Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout185-026185-026
T38889
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2024.06.11 15:10:38
-08'00'
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From:Yearout, Paul
To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC); NSK RWO CM
Cc:White, Bradley; Cozby, Kelly; Morales, Tony; Turcotte, Matthew
Subject:Nabors 7ES 3-06-24
Date:Friday, March 8, 2024 5:50:43 AM
Attachments:Nabors 7ES 3-06-24.xlsx
Thank you
Paul Yearout
7ES Toolpusher
Nabors Alaska Drilling Inc.
Office 907-670- 6132 Cell 907-244-6322
paul.yearout@nabors.com
*******************************
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transactions.
.58%
37'
1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown
Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program
Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Re-enter Susp Well
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 7878'feet 6678'feet
true vertical 6341' feet None feet
Effective Depth measured 6678'feet 6580', 7224' 7457'feet
true vertical 5399'feet 5873', 6018'feet
Perforation depth Measured depth
True Vertical depth
Tubing (size, grade, measured and true vertical depth) 3-1/2" J-55 7481' 5999'
Packers and SSSV (type, measured and true vertical depth)6580'
7224'
7457'
1827'
5336'
6018'
5979'
1827'
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure: 31bbls of 15.8ppg Class G
13a.
Prior to well operation:
Subsequent to operation:
13b. Pools active after work: None
15. Well Class after work:
Daily Report of Well Operations Exploratory Development Service Stratigraphic
Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL
Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG
Sundry Number or N/A if C.O. Exempt:
Authorized Name and
Digital Signature with Date: Contact Name:
Contact Email:
Authorized Title:Contact Phone:
3409' 3270'
Burst Collapse
7835'
Casing
6325'7858'
3379'
117'Conductor
Surface
Production
16"
9-5/8"
85'
measured
TVD
7"
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
185-026
50-029-21289-00-00
P.O. Box 100360
Anchorage, AK 99510
3. Address:
ConocoPhillips Alaska, Inc.
N/A
5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work:
ADL0025633
Kuparuk River Field/ Kuparuk Oil Pool - Suspended
KRU 3B-16
Plugs
Junk measured
Length
measured
true vertical
Packer
Representative Daily Average Production or Injection Data
Casing Pressure Tubing Pressure
14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283)
Gas-Mcf
MDSize
117'
N/A
324-046
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.
7238-7456'MD
Packer: SLB BluePack
Packer: Otis RRH
Packer: Otis WD Permanent
SSSV: Camco TRDP-1A
Elliott Tuttle
elliott.tuttle@conocophillips.com
(907) 263-4742Staff RWO/CTD Engineer
7385-7432', 7538-7574', 7592-7627'
5919-5958', 6047-6077', 6093-6123'
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 9:49 am, Apr 12, 2024
Digitally signed by Elliott Tuttle
DN: OU=CTD/ RWO Senior Engineer, O=
Conoco Phillips, CN=Elliott Tuttle, E=
elliott.tuttle@conocophillips.com
Reason: I am approving this document
Location:
Date: 2024.04.11 11:15:21-08'00'
Foxit PDF Editor Version: 13.0.0
Elliott Tuttle
DSR-4/12/24
RBDMS JSB 041824
Page 1/12
3B-16
Report Printed: 4/4/2024
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)
3/1/2024
12:00
3/1/2024
15:00
3.00 MIRU, MOVE OTHR P Set rig tongs on floor and Bridle up
blocks. Set top drive in stump, perform
pre-move check list, take on fuel and rig
water.
0.0 0.0
3/1/2024
15:00
3/2/2024
00:00
9.00 MIRU, MOVE DMOB P Prep to move rig to 3B-16, perform rig
maintenance
0.0 0.0
3/2/2024
00:00
3/2/2024
03:00
3.00 MIRU, MOVE MOB P Service rig, housekeeping,
maintenance, pits gun line and valve
replacement
0.0 0.0
3/2/2024
03:00
3/2/2024
12:00
9.00 MIRU, MOVE WAIT T Trucks on location moving Electrician
shack, Tool shack etc... BD steam and
water lines.***Standby for Nordic 3 Rig
Move
0.0 0.0
3/2/2024
12:00
3/2/2024
14:00
2.00 MIRU, MOVE MOB P MOB, CDR3 service module, 7ES
service module, Taylor Camp, and 7ES
shop to 3B-pad
0.0 0.0
3/2/2024
14:00
3/2/2024
17:00
3.00 MIRU, MOVE MOB P Mob sub towards CPF2 0.0 0.0
3/2/2024
17:00
3/2/2024
19:15
2.25 MIRU, MOVE WAIT T Standby for changeout/Santos Fire 0.0 0.0
3/2/2024
19:15
3/2/2024
22:00
2.75 MIRU, MOVE MOB P Mob sub towards 3B-pad 0.0 0.0
3/2/2024
22:00
3/2/2024
22:30
0.50 MIRU, MOVE MOB P KCS Y, check tires, take on LEPD 0.0 0.0
3/2/2024
22:30
3/3/2024
00:00
1.50 MIRU, MOVE MOB P Mob sub towards 3B-pad 0.0 0.0
3/3/2024
00:00
3/3/2024
02:30
2.50 MIRU, MOVE MOB P Continue MOB to 3B-pad 0.0 0.0
3/3/2024
02:30
3/3/2024
03:30
1.00 MIRU, MOVE RURD P Rig on pad. prep for backing over 3B-
16. Remove jeep Hang new tree in
cellar. Spread pit liner and ply wood
around well head.
0.0 0.0
3/3/2024
03:30
3/3/2024
05:00
1.50 MIRU, MOVE RURD P Spot Sub over 3B-16 Set front mats and
pitlinerset sub down.
0.0
3/3/2024
05:00
3/3/2024
07:00
2.00 MIRU, MOVE RURD P Lay down hardline for tiger tankhold
PJSM W/Cruz spot pit set mats release
trucks set down pits.
0.0 0.0
3/3/2024
07:00
3/3/2024
07:30
0.50 MIRU, MOVE RURD P Safe out walk ways and landings.
Inspect Derrick. Prep to raise Derrick.
0.0 0.0
3/3/2024
07:30
3/3/2024
09:00
1.50 MIRU, MOVE RURD P Raise Derrick Pin A-legs flip cattle chute 0.0 0.0
3/3/2024
09:00
3/3/2024
12:00
3.00 MIRU, MOVE RURD P Unpin Bridal lines. Pin Top drive. Hang
Bridal lines in Derrick.
Swap power to pits. RU interconnect.
RU mud lines. B/D F/rig floor tp pits.
Check lines. Start loading pits with fluid.
*** Note: Rig accepted
0.0 0.0
3/3/2024
12:00
3/3/2024
17:00
5.00 MIRU, MOVE RURD P Secure RF, connect the cement line,
hang rig tongs, place XO's subs and
elevators back on rack, remove leg
brace
0.0 0.0
3/3/2024
17:00
3/3/2024
20:00
3.00 MIRU, MOVE CIRC T R/U for well kill, kill line froze, thaw out
kill line
0.0 0.0
3/3/2024
20:00
3/4/2024
00:00
4.00 MIRU, MOVE CIRC T Attempt to pump through tubing,
maintan 1,000 psi, diesel and gas
returns 100 psi full open choke @ 2,100
psi returns stopped. Monitor, no flow,
blow down lines, pump down tubing, 19
stks 1,000 psi, pump down IA 520 stks
1,000 psi, blow down lines.
0.0 0.0
Rig: NABORS 7ES
RIG RELEASE DATE 3/14/2024
Page 2/12
3B-16
Report Printed: 4/4/2024
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)
3/4/2024
00:00
3/4/2024
02:00
2.00 MIRU, MOVE WAIT T Blow down all surface lines and
equipment, continue standby on HES
SL. Load and start processing DP 243
jts
0.0 0.0
3/4/2024
02:00
3/4/2024
07:45
5.75 MIRU, MOVE SLKL T HES SL on location, safety meeting, R/U
full PCE
0.0 0.0
3/4/2024
07:45
3/4/2024
09:00
1.25 MIRU, MOVE SLKL T RIH to tag at 6635' tapped through ciut
to 6649' Tubing pressure at 200
0.0 0.0
3/4/2024
09:00
3/4/2024
10:00
1.00 MIRU, MOVE SLKL T RD Slickline clear floor 0.0 0.0
3/4/2024
10:00
3/4/2024
11:30
1.50 MIRU, MOVE WAIT T Discuss plan forward mobilize LRS. 0.0 0.0
3/4/2024
11:30
3/4/2024
12:00
0.50 MIRU, MOVE SVRG P Service drawworks 0.0 0.0
3/4/2024
12:00
3/4/2024
13:00
1.00 MIRU, MOVE WAIT T standby for LRS pump truck 0.0 0.0
3/4/2024
13:00
3/4/2024
13:30
0.50 MIRU, MOVE RURD T RU LRS to attempt to gain circulation. 0.0 0.0
3/4/2024
13:30
3/4/2024
22:00
8.50 MIRU, MOVE CIRC T Pump 3BBLS Meth spear down IA
taking returns up the tubing pressure up
on IA to 1000 PSI 1 BBL to .7 BBL 1:1
returns dirty diesel.
3 BBL's meth swapped to diesel
Continue loading IA with diesel 23 BBL's
Swapped to meth 7 BBL's
Continue with diesel pumping 25.2
BBL's Diesel
Call out HAL slick line.
0.0 0.0
3/4/2024
22:00
3/5/2024
00:00
2.00 MIRU, MOVE CIRC T . Allow diesel/ Methanol to soak when
at suspecte ice plug depth while having
PTSM with crew coming on tour. line up
to continue pumping diesel as before.
On second cyle return line to tiger tank
froze up.
0.0 0.0
3/5/2024
00:00
3/5/2024
01:00
1.00 MIRU, MOVE SLKL T HAL slick line start, and check unit on
location. Work on thawing out hard line
to Tiger tank. Rig down frozen sections
of hard line, and move to pipe shed to
thaw.
0.0 0.0
3/5/2024
01:00
3/5/2024
05:00
4.00 MIRU, MOVE SLKL T Rig up HAL slick line PCE equipment,
and tools on the rig floor/ cellar. M/U
tools, stap lubricator and test to 2500
PSI: GOOD TEST.
Offline: continue to work on clearing ice
out of hardline in the pipe shed, and
riser to defuser line on tiger tank.
0.0 0.0
3/5/2024
05:00
3/5/2024
06:00
1.00 MIRU, MOVE SLKL T RIH with SL and pull ISO sleeve from
SSSV
0.0 0.0
3/5/2024
06:00
3/5/2024
08:00
2.00 MIRU, MOVE SLKL T Set catcher basket and PU dummy
valve retrieval tool. RIH and attempt to
pull GLM dummy valve. No valve on
running tool. Damage noticed on
retrieval tool upon inspection at surface.
0.0 0.0
3/5/2024
08:00
3/5/2024
12:00
4.00 MIRU, MOVE SLKL T MU another dummy valve retrieval tool.
RIH and attempt to pull GLM dummy
valve. No valve. Parts of fishing neck
from dummy valve found in tool.
Contact W/O engineer, and discuss plan
forward.
0.0 0.0
3/5/2024
12:00
3/5/2024
15:00
3.00 MIRU, MOVE SLKL T RIH with ISO sleeve and set across the
SSSV. RD SL.
0.0 0.0
Rig: NABORS 7ES
RIG RELEASE DATE 3/14/2024
Page 3/12
3B-16
Report Printed: 4/4/2024
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)
3/5/2024
15:00
3/5/2024
21:00
6.00 MIRU, MOVE OWFF T Well slowly U-tubing about 1 gallon per
5 minutes out the IA into a 5 gallon
bucket. Slowing down to 1.5" every 5
minutes after 4 hours.
0.0 0.0
3/5/2024
21:00
3/6/2024
00:00
3.00 MIRU, WHDBOP NUND P FMC set BPV. N/D tree. Inspect hanger
neck threads: Threads heavily
corroded/ damaged. FMC install
blanking plug.
0.0 0.0
3/6/2024
00:00
3/6/2024
03:00
3.00 MIRU, WHDBOP NUND P Install DSA and set stack on wellhead.
Install new API ring and TQ flanges.
Install riser.
0.0 0.0
3/6/2024
03:00
3/6/2024
04:30
1.50 MIRU, WHDBOP RURD P MU safety valves T/test joints. MU blank
sub to top drive. RU test pump and
hoses. Fill stack and choke with water
and purge out all air.
0.0 0.0
3/6/2024
04:30
3/6/2024
11:00
6.50 MIRU, WHDBOP BOPE P Initial BOP test. Tested BOP to 250 PSI
low, 3000 PSI high 5 min/each. AOGCC
witness waived by Brian Bixby.
Test 1: Blind rams, choke valves
1,2,3,16. Rig floor kill, outer test spool
valve, and IBOP
Test 2: Blind rams, conke valves 4,5,&6.
HCR kill, INner test spool valve, Manual
IBOP.
M/U 4" test assembly.
Test 3: Lower pipe rams, XT39 FOSV.
Test 4: Upper pipe rams, Choke valves
7,8,&9, Manual kill valve XT 39 Dart
Test 5: Super choke, and manual choke
(on choke manifold).
Test 6: Annular, choke valves 10, &11.
L/D 4" test joint, M/U 3.5" test assy.
Test 7: Lower pipe rams, 3.5" FOSV.
Test 8: Upper pipe rams, choke valves
12,13, &15
Test 9: Annular, and choke valve 14.
Test 10: HCR choke
Test 11: Manual choke.
Perform Accumulator draw down test:
GOOD.
0.0 0.0
3/6/2024
11:00
3/6/2024
12:00
1.00 MIRU, WHDBOP RURD P Blow down test equipment, choke and
kill. Suck out stack. Clean and clear rig
floor.
0.0 0.0
3/6/2024
12:00
3/6/2024
12:30
0.50 MIRU, WHDBOP MPSP P Pull blanking plug and BPV per FMC
rep.
0.0 0.0
3/6/2024
12:30
3/6/2024
13:30
1.00 MIRU, WHDBOP RURD P Prep rig floor to pull hanger. Rig up SLB
spooling unit, and tongs to pull 3.5"
tubing.
0.0 0.0
3/6/2024
13:30
3/6/2024
14:00
0.50 MIRU, WHDBOP SVRG P Grease Crown 0.0 0.0
3/6/2024
14:00
3/6/2024
16:00
2.00 MIRU, WHDBOP RURD P M/U BOT spear, engage spear into
hangerr. BOLDS
0.0 0.0
Rig: NABORS 7ES
RIG RELEASE DATE 3/14/2024
Page 4/12
3B-16
Report Printed: 4/4/2024
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)
3/6/2024
16:00
3/6/2024
17:00
1.00 MIRU, WHDBOP RURD P P/U and pull hanger, PUWT: 114K. Pull
hanger to the rig floor. SLB terminate
control lines.
0.0 6,632.0
3/6/2024
17:00
3/6/2024
19:30
2.50 MIRU, WELCTL CIRC P R/U to displace well to sea water.
Taking returns to the tiger tank.
Displace well.
6,632.0 6,632.0
3/6/2024
19:30
3/6/2024
20:00
0.50 SLOT, RPCOMP OTHR P Flow check well: Static. Blow down,
lines. PJSM for laying down tubing.
6,632.0 6,632.0
3/6/2024
20:00
3/7/2024
00:00
4.00 SLOT, RPCOMP PUTB P L/D 3.5" 9.3# tubing from 6,632' to 4050' 6,632.0 4,050.0
3/7/2024
00:00
3/7/2024
06:30
6.50 SLOT, RPCOMP PULL P POOH L/D Tubing from 4050' to
surface.
LD 209 joints of 3-1/2" tubing, 8 GLMs
and a SSSV.
Cut joint 27.99'.
32 Bands recovered.
4,050.0 0.0
3/7/2024
06:30
3/7/2024
07:00
0.50 SLOT, RPCOMP RURD P Install wear ring ID=6.5" 0.0 0.0
3/7/2024
07:00
3/7/2024
07:30
0.50 SLOT, RPCOMP SVRG P Dress air slips and grease. Replace
rough neck dies and grease. Grease
Drawworks.
0.0 0.0
3/7/2024
07:30
3/7/2024
08:30
1.00 SLOT, WHPST BHAH P MU BHA #1 Drift, clean out and logging. 0.0 532.0
3/7/2024
08:30
3/7/2024
12:00
3.50 SLOT, WHPST PULD P RIH on drill pipe singles. Monitoring
well on the trip tank. F/522' to 2043'
PUWT: 80 K
SOWT: 80 K
522.0 2,043.0
3/7/2024
12:00
3/7/2024
12:30
0.50 SLOT, WHPST CIRC P Shallow test MWD Per Baker MWD/ DD. 2,043.0 2,043.0
3/7/2024
12:30
3/7/2024
14:00
1.50 SLOT, WHPST PULD P RIH on drill pipe singles. Monitoring
well on the trip tank. F/ 2043 to 2898'
PUWT: 80 K
SOWT: 80 K
2,043.0 2,898.0
3/7/2024
14:00
3/7/2024
15:00
1.00 SLOT, WHPST SLPC P Hang blocks, and slip and cut drilling
line. Cut 89'.
2,898.0 2,898.0
3/7/2024
15:00
3/7/2024
20:00
5.00 SLOT, WHPST PULD P Continue to RIH picking up singles
monitoring well on the trip tank. F/
2898' 6630'.
PUWT: 124 K
SOWT: 105 K
Tag stump @ 6630' set down 10K
2,898.0 6,630.0
3/7/2024
20:00
3/7/2024
20:15
0.25 SLOT, WHPST WASH P P/U string 10'. Turn on pumps @ 120
GPM @ 400 PSI. Wash down and tag
stump @ 6630' set down 20K to
confirm solid base for setting the whip
stock in later run.
6,630.0 6,630.0
Rig: NABORS 7ES
RIG RELEASE DATE 3/14/2024
Page 5/12
3B-16
Report Printed: 4/4/2024
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)
3/7/2024
20:15
3/7/2024
20:30
0.25 SLOT, WHPST REAM P PIck up 10'. Bring pumps up to 210
GPM. Engage rotary @ 30 RPM. Wash
and ream down to stump to verify no
"junk" on top of or around stump. Tag
stump with 10 K. P/U 10', disengague
rotary. Come down and tag stump with
20 K
ROTWT: 110K
PUWT: 124 K
SOWT: 105 K
RPM: 30
TQ: 4 K
GPM: 210
PSI: 900
6,630.0 6,630.0
3/7/2024
20:30
3/7/2024
21:30
1.00 SLOT, WHPST CIRC P Pump 40 BBL high vis sweep, and
circulate surface to surface.
210 GPM @ 900 PSI
Flow check well after circ: STATIC.
6,630.0 6,630.0
3/7/2024
21:30
3/7/2024
23:30
2.00 SLOT, WHPST DLOG P Log out of the hole from 6630' to 6465'
@ 2'/min per MWD looking for Gama
signature. Sensor offset from mill 67'.
Gamma spike observed @ 6436'.
250 GPM @ 1100 PSI
PUWT: 120 K
6,630.0 6,465.0
3/7/2024
23:30
3/8/2024
00:00
0.50 SLOT, WHPST SVRG P Rig crew perform rig service prior to
POOH.
6,465.0 6,465.0
3/8/2024
00:00
3/8/2024
03:00
3.00 SLOT, WHPST TRIP P POOH from 6445' to 550'
120K UWT
6,465.0 550.0
3/8/2024
03:00
3/8/2024
04:30
1.50 SLOT, WHPST PULD P PU the rest of the drill pipe singles and
RIH from 550' to 1615'
550.0 1,615.0
3/8/2024
04:30
3/8/2024
05:30
1.00 SLOT, WHPST TRIP P POOH from 6445' to 550'
120K UWT
1,615.0 522.0
3/8/2024
05:30
3/8/2024
06:00
0.50 SLOT, WHPST OWFF P OWFF- No flow 522.0 522.0
3/8/2024
06:00
3/8/2024
07:30
1.50 SLOT, WHPST BHAH P LD BHA #1, clean magnet and rack
back 3 stands of HWDP
522.0 0.0
3/8/2024
07:30
3/8/2024
09:30
2.00 SLOT, WHPST BHAH P MU BHA #2, Whipstock and window
milling BHA. Orient tool and scribe as
per Baker hand.
0.0 452.0
3/8/2024
09:30
3/8/2024
11:30
2.00 SLOT, WHPST TRIP P TIH from 452' to 3590'
88K PUW
83K SOW
Shallow hole test MWD tools at 2000'.
452.0 3,590.0
3/8/2024
11:30
3/8/2024
12:00
0.50 SLOT, WHPST SVRG P Grease rough neck, air slips and
Drawworks
3,590.0 3,590.0
3/8/2024
12:00
3/8/2024
15:00
3.00 SLOT, WHPST TRIP P TIH from 3590' to 6629'.
126K PUW
104K SOW
Orient whipstock 45 LOHS.
3,590.0 6,629.0
Rig: NABORS 7ES
RIG RELEASE DATE 3/14/2024
Page 6/12
3B-16
Report Printed: 4/4/2024
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)
3/8/2024
15:00
3/8/2024
16:00
1.00 SLOT, WHPST WPST P Set the TOWS at 324 degrees at 6608'
with the BOWS at 6621'.
Shear anchor at 15K, pulled 10K over to
confirm set./
Shear out sheer bolt at 47K and pull
free.
6,629.0 6,608.0
3/8/2024
16:00
3/8/2024
18:00
2.00 SLOT, WHPST DISP P Pump 30 bbl Hi vis sweep. Then
displace seawater with 11.5 ppg LSND
mud.
6,608.0 6,608.0
3/8/2024
18:00
3/8/2024
19:45
1.75 SLOT, WHPST MILL P TIH, ROT=80 rpm, off bottom
torque=3,700 ft/lbs, On bottom
torque=4,762 ft/lbs, pumping 1,843
psi/58 spm pump #1, 64 spm pump #2,
Total SPM=122, Flow in 295 gal/min,
WOB=
6,608.0 6,613.0
3/8/2024
19:45
3/8/2024
20:00
0.25 SLOT, WHPST MILL P PUH, back ream, PUW=127k,
SOW=99k, BOBM, ROT=80 rpm, off
bottom torque=3,700 ft/lbs, On bottom
torque=4,762 ft/lbs, pumping 1,843
psi/58 spm pump #1, 64 spm pump #2,
Total SPM=122, Flow in 295 gal/min,
WOB=2-3k
6,613.0 6,613.0
3/8/2024
20:00
3/9/2024
00:00
4.00 SLOT, WHPST MILL P PUW=127k, SOW=99k, BOBM,
ROT=80 rpm, off bottom torque=3,700
ft/lbs, On bottom torque=5,562 ft/lbs,
pumping 1,843 psi/58 spm pump #1, 64
spm pump #2, Total SPM=121, Flow in
295 gal/min, WOB=4-5k, pump 20 bbl
sweep to clean hole
6,613.0 6,624.0
3/9/2024
00:00
3/9/2024
01:30
1.50 SLOT, WHPST MILL P BOBM, ROT=100 rpm, off bottom
torque=3,700 ft/lbs, On bottom
torque=4,790 ft/lbs, pumping 1,898
psi/57 spm pump #1, 63 spm pump #2,
Total SPM=120/7 bpm, Flow in 288
gal/min, WOB=6-8 k
6,624.0 6,662.0
3/9/2024
01:30
3/9/2024
02:45
1.25 SLOT, WHPST REAM P 6,662', TD rat hole, PUH 105 k, ROT=81
rpm, Off bottom torque=5,600 ft/lbs,
pumping 1,895 psi/122 spm/7 bpm,
back ream casing exit x 3 while
circulating sweep around, lower pump
rate to 2 bpm, drift casing exit (clean)
6,662.0 6,600.0
3/9/2024
02:45
3/9/2024
03:15
0.50 SLOT, WHPST OWFF P Stand back 1 stand, blow down TOP
Drive due to ambient temp -31° F,
Check well for flow
6,600.0 6,600.0
3/9/2024
03:15
3/9/2024
03:30
0.25 SLOT, WHPST TRIP P KBU, Pump Dry Job 14.4 ppg/15 bbl,
blow down TOP Drive
6,600.0 6,572.0
3/9/2024
03:30
3/9/2024
08:30
5.00 SLOT, WHPST TRIP P TOOH standing back stands in derrick
on elevators.
UWT 120K
DWT 95K
6,572.0 432.0
3/9/2024
08:30
3/9/2024
11:00
2.50 SLOT, WHPST BHAH P LD window milling BHA.
Upper watermelon mill in gauge at
6.151".
Lower watermelon mill in gauge at
5.875".
Window mill under gauge at at
5.8" (started at 6.125")
432.0 0.0
3/9/2024
11:00
3/9/2024
11:30
0.50 SLOT, WHPST SVRG P Service and inspect top drive. 0.0 0.0
3/9/2024
11:30
3/9/2024
12:00
0.50 SLOT, WHPST OTHR P M/U Johnny Wack Stick, jet BOPE of
metal from milling operations
0.0
3/9/2024
12:00
3/9/2024
15:00
3.00 PROD1, DRILL BHAH P MU Drilling BHA #4
Orient tool and scribe as per Baker
hand.
