0
FLOAT SHOE; 4,097.5-4,099.0
FLOAT COLLAR; 4,008.2-
4,009.6
Mandrel - valve; 3,974.1
GAS LIFT; 2,440.0
NIPPLE; 516.8
CONDUCTOR; 41.0-121.0
PATCH; 45.2
HANGER; 23.2
KUP PROD 1Q-20A
...
WELLNAME WELLBORE1Q-20A
1Q-20A Proposed RWO Completion
Description
Set Depth
MD
Set Depth
TVD OD ID
Weight
Length Grade Top Conn
Conductor 121 121 16 15.062 62.58 H-40 Welded
Surface 4099 3688.4 7.625 6.875 29.7 L-80 LTC
Intermediate 7179.5 5919.6 5.5 4.95 15.5 L-80 LTC-MOD
Liner 7923 6465 3.5 2.992 9.3 L-80 BTC-MOD
Tubing 6970.7 5767.408 3.5 2.992 9.3 L-80 ABM-EUE
PROPOSED COMPLETION
3-1/2" 9.3# L-80 EUE 8rd Tubing to Surface
3-½" x 1" Gas Lift Mandrels @ 2709', 4525', 5627', and
6800' RKB
3-1/2" PBR Assembly
3-1/2" Anchor Asssembly
3-1/2" x 5-1/2" Packer
3-½" Nipple Profile (2.813" min ID)
3-1/2" Non-sealing Overshot
REMAINING COMPLETION LEFT IN HOLE
3-1/2" Camco D Nipple No Go at 6942' RKB
Baker 80-40 PBR at 6956' RKB
Baker Anchor and SABL-3 Packer at 6970' RKB
Surface Casing
4099' RKB
Intermediate Casing
6970' RKB
Conductor
Production Liner
7923' RKB
Calculated TOC from
10/26/1995 Cement
Detail:5,525' RKB
WELL NAME API #SERVICE ORDER # FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPEDATE LOGGEDCOLOR PRINTS CDsCD5-1950103207600000 CRU WLSetting RecordFINAL FIELD3-Aug-21CD5-1950103207600000 CRU WLSetting RecordFINAL FIELD11-Aug-21CD5-9650103208110000 CRU WLPERFFINAL FIELD21-Jul-21CD2-31050103208260000 CRU WLDCSTFINAL FIELD16-Sep-21CD2-31050103208260000 CRU WLUSITFINAL FIELD24-Aug-21CD2-31050103208260000 CRU WLUSITFINAL FIELD25-Aug-21CD5-3150103208280000 CRU WLPERFFINAL FIELD27-May-21CD1-01A50103202990100 CRU WLRSTFINAL FIELD12-Sep-21MT7-0650103208310000 GMTU WLCORROSIONFINAL FIELD3-Oct-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD14-Sep-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD22-Oct-21MT7-0650103208310000 GMTU WLMECH CUTTERFINAL FIELD2-Sep-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD12-Dec-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD16-Dec-21MT7--0150103208320000 GMTU WLSCMTFINAL FIELD15-Nov-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD19-Feb-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD29-Mar-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD2-Apr-21Delivery Receipt______ďďLJĞůů_____X_______________________________________Print Name Signature DatePlease return via courier or sign/scan and email a copy to Schlumberger.A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted SLB Auditor-Originated:PTS - PRINT CENTER600 E 57th Pl - Ste AAnchorage, AK 99518Delivered to:AOGCCATTN: Natural Resources Technician333 W. 7th Ave., Suite 100Anchorage, AK 99501-3539Transmittal Date:20-Dec-21Transmittal #:________________Signature12/21/2021Wd͗ϭϵϱϭϱϲϬ Ͳ^Ğƚ͗ϯϲϮϱϭJRBy Abby Bell at 1:43 pm, Dec 21, 2021
3M-1750029217290000 KRU WLWFLFINAL FIELD24-Apr-213M-1950029217370000 KRU WLLDLFINAL FIELD25-Apr-213H-0150103200840000 KRU WLCHCFINAL FIELD26-Aug-213H-1250103200880000 KRU WLCCLFINAL FIELD23-Sep-213H-1250103200880000 KRU WLCHCFINAL FIELD29-Aug-213H-1250103200880000 KRU WLCUTTERFINAL FIELD23-Sep-213H-1250103200880000 KRU WLCUTTERFINAL FIELD24-Sep-211L-1250029220330000 KRU WLSBHPSFINAL FIELD6-Nov-213G-2450103201450000 KRU WLTBG CORRFINAL FIELD29-Oct-211A-2550029221160000 KRU WL WHIPSTOCKFINAL FIELD12-Oct-211A-2350029221310000 KRU WLRBPFINAL FIELD12-Jun-211R-2050029222070000 KRU WLPPROFFINAL FIELD2-Jun-212M-1150103201590000 KRU WLPPROFFINAL FIELD27-Aug-212M-0750103201780000 KRU WLBACKOFFFINAL FIELD5-Aug-211Y-1950029223910000 KRU WLPPROFFINAL FIELD31-May-212T-3050103202190000 KRU WLLDLFINAL FIELD2-May-211Q-20A50029225890100 KRU WLSET RECFINAL FIELD2-Aug-212M-3350103202400000 KRU WLLDLFINAL FIELD18-Oct-211F-03A50029208530100 KRU WLPERFFINAL FIELD19-Oct-211Q-08A50029212250100 KRU WLIPROFFINAL FIELD30-Apr-211E-3350029227970000 KRU WLPPROFFINAL FIELD26-Mar-211D-13550029228160000 KRU WLLDLFINAL FIELD16-Jul-213F-13A50029214990100 KRU WLGLSFINAL FIELD17-Jul-212N-318 50103203430000 KRU WLSCMTFINAL FIELD12-Nov-211C-12750029230240000 KRU WLIPROFFINAL FIELD17-Nov-213S-24A50103204560100 KRU WLCUTTERFINAL FIELD25-Oct-213S-0350103204580000 KRU WLIBPFINAL FIELD26-Oct-211B-2050029231640000 KRU WLPPROFFINAL FIELD22-Apr-211E-11950029231980000 KRU WLLDLFINAL FIELD26-Jun-212W-1750029233700000 KRU WLPPROFFINAL FIELD28-Aug-211H-11850029235780000 KRU WLIPROFFINAL FIELD4-Nov-211H-11450029235840000 KRU WLIPROFFINAL FIELD23-Jun-211H-11350029235880000 KRU WLWFLFINAL FIELD22-May-21
WELL NAME API #SERVICE ORDER # FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPEDATE LOGGEDCOLOR PRINTS CDsCD5-1950103207600000 CRU WLSetting RecordFINAL FIELD3-Aug-21CD5-1950103207600000 CRU WLSetting RecordFINAL FIELD11-Aug-21CD5-9650103208110000 CRU WLPERFFINAL FIELD21-Jul-21CD2-31050103208260000 CRU WLDCSTFINAL FIELD16-Sep-21CD2-31050103208260000 CRU WLUSITFINAL FIELD24-Aug-21CD2-31050103208260000 CRU WLUSITFINAL FIELD25-Aug-21CD5-3150103208280000 CRU WLPERFFINAL FIELD27-May-21CD1-01A50103202990100 CRU WLRSTFINAL FIELD12-Sep-21MT7-0650103208310000 GMTU WLCORROSIONFINAL FIELD3-Oct-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD14-Sep-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD22-Oct-21MT7-0650103208310000 GMTU WLMECH CUTTERFINAL FIELD2-Sep-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD12-Dec-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD16-Dec-21MT7--0150103208320000 GMTU WLSCMTFINAL FIELD15-Nov-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD19-Feb-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD29-Mar-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD2-Apr-21Delivery Receipt______ďďLJĞůů_____X_______________________________________Print Name Signature DatePlease return via courier or sign/scan and email a copy to Schlumberger.A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted SLB Auditor-Originated:PTS - PRINT CENTER600 E 57th Pl - Ste AAnchorage, AK 99518Delivered to:AOGCCATTN: Natural Resources Technician333 W. 7th Ave., Suite 100Anchorage, AK 99501-3539Transmittal Date:20-Dec-21Transmittal #:________________Signature12/21/2021Wd͗ϭϵϱϭϱϲϬ Ͳ^Ğƚ͗ϯϲϭϰϱJRBy Abby Bell at 1:43 pm, Dec 21, 2021
1D-0350029204080000 KRU WLIPROFFINAL FIELD29-Aug-211F-0750029208300000 KRU WLGLSFINAL FIELD13-Oct-212W-0950029212350000 KRU WLSCMTFINAL FIELD18-Nov-212W-0950029212350000 KRU WLSCMTFINAL FIELD22-Sep-212U-1350029212610000 KRU WLPPROFFINAL FIELD16-Oct-213N-0650029215380000 KRU WLPPROFFINAL FIELD31-Oct-211Y-1750029223680000 KRU WLPPROFFINAL FIELD25-Jul-211Q-20A50029225890100 KRU WLSBHPSFINAL FIELD29-Jul-213S-24A50103204560100 KRU WLUSITFINAL FIELD25-Nov-212N-318A50103203430100 KRU WLSCMTFINAL FIELD12-Nov-211D-0350029204080000 KRU WLIPROFFINAL FIELD27-Mar-211D-0550029204170000 KRU WLSCMTFINAL FIELD8-Oct-211D-0250029204290000 KRU WLIPROFFINAL FIELD2-Apr-211A-0550029206270000 KRU WLLDLFINAL FIELD1-May-211B-1050029206560000 KRU WLWHIPSTOCKFINAL FIELD25-Sep-211F-0350029208530000 KRU WLPERFFINAL FIELD19-Oct-211Y-0650029209580000 KRU WLPPROFFINAL FIELD1-Nov-212D-0850029211580000 KRU WLGLSFINAL FIELD18-Jul-212D-0450029211760000 KRU WLBISNFINAL FIELD20-Nov-212D-0450029211760000 KRU WLSCMTFINAL FIELD10-Oct-212X-1550029211990000 KRU WLPPROFFINAL FIELD17-Oct-211Q-0950029212090000 KRU WLIPROFFINAL FIELD17-Nov-212E-1450029212140000 KRU WLSHBPFINAL FIELD30-Oct-212W-0950029212350000 KRU WLBISNFINAL FIELD19-Nov-211Q-0250029212480000 KRU WLIPROFFINAL FIELD29-Apr-212W-1450029212530000 KRU WLIPROFFINAL FIELD1-May-211Q-1550029213080000 KRU WLIPROFFINAL FIELD28-Apr-211R-0850029213330000 KRU WLIPROFFINAL FIELD3-May-211R-1350029213850000 KRU WLIPROFFINAL FIELD27-Jun-213F-0250029214470000 KRU WLWHIPSTOCKFINAL FIELD14-Nov-213F-1450029215000000 KRU WLLDLFINAL FIELD30-May-213M-0550029217060000 KRU WLCHEM CUTFINAL FIELD28-Oct-213M-0550029217060000 KRU WLSTRINGSHOTFINAL FIELD27-Oct-21
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Tyson Wiese Digitally signed by Tyson Wiese
Date: 2021.08.26 15:28:01 -08'00'
RBDMS HEW 8/27/2021DSR-8/30/21 SFD 8/27/2021VTL 9/9/21
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Last Tag
Annotation Depth (ftKB)End Date Wellbore Last Mod By
Last Tag: RKB 7,625.0 12/26/2020 1Q-20A fergusp
Last Rev Reason
Annotation End Date Wellbore Last Mod By
Rev Reason: Set super patch & GLV's 8/9/2021 1Q-20A fergusp
Casing Strings
Casing Description
INTERMEDIATE
OD (in)
5 1/2
ID (in)
4.95
Top (ftKB)
39.1
Set Depth (ftKB)
7,179.5
Set Depth (TVD)…
5,919.6
Wt/Len (l…
15.50
Grade
L-80
Top Thread
LTC-MOD
Casing Description
LINER
OD (in)
3 1/2
ID (in)
2.99
Top (ftKB)
6,970.7
Set Depth (ftKB)
7,923.0
Set Depth (TVD)…Wt/Len (l…
9.30
Grade
L-80
Top Thread
BTC-MOD
Liner Details
Top (ftKB)Top (TVD) (ftKB)Top Incl (°)Item Des Com
Nominal ID
(in)
6,970.7 5,767.4 43.81 PACKER Baker 'SABL-3' LINER PACKER 2.815
Tubing Strings
Tubing Description
TUBING
String Ma…
3 1/2
ID (in)
2.99
Top (ftKB)
23.2
Set Depth (ft…
6,970.7
Set Depth (TVD) (…
5,767.4
Wt (lb/ft)
9.30
Grade
L-80
Top Connection
ABM-EUE
Completion Details
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°)Item Des Com
Nominal
ID (in)
23.2 23.2 0.02HANGER FMC GEN IV TUBING HANGER 3.500
516.8516.80.35 NIPPLE CAMCO DS LANDING NIPPLE 2.856" NO GO w/2.812" ID 2.812
6,942.7 5,747.2 43.68 NIPPLE CAMCO D NIPPLE NO GO 2.750
6,956.0 5,756.8 43.74 PBR BAKER 80-40 PBR w/ 10' STROKE 2.992
6,970.0 5,766.9 43.80 ANCHOR BAKER ANCHOR (STAB INTO SABL-3 PACKER) 2.992
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top
(ftKB)
Top
(TVD)
(ftKB)
Top Incl
(°)Des Com Run Date ID (in)SN
0.0 0.0 0.00 PATCH Surface Casing Patch: .375" Thickness; OAL
66" runs from bottom of mandrel hanger.
12/12/2008 7.625
4,797.0 4,201.6 41.25PACKER -
PATCH - UPR
2.72 NSAK packer & PTSA Assembly w/
1.78.1 R nipple (16.4' OAL)
8/7/2021 1.781 packer
A18127202
PTSA
A999020607
4,808.2 4,210.0 41.34 PBR 225 Seal bore deployment sleeve 10.42'
long.
Note: 2.25 Deployment sleeve, 2.375" spacer
pipe, sliding sleeve, 2.375" spacer pipe, 2.25
PTSA are all one assembly (OAL 2206.79')
8/5/2021 1.930 A13527002
4,818.6 4,217.8 41.41 SPACER PIPE 70 joints of 2 3/8" pipe 2069.83' OAL 8/5/2021 1.995
5,490.0 4,705.7 46.95TUBING LEAK Tubing leak identified with Relay LDL tools 10/5/2019 2.992
5,875.0 4,973.4 44.00 TUBING LEAK Tubing leak identified with Relay LDL tools 10/5/2019 2.992
6,611.5 5,507.3 44.03 TUBING LEAK Tubing leak identified with Relay CCL & SS
HOLEFINDER, 6611 - 6613'
11/8/2019 2.992
6,728.0 5,591.5 43.55 TUBING LEAK Tubing leak identified with Relay CCL & SS
HOLEFINDER
11/1/2019 2.992
6,896.4 5,713.6 43.48 SLEEVE -
CLOSED
2 3/8" sliding sleeve 8/5/2021 1.995 178NERA269
19-INC
6,900.2 5,716.4 43.49 SPACER PIPE 4 joints of 2 3/8" pipe. 114.44' long 8/5/2021 1.995
7,014.6 5,799.1 43.73 ANCHOR LATCH 225 PTSA w/ 1.781" R Nipple. ( 3.76' OAL)
3.47' of lenght is stabbed into lower packer.
8/5/2021 1.781A9902609
7,014.9 5,799.3 43.73 PACKER -
PATCH - LWR
NORTHERN SOLUTIONS 350-272 LWR
PKR MID-ELEMENT @ 7022' W/ 225 SEAL
BORE DEPLOYMENT SLEEVE ABOVE
PKR AND 2-3/8" SPACER PIPE, 1.710" R-
NIPPLE AND 2-3/8" MULE SHOE PUP
BELOW PKR
8/2/2021 1.710 A18127204,
A13527005
Perforations & Slots
Top (ftKB)Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB)Linked Zone Date
Shot
Dens
(shots/ft
)Type Com
7,560.0 7,562.0 UNIT B, 1Q-20A 3/22/1996 4.0 IPERF 2 1/2" Hollow Carrier; 90°
phasing
7,610.0 7,620.0 A-3, 1Q-20A 4/5/1996 4.0 APERF 2 1/2" Hollow Carrier; 180°
phasing; Oriented 142° CCW
F/ High Si
7,620.0 7,640.0 A-3, 1Q-20A 4/5/1996 2.0 APERF 2 1/2" Hollow Carrier; 180°
phasing; One Side Not
Loaded
Mandrel Inserts
St
ati
on
N
o/Top (ftKB)
Top (TVD)
(ftKB)
Top
Incl (°)Make Model OD (in)Serv
Valve
Type
Latch
Type
Port Size
(in)
TRO Run
(psi)Run Date Com
1 2,440.0 2,381.9 33.67 BST AXT 1 GAS LIFT GLV T-1 0.156 1,339.0 8/9/2021
2 3,974.1 3,590.8 38.79 BST AXT 1 GAS LIFT OVT-1 0.2500.08/9/2021
3 5,165.0 4,473.7 42.21 BST AXT 1 GAS LIFT DMY T-1 0.000 0.06/3/2021
4 6,168.2 5,187.0 43.02 BST AXT 1 GAS LIFT DMY T-10.000 0.012/24/2008
5 6,888.5 5,707.9 43.48 BST AXT 1 GAS LIFT OPEN OPEN 6/3/2021 Patch
ed
Notes: General & Safety
End Date Annotation
10/13/2010 NOTE: View Schematic w/ Alaska Schematic9.0
1/30/1996 NOTE: WELL SIDETRACKED
6/23/1995NOTE: Original Well was P&A'd due to gas at surface & lost circulation.
1Q-20A, 8/25/2021 1:53:15 PM
Vertical schematic (actual)
LINER; 6,970.6-7,923.0
APERF; 7,620.0-7,640.0
APERF; 7,610.0-7,620.0
IPERF; 7,560.0-7,562.0
INTERMEDIATE; 39.1-7,179.5
PACKER - PATCH - LWR;
7,014.9
ANCHOR LATCH; 7,014.6
SPACER PIPE; 6,900.2
SLEEVE - CLOSED; 6,896.4
GAS LIFT; 6,888.5
TUBING LEAK; 6,728.0
TUBING LEAK; 6,611.5
GAS LIFT; 6,168.2
TUBING LEAK; 5,875.0
SPACER PIPE; 4,818.6
TUBING LEAK; 5,490.0
GAS LIFT; 5,165.0
PBR; 4,808.2
PACKER - PATCH - UPR;
4,797.0
SURFACE; 40.9-4,099.0
GAS LIFT; 3,974.1
GAS LIFT; 2,440.0
NIPPLE; 516.8
CONDUCTOR; 41.0-121.0
PATCH; 0.0
KUP PROD
KB-Grd (ft)
22.50
Rig Release Date
9/17/1995
1Q-20A
...
TD
Act Btm (ftKB)
7,925.0
Well Attributes
Field Name
KUPARUK RIVER UNIT
Wellbore API/UWI
500292258901
Wellbore Status
PROD
Max Angle & MD
Incl (°)
47.41
MD (ftKB)
5,518.18
WELLNAME WELLBOREQ
Annotation
Last WO:
End Date
2/5/1996
H2S (ppm)
53
Date
7/15/2019
Comment
SSSV: NIPPLE
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By Samantha Carlisle at 10:21 am, May 03, 2021
321-223
Tyson Wiese Digitally signed by Tyson Wiese
Date: 2021.05.03 09:48:26 -08'00'
-00 DLB
X
DSR-5/4/21
ADL0025641 DLB
10-404 X
DLB 05/03/2021
00
X
VTL 5/17/21
BOP test to 3500 psig
VTL 5/17/21
3011 psig
dts 5/17/2021
JLC 5/17/2021
Jeremy Price
Digitally signed by
Jeremy Price
Date: 2021.05.17
12:58:34 -08'00'
RBDMS HEW 5/19/2021
From:Wiese, Tyson M
To:Loepp, Victoria T (CED)
Subject:RE: [EXTERNAL]KRU 1Q-20A (PTD 195-156) Jointed Pipe Patch MPSP
Date:Wednesday, May 12, 2021 12:03:27 PM
Victoria,
The Max Predicted Surface Pressure (with a gas gradient to surface) for 1Q-20A = 3,634 psi
(12/26/2020 recent SBHP) – (0.1 psi/ft)*(6,230’ TVD) = 3,011 psi. I plan to load the well with
11.6# KWF prior to the patch install.
On 1/11/2020 a CA-2 plug was set @ 6,942’ KB and a passing C-MIT to 2,500 psi was
performed. Other C-MITs have been done but this is the most recent. I plan to perform a
confirmation C-MIT again after we set the lower patch packer/plug.
Thanks,
Tyson Wiese
Wells Engineer
ConocoPhillips Alaska, Inc.
Desk Phone (907)-265-6093
Cell Phone (907)-230-5388
From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>
Sent: Wednesday, May 12, 2021 11:50 AM
To: Wiese, Tyson M <Tyson.M.Wiese@conocophillips.com>
Subject: [EXTERNAL]KRU 1Q-20A (PTD 195-156) Jointed Pipe Patch MPSP
CAUTION:This email originated from outside of the organization. Do not click links or open
attachments unless you recognize the sender and know the content is safe.