0.0 341.0
Rig: NABORS 7ES
RIG RELEASE DATE 3/14/2024
Last Tag
Annotation Depth (ftKB)Wellbore End Date Last Mod By
Last Tag: SLM 7,641.0 3B-16 9/13/2011 ninam
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Set Holdopen sleeve across SSSV 3B-16 1/31/2024 rogerba
Notes: General & Safety
Annotation End Date Last Mod By
NOTE: View Schematic w/ Alaska Schematic9.0 7/7/2010 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
PRODUCTION 7 6.28 23.7 7,858.4 6,325.2 26.00 J-55 BTC
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
23.6
Set Depth…
7,480.6
String Max No…
3 1/2
Set Depth…
5,998.6
Tubing Description
TUBING
Wt (lb/ft)
9.30
Grade
J-55
Top Connection
EUE 8RD
ID (in)
2.99
Completion Details: excludes tubing, pup, space out, thread, RKB...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°)Item Des
OD
Nominal
(in)Com Make Model
Nominal
ID (in)
23.6 23.60.01HANGER 8.000 FMC GEN III TUBING HANGER PARKE
R
141 3.500
1,827.4 1,827.4 1.74 SAFETY VLV 5.937 CAMCO TRDP-1A CAMCO TRDP-
1A
2.810
1,848.7 1,848.7 2.30 GAS LIFT 5.620 MERLA TMPD 2.937
3,066.0 2,998.5 32.49 GAS LIFT 5.620 MERLA TMPD 2.937
4,060.6 3,717.3 46.76 GAS LIFT 5.620 MERLA TMPD 2.937
4,614.6 4,089.3 48.72 GAS LIFT 5.620 MERLA TMPD 2.937
4,937.6 4,299.0 50.07 GAS LIFT 5.620 MERLA TMPD 2.937
5,250.3 4,500.8 49.69 GAS LIFT 5.620 MERLA TMPD 2.937
5,572.7 4,709.0 49.68 GAS LIFT 5.620 MERLA TMPD 2.937
5,880.9 4,908.6 49.71GAS LIFT 5.620 MERLA TMPD 2.937
6,348.4 5,198.3 54.18 GAS LIFT 5.620 MERLA TMPD 2.937
6,821.0 5,494.0 47.03 GAS LIFT 5.620 MERLA TMPD 2.937
7,169.9 5,747.0 39.29 GAS LIFT 5.620 MERLA TPDX 2.937
7,215.2 5,782.4 38.05 SBR 4.000 OTIS SEAL BORE RECEPTACLE OTIS 3.000
7,224.3 5,789.5 37.83 PACKER 5.980 OTIS RRH RETRIEVABLE
PACKER
OTIS RRH 2.969
7,260.8 5,818.6 36.92 INJECTION 5.960 MERLA TPDX 2.875
7,332.8 5,876.7 35.49 INJECTION 5.960 MERLA TPDX 2.875
7,373.3 5,909.8 34.92 BLAST RING 3.500 BLAST RINGS (2) 2.992
7,436.8 5,962.134.01 INJECTION5.960 MERLA TPDX 2.875
7,456.2 5,978.3 33.72 LOCATOR 5.060 OTIS STRAIGHT SLOT TYPE
LOCATOR
OTIS3.000
7,456.8 5,978.833.71 PACKER 6.156OTIS WD PERMANENT PACKER OTIS WD 4.000
7,460.2 5,981.6 33.67 SBE 3.500 OTIS SEAL BORE EXTENSION OTIS 3.000
7,471.8 5,991.3 33.49 NIPPLE 4.520 CAMCO D NIPPLE NO GO CAMCO D 2.750
7,479.3 5,997.5 33.38 WLEG 4.000 OTIS WIRELINE ENTRY GUIDE OTIS 3.000
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top (ftKB)
Top (TVD)
(ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in)
6,610.8 5,356.1 50.74 WHIPSTOCK Set TOWS @ 6,608' F/7ES
RKB
Adjusted RKB depth F/Parker
141 @ 6610.77'
Baker
Gen II
3/8/2024 1.000
6,632.0 5,369.6 50.41 CUT WELLTECH MECHANICAL
TUBING CUT. TATTLE-TAIL
INDICATED 3.53" BLADE
EXTENSION.
WELLTE
C
MECHA
NICAL
1/26/2024 2.992
7,170.0 5,747.139.29 LEAK -
TUBING
Found tbg leak w/ Relay LDL
11/28/21
11/28/2021 0.000
7,195.0 5,766.5 38.57 CEMENT
RETAINER
SET 3.5" FH-1 CEMENT
RETAINER AT 7195' RKB
FH1 005-
2725-
500
8/18/20230.000
7,240.0 5,802.0 37.44 TUBING
PUNCH
3 FT OF TUBING PUNCHES
(4 SPF)
8/4/2023 2.992
7,245.0 5,805.9 37.31 RBP Set RBP (OAL 9.03') TTS CPP3
5281/
CPEQ
35001
11/4/2021 0.000
7,245.0 5,805.9 37.31 OTHER Set 3.5" TTS pulling tool w/
Multiple Fish G-Necks (Top
Fish neck is 2.31" & Bottom
Fish neck 1.81") 19" OAL
2/4/2022 0.000
7,255.0 5,813.9 37.07 PATCH 21.5' Merla TBG PATCH; Set
across GLM #12 on 11/30/95/
w/ AVA Nipple 4' Below Top of
GLM
11/30/1995 2.313
7,260.9 5,818.6 36.92 SLEEVE-O 2.31" AVA CIC SLEEVE
(OAL=13")
9/13/2011 1.860
7,328.0 5,872.835.56 PATCH 21.5' Merla TBG PATCH; Set
across GLM #13 on 11/30/95
11/30/1995 2.375
7,471.9 5,991.3 33.49 NIPPLE
REDUCER
Set Nipple Reducer w/ 1.81" D
Profile; Set on 11/29/95
11/29/1995 1.813
3B-16, 4/4/2024 2:53:11 PM
Vertical schematic (actual)
PRODUCTION; 23.7-7,858.4
IPERF; 7,592.0-7,627.0
IPERF; 7,538.0-7,574.0
NIPPLE REDUCER; 7,471.9
PACKER; 7,456.8
INJECTION; 7,436.8
IPERF; 7,385.0-7,432.0
PATCH; 7,328.0
INJECTION; 7,332.8
PATCH; 7,255.0
INJECTION; 7,260.8
SLEEVE-O; 7,260.9
RBP; 7,245.0
OTHER; 7,245.0
TUBING PUNCH; 7,240.0
PACKER; 7,224.3
CEMENT RETAINER; 7,195.0
GAS LIFT; 7,169.9
LEAK - TUBING; 7,170.0
GAS LIFT; 6,821.0
Cement Plug; 6,678.0 ftKB
CUT; 6,632.0
WHIPSTOCK; 6,610.8
Primary –Full Bore; 6,569.5
ftKB
Nipple - Profile; 6,598.9
Packer; 6,580.2
Sleeve - Sliding; 6,569.8
Mandrel – GAS LIFT; 6,511.2
SURFACE; 30.2-3,409.3
Mandrel – GAS LIFT; 2,468.0
CONDUCTOR; 32.0-117.0
Hanger; 25.5
KUP INJ
KB-Grd (ft)
35.98
RR Date
4/7/1985
Other Elev…
3B-16
...
TD
Act Btm (ftKB)
7,878.0
Well Attributes
Field Name
KUPARUK RIVER UNIT
Wellbore API/UWI
500292128900
Wellbore Status
INJ
Max Angle & MD
Incl (°)
54.45
MD (ftKB)
6,400.00
WELLNAME WELLBORE
Annotation
Last WO:
End DateH2S (ppm)DateComment
SSSV: TRDP
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)
1,848.7 1,848.7 2.30 1 GAS LIFT DMY BK 1 0.05/20/1985 0.000
3,066.0 2,998.5 32.49 2 GAS LIFT DMY BK 1 0.05/20/1985 0.000
4,060.63,717.3 46.76 3 GAS LIFT DMY BK 1 0.05/20/1985 0.000
4,614.6 4,089.3 48.72 4 GAS LIFT DMY BK 1 0.05/20/1985 0.000
4,937.6 4,299.0 50.07 5 GAS LIFT DMY BK 1 0.05/20/1985 0.000
5,250.3 4,500.8 49.69 6 GAS LIFT DMY BK 1 0.05/20/1985 0.000
5,572.7 4,709.0 49.68 7 GAS LIFT DMY BK 1 0.05/20/1985 0.000
5,880.9 4,908.6 49.71 8 GAS LIFT DMY BK 1 0.05/20/1985 0.000
6,348.4 5,198.3 54.18 9 GAS LIFT DMY BK 1 0.05/20/1985 0.000
6,821.0 5,494.0 47.03 1
0
GAS LIFT DMY BK 1 0.05/20/1985 0.000
7,169.9 5,747.0 39.29 1
1
GAS LIFT DMY RM 1 1/2 0.0 11/8/2021 0.000
7,260.8 5,818.6 36.92 1
2
INJ PATCH 0 1 1/2 0.0 11/30/1995 0.000
7,332.8 5,876.7 35.49 1
3
INJ PATCH 0 1 1/2 0.0 11/30/1995 0.000
7,436.8 5,962.1 34.01 1
4
INJ DMY RM 1 1/2 0.0 11/15/1995 0.000
Perforations & Slots
Top (ftKB)Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB)Linked Zone Date
Shot
Dens
(shots/ft)Type Com
7,385.0 7,432.0 5,919.4 5,958.2 C-3, C-2, C-1,
3B-16
5/18/1985 12.0 IPERF 5" Scalloped Csg Gun; 120
deg. ph
7,538.0 7,574.0 6,046.8 6,077.3 A-4, A-3, 3B-16 5/18/1985 4.0 IPERF 4" Carrier JJ II; 120 deg. ph
7,592.0 7,627.0 6,092.6 6,122.6 A-2, 3B-16 5/18/1985 4.0 IPERF 4" Carrier JJ II; 120 deg. ph
Cement Squeezes
Top (ftKB)Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB)Des Com
Pump Start
Date
6,678.0 7,245.0 5,399.1 5,805.9 Cement Plug 31 BBLS 15.8 PPG CEMENT PUMPED THROUGH
RETAINER. INTO C-SANDS.
8/18/2023
7,986.0 Primary – Full
Bore
3B-16, 4/4/2024 2:53:14 PM
Vertical schematic (actual)
PRODUCTION; 23.7-7,858.4
IPERF; 7,592.0-7,627.0
IPERF; 7,538.0-7,574.0
NIPPLE REDUCER; 7,471.9
PACKER; 7,456.8
INJECTION; 7,436.8
IPERF; 7,385.0-7,432.0
PATCH; 7,328.0
INJECTION; 7,332.8
PATCH; 7,255.0
INJECTION; 7,260.8
SLEEVE-O; 7,260.9
RBP; 7,245.0
OTHER; 7,245.0
TUBING PUNCH; 7,240.0
PACKER; 7,224.3
CEMENT RETAINER; 7,195.0
GAS LIFT; 7,169.9
LEAK - TUBING; 7,170.0
GAS LIFT; 6,821.0
Cement Plug; 6,678.0 ftKB
CUT; 6,632.0
WHIPSTOCK; 6,610.8
Primary –Full Bore; 6,569.5
ftKB
Nipple - Profile; 6,598.9
Packer; 6,580.2
Sleeve - Sliding; 6,569.8
Mandrel – GAS LIFT; 6,511.2
SURFACE; 30.2-3,409.3
Mandrel – GAS LIFT; 2,468.0
CONDUCTOR; 32.0-117.0
Hanger; 25.5
KUP INJ 3B-16
...
WELLNAME WELLBORE
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
*All BOPE reports are due to the agency within 5 days of testing*
SSu bmit to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov
Rig Owner: Rig No.:7ES DATE: 3/6/24
Rig Rep.: Rig Email:
Operator:
Operator Rep.: Op. Rep Email:
Well Name:PTD #1850260 Sundry #324-046
Operation: Drilling: Workover: X Explor.:
Test: Initial: X Weekly: Bi-Weekly: Other:
Rams:250/3000 Annular:250/3000 Valves:250/3000 MASP:2827
MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES:
Test Result/Type Test Result Quantity Test Result
Housekeeping P Well Sign P Upper Kelly 1P
Permit On Location P Hazard Sec.P Lower Kelly 1P
Standing Order Posted P Misc.NA Ball Type 2P
Test Fluid Water Inside BOP 1P
FSV Misc 0NA
BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm
Stripper 0NATrip Tank PP
Annular Preventer 1 13 5/8" T90 P Pit Level Indicators PP
#1 Rams 1 3 1/2"" x 5 1/2"P Flow Indicator PP
#2 Rams 1 Blinds P Meth Gas Detector PP
#3 Rams 1 3 1/2" x 5 1/2"P H2S Gas Detector PP
#4 Rams 0NAMS Misc 0NA
#5 Rams 0NA
#6 Rams 0NAACCUMULATOR SYSTEM:
Choke Ln. Valves 1 3 1/8" Gate P Time/Pressure Test Result
HCR Valves 2 3 1/8" Gate P System Pressure (psi)3050 P
Kill Line Valves 2 3 1/8" & 2"P Pressure After Closure (psi)1600 P
Check Valve 0NA200 psi Attained (sec)16 P
BOP Misc 2 2 1/16" Gate P Full Pressure Attained (sec)110 P
Blind Switch Covers: All stations Yes
CHOKE MANIFOLD:Bottle Precharge: 1100 P
Quantity Test Result Nitgn. Bottles # & psi (Avg.): 5 @ 2050 P
No. Valves 16 P ACC Misc 0NA
Manual Chokes 1P
Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result
CH Misc 0NA Annular Preventer 24 P
#1 Rams 6 P
Coiled Tubing Only:#2 Rams 6 P
Inside Reel valves 0NA #3 Rams 6 P
#4 Rams 0 NA
Test Results #5 Rams 0 NA
#6 Rams 0 NA
Number of Failures:0 Test Time:6.5 HCR Choke 1 P
Repair or replacement of equipment will be made within days. HCR Kill 1 P
Remarks:
AOGCC Inspection
24 hr Notice Yes Date/Time 3-2-24 10:51PM
Waived By
Test Start Date/Time:3/6/2024 4:30
(date) (time)Witness
Test Finish Date/Time:3/6/2024 11:00
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Brian Bixby
Nabors
Test with 3 1/2" & 4" Joints. All alarms tested.
Tony Morales/ Paul Yearout
ConocoPhillips
Ron Phillips/ Seth Burson
KRU 3B-16
Test Pressure (psi):
tony.morales@nabors.com
nskrwo.cm@conocophillips.com
Form 10-424 (Revised 08/2022) 2024-0306_BOP_Nabors7ES_KRU_3B-16
9
9
9 9
9999
9
9
-5HJJ
1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown
Suspend Perforate Other Stimulate Pull Tubing Change Approved Program
Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing
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?
Yes No
9. Property Designation (Lease Number): 10. Field:
Kuparuk Oil Pool
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD):
7878'2827 None
Casing Collapse
Conductor
Surface
Production
Slotted 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:Elliott Tuttle
Contact Email:
Contact Phone: 907-263-4742
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
6678', 7245'6678' 5399'
1/8/2024
3-1/2"
Packer: Otis RRH
Packer: Otis WD Perm Packer
SSSV: Camco TRDP-1A
7858'
Perforation Depth MD (ft):
7385-7432', 7538-7574', 7592-
7627'
7835'
5919-5958', 6047-6077', 6093-
6123'
6325'7"
16"
9-5/8"
85'
3379'
117'
3270'
117'
3409'
J-55
TVD Burst
7481'
MD
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL 0025633
185-026
P.O. Box 100360, Anchorage, AK 99510 50-029-21289-00-00
ConocoPhillips Alaska, Inc
Proposed Pools:
AOGCC USE ONLY
Tubing Grade: Tubing MD (ft):
7224'MD and 5789' TVD
7457' MD and 5979'TVD
1827' MD and 1827' TVD
Perforation Depth TVD (ft):
Subsequent Form Required:
Suspension Expiration Date:
Will perfs require a spacing exception due to property boundaries?
Current Pools:
MPSP (psi):
17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval.
Authorized Name and
Digital Signature with Date:
Tubing Size:
PRESENT WELL CONDITION SUMMARY
Length
KRU 3B-16
Other:
N/A
Kuparuk River Field
elliott.tuttle@conocophillips.com
CTD/RWO Drilling Engineer
Size
Kuparuk Oil Pool
6341'
Plugs (MD):
Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
By Kayla Junke at 2:01 pm, Feb 02, 2024
324-046
Digitally signed by Elliott Tuttle
DN: OU=CTD/ RWO Senior Engineer, O=Conoco
Phillips, CN=Elliott Tuttle, E=elliott.tuttle@
conocophillips.com
Reason: I am the author of this document
Location:
Date: 2024.02.02 09:22:29-09'00'
Foxit PDF Editor Version: 13.0.0
Elliott Tuttle
1/8/2024
X
VTL 2/20/2024
Feb 02, 2024
BOP test to 3000 psig
Annular preventer test to 2500 psig.
10-404
X
Re-enter Susp Well
X
SFD 2/5/2024 DSR-2/13/24*&:JLC 2/21/2024
Brett W. Huber,
Sr.
Digitally signed by Brett W.
Huber, Sr.
Date: 2024.02.21 15:23:25 -09'00'02/21/24
RBDMS JSB 022324
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
February 1, 2024
Commissioner
State of Alaska
Alaska Oil & Gas Conservation
Commission
333 West 7th Avenue Suite 100
Anchorage, Alaska 99501
Dear Commissioner:
Elliott Tuttle
Senior Wells Engineer
CPAI Drilling and Wells
ConocoPhillips Alaska, Inc. hereby submits a application for a change of Sundry Approval to approved Sundry: 323-
664 (PTD# 185-026).
If you have any questions or require any further information, please contact me at +1-907-252-3347.
3B-16 has intermediate casing packoffs that will not test likely due to the internal casing packoffs and the design
limiting us from re-energizing the seals. This well/ pad is considered low risk for subsidence. Edits to the summary are
highlighted in red below.
Digitally signed by Elliott Tuttle
DN: OU=CTD/ RWO Senior
Engineer, O=Conoco Phillips, CN=
Elliott Tuttle, E=elliott.tuttle@
conocophillips.com
Reason: I am the author of this
document
Location:
Date: 2024.02.02
09:22:56
-09'00'
Foxit PDF Editor Version: 13.0.0
Elliott
Tuttle
3B-16A RWO Procedure
Kuparuk Injector
Sidetrack Setup
PTD #185-026
Page 1 of 2
Completed Pre-Rig Work
1. Perform Tubing Punch at 7240’ to 7243’ RKB (8/4/2023)
2. Perform Injectivity test at 1.6BPM at 1375psi, set Retainer at 7198’ RKB and pump cement to suspend 3B-16
(8/18/23)
3. Tag TOC at 6647’ SLM, MIT-T 2500psi, Passed (9/6/23)
4. Get a SBHP on 3B-15
Remaining Pre-Rig Work
5. Pull DV in Station 9 at 6348’ RKB
6. Perform tubing cut at 6632’ RKB
7. Ready well within 48Hrs on rig arrival
Rig Work
MIRU
1. MIRU Nabors 7ES on 3B-16. Circulate well over to 8.5ppg seawater.
2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete
30-minute NFT. Verify well is dead. Circulate KWF as needed.
3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/3,000 psi. Test annular 250/3,000
psi.
Retrieve Tubing, Set whipstock
4. Pull BPV, MU landing joint and BOLDS.
5. Pull 3-1/2” tubing down to cut (~6632’ RKB).
6. Grow and stretch of 7” production casing: set plug/ storm packer near surface, pressure test plug. ND to casing
head and let grow (if at all), pull 7” casing and re-land slips and PO, nipple up new tubing spool and BOP’s, test
flange break and IC packoffs.
7. Retrieve shallow set plug/ storm packer.
8. Drift/ clean out casing down to tubing cut.
9. Set Whipstock at 6613’ RKB TOWS oriented high side.
a. TOC in 7” estimated @ 6300’ RKB
Subsequent work to mill window and drill the 3B-16A sidetrack is covered in the Permit to Drill that will be submitted
in parallel.
3B-16A RWO Procedure
Kuparuk Injector
Sidetrack Setup
PTD #185-026
Page 2 of 2
General Well info:
Wellhead type/pressure rating: FMC Gen 3 Wellhead, 3K rated casing flange
Production Engineer: Brian Lewis
Reservoir Development Engineer: Lynn Aleshire
Estimated Start Date: 2/15/24
Workover Engineer: Elliott Tuttle (907 252-3347/ Elliott.tuttle@conocophillips.com)
Current Operations: This well is currently shut in.
Well Type: Injector
Scope of Work: Pull the existing 3-1/2” completion down to pre rig cut, install new IC Packoffs, set whipstock in
preparation to drill 3B-16A lateral
BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram
Following subject to change/be updated with pre-rig work:
MIT results:
MIT-T Passed
MIT-IA – Passed to 3000psi 10/31/23
MIT-OA Passed to 1800psi 10/9/23
IC POT &PPPOT Ongoing – 10/31/23 (deemed as need replaced)
TBG POT &PPPOT PASSED – 10/8/23
MPSP: 2,827 psi using 0.1 psi/ft gradient
Static BHP: 3419 psi/ 5920’ TVD (measured 8/16/19) Plan to get updated pressure on neighboring producer, 3B-15
(shut in since 10/3/23, 3425psi/ 5903’ TVD (measured 12/11/23)
3B-16 Proposed RWO-ST Completion
COMPLETION
INFO
MD
(ft RKB)
TVD
(ft RKB)
OD
(in)
Nom. ID
(in)
Weight
(lb/ft)Grade Thread
(top)
Thread
(btm)
Conductor 117 117 16 15.06 62.5 H-40 Welded Welded
Surface 3409 3270 9.625 8.92 36 J-55 BTC BTC
Production/
Intermediate 7858 6325 7 6.276 26 J-55 BTC BTC
Liner 8000 6157 3.5 2.99 9.3 L-80 Hyd563 Hyd563
Tubing 6670 5393 3.5 2.99 9.3 L-80 Hyd563 Hyd563
PROPOSED COMPLETION
3-1/2" 9.3# L-80 HYD563 Tubing to surface
(2 Each) 3-1/2" Baker BGLO-1.0RCT Monotrip GLM @
TBD
3 1/2" HP Defender @ XXXX RKB (2.813" ID)
3.5" x 7.0" Packer @ xxxx' RKB (4" ID)
3-½" X landing nipple at xxxx' RKB (2.813" min ID)
3-1/2" Landing Collar
3 1/2" Float Collar
3 1/2" Float Shoe
REMAINING COMPLETION LEFT IN HOLE
Planned tubing cut @ 6632' RKB
3.5" x 7.0" Packer (7224' RKB)
GLM
Blast Rings
GLM
3.5" x 7.0" Packer (7460' RKB)
2.75" D-Nipple (7472' RKB)
WLEG
Surface Casing
Production
Casing
Conductor
A-sand
perfs
C-sand
Perfs
KOP @ 6613' MD
(5357' TVDSS)
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag: SLM 7,641.0 3B-16 9/13/2011 ninam
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Set Cmt Retainer/Pump 33 bbls 15.8 ppg Cement. 3B-16 8/18/2023 appleha
Notes: General & Safety
Annotation End Date Last Mod By
NOTE: View Schematic w/ Alaska Schematic9.0 7/7/2010 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 32.0 117.0 117.0 62.50 H-40 WELDED
SURFACE 9 5/8 8.92 30.2 3,409.3 3,269.8 36.00 J-55 BTC
PRODUCTION 7 6.28 23.7 7,858.4 6,325.2 26.00 J-55 BTC
Tubing Strings: string max indicates LONGEST segment of string
Top (ftKB)
23.7
Set Depth …
7,480.6
Set Depth …
5,998.6
String Ma…
3 1/2
Tubing Description
TUBING
Wt (lb/ft)
9.30
Grade
J-55
Top Connection
EUE 8RD
ID (in)
2.99
Completion Details: excludes tubing, pup, space out, thread, RKB...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal
ID (in)
23.7 23.7 0.01 HANGER 8.000 FMC GEN III TUBING HANGER PARKE
R
141 3.500
1,827.5 1,827.4 1.74 SAFETY VLV 5.937 CAMCO TRDP-1A CAMCO TRDP-
1A
2.810
1,848.8 1,848.7 2.30 GAS LIFT 5.620 MERLA TMPD 2.937
3,066.1 2,998.5 32.49 GAS LIFT 5.620 MERLA TMPD 2.937
4,060.7 3,717.3 46.76 GAS LIFT 5.620 MERLA TMPD 2.937
4,614.7 4,089.3 48.72 GAS LIFT 5.620 MERLA TMPD 2.937
4,937.6 4,299.0 50.07 GAS LIFT 5.620 MERLA TMPD 2.937
5,250.4 4,500.8 49.69 GAS LIFT 5.620 MERLA TMPD 2.937
5,572.7 4,709.0 49.68 GAS LIFT 5.620 MERLA TMPD 2.937
5,880.9 4,908.6 49.71 GAS LIFT 5.620 MERLA TMPD 2.937
6,348.5 5,198.4 54.18 GAS LIFT 5.620 MERLA TMPD 2.937
6,821.0 5,494.0 47.03 GAS LIFT 5.620 MERLA TMPD 2.937
7,170.0 5,747.0 39.29 GAS LIFT 5.620 MERLA TPDX 2.937
7,215.3 5,782.4 38.05 SBR 4.000 OTIS SEAL BORE RECEPTACLE OTIS 3.000
7,224.3 5,789.5 37.83 PACKER 5.980 OTIS RRH RETRIEVABLE
PACKER
OTIS RRH 2.969
7,373.3 5,909.8 34.92 BLAST RING 3.500 BLAST RINGS (2) 2.992
7,456.3 5,978.3 33.72 LOCATOR 5.060 OTIS STRAIGHT SLOT TYPE
LOCATOR
OTIS 3.000
7,456.9 5,978.8 33.71 PACKER 6.156 OTIS WD PERMANENT PACKER OTIS WD 4.000
7,460.2 5,981.6 33.66 SBE 3.500 OTIS SEAL BORE EXTENSION OTIS 3.000
7,471.9 5,991.3 33.49 NIPPLE 4.520 CAMCO D NIPPLE NO GO CAMCO D 2.750
7,479.4 5,997.6 33.38 WLEG 4.000 OTIS WIRELINE ENTRY GUIDE OTIS 3.000
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top (ftKB)
Top (TVD)
(ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in)
7,170.0 5,747.1 39.29 LEAK -
TUBING
Found tbg leak w/ Relay LDL
11/28/21
11/28/2021 0.000
7,195.0 5,766.5 38.57 CEMENT
RETAINER
SET 3.5" FH-1 CEMENT
RETAINER AT 7195' RKB
FH1 005-
2725-
500
8/18/2023 0.000
7,240.0 5,802.0 37.44 TUBING
PUNCH
3 FT OF TUBING PUNCHES
(4 SPF)
8/4/2023 2.992
7,245.0 5,805.9 37.31 RBP Set RBP (OAL 9.03') TTS CPP3
5281/
CPEQ
35001
11/4/2021 0.000
7,245.0 5,805.9 37.31 OTHER Set 3.5" TTS pulling tool w/
Multiple Fish G-Necks (Top
Fish neck is 2.31" & Bottom
Fish neck 1.81") 19" OAL
2/4/2022 0.000
7,255.0 5,813.9 37.07 PATCH 21.5' Merla TBG PATCH; Set
across GLM #12 on 11/30/95/
w/ AVA Nipple 4' Below Top of
GLM
11/30/1995 2.313
7,260.9 5,818.6 36.92 SLEEVE-O 2.31" AVA CIC SLEEVE
(OAL=13")
9/13/2011 1.860
7,328.0 5,872.8 35.56 PATCH 21.5' Merla TBG PATCH; Set
across GLM #13 on 11/30/95
11/30/1995 2.375
7,471.9 5,991.3 33.49 NIPPLE
REDUCER
Set Nipple Reducer w/ 1.81" D
Profile; Set on 11/29/95
11/29/1995 1.813
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)
1,848.8 1,848.7 2.30 1 GAS LIFT DMY BK 1 0.0 5/20/1985 0.000
3,066.1 2,998.5 32.49 2 GAS LIFT DMY BK 1 0.0 5/20/1985 0.000
4,060.7 3,717.3 46.76 3 GAS LIFT DMY BK 1 0.0 5/20/1985 0.000
4,614.7 4,089.3 48.72 4 GAS LIFT DMY BK 1 0.0 5/20/1985 0.000
4,937.6 4,299.0 50.07 5 GAS LIFT DMY BK 1 0.0 5/20/1985 0.000
5,250.4 4,500.8 49.69 6 GAS LIFT DMY BK 1 0.0 5/20/1985 0.000
5,572.7 4,709.0 49.68 7 GAS LIFT DMY BK 1 0.0 5/20/1985 0.000
5,880.9 4,908.6 49.71 8 GAS LIFT DMY BK 1 0.0 5/20/1985 0.000
6,348.5 5,198.4 54.18 9 GAS LIFT DMY BK 1 0.0 5/20/1985 0.000
6,821.0 5,494.0 47.03 1
0
GAS LIFT DMY BK 1 0.0 5/20/1985 0.000
7,170.0 5,747.0 39.29 1
1
GAS LIFT DMY RM 1 1/2 0.0 11/8/2021 0.000
7,260.9 5,818.6 36.92 1
2
INJ PATCH 0 1 1/2 0.0 11/30/1995 0.000
7,332.9 5,876.8 35.49 1
3
INJ PATCH 0 1 1/2 0.0 11/30/1995 0.000
7,436.8 5,962.2 34.01 1
4
INJ DMY RM 1 1/2 0.0 11/15/1995 0.000
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
7,385.0 7,432.0 5,919.4 5,958.2 C-3, C-2, C-1,
3B-16
5/18/1985 12.0 IPERF 5" Scalloped Csg Gun; 120
deg. ph7,538.0 7,574.0 6,046.8 6,077.3 A-4, A-3, 3B-16 5/18/1985 4.0 IPERF 4" Carrier JJ II; 120 deg. ph
7,592.0 7,627.0 6,092.6 6,122.6 A-2, 3B-16 5/18/1985 4.0 IPERF 4" Carrier JJ II; 120 deg. ph
Cement Squeezes
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Des Com
Pump Start
Date
6,851.0 7,245.0 5,514.6 5,805.9 Cement Plug 30 BBLS 15.8 PPG CEMENT PUMPED THROUGH
RETAINER. INTO C-SANDS.