Tyson,
1. What is the MPSP and basis?
2. What is the integrity of the production casing? Has a CMIT TXIA been done?
Thanx,
Victoria
Max Predicted Surface Pressure
3,011 psi. load the well with
11.6# KWF prior to the patch install.
passing C-MIT to 2,500 psi w
Victoria Loepp
Senior Petroleum Engineer
State of Alaska
Oil & Gas Conservation Commission
333 W. 7th Ave
Anchorage, AK 99501
Work: (907)793-1247
Victoria.Loepp@alaska.gov
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 Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.gov
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Last Tag
Annotation Depth (ftKB) End Date Wellbore Last Mod By
Last Tag: RKB 7,625.0 12/26/2020 1Q-20A fergusp
Last Rev Reason
Annotation End Date Wellbore Last Mod By
Rev Reason: UPDATED SCHEMATIC - so Anchor assembly stings into
the Baker 'SABL-3' LINER PACKER
2/4/2021 1Q-20A pproven
Casing Strings
Casing Description
CONDUCTOR
OD (in)
16
ID (in)
15.06
Top (ftKB)
41.0
Set Depth (ftKB)
121.0
Set Depth (TVD) …
121.0
Wt/Len (l…
62.58
Grade
H-40
Top Thread
WELDED
Casing Description
SURFACE
OD (in)
7 5/8
ID (in)
6.87
Top (ftKB)
40.9
Set Depth (ftKB)
4,099.0
Set Depth (TVD) …
3,688.4
Wt/Len (l…
29.70
Grade
L-80
Top Thread
LTC
Casing Description
INTERMEDIATE
OD (in)
5 1/2
ID (in)
4.95
Top (ftKB)
39.1
Set Depth (ftKB)
7,179.5
Set Depth (TVD) …
5,919.6
Wt/Len (l…
15.50
Grade
L-80
Top Thread
LTC-MOD
Casing Description
LINER
OD (in)
3 1/2
ID (in)
2.99
Top (ftKB)
6,970.7
Set Depth (ftKB)
7,923.0
Set Depth (TVD) … Wt/Len (l…
9.30
Grade
L-80
Top Thread
BTC-MOD
Liner Details
Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com
Nominal ID
(in)
6,970.7 5,767.4 43.81 PACKER Baker 'SABL-3' LINER PACKER 2.815
Tubing Strings
Tubing Description
TUBING
String Ma…
3 1/2
ID (in)
2.99
Top (ftKB)
23.2
Set Depth (ft…
6,970.7
Set Depth (TVD) (…
5,767.4
Wt (lb/ft)
9.30
Grade
L-80
Top Connection
ABM-EUE
Completion Details
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des Com
Nominal
ID (in)
23.2 23.2 0.02 HANGER FMC GEN IV TUBING HANGER 3.500
516.8 516.8 0.35 NIPPLE CAMCO DS LANDING NIPPLE 2.856" NO GO w/2.812" ID 2.812
6,942.7 5,747.2 43.68 NIPPLE CAMCO D NIPPLE NO GO 2.750
6,956.0 5,756.8 43.74 PBR BAKER 80-40 PBR w/ 10' STROKE 2.992
6,970.0 5,766.9 43.80 ANCHOR BAKER ANCHOR (STAB INTO SABL-3 PACKER) 2.992
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top
(ftKB)
Top
(TVD)
(ftKB)
Top Incl
(°) Des Com Run Date ID (in) SN
0.0 0.0 0.00 PATCH Surface Casing Patch: .375" Thickness; OAL
66" runs from bottom of mandrel hanger.
12/12/2008 7.625
5,490.0 4,705.7 46.95 TUBING LEAK Tubing leak identified with Relay LDL tools 10/5/2019 2.992
5,875.0 4,973.4 44.00 TUBING LEAK Tubing leak identified with Relay LDL tools 10/5/2019 2.992
6,611.5 5,507.3 44.03 TUBING LEAK Tubing leak identified with Relay CCL & SS
HOLEFINDER, 6611 - 6613'
11/8/2019 2.992
6,728.0 5,591.5 43.55 TUBING LEAK Tubing leak identified with Relay CCL & SS
HOLEFINDER
11/1/2019 2.992
6,942.0 5,746.7 43.68 2.75" CA-2 Plug 2.75" CA-2 Plug (32" OAL) 12/26/2020 0.000
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft
)Type Com
7,560.0 7,562.0 UNIT B, 1Q-20A 3/22/1996 4.0 IPERF 2 1/2" Hollow Carrier; 90°
phasing
7,610.0 7,620.0 A-3, 1Q-20A 4/5/1996 4.0 APERF 2 1/2" Hollow Carrier; 180°
phasing; Oriented 142° CCW
F/ High Si
7,620.0 7,640.0 A-3, 1Q-20A 4/5/1996 2.0 APERF 2 1/2" Hollow Carrier; 180°
phasing; One Side Not
Loaded
Mandrel Inserts
St
ati
on
N
o/Top (ftKB)
Top (TVD)
(ftKB) Make Model OD (in) Serv
Valve
Type
Latch
Type
Port Size
(in)
TRO Run
(psi) Run Date Com
1 2,440.0 2,381.9 BST AXT 1 GAS LIFT GLV T-2 0.156 1,320.0 11/26/2014
2 3,974.1 3,590.8 BST AXT 1 GAS LIFT GLV T-1 0.188 1,348.0 11/26/2014
3 5,165.0 4,473.7 BST AXT 1 GAS LIFT OV T-1 0.250 0.0 9/9/2019
4 6,168.2 5,187.0 BST AXT 1 GAS LIFT DMY T-1 0.000 0.0 12/24/2008
5 6,888.5 5,707.9 BST AXT 1 GAS LIFT DMY T-1 0.000 0.0 11/25/2014
Notes: General & Safety
End Date Annotation
10/13/2010 NOTE: View Schematic w/ Alaska Schematic9.0
1/30/1996 NOTE: WELL SIDETRACKED
6/23/1995 NOTE: Original Well was P&A'd due to gas at surface & lost circulation.
1Q-20A, 2/4/2021 3:20:01 PM
Vertical schematic (actual)
LINER; 6,970.6-7,923.0
APERF; 7,620.0-7,640.0
APERF; 7,610.0-7,620.0
IPERF; 7,560.0-7,562.0
INTERMEDIATE; 39.1-7,179.5
2.75" CA-2 Plug; 6,942.0
GAS LIFT; 6,888.5
TUBING LEAK; 6,728.0
TUBING LEAK; 6,611.5
GAS LIFT; 6,168.2
TUBING LEAK; 5,875.0
TUBING LEAK; 5,490.0
GAS LIFT; 5,165.0
SURFACE; 40.9-4,099.0
GAS LIFT; 3,974.1
GAS LIFT; 2,440.0
NIPPLE; 516.8
CONDUCTOR; 41.0-121.0
PATCH; 0.0
KUP PROD
KB-Grd (ft)
22.50
Rig Release Date
9/17/1995
1Q-20A
...
TD
Act Btm (ftKB)
7,925.0
Well Attributes
Field Name
KUPARUK RIVER UNIT
Wellbore API/UWI
500292258901
Wellbore Status
PROD
Max Angle & MD
Incl (°)
47.41
MD (ftKB)
5,518.18
WELLNAME WELLBORE1Q-20A
Annotation
Last WO:
End Date
2/5/1996
H2S (ppm)
53
Date
7/15/2019
Comment
SSSV: NIPPLE
P'TD" m -'L6 E -Set: 34695
Baker Hughes $ Transmittal No: 2018-02WS
Baker Hughes- Transmittal Form
17021 Aldine Westfield Rd., Houston, TX 77073
Tel: 1-713-679-0061
From: Baker Hughes
Reg. Agency Alaska Oil and Gas Conservation Commission
Attn. Abby Bell
Name: Guillermo Bur
Natural Resource Technician II
Location: 333 West 7th Avenue
Department: Wireline Services
907-793-1225
Date: 12 -Feb -21
JOB NUMBER:
WELL Several Page 1/1
Item No:
DESCRIPTION - SFTP logs
Digital
Copies
1Q-20 well - MVRT log reports (PDF)
Name Format
1
500292258901 1Q -20A CSGINSP 1-8-2021.PDF PDF
1
Data received by the AOGCC 02/12/2021, updated transmittal received 02/19/2021
BY DAT 2 R C IVED DATE: 03/10/2021
TRANSMTTEGuille
mol Bur -Feb -21
SIGN IN RECEIVED BY SECTION AND RETURN SIGNED COPY TO BH
PTD: 1951560
E -Set: 34695
Baker Hughes $ Transmittal No: 2018-02WS
Baker Huqhes- Transmittal Form
17021 Aldine Westfield Rd., Houston, TX 77073
Tel 1-713-879-0061
From: Baker Hughes
Reg. Agency Alaska Oil and Gas Conservation Commission
Attn. Abby Bell
Name: Guillermo Bur
Natural Resource Technician II
Location: 333 West 7th Avenue
Department: Wireline Services
907-793-1225
Date: 12 -Feb -21
JOB NUMBER:
WELL Several Page 1/1
Item No:
DESCRIPTION - SFTP logs
Digital
Copies
10-20 well - MVRT log reports (PDF)
Name Format
1
500292258901 10-20A CSGINSP 1-8-2021.PDF PDF
1
Received by the AOGCC 02/16/2021,
TRANSMITTED BY DATE: RECEIVED BY: DATE:
02/19/2021
Guillermo Bur 12 -Feb -2140449 Of
SIGN IN RECEIVED BY SECTION AND RETURN SIGNED COPY TO BH
ORIGINATED TRANSMITTAL DATE:1/11/2020
ALASKA E-LINE SERVICES TRANSMITTAL #:2351
42260 Kenai Spur Hwy
PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk
PH: (907) 283-7374 FAX: (907) 283-7378
DELIVERABLE DESCRIPTION
TICKET #WELL #API #LOG DESCRIPTION DATE OF LOG
2351 1Q-20A 50-129-22589 24 MultiFinger Caliper Log 1/7/2021
DELIVERED TO DIGITAL FILE PRINTS CD's
Company & Address # of Copies # of Prints # of Copies
Conoco Phillips Alaska Inc.1 0 0
Attn: NSK-69
tom.osterkamp@conocophillips.com
Received By:
Print Name Signature Date
AOGCC 1 0 0
ATTN: Natural Resources Technician II
abby.bell@alaska.gov
Received By:
Print Name Signature Date
DNR 1 0 0
Natural Resource Tech II
DOG.Redata@alaska.gov
Recevied By:
Print Name Signature Date
Please return via e-mail a copy to both Alaska E-Line Services and Conoco Phillips Alaska:
tom.osterkamp@conocophillips.com reception@ake-line.com
Received by the AOGCC 01/11/2021
PTD: 1951560
E-Set: 34565
Abby Bell Abby Bell 01/12/2021
195156
WELL LOG TRANSMITTAL 9906023569
To: Alaska Oil and Gas Conservation Comm. November 21, 2019
Attn.: Natural Resource Technician
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
RE: Multi Finger Caliper (MFC), Leak Detect Log, and Packer Setting Record: 1Q -20A
Run Date: 10/05/2019 and 10/31/2019
The technical data listed below is being submitted herewith. Please address any problems or
concerns to the attention of:
Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518
FRS_ANC@halliburton. com
10-20A
Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom
50-029-22589-01
RECEIVED
DEC 0 9 2019
ACGCC
FLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE
TRANSMITTAL LETTER TO THE ATTENTION OF:
Halliburton
Wireline & Perforating
Attn: Fanny Sari
6900 Arctic Blvd.
Anchorage, Alaska 99518
Office: 907-275-2605
0
FRS_ANC@halliburton.com
Date: Signed:
•
~ . .
ConocoPh i I I i ps
Alaska
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
August 11, 2009
•
~~~;~~~~~
,t
~ ~ : ~l ~ _; %i~~`^
~~.ti1 ~
r,
_~;, >,~.;~ rr~,s~~ ~°_
;+~~~.~.:, ~~~; t ,~:;~ t,
,
y
`~J `t'
Mr. Tom Maunder a ~ /
Alaska Oil & Gas Commission ~ ~
333 West 7~' Avenue, Suite 100 .:, , „ ,
Anchorage, AK 99501 =::.~-'~ +~%~~` ~'~;'' t ~ ~~~'~
Dear Mr. Maunder:
g'
~"~ ~
Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). 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 June 26~' 2009 and the corrosion inhibitor/sealant was pumped August
10~` 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling,
and volumes used on each conductor.
Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions.
Sincerely,
~~~
MJ Loveland
ConocoPhillips Well Integrity Projects Supervisor
• .
ConocoPhillips Alaska Inc.
Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off
Report of Sundry Operations (10-404)
Kuparuk Field
Date 08/11/09
ell Name
PI #
TD #
Initial top of
cement
Vol. of cement
um ed
Final top of
cement
Cement top off
date
Corrosion
inhibitor i~,e rau
Corrosion
inhibitor/
sealant date
bbls a~
1 Q-20A 50029225890100 1951560 12'6" 2.60 8" 6/26/2009 2.12 8/10/2009
•
•
From: Maunder; Thomas E (DOA)
Sent: Monday, December 22, 2008 9:02 AM
To: 'NSK Well Integrity Proj'
Subject: RE: 1Q-20A
~~~ - (~~
Hi MJ,
I'd appreciate the denso tape photo. Having "all" shows the full repair process.
Thanks,
Tom
From: NSK Well Integrity Proj [mailto:N1878@conocophillips.com]
Sent: Monday, December 22, 2008 8:57 AM
To: Maunder, Thomas E (DOA)
Cc: NSK Well Integrity Field Supv
Subject: RE: iQ-20A ,~ ~ ~ : ~ ~
~~t4~~'~~ ' C~~i.r ~ ` 20fl~
Tom,
The Photo showing the denso tape actually covers the repair.
We thought the other two photos showcased the work better.
But we can send it if needed.
MJ
From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov]
Sent: Monday, December 22, 2008 8:54 AM
To: Winter, Roger (ASRC Energy Services)
Cc: NSK Well Integrity Proj
Subject: RE: iQ-20A
Thanks Roger. Do you have the final photo of everything "wrapped up"?
Tom Maunder, PE
AOGCC
From: Winter, Roger (ASRC Energy Services)
[mailto:Roger. Winter@contractor.conomphitlips.com]
Sent: Friday, December 19, 2008 4:08 PM
To: Maunder, Thomas E (DOA)
Cc: NSK Well Integrity Proj
Subject: 1Q-20A
Tom sorry for the sloppy info, here is the report and damage + repair photo's.
«20081219155222_001.PDF» «Copy right hole.jpg» «Copy right patch.jpg»
Roger Winter
Wells Supervisor
NSK 69 Wells Group
Office 211
Office # 659-7506 Cell # 943-1055
Page 1 of 1
•
Maunder, Thomas E (DOA)
From: Maunder, Thomas E (DOA)
Sent: Friday, December 19, 2008 10:27 AM
To: 'NSK Problem Well Supv ;NSK Well Integrity Proj
Subject: 1Q-20A (195-156)
Problem Wells,
I am reviewing the 404 submitted following the shallow surface casing repair on this well. Photos were of the
work were included, however they are black and white Xerox copies and when scanned into our file system will
not be easi{y viewed. I request that colored copies of the photos be submitted. Sending by email is fine.
Call or message with any questions.
Tom Maunder, PE
AOGCC
12/19/2008
• •
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS`
i s operations Perforated Abandon ::^ :.:?: ::::::::::.
f~epair Welt :.. ~
?Plug Perforations ^
:Stimulate ^
`Other:::: , .~ . SG Patch
..,..
C
Alter assn
g :^ ::...
...:...:...:.~?uU'Fubing ~
Perforat N' `
e evv Root ,^
?: Vllaivei ^
,...
r:.:c:ca::.c.:c
Tune 1=xfer~Sior:::. i^
Ghpng~Approtred Program ^ '.:.
:i3perat~:ttdown
Perforate.. °
^. ;. p
Re-enter Sus ended WWII
2. O erator Name:
p
~}, Current Well. Status
5. Permit to Drill Number:
ConocoPhillips Alaska, Inc. ~~ relo~i~rietxt:':::: ~
` :Expigraiory ^ 195-156
3. Address: Stratig~aphic... ^.: ::: SefY!~.:..^ -.. ... .. : 6. API Number:
P. O. Box 100360, Anchorage, Alaska 99510 50-029-22589-01 •
7. KB Elevation (ft): 9. Well Name and Number:
RKB 79' 1 Q-20a
8. Property Designation: 10. Field/Pool(s):
ADL0025634 ALK 2567 Kuparuk River Field /Kuparuk Oil Pool
11. Present Well Condition Summary:
Total Depth measured 7925' feet
true vertical 6468' feet Plugs (measured)
Effective Depth measured feet Junk (measured)
true vertical feet
Casing Length Size MD TVD Burst Collapse
Structural
CONDUCTOR 121' 16" 121' 121' 6890 4790
SURFACE 5537' 7-5/8" 4099' 3688' 6890 4790
PRODUCTION 8502' 5-1/2" 7180' 5920' 7000 4990
LINER 953' 3-1/2" 7923' 6460' 10159 10533
Pertoration depth: Measured depth: 7560-7562' 7610-7640'
true vertical depth: 7560-7562' 7610-7640'
Tubing (size, grade, and measured depth) 3.5", L-80, 6970' MD.
Packers & SSSV (type & measured depth) Baker SABL-3 liner top pkr Packer 6971 `
,.
,
.
Copies of Logs:artd Surveys run:
.: Explorato
ry prii ~ ~ Q
Aevelo ent Service
:.. :...:.:.. ..
Dail Re ort of Well O eratio~s._~F..::::::::;.:..: < :::::::::::::.::> :
Y__ P ............ ..... P
::::::::
:<1:6:.\IVell Status after prgposec#vrork : ° .:::° <.... '.., :.'
, : ::..:.:::...:.:. :...: ~ .;._ Ga.~ : :::1lVP~~^.:. `..:::''~~~:Q W1NJ ,^ WDSPL:°C~:
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Suridry:;hli~rnbec:orhffA: ii.C:Q.,ExemPt.• :::::::::::::::::.::::
::::::::::::::::::
.......
... ,...... .
~:: ' :::;:: _ -224::::
.
...................................................................
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,...,.. ........:.... : n-ArendlR 2.:: IntEr .:....: .
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?::.:Printed Name::. ,ion. Arend ....:::::::::::: ` .:::.
;.:::.:::.::::::::rile ::.::; :.;:::::.:::.:
:1t1(e.I( Ime rltyteld Su `ryasor E:~ :.:.:.:.:.:.:.:
signature - Ptioise. 65971)43 ::::.:::::.:. .:.659=70~4~~:,.:.:..:;::;:::<:.::::.',Date:>:::.:,.:::::::::::::..':.:::,:.. 121:1:5f2~0$
Form 10-404 Revised 04/2004 Submit riginal On~~~
• 1 Q-20a •
DESCRIPTION OF WORK COMPLETED
SUMMARY
Date Event Summary
11/30/08
T/I/O = SI/0/O.Nitrogen purged through OA valve.Cut and removed 12'-1" of conductor
casing.Removed cement from conductor and cleaned for inspection.Marked "A" and "B" !,
bands."A" band is 10",and "B" band is 12","A" band begins @ flutes and Bottom of "B" band is
6' down from flutes.Cleared scaffold of debris and reinstalled conductor containment.
12/01/08 Notified AOGCC State man to witnes damage to surface casing
12/12/08 SC patch weld -Complete. Purge nitrogen down annulus while welding Patch as per M.E.
specs. Weld 41" .500" upper wedding band A in no-go style including tie in seal weld to
mandrel hanger. Welded 4", .500 wall band "B" below SC coupling. Install .375" SC patch
that straddles SC cou lin .Total patch length from bottom of mandrel hanger to lower most
weddina band is 66". T/I/O = SI/0/0.
12/13/08
12/14/08
MITOA -PASSED Post SC atch weld. Pre MIT T/I/O = SI/0/0. Pressured OA to 1800 psi
with 1.0 bbl diesel. Start MIT T/I/O = SI/0/1800, 15 min read T/I/O = SI/0/1680, 30 min read
T/I/O = SI/0/1660, 45 min read T/I/0= SI/0/1660, 60 min read T/I/0= SI/0/1660. Total loss of
140 psi. Bled OA to zero. T/I/O = SI/0/0. Remove manifolds with gauges & install needle
valves for back filling excavation on IA/OA. Install VR plug in IA. Wrapped SC with Denso
wrap and pictures taken.
Install new conductor. Assist welders installing 12'1" of 16" 62.5# API 5L Gr B Conductor
casing. Ready to remove scaffolding, stairs & shoring box. T/I/O = SI/0/0.
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COI~TSERQATIO 1~Il IISSIpK
Perry HIein
Well Integrity Projects Supervisor
ConocoPhillips Alaska Inc.
PO Box 100360
Anchorage, AK 99510
•
SARAH PALIN, GOVERNOR
333 W, 7th AVENUE, SUITE 100
ANCHORAGE, ALASKA 99501-3539
PHONE (907) 279-1433
FAX (907) 276-7542
is~
Re: Kuparuk River Field, Kuparuk River Oil Pool, 1 Q-20a
Sundry Number: 308-224
~~~tdE~- JUN ~ 2008
Dear Mr. HIein:
Enclosed is the approved Application for Sundry Approval relating to the
above referenced well. Please note the conditions of approval set out in the
enclosed form.
When providing notice for a representative of the Commission to witness any
required test, contact the Commission's petroleum field inspector at (907)
659-3607 (pager).
As provided in AS 31.05.080, within 20 days after written notice of this
decision, or such further time as the Commission grants for good cause
shown, a person affected by it may file with the Commission an application
for rehearing, A request for rehearing is considered timely if it is received by
4:30 PM on the 23rd day following the date of this letter, or the next working
day if the 23rd day falls on a holiday or weekend. A person may not appeal
a Commission decision to Superior Court unless rehearing has been
requested.