8/17/2023
7,238.0 7,456.0 5,800.4 5,978.1 Cement
Squeeze
30 BBLS 15.8 PPG CEMENT PUMPED THROUGH
RETAINER AND INTO THE C-SANDS.
8/18/2023
3B-16, 8/18/2023 5:12:49 PM
Vertical schematic (actual)
PRODUCTION; 23.7-7,858.4
FLOAT SHOE; 7,856.8-7,858.4
FLOAT COLLAR; 7,768.3-7,769.8
IPERF; 7,592.0-7,627.0
IPERF; 7,538.0-7,574.0
WLEG; 7,479.4
NIPPLE REDUCER; 7,471.9
NIPPLE; 7,471.9
SBE; 7,460.2
PACKER; 7,456.9
LOCATOR; 7,456.3
INJECTION; 7,436.8
IPERF; 7,385.0-7,432.0
PATCH; 7,328.0
INJECTION; 7,332.9
PATCH; 7,255.0
INJECTION; 7,260.9
SLEEVE-O; 7,260.9
RBP; 7,245.0
OTHER; 7,245.0
TUBING PUNCH; 7,240.0
Cement Squeeze; 7,238.0 ftKB
PACKER; 7,224.3
SBR; 7,215.3
CEMENT RETAINER; 7,195.0
GAS LIFT; 7,170.0
LEAK - TUBING; 7,170.0
Cement Plug; 6,851.0 ftKB
GAS LIFT; 6,821.0
GAS LIFT; 6,348.5
GAS LIFT; 5,880.9
GAS LIFT; 5,572.7
GAS LIFT; 5,250.4
GAS LIFT; 4,937.6
GAS LIFT; 4,614.7
GAS LIFT; 4,060.7
SURFACE; 30.2-3,409.3
FLOAT SHOE; 3,407.7-3,409.3
FLOAT COLLAR; 3,319.0-3,320.6
GAS LIFT; 3,066.1
GAS LIFT; 1,848.8
SAFETY VLV; 1,827.5
CONDUCTOR; 32.0-117.0
HANGER; 30.2-35.1
HANGER; 23.7
KUP INJ
KB-Grd (ft)
35.98
RR Date
4/7/1985
Other Elev…
3B-16
...
TD
Act Btm (ftKB)
7,878.0
Well Attributes
Field Name
KUPARUK RIVER UNIT
Wellbore API/UWI
500292128900
Wellbore Status
INJ
Max Angle & MD
Incl (°)
54.45
MD (ftKB)
6,400.00
WELLNAME WELLBORE3B-16
Annotation
Last WO:
End DateH2S (ppm) DateComment
SSSV: TRDP
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
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?
Yes No
9. Property Designation (Lease Number): 10. Field:
Kuparuk Oil Pool
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD):
7878'2827 None
Casing Collapse
Conductor
Surface
Production
Slotted 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:Elliott Tuttle
Contact Email:
Contact Phone: 907-263-4742
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
KRU 3B-16
Other:
N/A
Kuparuk River Field
elliott.tuttle@conocophillips.com
CTD/RWO Drilling Engineer
Size
Kuparuk Oil Pool
6341'
Plugs (MD):
Subsequent Form Required:
Suspension Expiration Date:
Will perfs require a spacing exception due to property boundaries?
Current Pools:
MPSP (psi):
17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval.
Authorized Name and
Digital Signature with Date:
Tubing Size:
PRESENT WELL CONDITION SUMMARY
Length
AOGCC USE ONLY
Tubing Grade: Tubing MD (ft):
7224'MD and 5789' TVD
7457' MD and 5979'TVD
1827' MD and 1827' TVD
SSSV: 8127'MD/3623'TVD
Perforation Depth TVD (ft):
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL 0025633
185-026
P.O. Box 100360, Anchorage, AK 99510 50-029-21289-00-00
ConocoPhillips Alaska, Inc
Proposed Pools:
J-55
TVD Burst
7481'
MD
117'
3270'
117'
3409'
16"
9-5/8"
85'
3379'
Perforation Depth MD (ft):
7385-7432', 7538-7574', 7592-
7627'
7835'
5919-5958', 6047-6077', 6093-
6123'
6325'7"
6678', 7245'6678' 5399'
1/8/2024
3-1/2"
Packer: Otis RRH
Packer: Otis WD
SSSV: Camco TRDP-1A
7858'
Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
By Grace Christianson at 4:13 pm, Dec 12, 2023
Digitally signed by Elliott Tuttle
DN: OU=CTD/ RWO Senior Engineer
, O=Conoco Phillips, CN=Elliott Tuttle
, E=elliott.tuttle@conocophillips.com
Reason: I am the author of this
document
Location:
Date: 2023.12.12 15:29:28-09'00'
Foxit PDF Editor Version: 13.0.0
Elliott
Tuttle
323-664
X
BOP test to 3000 psig
Annular preventer test to 2500 psig
SFD 12/20/2023VTL 01/03/2024
Re-enter Susp Well
X
DSR-12/14/23
10-407
*&:JLC 1/3/2024
Brett W. Huber, Sr.Digitally signed by Brett W. Huber,
Sr.
Date: 2024.01.03 15:21:21 -09'00'01/03/24
RBDMS JSB 010424
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
December 12, 2023
Commissioner
State of Alaska
Alaska Oil & Gas Conservation
Commission
333 West 7th Avenue Suite 100
Anchorage, Alaska 99501
Dear Commissioner:
Elliott Tuttle
Senior Wells Engineer
CPAI Drilling and Wells
ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Injector (PTD# 185-
026).
Well 3B-16 was drilled and completed in April 1985 Parker 141 drilled surface and production hole, cased and
cemented. well was Arctic Packed at this time and a CBL was pulled. Roll'n 4 rigged up in May to perf the A&C sands
and run the 3 1/2" upper completion. The well was then frac'd in June. By decemeber, 3B-16 was swapped to a water
injector. September 2001 the well was put on EOR injection. Due to a plug set in the selective part of this completion
and unable to be removed, the well will be worked over to support a slant well, 3B-16A, be drilled above the
completion issues to obtain the same pool but only target the Kuparuk A sand.
If you have any questions or require any further information, please contact me at +1-907-252-3347.
After a suspension of 3B-16 on a previously approved form 10-403 (sundry # 323-333), the tubing will be pulled,
whipstock set. A permit to drill will be submitted separately to drill a short slant well to reacquire the Kuparuk A-
sand. A cemented liner and upper completion will be landed, CBL will be run and the A sand will be re-acquired post
rig by way of e-line.
Digitally signed by Elliott Tuttle
DN: OU=CTD/ RWO Senior
Engineer, O=Conoco Phillips,
CN=Elliott Tuttle, E=elliott.tuttle
@conocophillips.com
Reason: I am the author of this
document
Location:
Date: 2023.12.12
15:29:52
-09'00'
Foxit PDF Editor Version: 13.0.0
Elliott
Tuttle
3B-16A RWO Procedure
Kuparuk Injector
Sidetrack Setup
PTD #185-026
Page 1 of 2
Completed Pre-Rig Work
1. Perform Tubing Punch at 7240’ to 7243’ RKB (8/4/2023)
2. Perform Injectivity test at 1.6BPM at 1375psi, set Retainer at 7198’ RKB and pump cement to suspend 3B-16
(8/18/23)
3. Tag TOC at 6647’ SLM, MIT-T 2500psi, Passed (9/6/23)
4. Get a SBHP on 3B-15
Remaining Pre-Rig Work
5. Pull DV in Station 9 at 6348’ RKB
6. Perform tubing cut at 6632’ RKB
7. Ready well within 48Hrs on rig arrival
Rig Work
MIRU
1. MIRU Nabors 7ES on 3B-16. Circulate well over to 8.5ppg seawater.
2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete
30-minute NFT. Verify well is dead. Circulate KWF as needed.
3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/3,000 psi. Test annular 250/3,000
psi.
Retrieve Tubing, Set whipstock
4. Pull BPV, MU landing joint and BOLDS.
5. Pull 3-1/2” tubing down to cut (~6632’ RKB).
6. Set Whipstock at 6613’ RKB TOWS oriented high side.
a. TOC in 7” estimated @ 6300’ RKB
Subsequent work to mill window and drill the 2M-24A sidetrack is covered in the Permit to Drill that will be submitted
in parallel.
3B-16A RWO Procedure
Kuparuk Injector
Sidetrack Setup
PTD #185-026
Page 2 of 2
General Well info:
Wellhead type/pressure rating: FMC Gen 3 Wellhead, 3K rated casing flange
Production Engineer: Brian Lewis
Reservoir Development Engineer: Lynn Aleshire
Estimated Start Date: 1/8/24
Workover Engineer: Elliott Tuttle (907 252-3347/ Elliott.tuttle@conocophillips.com)
Current Operations: This well is currently shut in.
Well Type: Injector
Scope of Work: Pull the existing 3-1/2” completion down to pre rig cut, set whipstock in preparation to drill 3B-16A
lateral
BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram
Following subject to change/be updated with pre-rig work:
MIT results:
MIT-T Passed
MIT-IA – Passed to 3000psi 10/31/23
MIT-OA Passed to 1800psi 10/9/23
IC POT &PPPOT passed – 10/31/23
TBG POT &PPPOT PASSED – 10/8/23
MPSP: 2,827 psi using 0.1 psi/ft gradient
Static BHP: 3419 psi/ 5920’ TVD (measured 8/16/19) Plan to get updated pressure on neighboring producer, 3B-15
(shut in since 10/3/23, 3425psi/ 5903’ TVD (measured 12/11/23)
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag: SLM 7,641.0 3B-16 9/13/2011 ninam
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Set Cmt Retainer/Pump 33 bbls 15.8 ppg Cement. 3B-16 8/18/2023 appleha
Notes: General & Safety
Annotation End Date Last Mod By
NOTE: View Schematic w/ Alaska Schematic9.0 7/7/2010 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 32.0 117.0 117.0 62.50 H-40 WELDED
SURFACE 9 5/8 8.92 30.2 3,409.3 3,269.8 36.00 J-55 BTC
PRODUCTION 7 6.28 23.7 7,858.4 6,325.2 26.00 J-55 BTC
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
23.7
Set Depth …
7,480.6
String Max No…
3 1/2
Set Depth …
5,998.6
Tubing Description
TUBING
Wt (lb/ft)
9.30
Grade
J-55
Top Connection
EUE 8RD
ID (in)
2.99
Completion Details: excludes tubing, pup, space out, thread, RKB...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal
ID (in)
23.7 23.7 0.01 HANGER 8.000 FMC GEN III TUBING HANGER PARKE
R
141 3.500
1,827.5 1,827.4 1.74 SAFETY VLV 5.937 CAMCO TRDP-1A CAMCO TRDP-
1A
2.810
1,848.8 1,848.7 2.30 GAS LIFT 5.620 MERLA TMPD 2.937
3,066.1 2,998.5 32.49 GAS LIFT 5.620 MERLA TMPD 2.937
4,060.7 3,717.3 46.76 GAS LIFT 5.620 MERLA TMPD 2.937
4,614.7 4,089.3 48.72 GAS LIFT 5.620 MERLA TMPD 2.937
4,937.6 4,299.0 50.07 GAS LIFT 5.620 MERLA TMPD 2.937
5,250.4 4,500.8 49.69 GAS LIFT 5.620 MERLA TMPD 2.937
5,572.7 4,709.0 49.68 GAS LIFT 5.620 MERLA TMPD 2.937
5,880.9 4,908.6 49.71 GAS LIFT 5.620 MERLA TMPD 2.937
6,348.5 5,198.4 54.18 GAS LIFT 5.620 MERLA TMPD 2.937
6,821.0 5,494.0 47.03 GAS LIFT 5.620 MERLA TMPD 2.937
7,170.0 5,747.0 39.29 GAS LIFT 5.620 MERLA TPDX 2.937
7,215.3 5,782.4 38.05 SBR 4.000 OTIS SEAL BORE RECEPTACLE OTIS 3.000
7,224.3 5,789.5 37.83 PACKER 5.980 OTIS RRH RETRIEVABLE
PACKER
OTIS RRH 2.969
7,260.9 5,818.6 36.92 INJECTION 5.960 MERLA TPDX 2.875
7,332.9 5,876.8 35.49 INJECTION 5.960 MERLA TPDX 2.875
7,373.3 5,909.8 34.92 BLAST RING 3.500 BLAST RINGS (2) 2.992
7,436.8 5,962.2 34.01 INJECTION 5.960 MERLA TPDX 2.875
7,456.3 5,978.3 33.72 LOCATOR 5.060 OTIS STRAIGHT SLOT TYPE
LOCATOR
OTIS 3.000
7,456.9 5,978.8 33.71 PACKER 6.156 OTIS WD PERMANENT PACKER OTIS WD 4.000
7,460.2 5,981.6 33.66 SBE 3.500 OTIS SEAL BORE EXTENSION OTIS 3.000
7,471.9 5,991.3 33.49 NIPPLE 4.520 CAMCO D NIPPLE NO GO CAMCO D 2.750
7,479.4 5,997.6 33.38 WLEG 4.000 OTIS WIRELINE ENTRY GUIDE OTIS 3.000
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top (ftKB)
Top (TVD)
(ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in)
7,170.0 5,747.1 39.29 LEAK -
TUBING
Found tbg leak w/ Relay LDL
11/28/21
11/28/2021 0.000
7,195.0 5,766.5 38.57 CEMENT
RETAINER
SET 3.5" FH-1 CEMENT
RETAINER AT 7195' RKB
FH1 005-
2725-
500
8/18/2023 0.000
7,240.0 5,802.0 37.44 TUBING
PUNCH
3 FT OF TUBING PUNCHES
(4 SPF)
8/4/2023 2.992
7,245.0 5,805.9 37.31 RBP Set RBP (OAL 9.03') TTS CPP3
5281/
CPEQ
35001
11/4/2021 0.000
7,245.0 5,805.9 37.31 OTHER Set 3.5" TTS pulling tool w/
Multiple Fish G-Necks (Top
Fish neck is 2.31" & Bottom
Fish neck 1.81") 19" OAL
2/4/2022 0.000
7,255.0 5,813.9 37.07 PATCH 21.5' Merla TBG PATCH; Set
across GLM #12 on 11/30/95/
w/ AVA Nipple 4' Below Top of
GLM
11/30/1995 2.313
7,260.9 5,818.6 36.92 SLEEVE-O 2.31" AVA CIC SLEEVE
(OAL=13")
9/13/2011 1.860
7,328.0 5,872.8 35.56 PATCH 21.5' Merla TBG PATCH; Set
across GLM #13 on 11/30/95
11/30/1995 2.375
7,471.9 5,991.3 33.49 NIPPLE
REDUCER
Set Nipple Reducer w/ 1.81" D
Profile; Set on 11/29/95
11/29/1995 1.813
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)
1,848.8 1,848.7 2.30 1 GAS LIFT DMY BK 1 0.0 5/20/1985 0.000
3,066.1 2,998.5 32.49 2 GAS LIFT DMY BK 1 0.0 5/20/1985 0.000
4,060.7 3,717.3 46.76 3 GAS LIFT DMY BK 1 0.0 5/20/1985 0.000
4,614.7 4,089.3 48.72 4 GAS LIFT DMY BK 1 0.0 5/20/1985 0.000
3B-16, 12/12/2023 2:48:32 PM
Vertical schematic (actual)
PRODUCTION; 23.7-7,858.4
IPERF; 7,592.0-7,627.0
IPERF; 7,538.0-7,574.0
NIPPLE REDUCER; 7,471.9
PACKER; 7,456.9
INJECTION; 7,436.8
IPERF; 7,385.0-7,432.0
PATCH; 7,328.0
INJECTION; 7,332.9
PATCH; 7,255.0
INJECTION; 7,260.9
SLEEVE-O; 7,260.9
RBP; 7,245.0
OTHER; 7,245.0
TUBING PUNCH; 7,240.0
Cement Squeeze; 7,238.0 ftKB
PACKER; 7,224.3
CEMENT RETAINER; 7,195.0
GAS LIFT; 7,170.0
LEAK - TUBING; 7,170.0
GAS LIFT; 6,821.0
Cement Plug; 6,678.0 ftKB
GAS LIFT; 6,348.5
GAS LIFT; 5,880.9
GAS LIFT; 5,572.7
GAS LIFT; 5,250.4
GAS LIFT; 4,937.6
GAS LIFT; 4,614.7
GAS LIFT; 4,060.7
SURFACE; 30.2-3,409.3
GAS LIFT; 3,066.1
GAS LIFT; 1,848.8
SAFETY VLV; 1,827.5
CONDUCTOR; 32.0-117.0
KUP INJ
KB-Grd (ft)
35.98
RR Date
4/7/1985
Other Elev…
3B-16
...
TD
Act Btm (ftKB)
7,878.0
Well Attributes
Field Name
KUPARUK RIVER UNIT
Wellbore API/UWI
500292128900
Wellbore Status
INJ
Max Angle & MD
Incl (°)
54.45
MD (ftKB)
6,400.00
WELLNAME WELLBORE3B-16
Annotation
Last WO:
End DateH2S (ppm) DateComment
SSSV: TRDP
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)
4,937.6 4,299.0 50.07 5 GAS LIFT DMY BK 1 0.0 5/20/1985 0.000
5,250.4 4,500.8 49.69 6 GAS LIFT DMY BK 1 0.0 5/20/1985 0.000
5,572.7 4,709.0 49.68 7 GAS LIFT DMY BK 1 0.0 5/20/1985 0.000
5,880.9 4,908.6 49.71 8 GAS LIFT DMY BK 1 0.0 5/20/1985 0.000
6,348.5 5,198.4 54.18 9 GAS LIFT DMY BK 1 0.0 5/20/1985 0.000
6,821.0 5,494.0 47.03 1
0
GAS LIFT DMY BK 1 0.0 5/20/1985 0.000
7,170.0 5,747.0 39.29 1
1
GAS LIFT DMY RM 1 1/2 0.0 11/8/2021 0.000
7,260.9 5,818.6 36.92 1
2
INJ PATCH 0 1 1/2 0.0 11/30/1995 0.000
7,332.9 5,876.8 35.49 1
3
INJ PATCH 0 1 1/2 0.0 11/30/1995 0.000
7,436.8 5,962.2 34.01 1
4
INJ DMY RM 1 1/2 0.0 11/15/1995 0.000
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
7,385.0 7,432.0 5,919.4 5,958.2 C-3, C-2, C-1,
3B-16
5/18/1985 12.0 IPERF 5" Scalloped Csg Gun; 120
deg. ph
7,538.0 7,574.0 6,046.8 6,077.3 A-4, A-3, 3B-16 5/18/1985 4.0 IPERF 4" Carrier JJ II; 120 deg. ph
7,592.0 7,627.0 6,092.6 6,122.6 A-2, 3B-16 5/18/1985 4.0 IPERF 4" Carrier JJ II; 120 deg. ph
Cement Squeezes
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Des Com
Pump Start
Date
6,678.0 7,245.0 5,399.1 5,805.9 Cement Plug 31 BBLS 15.8 PPG CEMENT PUMPED THROUGH
RETAINER. INTO C-SANDS.
8/18/2023
7,238.0 7,456.0 5,800.4 5,978.1 Cement
Squeeze
31 BBLS 15.8 PPG CEMENT PUMPED THROUGH
RETAINER AND INTO THE C-SANDS.
8/18/2023
3B-16, 12/12/2023 2:48:33 PM
Vertical schematic (actual)
PRODUCTION; 23.7-7,858.4
IPERF; 7,592.0-7,627.0
IPERF; 7,538.0-7,574.0
NIPPLE REDUCER; 7,471.9
PACKER; 7,456.9
INJECTION; 7,436.8
IPERF; 7,385.0-7,432.0
PATCH; 7,328.0
INJECTION; 7,332.9
PATCH; 7,255.0
INJECTION; 7,260.9
SLEEVE-O; 7,260.9
RBP; 7,245.0
OTHER; 7,245.0
TUBING PUNCH; 7,240.0
Cement Squeeze; 7,238.0 ftKB
PACKER; 7,224.3
CEMENT RETAINER; 7,195.0
GAS LIFT; 7,170.0
LEAK - TUBING; 7,170.0
GAS LIFT; 6,821.0
Cement Plug; 6,678.0 ftKB
GAS LIFT; 6,348.5
GAS LIFT; 5,880.9
GAS LIFT; 5,572.7
GAS LIFT; 5,250.4
GAS LIFT; 4,937.6
GAS LIFT; 4,614.7
GAS LIFT; 4,060.7
SURFACE; 30.2-3,409.3
GAS LIFT; 3,066.1
GAS LIFT; 1,848.8
SAFETY VLV; 1,827.5
CONDUCTOR; 32.0-117.0
KUP INJ 3B-16
...
WELLNAME WELLBORE3B-16
3B-16 Proposed RWO-ST Completion
COMPLETION
INFO
MD
(ft RKB)
TVD
(ft RKB)
OD
(in)
Nom. ID
(in)
Weight
(lb/ft)Grade Thread
(top)
Thread
(btm)
Conductor 117 117 16 15.06 62.5 H-40 Welded Welded
Surface 3409 3270 9.625 8.92 36 J-55 BTC BTC
Production/
Intermediate 7858 6325 7 6.276 26 J-55 BTC BTC
Liner 8000 6157 3.5 2.99 9.3 L-80 Hyd563 Hyd563
Tubing 6670 5393 3.5 2.99 9.3 L-80 Hyd563 Hyd563
PROPOSED COMPLETION
3-1/2" 9.3# L-80 HYD563 Tubing to surface
(2 Each) 3-1/2" Baker BGLO-1.0RCT Monotrip GLM @
TBD
3 1/2" HP Defender @ XXXX RKB (2.813" ID)
3.5" x 7.0" Packer @ xxxx' RKB (4" ID)
3-½" X landing nipple at xxxx' RKB (2.813" min ID)
3-1/2" Landing Collar
3 1/2" Float Collar
3 1/2" Float Shoe
REMAINING COMPLETION LEFT IN HOLE
Planned tubing cut @ 6632' RKB
3.5" x 7.0" Packer (7224' RKB)
GLM
Blast Rings
GLM
3.5" x 7.0" Packer (7460' RKB)
2.75" D-Nipple (7472' RKB)
WLEG
Surface Casing
Production
Casing
Conductor
A-sand
perfs
C-sand
Perfs
KOP @ 6613' MD
(5357' TVDSS)
1a. Well Status:SuspendedAbandonedOtherSPLUGOil 1b. Well Class:
20AAC 25.11020AAC 25.105 ExploratoryDevelopment
WDSPLGINJ WINJ No. of Completions: ___________________Stratigraphic TestService
14. Permit to Drill Number / Sundry:6. Date Comp., Susp., or2. Operator Name:
Aband.:
15. API Number:7. Date Spudded:3. Address:
16. Well Name and Number:8. Date TD Reached:4a. Location of Well (Governmental Section):
Surface:
17. Field / Pool(s):9. Ref Elevations: KB:Top of Productive Interval:
GL: BF:
10. Plug Back Depth MD/TVD: 18. Property Designation:Total Depth:
11. Total Depth MD/TVD: 19. DNR Approval Number:4b. Location of Well (State Base Plane Coordinates, NAD 27):
Zone- 4y-x-Surface:
20. Thickness of Permafrost MD/TVD:12. SSSV Depth MD/TVD:Zone- 4y-x-TPI:
Zone- 4y-x-Total Depth:
5. Directional or Inclination Survey: Yes (attached) No 21. Re-drill/Lateral Top Window MD/TVD:13. Water Depth, if Offshore:
Submit electronic information per 20 AAC 25.050 N/A (ft MSL)
22. Logs Obtained:
23.
BOTTOM
117'H-4016"
3270'J-559-5/8"
6325'J-557"
25.NoYes24. Open to production or injection?
26.
NoYesWas hydraulic fracturing used during completion?
DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED
27.
Method of Operation (Flowing, gas lift, etc.):Date First Production:
Gas-MCF:Production forHours Tested:
Test Period
Oil Gravity - API (corr):Gas-MCF:CalculatedCasing Press:
Press. 24-Hour Rate
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
CASING, LINER AND CEMENTING RECORD
List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion,
TUBING RECORD
375 sx Class G, 250 sx AS I8-1/2"
7457' MD/ 5979' TVD
7481'3-1/2"
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
ConocoPhillips Alaska, Inc.
WAG
Gas
185-026/ 323-3339/6/2023
50-029-21289-00-00
KRU 3B-16
ADL0025633
228' FSL, 802' FEL, Sec. 16, T12N, R9E, UM
1702' FNL, 1254' FWL, Sec. 21, T12N, R9E, UM
ALK 2566
3/31/1985
7878' MD/ 6341' TVD
85'
P.O. Box 100360, Anchorage, AK 99510-0360
5991348518231
1674' FNL, 1299' FWL, Sec. 21. T12N, R9E, UM
CASING WT. PER
FT.GRADE
4/6/1985
CEMENTING RECORD
5989439
1600' MD/ 1600' TVD
SETTING DEPTH TVD
5989412
TOP HOLE SIZE AMOUNT
PULLED
515061
515017
TOP
SETTING DEPTH MD
suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log,
spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar
locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary.
N/A
BOTTOM
7224 MD/ 5789' TVD
PACKER SET (MD/TVD)
24"
12-1/4"
265 sx PF "C"
30'920 sx AS III, 360 sx Class G
32'
3409'30'
32'
Kuparuk River Field/ Kuparuk River Oil Pool
Flow Tubing
Plugged for Redrill
Gas-Oil Ratio:Choke Size:
Per 20 AAC 25.283 (i)(2) attach electronic information
24'26.0#
62.5#
36.0#
117'
24'
Sr Res EngSr Pet GeoSr Pet Eng
1827' MD/ 1827' TVD
Water-Bbl:Oil-Bbl:
Water-Bbl:
PRODUCTION TEST
N/A
Oil-Bbl:Date of Test:
7858'
DEPTH SET (MD)SIZE
Due within 30 days of Completion, Suspension, or AbandonmentForm 10-407 Revised 10/2022
6678-7245' 31 bbls 15.8 ppg Cement thru retainer into C-Sands
7238-7456' 31 bbls 15.8 ppg Cement thru retainer into C-Sands
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size
and Number; Date perf'd or liner run):
7385-7432', 7538-7574', 7592-7627' MD (Cemented) and
5919-5958', 6047-6077', 6093-6123' TVD (Cemented)
6678' MD/ 5399' TVD
CCL
asing collar
locator
6678' MD/ 5399' TVD
3409
7858 250 sx AS I
31
31
7432
C-Sands7238-7456'
6678-
By Grace Christianson at 3:02 pm, Dec 07, 2023
Suspended
9/6/2023
JSB
RBDMS JSB 122123
xGDSR-1/29/24JJL 12/02/24
Conventional Core(s): Yes No Sidewall Cores:
N/A
30.
MD TVD
Surface Surface
1600' 1600'
Top of Productive Interval
N/A
31. List of Attachments: Schematics, Summary of Operations
32. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Digital Signature with Date:
General:
Item 1a:
Item 1b:
Item 4b:
Item 9:
Item 15:
Item 19:
Item 20:
Item 22:
Item 23:
Item 24:
Item 27:
Item 28:
Item 30:
Item 31:
Formation Name at TD:
If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if
needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired.
Yes No
Well tested? Yes No
28. CORE DATA
If Yes, list intervals and formations tested, briefly summarizing test results for
each. Attach separate pages if needed and submit detailed test info including
reports and Excel or ASCII tables per 20 AAC 25.071.
NAME
Permafrost - Top
Permafrost - Base
29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS
Authorized Title:
Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345),
and/or Easement (ADL 123456) number.
The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements
given in other spaces on this form and in any attachments.
The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic
diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from
a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071.
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core
analysis, paleontological report, production or well test results, per 20 AAC 25.070.
Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each
segregated pool is a completion.
TPI (Top of Producing Interval).
Authorized Name and
N/A Plugged for Redrill
N/A Plugged for Redrill
INSTRUCTIONS
Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and
other tests as required including, but not limited to: core analysis, paleontological report, production or well test results.
Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29.
Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool.
If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the
producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,
showing the data pertinent to such interval).
Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit
detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity,
permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology.
Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain).
Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical
laboratory information required by 20 AAC 25.071.
Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion,
suspension, or abandonment; or 90 days after log acquisition, whichever occurs first.
Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov
Katherine O'Connor
Katherine.OConnor@conocophillips.com
(907) 2633718
Interventions Engineer
Signed in lieu of
Katherine O'Connor
Digitally signed by Allen Eschete
DN: CN=Allen Eschete, E=Allen.Eschete@ConocoPhillips.comReason: I am the author of this document
Location:Date: 2023.12.07 12:48:32-09'00'
Foxit PDF Editor Version: 13.0.0
Allen Eschete
Last Tag
Annotation Depth (ftKB) End Date Wellbore Last Mod By
Last Tag: SLM 7,641.0 9/13/2011 3B-16 ninam
Last Rev Reason
Annotation End Date Wellbore Last Mod By
Rev Reason: Set Cmt Retainer/Pump 33 bbls 15.8 ppg Cement. 8/18/2023 3B-16 appleha
Casing Strings
Casing Description
CONDUCTOR
OD (in)
16
ID (in)
15.06
Top (ftKB)
32.0
Set Depth (ftKB)
117.0
Set Depth (TVD) …
117.0
Wt/Len (l…
62.50
Grade
H-40
Top Thread
WELDED
Casing Description
SURFACE
OD (in)
9 5/8
ID (in)
8.92
Top (ftKB)
30.2
Set Depth (ftKB)
3,409.3
Set Depth (TVD) …
3,269.8
Wt/Len (l…
36.00
Grade
J-55
Top Thread
BTC
Casing Description
PRODUCTION
OD (in)
7
ID (in)
6.28
Top (ftKB)
23.7
Set Depth (ftKB)
7,858.4
Set Depth (TVD) …
6,325.2
Wt/Len (l…
26.00
Grade
J-55
Top Thread
BTC
Tubing Strings
Tubing Description
TUBING
String Ma…
3 1/2
ID (in)
2.99
Top (ftKB)
23.7
Set Depth (ft…
7,480.6
Set Depth (TVD) (…
5,998.6
Wt (lb/ft)
9.30
Grade
J-55
Top Connection
EUE 8RD
Completion Details
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des Com
Nominal
ID (in)
23.7 23.7 0.01 HANGER FMC GEN III TUBING HANGER 3.500
1,827.5 1,827.4 1.74 SAFETY VLV CAMCO TRDP-1A 2.810
7,215.3 5,782.4 38.05 SBR OTIS SEAL BORE RECEPTACLE 3.000
7,224.3 5,789.5 37.83 PACKER OTIS RRH RETRIEVABLE PACKER 2.969
7,373.3 5,909.8 34.92 BLAST RING BLAST RINGS (2) 2.992
7,456.3 5,978.3 33.72 LOCATOR OTIS STRAIGHT SLOT TYPE LOCATOR 3.000
7,456.9 5,978.8 33.71 PACKER OTIS WD PERMANENT PACKER 4.000
7,460.2 5,981.6 33.66 SBE OTIS SEAL BORE EXTENSION 3.000
7,471.9 5,991.3 33.49 NIPPLE CAMCO D NIPPLE NO GO 2.750
7,479.4 5,997.6 33.38 WLEG OTIS WIRELINE ENTRY GUIDE 3.000
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top
(ftKB)
Top
(TVD)
(ftKB)
Top Incl
(°) Des Com Run Date ID (in) SN
7,170.0 5,747.1 39.29 LEAK - TUBING Found tbg leak w/ Relay LDL 11/28/21 11/28/2021 0.000
7,195.0 5,766.5 38.57 CEMENT
RETAINER
SET 3.5" FH-1 CEMENT RETAINER AT
7195' RKB
8/18/2023 0.000 005-2725-500
7,240.0 5,802.0 37.44 TUBING PUNCH 3 FT OF TUBING PUNCHES (4 SPF) 8/4/2023 2.992
7,245.0 5,805.9 37.31 RBP Set RBP (OAL 9.03') 11/4/2021 0.000 CPP35281/CP
EQ35001
7,245.0 5,805.9 37.31 OTHER Set 3.5" TTS pulling tool w/ Multiple Fish G-
Necks (Top Fish neck is 2.31" & Bottom Fish
neck 1.81") 19" OAL
2/4/2022 0.000
7,255.0 5,813.9 37.07 PATCH 21.5' Merla TBG PATCH; Set across GLM
#12 on 11/30/95/ w/ AVA Nipple 4' Below
Top of GLM
11/30/1995 2.313
7,260.9 5,818.6 36.92 SLEEVE-O 2.31" AVA CIC SLEEVE (OAL=13") 9/13/2011 1.860
7,328.0 5,872.8 35.56 PATCH 21.5' Merla TBG PATCH; Set across GLM
#13 on 11/30/95
11/30/1995 2.375
7,471.9 5,991.3 33.49 NIPPLE
REDUCER
Set Nipple Reducer w/ 1.81" D Profile; Set on
11/29/95
11/29/1995 1.813
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft
)Type Com
7,385.0 7,432.0 5,919.4 5,958.2 C-3, C-2, C-1,
3B-16
5/18/1985 12.0 IPERF 5" Scalloped Csg Gun; 120
deg. ph
7,538.0 7,574.0 6,046.8 6,077.3 A-4, A-3, 3B-16 5/18/1985 4.0 IPERF 4" Carrier JJ II; 120 deg. ph
7,592.0 7,627.0 6,092.6 6,122.6 A-2, 3B-16 5/18/1985 4.0 IPERF 4" Carrier JJ II; 120 deg. ph
Cement Squeezes
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Des Com
Pump Start
Date
6,678.0 7,245.0 5,399.1 5,805.9 Cement Plug 31 BBLS 15.8 PPG CEMENT PUMPED THROUGH
RETAINER. INTO C-SANDS.
8/18/2023
7,238.0 7,456.0 5,800.4 5,978.1 Cement
Squeeze
31 BBLS 15.8 PPG CEMENT PUMPED THROUGH
RETAINER AND INTO THE C-SANDS.
8/18/2023
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 1,848.8 1,848.7 2.30 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 5/20/1985
2 3,066.1 2,998.5 32.49 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 5/20/1985
3 4,060.7 3,717.3 46.76 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 5/20/1985
4 4,614.7 4,089.3 48.72 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 5/20/1985
5 4,937.6 4,299.0 50.07 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 5/20/1985
6 5,250.4 4,500.8 49.69 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 5/20/1985
7 5,572.7 4,709.0 49.68 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 5/20/1985
8 5,880.9 4,908.6 49.71 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 5/20/1985
9 6,348.5 5,198.4 54.18 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 5/20/1985
1
0
6,821.0 5,494.0 47.03 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 5/20/1985
1
1
7,170.0 5,747.0 39.29 MERLA TPDX 1 1/2 GAS LIFT DMY RM 0.000 0.0 11/8/2021
1
2
7,260.9 5,818.6 36.92 MERLA TPDX 1 1/2 INJ PATC
H
0 0.000 0.0 11/30/1995
1
3
7,332.9 5,876.8 35.49 MERLA TPDX 1 1/2 INJ PATC
H
0 0.000 0.0 11/30/1995
1
4
7,436.8 5,962.2 34.01 MERLA TPDX 1 1/2 INJ DMY RM 0.000 0.0 11/15/1995
3B-16, 12/7/2023 12:36:41 PM
Vertical schematic (actual)
PRODUCTION; 23.7-7,858.4
FLOAT SHOE; 7,856.8-7,858.4
FLOAT COLLAR; 7,768.3-
7,769.8
IPERF; 7,592.0-7,627.0
IPERF; 7,538.0-7,574.0
WLEG; 7,479.4
NIPPLE REDUCER; 7,471.9
NIPPLE; 7,471.9
SBE; 7,460.2
PACKER; 7,456.9
LOCATOR; 7,456.3
INJECTION; 7,436.8
IPERF; 7,385.0-7,432.0
PATCH; 7,328.0
INJECTION; 7,332.9
PATCH; 7,255.0
INJECTION; 7,260.9
SLEEVE-O; 7,260.9
RBP; 7,245.0
OTHER; 7,245.0
TUBING PUNCH; 7,240.0
Cement Squeeze; 7,238.0 ftKB
PACKER; 7,224.3
SBR; 7,215.3
CEMENT RETAINER; 7,195.0
GAS LIFT; 7,170.0
LEAK - TUBING; 7,170.0
GAS LIFT; 6,821.0
Cement Plug; 6,678.0 ftKB
GAS LIFT; 6,348.5
GAS LIFT; 5,880.9
GAS LIFT; 5,572.7
GAS LIFT; 5,250.4
GAS LIFT; 4,937.6
GAS LIFT; 4,614.7
GAS LIFT; 4,060.7
SURFACE; 30.2-3,409.3
FLOAT SHOE; 3,407.7-3,409.3
FLOAT COLLAR; 3,319.0-
3,320.6
GAS LIFT; 3,066.1
GAS LIFT; 1,848.8
SAFETY VLV; 1,827.5
CONDUCTOR; 32.0-117.0
HANGER; 30.2-35.1
HANGER; 23.7
KUP INJ
KB-Grd (ft)
35.98
Rig Release Date
4/7/1985
3B-16
...
TD
Act Btm (ftKB)
7,878.0
Well Attributes
Field Name
KUPARUK RIVER UNIT
Wellbore API/UWI
500292128900
Wellbore Status
INJ
Max Angle & MD
Incl (°)
54.45
MD (ftKB)
6,400.00
WELLNAME WELLBORE3B-16
Annotation
Last WO:
End DateH2S (ppm) DateComment
SSSV: TRDP
Notes: General & Safety
End Date Annotation
7/7/2010 NOTE: View Schematic w/ Alaska Schematic9.0
3B-16, 12/7/2023 12:36:55 PM
Vertical schematic (actual)
PRODUCTION; 23.7-7,858.4
FLOAT SHOE; 7,856.8-7,858.4
FLOAT COLLAR; 7,768.3-
7,769.8
IPERF; 7,592.0-7,627.0
IPERF; 7,538.0-7,574.0
WLEG; 7,479.4
NIPPLE REDUCER; 7,471.9
NIPPLE; 7,471.9
SBE; 7,460.2
PACKER; 7,456.9
LOCATOR; 7,456.3
INJECTION; 7,436.8
IPERF; 7,385.0-7,432.0
PATCH; 7,328.0
INJECTION; 7,332.9
PATCH; 7,255.0
INJECTION; 7,260.9
SLEEVE-O; 7,260.9
RBP; 7,245.0
OTHER; 7,245.0
TUBING PUNCH; 7,240.0
Cement Squeeze; 7,238.0 ftKB
PACKER; 7,224.3
SBR; 7,215.3
CEMENT RETAINER; 7,195.0
GAS LIFT; 7,170.0
LEAK - TUBING; 7,170.0
GAS LIFT; 6,821.0
Cement Plug; 6,678.0 ftKB
GAS LIFT; 6,348.5
GAS LIFT; 5,880.9
GAS LIFT; 5,572.7
GAS LIFT; 5,250.4
GAS LIFT; 4,937.6
GAS LIFT; 4,614.7
GAS LIFT; 4,060.7
SURFACE; 30.2-3,409.3
FLOAT SHOE; 3,407.7-3,409.3
FLOAT COLLAR; 3,319.0-
3,320.6
GAS LIFT; 3,066.1
GAS LIFT; 1,848.8
SAFETY VLV; 1,827.5
CONDUCTOR; 32.0-117.0
HANGER; 30.2-35.1
HANGER; 23.7
KUP INJ 3B-16
...
WELLNAME WELLBORE3B-16
DTTMSTART JOBTYP SUMMARYOPS
8/4/2023 ACQUIRE
DATA
RAN TUBING PUNCH W/ 1.56'', 0 PHASE GUN TO PUNCH HOLES @
7240' TO 7243' ( 3FT @ 4 spf =12 HOLES), CCL TO TOP SHOT = 6.7',
CCL STOP DEPTH = 7233.3', CORRELATED TO TBG TALLY DATED
5/20/1985. JOB IS READY FOR CT
8/17/2023 ACQUIRE
DATA
RIH WITH CEMENT RETAINER. GET HUNG UP IN GLM AT 7,170' AND
RETAINER SOFT SETS. WHILE CHANGING TOOLS AT SURFACE,
IDENTIFY CRACK IN COIL TUBING. TRIM 900' OF COIL TO CUT OUT
BAD SPOTS. JOB IN PROGRESS.
8/18/2023 ACQUIRE
DATA
RUN VENTURI / BURN SHOE AND TAG CEMENT RETAINER AT 7,164'.
MILL UP/PUSH CEMENT RETAINER DOWN TO PLUG AT 7,245'.
PERFORM INJECTIVITY TEST AT 1.6 BPM @ 1375 PSI. RUN CEMENT
RETAINER DRIFT / COIL FLAG. SET CEMENT RETAINER @ 7198' ME
RKB, PUMP 31 BBLS THROUGH RETAINER, LAY IN 3 BBLS ON TOP OF
RETAINER. CHASE OOH FREEZE PROTECT WELL TO 3000'. WAIT 24
HRS FOR SLICKLINE TAG AND TEST.
8/23/2023 ACQUIRE
DATA
PERFORM A PRE AOGCC WITNESSED TAG TOC @ 6681' RKB
8/25/2023 ACQUIRE
DATA
PRE STATE WITNESSED MIT-T TO 2500 PSI, PASSED, IN PROGRESS.
9/6/2023 ACQUIRE
DATA
PERFORMED STATE WITNESSED (ADAM EARL) TAG TOC @ 6647'
SLM. MIT-T @ 2500 psi, PASSED, JOB COMPLETE.
3B-16 Plug for Redrill
Summary of Operations
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Jim Regg DATE:
P.I. Supervisor
SUBJECT:
FROM:
Petroleum Inspector
Section:16 Township:12N Range:9E Meridian:Umiat
Drilling Rig:n/a Rig Elevation:n/a Total Depth:7878 ft MD Lease No.:ADL 025633
Operator Rep:Suspend:P&A:X
Conductor:16"O.D. Shoe@ 117 Feet Csg Cut@ Feet
Surface:9 5/8"O.D. Shoe@ 3409 Feet Csg Cut@ Feet
Intermediate:O.D. Shoe@ Feet Csg Cut@ Feet
Production:7"O.D. Shoe@ 7858 Feet Csg Cut@ Feet
Liner:O.D. Shoe@ Feet Csg Cut@ Feet
Tubing:3 1/2"O.D. Tail@ 7481 Feet Tbg Cut@ Feet
Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified
Fullbore Retainer 7450 ft 6647 ft Wireline tag
Initial 15 min 30 min 45 min Result
Tubing 2740 2620 2580
IA 1510 1510 1510
OA 70 70 70
Initial 15 min 30 min 45 min Result
Tubing
IA
OA
Remarks:
Attachments:
Sid Ferguson
Casing/Tubing Data (depths are MD):
Plugging Data (depths are MD):
I traveled out to KRU 3B-16 to witness a wireline tag and pressure test for P&A / slot recovery. Tagged top of cement @ 6,647 ft
MD with a tool string consisting of 8 feet of 2 1/8-inch weight bar, oil jars, spangs, 2.55-inch centralizer, and a 2 1/4-inch sample
bailer. The hanging wt was 175lbs at surface and 350lbs just above the plug. The sample bailer brought up a good sample of
cement and interface. Pressure test went as follows in chart above.
September 6, 2023
Adam Earl
Well Bore Plug & Abandonment
KRU 3B-16
ConocoPhillips Alaska Inc.
PTD 1850260; Sundry 323-333
none
Test Data:
P
Casing Removal:
rev. 3-24-2022 2023-0906_Plug_Verification_KRU_3B-16_ae
C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\H2LGR515\2023-08-18_22112_KRU_3B-16_CoilFlag_Transmittal.docx
DELIVERABLE DISCRIPTION
Ticket # Field Well # API # Log Description Log Date
22112 KRU 3B-16 50-029-21289-00 Coil Flag 18-Aug-23
DELIVERED TO
Company & Address
DIGITAL FILE
# of Copies
LOG PRINTS
# of Prints
CD’s
# of Copies
1
AOGCC
Attn: Natural Resources Technician
333 W. 7th Ave., Suite 100
Anchorage, Ak. 99501-3539
Delivered By: CPAI Sharefile
______________________________ ______________________________________
Date received Signature
PLEASE RETURN COPY VIA EMAIL TO:
DIANE.WILLIAMS@READCASEDHOLE.COM
READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503
PHONE: (907)245-8951
E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM
PTD: 185-026
T37952
8/23/2023
Kayla
Junke
Digitally signed
by Kayla Junke
Date: 2023.08.23
16:05:32 -08'00'
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: ___________________
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?
Will planned perforations require a spacing exception? Yes No
9. Property Designation (Lease Number): 10. Field: Current Pools:
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD):
7878'None
Casing Collapse
Structural
Conductor
Surface
Intermediate
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:
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:
Post Initial Injection MIT Req'd? Yes No
Spacing Exception Required? Yes No Subsequent Form Required:
APPROVED BY
Approved by: COMMISSIONER THE AOGCC Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval.
Authorized Name and
Digital Signature with Date:
AOGCC USE ONLY
Katherine O'Connor
katherine.oconnor@conocophillips.com
(907) 263-3718
Senior Well Interventions Engineer
Tubing Grade: Tubing MD (ft):
7224' MD and 5789' TVD
7457' MD and 5979' TVD
1827' MD and 1827' TVD
Perforation Depth TVD (ft): Tubing Size:
J-55 7481'
7/1/2023
Packer: Otis RRH Rtvbl Packer
Packer: Otid WD Perm Packer
SSSV: Camco TRDP-1A
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
185-026
P.O. Box 100360, Anchorage, AK 99510 50-029-21289-00-00
ConocoPhillips Alaska, Inc.