Sincerely,
Daniel T. Seamount, Jr.
Chair
DATED thi~~2. day of June, 2008
Encl,
ConocoPhillips
•
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
June 23, 2008
Mr. Tom Maunder
Alaska Oil & Gas Commission
333 West 7th Avenue, Suite 100
Anchorage, AK 99501
q ~~~~ 2 5 2008
M~~`7t~."t Zvi: ti
Dear Mr. Maunder:
Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips
Alaska, Inc. well 1Q-20a PTD 195-156 surface casing excavation and repair.
Please call MJ Loveland or me if you have any questions.
Sincerely,
r
t.,_
l
Perry
Well Integrity Projects Supervisor
- -
STATE OF ALASKA
~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~ ,~U~°"I `~ 5 2~
APPLICATION FOR SUNDRY APPROVE ~~~ ~ ~~~ G~~~a ~Ol~fni~swon
20 AAC 25.280 BnriFF€r:r~nv
1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other ^
Alter casing ^ Repairwell 0' Plug Pertorations ^ 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 ^ 195-156 -
3. Address: Stratigraphic ^ Service ^ 6. API Number:
P. O. Box 100360, Anchorage, Alaska 99510 50-029-22589-01
7. If perforating, closest approach in pool(s) opened by this operation to nearest property line
where ownership or landownership changes:
Spacing Exception Required? Y@S ^ NO Q 10-20a
9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ~
ADL0025634 i ALK 2567 RKB 79' Kuparuk River Field /Kuparuk Oil Pool
12. PRESENT WELL CONDITION SUMMARY
Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ff): Effective Depth TVD (ft): Plugs (measured): Junk (measured):
7925' ~ 6468'
Casing Length Size MD TVD Burst Collapse
CONDUCTOR 121' 16" 121' 121'
SURFACE 5537' 7-5/8" 4099' 3688' 6890 4790
PRODUCTION 8502' S-1/2" 7180' 5920' 7000 4990
LINER 953' 3-1 /2" 7g23' 6466' 10159 10533
Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft):
7560-7562' 7610-7640' 7560-7562' 7610-7640' 3.5" L-80 6970'
Packers and SSSV Type: Packers and SSSV MD (ft)
Baker SABL-3 liner top pkr Packer 6971'
no SSSV no SSSV
13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work:
Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development^ Service ^
15. Estimated Date for 16. Well Status after proposed work:
Commencing Operations: July 13, 2008 Oil^ Gas ^ Plugged ^ Abandoned ^
17. Verba! Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^
Commission Representative:
18. I hereby certify that t ing i e an c ect tot best of my knowledge. Contact: Perry Klein / MJ Loveland
Printed Nam ___ Perry Klein Title: Well Integrity Projects Supervisor
Signature 'L Phone 659-7043 Date 06-22-08
Commission Use Onl
Sundry Number:
Conditions of approval: Notify Commission so that a representative may witness
Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^
Other: ~°d~~ ~ ~~ ~C~U `. C~- ~ \ ~~` ~:~ c~~ ~ ~ '~ i~S-~'e C~ C.'C%~`~<~.~C~ ~ ~~:s~ L~~~'C\~.
~~~c~ ~~ ~ ~g~ ~t .
Subsequent Form Required: ~t`~
APPROVED BY /2
~
Approved by' COMMISSIONER THE COMMISSION Date:
`
Form 10-403 Revised 06/2 ~' r` ~ n' ~ ! Submit in Duplicate
~ •
ConocoPhillips Alaska, Inc.
Kuparuk Well 1Q-20a (PTD 195-156)
SUNDRY NOTICE 10-403 APPROVAL REQUEST
June 22, 2008
This application for Sundry approval for Kuparuk well 1Q-20a is for the repair of a surface
casing leak. The well is an oil producer, drilled in Sept 1995. 7 5/8" surface casing was run and
cemented as planned. After drilling out the surface high pressures and gas were encountered
after weighting up, losses were encountered and a 17 ppg plug was set across the Kuparuk and a
15.8 ppg plug was set at the surface shoe. In Oct 1995 the 1 Q-20 well bore was side tracked as
1 Q-20a. In Jan 1996 the production liner was drilled and the well was completed. On March 3,
2007 fluids were observed flowing from the conductor top during a diagnostic MITOA and the
suspected surface casing leak was reported to AOGCC 3/4/2007. Subsequent testing indicated a
leak in the surface casing approximately 2' 10" down from the OA valve.
With approval, repair of the surface casing will require the following general steps:
1. Shut-in and secure well. Set positive pressure plug @ 6942' and fluid pack the IA as
needed to remove all gas. Freeze protect T and IA as needed. PT plug to verify barrier.
2. Excavate wellhead location.
3. Install nitrogen purge equipment.
4. Cut away the conductor casing and remove cement around surface casing leak for inspection.
5. Notify AOGCC Field Inspector of repair operation so they may witness the event.
6. Repair damaged surface casing to return the casing to operational integrity. Repair options
include sleeve patch, seal weld, lap patch, deposition weld and will be determined after
inspection of the casing damage.
7. QA/QC the repair welds and MIT-OA to verify integrity
8. Install anti-corrosion coating on exposed surface casing.
9. Patch the conductor and top off the conductor void with cement and waterproof sealant.
10. Backfill gravel around the wellhead.
11. Remove plugs and return the well to production.
12. Submit 10-404 report of repair operations to AOGCC.
~i
KRU 1 Q-20A
ConocoPhillips A laska, Inc.
1 Q-20A
API: 50029225
8
901 Well
Type; PROD Angle-@ TS: 43 deg @ 7363.
SSSV Type: .
_
NIPPLE .
,
Ori C_ompleuon: 2/3%19.9.6_ An 1e TD: 43 deg @ 7925
Annular Fluid: Last W/0:
, Rev Reason_ GLV C/O _
Reference Log: _ -
Ref Log_Date_ - __ _ _
_ Las[ U date: 7/12/2007
Last Tag: _
7620' RI(B est 20' Fill TD: 7923 ftKB
NIP (516517 Last Ta Date: _
4/27/2006 Max Hole An le: 47 de 5518
,
00:3.500) CasingStrin~_ AL
L STRINGS
_
Description Size l T~ Bottom _ - Wt
ND
- Grade
- -- Thread
CONDUCTOR 16.000 I _
0 _ _ _
121 .
121 62.58 H-40
- -
SUR.CASING 7.625 i __
0
~ -
4099 3688 _29.70 f L-80
_
PROD. CASING 5.500 I __
_
0 7180 1_5.50 I
5920 L-80_
Lift
G -- -
LINER
3.500
_
6970
7923
_
7923 9.30 I
L-80
as
3ndrel/Dummy Tubin Strin~
- TUBING
-------
Vale 1 _
- -- -
Size To T
p _
Bottom i
-- -
ND
Wt
Grade
Thread
(2439-2440,
3.500 O
i
6970 ----i
-- 5767--- --
- 9.30
_
L-80 __
-- --
ABM EUE
00:4.750) Perforations Summar~
-
Interval __
ND _-
Zone
Status
Ft
$PF
Date
hype
Comment
Gas Lift 7560 - 7562 7560 - 7`x62 UNIT B C 2 0 3/23/1996 r Sqz_ _
3ndrel/Dummy 7610 - 7620 7610 - 7620 A-3 10 4 ~ 4/5/1996 APERF 2 1/2" Hollow Carrier; 180 deg.
vale 2 phasing; Oriented 142 deg.
(39743975, CCW F/ Hi h Sf
OD:a75o) 7620 - 7640 7620 - 7640 A-3 20 2 4/5/1996 APERF 2 1/2" Hollow Carrier; 180 deg.
hasin ~ One Side Not Loaded
Gas Lift Stimulations & Treatments
~ Type Comment
Interval Date
andrel/Dummy
valee 3 -
- -- - - ---- - - - -
7560 - 7562 3/23/1996 Cement S ueeze Cancelled Attem t to Cement ueeze
(5,s55,ss, Gas Lilt MandrelsNalves
00:4.750) St MD ND Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv
Cmnt
_ _ _
1 2439 2381 BST AXT DMY 1.0 T-1 0.156 1334 i 6!27/2007
Gas Lift 2 3974 3591 BST AXT DMY 1.0 T-1 0.000 0 2/4/1996_
andrel/Dummy 3 5165 4473 BST AXT DMY 1.0 T-1 0.188 1353 6/27/2007
val~e4
61685169 4 6168 187 BST
5 AXT DMY 1.0__ T-1 0.000 0 _ 2/4/1996__
(
,
00:4
750)
~ 5 6888 .
.
5708 BST AXT DMY 1.0 T-1 0.188 0 6/27/2007
. .
Other lu s e ui .etc. -JEWELRY
De th ND Type Description __~ ID
Gas lift 516 516 NIP Camco'DS' Landing Nipple; 2.85. 6" NO GO 2.812" I 2.812
andreuDummy 6942 5747 NIP -~
Camco'D' NI le NO GO 2750
valvE 5 6956 5757 PBR __ _ _ _ _ _ . _
Baker 80.40 w/ 10' Stroke ~ 2.992
(6688-688s, 6970
5767 ANCHOR Baker Stab into'SABL-3' Liner Pkr _~~ 2.992
00:4.750) _ _
6970 5767 TTL 2.992
6971 ~
5768 PKR Baker'SABL-3' LINER PACKER 2.812
NIP _
General Notes - ~.~ -_.:_._. _.
(69425943 ,
Date Note
,
00:3.500) 6123/1995
NOTE: Ori final Well was P & A'd due to as at surface 8 lost circulation.
. _
PBR
(6956-6957,
00:3.500)
TUBING
(0-6970,
00:3.500,
10:2.992)
TTL
(69705971,
00:3.500)
Cement
Squeeze
(7560-7562)
Pert
(7560-7562)
Perf
(7610-7620)
Perf
(7620-7640)
LINER
(6970-7923,
00:3.500,
Wt:9.30)
Schlumberger
NO. 3604
Schlumberger -DCS
2525 Gam bell Street, Suite 400
Anchorage, AK 99503-2838
A TTN: Beth
:.:¿EGE1\¡EO /
(\ -- r:.
::--",' '21 ~2J05 i\f~i\C<)
Company: Alaska Oil & Gas Cons Comm
Attn: Helen Warman
333 West 7th Ave, Suite 100
Anchorage, AK 99501
,.i Gas Cens. CÜ¡T.¡{;¡~:m>
i~nçhor;,;g8
h _' ' _._" _ fì\i 2 ~ 2ûlY5Field:
Sçl\NNEU NU ~ -
Kuparuk
Well Job # Log Description Date BL
2C-05 11072930 INJECTION PROFILE 11/02/05 1
2Z-09 11057062 INJECTION PROFILE 11/03/05 1
20-09 11141218 LEAK DETECTION LOG 11/04/05 1
3F-03 11141219 INJECTION PROFILE 11/05/05 1
3F-01 11057064 PRODUCTION PROFILE 11/05/05 1
3F-15 11057065 INJECTION PROFILE 11/07/05 1
1 F-03A 11141222 LEAK DETECTION LOG 11/08/05 1
1G-17 11141221 PRODUCTION PROFILE 11/07/05 1
1J-164 N/A USIT 11/12/05
3G-25X 11141229 SBHP SURVEY 11/16/05 1
1 Q-20A 11144038 SBHP SURVEY ,q~- 15~ 11/17/05 1
Color
CD
1
SIGNED:¿-_~C~(:' ,__
~ - - rT
.J
DATE: n)YI)(SI?
Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you.
11/18105
-
153 - Oc:¡c¡ U i
féy5-~ \3& L'lC
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iú3-ddl U 'I (
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If)') -d'=t~ U¡ C
,q ~~ 09/L)
i 9 C¡ -oee;:{ ~-
,,)05-144-.¿v
/ c¡ (.tJ - j 3l¿;
/95-f5l..::.
---/
Change Approved Program
2. Operator Name:
ConocoPhillips Alaska, Inc.
3. Address:
P. O. Box 100360
7. KB Elevation (ft):
RKB 79'
1. Operations Performed:
Abandon
Alter Casing
STATE OF ALASKA ( RECEIVED
ALASKA Oil AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS'j~ 1 () 2004
0 Suspend 0 Operation Shutdown 0
0 Repair Well 0 Plug Perforations 0
0 Pull Tubing 0 Perforate New Pool 0
4. Current Well Status:
Development - B
Stratigraphic 0
Perforate lAJaska Oi! 81 G)(~r~m1$. C¡Qr!&m~IY Disp. 0
Stimulate 0 Tirt\~J~~~ 0 Other 0
Re-enter Suspended Well 0
5. Permit to Drill Number:
195-156/
6. API Number:
50-029-22589-01
Exploratory 0
Service 0
9. Well Name and Number:
1 Q-20A
8. Property Designation:
Kuparuk River Unit
11. Present Well Condition Summary:
10. Field/Pool(s):
Kuparuk Oil Pool
Total Depth
Effective Depth
Casing
Structural
CONDUCTOR
SUR. CASING
PROD. CASING
LINER
Perforation depth:
measured 7925' feet
true vertical 6468' feet
measured 7923 feet
true vertical feet
Length Size MD
121' 16" 121'
40201 7-5/8" 40991
7101' 5-1/2" 7180'
9531 3-1/2" 79231
Plugs (measured)
Junk (measured)
TVD
Burst
Collapse
121'
36881
5920'
64661
Measured depth: 7560-7562, 7610-7640'
true vertical depth: 6199-6201, 6236-6258'
Tubing (size, grade, and measured depth) 3-1/2" , L-80, 6970' MD.
Packers & SSSV (type & measured depth) pkr= BAKER 'SABL-3' LINER PACKER pkr= 6971'
SSSV= NIP SSSV= 516'
12. Stimulation or cement squeeze summary:
Intervals treated (measured)
N/A
13.
Treatment descriptions including volumes used and final pressure:
Representative Daily Average Production or Injection Data
Gas-Met Water-Bbl
863 118
863 118
15. Well Class after proposed work:
Exploratory D Development 0 Service D
16. Well Status after proposed work:
Oil0 GasD WAGD GINJD WINJ D
17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A it C.O. Exempt:
Prior to well operation
Subsequent to operation
14. Attachments
Copies of Logs and Surveys run -
Daily Report of Well Operations _X
Contact
Printed Name
Oil-Bbl
378
378
Casinq Pressure
559
559
Tubinq Pressure
172
172
WDSPLD
Dethelfs/McConnell, 659-7224
~rry Dethle.fS ~
:/~/ é G--""'Z)
Signature
Title
Phone
Problem Well Supervisor
9' ¡) 1 - &./~ ~? 22.~' Date
?/~/
Form 10-404 Revised 2/2003 .
() Q J ~ r f\I ^ I
SUBMIT IN DUPLICATE
ConocoPhillips Alaska, Inc.
Kuparuk WelllQ-20A (PTD 1951560)
Report Of Sundry Operations
06/08/04
A cement shoe was pumped down the Outer Annulus (OA) of 1Q-20A on 06/01/04. Details of
the operation are as follows:
Pumped 19.5 bbl or 1000' OA cement shoe. T/I/O = 1000/550/0 Bled IA to 200 psi in 45
minutes, MIRU Schlumberger cement truck; pumped 75 bbls of fresh water at a rate of 4.2 bpm
@ 1700 psi, followed by 19.5 bbls of 15.8 ppg "Tail" cement slurry. Chased cement to shoe with
5 bbls of water and 54 bbls of diesel. (59 bbls of displacement).
Noticed a slight increase in pumping pressure when cement reached existing shoe depth. SD
pump and OA sustained 1000 psi, bled back to 520 psi. In 10 minutes the OAP increased back to
820 psi. Bled OA back to 600 psi and monitored for 15 minutes. OAP increased back up to 860
psi, bled back down to 600 psi and monitored for additional 15 minutes. Final pressures;
1000/220/620
NSK Problem Well Supervisor
06108/04
(
8: i¡; ConocoPhillips Alaska, Inc.
. 1Q-20A
API: 500292258901
I . SSSV Type: NIPPLE
Annular Fluid:
Reference Log:
Last Tag: 7631
Last Tag Date: 3/24/2004
Casing String - ALL STRINGS
Description
CONDUCTOR
SUR. CASING
PROD. CASING
LINER
Tubing String - TUBING
Size I Top
3.500 0
PelforatlonsSummary
Interval TVD
7560 - 7562 7560 - 7562
7610 - 7620 7610 - 7620
NIP (516-517,
00:3.500)
Gas Lift
MandrelNalve
1
(2439-2440,
Gas Lift
mdrel/Oummy
Valve 2
(3974-3975,
00:4.750)
Gas Lift
MandrelNalve
3
(5165-5166,
Gas Lift
mdrel/Oummy
Valve 4
(6168-6169,
00:4.750)
Gas Lift
MandrelNalve
5
(6888-6889,
NIP
(6942-6943,
00:3.500)
PBR
(6956-6957,
00:3.500)
TUBING
(0-6970,
00:3.500,
10:2.992)
TTL
(6970-6971,
00:3.500)
Cement
Squeeze
(7560-7562)
Perf
(7560-7562)
Perf
(7610-7620)
Perf
(7620-7640)
LINER
(6970-7923.
00:3.500,
Wt:9.30)
II-III
I i.l
.-.,
."
(
J
7620 - 7640
7620 - 7640
KRU
1 Q-20A
Well Type: PROD
Orig 10/26/1995
Completion:
Last W/O: 2/4/1996
Ref Log Date:
TD: 7923 ftKB
Max Hole Angle: 47 deg (â) 5518
Angle (éi) TS: 43 deg (â) 7363
Angle @ TD: 43 deg @ 7925
Rev Reason: TAG, GLV design
Last Update: 4/412004
Size
16.000
7.625
5.500
3.500
Top
0
0
0
6970
Bottom
121
4099
7180
7923
Wt
62.58
29.70
15.50
9.30
Grade
H-40
L-80
L-80
L-80
TVD
121
3688
5920
7923
Thread
Bottom
6970
TVD
5767
Wt I Grade I
9.30 L-80
Thread
ABM EUE
Zone
UNITS
A-3
A-3
Status Ft SPF Date Type
C 2 0 3/23/1996 Sqz
10 4 4/5/1996 APERF 21/2" Hollow Carrier; 180
deg. phasing; Oriented 142
deg. CCW F/ High Si
20 2 4/5/1996 APERF 21/2" Hollow Carrier; 180
deg. phasing; One Side Not
Loaded
Comment
St MD TVD Man Man Type V Mfr V Type VOD Latch Port TRO Date Vlv
Mfr Run Cmnt
1 2439 2381 BST AXT GLV 1.0 T-1 0.156 1334 3/26/2004
2 3974 3591 BST AXT DMY 1.0 T-1 0.000 0 2/4/1996
3 5165 4473 BST AXT GLV 1.0 T-1 0.188 1362 3/26/2004
4 6168 5187 SST AXT DMY 1.0 T-1 0.000 0 2/4/1996
5 6888 5708 BST AXT OV 1.0 T-1 0.250 0 3/26/2004
Description ID
Camco 'OS' Landing Nipple; 2.856" NO GO 2.812" 2.812
6942 5747 NIP Camco'D' Nipple NO GO 2.750
6956 5757 PBR Baker 80-40 w/ 10' Stroke 2.992
6970 5767 ANCHOR Baker (Stab into 'SABL-3' Liner Pkr 2.992
6970 5767 TTL 2.992
6971 5768 PKR Baker 'SABL-3' LINER PACKER 2.812
Note on Schematic: Original Well was P & A'd due to gas at surface and lost circulation.
MEMORANDUM
TO:
THRU:
Tom Maunder,
P. !. Supervisor
State of Alaska
Alaska Oil and Gas Conservation Commission
Julie Heusser, ~,~,~ DATE: May 17, 2001
Commissioner
FROM: John Crisp, SUBJECT:
Petroleum Inspector
Safety Valve Tests
Kuparuk River Unit
lQ Pad
May 17 ,.2001: I traveled to Phillips Alaska's Kuparuk River Field to witness
Safety Valve System tests.
Ernie Bamdt was Phillips Rep. in charge of SVS testing. Testing was conducted
in a safe & efficient manner. I witnessed one failure, the SSV on 1Q-05 would
not pass the DP test. The valve was serviced & would not pass the re-test. Well
1Q-05 is shut in until repaired & re-tested. The AOGCC test report is attached
for reference.
I inspected 20 well houses on lQ Pad w/no problems witnessed.
$.U.MMARY: ! witnessed SVS testing in Kuparuk River Field.
15 wells, 30 components tested. 1 failure witnessed. 3.33% failure rate.
20 well houses inspected.
Attachments: SVS KRU lQ 5-17-01jc
CC;
NON-C,O, NFIDENTIAL
SVS KRU lQ 5-17-01jc
Alasga Oil and Gas Conservation Commis~.
Safety Valve System Test Report
Op~ator: Phillips Alaska
Operator Rep: ,Ernie Bamdt
AOGCC Rep: John Cr~P
Submitted By: John Crisp Date:
Field/Unk/Pad: ~UP. ,aruk,Rive.r U. nit ,1. Q P~.
Separator psi: LPS 85 HPS
5/17/01
Well Permit Separ Set [dP Test Test Test Date oil, WAG, GIDIJ,
Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE
Q-O:A,
~lQ-03 1842330 85 70 65! P P OIL
!Q,-04 .. ,1842340 ' 85 ' ' 60 " 55' P ' P ...... (~IL
lQ-,0.5, 1842170 85 70 54 p ' 4 ' OIL
iJQ-06 . ,,1,8/~2080 ,, 85 60 55 P'" i',,'e i."' ,,'~'i,' ' OIL
i.lQ-09 1841920 3750 2000 1900 .... P P ..... WAG
ilQ-10 ..... 1841980 '' 85 ~0 ' 62 P e .............. oIL!