KRU 3B-16
N/A- Plugged for RedrillKuparuk River Oil Pool Kuparuk River Field
N/A
Length Size
Proposed Pools:
TVD Burst
PRESENT WELL CONDITION SUMMARY
6341' 7245' 5806' 7245'
MD
117'
3270'
117'
3409'
6325'7858'
16"
9-5/8"
85'
3379'
Perforation Depth MD (ft):
7385-7432', 7538-7574', 7592-
7627'
7835'
5919-5958', 6047-6077', 6093-
6123'3-1/2"
7"
Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
ADL0025633
By Grace Christianson at 9:58 am, Jun 09, 2023
323-333
Digitally signed by Katherine O'Connor
DN: CN=Katherine O'Connor, O=
ConocoPhillips, OU=Wells Group, E=
katherine.oconnor@conocophillips.com, C=US
Reason: I am the author of this document
Location:
Date: 2023.06.09 07:58:27-08'00'
Foxit PDF Editor Version: 12.0.1
Katherine
O'Connor
MDG 6/12/2023
VTL 6/26/2023
X
X
Suspension expires 12/31/2023
10-407
DSR-6/12/23BWH 6/26/23
06/26/23
RBDMS JSB 062723
Jessie L.
Chmielowski
Digitally signed by Jessie
L. Chmielowski
Date: 2023.06.26 13:47:39
-08'00'
Date: 6-8-23
Date of Work: 7-01-23
Subject: 3B-16 Reservoir Abandonment
Prepared by: Katherine O’Connor (214) 684-7400
Well History
3B-16 is a WAG injector with TxIA communicaƟon that has been shut in since Nov 2021. An LDL was ran
in Nov 2021 and found the tubing leak at 7171’ RKB. During this operaƟon a plug was set @ 7245’ RKB,
and the plug was never able to be retrieved. Coil tried both Įshing it and milling on it for 11 days but
never made any progress – it is now an irretrievable Įsh. The objecƟve of this program is to abandon the
reservoir in preparaƟon for the sidetrack, which is scheduled for 16 September 2023.
Notes:
x Tubing leaks @ 7171’ RKB and 7255’ & 7326’ RKB (in the selecƟve)
x Last tag 7245’ on 9/20/2022, tag TOF
x InclinaƟon Max: 54 deg @ 6400’ RKB
x Min ID: 2.81” @ 1827’ RKB
x Last SBHP 08/16/2019 || 3581 psi
x Planned KOP for sidetrack ~6725’ RKB
CalculaƟons
Procedure:
Eline
1. Tag top of Įsh @ approx. 7245’ RKB
2. Pick up hole 5’ and punch tubing @ ~7240’
Coil
1. RIH with one trip cement retainer, set retainer @ ±7,200’ RKB (middle of joint of tubing)
2. The total cement pumped is ±33 bbls (30 below retainer and 3 above retainer) for planned TOC
at 6855’ RKB. Expect some to slump due to tubing leak. Recalculate cement volumes as
necessary depending on retainer depth
3. Pump the following cement schedule:
a. ±10 bbl diesel to establish injecƟvity
b. ±10 bbl freshwater spacer
c. ±33 bbls 15.8ppg Class G cement
4. AŌer 30 bbls pumped, unsƟng retainer and lay in the remaining 3 bbls into the tubing leaving
TOC at ±6855’ RKB
String Top Bottom Size Length ID bbls/ft volume ft/bbl notes
3.5" tubing 0 7480 3.5" 9.3# 7480 2.992" 0.0087 65.0 115.0 tally depth
3.5" x 7" annulus (IA) 0 7224 3.5" 9.3# x 7" 26# 7224 6.28" x 3.5" 0.0264 190.8 37.9 uppermost packer
3.5" x 7" annulus (IA)7224 7457 3.5" 9.3# x 7" 26# 233 6.28" x 3.5" 0.0264 6.2 37.9 selective annulus
7" liner 7480 7858 7" 26# 378 6.28" 0.0383 14.5 26.1
The objecƟve of this program is to abandon the
reservoir in preparaƟon for the sidetrack, which is scheduled for 16 September 2023.
5. POOH above TOC and circulate clean
6. RDMO
Slickline & Fullbore
1. WOC for minimum 24 hours. NoƟfy AOGCC inspector of cement Ɵming and plug tag at least 24
hours in advance.
2. RU Slickline and PT equipment as required
3. RIH to tag TOC (AOGCC witness) @ approx. 6855’ RKB, record results
4. CMIT-TxIA to 2500 psi (AOGCC witness), record results
Planned TOC
6855’ RKB
Originated: Delivered to:14-Jan-22Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL #1 1A-05 50-029-20627-00 907568283 Kuparuk River Multi Finger Caliper Field & Processed 13-Dec-21 0 12 1A-19 50-029-22111-00 n/a Kuparuk River Plug Setting Record Field- Final 9-Dec-21 0 13 1E-31 50-029-22791-00 907551730 Kuparuk River Leak Detect Log Field- Final 7-Dec-21 0 14 1E-31 50-029-22791-00 907551730 Kuparuk River Multi Finger Caliper Field & Processed 6-Dec-21 0 15 1L-19 50-029-22049-00 907423896 Kuparuk River Multi Finger Caliper Field & Processed 27-Dec-21 0 16 1L-19A 50-029-22049-01 n/a Kuparuk River Multi Finger Caliper Field & Processed 10-Jan-22 0 17 2W-16 50-029-21255-00 907594924 Kuparuk River Plug Setting Record Field- Final 29-Dec-21 0 18 3B-16 50-029-21289-00 907292763 Kuparuk River Leak Detect Log Field- Final 28-Nov-21 0 19 3B-16 50-029-21289-00 907292763 Kuparuk River Multi Finger Caliper Field & Processed 3-Dec-21 0 110 3F-04 50-029-21449-00 907551131 Kuparuk River Multi Finger Caliper Field & Processed 4-Dec-21 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:01/14/2022Wd͗ϭϴϱϬϮϲϬ Ͳ^Ğƚ͗ϯϲϮϯϳBy Abby Bell at 12:45 pm, Jan 14, 2022
Originated: Delivered to:14-Jan-22Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL #1 1A-05 50-029-20627-00 907568283 Kuparuk River Multi Finger Caliper Field & Processed 13-Dec-21 0 12 1A-19 50-029-22111-00 n/a Kuparuk River Plug Setting Record Field- Final 9-Dec-21 0 13 1E-31 50-029-22791-00 907551730 Kuparuk River Leak Detect Log Field- Final 7-Dec-21 0 14 1E-31 50-029-22791-00 907551730 Kuparuk River Multi Finger Caliper Field & Processed 6-Dec-21 0 15 1L-19 50-029-22049-00 907423896 Kuparuk River Multi Finger Caliper Field & Processed 27-Dec-21 0 16 1L-19A 50-029-22049-01 n/a Kuparuk River Multi Finger Caliper Field & Processed 10-Jan-22 0 17 2W-16 50-029-21255-00 907594924 Kuparuk River Plug Setting Record Field- Final 29-Dec-21 0 18 3B-16 50-029-21289-00 907292763 Kuparuk River Leak Detect Log Field- Final 28-Nov-21 0 19 3B-16 50-029-21289-00 907292763 Kuparuk River Multi Finger Caliper Field & Processed 3-Dec-21 0 110 3F-04 50-029-21449-00 907551131 Kuparuk River Multi Finger Caliper Field & Processed 4-Dec-21 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:01/14/2022Wd͗ϭϴϱϬϮϲϬ Ͳ^Ğƚ͗ϯϲϮϯϲBy Abby Bell at 12:45 pm, Jan 14, 2022
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From:Wallace, Chris D (CED)
To:AOGCC Records (CED sponsored)
Subject:FW: KRU 3B-16 (PTD# 185-026) TxIA communication
Date:Thursday, November 18, 2021 10:44:37 AM
From: Smith, Travis T <Travis.T.Smith@conocophillips.com>
Sent: Tuesday, November 2, 2021 3:28 PM
To: Wallace, Chris D (CED) <chris.wallace@alaska.gov>
Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; Well Integrity Specialist CPF1 & CPF3
<n1617@conocophillips.com>
Subject: KRU 3B-16 (PTD# 185-026) TxIA communication
Chris—
KRU injection well 3B-16 (PTD# 185-026) was reported by operations with TxIA communication while
on water injection. The well has been shut-in and freeze-protected. DHD will perform routine
diagnostics, including wellhead testing and an MITIA. Based on diagnostics we will formulate a path
forward and submit Sundry paperwork as necessary. The well will remain shut-in until the issue can
be resolved.
Let me know if you have any questions or disagree with the plan.
Travis Smith
WNS Intervention & Integrity Engineer
907-670-4014
Travis.T.Smith@conocophillips.com
MEMORANDUM
State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Jim Regg
DATE: Monday, July 8, 2019
P.I. Supervisor '\C'(��. 7/cl��
SUBJECT: Mechanical Integrity Tests
( l
ConocoPhillips Alaska, Inc.
38-16
FROM: Guy Cook
KUPARUK RIV UNIT 313-16
Petroleum Inspector
Sre: Inspector
Reviewed By:
P.I. Supry '�
NON -CONFIDENTIAL Comm
Well Name KUPARUK RIV UNIT 313-16 API Well Number 50-029-21289-00-00 Inspector Name: Guy Cook
Permit Number: 185-026-0 Inspection Date: 6/28/2019
InSp Num: mi[GDC]90628174844
Rel Insp Num:
Packer Depth Prelest Initial 15 Min 30 Min 45 Min 60 Min
Well 3B-16 'Type Inj w "TVD 5789 Tubing I 15„ 1534 1534
PTD 185o�Type Test! SPT Test psi s0o IA no 2515 - 2390 - 1370
BBL Pumped: z.a BBL Returned: 2 OA 300 - 340- 340 340
Interval 4vRTST P/F ✓
Notes: Job completed with a Little Red Services pump truck and calibrated analog gauges.
Monday, July 8, 2019 Page I of I
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
TO: DATE: Wednesday,June 24,2015
Jim Regg _
P.I.Supervisor � '7 ( (z (15 SUBJECT: Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA INC
3B-I6
FROM: Chuck Scheve KUPARUK RIV UNIT 3B-16
Petroleum Inspector
Src: Inspector
Reviewed B
P.I.SuprvJ
NON-CONFIDENTIAL Comm
Well Name KUPARUK RIV UNIT 3B-16 API Well Number 50-029-21289-00-00 Inspector Name: Chuck Scheve
Permit Number: 185-026-0 Inspection Date: 6/18/2015
Insp Num: mitCS 150621105940
Rel Insp Num:
•
Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min
Well 3B-16Type Inj I W' TVD 5759 Tubing 2741 2741 • 2741 2741
PTD i 1850260 Type Test SPT Test psi 1500 - IA 1130 - 2000 - 1940 • 1940 =
Interval I4YRTST PAF P OA 400 , 400 - 400 400 -
Notes:
SCANNED
Wednesday,June 24,2015 Page 1 of 1
1417
WELL LOG TRANSMITTAL
To: Alaska Oil and Gas Conservation Comm. September 30, 2011
Attn.: Howard Okland
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
RE: Injection Profile: 3B-16
Run Date: 9/22/2011
The technical data listed below is being submitted herewith. Please address any problems or
concerns to the attention of:
Klinton Wood, Halliburton Wireline& Perforating, 6900 Arctic Blvd., Anchorage, AK 99518
3B-16
Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom
50-029-21289-00
Injection Profile Log 1 Color Log
50-029-21289-00
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE
TRANSMITTAL LETTER TO THE ATTENTION OF:
Halliburton
Wireline & Perforating
Attn: Klinton Wood
6900 Arctic Blvd.
Anchorage, Alaska 99518
Office: 907-273-3527
Fax: 907-273-3535
klinton.wood@halliburton.com
Date: 1t12 Signed: Ai (-96
1 •
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE: Wednesday, June 22, 2011
TO Jim R �� � C 6(Z3'/� SUBJECT: Mechanical Integrity Tests
P.I. Supervisor visor I
CONOCOPHILLIPS ALASKA INC
3B -I6
FROM: Lou Grimaldi KUPARUK RIV UNIT 3B -16
Petroleum Inspector
Src: Inspector
Reviewed By:
P.I. Supry :3
NON- CONFIDENTIAL Comm
Well Name: KUPARUK RIV UNIT 3B - 16 API Well Number: 50 029 - 21289 - 00 - 00 Inspector Name: Lou Grimaldi
Insp Num: mitLGl 10620173429 Permit Number: 185 - 026 - Inspection Date: 6/16/2011
Rel Insp Num:
Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
Well ' 3B -16 ' ' r
Type Inj. W > TVD 5789 , 1 IA 1400 1716 • 1697 I 1693 -
P.T.D 1850260 ' TypeTest I SPT 1 Test psi 1500 = OA 520 530 550 550
Interval 4YRTST p/F P Tubing I 2193 , 2193 2193 2193
Notes: Fluid to surface. 1 Bbl pumped and returned. Good stable test. -
7
'.o.: ,�;'' JIUN 2. 4 201
Wednesday, June 22, 2011 Page 1 of 1
.
Conoc~hillips
Alaska
.
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
RECEIVED
14UG 1 8 2007
Alaska 0;1 & Gas Cons Cnrn . .
. ...,..mISSlon
Anchorage
August 7, 2007
Mr. Tom Maunder
Alaska Oil & Gas Commission
333 West 7th Avenue, Suite 100
Anchorage, AK 99501
1 ~5-oa..0
sCANNED AUG 1,42007
Dear Mr. Maunder:
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 by surface casing annulus. The voids that
were greater than 3 feet were first filled with cement to a level of 20". The remaining volume of
annular void respectively was filled with a corrosion inhibiter, RG2401, 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 top-fill operation was completed on July 27,2007. Schlumberger Well Services
mixed 15.7 ppg Arctic set I in a blender tub. The cement was pumped into the conductor bottom
and cemented up via a hose run to the existing top of cement. The corrosion inhibitor/sealant
was pumped in a similar manner August 5, 2007. The attached spreadsheet presents the well
name, top of cement depth prior to filling, and volumes used on each conductor.
Please call me at 907-659-7043, if you have any questions.
ø~~
M~d
ConocoPhillips Well Integrity Projects Supervisor
.
.
ConocoPhillips Alaska Inc.
Suñace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off
Report of Sundry Operations (10-404)
Kuparuk Field
Date
8/7/2007
Corrosion
Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/
Well Name PTD# cement pumped cement date inhibitor sealant date
ft bbls ft na aal
38-02 185-057 32" .4 bbls 20" 7/27/2007 4.2 8/5/2007
38-03 185-060 29' 5.2 bbls 20" 7/27/2007 4.2 8/5/2007
38-04 185-061 14' 2.5 bbls 20" 7/27/2007 4.2 8/5/2007
38-05 185-075 SF N/A SF 7/27/2007 1.7 8/5/2007
38-07 185-077 45' 6.1 bbls 20" 7/27/2007 6.8 8/5/2007
38-08 185-087 14' .5 bbls 20" 7/27/2007 2.5 8/5/2007
38-09 185-113 SF N/A SF 7/27/2007 1.7 8/5/2007
38-11 185-115 20' 2.9 bbls 20" 7/27/2007 5.1 8/5/2007
38-12 185-116 43' 7 bbls 20" 7/27/2007 3.4 8/5/2007
38-13 185-023 43' 5.9 bbls 20" 7/27/2007 11.9 8/5/2007
38-14 185-024 11' 8.9 bbls 20" 7/27/2007 5.1 8/5/2007
38-15 185-025 57' 9 bbls 20" 7/27/2007 7.6 8/5/2007
38-16 185-026 43' 6.8 bbls 20" 7/2712007 7.6 8/512007
ME MORANDUlVI
.
State of Alaska .
\Iaska Oil and Gas Conservation Commission
10: Jim Regg
P.I. Supenisor
() \IT: I ::cscia\ June í L
I
SIB.IECT: \lech:1I11cai integrity 1 csts
CO\J)C(JPEfLLlPS _\LAS~\ f:\C
FRO:\!:
John Crisp
Petroleum Inspector
'3·
KUPARUK RIV L'èiIT 3B-16
\~b~OW
Src: Inspector
Reviewed Bv:
;-;-:::
P.I. Suprv ~í32--
Comm
NON-CONFIDENTIAL
Well Name: KUPARUK R[V UNIT 38-[6
Insp Num: mitJCr0706121346[7
Rei Insp Num:
Permit Number:
185-026-0
Inspector Name: John Crisp
Inspection Date: 6í8í2007
API Well Number: 50-029-21289-00-00
Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
Well m-16 Typeinj. , w : TVD ! 5790 IA! 1100 2970 I 2890 2870 !
P.T.Di- 185Ô26~r"!JpeTe~t--tsPT :jest psi ________150o~~~~ÓA -~~520- ..:" -62~______ 6;0~______ 620_~~- ____ ______-_-
.lIlteryal _ 4YRTST _P/F _. ~ _____.(_~ubing! _ 233~,-_2357----,_ 2345_L2=~ _L__ ._L _.__
Notes: 24 bbl's pumped for test
SCANNED JUN 2 1 2007
Tuesday, June 12,2007
Page 1 of 1
Schlumberger
RECE\VEU
NO. 3615
Schlumberger -DCS
2525 Gambell Street, Suite 400
Anchorage, AK 99503-2838
A TTN: Beth
r"iF""r Î' ') 1 ?ons
u _'-' ~ -.L '- >vI.J
Com pany:
~ C'ff & Gas ConS. C-omm~{Cn
Ar.cliorage
Field:
-~~-~ Well Job # Log Description Date BL
1 Y -19 11144040 PIEZO SONA TOOL 11/19/05 1
1Y-27 11072935 PRODUCTION PROFILE W/DEFT 11/22/05 1
2D-09 11072933 SBHP SURVEY 11/18/05 1
1 R-15 11072932 SBHP SURVEY 11/18/05 1
3F-05 N/A PRODUCTION LOG 11/13/05 1
1 L-25 11056689 SBHP SURVEY 09/14/05 1
3F-12 11057064 INJECTION PROFILE 11/06/05 1
3H-01 11056685 PRODUCTION PROFILE W/DEFT 09/10/05 1
10-16 11141232 PRODUCTION PROFILE WIDEFT 12/01/05 1
1 E-33 N/A GLS & BHP 12/04/05 1
3N-13 11141234 INJECTION PROFILE 12/03/05 1
2N-329 11141236 SLIM CHFR 12/08/05 1
1 C-07 11141231 PRODUCTION PROFILE W/DEFT 11/30/05 1
10-09 11141233 INJECTION PROFILE 12102/05 1
3B-16 /85-0ëJ.f.t> N/A INJECTION PROFILE 12/08/05 1
10-06 N/A PRODUCTION PROFILE W/DEFT 12/10/05 1
-~~ 2A-21 11141237 INJECTION PROFILE 12/12/05 1
2A-24 11144049 PROD PROFILE W/DEFT 12/15/05 1
10-101 11144044 MDT 11/24/05
12/20/05
\ ~ LJ --D ~
Alaska Oil & Gas Cons Comm
Attn: Helen Warman
333 West 7th Ave, Suite 100
Anchorage, AK 99501
Kuparuk
Color CD
1
SIGNED: f;CANNED JAN :3 G (ÜD6DATE:ð~)
Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you.
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
Mechanical Integrity Test
Email to: Tom_Maunder@admin.state.ak.us and Bob_Fleckenstein@admin.state.ak.us
OPERATOR:
FIELD / UNIT / PAD:
DATE:
OPERATOR REP:
AOGCC REP:
ConocoPhillips Alaska Inc.
Kuparuk/KRU/3B
06/05/03
Arend/Brake- APC
Chuck Scheve
Packer Depth Pretest Initial 15 Min. 30 Min.
Welll3B-01 [ Typelnj I Sp I T.V.D. I 5954 I Tubingl 23501 23501 23501 23501 Interval
p.T.D. I1850560 TypeTest Test psiI 15oo I Casing I 1250] 22501 22001 22001 P/F
Notes:
P,T.D. I1850750 Type Test Test psi[ 1500 I CasingI 13501 20751 20501 20501 P/F I P
Notes:
Welll3B'07 I I Tubing I 37001 37001 37001 37001
p.T,D, I1850770 Type Test Test psiI 1500 I Casingl 7501 22001 21501 21501 P/F
Notes:
,,
WeIII3B-12 I Typelnjl Gp I T.V.D. 15743 I Tubingl 26501 26501 2650[ 265ol,nterva, I ~
P.T.D. I1.851160 TypeTest" Test psiI 1500 I CasingI. 13501 20°01 2o001 2o0ol PiE
Notes:
P,T::D. II'850250 Type Test Test psiI 1500 I Casing I ~40Ol 2~'501 25(
Notes:
)01 '13001 IntervalI I~
)01 25001 P/F
.P,T,D:I.1850260 Type Test Test psiI 15oo I Casing I 13001 20251 20001 20001 P/F
Notes:
Test Details:
TYPE INJ codes
F = Fresh Water Inj
G = Gas Inj
S = Salt Water Inj
N = Not Injecting
TYPE TEST Codes
M = Annulus Monitoring
P = Standard Pressure Test
R = Internal Radioactive Tracer Survey
A = Temperature Anomaly Survey
D = Differential Temperature Test
INTERVAL Codes
I = Initial Test
4 = Four Year Cycle
V = Required by Variance
Test during Workover
O = Other (describe in notes)
MIT Report Form
Revised: 05/19/02
2003-0605_MIT_KRU_3B-01_-05_-07_-12 -15 -16.xls
6/25/2003
'KRU MIT's
Subject: KRU MIT's
Date: Fri, 6 Jun 2003 15:28:32 -0800
From: "NSK Problem Well Supv" <nl 617~conocophillips.com>
To: bob_fleckenst¢in@admin.state.ak.us, tom_maunder~admin.state.ak.us,
jim_regg@admin.state.ak.us
CC: "nl 617" <nl 617~conocophillips.com>
Attached are the 4 year cycle MIT Results for 3B and 3F.
Please call with any questions.
MJ Loveland
Problem Well Supervisor
ConocoPhillips Alaska Inc.
(907) 659-7224, 659-7043
(See attached file: MIT KRU 3F 06-05-03.xls) (See attached file: MIT KRU 3B
06-05-03.xls)
~_~MIT KRU 3F 06-05-03.xls
Name: MIT KRU 3F 06-05-03.xls
Type: EXCEL File (application/msexcel),?
Encoding: base64
~MIT KRU 3B 06-05-03.xls
TypeI EXCEL File (application/msexcel):I
Encoding. base64
I of I 6/25/2003 4:37
MEMORANDUM
State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Randy Rueddch
Commissioner
THRU:
FROM:
Jim Regg "~g',~
P.I. Supervisor
DATE: June 5, 2003
SUBJECT: Mechanical Integrity Test
Conoco Phillips
3B Pad
KRU
Chuck Scheve
Petroleum Inspector
NON- CONFIDENTIAL
Packer Depth Pretest Initial 15 Min. 30 Min. I
· I Typ.,nj.Isi I TuU,ng12350 I I 2350 I 2350 I lntervall 4 I
We,I
3B-01 ITypetestl P ITestpsil 1489 I Casingl 1250I 2250I 2200I 2200I P/F I ~P I
P.T.D.I 185-056
Notes:
WellI
3B-07I
P.T.D. I 185-077
Notes:
Notes:
WellI 3B-05
ITypelnj.I G I T.V.D.I ~3, I Tubingl 3700 I 3700 I 3700 I 3700 Ilntervall 4I
P.T.D.I
185-075
I
TypetestI P ITestpsil 1484 I Casingl 1350I 2075I 2050I 2050I P/F I _P I
I
Type lnj.I g I t.V.d. I 5914 I Tubing 13700 I 3700 I ~00 i~00 I lntervall 4
Type testI P I Testpsil 1479 ICasingI 750 I 22001 21501 21501 P/f I ~P
WellI 3B-12 I Typei.J.I G I T.V.D. I 5743 I Tubing I ~0I~oI=~oI=~o l inter~all 4
P.T,D.I 185-116 ITypetestl P ITestpsil 1436 I Casingl 1350I 2000I 2000I 2000I P/F I ~P
Notes: ~
P.T.D.] 185~025 ~Typetest~ P ~Testpsi~ 1~2 ~Casing~ 1400 ~ 2550 ~ 2500 I 2500 ~ p/F
Notes:
i .~"~t~;~.,:~;.i:~i.,~..~ I Typeln~.I G'.I T.V.~. 1~90 I Tubing I 2780 I 2780 1=7 0 l lnte~all 4
'P.T.D.t'"~-~6 ITypetestl P ITestpsil 1~8 I casingl ~300I 2025I 2000I 2000I P/F
NOtes:
Type IN J. Fluid Codes
F = FRESH WATER INJ.
g - GAS I NJ.
S = SALT WATER IN J.
N = NOT INJECTING '
Type Test
M= Annulus Monitoring
P= Standard Pressure Test
R= Internal Radioactive Tracer Survey
A= Temperature Anomaly Survey
D= Differential Temperature Test
Interval
I= Initial Test
4= Four Year Cycle
'V= Required by Variance
W= Test during Workover
O= .Other (describe in notes)
Test's Details
I traveled to Conoco Phillips 3B Pad in the KuParuk field and wimessed the routine 4 year MIT's on the above limed 6
wells. The pretest pressures were obsel~ed and found to be stable. The standard annulus pressure tests were then
performed with all wells demonstrating good mechanical integrity.