,,!Q-11 1841990 .........
,lQ-12 1841930
1Q-lS ,, 1,850,4,60, ....
1Q-l,6 1850470 .... 85 .... 70 , , 64 P ...... P ....... OIL
Q-20A i~i560,, 8~ 70 ....6,0 ,_P , , , P ........ 0IL
., ~
lQ-21 1951330
Q-22 ~ 1951400 '8'5 ' ' '70 55 P' e OIL
Q-23 195'1410' ' ' 85 70 ..... 50 e" P ............ OIL
'1Q,26. 1951320 ' ' 85 ' 70 52 15' P .... 't~I[L
Q-08 "'1970930 ' 57 b"2600 185o" P "i; .......... WAG
lQ-13 18504~6 3750 2000 1850 P P ....... ~AG
Q714 18504~,.0, 3750 ~000' , ,18go P ,, ,, e . ," WAG
1Q-24 1951210 3750 2000! 2100 P P WAG
.
,,
Wells: 15 Components: 30 Failures: 1 Failure Rate: 3.33% ~ 9o oar
Remarks:
1Q-05 was serviced & re-tested, re-test failed & Well was shut in for repairs. , .....
RJF 1/16/01 Page 1 ofl SVS KRU lQ 5-17-01jc
THE MATERIAL
UNDER THIS COVER HAS BEEN
MICROF:ILMED
ON :OR
BEFORE
JAN____UA 2001
M
PL
A T
E IA L
E
W
U N
D
E
R
T H
I~S M
A R
K
E R
MEMORANDUM
TO: Julie Heusser,
Commissioner
State of Alaska
Alaska Oil and Gas Conservation Commission
DATE'
November 13, 2000
THRU:
FROM: SUBJECT:
Blair Wondzell,
P. I. Supervisor
John Crisp,
Petroleum Inspector
Safety Valve Tests
Kuparuk River Unit
lQ Pad
November 13, 2000: I traveled to Phillips AlaSka's KRU lQ Pad to witness
Safety Valve System tests.
Kuparuk's problem wells group now has a down hole diagnostics crew for wells
work, this includes SVS testing. The gentlemen I worked with were not
comfortable with testing procedures for MI wells in Kuparuk. Test procedures
were discussed & everyone agreed that improvements in procedures could be
implemented. We were able to test one producer & two MI wells after my arrival /
on lQ Pad. DHD crew was scheduled for safety training after lunch. When DHD
/
crew's training is completed & test procedures are in place it will be a good
improvement for State testing in Kuparuk.
SUMMARY: I Witnessed SVS testing in KRU on lQ pad.
3 wells, 6 components tested. No failures witnessed.
Attachments: sVs KRU lQ 11-13-00jc
cc;
NON.CONFIDENTIAL
SVS KRU lQ 11-13-00jc.doc
Alaska Oil and Gas Conservation Commission
Safety Valve System Test Report
Operator: Phillips Alaska
Operator Rep: Pete Nezaticky
AOGCC Rep: John Crisp
Submitted By: John Crisp Date:
FielclFcl~ad: Kuparuk River Field 1Q Pa
Separator psi: LPS 88 HPS
11/13/00
Well Permit Separ set L/P Test Test Test Date
Oil, WAG, GINJ,
Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE
1Q-02A 1951940
lQ-03 1842330
lQ-04 1842340~
lQ-05 1842170~
, ,
lQ-06 1842080
lQ-09 1841920! I ',
lQ-10 1841980
lQ-11 1841990
lQ-12 1841930
· ,
lQ-15 1850460
lQ-16 1850470
1Q-20A 1951560 88 70 54 P P OIL
lQ-21 1951330 .
,,
1Q-22 1951400
1Q-23 1951410
1Q-26 1951320
lQ-08 1970930 4000 2000 1850 P P 'wAG
,
1Q214 1850450 4000 2000 1990 P P WAG
Wells: '3 Components:
Remarks:
6 Failures: ~ 0 Failure Rate: 0.0% [-3 90 var
11 / 16/00
Page 1 of 1
SVS KRU lQ ll-13-00jc.xls
PERMIT
DATA
AOGCC Individual Well
Geological Materials Inventory
Page: 1
Date: 04/20/98
T DATA PLUS RUN RECVD
95-156
FASOR DIL-GR
95-156 PHASOR
95-156 7210 ~1~pHASOR IND 04/10/96
95-156 7211 ~,,~t~'SLIM1 MWD 04/10/96
95-156 SLIM 1/GR ~PIA 04/10/96
- zp/
DAILY WELL OPS R q/!?~/'~/ TO ~,.'/ /'~'~(~/ .'??/./~.~/'-.~/
Are dry ditch samp~"es required? yes ~ And received?
Was the well cored? yes alysis & description received?
Are well tests required? yes
Well is in compliance ~
Initial
COMMENTS
~ho~ ~_Received? yes~~
ARCO Alaska, Inc.
Post Office Box 1003bu
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
August 22, 1996
Mr. David J. Johnston
Commissioner
State of Alaska
Alaska Oil & Gas Conservation Commission
3001 Porcupine Drive
Anchorage, Alaska 99501
Subject: 1Q-20A (Permit No. 95-156) Well Completion Report
Dear Mr. Commissioner:
Enclosed is the well completion report for the completion on KRU 1Q-20A.
This well was top set above the Kuparuk formation by Parker rig 245
because of high reservoir pressure. The well was later drilled out by Nordic
rig # 1 and a 3.5" liner run to T.D.
If there are any questions, please call 263-4622.
Sincerely,
W. Isaacson
Drilling Engineer
Kuparuk Drill Site Development
WSI/skad
RECEIVED
AUG 2 3 1996
0il & Gas Cons. Commission
Anchorage
STATE OF ALASKA
,-,bASKA OIL AND GAS CONSERVATION C ..... iISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
I Status of Well Classification of Service Well
OIL [~] GAS E~ SUSPENDED [~] ABANDONED [] SERVICE ~]
2 Name of Operator 7 Permit Number
ARCO Alaska, Inc 95-156
3 Address 8 APl Number
P.O. Box 100360, Anchorage, AK 99510-0360 -~_,,.~,_ _, _. ,_,.,.,__..,_..- 50-029-22589-01
4 Location of well at surface ,~,',,~ t .~,,~i~ 9 Unit or Lease Name
1090' FNL, 1820' FEL, Sec. 26, T12N, R9E, UM ~t ...... , '---~ ~()~'i ! Kuparuk River Unit
2274' FSL, 1767' FEL, Sec. 23, T12N, R9E, UM ~ i - 1Q-20A
At Total Depth ~~=~ 11 Field and Pool
2639' FNL, 1871' FEL, Sec. 23, T12N, R9E, UM "' ...... ' ...... ' ..... ':¢ KUPARUK RIVER
5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No.
Nordic ¢1 Ri~] RKB 25', Pad 54'I ADL 25634 ALK 2567
12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore [16 No. of Completions
10-24-95 (sidetrack) 02-2-96 (drillout) 05-Apr~96 (perrd) NA feet MSL
17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 DirectionalSurvey 120 Depth where SSSV set 121 Thickness of permafrost
7925'MB &6471'TVD 7826'MD &6398'TVD YES r~ NO--biI NA feetMDI -= 1380'ss APPROX
22 Type Electric or Other Logs Run
Slim 1/GR, GR/CCL/CBT
23 CASING, LINER AND CEMENTING RECORD
SETTING DEPTH MD
CASING SIZE W'T GRADE TOP BTM HOLE SIZE CEMENT RECORD
16" 62.58# H-40 SURF. 121' 24" 223 sx AS I
7.625" 29.7# L-80 SURF. 4099' 9.875" 630 sx AS III Lead, 320 sx Class G Tail
5.5" 15.5# L-80 SURF. 7180' 6.75" 130 sx Class G
3.5" 9.3# L-80 6971' 7923' 4.75" 100 sx Class G
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)
3.5" 6970' 6971'
7620'-7640' MD 2 spf 6246'-6261'TVD
7610'- 7620' MD 4 spf 6239' - 6246' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC
DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED
7610- 7640' pumped 12M# 20/40, 153.3M# 12/18, 10.5M#
10/14 proppant (175.2M# w/10.2 ppa @
perfs
27 PRODUCTION TEST
Date First Production IMethod of Operation (Flowing, gas lift, etc.)
6-Apr-96I Gas Lift
Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO
14-Apr-96 12 TEST PERIOD ¢ 367 191 0 209I 521
FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr)
Press 247 7 3 24-HOUR RATE ¢ 734 382 0 =24"
28 CORE DATAr~
Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ~ L
An~horag6
Form 10-407 Submit in duplicate
Rev. 7-1-80 CONTINUED ON REVERSE SIDE
90.
GEOLOGIC MAF~ERS FORMATION TESTS
NAME Include interval tested, pressure data, all fluids recovered and gravity,
MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase.
Top Kuparuk C 7563' 6058'
Bottom Kuparuk C 7454' 6125'
Top Kuparuk A 7576' 6214'
Bottom Kuparuk A 7716' 6317'
FREEZE PROTECTED ANNULUS
31. LIST OF A-I-FACHMENTS
Daily Drilling History, Directional Survey
32. I hereby certify that the foregoing is true and correct to the best of my knowledge.
INSTRUCTIONS
General' This form is designed for submitting a complete and correct well completion report and log on
all types of lands and leases in Alaska.
Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt
water disposal, water supply for injection, observation, injection for in-situ combustion.
Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements
given in other spaces on this form and in any attachments.
Item 16 and 24: If this well is completed for separate production from more than one interval (multiple
completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported
in item 27. Submit a separate form for each additional interval to be separately produced, showing the
data pertinent to such interval.
Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.).
Item 23: Attached supplemental records for this well should show the details of any multiple stage cement-
ing and the location of the cementing tool.
Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In-
jection, Gas Injection, Shut-in, Other-explain.
Item 28: If no cores taken, indicate "none".
Form 10-407
Date' 5/28/96
ARCO ALASKA INCORPORATED
WELL SUMMARY REPORT
Page: 1
WELL:iQ-20A RIG-PARKER 245
WELL ID: AK8277 AFC: AK8277 TYPE-
STATE:ALASKA
AREA/CNTY: NORTH SLOPE EAST
FIELD' KUPARUK RIVER UNIT
SPUD:09/05/95 START COMP'
BLOCK:
FINAL:
WI: 55% SECURITY:0
AFC EST/UL:$ 1200M/
API NUMBER: 50-029-22589-00
OM
09/05/95 (1)
TD: 484' (484)
SUPV: GR
DAILY:
09/06/95 (2)
TD' 4110' (3626)
SUPV:DWG
DAILY:
09/07/95 (3)
TD: 4110' ( 0)
SUPV'JT
DAILY:
09/08/95 (4)
TD: 5260' (1150)
SUPV' JT
DAILY:
09/09/95 ( 5)
TD' 6715' (1455)
SUPV:JT
DAILY'
09/10/95 ( 6)
TD' 7353' (638)
SUPV' JT
DAILY:
09/11/95 ( 7)
TD' 7353' ( 0}
SUPV' JT
DAILY:
09/12/95 (8)
TD' 7353' ( 0)
SUPV:JT
DAILY-
MW: 9.0 PV/YP: 30/36 APIWL: 6.0
DRILL 9-7/8" HOLE @ 484'
Move rig to lQ-20. Accept rig at 1630 hrs. 9/4/95. Drill
cement in conductor from 88' to 95'. Spud well @ 0300 hrs
9/5/95. Drill cement in conductor from 95' to 121' Drill
9-7/8" hole from 121' to 484'.
$130,346 CUM: $130,346 ETD: $0 EFC: $1,330,346
MW: 10.0 PV/YP: 24/36 APIWL: 5.8
SHORT TRIP TD 7-5/8 CSG PT.
Drill 9-7/8" hole from 484' to 4110'
$78,563 CUM: $208,909 ETD: $0 EFC: $1,408,909
MW: 10.1 PV/YP' 24/12 APIWL: 6.0
NU BOPE
Run 7-5/8" casing. Cement well.
$181,444 CUM: $390,353 ETD: $0 EFC: $1,590,353
MW: 8.8 PV/YP: 5/10 APIWL: 14.6
DRILLING
Test BOPE. Wash and ream to 3984' Drilled from 4220' to
5260'
$71,141 CUM: $461,494 ETD: $0 EFC: $1,661,494
MW: 9.1 PV/YP' 12/ 6 APIWL' 6.8
DRILLING
Drilled from 5260' to 6715'
$75,220 CUM' $536,714 ETD'
·
MW' 10.8
CIRCULATING TO CONTROL WELL
Drilled from 6715' to 7353' Circulating gas cut mud. Shut
in well. Monitor pressure.
$94,098 CUM: $630,812 ETD' $0 EFC: $1,830,812
$0 EFC- $1,736,714
PV/YP' 25/10 APIWL: 3.2
MW' 11.5 PV/YP' 28/10 APIWL: 2.8
CIRCULATING TO CONTROL WELL.
Shut in well and monitor pressure. Circulating to control
well.
$110,146 CUM' $740,958 ETD- $0 EFC: $1,940,958
MW: 12.5 PV/YP: 34/15 APIWL: 2.0
CIRCULATING
Continuing to have well control problems. Final weight up
to 12.5 ppg.
$90,075 CUM: $831,033 ETD: $0 EFC: $2,031,033
Date' 5/28/96
ARCO ALASKA INCORPORATED
WELL SUMMARY REPORT
Page' 2
09/13/95 (9)
TD' 7353' ( 0}
SUPV:DCL
DAILY:
09/14/95 (10)
TD: 7353' ( 0}
SUPV: DCL
DAILY:
09/15/95 ( 11)
TD' 7353' ( 0)
SUPV'DCL
DAILY:
09/16/95 (12)
TD: 6705' ( 0)
SUPV:JT
DAILY:
09/17/95 (13)
TD: 6705' ( 0)
SUPV:JT
DAILY:
09/18/95 (14)
TD: 3840' ( 0)
SUPV:JT
DAILY:
10/23/95 (15)
TD: 4120' (280)
SUPV:JT
DAILY:
10/24/95 ( 16)
TD: 5056' (936)
SUPV: JT
DAILY:
10/25/95 ( 17}
TD: 7190' (2134)
SUPV:RLM
DAILY:
10/26/95 ( 18)
TD: 7190' ( 0)
SUPV:RLM
MW: 12.5 PV/YP: 30/14 APIWL: 1.8
CIRCULATING-PREP TO SPOT LCM
Continue to have well control problems. Monitoring well.
$76,605 CUM: $907,638 ETD: $0 EFC: $2,107,638
MW: 12.5 PV/YP: 34/16 APIWL: 2.2
CIRC 12.5 PPG MUD AROUND
Finish circ out gas cut mud. Monitor well; well dead. Spot
50 bbl LCM pill on bottom. Preparing to set plug when
complete returns were lost. Circulating 12.5 ppg mud w/18
ppb LCM.
$92,224 CUM: $999,862 ETD: $0 EFC: $2,199,862
MW: 12.5 PV/YP: 21/18 APIWL: 3.0
PREP TO SET P & A PLUG
Test cement lines. Spot balanced cement plug across the
Kuparuk sands. Tag cement plug @ 7082' Circulate to clean
hole and prep for second cement plug.
$124,537 CUM: $1,124,399 ETD: $0 EFC: $2,324,399
MW: 12.5 PV/YP: 17/19 APIWL: 4.4
ATTEMPT TO SET CEMENT RETAINER
Spot balanced cement plug. Tag cement at 6705' Attempt to
set cement retainer.
$82,061 CUM: $1,206,460 ETD: $0 EFC: $2,406,460
MW. 0.0 PV/YP- 0/ 0 APIWL: 0.0
LDDP
Set retainer at 3908'. Cement. Test casing. OK. Displace
well to diesel.
$269,437 CUM: $1,475,897 ETD' $0 EFC: $2,675,897
MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0
MOVE RIG TO 1Q-26
Move rig to 1Q-26. Release rig @ 2030 hrs. 9/17/95.
$310,084 CUM: $1,785,981 ETD: $0 EFC: $2,985,981
MW: 9.5 PV/YP: 14/ 9 APIWL: 7.5
TRIPPING PIPE
Accept rig @ 10:00 10/22/95. Test BOPE to 3000 psi. Drill
out 10' cement stringer. Drill EZSV and hard cement to
4099', no cement to 4110', hard cement to 4120' Perform
FITto 12.5 ppg EMW.
$84,229 CUM: $1,870,210 ETD: $0 EFC: $3,070,210
MW: 9.6
DRILLING AWAY
Drilled from 4120' to 5056'.
$73,569 CUM: $1,943,779 ETD:
PV/YP' 15/10
APIWL' 6.8
$0 EFC: $3,143,779
MW' 9.6 PV/YP' 14/ 8 APIWL: 6.5
CIRCULATE FOR SHORT TRIP
Directional drill 6-3/4" hole from 5056' - 7190'
$72,914 CUM' $2,016,693 ETD' $0 EFC' $3,216,693
MW' 9.8 PV/YP' 18/10 APIWL' 6.8
NIPPLE DOWN BOPE
Run 5.5" casing to 7180' Cement casing, CIP at 0410 hrs.
10/26/95.
Date: 5/28/96
ARCO ALASKA INCORPORATED
WELL SUMMARY REPORT
Page: 3
DAILY:
10/27/95 (19)
TD: 7190' ( 0}
SUPV:RLM
DAILY:
$126,788 CUM: $2,143,481 ETD:
$0 EFC: $3,343,481-
MW: 0.0 PV/¥P: 0/ 0 APIWL: 0.0
RIG RELEASED
Nipple down and set back BOPE. Test packoff to 3000 psi.
Freeze protect. Release rig @ 1600 hrs 10/26/95.
$35,558 CUM: $2,179,039 ETD: $0 EFC: $3,379,039
End of WellSummary for Well:AK8277
Date: 5/29/96
ARCO ALASKA INCORPORATED
WELL SUMMARY REPORT
Page: 1
WELL:iQ-20A RIG-NORDIC
WELL ID: AK8277 AFC: AK8277 TYPE'
--
STATE'ALASKA
AREA/CNTY' NORTH SLOPE EAST
FIELD' KUPARUK RIVER UNIT
SPUD'09/05/95 START COMP:
BLOCK:
FINAL'
WI: 55% SECURITY:0
AFC EST/UL'$ 1200M/
API NUMBER: 50-029-22589-00
OM
01/28/96 (20)
TD- 7190' ( 0)
SUPV: DEB
DAILY:
01/29/96 (21)
TD' 7190' ( 0)
SUPV'DLW
DAILY:
01/30/96 ( 22}
TD: 7212' ( 22)
SUPV:DLW
DAILY:
01/31/96 ( 23)
TD: 7365' (153)
SUPV'DLW
DAILY:
02/01/96 ( 24)
TD' 7591' ( 226)
SUPV'DLW
DAILY:
MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0
RU GBR TONGS
Move rig from 1Q-02A to 1Q-20A. Accepted rig @ 0830 hfs
1/27/96. ND tree and tubing head adapter. NU BOPE. Test
BOPE to 250/5000 psi; test annular to 300/3000 psi.
$41,050 CUM: $2,220,089 ETD: $0 EFC: $3,420,089
MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0
LOOK FOR CMT @ 6850
RIH with 3.5" drill string to 130' hitting ice plugs. Circ
and recover diesel freeze protection fluid @ 2100'. RIH to
2100' continue to P/U new 2-7/8" DP and break in new
,
connections to 6725' Break circulation every 2000' and
pump pipe volume w/fresh water. P/U kelly and circulate @
6725' Displace all mud w/fresh water.
$33,757 CUM: $2,253,846 ETD: $0 EFC: $3,453,846
MW: 11.6 PV/YP: 33/21 APIWL: 4.2
DRILL 4.75" HOLE @ 7212'
Continue singling in looking for cement. Tagged up @ 6942'
Clean out to float collar 7086' Nordic %1 RKB. Test 5.5
casing from 7086 to surface w/3500 psi for 30 min. 100 psi
loss OK. Continue to clean out cement from 7086'to 7166'
5.5 casing shoe Nordic rig %1 MD. Continue drilling 4.75"
hole from 7066 to 7081'. FIT @ 5920' TVD. Drill 4.75" hole
from 7181' to 7200' Clean screens on rig pumps. Drill from
7200' to 7202' bit balling up not making hole. Clean
screens on pumps and suction valves, replace packing on one
plunger. Drill from 7202; to 7212', trying to unball bit.
Working with motor and trying to make bit drill.
$50,970 CUM: $2,304,816 ETD: $0 EFC: $3,504,816
MW: 11.8 PV/YP: 33/11 APIWL: 4.4
DRILL 4.75" HOLE @ 7365'
Continue drilling 4.75" hole w/BHA %1 Hycallog PDC bit
balling up in shales, drills sand, OK. Change bit. Continue
drilling 4.75" hole from 7253' to 7365'
$41,470 CUM: $2,346,286 ETD: $0 EFC: $3,546,286
MW: 11.7 PV/YP: 33/15 APIWL: 4.0
CBU @ 7591 GAS CUT MUD ll.3PPG
Continue drilling 4.75" hole from 7365' to 7591'. Check for
flow after drilling sands. Had gas cut mud 11.1 ppg from
11.7 ppg, could have been from connection @ 7491'. Wash and
ream 40' to bottom, no fill. Continue CB~~~~ll.3
ppg from 11.7 ppg.
I\L~L/ V LL./
$40,030 CUM: $2,386,316 ETD: $0 EFC: $3,586,316
AUG 2 3 1995
Alask~ Oil & G~ Cone.
Anchora,.,le
Date: 5/29/96
ARCO ALASKA INCORPORATED
WELL SUMMARY REPORT
Page: 2
02/02/96 (25)
TD: 7925' (334)
SUPV: DLW
DAILY:
02/03/96 (26)
TD: 7925' ( 0)
SUPV:DLW
DAILY:
02/04/96 (27)
TD: 7925' ( 0)
SUPV:DLW
DAILY:
02/05/96 ( 28)
TD: 7925' ( 0)
SUPV:DLW
DAILY:
02/06/96 ( 29}
TD: 7925' ( 0)
SUPV:DLW
DAILY:
MW: 12.3 PV/YP: 35/16 APIWL: 3.8
CIRC & RAISE MUD WT. TO 12.6
Drill 4.75" hole from 7591' to 7641'. Gas cut mud to
surface. Close and put on choke circulate through poor boy
gas buster. Mud gas cut to 11.0 ppg from 11.9 ppg. Flow
check after bottoms up OK. Drill from 7641' to 7654' gas
cut mud to service from flow check. Circulate gas cut mud
from 12.2+ ppg to 11.9 ppg. Continue drill while raising
mud weight from 7654' to 7870' Gas cut mud on bottoms up
11.7 ppg from 12.3 ppg. No gas cut mud on connections.
Continue drill 4.75" hole from 7870' to 7925'. Monitor well
for 5 min before short trip. Well dead no flow. RIH to
7923' Gas cut mud 10.7 ppg from 12.3 ppg. Continue to
circulate and raise mud weight to 12.6 ppg.
$25,225 CUM: $2,411,541 ETD: $0 EFC: $3,611,541
MW: 12.7 PV/YP: 37/16 APIWL: 3.6
RUN 3.5" LINER ON 2-7/8" DP
Circulate and raise mud weight from 12.3 ppg to 12.6+ ppg.
Monitor well for 5 min. OK. Pull 13 stands slowly to 7150'
inside 5.5" casing. CBU from 7150' No gas cut mud 12.7 ppg.
Monitor well for 5 min. OK. RIH to 7925' CBU @ 7925' No
gas cut mud 12.8 ppg in & 12.7 ppg out. Monitor well for 5
min. OK. POOH to 5.5" shoe. Check for flow well stable. Run
E-logs from 7925' to 7180' Run 3.5" liner and packer.
$84,847 CUM: $2,496,388 ETD: $0 EFC: $3,696,388
MW: 12.7 PV/YP: 37/16 APIWL: 3.6
LOAD HOUSE, STEAM, STRAP & DRI
Continue running 3.5" line on 2-7/8" DP to 5.5" casing shoe
@ 7180' Run liner through open hole from 7180' to 7925'.
Cement casing. CIP @ 1410 hrs. Load 3.5" tubing in pipe
house, steam, strap & drift to 2.86"
$58,897 CUM: $2,555,285 ETD: $0 EFC: $3,755,285
MW: 12.7 PV/YP: 37/16 APIWL: 3.6
DISPLACE MUD W/SEA WATER
Continue running 3.5" tubing w/jewelry. Pressure up to set
packer. Test casing. OK.
$106,402 CUM: $2,661,687 ETD: $0 EFC: $3,861,687
MW: 8.4 PV/YP: 0/ 0 APIWL: 0.0
RELEASE RIG
Pump diesel down 5.5" x 3.5" annulus. "U" tube back to
tubing til balanced for freeze protection to 2100' NU tree
and test pack off 5000 psi. Test tree to 250-5000 psi. OK.
Release rig @ 1500 hrs.
$28,470 CUM: $2,690,157 ETD: $0 EFC: $3,890,157
End of WellSummary for Well:AK8277
ARCO Alaska, Inc.
KUPARUK RIVER UNIT
WELL SERVICE REPORT
K1(1Q-20(W4-6))
WELL JOB SCOPE JOB NUMBER
1Q-20 PERFORATE, PERF SUPPORT 0403962055.6
DATE DAILY WORK UN IT NUMBER
04/05/96 PERFORATE, PERF SUPPORT
DAY OPERATION COMPLETE I SUCCESSFUL I KEY PERSON SUPERVISOR
I YES YES SWS-WARNER GOLDEN
InitialTbgPross IFinalTbgPress IlnitiallnnerAnn IFinallnnorAnn IlnitialOutorAnn IFinalOutorAnn
450 PSI 1420 PSI 200 PSI 200 PSI 200 PSi 200 PSI
DAILY SUMMARY
IPERFORA'I ED A-SANDS F/7610'-7640'. FIRST GUN ONLY FIRED ON ONE SIDE: F/7620'-7640', 2 SPF, UNKNOWN ORIENTATION.
SECOND GUN FIRED AS DESIGNED; FY 7610'-7620, 4 SPF, 180 DEGREE PHASING, 142 DEGREES CCW F/HIGH SIDE.
TIME LOG ENTRY
09:00 MIRU SWS E-LINE & HOT OIL. TGSM: PERFORATING AROUND CONSTRUCTION ACTIVITIES.
10:00
10:45
11:00
12:00
12:15
13:00
13:40
14:15
14:30
15:00
PT LUBRICATOR TO 3000 PSI - GOOD. RIH W/CCL, MPD,20' 2-1/2" HOLLOW CARRIER;4 SPF, 180 DEGREE
PHASING, ORIENTED 142 DEGREES CCW F/HIGH SIDE, BIG HOLE CHARGES.
TIED INTO CBL DAII::D 2/26/96. PERFORATED 7620'-7640' RKB.WHP BEFORE PERFORATING = 1600 PSI, WHP
AFTER PERFORATING = 1670 PSI.
POOH, STUCK AT 7615' RKB. PULLED 1000 PSI ABOVE NORMAL - PULLED FREE.STUCK AT 7510' RKB, BLEED
WHP TO 100 PSI PULLED FREE.AFTER BLEEDING WHP TO 100 PSI, WHP BUILT BACK TO 1600 PSI IN 10 MIN.
WITH GUN IN LUBRICATOR PUMPED 5 BBLS OF DSL DOWN WELL AT 2500 PSI, 0.5 BPM.
GUN #1 DID NOT FIRE ON ONE SIDE. PERF'D INTERVAL F/7620'-7640' RKB, IS ONLY 2 SPF. DO NOT KNOW IF THE
PERFORATIONS ARE ON THE LOW OR HIGH SIDE OF THE HOLE.
RIH W/CCL, WB, MPD, 10'-2-1/2" HOLLOW CARRIER; 4 SPF, 180 DEGREE PHASING, ORIENTED 142 DEGREES
CCW F/HIGH SIDE, BIG HOLE CHARGES.
TIED INTO CBL DA~i-D 2/26/96. PERFORATED 7610'-7620' RKB.WHP BEFORE PERFORATING = 1700 PSI, WHP
AFTER PERFORATING = 1700 PSI.NO PROBLEMS COMING CCH.
WITH GUN IN LUBRICATOR PUMPED 5 BBLS OF DSL DOWN WELL AT 2500 PSI, 0.75 BPM.
GUN #2 FIRED AS DESIGNED.
RDMO SWS E-LINE & HOT OIL.
RECEIVED
-PAG£
~£LL NAME
LOCATION
PROGRAM
ARCO ALASXA~ INC,
IQ-20A "
XUPARUK
ALASXA
" GRI8 CONVERGENCE ANGLE 0,00
.
DATE: 25-0CT-~5
· i-..':~ ' W£L~ HUMBER ' 0
'~'~-~: .... API ~LL NO: 50-029-225~?-01
..' AFE A~8277
.WELL HEAD LOCATION: LAT(~i/-~) 0,00
:,
.
,-AZIMUTH FROM ROTARY TADL£ ?0 ?ARG£T
· ~:-i'~ ~7 -
4120,00
3Z08,??
3~,40
1212,13
549,79
'~ASUR~D DEPTH
TRUE U~RT D~PTH
.-INCLINATION
'AZIMUTH
. ~ATITUD£(NI-S)
=" .' ~ '~P~RTURE(£/-W)
·
D£P(£/-W)
0o14
RECEIVED
AUG 2 3 199G
_
Alaska Oil &.~s Cons, Comm~sS~'°'D '
Anchorage
.u, 2
< 5OR~£Y CALCULATIONS
M******~****w CIF:CULAR ARC
M~ASUR£~
5£P~H
ft
4120,00
4226,59
4315',20
4409,20
4501~0
INT£RUAL ~,~RT!~A~
DEPTH
ft' ft
0,0 3708,12
106,9 3789,40
88,3 38~2,41
94,0 3918,¢8
72,3 3?85,00
ft
0,00
127,96
1~4,51-
STAT!Oh AZ]MU?H
INCLN,
deg ~eg ft
38,40 24,31 1212,13
42,?0 ~,00 . 1278,52
46,10 2,70' 1340,03'
44,20 357,30
~/'-~
ft
.569,4! 13~,56
575,6~ 145~,47
576,27 :520,0~
· ~ ~.-',~ ,
45?3,05
4683,28
4776,17
4867,2~
4761,81
?1,5 4051,74
70,2 4119,16
73,1 4258,~4
92,6 4326,98
321,22
380,86
441o54
502,4? '
564,53 -
42,20 354,3~ 1533,31 569,3~
41,10 35~,17 15~2,'78 563,34
'41,10 352,80 !~53,66 556,42 !744,76
41,79 350,87 17!4,63 547,66
43,57 352,25 1776,66 538,4~ !955,47
5055,43
5147,45
~333,45
5518,17
5607,84
5792,07
6161,40
6343,28
6712,1~
7t~O,O0
93,6 (375,63
92,0 4463,94
186,0 4597,55
184,7 4728,08
89+? 4187,00
184,2 4917,30
183,6. 5049,61
185,7 5185,30
18~,9 ~317,77
~82,2 5448,~6
686,42
~07,60
933,87
_
1125,37
I248,I3
1367,64
1484,99
1606,47
186,6 5583,26 1730,72
I86,6 5718,6! !850,90
92,7 5785,61 .I710,22
~2,7 5))2,79 1~70,30
40,7~ 5882,61 I?~6+80
- PROJECTED TO TD
'65,! 5730,5~
42,15 345,79 1839,1~
41,98 343,86 1895;65
44,40 340+?0 2019,93
47,4! 343,69 2146+30
47,00 345,I0 2209,67
44,72 346,8~ 2337,91
43,I2 342,59 2460,76
43,00 338,80 25)0,37
43o5! 342,21 2697,82
_
341,55
337,36
3~!,87
43,56
43,48
43,90
43,21
42,66
42,66
344,07
24.01
".3,25
'.-I ql
18,60
!7 ;71
(I,1
de~,'
lOOft
0,00
10,21
6,!7
'y,~.~
2,11
1,23
1,56
2,17
510,25 i~:~.,'::~ ~.:.~ !,42
471,6:S 2074,,:,~ [',14 1,69
431,41 218~,~2 !1,87 1.~6
413,71 224~,~6 ~0,60 1,~4
5,61
4,66
381,67 2365,.56
306,33 257,~,J?
264,77 ~710 /.
229,$2 2B28,73
2"7'43,73
2064,02
:,i.)3,40
3183,52 102,~"'
1210,0~ ~4,7x
32)2,47 82)65
1,42
1,84
1,40
1,31
1.,42
2750,~7 '2,76 1,60
32!I.~5 1,69 3,93
9253,54 1,46 0,04
RECEIVED
AUG 2 3 199G
GeoQuest
500 W. International Airport Road
Anchorage, AK 99518-1199
ATTN: Sherrie
NO. 10093
Company:
3/26/96
Alaska Oil & Gas Cons Comm
Attn: Larry Grant
3001 Porcupine Drive
Anchorage, AK 99501
Field: Kuparuk (Open Hole)
LIS
/,~, _~.~. ~-~ .~?Well Job# Log Description Date BL RF Sepia DIR MWD Tape
1Q-20A 96077 PHASOR DUALINDUCTION-GR 960202 I c.~ I "~ I -
SIGNED-
Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you.
GeoQuest
500 w. International Airport Road
Anchorage, AK 99518-1199
ATTN: Sherrie
NO. 10076
Company:
3/1 9/96
Alaska Oil & Gas Cons Comm
Attn: Larry Grant
3001 Porcupine Drive
Anchorage, AK 99501
Field: Kuparuk (Open Hole)
--~'~ LIS
~ ..~.~- f II Job# Log Description Date BL RF Sepia DIR MWD Tape
1Q-20A 96078 SLIMIGR 951 025 I I 1
SIGNED'
Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you.
DATE:
ARCO Alaska, Inc.
Date' April 3, 1996
Transmittal #: 9357
RETURN TO:
ARCO Alaska, inc.
Attn.: Julie Nash
Kuparuk Operations File Clerk
ATe-1119 B
P.O. Box 100360
Anchorage, AK 99510-0360
Transmitted below are the following open hole items. Please acknowledge
receipt and return one signed copy of this transmittal.
q~-l;3 !Q-21
~£-. t~ 1Q-22A
,, -,./3H-28A
d &- ~-~'"',,3 H_28A
~ F'- Lf'~ 1Q-20A
Acknowledged'
Dual Induction-SFL 02/29/96
Phaser Dual INduction-GR 02/17/96
CDR 02/17/96
CDN 02/27/96
Pha~ctio~~ 02/02/96Date:
9434-10412
8342-95O4
50-103-20236-01
50-103-20236-01
6950-7915
DISTRIBUTION'
Mr. Vernon E. Pringle Jr.
DeGIoyler and MacNaughton
One Energy Square
Dallas. TX 75206
Sharon AIIsup-Drake
DS Development
ATe - 1205
Clifton Posey
Geology
ATe - 1251
ChapmanZuspan
,,~c~- Wells Group
',i ,,_.,, i \
NSK 69
Larry Grant
AOGCC
3001 Porcupine Drive
Anchorage, AK 99501
GeoQuest
500 W. International Airport Road
Anchorage, AK 99518-1199
ATTN: Sherrie
NO. 10097
Company:
3~29/96
Alaska Oil & Gas Cons Corem
Attn: Larry Grant
3001 Porcupine Drive
Anchorage, AK 99501
Field: Kuparuk (Open Hole)
LIS
Well Job # Log Description Date BL RF Sepia DIR MWD Tape
1 Q-21 96085 ;DUAL INDUCTION-SFL 960229 I I 1
, ,
1-6h,2~A I~-~ 96074 PHASOR DUALINDUCTION-GR 960217 I I .-~--
3H-28A 96086 CDR/CDN 960227 1 1 1
.......
SIGNED: ..... DATE:
Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you.
'1,996
()il & Gas Cons,
,Anchora?]e
CON~ER¥~TION COMMISSION
March 18, 1996
William S. Is~cson
Drilling Engineer
Kupa_,,mk Drill Site Development
ARCO Alaska, Inc.
P.O. Box 100360
Anchorage, AK 99510-0360
TONY KNOWLE$o GOVERNOi~
3001 PORCUPINE DRIVE
ANCHORAGE, ALASKA 99501-3192
PHONE: (907) 279-1433
FAX: (907) 276-7542
Re:
Requested annular disposal of cement washdown water from coiled tubing cement
squeezes
Dear Mr. Isaacson:
The Commission has received your request for autho~on for disposal of cement washdown
water from cement squeeze operations in the annuli of wells currently being utilized by Parker Rig
#245. The washdown water would be generated by cement squeeze operations on the following
wells: 1Q-02A, 1Q-20A, 1Q-22, and 2M-09. Disposal would take place into the annuli of wells
being used by Parker Rig #245 on drill sites IF, 2A, or 2M, for which annular disposal has already
been authorized.
ARCO Alaska, Inc. (ARCO) must demonstrate that complying with the limitahon of disposal
through the annular space of a well on the same pad is imprudent. There are annul/available for
disposal on the lQ pad. The cement squeeze operations will each generate an estimated 30-50 bbls
of water and 1 bbl of cement. Grind and inject facilities are not required for disposal of the cement
washdown water generated during these squeeze operations.
Pending submittal of information that it is imprudent not to do so, the Commission denies the
request by ARCO Alaska, Inc. to dispose of cement washdown water from the 1Q-02A, 1Q-20A
and 1 Q-22 wells in the annuli of wells not located on 1Q pad. The cement washdown water from
these wells may be either injected into annuli on the lQ pad, or disposed of in a Class I well.
The Commission also suggests the cement washdown water from the 2M-09 well be temporarily
stored and disposed ofwhen Parker Rig #245 is conducting annular injection operations on the 2M
pad. As an alternative to storage, the cement washdown water from the 2M-09 well may also be
disposed of in a Class I well.
David ~J_o~0n~
Chairman
I. David Norton, P.E.
Commissioner
/~,,.,.~.. .0. .~.~ ,~-.
tTuckerman Babcock
Commissioner
ARCO Alaska, Inc.
Post Office Box 100360
Anch=rage, Ala~ka 99S10-0,360
Telel~hone 907 276 1215
?-
-"'~"' David W. ,.,h
d,.,,,ns,on, Chairman
Al~ka Oil And Gas Conservation Commission
3001 Porcupine Drive
Anchorage, AK 99501
(90~ 27g-1433
(907) 276-7542 (fax)
Re: Annular Disposal of 'Drilling Wastes' for
Cement Squeeze Operations on KRU Wells 1Q-02A, 1Q-20A, 1Q-22, and 2~-09
Gentlemen:
ARCO hereby requests a waiver to the AOGCC Regulations coverfng Annular Disposal of
Drilling Waste recently adopted by the Commission on January 31, 1996. This waiver is
requested to cover ARCO's cement squeeze operations on wells 1Q-02A, 1Q-20A, 1Q-22, and
2M-09.
Each of the lQ wells were recently ddlled and completed. Due to difficulties in the cementing
portion of the ddlling operations, cement squeezes will be necessan/prior to bringing the wells on
service. Well 2M-09 is currently planned for sidetrack operations and a cement squeeze is
necessary in order tO plug and abandon the existing wellbore.
The waiver being requested is to Section (d), Part (4) of 20 AAC 25.080., which limits the annular
disposal of drilling waste, to drilling operations on the same ddll pad as the annulus being injected
into. ARCO requests the AOGCC grant permission to allow cement wash-water generated from
cement squeeze operations on the aforementioned wells, be injected into the annulus being used
at that lime by Parker ~45 on drill site 1F, 2A, or 2M.
We appreciate your consideration of this request. If you have any questions or require any
additional information on this matter, please contact me at 263-4622.
Sincerely,
William S. Isaacson
Ddlling Engineer
Kuparuk Drill Site Development
ARCO A~t.'~Jca, Inc. is a Snbaidiary of AQamid~,ld~fl~lc~on~p~ny
ARCO Alaska, Inc.
.FACSIMILE
, _TBANSMISSION
Iate: ~/I1~ / (~ C Time:
umber of Pages (C, over +):
From:
Phone:
Location: ,..
To: ~'J ~ ~,~_o ~
Location: A 0(.- (_ ¢_
Copies To:
Phone #:
Kuparuk Drill Site Development,
P. O. BOX 100360
ANCHORAGE, AK 99510-0360
FAX # 907 265-622-4
ATO-12O9
Subject:
Comments:
...
,
..
ARCO Alaska, Inc.
Post Office Box 100360
Anchorage, Alaska 99510-0360 ~ ,
Telephone 907-276-1215
November 6, 1995
Mr. Bob Crandall
Alaska Oil&Gas Conservation Commission
3001 Porcupine Dr.
Anchorage, AK 99501
Subject'
Waiver of Continuous Directional Surveys on KRU lQ Pad DrilI-OutsC\~'-/
Dear Mr. Crandall:
As per our telephone conversation of October 27, 1995, the following letter is to
_~onfirm the waiver of continuous directional surveys on KRU wells 1Q-20A, 21, and
22. Each of these wells was originally planned to be drilled to total depth and 5-1/2"
casing run through the Kuparuk. Unexpectedly, the 5-1/2" casing had to be set
above the Kuparuk due to extreme fluid loss in shallow formations or high pressures
encountered within the Kuparuk interval.
Currently, each of the wells has continuous directional surveys from the surface to
within 190' TVD of the top of the Kuparuk Formation. Standard practices in the
Kuparuk field are to drop magnetic single shot surveys at TD when the Kuparuk is
top set or when the MWD is left out of the drilling assembly used to TD the well. Due
to the reduced size of the hole to be drilled-out below the 5-1/2" casing, equipment
needed to acquire a single shot survey at TD is currently not available, or what is
available substantially reduces the dependability of the drill string bottom hole
assembly. As well, standard cased hole gyro survey tools can not be run due to
internal diameter constraints of the 3-1/2" liner to be run in each of the lQ drill-outs.
Plans are to drill-out each well with a drilling assembly designed to hold the final
angle at which the 5-1/2" casing was set and drill to the predicted TD. Future wells
to be drilled-out be!ow 5-!/2" casing wi!! require the acquisition of the appropriate
materials to enable single shot surveys to be taken at TD.
Included with this letter is a plot of actual directional data from drilling operations to
date with the estimated 3-1/2" liner setting depth for each drill-out.
Thank you, and please feel free to call if you haVe any questions or comments.
can be reached at 263-4622.
Sincerely,
William S. Isaacson
Drilling Engineer
;Crea~:l by' :
Dote p~ottecl : 27-0ct-95
Plot Re~e~enee L~ 20A Ve~,~on ~,1.