M.I.T/s performed: _6 Number of Failures: _0
Attachments:
Total Time during tests: 4 hours
cc:
MIT report form
5/12/00 L.G. 2003-0605_M IT_KRU_3 B-16_cs.xls 6/24/2003
SCANNED JUL 0 8 2003
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _
Pull tubing _ Alter casing _ Repair well_ Other_X WI to WAG Injection
2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet)
Phillips Alaska, Inc. Development__ RKB 85 feet
3. Address Exploratory __ 7. Unit or Property name
P. O. Box 100360 Stratigraphic__
Anchorage, AK 99510-0360 Service__X Kuparuk Unit
4. Location of well at surface 8. Well number
5048' FNL, 800' FEL, Sec. 16, T12N, R9E, UM (asp's518231, 5991349) 3B-16
At top of productive interval 9. Permit number / approval number
1674' FNL, 1299' FWL, Sec. 21, T12N, R9E, UM 185-026 /
At effective depth 10. APl number
50-029-21289
At total depth 11. Field / Pool
1701' FNL, 4028' FEL, Sec. 21, T12N, R9E, UM (asp's 515012, 5989411) Kuparuk Oil Pool
12. Present well condition summary
Total depth: measured 7878 feet Plugs (measured)
true vertical 6343 feet
Effective depth: measured feet Junk (measured)
true vertical feet
Casing Length Size Cemented Measured Depth True vertical Depth
CONDUCTOR 1 17' 16" 265 sx PFC 117' 117'
SUR. CASING 3324' 9-5/8" 920 sx AS III & 360 sx Class G 3409' 3270'
PROD. CASING 7773' 7" 375 sx C~ass G & 25O sx AS I 7858' 6325'
Perforation depth: measured 7385-7432; 7538-7574; 7592-7627 ::':~' ;;: !' ' ;';;' ( ':';I? !:;'' !'''''''''
true vertical 5919-5958; 6047-6077; 6093-6123 ./!-:;' !' :i i17' ;, ~; '.' -:,:~.
Tubing (size, grade, and measured depth) 3-1/2", 9.3#, J-55 Tbg @ 7481' MD.
Packers & SSSV (type & measured depth) OTIS 'RRH' @ 7224' MD; OTIS 'WD' @ 7457' MD;
CAMCO 'TRDP-1A' @ 1828' MD.
13. Stimulation or cement squeeze summary
Intervals treated (measured) N/A
Treatment description including volumes used and final pressure
14. Representative Daily Average Production or Injection Data
OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure
Prior to well operation 3609 500 1562
Subsequent to operation 5550 500 2866
15. Attachments
Copies of Logs and Surveys run _
Daily Report of Well Operations __X Oil __ Gas __ Suspended __ Service _X WAG Injection
17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Jeff Spencer 659-7226
Sig~dA sp,~~~(-'~"~~~'Y~~ Title Production Engineering Supervisor Date fc'~J/'~/'~/~
· Prepared by Robert Christensen 659-7535
Form 10-404 Rev 06/15/88 ·
SUBMIT IN DUPLICATE
3B-16
DESCRIPTION OF WORK COMPLETED
SUMMARY
Date Event Summary
Alaska Oil Gas Conservation Commission
31]01 Porcupine Drive
Anchnra§e, Ala.~ka 99501-3192
907-279-1433
To: ~ Fie:
Permit #
The following data is hereby acknowledged as being received:
Dated:
Copy sent to sender: Ycs~
No ~
ARCO Alaska, lnc
Post Office .x 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
May 2, 1988
Mr. C. V. Chatterton
Alaska Oil and Gas ConTnission
3001 Porcupine Drive
Anchorage, Alaska 99501
Dear Mr. Chatterton-
Subject' Kuparuk River Field
Water Injection Surveys
In compliance with Rule 4 Conservation Order Number 198, Kuparuk River
Field Waterflood Rules, we are hereby submitting injectivity surveys
for Kuparuk water injection wells for the first quarter of 1988.
The data is provided in the form of separate zone surveys as or spinner
logs listed in Attachment I. The spinner logs will be sent separately.
Injection rates determined by separate zone surveys are also listed in
Attachment I.
If you have any questions concerning the information reported, please
contact me at (907) 263-4978.
Sincerely,
~4. H. Kraly
Operations Engineer
MHK/SPT:pg:0163
Attachments
ARCO Alaska, Inc. ia a Subaidiary of AtlantlcRIchlieldCompany
3~-' If'
5. S
J
I
STATE OF ALASKA ....
ALA~. ~A OIL AND GAS CONSERVATION CCi ..... ISSION
APPLICATION FOR SUNDRY APPROVALS
Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing ~ Amend order [] Perforate ~,,"Other []
2. Name of Operator 5. Datum elevation (DF or KB)
ARCO Alaska, ]'nc RKB 93 feet
6. Unit or Property name
Ku~aruk River Unit
7. Well number
3F-16
8. Permit number
Permit #85-294
9, APl number
50-- 029-21502
10. Pool
Kuparuk River Oil Pnnl
Plugs (measured]None
3. Address
PO Box 100360, Anchorage, AK 99510
4. Location of well at surface
82' FSL, 227' FEL, Sec. 19 T12N RgE UM
At top of pro~luctive interval ' ' '
1589' FNL, 3639' FEL, Sec. 19, T12N, R9E, UM
At effective depth
1365' FNL, 3850' FEL, Sec. 19, T12N, RgE, UM
At total depth
1310' FNL, 3945' FEL~ Sec.~9, T12N, R9E; UM
11. Present well condition summary
Total depth: measured 8600' ND feet
true vertical6266, TVD feet
Effective depth: measured 8484' MD feet
true vertical6180, TVD feet
Casing Length Size
Structural
80' 16"
Conductor
Surface 3849' 9- 5 / 8"
x X x~rxt~)~'r~i~te
Production
xxxxL, xxxx
Perforation depth:
Junk (measured) None
8538' 7"
measured 8369'-8381' MD
8273'-8322' MD
true vertica16102'-6110' TVD
6032'-6071' TVD
Cemented Measured depth
328 SX ASII 115' MD 115'
1125 SX PF E & 3884' MD 3046'
425 SX Class G
250 SX Class G 8573' MD 6246' TVD
& 180 SX PFC
4 spf, 8014'-8112' MD 12 spf
5845'-5916' TVDt~.C.-.-
BOP sketch []
Tubing (size, grade and measured depth)
3-~" J-55 fa 8203' MD
Packers and SSSV (type and measured depth)
Baker FH[ fa 7937', Raker FR-] 0 ~1_~!'; Camco SSSV fa !8!4'
12.Attachments Description summary of proposal [] Detailed operations program []
Adding perforations to a new interval and refrac
13. Estimated date for commencing operation
December 20, 1987
True Vertical depth
TVD
TVD
14. If proposal was verbally approved
Name of approver
Date approved
15. I hereby certify that the [oregoing is true and correct to the best of my knowledge
Signed .~,~.~. ~/~~~~ Title Sr. Operations Engineer
Date12/17/87
Commission Use Only
Conditions of approval
Notify commission so representative may witness
[] Plug integrity [] BOP Test [] Location clearance
Approved Copy
Returned
Commissioner
[ Approval No....~ .--- F~ ~, ~_
ORIGINAL SIGNED BY
Approved by LONNIE C. SMITH
by order of
co i ion
Submit in triplicate
Form 10-403 Rev 12-1-85
ARCO Alaska, Inc.
Post Office B( ~0360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
January 24, 1985
Mr. C. V. Chatterton, Chairman
Alaska Oil and Gas Conservation Commission
3001 Porcupine Drive
Anchorage, AK 99501
Dear Mr. Chatterton:
Attached in duplicate are subsequent notices
following wells at the Kuparuk River Field:
Well Action Date Performed
2V-1 Conversion 12/18/85
2V-4 Conversion 12/19/85
2V-5 Conversion 12/19/85
2V-6 Conversion 12/19/85
2V-8 Conversion 12/18/85
3B-2 Conversion 12/29/85
3B-5 Conversion 12/29/85
3B-10 Conversion 12/29/85
3B-16' Conversion 12/29/85
3C-2 Conversion 12/30/85
3C-5 Conversion 12/30/85
3C-7 Conversion 12/30/85
3C-12 Conversion 12/30/85
on the
If you have any questions, please
J. M. Drumm
Kuparuk Operations Coordinator
TMD/kmc
Attachment (Duplicate)
call
me at 263-4212.
RECEIVED
, /NN 2 7 1986
NaS~ .(}it & Gas Cons. commission
._.....~ ~ 'Anchorage
ARCO Alaska, Inc. is a Subsidiary of AtlanticRIchfieldCompany
STATE OF ALASKA
ALASKA OiL AND GAS CONSERVATION COMMISSION
SUNDRY NOTICES AND REPORTS ON WELLS
1. DRILLING WELL []
COMPLETED WELL
OTHER []
2. Nameof Operator 7. Permit No.
ARCO ALA
SKA, INC. 85-26
3. Address 8. APl Number
P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50- 029-21 289
4. Location of Well
SURFACE LOCATION' 228' FSL, 802' FEL, SEC. 16,
T12N, RDE, UM
5. Elevation in feet (indicate KB, DF, etc.)
85' (RKB)
6. Lease Designation and Serial No.
ADL 25633, ALK 2566
9. Unit or Lease Name
KUPARUK RIVER UNIT
10. Well Number
3B-16
11. Field and Pool
KUPARUK RIVER FIELD
KUPARUK RIVER. O! L
POOL
12.
Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data
NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF:
(Submit in Triplicate) (Submit in Duplicate)
Perforate [] Alter Casing [] Perforations [] Altering Casing
Stimulate [] Abandon [] Stimulation [] Abandonment
Repair Well [] Change Plans [] Repairs Made [] Other
Pull Tubing [] Other [] Pulling Tubing ~
(Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.)
13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any
proposed work, for Abandonment see 20 AAC 25.105-170).
On December 29, 1985 Kuparuk well 3B-16 was converted
producer to a water injector well as part of the full
waterflood conversion effort. Water is being injected
"A" and "C" sands.
from a
field
into both
the
14. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Signed -~-. ~"~ ~'<-~ - Title KUPARUK Date
The space below for Commission use OPERAT IONS COORD I NATOR
1/23/86
Conditions of APproval, if any:
By Order of
Approved by COMMISSIONER the Commission
Date
Form 10-403
Rev. 7-1-80
Submit "Intentions" in Triplicate
and "Subsequent Reports" in Duplicate
ARCO Alaska, Inc.
Post Office B 00360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
December 9, 1985
Mr. C. V. Chatterton, Chairman
Alaska Oil and Gas Conservation Commission
3001 Porcupine Drive
Anchorage, AK 99501
Dear Mr. Chatterton:
Attached are our notices of intention to
field wells 3B-2, 3B-5, 3B-10, 3B-16, 3C-2,
3C-12 to water injection wells.
If you have any questions, please call me at
convert Kuparuk
3C-5, 3C-7, and
263-4212.
T. Mark Drumm
Kuparuk Operations Coordinator
TMD:ps:Fi le
Attachment (In Triplicate)
ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
SUNDRY NOTICES AND REPORTS ON WELLS
1. DRILLING WELL [] COMPLETED WELL
2. Name of Operator
ARCO ALASKA, ! NC.
3. Address
P. O. BOX 100360, ANCHORAGE, ALASKA 99510
OTHER []
4. Location of Well
SURFACE LOCATION. 228' FSL, 802' FEL, SEC. 16,
T12N, RgE, UM
5. Elevation in feet (indicate KB, DF, etc.)
85'
12.
7. Permit No.
85-26
8. APl Number
50- 029-21 289
9. Unit or Lease Name
KUPARUK RIVER UN IT
10. Well Number
3B-16
11. Field and Pool
KUPARUK RIVER FI ELD
I6. Lease Designation and Serial No. KUPARUK R I VER O I L
(RKB) ADL 25633, ALK :2566 POOL
Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data
NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF:
(Submit in Triplicate) (Submit in Duplicate)
Perforate [] Alter Casing [] Perforations [] Altering Casing []
Stimulate [] Abandon [] Stimulation [] Abandonment []
Repair Well [] Change Plans [] Repairs Made [] Other []
Pull Tubing [] Other ){~] Pulling Tubing []
(Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.)
13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any
proposed work, for Abandonment see 20 AAC 25.105-170).
It is proposed that Kuparuk well 3B-16 be converted from a producer
a water injection we l I. The we l I has produced from both the "A" and
"C" sands. Injection will be into both sands also.
to
ANT ICI PATED START DATE-
January 1, 1986
14. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Signed ~'/'/~ ~'~/¢,~-~---~ Title KUPARI IK
The space below for Commission use OPERAT IONS COORD I NATOR
oate 12/6/85 -
Conditions of Approval, if any:
Approved by
By Order of
COMMISSIONER the Commission
Form 10~,03
Rev_ 7-1-20
Submit "Intentions" in Triplicate
and "Subsequent Reports" in Duplicate
ARCO Alaska, Inc.
_ ~. Post Office Box 100360
..'~ Anchorage, Alaska 99510-0360
"'~ Telephone 907 276 1215
..
·
_
:... -,.: - .. :. ·
..
R~TURN TO= ARCO ~J&SKA, :]:NC.
KUPARUK OPERATIONS ENGIN~:~RING
R/~COKD$' CLERK
ATO-1115B
P.O. BOX 100360
ANCHORAGE, AK 99510
DATE: 10-31-85
TRANSMITTAL NO: 5421
TRANSMITTED HEREWITH AR~ THE FOLLOWING ITEMS.
RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL.
FINALS/ SCHL/ CEMENT
<ONE * OF EACH>
~lA-3 / CEMENT. EVALUATION TOOL
-lB-4~ .CEMENT EVALUATION TOOL
~lR-9 /' CET LOG
1R-10~ CET LOG
~IR-11 / CET/CEL
-1R-12" CET LOG
~2A-13 - CBL/VDL
2A-13 / C~:T/CEL
J2U-3--- CEMENT EVALUATION TOOL
'~2U-10/ CEMENT EVALUATION TOOL
'~2Z-13/ CET LOG
"27.-14 ~ CET LOG
"2Z- 15~ CET LOG
~2Z-16-. CET LOG
~3B-4/ CEMENT EVALUATION TOOL
~3B- 12" CET LOG
~3B-12 '~ CEMENT EVALUATION LOG W/ AC
~3B-16 ~'" CEMENT ~VALUATION TOOL
~3C-9/ CET LOG
~3C-10~ CET LOG
PLEASE ACKNOWLEDGE
05-04-85 RUN #1 7468-8287
05-28-85 RUN #1 7200-7995
07-17-85 RUN #1 5990-8084
07-16-85 RUN #1 7500'8632
07-25-85 RUN %1 5744-7129
07-26-85 RUN #1 4992-8144
07-13-85 RUN #1 6388-7554
07-24-85 RUN #1 6382-8032
03-26-85 RUN #2 6100-6600
05-19-85 RUN #1 5450-6950
07-09-~5 RUN #1 6000-8411
07-09-85 RUN #1 5500-8173
07-01-85 RUN #1 2700-6617
~7-01-85 RUN #1 6100-8011
05-31-85 RUN #1 6000-7743
07-14-85 RUN #2 6139-8089
0'7-06-85 RUN #1 5500-8096
05-09-85 RUN #1 6186-7762
07-14-85 t~UN ~1 7485-8210
07-14-85 RUN %1 8190-8805
RECEIPT ACKNOWLEDGED:
DIST~{ISUTION:
BPAE DRILLING*BL W. PASHER
B. CUKKIE}< L. JU~NSTON ' · ~XXON
CHEVRON MOBIL PHILLIPS OIL
D & M NSK CLEkK*BL J. RATHMELL
- , -"' '"-
SOHIO
UNION
VAULT/~0' FILMS
ARCO Alaska, Inc. /-"~
Post Office B :00360
Anchorage, Alaska 99510
Telephone 907 276 1215
September 17, 1985
Mr. C. V. Chatterton
Commissioner
State of Alaska
Alaska Oil & Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, AK 99501
SUBJECT' Well Completion Reports
Dear Mr. Chatterton'
Enclosed are Well Completion Reports for the following wells-
2E-14
2E-15
2E-16
3B-16
If you have any questions, please call me at 263-4944.
Sincerely,
d. Gruber
Associate Engineer
JG/tw
GRU11/L63
Enclosures
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany
STATE OF ALASKA .... .
ALASKA .L AND GAS CONSERVATION CL..,MISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
1. Status of Well Classification of Service Well
OIL [~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] . -
2'. Name of Operator 7. Permit Number
ARCO Alaska, Inc. 85-26
, ,
3. Address 8. APl Number
P. 0. Box 100360, Anchorage, AK 99510 50- 029-21289
r
4. Location of well at surface 9. Unit or Lease Name
228' FSL, 802' FEL, Sec.16, T12N, RgE, UM Kuparuk River Unit
At Top Producing Interval 10. Well Number
1674' FNL, 1299' FWL, Sec.21, T12N, RgE, UM 3B-16
At Total Depth 11. Field and Pool
1702' FNL, 1254' FWL, Sec.21, T12N, RgE, UM Kuparuk River Field
, ,
5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool
85' RKB ADL 25633 ALK 2566
12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions
03/31/85 04/06/85 04/07/85*I N/A feet MSLI 1
1"7. :l-otal Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where ssSv set 21. Thickness of Permafrost
7878'MD,6341 'TVD 7768'MD,6245'TVD YES [~X NO [] 1827 feet MD 1600' (Approx)
,,
22. Type Electric or Other Logs Run
DIL/SFL/SP/GR, FDC/CNL, Cal, Gyro
23. CASING, LINER AND CEMENTING RECORD
SETTING DEPTH MD
CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED
lb" 62.5# H-40 Surf 97' 24" 265 sx PF "C"
9'5/8" 36.0# J-55 Surf 3409' 12-1/4" 920 sx AS Ill & 360 sx :lass G
7" 26.0# J-55 Surf 7858' 8-1/2" 375 sx Class "G" & 250 ix AS I I
,,
24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD
interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD)
7627' - 7592' w/4 spf, 120° phasing 3-1/2" 7481' 7224' & 7457'
7574' - 7538'
26. ACID, FRACTURE, cEMENT SQUEEZEi ETC.
7385' - 7432' w/12 spf, 120° phasing DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED
7516' - 7518' 100 sx Class G
,
See attached Adde ,dum, dated 7/26/85, fOr frac dated.
27. N/A PRODUCTION TEST
Date First Production Method of Operation (Flowing, gas lift, etc.)
Date of Test Hou~sTested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SiZE IGAs-OILRATIO
TEST PERIOD I~
....
Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER~BBL OIL GRAVITY-APl (corr)
Press. 24-HOUR RATE I~
~8. CORE DATA
Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE k£C[IV[D
~iaska Oil & Gas C0rls. Commission
'~nchora,ge
Form 10-407 * NOTE: Tubing was run and the well perforated 5/20/85. GRU11/WC13 Submit in duplicate
Rev. 7-1-80 CONTINUED ON REVERSE SIDE
29. 30.
GEOLOGIC MARKERS FORMATION TESTS
NAME Include interval tested, pressure data, all fluids recovered and gravity,
MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase.
.,
Top Upper Sand 7382' 5916' N/A
Base Upper Sand 7419' 5946'
Top Lower Sand 7528' 6037'
Base Lower Sand 7676' 6164'
31. LIST OF ATTACHMENTS
Addendum
32. I hereby certify that the foregoing is true and correct to the best of my knowledge
! ~ ,, /~,'i ~ Associate Engineer Date / /~) ~t~;:~
Signed ~j~? ,,,/.,~J ~/~.~ _/'. ..... Title ~_ ;.~,
INSTRUCTIONS
General: This form is designed for submitting a complete and correct well completion report and log on
all types of lands and leases in Alaska.
Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt
water disposal, water supply for injection, observation, injection for in-situ combustion.
Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements
given in other spaces on this form and in any attachments.
Item 16 and 24: If this well is completed for separate production from more than one interval (multiple
completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported
in item 27. Submit a separate form for each additional interval to be separately produced, showing the
data pertinent to such interval.
Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.).
Item 23: Attached supplemental records for this well should show the details of any multiple stage cement-
ing and the location of the cementing tool.
Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In-
jection, Gas Injection, Shut-in, Other-explain.
Item 28: If no cores taken, indicate "none".
Form 10-407
ADDENDUM
WELL:
4/t5/85
6/t~/s5
3B-16
Arctic Pak w/41.4 bbls AS I, followed by 55 bbls Arctic
Pak.
Frac well w/336 bbls gelled diesel in 8 stages w/1050#
100 mesh & 10,920# of 20/40 sand.
Dri~intendent
RECEIVED
SEP ~ 9 I98§
Alaska Oil & Gas Cons. Commission
Anchorage
· Bate
ARCO Alaska, In¢ '~
Posl Office ~ox 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
DATE: 0~-3 0-~ 5
TRANSMITTAL N0:5315
At{CO ALASKA, INC.
KUPARUK OPERATIONU ENGINEERING
RECORDS CLERK
ATO-1115B
P.O. BOX 100360
ANCtlORAGE, AK 99510
TR~N$IqlTI'ED HEKEW I
RECEIPT AND RETURN
CSL FINAL PRINTS/S
~'~ 3B- 14 04-1U-85 RUN #1 4695-6672
~3B-16 04-12-U 5 RUN #1 5860-7758
~"~3B- 4 05-07-85 RUN #1 57~2-775~
~313-15 04-12-U5 RUN #1 6693-8357
~'~3b-2 05-U7-85 RUN #1 4885-8158
q 3B-3 05-07-85 RUN #1 4770-6495
2U-12 05-04-85 t<UN #1 6100-7409
~-3B-13 O4-1U-U 5 RUN #1 56~9-7921
TII ARE TIlE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE
ONE SIGNED COPY OF THIS TRANSMITTAL.
CHL/ONE * OF EACH
RECEIPT ACKNO%,LEDGLD:
D1S'Z'RI }3U T i(3N:
DPAE bt(ILLING ~i_.-- W. PAStiER
S. CU]{RiLR L. JOi-INbT~N LXXON
ChLV~UN MOBIL PIlILLIPS OIL
b & M NSK CLERK*BL ~. I<ATIiMELL~
DATE: ..... ~.:: ,,,~ ; ,.
STATL O[" AL'2{S-~7[*IJL
SOHIO /SE
U Iq I
K. TULIN/VAULT*FILM
ARCO Alaska, lng '.
Post Office x 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
DATE: 08-21-85
TRANSMITTAL NO: 5292
Ri~T URN TO:
ARCO aLASKA, INC.
KUPARU K OPERATIONS
RECORDS CLERK ,
ATO-1115B
P.O. BOX 100360
ANCHORAGE, AK 99510
ENGINEERING
TRANSMITTED
HERE%$ITH ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE
RN ONE
SSURE REPORT--ENVELOPE FACE DATA
CAMCO -~3B- 15 ·
CAMCO 3B-16 -' ~''
CAMCO ~ 3C- 11-"
CAMCO
CAMCO
CAMCO
CAMCO
CAMCO
CAMCO
CAMCO
C~2~IC0
CAMCO
CAMCO
CAMCO
CAMCO
OTIS
DRESSE~{
OTIS
OTIS
t~ECEIPT AND RETU
KUPARUK WELL PRE
' lB-1 .... 05-30-85
1B-2~ 05-30-85
'~iB- 4~ ' 05-16-85
-' 1C-4 07-24-85
~- 1C-6~' 07-25-85
- 1D-8-~ '07-30-85
--1H-3 ' 07-30-85
~' lQ-13j 06-24-85
"' lQ- 14~' 06-23-85
XlQ-15 ...... 06-21-85
"lQ- 16~' 06-21-85
~ 1R-5~'-~ 07-05-85
' 1R-6-/ 07-06-85
~lR-7/ 07-06-85
-' 1R-8 ~' 07-08-85
~2A-2 .... 07-04-85
·
"2W-7''~ 07-26-85
~2V-3 07-11-85
~-2W- 15" 08-04-85
3B-1- 06-14-85 ????
3B-2~-~'' 06-14-85 CAMCO
'-3B-3~ 06-28-~5 OTIS
~3B-3~ 06-15-85 CAMCO
~3B-4~ 06-15-85 CAMCO
"3B-5/ 06-26-85 -CAMCO
3 B- 6 ~ O 6- 26- 85 CArd, CO
--3B- 7'~ 06-28-85 CAMCO
3B-7 / 06-27-85 CAMCO
3B-8~' 06-28-85 OTIS
--3B- 9~ 07-18- 8 5 CAMCO
~3B- 10-" 07-20-85 CAMCO
'-3B-11-~ 07-20-85 CAMCO
3B-12 .... 07-21-85 CAMCO
3B-13- 05-29-8 5 OTIS
'-'3B-14 05-29-85 OTIS
RECEIPT ACKNOWLEDGED:
SIGNED COPY OF THIS TRANSMITTAL.
05-28-85 OTIS
05-28-85 OTIS
07-29-85 CAMCO
DISTRIBUTION:
W. PAShER
EXXON
PHILLIPS OIL*
J. RATHMELL*
BPAE* DRILLING
B. CURRIER L. JOHNSTON
CHEVRON* b~BIL*
D & M* NSK CLERK
STATE OF ALASKA*
SOH I O*
UNION*
K. TULIN/VAULT
ARCO Alaska, Inc. ~s a Subsidiary of AllanticRichfieldCompany
ARCO Alaska, ir?-''', ' --
Post Offic,. ~ox 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
DATE:07-16-85
TRANSMITTAL NO:5252
RETURN TO:
TRANSMITTED
RECEIPT AND
ARCO ALASKA, INC.