Coordin~e~ are in teat referem:e ~lot II20.
True Vertical Depths are refem~:e RKI~ (Perker 11245).
0 3300~
°
36O0
"
(- 4-2004
~ ,~5oo..I
~_
I s7ooi
6000J
7 ,5/8 CASING
Kick off Point
ARCO ALASKA,
Inc.
Field : Kuporuk RiYer Unif Location : North Slope, Alaska
Scale I : 75.00
150 0
I I I I I I I I I I I I I I I I I
Easf -->
150 300 450 600 750 900 1050
3900
_
_5750
.3600
d of Build
1Q-20(C2) 29-5ep-95
66001~ I I I I I I I I ! I i I! II II I I II
900 1200 1500 18~ 21 O0 2400 2700 5000 ~3~ 36~ 5900
_3¢5O
_3300
--
_3150
_3000
,
_2850
_2700
_2550
--
_2400
-
_2250
_2100
_1950
_1800
_
1650
_1500
_1350
--
_ 1200 "
_ C~
1050 o
Scale 1 : 150.00
Vertical Section on 0.14 azimuth with reference 0.00 N, 0.00 E from slot 1~20
ARCO ALASKA, Inc.
Field : Kuparuk River Unit Location
Nor"ih Slope, Alaska
o -]
..
500
Kick off Point
End of
East -->
500 0 500 1000 1500 2000 2500 3000 3500
I I [ I I I I I I I [ I I I ~ ~ -
7 5/8 Casln~
1Q-21(D) Rvsd 22-Auq-95 ~
I
End of
70001 I I I I I I I I I I I I I I I I II I I I I I I I I I I I I I
0 500 1000 1500 2000 2500 30oo 3500 40oo 450o 5000 55oo eooo 6500 7000 7500
Scale 1 · 250.00
Vertical Section on 23.69 azimuth with reference 0.00 N, 0.00 E from stat #21
_7000
_6500
_4500
_3500
_2500
_2000
_1500
_1ooo
_
o ID
&O~' wO
!Creot.~l by : jones
:Dote plot[ecl : i,,1,--Oct--g..%
Plot Reference ~a 2.2 Ve~/o~
;Coorclin~te~ are in feet reference alot ~22.
jTrueVertical Depths are referet~e
(Pa~er
1~2¢5).
----
o
400
800 1
_
1200_
.-I---
k'~. 2000_
(1) -
~ 2400~
~-~ 3200
3600
_
4000_
4400_
_
4800_
-
5200_
Kick off Point
End of
ARCO ALASKA,
Field : Kuparuk River Unit Location : North Slope, Alaska
sco,,,:=.oo Easf -->
500 0 500 1000 1500 2000 2500 3000 .3500 4000 4500
L_ I I I I I I I I I I II I i II I I II J450o
-
4000
10-22{K) Rvsd 25-Seo-g5 ~
_3500
7 5/8 Casinq
_5000
_2500
_2000
-
_~soo
_1000
56001
6000t
64004
End of
GlOO' 'rvO
7200J I I I I I I I I I I I II II II I I II II II II I I I I I
0 400 800 1200 1600 2000 2400 2800 .3200 36013 4000 4400 4800 5200 5600 6000
Scale t · 200.00
Vertical Section on 46.57 azimuth with reference 0.00 N, 0.00 E from slot #22
ALASKA OIL AND GAS
CONSERVATION COMMISSION
TONY KNOWLE$, GOVERNOR
3001 PORCUPINE DRIVE
ANCHORAGE, ALASKA 99501-3192
PHONE: (907) 279-1433
FAX: (907) 276-7542
October 11, 1995
Mike Zanghi, Drill Site Develop. Supv.
ARCO Alaska Inc.
P O Box 100360
Anchorage, AK 99510-0360
Re:
Company
Permit #
Surf Loc
Btmhole Loc
Kuparuk River Unit 1Q-20A ·
ARCO Alaska Inc
95-156
1090'FNL, 1820'FEL, Sec 26, T12N, R09E, UM
2568'FSL, 1852'FEL, Sec 23, T12N, R09E, UM
Dear Mr. Zanghi:
Enclosed is the approved application for permit to re-drill the above referenced well.
The permit to re-drill does not exempt you from obtaining additional permits required by law
from other governmental agencies, and does not authorize conducting re-drilling operations
until all other required permitting determinations are made.
Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035.
Sufficient notice (approximately 24 hours) must be given to allow a representative of the
Commission to witness a test of BOPE installed prior to drilling a new hole. Notice may be given
on the North Slope pager at 659-3607.
Chairman
~ _ _
BY ORDER OF THE MISSION
jolencl
c: Dept of Fish & Game, Habitat Section - w/o encl
Dept of Environmental Conservation - w/o encl
STATE OF ALASKA
ALAS, ~ OIL AND GAS CONSERVATION COMMISSi,~,,,I
PERMIT TO DRILL
20 AAC 25.005
la. Type of Work Drill E] Redrill E] lb Type of Well Exploratory E] Stratigraphic Test [] Development Oil X
Re-Entry X Deepen [] Service [~ Development Gas r~ Single Zone X Multiple Zone []
2. Name of Operator 5. Datum Elevation (DF or KB) 1 0. Field and Pool
ARCO Alaska, Inc. RKB 41', Pad 54' feet Kuparuk River Field
3. Address 6. Property Designation Kuparuk River Oil Pool
P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25634, ALK 2567
4. Location of well at surface 7. Unit or property Name 1 1, Type Bond (see 20 AAC 25.025)
1090' FNL, 1820' FEL, Sec. 26, T12N, R9E, UM Kuparuk River Unit Statewide
At top of productive interval (@ TARGET) 8. Well number Number
2446' FSL, 1811' FEL, Sec. 23, T12N, R9E, UM 1Q-20A #U-630610
At total depth 9. Approximate spud date Amount
2568' FSL, 1852' FEL, Sec. 23, T12N, R9E, UM 1 0/1 9/95 $200,000
12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15, Proposed depth (MD and TVD)
property line 1Q-15 (@ KOP) 7906' MD
2446 ~ TD feet 891.6' ~ 4220' MD feet 2560 6487' TVD feet
16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2))
Kickoff depth 4220' feet Maximum hole angle 45.1° Maximum surface 2184 psig At total depth (TVD) 3870 psig
18. Casing program Setting Depth
size Specifications Top Bottom Quantity of cement
Hole Casing Weight Grade Coupling Length MD TVD MD TVD /include stage dataI
24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' _+200 CF
9.875" 7.625" 29.7# L-80 LTC 4058' 41' 41' 4099' 3690' 630 Sx Arcticset III &
HF-ERW 320 Sx Class G
6.75" 5.5" 15.5# L-80 LTCMOE 7031' 41' 41' 7172' 5926' 120 Sx ClassG
HF-ERW Top 1000' above shoe
4.75" 3.5" 9.3# L-80 EUE8rdM 1034' 6872' 5708' 7906' 6487' 70SxClassG
Top ~ top of liner
19. To be completed for Redrill, Re-entry, and Deepen Operations.
Present well condition summary
Total depth: measured 7353 feet Plugs (measured) 6705' MD Cement plug, tagged
true vertical 6259 feet on 9/15/95
Effective depth: measured 3840 feet Junk (measured) 3908' MD Cement retainer with
true vertical 3490 feet 92 bbl cement pumped below, set on 9/16/95
Casing Length Size Cemented Measured depth True Vertical depth
Structural
Conductor 8 0' 1 6" _+200 CF 1 21 ' 1 21'
Surface 4058' 7.625" 630 Sx AS III & 320[~S~01 ~' ~; ~' ~.z~)9' 3690'
Intermediate ~ ~-. -~ L~ l! '~
Production
Liner0CT 0 ::; i995
Perforation depth: measured
true vertical Alaska. 0il & Gas Cons, C0nlmissi0ri
20. Attachments Filing fee X Property plat r-] BOP Sketch X Di[,~J~'(J~"'S~h ~ Drilling program X
Drilling fluid program X Time vs depth plot ~ Refraction analysis [] Seabed report [~ 20 AAC 25.050 requirements X
21. I hereby certify/jhat the foreji~oing is true and correct to the best of my knowledge
Signed I['J{'~'//-~_'/"~ ! Title Drill Site Develop. Supv. Date ('~'"~"-~"~"~"'"'
Commission Use Only
Permit Number '-rAPlnumber IApprovaldate / ! I See cover letter for
.~-~'""/'~'~ ¢-~* J50- ~ ~---'~-- ;P_._ 2... ,~' ~ - 0 ,/ /0/~'//~.¢~'" other recluirements
Conditions of approval Samples required [--~ Yes .~ No Mud Icg required [--~ Yes ~! No
Hydrogen sulfide measures J~ Yes E] No Dire~l survey required J~ Yes [] No
Required working pressure for BOP• E] 2M ~ 3M~~i E] 1OM E] 15M
Other:
Original Signed By
David W. Johnstonby order of /. /_
Approved by Commissioner the commission Date /C:>//~../~ ,~,~"
Form 10-401 Rev. 7-24-89
Submit in triplicate
GENERAL DRILUNG PROCEDURE
KUPARUK RIVER FIELD
1Q-20A SIDETRACK
,
.
,
.
.
.
,
.
.
10.
11.
12.
13.
14.
15.
16.
17.
18.
Move in and rig up Parker #245 to topset the Kuparuk formation.
Install and test BOPE to 3000 psi.
RIH, tag and drill up EZSV cement retainer and cement to 4000' MD. Ensure hole is
clean of junk from retainer.
PU sidetrack assembly, RIH and sidetrack below existing surface casing at 4,099'
MD. Estimated KOP is 4,220' MD. Establish sidetrack from original hole.
Note: Original shoe tested at 12.5 ppg EMW on-9/7/95.
PU drilling assembly, RIH and drill 6-3/4" hole to total depth (7,172') according to
directional plan.
Run and cement 5-1/2" casing string.
Note; If significant hydrocarbon zones are present above the Kuparuk, sufficient
cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. There
is one known significant hydrocarbon zone found in 1Q-20 original wellbore logs at
4,007' TVD. It is expected in 1Q-20A sidetrack as well. Cement will be down
squeezed in the annular space between the surface and production casing after the
primary cement job is completed. (Distance between top of hydrocarbons and surface
shoe will be ___317' TVD.)
ND BOPE. NU tubinghead and master valve.
Secure well and release rig.
Move in and rig up Nordic #1.
Install and test BOPE. Pressure test 5-1/2" casing to 3500 psi.
Drill out cement and 10' of new hole. Perform leak off test to 14.0 ppg EMW.
Drill 4-3/4" hole to total depth (7,906') according to directional plan.
Run open hole evaluation logs as needed.
Run and cement 3-1/2" liner. Set liner hanger and packer with SBE.
Run completion assembly. Pressure test SBE/XO.
ND BOPE and install production tree.
Shut in and secure well.
Clean location and release rig in preparation for perforating...
DRILLING FLUID PROGRAM
Well 1Q-20A
'[~ensity
PV
YP
Viscosity
Initial Gel
10 Minute Gel
APl Filtrate
pH
% Solids
Sidetrack to
Topset Kuparuk
(Parker #245)
8.4-9.6
5-15
5-8
30-40
2-4
4-8
8-10
9.5-10
4-7%
Drill out
to TD
INordic #1)
12.5
10-18
8-12
35-50
2-4
4-8
4-5 through Kuparuk
9.5-10
<12%
Drilling Fit~i~l System (Parker #245)
Tandem Brandt Shale Shakers
Triple Derrick Shale Shakers
Solids Processing System to-minimize drilling waste
Mud Cleaner, Centrifuges, Degasser
Pit Level Indicator (Visual and Audio Alarm)
Trip Tank
Fluid Flow Sensor
Fluid Agitators
Drilling Fluid System (Nordic #1)
Baroid Model 2 Tandem Shale Shaker
Swaco 6-Cone Desilter
Triflow Vacuum Degasser, Poor Boy Degasser
Pit Level Indicator (Visual and Audio Alarm)
Trip Tank
Fluid Flow Sensor
Fluid Agitators
Notes-
Drilling fluid practices will be in accordance with the appropriate regulations stated in 20
AAC 25.033.
Maximum anticipated surface pressure for Parker #245 is calculated using a surface casing
leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ff. This shows that formation
breakdown would occur before a surface pressure of 2,184 psi could be reached.
Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi.
Maximum anticipated surface pressure for Nordic #1 is calculated using an intermediate
casing leak-off of 14.5 ppg EMW and a seawater gradient of 0.45 psi/ff. This shows that
formation breakdown would occur before a surface pressure of 1,802 psi could be reached.
Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi.
The nearest existing well to 1Q-20A sidetrack is 1Q-15. As designed, the minimum distance
between the two wells would be 891.6' @ 4220' MD (estimated KOP).
Annular Pumpin~l Activities:
Incidental fluids developed from ddlling operations will be hauled to the nearest permitted
disposal well or will be pumped down the surface/production casing annulus of an existing
well. That annulus will be left with a non-freezing fluid during any extended shut down (> 4
hr) in pumping operations. The 1Q-20A surface/production casing annulus will be filled
with diesel after setting the 5-1/2" intermediate casing and prior to Parker #245 moving off of
the well. A significant hydrocarbon zone is expected +317' TVD below the surface shoe. If
seen as expected, the annulus will later be sealed with cement from the surface shoe to the
base of the permafrost, with Arctic pack fluid or diesel from the base of the permafrost to the
surface. Alternatively, if the hydrocarbons are far below the shoe then sufficient cement
volume will be pumped dudng the production cement job to cover the formation.
It is requested that 1Q-20A be permitted for annular pumping occurring as a result of the
ddlling project on DS lQ, per proposed regulations 20 AAC 25.005 (k). Any zones
containing significant hydrocarbons will be isolated ~rior to initiating any annular pumping.
There will be no USDW's open below the shoe or potable/industrial water wells within one
mile of the receiving zone. Surface casing is set in the Creatceous shales below the base
of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are
known to provide vertical barders to fluid flow. Generally, the surface casing shoe is set
200' vertical below the base of the-West Sak into the heart of the shales.
Drilling Area Risks:
Risks in the 1Q-20A are minimal due to the setting of the intermediate casing stdng above
the Kuparuk. The original 1Q-20 well saw well control problems resulting in a final mud
weight of 12.5 ppg. Afterwards severe lost circulation occurred as a result of the high mud
weight. It may be possible to see lost circulation and/or well control problems below the
intermediate casing. (Low mud weights will be used to drill to the intermediate casing point
and so lost circulation problems will be minimized in that interval.)
Lost circulation in and above the Kuparuk will be addressed with lost circulation matedai
(LCM) and reduced circulating rates as needed. Data from the odginal drilling attempt on
1Q-20 show that a mud weight of 12.5 ppg will provide sufficient overpressure to safely drill,
tdp pipe, and cement. The 7-5/8" surface casing shoe was tested to an equivalent mud
weight of 12.5 ppg on 09/07/95. The 5-1/2" casing shoe will be tested to an equivalent mud
weight of 14.0 ppg upon drilling out of the intermediate casing.
ARCO ALASKA,
Structure : Pod lQ
Well : 20A
Field : Kuporuk River Unit Location : North Slope, Alaska
:,oo.oo Easf
200 0 200 400 600 800 1000 1200 1400
iCreated by : jones For: D
iOote plotted : 4--0ct--95
iPIot Reference is 20~ Version
iCoordinotes ora in feet r~l'erence slot ~20.
!True Vertical Oepth ar* re erenc RKB (Porker
TD LOCATION:
2568' FSL, 1852' FEL
SEC. 23, T12N, R9E
C~ 5600_
0
_
..
3800~
o 4000_
4200_
(---)4600_
_
4800]
~_ 5000_
(1) _
5200_
N .14 DEG E
3536' {TO TARGET)
***PLANE OF PROPOSAL***
.
· CASING
KOP/SIDETRACK PT ]¥D=3787 TMD=4220 DEP=1270
38.18 .3 BEG / 100' OLS
38.38
3879 T/ COLVILLE TVD=4007 TMD=4501 DEP=1438
i - 5 1/2 Casing Pt
TARGET - 8/ Kuporuk
Top Unit A
Unit B
'ap Unit C
p Kuparuk (EOD)
K-1
2/:J°P
olville
ille Red
39
40.16
41.11
42.21
43.46 F-OC TVD=4493 TMD=5148 DEP=1858
]~ LLE RED '1¥D=4774 TMD=5546 DEP=2125
" Top
TARGET LOCATION:
2446' FSL, 1811' FEL
SEC. 23, T12N, R9E
TARGET
TVD=6334
TMD=7706
0EP=3536
NORTH 3536
EAST 9
~ 5400_
I-- -
5600_
I
--
I 5800_
V
6000t
6200_
6600
4OOO
_
_3800
_
_3600
_3400
_
_3200
_
_3000
_ A
_2800 J
- I
_2600
- Z
_2400
_2200
_2000
_ 1800
MAXIMUM ANGLE ,'-'~,~
45.11 DEG
,~,,. ..... "~- --' .] :: .j. ?:.-: .. _12oo o
B/ GO~LLE WD=5539 TMD=6630 "C U ..._<::..,:~
HRZ Midpoint WD=5736 TMD=6909 0EP=3039
BEB[N ~GLE DROP ~=5788 TMD=6983 DEP=3088
DROP 2 DE6 / 100
K--1 WD=5887 TMD~O DEP~178~ ~'42~ '
T/ KUPARUK (EOD) WD=5976 T~=7238 DEP=3252~
T/ UNIT C WD=6034
T/ UNIT B WD=6102 mD=7403 DEP=3352
T/ UNIT A TVD~' TMD=T549 DEP=34~ X ~ TARGET ANGLE
TARGET - B/ KUPARUK TVD=faa4 ~D=~06
TD -
LIN~
_1600
--
_ 1400 --'
..
--
~ , , ~ , ~ ~ , , , , ~ ~ t , ~ ~ ~ , , , , ~ , ~ ~ , , ,
1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 5000 3200 3400 5600 5800
Scale 1 ' 100.00
Vertical Section on 0.14 azimuth with reference 0.00 N, 0.00 E from slot #20
ARCO ALASKA, Inc.
ICr~ot~ b~ : jo~ For: I)?DrRASIti I Sfrucfure : Pod 10 Well : 20A
iOot. ~.o..~: ~-o:t-gs ] i Field : Kuparuk River Unit Location : North Slope. Alaska
iPIot Reference is 20A Version ~D. I
.
iCoordinatee ore in feet reference slot 1~20.
iTrue Verl. icol Depths are refereng~ RKB (Porker
3000_
2900_
2800_
2700_
2600_
2500_
2300 _
2200_
21 O0t
2ooo~
--
1900_
800_
1700_
1600_
1500_
c~ 14oo_
--
..
~ 1500_
co 1200
East
300 200 1 O0 0 1 O0 200 500 400 500 600 700 800 900 1000 11 O0 ! 200 1300
, I I I I I I I I I I I I I I I I I I I
5500
~5300
5100
3700
490{
'/
$900
5700
5500
~1oo
4500
igo0
5700
5500
4100
4100
3900 5900
45O0
::i W~!.i. :- '-.'U;:L"~j!,~,-..!qF,
.... ', ~'U! ;!74.
300 200 1 O0 0 1 O0 200 300 400 500 600 700 800 go0 1000 11 O0 1200 1300
Scale 1 ' .50.00
East -->
_$000
_
_2900
_2800
_
_2700
A
I
I
ooZ
O
18O0
1400 o
300 - -
0
0
I
8.
9.
10.
11.
12.
13.
14.
13 5/8" 5000 PS '3OP STACK
ACCUM U LATOR CAPACITY TEST
1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL
WITH HYDRAULIC FLUID.
2_ ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH
1500 PSI DOWNSTREAM OF THE REGULATOR.
3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND
RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS
ARE CLOSED WITH CHARGING PUMP OFF.
4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER UMIT
IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING
PRESSURE.
BOP STACK TEST
FILL BOP STACK AND MANIFOLD WITH WATER.
CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED.
PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT
IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD.
CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES
ON THE MANIFOLD. ALL OTHERS OPEN.
TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES.
INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES.
BLEED TO ZERO PSI.
OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE
VALVES.
CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE lINES.
TEST TO 250 PSI AND 30(X) PSI AS IN STEP 4.
C(:X~INUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI
LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST
ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE.
OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM
RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES.
OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE.
CLOSE BUND RAMS AND TEST TO 3000 PSI FOR 3 MINUTES. BLEED TO
ZERO PSI.
OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD
AND lINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE
DRIllING POSITION.
TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES.
TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP.
RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM.
SIGN AND SEND TO DRILLING SUPERVISOR.
PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY
OPERATE BOPE DAILY.
VBRS WILL ACCOMODATE 3-1/2" TO 5-1/2" PIPE ODS.
1. 16" - 2000 PSI STARTING HEAD
2_ 11" - 3000 PSI CASING HEAD
3. 11" - 3000 PSI X 1:~5/8" - 5000 PSI
SPACER SPOOL
4. 13-5/8" - 5000 PSI PIPE RAMS
5. 13-5/8"-5000 PSI DRLG SPOOLW/
CHOKE AND KILL LINES
6. 1;~5/8" - 5000 PSI DOUBLE RAM W/
PIPE RAMS ON TOP, BLIND RAMS ON BTM
7. 13~5/8" - ~:)O0 PSI ANNULAR
7-1/16" 5000 PSI BOP STACK
MUD
CROSS
4
I
PIPE RA~ >
5 BLIND RAM
PIPE RAM >
I
(21
ACCUM ULAT(:;)R CAPACITY TEST
1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL
WITH HYDRAULIC FLUID.
2. ASSURE THAT ACCUMULATOR PRESSURE tS 3000 PSI WITH
1500 PSI DOVVNSTREAM OF THE REGULATOR.
3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND
RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS
ARE CLOSED WITH CHARGING PUMP OFF.
4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT
IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING
PRESSURE.
BOp STACK TEST
1. FILL BOP STACK AND MANIFOLD WITH WATER
2_ CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED.
PREDETERMINE DEPTH THATTEST PLUG WILL SEAT AND SEAT
IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD.
3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES
ON THE MANIFOLD. ALL OTHERS OPEN.
4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 5 MINUTES.
INCREASE PRESSURE TO 3500 PSI AND HOLD FOR 5 MINUTES.
BLEED TO ZERO PSI.
5. OPEN ANNULAR PREVENTOR AND INSIDE MANUAL KILL AND CHOKE LINE
VALVES. CLOSE TOP PIPE RAMS, HCR VALVE ON CHOKE LINE, AND
OUTSIDE MANUAL VALVE ON KILL UNE.
6. TEST TO 250 PSI AND 3500 PSI AS IN STEP 4.
7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW
AND 3500 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY
CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE.
8. OPEN TOP PIPE RAMS AND CLOSE BO3-FOM PIPE RAMS. TEST BO3-FOM
RAMS TO 250 PSI AND 3500 PSI.
9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE.
10. CLOSE BUND RAMS AND TEST TO 3500 PSI FOR 5 MINUTES. BLEED TO
ZERO PSI.
11. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD
AND UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE
DRILLING POSITION.
12. TEST STANDPIPE VALVES TO 3500 PSI.
13. TEST KELLY COCKS AND INSIDE BOP TO 3500 PSI WITH KOOMEY PUMP.
14. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM.
SIGN AND SEND TO DRILLING SUPERVISOR.
15. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY
OPERATE BOPE DAILY.
1.11" - 3000 PSI CASING HEAD
2. 11" - 3000 PSI x 7-1/16" 5000 PSI TUBING HEAD
3.7-1/16" - 5000PSI SINGLE GATE W/PIPE RAMS
4. 7-1/16"- 5000 PSI DRLG SPOOL W/CHOKE & KILL LINES
5.7-1/16" - 5000 PSI SINGLE GATE W/ BLIND RAMS
6. 7-1/16" - 5000 PSI SINGLE GATE W/PIPE RAMS
7.7-1/16" - 5000 PSI ANNULAR PREVENTER
AL _ ,A OIL AND GI~ CONSERVATION COMI~i' ~
APPLICATION FOR SUNDRY APPROVALS
1. Type of Request: Abandon _~ Suspend
Alter casing _ Repair well _
Change approved program _
Operation Shutdown_ Re-enter suspended well_
Plugging _ Time extension Stimulate
Pull tubing _ Variance _ Perforate _ 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 _
Sen4ce
4. Location of well at surface
1090' FNL, 1820' FEL, Sec. 26, T12N, RDE, UM
At top of productive interval
At effective depth
UUi-'L/L,/RI E
At total depth
1964' FSL, 583' FEL, Sec. 23, T12N, R9E, UM
12. Present well condition summary
Total Depth: measured
true vertical
7353' feet
6259' feet
6. Datum elevation (DF or KB)
RKB 41' Pad level 94'
7. Unit or Property name
Kuparuk River Unit
feet
8. Well number
1Q-20
9. Permit number
95-131
10. APl number
50-029-22589
11. Field/Pool Kuparuk River Field
Kuparuk River Oil Pool
Effective depth: measured
true vertical
7353' feet
6259' feet
Casing
Structural
Conductor
Surface
Intermediate
Production
Liner
Perforation depth:
Length
80'
4058'
measured
true vertical
Size
16"
7-5/8"
Tubing (size, grade, and measured depth
Packers and SSSV (type and measured depth)
Cemented
250 Sx AS I
630 sx AS !il &
320 sx Class G
Measured depth True vertical depth
121' 121'
4099' 3690'
°EP ~, 4 1995
Ata~ u~l & Gas Cons. C0mmiss[0n
~ ~ch0rage.
13. Attachments Description summary of proposal _ Detailed operation program ~ BOP sketch _
14. Estimated date for commencing operation ! 15. Status of well classification as:
9/13/95 I Oil * Gas __ Suspended _
16. If proposal was verbally approved
Name of approver Blair Wondzell Date approved 9/13/9 Service
7. I hereby certify jhat the foregoing is true and correct to the best of my knowledge.
Sicjned -' Title Drill Site Dev Sul3v ,,' Date~-~~~~ I
FOR COMMISSION USE ONLY ' -
Conditions of approval: No~ommission so representative may witness IApproval N..o. . . . I
__ Location clearance __ ' ~ roved Cop]} ~/._A-'"'/~
Plug integrity .~ BOP Test Subsequent form require ~10-//-~'7,D~ PD,.,furne4'~ '
Mechanical Integrity Test _
Jriginal Signed By - ~'",' ")'- ~-
~vid W. Johnston (~ommissioner""////"~/~-
/,..
/..
Date
//
Approved by the order of the Commission //~L-"~
Form 10-403 Rev 06/15/88 SUBMIT IN YR'IPLI'CATE
WELL PERMIT CHECKLIST
COMPANY /~f~_- ~3
c .Ass /--O, ,,/
WELL NAME
GEOL AREA
ADMINISTRATION
ENGINEERING
APPR DATE;
1. Permit fee attached .................. N
2. Lease number appropriate ............... N
3. Unique well name and number .............. N
4. Well located in a defined pool ............. N
5. Well located proper distance from drlg unit boundary.. N
6. Well located proper distance from other wells ..... N
' 7. Sufficient acreage available in drilling unit ..... N
8. If deviated, is wellbore plat included ........ N
9. Operator only affected party ............. N
10. Operator has appropriate bond in force ........ N
11. Permit can be issued without conservation order .... N
12. Permit can be issued without administrative approval. N
13. Can permit be approved before 15-day wait ....... N
14. Conductor string provided ...............
15. Surface casing protects all known USDWs ........
16. CMT vol adequate to circulate on conductor & surf csg.
17. CMT vol adequate to tie-in long string to surf csg . .
18. CMT will cover all known productive horizons .....
permafrost.
19. Casing designs adequate for C, T, B & · .
20. Adequate tankage or reserve pit ............
21. If a re-drill, has a 10-403 for abndnmnt been approved.
22. Adequate wellbore separation proposed .........
23. If diverter required, is it adequate ...........
24. Drilling fluid program schematic & equip list adequate
25. BOPEs adequate ............. ~pSl
26. BOPE press rating adequate; test to ~6~ g.
27. Choke manifold complies w/API RP-53 (May 8~.---~. · · .
28. Work win occur without operation shutdown .......
29. Is presence of H2S gas probable ............
GEOLOGY
/
30. Permit can be issued w/o hydrogen sulfide measures .... Y ~/_
31. Data presented on potential overpressure zones ..... Y/N~~ ~ /~
32. Seismic analysis 9f shallow gas zones .......... ~ N $ / ~'
33. Seabed condition survey (if off-shore) ........ /Y N
34. Contact name/phone for weekly progress reports . . . ~. Y N
[exploratory only] ...//
GEOLOGY:
ENGINEERING: COMMISSION:
BEW DWJ~
TAB
Comments/Instructions:
· '""~o~.CAcheldist rev 03/94
Well History File
APPENDIX
Information of detailed nature that is not
particularly germane to the Well Permitting Process
but is part of the history file.
To improve the readability of the Well History file and to
simplify finding information, information of this
nature is accumulated at the end of the file under APPENDIX.
No special effort has been made to chronologically
organize this category of information.
COMPANY NAME : ARCO ALASKA, INC.
WELL NAME : ZQ-20A
FIELD NAME : KUPARUK
BOROUGH : NORTH SLOPE
STATE : ALASKA
API NUMBER : 50-029-22589-01
REFERENCE NO : 96077
Date.~
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**** REEL HEADER ****
SERVICE NAME : EDIT
DATE : 96/03/25
ORIGIN : FLIC
REEL NAME : 96077
CONTINUATION # :
PREVIOUS REEL :
COI4MENT : ARCO ALASKA INC, 1Q-2OA, KUPARUK, API #50-029-22589-01
**** TAPE HEADER ****
SERVICE NAME : EDIT
DATE : 96/03/25
ORIGIN : FLIC
TAPE NAME : 96077
CONTINUATION # : 1
PREVIOUS TAPE :
COMMENT : ARCO ALASKA INC, 1Q-2OA, KUPARUK, API #50-029-22589-01
TAPE H~ER
KUPARUK
OPEN HOLE WIRELINE LOGS
WELL NAME:
API NUMBER:
OPERATOR:
LOGGING COMPANY:
TAPE CREATION DATE:
JOB DATA
JOB NUPiBER:
LOGGING ENGINEER:
OPERATOR WITNESS:
SURFACE LOCATION
RUN 1
96077
D.WARNER
D.WESTER
SECTION:
TO~FNSHIP:
RANGE:
FNL:
FSL:
FEL:
FWL :
ELEVATION (FT FROM MSL O)
KELLY BUSHING:
DERRICK FLOOR:
GROUND LEVEL:
WELL CASING RECORD
1ST STRING
2ND STRING
1Q-20A
500292258901
ARCO ALASKA, INC.
SCHLUMBERGER WELL SERVICES
25-MAR-96
RUN 2 RUN 3
..........
26
12N
9E
1090
1820
83. O0
82. O0
54.10
OPEN HOLE CASING DRILLERS
BIT SIZE (IN) SIZE (IN) DEPTH (FT)
5.500 7180.0
4.750
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25-MAR-1996 14:46
3RD STRING
PRODUCTION
REMARKS:
STRING
No depth adjustments were made to this data because it
has been requested by Dave Sharer of ARCO through Floyd
Bettis of Schlumberger to establish this DITE/GR data
as the depth control GR for all subsequent logging.
Primary depth control, including the use of magnetic
marks, ~as used by the field logging crew.
$
$
PAGE:
**** FILE HEADER ****
FILE NAME : EDIT .001
SERVICE : FLIC
VERSION · O01CO1
DATE · 96/03/25
MAX REC SIZE : 4096
FILE TYPE : LO
LAST FILE :
FiLE HEADER
FILE1FUMBER: 1
EDITED OPEN HOLEMAIN PASS
Ail tool strings; Clipped curves; No cased hole data.
DEPTH INCREMENT: 0.5000
FILE SU~94ARY
LDWG TOOL CODE START DEPTH STOP DEPTH
DITE 7912.0 7165.0
GR 7887.0 7165.0
$
BASELINE CURVE FOR SHIFTS:
CURVE SHIFT DATA (MEASURED DEPTH)
BASELINE DEPTH
$
MERGED DATA SOURCE
LDWG TOOL CODE
..............
$
REMARKS: No depth shifting as per Dave Shafer of ARCO.
$
.......... EQUIVALENT UNSHIFTED DEPTH ..........
RUN NO. PASS NO.
MERGE TOP MERGE BASE
LIS FOR~fAT DATA
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PAGE:
** DATA FORMAT SPECIFICATION RECORD **
* * SET TYPE - 64EB * *
TYPE REPR CODE VALUE
1 66 0
2 66 0
3 73 48
4 66 1
5 66
6 73
7 65
8 68 0.5
9 65 FT
11 66 85
12 68
13 66 0
14 65 FT
15 66 68
16 66 1
0 66 0
** SET TYPE - CHAN **
N~E SERV PIT SERVICE API APIAPI API FILE NUMB NUMB SIZE REPR PROCESS
ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX)
DEPT FT 100303 O0 000 O0 0 1 1 1 4 68 0000000000
IDPH DTE 0H~2~100303 O0 000 O0 0 1 1 1 4 68 0000000000
IMPH DTE OH~iM 100303 O0 000 O0 0 1 1 1 4 68 0000000000
ILD DTE OH~ 100303 O0 000 O0 0 1 1 1 4 68 0000000000
ILM DTE OH~2~ 100303 O0 000 O0 0 1 1 1 4 68 0000000000
SFL DTE OH~2~ 100303 O0 000 O0 0 ! 1 ! 4 68 0000000000
GR DTE GAPI 100303 O0 000 O0 0 1 I 1 4 68 0000000000
TEND DTE LB 100303 O0 000 O0 0 1 1 1 4 68 0000000000
TENS DTE LB 100303 O0 000 O0 0 1 1 1 4 68 0000000000
.~f~ESDTE 0~q~2~100303 O0 000 O0 0 1 1 1 4 68 0000000000
MT~DTE DEGF 100303 O0 000 O0 0 1 1 1 4 68 0000000000
SP DTE MV 100303 O0 000 O0 0 1 1 1 4 68 0000000000
** DATA **
DEPT. 7912. 000 IDPH.DTE 2. 707 IMPH.DTE 3. 439 ILD.DTE
ILM. DTE 3.379 SFL.DTE 3.555 GR.DTE -999.250 TEND.DTE
TENS.DTE 3905. 000 MRES.DTE O. 653 MTEM.DTE 149. 000 SP.DTE
2.676
428.500
-12.633
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PAGE:
DEPT. 7165. 000 IDPH.DTE
ILM. DTE O . 859 SFL . DTE
TENS.DTE 3340. 000 f~fl~ES.DTE
O. 753 IMPH.DTE
2. 494 GR. DTE
O. 622 MTEM. DTE
0.669
93.938
134.263
ILD.DTE
TEND.DTE
SP.DTE
0.434
517.000
-50.781
** END OF DATA **
**** FILE TRAILER ****
FILE NA~E : EDIT .001
SERVICE : FLIC
VERSION : O01CO1
DATE : 96/03/25
MAX REC SIZE : 4096
FILE TYPE : LO
LAST FILE
**** FILE HEADER ****
FILE NAME : EDIT .002
SERVICE : FLIC
VERSION : O01CO1
DATE : 96/03/25
MAX REC SIZE : 4096
FILE ~fPE : LO
LAST FILE :
FILE HEADER
FILE NUMBER: 2
EDITED CASED HOLE MAIN PASS
Clipped curves for open hole logs run into casing.
PASS NUMBER: 2
DEPTH INCREMENT: O. 5000
FILE SUMMARY
LDWG TOOL CODE START DEPTH
GRCH 7165.0
$
BASELINE CURVE FOR SHIFTS:
CURVE SHIFT DATA (MEASURED DEPTH)
STOP DEPTH
6948.0
BASELINE DEPTH
$
.......... EQUIVALENT ~,ISHIFTED DEPTH ..........
RE, lARKS: No depth shifting as per Dave Shafer o£ARCO.
$
LIS FORMAT DATA
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PAGE:
** DATA FORMAT SPECIFICATION RECORD **
** SET TYPE - 64EB **
TYPE REPR CODE VDLUE
1 66 0
2 66 0
3 73 16
4 66 1
5 66
6 73
7 65
8 68 0.5
9 65 FT
11 66 0
12 68
13 66 0
! 4 65 FT
15 66 68
16 66 1
0 66 1
** SET TYPE - CHAN **
NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS
ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX)
DEPT FT 100303 O0 000 O0 0 2 1 1 4 68 0000000000
GRCH DTE GAPI 100303 O0 000 O0 0 2 1 1 4 68 0000000000
TEND DTE LB 100303 O0 000 O0 0 2 1 1 4 68 0000000000
TENS DTE LB 100303 O0 000 O0 0 2 1 1 4 68 0000000000
** DATA **
DEPT. 7165.000 GRCH.DTE 93.938 TEND.DTE 517.000 TENS.DTE
DEPT. 6948. 000 GRCH.DTE 131 . 250 TEND.DTE 476. 500 TENS.DTE
3340.000
3275.000
** END OF DATA **
LIS' Tape Verification Listing
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PAGE:
**** FILE TRAILER ****
FILE NAME : EDIT .002
SERVICE : FLIC
VERSION : O0!CO1
DATE : 96/03/25
MAX REC SIZE : 4096
FILE TYPE : LO
LAST FILE :
**** FILE HEADER ****
FILE NAME : EDIT .003
SERVICE : FLIC
VERSION · O01CO1
DATE : 96/03/25
MAX REC SIZE : 4096
FILE TYPE : LO
LAST FILE :
FILE HEADER
FILE NUMBER 3
RAW OPEN HOLEMAIN PASS
Curves and log header data for each run and tool string in separate files.
RUN NUMBER: 1
TOOL STRING NUMBER: 1
PASS NUMBER: 2
DEPTH INCREMENT: O . 5000
FILE SUM~iARY
VENDOR TOOL CODE ST;~T DEPTH
DITE 7912.0
GR 7887.0
$
LOG HEADER DATA
DATE LOGGED:
SOFTWARE VERSION:
TIME CIRCULATION ENDED:
TIME LOGGER ON BOTTOM:
TD DRILLER (FT) :
TD LOGGER (FT) :
TOP LOG INTERVAL (FT) :
BOTTOM LOG INTERVAL (FT) :
LOGGING SPEED (FPHR) :
STOP DEPTH
..........
7165.0
6948.0
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE
DITE PHASOR INDUCTION
DITE PHASOR INDUCTION
DITE AUX. MEASURE~ENT
02-FEB-96
CP42.2
1130 2-FEB-96
2315 2-FEB-96
7923.0
7921.0
6950.0
7915.0
3600.0
TOOL NUMBER
DIS-270
D~C-1~3
AlUM-AA-950
LIS Tape V=rification Listing
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PAGE:
GR
TCC
TCC
$
GAMMA RAY
TELE~iETRY CARTRIDGE
TELEMETRY CARTRIDGE
SGC-SA-271
TCC-B-290
TCM-AB-19
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLERS CASING DEPTH (FT) :
LOGGERS CASING DEPTH (FT):
4. 750
7180.0
7166.0
BOREHOLE CONDITIONS ~FUD TYPE:
MUD DENSITY (LB/G):
~ VISCOSITY (S):
MUD PH :
FLUID LOSS (C3):
MAXIMUM RECORDED TEMPERATURE (DEGF)
RESISTIVITY (OHT4~) AT TEMPERATURE (DEGF)
MUD AT MEASURED T~.,"qPERATURE (MT)
MUD AT BOTTOM HOLE TEMPERATURE (BHT)
MUD FILTRATE AT (MT):
MUD FILTRATE AT (BHT) :
MUD CAKE AT (MT):
MUD CAKE AT (BHT) :
DISP WEIGHTED CLAY/POLY
12.30
56.0
i0.0
149.0
1. 270 63.0
O. 880 63.0
2. 050 63.0
NEUTRON TOOL
TOOL TYPE (EPITHERMAL OR THERMAL) :
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN) :
TOOL STANDOFF (IN):
REMARKS: USED NORDIC RKB FOR DEPTH REFERENCE. PRIMARY DEPTH
CONTROL USED INCLUDING THE USE OF MAGNETIC MARKS.
DID NOT USE CENTRALIZERS; THIS IS NOT RECOf~4ENDED BY
SWS DUE TO POOR REPEATIBILITY.
MEDIUM SPIKED AT 7620' BUT REPEATED ON BOTH PASSES.
$
LIS FORMAT DATA
** DATA FORMAT SPECIFICATION RECORD **
** SET TYPE - 64EB **
TYPE REPR CODE VALUE
1 66 0
2 66 0
3 73 48
4 66 1
LIS Tape Verification Listing
Schlumberger Alaska Computing Center
25-MAR-1996 14.46
PAGE:
TYPE REPR CODE VALUE
5 66
6 73
7 65
8 68 0.5
9 65 FT
1i 66 85
12 68
13 66 0
14 65 FT
15 66 68
16 66 1
0 66 1
* * SET TYPE - CHAN * *
NAME SERVOSVIT SERVICE API API API API FILE .~JMB NUMB SIZE REPR PROCESS
ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX)
DEPT FT 100303 O0 000 O0 0 3 1 ! 4 68 0000000000
IDPH LOG 0H~100303 O0 000 O0 0 3 1 1 4 68 0000000000
IMPH LOG OH~H~lO0303 O0 000 O0 0 3 1 1 4 68 0000000000
ILD LOG OH~f 100303 O0 000 O0 0 3 1 1 4 68 0000000000
ILM LOG Oh2V~4 100303 O0 000 O0 0 3 1 1 4 68 0000000000
SFLU LOG 0H~4~100303 O0 000 O0 0 3 1 ! 4 68 0000000000
GR LOG GAPI 100303 O0 000 O0 0 3 1 1 4 68 0000000000
HTENLOG LB 100303 O0 000 O0 0 3 1 1 4 68 0000000000
TENS LOG LB 100303 O0 000 O0 0 3 1 1 4 68 0000000000
MRES LOG OH~ 100303 O0 000 O0 0 3 1 1 4 68 0000000000
MTEMLOG DEGF 100303 O0 000 O0 0 3 1 1 4 68 0000000000
SP LOG MV 100303 O0 000 O0 0 3 1 1 4 68 0000000000
** DATA **
DEPT. 7988.000 IDPH. LOG 2.689 IMPH.LOG 3.170 ILD.LOG
ILM. LOG 3.152 SFLU. LOG 3.590 GR.LOG 99.938 HTEN. LOG
TENS.LOG 1845.000 MRES.LOG 0.653 MTEM. LOG 149.000 SP.LOG
2. 672
-17. 750
-15. 461
** E~vqD OF DATA **
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PAGE:
**** FILE TRAILER ****
FILE NAME : EDIT .003
SERVICE : FLIC
VERSION : O01CO1
DATE : 96/03/25
MAX REC SIZE : 4096
FILE TYPE : LO
LAST FILE :
**** FILE HEADER ****
FILE NAME : EDIT .004
SERVICE : FLIC
VERSION : O01CO1
DATE : 96/03/25
MAX REC SIZE : 4096
FiLE TYPE : LO
LAST FILE :
RUN NUMBER:
TOOL STRING NUMBER:
PASS NUMBER:
DEPTH INCREMENT:
FILE S~Y
FILE H~ER
FILE NU~BER 4
RAW OPEN HOLE REPEAT PASSES
Curves and log header data for each pass, tool string, and run in separate files.