KUPARUK OPERATIONS
RECORDS CLERK
ATO-1115B
P.O. BOX 100360
ANCHORAGE, AK 99510
ENGINEERING
HEREWITH ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE
RETURN ONE SIGNED COPY OF THIS TRANSMITTAL.
OPEN HOLE
(ONE * OF
3B-13 ~.'5"
2"
5"
2"
5"
2"
3B-14
FINAL PRINTS/SCHL
EACH-)
DIL/SFL-GR 03-09-85 RUN #1 3657-8014
DIL/SFL-GR 03-09-85 RUN #1 3657-8014
DEN/NEU PORO 03-09-85· RUN #1 5900-7989
DEN/NEU PORO 03-09-85 RUN #1 5900-7989
DEN/NEU RAW 03-09-85 RUN #1 5900-7989
DEN/NEU RAW 03-09-85 RUN #1 5900-7989
CYBERLOOK 03-09-85 RUN #1 3657-8014
/
~/5~ DIL/SFL-GR 03-20-85 RUN #2 3311-6770
2" DIL/SFL-GR 03-20-85 RUN #2 3311-6770
5" LITHO DEN/NEU PORO 03-21-85 RUN #2 6100-6774
2" LITHO DEN/NEU PORO 03-21-85 RUN #2 6100-6774
5" LITHO DEN/NEU RAW 03-21-85 RUN #2 6100-6774
2" LITHO DEN/NEU RAW 03-21-85 RUN #2 6100-6774
5" LONG SPACING SONIC 03-20-85 RUN #2 3311-6731
2" LONG SPACING SONIC 03-20-85 RUN #2 3311-6731
5" (AND 25") MICROLOG 03-21-85 RUN #2 6100-6735
2''' MICROLOG 03-21-85 RUN #2 6100-6735
CYBERLOOK 03-22-85 RUN #2 6111-6727
DUAL DIPMETER-GR 03-21-85 RUN 92 3311-6774
3B-16
5" DIL/SFL-GR 04-06-85 RUN #1 3412-7828
2" DIL/SFL-GR 04-06-85 RUN #1 3412-7828
5" DEN/NEU PORO 04-06-85 RUN #1 4300-7805
2" DEN/NEU PORO 04-06-85 RUN #1 4300-7805
5" DEN/NEU RAW 04-06-85 RUN #1 4300-7805
2" DEN/NEU RAW 04-06-85 RUN #1 4300-7805
CYBERLOOK 04-06-85 RUN #1 7150-7890
RECEIPT ACKNOWLEDGED:
BPAE
B. CURRIER
CHEVRON
D & M*BL
DISTRIBUTION:
DRILLING*BL W. PASHER
L. JOHNSTON EXXON
MOBIL PHILLIPS OIL
NSK CLERK*BL J. RATHMELL*BL
DATE:
-.
STAT
SOHIO
UNION
K. TULIN/VAULT*FILMS
ARCO Alaska, Inc is a Subsidiary of AtlanticRichheldCompany
ARCO Alaska, Inc.
Post Office Box ~00360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
June 18, 1985
Mr. C. V. Chatterton
Commissioner
State of Alaska
Alaska Oil & Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, AK 99501
SUBJECT: 38-16
Dear Mr. Chatterton-
Enclosed is the Well Completion Report for 38-16.
any questions, please call me at 263-4944.
Sincerely,
Gruber
Associate Engineer
JG/tw
GRU9/L69
Enclosure
If you have
i ,ECEIVED
J u N 2 :i. 1985
.,~!aska bd & Gas Cons. Commission
Anchorage
ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany
.... .~-~- STATE OF ALASKA ~--.
, ALASKA .~ AND GAS CONSERVATION Ct /IlSSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
1. Status of Well Classification of Service Well
OIL I~(x GAS [] SUSPENDED [] ABANDONED [] SERVICE [] .-.
,,.
2. Name of Operator 7. Permit Number
ARCO Alaska, Inc. 85-26
,.
3. A~ldress '' 8. APl Number
P. 0. Box 100360, Anchorage, AK 99510 50- 029-21289
,
4'. Location of well at surface 9. Unit or Lease Name
228' FSL, 802' FEL, Sec.16, T12N, RgE, UM Kuparuk River Unit
At Top Producing Interval 10. Well Number
1674' FNL, 1299' FWL, Sec.21, T12N, RgE, UM 3B-16
At Total Depth 11. Field and Pool
1702' FNL, 1254' FWL, Sec.21, T12N, RgE, UM Kuparuk River Field
5'. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool
85' RKBI ADL 25633 ALK 2566
,
12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions
03/31/85 04/06/85 04/07/85*I N/A feet MSLI 1
1"7. 'l:'otal Depth (MD+TVD) 18. Plug Back' Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 1 21. Thickness of Permafrost
7878'MD,6341 'TVD 7768'MD,6245'TVD YES [~X NO [] 1827 feet MD/ 1600' (Approx)
22. Type Electric or Other Logs Run
DIL/SFL/SP/GR, FDC/CNL, Cal, Gyro
23. CASING, LINER AND CEMENTING RECORD
SETTING DEPTH MD
CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED
16" 62.5# H-40 Surf 97' 24" 265 sx PF "C"
9-5/8" 36.0# J-55 Surf 3409' 12-1/4" 920 sx AS III & 360 sx ;lass G
7" 26.0# J~55 Surf 7858' 8-1/2" 375 sx Class "G" & 250 ;x AS I
,
24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD
interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD)
7627' - 7592' w/4 spf, 120° phasing [" 3-1/2" 7481' 7224' & 7457'
7574' - 7538'
26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
7385, - 7432, w/12 spf, 120° phasing DEPTH INTERVAL (MD) AMOUN~- & KIND OF MATERIAL USED
7516' - 7518' 100 sx Class G
,
27. N/A PRODUCTION TEST
Date First Production Method of Operation (Flowing, gas lift, etc.)
Date of Test Hours Tested PRODUCTIoN FOR ;OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO
TEST PERIOD I~
..
,
Flow Tubing Casing Pressure CALCULATED,1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr)
Press. 24-HOUR RATE ~
'"~8. CORE DATA'
Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips.
Alaska 0ii & Gas Cons. o0mmissi0~
Anchorage
,,
Form 10-407 * NOTE: Tubing was run and the well perforated 5/20/85. GRUg/WC49 Submit in duplicate
Rev. 7-1-80 CONTINUED ON REVERSE SIDE
29. 30.
GEOLOGIC MARKERS FORMATION TESTS
NAME Include interval tested, pressure data, all fluids recovered and gravity,
MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase.
Top Upper Sand 7382' 5916' N/A
Base Upper Sand 7419' 5946'
Top Lower Sand 7528' 6037'
Base Lower Sand 7676' 6164'
31. LIST OF ATTACHMENTS
W~.ll Hi.~tory (compleX. ion d~ils~
32. I hereby certify that the foregoing is true and correct to the best of my knowledge
Signed (~ ~//~ .~~L,~" Title Associate Engineer Date
INSTRUCTIONS
General' This form is designed for submitting a complete and correct well completion report and log on
all types of lands and leases in Alaska.
Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt
water disposal, water supply for injection, observation, injection for in-situ combustion.
Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements
given in other spaces on this form and in any attachments.
Item 16 and 24' If this well is completed for separate production from more than one interval (multiple
completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported
in item 27. Submit a separate form for each additional interval to be separately produced, showing the
data pertinent to such interval.
Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.).
Item 23: Attached supplemental records for this well should show the details of any multiple stage cement-
ing and the location of the cementing tool.
Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In-
jection, Gas Injection, Shut-in, Other-explain.
Item 28: If no cores taken, indicate "none".
Form 10-407
ARCO 011 and Gas Company
Well History- Initial Report- Daily
Inetructlona: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are stinted.
Daily work prior to spudding should_be summarized on the form giving inclusive dates only,
District
IState
Alaska
Alaska
Field
Kuparuk River
Auth. or W.O. no.
AFE 604461
Roll'N 4
ICounty, parish or borough
North Slope Borough
Lease ADL 25633
or
Unit
Title Completion
Well no,
3B-16
API 50-029-21289
Operator
ARCO Alaska, Inc.
Date [Hour
5/16/85
Spudded or W.O. begun
Complete
Date and depth
as of 8:00 a.m.
5/16/85
5/17/85
5/18/85
thru
5/20/85
Complete record for each day reported
7" @ 7858'
7768' PBTD
Moving rig.
IARCO W,I.
Prior status
i000 hrs.
7" @ 7858'
7768' PBTD, 7878' TD, Prep to stage cmt
10.2 ppg NaC1/NaBr
~ccept ri~ @ 1000 hrs, 5/16/85. ND tree, NU & tst BOPE. RU DA
WL, perf 7516'-7518' w/4 SPF, RD DA. TIH w/Howco Champ pkr,
set @ 7243'. Tst ann on p~r; OK. M&P 100 sx C1 "G" w/l%
CFR-2; .2% Halad-24 & 5% KC1. Displ w/bride. Prep to stage
cmt.
7" @ 7858'
7768' PBTD, 7878' TD, Space out
10.2 ppg NaC1/NaBr
Fin staging cmt sqz @ 1/4 - 1/2 BPM @ 2500 psi. Rev circ, TOH.
TIH w/bit & WOC. Tat cmt @ 7215'. Drl hard cmt & cln out to
PBTD, CBU, POOH, LD DP. RU DA. Perf "A" sand w/4 rns total
f/7627'-7592' & 7574'-7538'. Perf "C'~ sands f/7432'-7385'. Rn
I~[ I!
GR/JB. RIH w/perm pkr, set @ 7462~, ~OOH, RD DA. RIH w/3½
CA. Prep to space out.
RECEIVED
Alaska Oil & Gas Cons. Commission
Anchorage
56.24%
if a w.o.
The above is correct
For form preparation and distribution, ~
see Procedures Manual, Section 10,
Drilling, Pages 86 and 87.
6/05/85
Drilling Superintendent
ARCO Oil and Gas Company
Daily Well History-Final Report
Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold.
"Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not
required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire
operation if space is available.
Alaska North Slope Borough
Field ~hease or Unit
Kuparuk River I ADL 25633
Auth. or W.O. no, ~Title
AFE 604461 I Completion
Roll'N 4
Operator I A.R.Co.
ARCO Alaska, Inc.
Spudded or W.O. begun ~Oate
Complete
5/21/85
Date and depth
as of 8:00 a.m.
Complete record for each day reported
cost center code
Alaska
IWell no.
3B-16
API 50-029-21289
W.I. ~otal number of wells (active or inactive) on this
56.24% Icost center prior to plugging and
Jabandonment of this well
I
IHour I Prior status if a W.O.
5/16/85 / 1000 hrs.
!
7" @ 7858'
7768' PBTD, 7878' TD, RR
Diesel/Crude
RIH w/232 its, 3½", 9.3#, J-55 EUE 8RD IPC tbg & ind. Drop
ball, set pkr, shear PBR, re-lnd tbg. Set BPV. ND BOPE, NU &
tst tree. Displ well to crude. Tst SSSV. RR @ 2400 hrs,
5/20/85.
SSSV @ 1827'.- Retrv Pkr @~'l - "D" Nipple @ 7472' I
Tailpipe @ 2A~f'. ~Z~ PerTT'), p~ ~
d74~i"
Old TD I New TD I PB Depth l
Released rig IDatel l KZ~of~ri?
2400 hrs. 5/20/85 Rotary
Classifications (oil, gas, etc.) ] Type completion (single, dual, etc,)
Oil J Single
Producing method ' 0~ficia'
. . reservoir name(s) · .
Flowing Kuparuk sands
Potential test data
Well no. Date Reservoir I Producing Interval Oil or gas Test time Production
Oil on test Gas per day
Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date
corrected
The above is correct
For form preparation and di~ribution,
see Procedures Manual, Section 10,
Drilling, Pages 86 and 87.
IDate 6/05/85 ITM
Drilling Superintendent
ARCO Alaska, Inc.
Post Office [~'~ 100360
Anchorage, A,,~ka 99510-0360
Telephone 907 276 1215
Date: 6/12/85
Transmittal No.: 5212
Return To:
ARCO Alaska, Inc.
Attn: Records Clerk
ATO-1115-B
P.O. Box 100360
Anchorage, AK 99510
.Transmitted herewith are the following items. Please acknowledge receipt
and return one signed copy of this transmittal.
Otis Static Gradient Final Report
'"2A-2 5/27/85
--.2H-1 5/27/85
~'--3B-14 5/29/85
~.~3B-15 5/28/85
_~'3B-16 5/28/85
Receipt Acknowledged:
BPAE
B. CURRIER
DISTRIBUTION
DRILLING W. PASHEE
L. JOHNSTON EXXON
SOHIO
CHEVRON
MOBIL
PHILLIPS DIL ·
UNION
D&M
J. RATt~ELL
K. TULIN/VAULT
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany
ARCO Alaska, Inc.
Post Office Box ~00360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
May 31, 1985
Mr. C. V. Chatterton
Commi s s i oner
State of Alaska
Alaska Oil & Gas Conservation
Commi ss ion
3001 'Porcupine Drive
Anchorage, AK 99501
SUBJECT: 3B-16
Dear Mr. Chatterton:
Enclosed is an addendum to the 3B-16 Well History to include with
the Well Completion Report dated 05/23/85.
If you have any questions, please call me at 263-4944.
Sincerely,
Gruber
Associate Engineer
JG/tw
GRU9/L24
Enclosure
RECEIVED
JUN 1 2 1 85
Alaska 0il & Gas Cons. Commission
Anchorage
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany
ADDENDUM
WELL:
4/15/85
3B-16
Arctic Pak w/41.4 bbls AS I, followed by 55 bbls Arctic
Pak.
Drilling ~uperint'endent
RECEIVED
JUN 1 ~ Lo85
Alaska Oil & Gas Cons. Commission
..¢~/~nchpra§e
Date
ARCO Alaska, Inc.
Post Office ~,~,, 100360
Anchorage, Alaska 99510-0360
Telephor~e 907 276 1215
May 24, 1985
Mr. C. V. Chatterton
Commi s s ioner
State of Alaska
Alaska Oil & Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, AK 99501
SUBJECT- 3B-16
Dear Mr. Chatterton'
Enclosed are the Well Completion Report and gyroscopic survey for
3B-16. The tubing details will be submitted when the well is
completed.
If you have any questions, please call me at 263-4944.
Sincerely,
GrUber
Associate Engineer
JG/tw
GRU9/L05
Enclosures
RECEIVED
0 ]985
Alaska Oil & O~s Cons. Commission
Anchorage
ARCO A~aska, Inc. is a Subsidiary of AtlanticRichfieldCompany
,,~-'-~ STATE Of ALASKA
ALASKA ~.AND GAS CONSERVATION Ct /IlSSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
1. Status of Well Classification of Service Well
OIL [] GAS [] SUSPENDED I~X ABANDONED [] SERVICE [] .....
, ,
2. Name of Operator 7. Permit Number
ARCO A1 aska, Inc. 85-26
3, Address 8. APl Number
P, 0, Box 100360, Anchorage, AK 99510 50- 029-21289
4. Location of well at surface ....................... 9. Unit or Lease Name
228' FSL, 802' FEL, Sec.16, T12N, RgE, UM ;~r.J~.f~l!~lq~j Kuparuk River Unit
At Top Producing Interval
1674' FNL, 1299' FWL, Sec,21, T12N, RDE, UH isurL __ ~ 10. Well Number
3B-16
At Total Depth B.H. 11 Field and Pool
1702' FNL, 1254' FWL, Sec.21, T12N, RgE, UM Kuparuk River Field
'~. Elevation in feet (indicate KB, DF, etc.) J 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool
85' RKBJ ADL 25633 ALK 2566
,
'i'2. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions
03/31/85 04/06/85 04/07/85J N/A feet MS LI N/A
i7. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost
7878'MD,6341 'TVD 7768'MD,6245'TVD YES I~X NO [] N/A feet MD 1600' (Approx)
22. Type Electric or Other Logs Run
DIL/SFL/SP/GR, FDC/CNL, Cal, Gyro
23. CASING, I~INER AND CEMENTING RECORD
SETTING DEPTH MD
CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED
16" 62.5# H-40 Surf 97' 24" 265 sx PF "C"
.... 9-5/8" 36.0# J-55 Surf 3409' 12-1/4" 920 sx AS Ill & 360 sx I;lass G
7" 26.0# J-55 Surf 7858' 8-1/2" 375 sx Class "G" & 250 ;x AS I
,
24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD
interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD)
None N/A
26. ACID, FRACTURE, cEMENT SQuEEzEi ETC.
DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED
N/A ,
,.,
27. N/A PRODUCTION TEST
Date First Production Method of Operation (Flowing, gas lift, etc.)
Date of Test Hours Tested PRODUCTION FOR ;OIL-BBL GAs~McF WATER-BBL CHOKE SIZE IGAS-OILRATIO
TEST PERIOD ~
I
'"Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRA~/ITY-API (corr)
Press. 24,HOUR RATE ~
'28. CORE DATA
.....
Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips.
NONE
RECEIVED
Alaska 0ii & Gas Cons. C0mrnissinr~
,..
Form 10-407 TENP/WC12
/-{~)ch°~nit in duplicate
Rev. 7-1-80 CONTINUED ON REVERSE SIDE
29 .... 30.
GEOLOGIC MARKERS FORMATION TESTS
NAME .. Include interval tested, pressure data, all fluids recovered and gravity,
MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase.
,,.
Top Upper Sand 7382' 5916' N/A
Base Upper Sand 7419' 5946'
Top Lower Sand 7528' 6037'
Base Lower Sand 7676' 6164'
31. LIST OF ATTACHMENTS
We!! H!sto?y, r_.y~-n,~np!c Survey (_P O O p J e ~ )-
32. I hereby certify that the foregoing is true and correct to the best of my knowledge
(~ ~ ~)~J_~(j~L.,/ Title Associate Engi neer Date ~I_ ~) _ ~
Signed
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
ARCO Oil and Gas Company
Well History - Initial Report - Daily
Iltatl'~ctlona: Prepare and submit the "Initial ReMit" on the tirst Wednesday after a well is spudded or workover operations are started.
Daily work prtor to spudding should be summarized on the form giving inclusive dates only.
District IC°unty' parlsllor borough I State
Alaska North Slope Borough Alaska
Field ILea" or Unit lWell no.
Kuparuk River I ADL #25633 I 3B-[6
Auth. or W.O. no, ~Title
AFE 604461 I Drill, Complete & Perforate
Parker #141 API 50-029-21289
Operator IARCO W I
ARCO Alaska, Inc. J 56.24%
Spu~dedorw. O. begUnspudded IDar°3/31/85 IH°ur0445 Hrs. ]Pr,orstatusifaW.O.
Date and depth
aa of 8:00 a.m.
Complete record for each day reported
3/31/85
thru
4101185
4/02/85
4104185
The above ia correct
Signature
16" @ 97'
2578', (2481'), TOH
Wt. 9.2+, PV 10, YP 15, PH 9.0, WL 13, Sol 6.8
Accept ri~ @ 0000 hfs, 3/31/85. NU diverter sys. Spud well @
0445 hfs, 3/31/85. Drl 12¼" hole to 2578'.
1986', 6.5°, SS1W, 1985.71TVD, 7.36 VS, 1.21S, 7.61
2520', 18.2°, S62W, 2505.79 TVD, 122.32 VS, 40.53S, 116.36
9-5/8" @ 3409'
3319' PBTD, (741'), Tst csg to 1500 psi
Wt. 9.2, PV 10, YP 12, PH 8.5, WL 13, Sol 10
Drl & surv 12¼" hole to°~r~, s~ort trip, C&C, TOH. RU & rn
78 jts, 9-5/8", J-55, 36# BTC csg to 3409', FC @ 3319'. Cmt
w/920 sx AS III, followed by 360 sx C1 "G" w/2% CaCi~ & .2%
D-46. Displ'd mud using rig pmps, bumped plug. Circz cmt to
surf. Displ & bump plug. Holding press @ report time.
2653', 21.2°, S63.5W, 2630.99 TVD, 167.14VS, 61.06, 156.21
2996', 29.9°, S62.3W, 2940.60 TVD, 314.25VS, 127.73, 287.37
3202', 39.1°, S66.5W, 3191.76 TVD,. 488.41VSy 202.62, 444.62
9-5/8" @ 3409'
4480', (1161'), Drlg 8½" hole
Wt. 8.8, PV 6, YP 9, PH 10.5, WL 20, Sol 4
Tst csg to 1500 psi. ND diverter sys. NU &tst BOPE. TIH
w/8½" BHA, tst csg to 1500 psi. DO cmt & flt equip + 10' new
hole. Conduct leak-off tst to 12.5 ppg EMW, TOH, PU turbine,
TIH, drl & surv to 4480'.
3593', 46.4°, S69.2W, 3403.64 TVD, 687.11 VS, 276.53S, 629.67W
4091', 46.5°, S68W, 3746.76 TVD, 1046.82 VS, 408.23S, 965.72W
9-5/8" @ 3409'
5925', (1445'), Drlg 8½" hole
Wt. 9.3, PV 9, YP 11, PH 9.0, WL 8, Sol 7.2
Drl & Surv f/4480'- _~__', TOH & PU rotary assy. TIH, rotary
table overheard. S~f~ed TOH & went back to btm; no problems.
Drl & surv ~-5925'..
4433', 47.5°, S65W, 3980 TVD, 1296.68, 507.97S, 1195.10
4901', 50.3°, S58.9W, 4287.65 TVD, 1649.15, 673.81S, 1506.34
5216', 49.'6°, S56.5W, 4490.34 TVD, 1888.88, 802.66S, 1710.16
5409', 50°, S57.3W, 4614.91TVD, 2035.20, 883.16S, 1833.65
RECEIVED
Anchorage
For form preparation and dlat~bu~o~-, ~' -
see Procedures Manual Section 10,
Drilling, Pages 86 and 87.
IDate 4/30/85 ITM
Drilling Superintendent
ARCO Oil and Gas Company
Daily Well History-Final Report
Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned. or Sold.
"Final Report" should be submitted also when operations are suspended for an indefinite or appreciable ;ength of time On workovers when an official test is not
required upon completion, report completion and representative test data in blocks prowded The "Final Report" form may be used for reportmg the entire
operation if space is available.
District
Alaska
Field
Kuparuk River
Auth. or W.O. no,
AFE 604461
Parker #141
Operator
ARCO Alaska, Inc.
Spudded or W.O. begun
Spudded
Date and depth
as of 8:00 a.m,
4/05/85
thru
4/~F~/85
4/07/85
ICounty or Parish
Lease or Unit
Title
Accounting cost center code
State
North Slope Borough Alaska
ADL #25633
Drill, Complete & Perforate
API 50-029-21289
IA.R.Co. W.t.
56.24%
Date 3/31/85
Complete record for each day reposed
I otal number of wells (active or inactive) on this
est center prior to plugging and
bandonrnent of this well
I
our I Prior status if a W.O.
0445 Hrs.
7" @ 7858'
7768' ?B, (1953'), RR
Drl & surv 8½" hole to 7781', C&C f/logs, TOH. RU loggers,
logs would not go below 7360', POH. TIH, drl & surv
7781'-7878', C&C, TOH. RU loggers, log DIL/SFL/SP/GR
f/7828'-3412', FDC/CNL f/7805'-4300', Cal f/7856'-6300', RD
loggers. TIH, C&C, TOH, LD DP. Chg rams to 7" & tst. RU & rn
190 jts, 7", 26#, J-55 BTC csg w/PBTD @ 7768'. Cmt w/375 sx C1
"G" cmt. Bump plug. ND BOPE, set slips & pack-off, tst to
3000 psi. RR @ 1800 hrs, 4/7/85.
5912', 49.4°, S55.4W, 2415 TVD, 2416 VS, 1096, 2153
6567', 51.4°, S54.3W, 5344 TVD, 2924 VS, 1396, 2572
6878', 46°, S55W, 5544 TVD, 3148 VS, 1527, 2757
7377', 34.6°, S58.6W, 5924 TVD, 3468 VS, 1704, 3027
7746', 27.2°, S58.5W, 6241TVD, 3657 VS, 1803, 3189
Arctic Pak w/41.4 bbls AS I, followed by 55 bble Arctic Pak.
no.
3B-16
Old TD New TD
7878' (4/5/85) 7768'
Released rig Date
1800 Hrs.
Classifications (oil, gas, etc.)
0il
PB Depth
I K nd of r g
4/7/85 Rotary
Type completion (single, dual, etc.)
Single
Producing method Official reservoir name(s)
Flowing Kuparuk Sands
Potential test data
Well no. Date Reservoir Producing interval Oil or gas Test time Production
Oil on test Gas per day
,,,
Pump size, SPM X length Choke size i T.P. C.P. Water % GO~ Graviiy Allowable
corrected
Th~ above is correct
......................... O~tlI'BIoSIOFI
Signature J Date I Title
.qcho~
~/)~ ~,-,-L4
For form preparation and d~tribution,
see Procedures Manual, Section 10,
Drilling, Pages 86 and 87.
S UB-$ URFA CE
DIRECTIONAL
SURVEY
~-~ UIDANCE
r~-] ONTINUOUS
r-~ OOl
Company
Well Name
Field/Location
ATLANTIC RICHFIELD COMPANY
3B-16 (228' FSL~ 802' FEL~ S16, T12N. R9E. UM5
KUPARUK, NORTH SLOPE, ALASKA
Job Reference No.