1
1
1
0.5000
VENDOR TOOL CODE START DEPTH STOP DEPTH
DITE 7912.0 7165.0
GR 7887.0 7141 . 0
LOG HE;2~ER DATA
DATE LOGGED:
SOFTWARE VERSION:
TIME CIRCULATION ENDED:
TIME LOGGER ON BOTTOM:
TD DRILLER (FT) :
TD LOGGER (FT) :
TOP LOG INTERVAL (FT) :
BOTTOM LOG INTERVAL (FT) :
LOGGING SPEED (FPHR) :
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE
DITE PHASOR INDUCTION
DITE PHASOR INDUCTION
DITE AUX.MEASL~ENT
02-FEB-96
CP42.2
1130 2-FEB-96
2252 2-FEB-96
7923.0
7921.0
6950.0
7915.0
TOOL NUMBER
DIS-270
DIC-163
'A~4-AA-950
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PAGE:
10
GR
TCC
TCC
$
GA~94A RAY
TEL~iETRY CARTRIDGE
TELEMETRY CARTRIDGE
SGC-SA-271
TCC-B-290
TCM-AB- 19
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLERS CASING DEPTH (FT) :
LOGGERS CASING DEPTH (FT) :
4.750
7180.0
7166.0
BOREHOLE CONDITIONS
MUD TYPE:
MUD DENSITY (LB/G):
M~JD VISCOSITY (S) :
~ PH:
FLUID LOSS (C3):
MAXIMUM RECORDED TEMPERATURE (DEGF) :
RESISTIVITY (O.~4M) AT TEMPERATURE (DEGF) :
MUD AT MEASURED TEMPERATURE (MT):
MUD AT BOTTOM HOLE TEMPERATURE (BHT) :
MUD FILTRATE AT (MT):
MUD FILTRATE AT (BHT) :
MUD CAKE AT (MT):
MUD CAKE AT (BHT) :
DISP WEIGHTED CLAY/P
12.30
56.0
10.0
149.0
1. 270 63.0
O. 880 63.0
2. 050 63.0
NEUTRON TOOL
TOOL TYPE (EPITHERMAL OR THERMAL):
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN) :
TOOL STANDOFF (IN):
REMARKS: USED NORDIC RKB FOR DEPTH REFERENCE. PRIMARY DEPTH CONTROL
USED INCLUDING THE USE OF MAGNETIC MARKS.
DiD NOT USE CENTRALIZERS; THIS IS NOT RECO~4~ENDED BY SWS
DUE TO POOR REPEATIBILITY.
MEDIUM SPIKED AT 7620' BUT REPEATED ON BOTH PASSES.
LIS FORMAT DATA
* * DATA FORMAT SPECIFICATION RECORD * *
* * SET TYPE - 64EB * *
TYPE REPR CODE VALUE
1 66 0
2 66 0
3 73 48
4 66 1
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PAGE:
11
TYPE REPR CODE VALUE
5 66
6 73
7 65
8 68 0.5
9 65 FT
il 66 85
12 68
13 66 0
14 65 FT
15 66 68
16 66 i
0 66
** SET TYPE - CHARY **
NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS
ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX)
DEPT FT 100303 O0 000 O0 0 4 1 1 4 68 0000000000
IDPH RPT OH~4~ 100303 O0 000 O0 0 4 1 1 4 68 0000000000
IMPH RPT 0H~4~i00303 O0 000 O0 0 4 1 1 4 68 0000000000
ILD RPT 0,q~100303 O0 000 O0 0 4 1 1 4 68 0000000000
I~ RPT 0H~100303 O0 000 O0 0 4 1 1 4 68 0000000000
SFLU RPT OH~flO0303 O0 000 O0 0 4 1 1 4 68 0000000000
GR RPT GAPI 100303 O0 000 O0 0 4 1 1 4 68 0000000000
HTENRPT LB 100303 O0 000 O0 0 4 1 1 4 68 0000000000
TENS RPT LB 100303 O0 000 O0 0 4 1 1 4 68 0000000000
~RES RPT 0H~100303 O0 000 O0 0 4 1 1 4 68 0000000000
MTE~RPT DEGF 100303 O0 000 O0 0 4 1 1 4 68 0000000000
SP RPT PF~T 100303 O0 000 O0 0 4 1 1 4 68 0000000000
** DATA **
DEPT. 7983 . 000 IDPH. RPT 2. 682 IMPH. RPT 3 . 051 ILD. RPT
II=~.RPT 3,037 SFLU. RPT 3.590 GR.RPT 100. 375 HTEN. RPT
TENS.RPT 1595. 000 M2~ES.RPT O. 655 MTE~.RPT 148. 550 SP.RPT
DEPT. 7141.000 IDPH.RPT 48.250 IMPH.RPT 1950.000 ILD.RPT
ILM. RPT 1950.000 SFLU. RPT 0.324 GR.RPT 91.813 HTEN.RPT
TENS.RPT 3350.000 MRES.RPT 0.622 MTEM. RPT 133.700 SP.RPT
2. 652
49.188
-8.188
43.719
490.750
-111.938
** END OF DATA **
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PAGE:
12
**** FILE TRAILER ****
FILE NAME : EDIT .004
SERVICE : FLIC
VERSION · O01CO1
DATE : 96/03/25
MAX REC SIZE : 4096
FILE TYPE : LO
LAST FILE :
**** FILE HEADER ****
FILE NAME : EDIT .005
SERVICE : FLIC
VERSION · O01CO1
DATE ' 96/03/25
MAX REC SIZE : 4096
FILE TYPE : LO
LAST FILE :
GR
LOG HEADER DATA
FILE HEADER
FILE NUMBER 5
RAW CASED HOLE MAIN PASS
Curves and log header data for open hole logs run into casing.
PASS NUMBER: 1
DEPTH INCREMENT: O. 5000
FILE SUMPL~RY
VENDOR TOOL CODE START DEPTH STOP DEPTH
7165.0 6948.0
DATE LOGGED: 02-FEB-96
SOFTWARE VERSION: CP42.2
TIME CIRCULATION ENDED: 1130 2-FEB-96
TIME LOGGER ON BOTTOM: 2315 2-FEB-96
TD DRILLER (FT) : 7923.0
TD LOGGER (FT) : 7921.0
TOP LOG INTERVAL (FT) : 6950.0
BOTTOM LOG INTERVAL (FT) : 7915.0
LOGGING SPEED (FPHR) :
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE TOOL NUMBER
DITE PHASOR INDUCTION DIS- 270
DITE PHASOR INDUCTION DIC- 1 63
D I TE AUX. MEASUREMENT A~4~- AA - 950
GR GAP94A RAY SGC-SA-271
TCC TELEMETRY CD~gTRIDGE TCC-B-290
TCC TELEMETRY CARTRIDGE T~-AB-19
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PAGE:
13
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLERS CASING DEPTH (FT) :
LOGGERS CASING DEPTH (FT) :
4. 750
7180.0
7166.0
BOREHOLE CONDITIONS
MLrD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S) :
MUD PH:
FLUID LOSS (C3):
MAXIMUM RECORDED TEMPERATURE (DEGF) :
RESISTIVITY (OB?4M) AT TEMPERATURE (DEGF) :
MUD AT MEASURED T~4PERATL~E (MT):
MUD AT BOTTOM HOLE TEMPERATURE (BHT):
~JD FILTRATE AT (MT):
t~UD FILTRATE AT (BHT) :
MUD CAKE AT (MT):
MUD CAKE AT (BHT) :
DISP WEIGHTED CLAY/P
12.30
56.0
10.0
149.0
1. 270 63.0
O. 880 63.0
2. 050 63.0
NEUTRON TOOL
TOOL TYPE (EPITHERF~L OR THER~Y~aJL) :
~/~ATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
TOOL STANDOFF (iN):
REFL~RKS: USED NORDICRKB FOR DEPTH REFERENCE. PRIMARY DEPTH COAFfROL
USED INCLUDING THE USE OF MAGNETIC ~U~KS.
DID NOT USE CENTRALIZERS; THIS IS NOT RECOM~4ENDED BY SWS
DUE TO POOR REPEATIBILITY.
MEDIUM SPIKED AT 7620' BUT REPEATED ON BOTH PASSES.
$
LiS FORMAT DATA
** DATA FO~AT SPECIFICATION RECORD **
** SET TYPE - 64EB **
TYPE REPR CODE VALUE
1 66 0
2 66 0
3 73 16
4 66 1
5 66
6 73
7 65
LIS Tape Verification Lis~ing
Schlumberger Alaska Computing Center
25-MAR-1996 14.~6
PAGE: 14
TYPE REPR CODE VALUE
8 68 0.5
9 65 FT
11 66 0
12 68
13 66 0
·
14 65 FT
15 66 68
16 66 1
0 66 1
** SET TYPE - CHAN **
NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS
ID OP~ER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX)
DEPT FT 100303 O0 000 O0 0 5 1 1 4 68 0000000000
GRCH CSG GAPI 100303 O0 000 O0 0 5 ! i 4 68 0000000000
HTEN CSG LB 100303 O0 000 O0 0 $ i 1 4 68 0000000000
TENS CSG LB 100303 O0 000 O0 0 5 1 ! 4 68 0000000000
** DATA **
DEPT. 7165.000 GRCH. CSG 93.938 HTEN. CSG
DEPT. 6948.000 GRC~H. CSG 131.250 HTEN. CSG
517.000 TENS.CSG 3340.000
476.500 TENS.CSG 3275.000
** E~ OF DATA **
**** FILE TRAILER ****
FILE NAME : EDIT .005
SERVICE · FLIC
VERSION · O01CO1
DATE : 96/03/25
MAX REC SIZE : 4096
FILE TYPE : LO
LAST FILE :
LIS Tape Verl£icarion Listing
Schlumberger Alaska Computing Center
25-MAR-1996 14~_~
PAGE:
15
**** TAPE TRAILER ****
SERVICE NAME : EDIT
DATE : 96/03/25
ORIGIN : FLIC
TAPE NAME : 96077
CONTINUATION # : 1
PREVIOUS TAPE :
COf~4~VT : ARCO ALASKA INC, IQ-2OA, KUPARUK, API #50-029-22589-01
**** REEL TRAILER ****
SERVICE NAME : EDIT
DATE : 96/03/25
ORIGIN : FLIC
REEL NAME · 96077
CONTINUATION # :
PREVIOUS REEL :
COGENT : ARCO ALA, SKA iNC, 1Q-2OA, KUPARUK, API #50-029-22589-01
...............................
* ~S~ COMP~ING C~TER *
*
******************************
* ............................
....... SCHL~ERGER .......
* ............................
******************************
COMPANY NAME : ARCO ALASKA, INC.
WELL NAME : 1Q-20A
FIELD NAME : KUPARUK
BOROUGH : NORTH SLOPE
STATE : ALASKA
API NUMBER : 500292258901
REFERENCE NO : 96078
Date I~._~~
LIS Tape Verification Listing
Schlumberger Alaska Computing Center
15-MAR-1996 10:41
PAGE:
**** REEL HEADER ****
SERVICE NAM~ : EDIT
DATE : 96/03/15
ORIGIN . FLIC
REEL NAME : 96078
CONTINUATION # :
PREVIOUS REEL :
COFk4F~VT : ARCO ALASKA INC., KUPARUK 1Q-2OA, API #50-029-22589-01
**** TAPE HEADER ****
SERVICE NAME : EDIT
DATE · 96/03/15
ORIGIN · FLIC
TAPE NAME : 96078
CONTINUATION # : 1
PREVIOUS TAPE
COMMENT : ARCO ALASKA INC., KUPARUK 1Q-2OA, API #50-029-22589-01
TAPE HEADER
KUPARUK
~WD/MAD LOGS
WELL NAME:
API NUMBER:
OPERATOR:
LOGGING COMPANY:
TAPE CREATION DATE:
JOB DATA
JOB NUMBER:
LOGGING ENGINEER:
OPERATOR WITNESS:
SURFACE LOCATION
SECTION:
TOWNSHIP:
RANGE:
FNL:
FSL:
FEL:
FWL :
ELEVATION(FT FROM MSL O)
KELLY BUSHING:
DERRICK FLOOR:
GROUND LEVEL:
WELL CASING RECORD
1ST STRING
2ND STRING
1Q-20A
500292258901
ARCO ALASKA, INC.
SCHLUMBERGER WELL SERVICES
15-MAR-96
BIT RUN 1
.........
96078
GREEN
TRANTHAM
BIT RUN 2 BIT RUN 3
26
12N
8E
1090
1820
95.00
95.00
54.10
OPEN HOLE CASING DRILLERS
BIT SIZE (IN) SIZE (IN) DEPTH (FT)
6.750 7.625 4099.0
O0 O0
LIS Tape Ver±fication Listing
Schlumberger Alaska Computing Center
15-MAR-1996 10:41
3RD STRING
PRODUCTION STRING
REMARKS:
SLIM1 MWDREAL TIME GR RECORDED23-OCT-95 TO 25-0CT-95.
$
$
PAGE:
**** FILE HEADER ****
FILE NAME : EDIT .001
SERVICE : FLIC
VERSION : O01CO1
DATE : 96/03/15
MAX REC SIZE : 1024
FILE TYPE : LO
LAST FILE :
FILE HEADER
FILE NUMBER: 1
EDITED MERGED MWD
Clipped curves; all bit rufus merged.
DEPTH INCREM: 0.5000
FILE SUMFiARY
LDWG TOOL CODE START DEPTH
MWD 4120.0
$
BASELINE CURVE FOR SHIFTS: NONE
CURVE SHIFT DATA (MEASURED DEPTH)
BASELINE DEPTH
$
MERGED DATA SOURCE
LDWG TOOL CODE
$
REMARKS: REALTIME AND INTERPOLATED GR/ROP FROM SLIM1 MWD.
$
STOP DEPTH
7190.0
.......... EQUIVALENT UNSHIFTED DEPTH ..........
BIT RUN NO. MERGE TOP MERGE BASE
LIS FORMAT DATA
LIS Tape Verification Listing
Schlumberger Alaska Computing Center
15-MAR-1996 10:41
PAGE:
** DATA FORMAT SPECIFICATION RECORD **
** SET TYPE - 64EB **
TYPE REPR CODE VALUE
1 66 0
2 66 0
3 73 16
4 66 1
5 66
6 73
7 65
8 68 O. 5
9 65 FT
11 66 64
12 68
13 66 0
14 65 FT
15 66 68
16 66 1
0 66 0
** SET TYPE - CHAN * *
NAM~ SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS
ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX)
DEPT FT O0 000 O0 0 1 1 1 4 68 0000000000
GRRW MWD AAPI O0 000 O0 0 1 1 1 4 68 0000000000
GRIN MWD AAPI O0 000 O0 0 1 1 1 4 68 0000000000
ROP MWD FPHR O0 000 O0 0 1 1 1 4 68 0000000000
** DATA **
DEPT. 7190.000 GRRW. MWD -999.250 GRIN. MWD -999.250 ROP.MWD
DEPT. 7000. 000 GRRW. MWD 138. 300 GRIN. MWD 138. 300 ROP.MWD
DEPT. 6000.000 GRRW.MWD 72.400 GRIN. MWD 72.400 ROP.MWD
DEPT. 5000.000 GRRW. MWD -999.250 GRIN. MWD 88.733 ROP.MWD
DEPT. 4120.000 GRRW. MWD -999.250 GRIN.MWD -999.250 ROP.MWD
211.100
55.900
158.000
188.300
-999.250
** END OF DATA **
LIS Tape Verification Listing
Schlumberger Alaska Computing Center
15-MAR-1996 10:41
PAGE:
**** FILE TRAILER ****
FILE NAM~ : EDIT .001
SERVICE : FLIC
VERSION : O01CO1
DATE : 96/03/15
MAX REC SIZE : 1024
FILE TYPE : LO
LAST FILE :
**** FILE HEDi~ER ****
FILE NAME : EDIT .002
SERVICE · FLIC
VERSION : O01CO1
DATE : 96/03/15
MAX REC SIZE : 1024
FILE TYPE : LO
LAST FILE :
FILE HEADER
FILE NUMBER 2
RAW MWD
Curves and log header data for each bit run in separate files.
BIT RUN NUMBER: 1
DEPTH INCREMENT: O . 5000
FILE SUFk4AR Y
VENDOR TOOL CODE START DEPTH STOP DEPTH
4120.0 7190.0
LOG HEADER DATA
DATE LOGGED:
SOFTWARE:
SURFACE SOFTWARE VERSION:
DOWN-HOLE SOFTWARE VERSION:
DATA TYPE (MEMORY or REAL-TIME):
TD DRILLER (FT) :
TOP LOG INTERVAL (FT) :
BOTTOM LOG INTERVAL (FT) :
BIT ROTATING SPEED (RPM) :
HOLE INCLINATION (DEG)
MINIMUM ANGLE:
MAXIMUM ANGLE:
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE
GR GAM~A RAY
$
25-0CT-95
5.5C
5.5
R~- TIME
7190.0
4120.0
7190.0
9O
38.4
46.1
TOOL NUMBER
...........
SLIM1 A
LIS Tape Verification Listing
Schlumberger Alaska Computing Center
15-MAR-1996 10:41
PAGE:
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLERS CASING DEPTH (FT) :
BOREHOLE CONDITIONS
MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S) :
MUD PH:
MUD CHLORIDES (PPM) :
FLUID LOSS (C3):
RESISTIVITY (OPff4M) AT TEMPERATURE (DEGF) :
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATIONG TEMPERATURE :
MUD FILTRATE AT (MT):
MUD CAKE AT (MT):
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
LIS FORMAT DATA
6. 750
4099.0
LSND
9.50
39.0
** DATA FORMAT SPECIFICATION RECORD **
** SET TYPE - 64EB **
TYPE REPR CODE VALUE
1 66 0
2 66 0
3 73 32
4 66 1
5 66
6 73
7 65
8 68 0.5
9 65 FT
11 66 32
12 68
13 66 0
14 65 FT
15 66 68
16 66 1
0 66 1
LIS Tape Verification Listing
Schlumberger Alaska Computing Center
15-MAR-1996 10:41
PAGE:
** SET TYPE - CHAN **
NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS
ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX)
DEPT FT O0 000 O0 0 2 1 1 4 68 0000000000
GR RAW CPS O0 000 O0 0 2 1 1 4 68 0000000000
GR MWD AAPI O0 000 O0 0 2 1 1 4 68 0000000000
GR INT AAPI O0 000 O0 0 2 1 1 4 68 0000000000
ROP MWD F/HR O0 000 O0 0 2 1 1 4 68 0000000000
ROPSMWD F/HR O0 000 O0 0 2 1 1 4 68 0000000000
ROP5 INT F/HR O0 000 O0 0 2 1 1 4 68 0000000000
VDEPMWD FT O0 000 O0 0 2 1 1 4 68 0000000000
** DATA **
DEPT. 7190.000 GR.RAW -999.250 GR.MWD -999.250 GR.INT
ROP.MWD 168.100 ROPS.MWD 211.100 ROPS.INT 211.100 VDEP.MWD
DEPT. 7000.000 GR.RAW 26.700 GR.MWD 138.300 GR.INT
ROP.MWD 41.600 ROPS.MWD 55.900 ROPS.INT 55.900 VDEP.MWD
DEPT. 6000.000 GR.RAW 29.500 GR.MWD 72.400 GR.INT
ROP.MWD 166.000 ROPS.MWD 158.000 ROPS.INT 158.000 VDEP.MWD
DEPT. 5000.000 GR.RAW -999.250 GR.MWD -999.250 GR.INT
ROP.MWD 165.800 ROPS.MWD 188.300 ROPS.INT 188.300 VDEP.MWD
DEPT. 4120.000 GR.RAW -999.250 GR.MWD -999.250 GR.INT
ROP.MWD -999.250 ROPS.MWD -999.250 ROPS.INT -999.250 VDEP.MWD
-999.250
5930.500
138.300
5791.800
72.400
5067.400
88.733
4355.000
-999.250
-999.250
** END OF DATA **
**** FILE TRAILER ****
FILE NAME : EDIT .002
SERVICE · FLIC
VERSION · O01CO1
DATE : 96/03/15
MAX REC SIZE : 1024
FILE TYPE : LO
LAST FILE :
LI~ Tape Ver=£ication Listing
Schlumberger Alaska Computing Center
15-MAR-1996 10:~1
PAGE:
**** TAPE TRAILER ****
SERVICE NAME : EDIT
DATE : 96/03/15
ORIGIN : FLIC
TAPE NAME : 96078
CONTINUATION # : 1
PREVIOUS TAPE :
COB~4ENT . ARCO ALASKA INC., KUPARUK 1Q-2OA, API #50-029-22589-01
**** REEL TRAILER ****
SERVICE NA~iE : EDIT
DATE : 96/03/15
ORIGIN : FLIC
REEL NAME : 96078
CONTINUATION # :
PREVIOUS REEL :
CO~_~T : ARCO ALASKA INC., KUPARUK 1Q-2OA, API #50-029-22589-01