70336
ko~3~ed By:
~TEST
Date
25-APR~El~8~ i V E D
Computed By:
Anchorage
~ $CHI, UMB~RG~R ~
CUSTOMER LISTING
FOR
ARCO ALASKA, INC,
KUPARUK
NORTH S6~PE,AbASKA
SURVEY DATE: 12 APR fl5
ENGINEER! T,
METHODS OF CnMPUTATION
TOOL 60C~TION: TANGENTIAL- averaged deviation and azimuth
TNTERPOLATION: LIWEAR
VFRTICAL SECTION: HOR?Z, DZST, PROdMCTED ONTO A TARGET AZINIITH OF' SOUTH 63 DEG 52 MIN WEST
ARCO AbASKA,
3B-]6
NORTH SLOPE,ALASKA
COMPUTATION DAT~: 26-APR-85
PAGE
DATE OF SURVEYt 12 APR 85
KELLY BUSHING EbEVATIONt
ENGINFEP: T, WEST
INTERPOLATED VAbU~$ FOR EVEN ~00 FEET OF MEASURED DEPTH
T~UE SUB-SEA COUR$~
tEA&URED V~RTICAL VERTICAL DEVIATION AZIMU?H
DEPTH DEPTH DEPTH DEG MIN D£G MIN
-85 O0
15 O0
{15 O0
~15 O0
315 O0
415 O0
515 O0
615,00
715,00
814,99
0,00
100 O0
200 O0
300 O0
400 O0
500 O0
600 O0
?00 O0
800 O0
899 99
999 99 014 09
1009 90 1014 99
99 1114 09
90 1214 09
90 131! 99
99 1414 09
98 ~514 ~8
98 614,98
96 1714,96
88 i8i4,88
0 14 S 55 25
0 16 S 29 4 E
0 17 S 11 51 E
020 S 2
021 S 6 49 W
024 $ .10 17 W
0 26 $ 46 36 W
0 53 S 78 44 W
1 1 N 86 33 w
3 3g S 75 26 w
0.00
lO0 O0
2OO O0
300 O0
4O0 O0
5OO O0
600,00
700,00
800,00
O00,O0
S 79 1. W
S 76 12 W
S 73 58 w
S 67 46 W
S 64 5n w
S 60 57 W
S ~3 16 W
S 64 44 W
S 65 8 W
S 65 12 W
10!4,46 6 43
2013,44 9 14
2111.75 12 ?
10 2709.10 14 20
51 2305,51 15 ~O
20 2401.29 17 44
60 2495 69 20 30
67 2588~67 22 37
1~ 2680,12 ~5 1
77 2769,77 97 43
I000.00
1100,00
1~00 O0 1199
1300 O0 1299
1400 O0 1399
150~ O0 ~499
1600 O0 1599
1700 O0 1699
1800 O0 17o~
1900 O0
$ 65 20 W
S 65 44 w
S 66 12 w
$67 14 W
$ 67 45 W
$ 67 41 w
S 68 O W
8 68 10 w
S 67 40 w
$ 67 30 w
2000.00 t9q9 46
2100,00 20~8 4
2~00,00 2196 ~5
2300,00 ~294
2400,00 ~300
2500,00 2486
2600.00 2580
2700,00 ~673
2800,00 2765
2000.00 2854
85,00 FT
-2,44
-2,40
-2.22
-1.92
-1.,55
'1,06
0.14
1.61
5.11
13,00
27.67
45,57
68,25
94.74
123,45
193,17
233,61
277,88
326.49
37q.55
437,10
49~,47
564,19
633,44
704,q2
77~,10
852.03
925,72
0 00
0 22
0 08
0 '11
0 10
0 22
0 14
0 09
0
0,2~
0,07
0,15
0,07
0,31
0,40
0,37
0,~5
O, 8
3,14
3,80
86
3 38
3 27
2 46
2 10
2 77
2 54
2,51
2 39
2 45
2 96
4 1!
3 14
1,77
1,62
0,95
0,58
1,08
0,00 N
O, 14 S
0 O0 S
0 23 N
0 28 tu
0 21 N
0 ~0 N
0 03. N
0 01N
0,00
0,04 W 0
0,0! W 0
0,14 E '0
0,39 E 0
0'73 E 0
1,11E 1
15E
2,31 E 2
0 O0 N 0 0 E
14 S 15 50 W
0
1 S'8! 42 W
27 N 3'0 6 g
48 N 53 49 g
76 N 74 6 g
N 84 41 r
55 N 87 19 ')
95 N 8q 2: c,
N 89 39 g
0 13 S
0 46 S
0 90 S
1 45 $
08 S
73 S
3 36 S
3788
3 84S
4 37 S
2 66 E
2 95 E
3 12 g
3 18 E
3 .16
3 06 E
2 82 E
170 E
O:09
3,55
2 66 S 87 13 E
98 S 81 7 E
24 S 73 50 E
50 S 65 28 g
78 ,5 56 40 E
11 ,S 48 16 g
39 S 40 2 g
15 S 24 7 E
84 S '1 21 g
63 S 392 W
6 32 S
9
14
21
32
45
61
77
94
11.2
1
16 S 226
03 S 43
86 $ 65
02 S ~9
66 S 115
24 S 144
20 S 177
28 S 213
87 S 254
39 iv 13 91 S 62 58
32 w 27 87
87 vi 46 06 S 72 t6 w
30 w 68 86 $ 71 29
82 w 95 35 S 70 22
10 W 123 83 S 68 21
14 W 156 61 S 66 58
29 W 193,37 S 66 28
96 W 233,81 S 66 13 W"
14 W 278,08 S 66 3
133 23 S 298 30 W 326 70 S 65 55 W
155 23 $ 346 61 W 379 78 S 65 52 W
178
202
228
254
336
71S 399 19 W 437
95 $ 455 65 W 498
10 S 516 52 W 564
48 S 580. 72 W 634
4] $ 647,11. W 705
60 $ 715,29 W 779
43 $ 783,99 W 853
61S 852,25 W 926
37 S 65 52 W
81 S 65 59 W
65 S 66 10 W
03 S 66 20 W
66 S 66 29 W
03 S 66 39 W
13 S 66 46 ~
97 $ 66 50 w
3000 oo ~942 14 2857,14 30 ~5
3100:00 3026 87 2041,87 33~8
3200,00 3108 61 3023,61 36 36
3300,00 3187 40 3102,49 39 24
3400 O0 3262 7~ 3177,72 42 47
3500 O0 3334 71 3249,91 44 53
3600 O0 3404,46 3~19,46 46 36
3700 O0 3472,36 3387,36 47 43
3800 O0 3539,50 3454.50 47 41
3900 O0 3606,93 3521,03 47 IR
O,O0
0 10
-0.23
-0.47
-0.74
-1,04
-1,42
-2,08
VERTICAb DOGbEG RECTANGULAR COORDINATES HORIZ, DEPARTURE
SECTION SEVERITY NORTH/SOUTH E~ST/WEST DIST, AZIMUTH
FEET DEG/IO0 FEET FEET FEET DEG MIN
ARCO ALASKA, TNC.
KUPARUK
NORTH 5LDPE,ALASKR
IEA$1IRED VERTICAb VERTICRb DEVIA?ION AZIMU?H
DEPTH DEPTH DEPTH DEG MIN DEG M.IN
CnHPU?A?ION DATE: 26-APR-SS PAGE 2
DATE OF SURVE¥~ 12 APR 85
KgbbY BUSHING EbEVATION~
ENGINEERI T, WES~
INTERPOLATED VA[,U~$ FOR EVEN 100 Fg~T OF MgASUR£D DEPTH
VERT?¢Ab DO~G REC?ANGUDAR COORDINATES HORI[~ DEPAR?DRE
SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH
FEET DEG/100 FEET FEET FEET DEG ~IN
4000.00 3675 05 3590.05 46 58
4100 O0 3743 38 38 7
,90 46 ~8
4200 O0 ~811
4300 O0 3879
4400 O0 3946
4500 O0 4012
4600 O0 4078
4700.00 4144
6800,00 4209
4900,00 4273
83 3794,83 47 40
45 3061,45 48 21
80 3927 80 48 48
60 3n93:60 48 38
27 4059.27 49 14
38 4124,38 49 33
83 4188,83 50 9
5000 O0 4338 02
5100
5~00
53O0
5400
5500
560g
57O
5800
5900
02 49 57
O0 44O2
O0 4461
O0 453
O0 4596
O0 4661
O0 4725
O0 4790
O0 4855
O0 4920
4253,
47 43i7,47 49 46
18 4382,18 49 39
86 4446,~6 49 44
45 4511,45 49 50
01 4576.01 49 48
76 4640 76 a9 38
39 4705:39 49 44
1 4770 21 49 2~
;
1 4835.0! 49 46
6000.00 4984 36 4899.36 50 14
6100.00 5047 74 4962.74 51 16
6200.00 5109 ~5 5024.35 52 39
6~00.00 5084.04
5169
640O O0 52~7
6500 O0 5286
6600 O0 5348
67OO O0 5412
6800 O0 5478
6900,00 5547
O4 53 55
18 51.4~, 18 54 27
30 52o . 9 52
09 5263.09 50 54
1~ 5327 18 49 22
44 5393:44 47 25
)0 5462,30 45 34
7000,00 5618 51 5533,51
7100,00 5692 34 5607.34
.00 ~848
7400,00 5910
7500,00 6013
7600,00 6098
7700,00 6i84
oo.oo
78,00 6341
43 34
41 17
16 5684,16 38 26
86 5763,86 35 57
68 5845.68 34 33
66 5928,66 33 5
30 6013.30 31 19
75 6099.75 ~8 45
2 6187.72 28 29
5 6~56,35 78 22
S 66 33 w 998.82
S 65 53 w 107!.77
S 65 38 w 1144 57
S 64 52 W 1217 92
S 62 5 W 1292 48
S 60 36 W I]67 24
S 58 35 W 1442
$ 58 21 W 1517 38
S 58 19 W 159~ 93
S 58 20 W 1669 03
8 57 41 W 1745 32
S 56 49 W 1821 26
S 56 5 W 1896
$ 55 27 W I972
$ 54 36 W 2047
S 53 21 w 21.23
S 53 31W 2197
S 53 44 w 2273
S 53 50 W 2348
S 53 55 W 2423
87
37
82
05
98
08
07
08
S 53 44 W 2498.45
S 53 21 W 2574 54
S 53 4 W 2651 94
S 52 48 W 2730 73
S 52 44 W 2~10 59
S 52 31W 2889 60
$ 52 40 W 2966,77
S 52 9 W 3042,01
S 52 46 W 3115.37
S 52 45 W 3186.54
S 53 14 W 3255,48
S 53 20 W 3321.78
$ 54 38 W 3384.85
$ 56 37 W 3444,58
S 58 7 W 3501,74
S 57 45 W 3557.22
S 57 30 W 3610,15
$ 58 4 W 3660,08
$ 58 14 W 3707,40
S 58 14 W 3744.28
0 45
0
0 13
2 43
0 78
2 44
0 83
0 20
0 47
0 41
0,79
0,73
0,85
0,64
0,90
0,5t
0,79
23
0,43
1,29
1,57
0
2 24
2 29
1 63
2 63
1,73
1,96
2,39
1,31
1,63
1,75
O0
0,00
85,00 FT
452
483
516
552
59O
629
669
709
59 S 1052
58 $ 11
10 S 1252
45 S 1316
94 S 1381
78 $ 1445
91 $ 1510
84 W !146
62 w 1219
21 W 1293
06 w 136
8
86 w 1443
iOW 1517
7O W i593
79 w 1669
37 $ 66 39 W
81 S 66 28 W
38 S 66 12 W
$ 65 8 W
27 $ 64 49 W
750 49 S 1575 85 W 1745 43 S 64 32 W
791 85 S lb40 16 W 1821 30 S 64 13 W
833
876
920
965
1010
1056
96 $ 1703
85 S 1766
57 $ 1829
50 ~ 1891
93 S 19~
12 $ 2013
O8 $ 2075
96 8 2136
71 w 1
w
36 W 2047
W 2198
77 W 2273
24 W 2349
77 W 2424
87 S 63 55 W
39 S 63' 36 W
93 S 63 17 W
.32 $ 62 57 W '
50 S 62 37 W
91 S 62 19 W
25 $ 62 3 W
67 S 61 47 W
12
1284
133
138~
1430
1478
1525
1571
1614
14 8 2198,56 w 2500 49 S 61 33 W
12 S 2260,76 W 2577 11 S 61 18 w
27 S 2323,84 W 2655 11 $ 61 4 W
55 S 2387.92 W 2734 56 5 60 50 W
71S 2452,75 W ~815 16 S 60 36 W
70 S 2516.73 w 2894 96 S 60 22 W
52 $ 2579.23 w 2972 95 S 60 10 "'
30 S 2640,08 W 3049 03 S 59 58
14 S 2699,30 w 3123 25 S 59 47 W
90 S 2757,1i W 3195,24 S 59 38 W
1657 18 8 2813,16 W 3264
1697 43 S 2867,26 w 3332
1734
1769
1799
t829
1858
1885
1910
t929
94 $ 2919,~0 W 3~
11 $ 2968, 8 W 3
94 S 3017,41 W 3513
62 S 3064.66 W 3569
23 S 3109,57 W 3622
16 S 3151,98 W 3672
19 5 3192.41 W 3720
70 S 3223,92 w 3757
98 S 59 29 W
03 $ 59 22 W
76 $ 59 16 W
Ol S 59 12 W
48 S 59 10 W
26 S 59 9 w
49 $ 59 8 W
71 $ 59 7 W
25 S 59 6 w
31 $ 59 5 w
393 21 S 919 63 W 1000 '3,7 $ 66 50 W
422 67 $ 986 44 W 1073 18 S 66 48 W
O0 S 66 44 w
ARCO ALASKA, INC.
3B-16
KUPARUK
NOR?H SLOPE,ALASKA
TRUE SUB-SEA COURSE
EASURFD VERTICAL VERTTCAb DEVIATION AZIMUTH
DEPTH DEPTH DEPTH PEG MIN DEG.
0.00
1000.00 999
2000.0 1 09
3000.n~
4000,00 3675
5000.00 4338
6000,00 49"4
7000,00 5618
787g,00 6341
0 O0
99
COMPUTATION DATE:'26-APR-85 PAGE
DATE OF SURVEY: 12 APR 85
KELLY BUSHING ELEVATION{
ENGINEER~ T, WEST
INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPT
VERTICAL D'OGbMG RECTANGULAR COORDINATES HORIZ,= DEPARTURE
SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH
FEET DE~/!00 FEET FEET FEET DEG SIN
N 0 0 E 0.00 0.00
S 55 25 E '~.33 0.28
S 79 I W 13.90 3.80
S 65 20 W 326.49 2.39
S 6b 33 W 998.82 0.45
S 57 4! W 1745,32 0.79
S 53 44 W 249~.45 0.43
S 58 14 W 3744.28 0'00
-85 O0 0 0
i99 0 14
gl~ 4 6 43
~6 10 6
14 281~ 14 30 35
05 3590 05 46 58
02 4~53.02 49 59
36 4,99.36 50 ~4
15533.~ 43 4
~5 6256. 28 22
0,00 N
0.13 S
6 3~ S 12
133 23 S 298
393 21 $ 9~9
750 49 S 1575
! 1852
1929 70 $ 3
39 W 1~
30'W 32
63 w 100
85 w 1745
56 w 2500
16 w 3
85,00 FT
0 00 E 0 O0 N 0 0 E
2 66 E 2 66 S 87 13 g
91 S 62 58 W
70 S 65 55 w
17 S 66 50 W
64
31 S 59 5 ~
ARCO ALASKA, INC.
35-16
KUPaRUK
NORTH SLUPE,AI,ASKA
COhPU?AT[ON DATE126-APR-85 PAGE
DATE OF.SURVEY: 12 APR 85
KELLY BUSHING EbEVATIONI
ENGINEER; T, WEST
INTERPOLATED VALUES FOR EYEN 100 FEET OF SUB-SEA DEPTH
TRUE SUB-SEA COURS~
IEASURED V£RTICAL VERTICAL DEVIATION AZIMUTH
DEPTH D~PTH DEPTH PEG MIN DEG MTN
0 O0
85 O0
185 O0
285 O0
385 O0
4~500
5a5 O0
6~5 O0
785 O0
885 O0
-85,00 0 0 N 0 0 E
o.oo o 4 w
loo oo o .
30 ,000' 011 ~ 8732 ~
400,00 0 O 6 64 17 ~
500,00 0 15 S 79 51 ~
600,00 0 14 S 8738 £
700,00 0 14 S 84 49 F
800,00 0 12 S 81 52
0 O0
85 O0
185 O0
285 O0
385 O0
485 O0
585 O0
685 O0
785 O0
885 01
085 O1 985 O0 O00 O0
1085 01 1085 O0 1000 O0
01 1185
O1 1285
O1 1385
O1 1485
02 1585
02 !685
04 1785
09 1885
O0 1100 O0
O0 1200 O0
OOoo
on 1500,00
O0 1600,00
O0 1700,00
O0 1800,00
0 14 S 60 5 £
0 15 S 29 56 E
0 16 ~ 15 20 E
0 19 S 3 24 E
0 2~ $ 4 40 W
0 2~ ~ ~0 6 W
0 24 S 38 4 W
0 52 S 77 2~ W
0 57 . 87 1~ ~
3 10 S 76 51 w
1185
1285
1385
1485
1585
1685
1785
1885
6 13
O0 2000,00 8 50
O0 21.00,00 11 41
O0 2~00,00 !4 11
O0 2~00 O0 15 46
O0 2400~00 17 41
O0 2500.00 20 35
O0 2600,00 22 57
O0 2700,00 25 35
O0 2800,00 28 31
85,00 FT
1~8~,45 1985 On 1000,00
2086,39 20a5
2187,99 2185
2290,61 7285
2394,27 2385
2498,65 24~5
260460 25~5
2712'29 2685
2822:00 2785
2934,~? 2885
VERTTCRb DO~LEG RECTANGULAR COORDINATES HORZZ, DEPARTURE
SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH
FEET DEG/IO0 FEET FEET FEET DEG
I 50,15 2985 O0 2900,00 32 13
70,74 3085 O0 3000,00 35 48
3~96,76 ~185 O0 3100,00 39 16
3430,57 '3285 O0 3200,00 4337
3571,80 3385 O0 3300,00 46 9
372 ,818 3485 O0 3400,00 ~7 51.
38b?,61 3585 O0 3500,00 47 3~
4014.57 3685 O0 3600,00 47 0
4160,62 3785 O0 3700,00 46 48
4307,68 3885,00 3800,00 47 48
0,00
0,08
0,05
-0,19
-0,43
0,72
0,99
1,37
1.72
-2,04
~,30
,44
'~,42
-2,25
-1,97
'1,61
'1,16
-0,08
1,39
4,24
S 78 55 W 12,~3
S 77 17 W 25,56
S 74 11 W 43,13
$ 67 41 W 65.94
S 65 37 W 93,18
S 60 57 w 123,03
S 63 24 W ~57.99
S 64 48 W 197,q3
S 65 7 W 243,03
S 65 15 W 294.01
$ 65 20 w
S 66 OW
567 12 w
352.52
419.83
496.41
S 67 40 W 585.08
8 67 59 W 684.56
S 68 5 W 792.00
S 67 34 w 901.94
$ 66 28 w 1009.46
S 65 43 W 1115,83
S 64 39 W 1223,60
0,00
0
0
o
0 ~
0 05
0 O5
0 04
0,15
0 03
0 14 '
0 15
0 10
0 40
0 25
0 5'/
0 32
0:28
3 50
3,14
2,33
,87
~,,29
3,08
2,4i
2,30
2,71
2,21
3,05
3 35
9'/
! 98
1 68
0 58
0 4!
0 gO
2 76
0 O0 N
0 13 S
1 ~
0,~9 N
0 23 N
0 12 ~
0 0'7 ~,
0 04 N
0,02 ~
O, 10 S
0,40 S
0835
1~36 S
1998
2635
3288
3745
3858
4 lSS
8 7 $
13 35 ,5
20 98 S
31 36 $
0'00 E
0 02 W
003 W
0 11 E
0 34 E
0 69 g
I 05 E
149 g
189 E
2 26 E
2 61 E
2 91 E
3 10 E
3 18 E
3 17 F
3 09 E
2 90 F
192 E
0 35 E
2 68 W
10 79 w
24 22 W
41 49 w
63 15 W
88 40 w
0 O0 N 0 0 E
13 $ 10 24 W
05 S 36 53 W
24 N 27
3
E
45 N 50 9
E
73 N 71 50 E
05 N 8~43 r,'
49 N 8. 7 )
26 N 89 23 E
2 61 S 87 51 E
2 94 S 8212 E
21 S 74 58 E
46 S 66 46 g
74 S 57 55 E
05 S 49 35 E
38 S 41 28 g
20 S 27 14 g
87 $ 5 7 g
95 $ 32 51 ~
12 35 S 60 52 W
25 73 S 70 i8 ~
43 59 $ 72 9 W
66 55 $ 71 37 W
93 80 S 70 27 W
45
61
79
98
119
46 S 114
97 S 145
23 S 181
24 S 222
64 S 268
74 W 123
58 W 158
59 W 198
50 W 243
80 W 204
42 S 68 23 W
21 S 66 56
12 S 66 25 ~ /
22 S 66 10 W
22 S 66 0 W
144 05 S 3~1 98 W 352 74 S 65 53 W
171 70 S 383 40 W 420 09 S 65 52 ~
45
3
202 15 $ 76 W 496
236 04 S 535 89 W 585
273 81S 628 17 W 685
313 79 S 72823 W 702
355 54 S 830 20 W 903
397 46 S 929 40 W 1010
440,75 S 10~6,64 W 1117
485,43 S 1124,76 W 1225
75 S 65 59 W
57 S 6613 W
26 S 66 26 w
96 S 66 41W
13 $ 66 49 w
83 S 66 50 W
25 S 6645 W
04 $ 66 39 W
APCO ALASKA, TNC,
38'16
NORTH SLOPE,ALASKA
TRUE SUB'SEA CflURSF
IEAS[!RED VERTICAL VERTTCRL DEVIATION AZIMUTH
DEPTH DEPTH DEPTH DEG
COMPUTATION DATEr 26-APR-85 PAGE 5
DATE OF SURVEYt 12 A~H ~5
KELLY BUSHING ELEVATION,
ENGINEERI T, WEST
.INTERPUE, ATED VALUES FOR EVE)) 100 FEET DF SUB-SEA DEPTH
VERTICAL DOGLEG RECTANGULAR COORDINATES HOR[Z, DEPARTURE
SECTION SEVERITY NORTH/SOUTH ERST/WEST DIST, AZIMUTH
f'EET DEG/IO0 FEET FEET FEET PEG
85,00 FT
445? 94 3985 O0 3900 O0 48 24
4609:67 4085 O0 4000 O0 48 4!
476~48 41~5 O0 4~00 00 49 25
4917.42 4285 00 4200
5072.92 4385 O0 4300
5227.52 4485 O0 4400
5382,26 4585 O0 4500
5537,{4 4685 O0 4600
5691,66 4?85 O0 4700
5845,~8 4885 O0 4800
O0 50 6
O0 49 50
O0 49 41
O0 49 49
O0 49 3q
O0 49 45
O0 49 35
6001.00 49~:00
6160 12 508 O0
s 27: a
6809:67 548 O0
55~ O0
6q5~,4[
7090 23 5685,00
,35 5885,00
4900 O0 50 15
5ooo:oo s
5100 O0 54 21,
5~00 O0 53 0
5)00 O0 50
5400 O0 47 12
5500 O0 44 31
5600 O0 41 31
5700 O0 37 57
ssoo:oo
7465.70
584.41
~ . 0
59~5 O0
6otm5 O0
6185 O0
6285 O0
6341 35
5900.00 ~3 4~
6000,00 31 36
6100,00 ~8 44
6~00.00 28 2~
6256,35 78 22
S 61 41W 1335.72
S 58 31 W 1440.5.3
S 58 19 W 1564,54
$ 58 15 W 1682,34
S 57 2 W 1800,72
S 55 54 W 19~7 64
$ 54 48 W 2034 44
S 53 24 W 215~ 92
$ 53 43 W 2266 82
$ 53 53 W 238~ 42
S 53 44 W 2499.20
S 53 11 W 2620.92
S 52 51 W 2752.39
S 52 3! W 2887.78
S 52 2'2 W 3010,61
S 52 55 W 312~,35
$ 52 5~ W 3223.68
S 53 25 W 3315.44
S 54 51 W 3397.16
S 57 38 W 3470.12
S 57 41 W 3538.48
$ 57 23 W 3607.06
S 58 5 W 3660.~2
S 58 14 W 3714.00
$ 58 14 W 3744.28
1,75
17
I'27
0 63
0 83
0 6!
0 4
o
0,43
1,26
1,63
2,.06
1 76
2 27
2 53
1 97
2 71
1 10
2 '37
I 91
4 5~
0 O0
0 O0
536 90 $ 1224
594
654
716
78O
845
912
982
1052
1121
23 S 13~3
80 S 1421
93 S 152
55 S 162~
69 S 172
74 S 181~
35 S 20
66 S 2103
40 W 1336 95 S 66 19 W
05 W 1450 37 S 65 48 W
43 w 1565
17 W 1682
81W 1800
09'W 1917
30 W 2034.
84 W 2151.
64 W 2267
41W 2383
01 S 65 15 W
55 $ 64 46 W
78 $ 64 18 W
64 'S 63 49 W
53 $ 63 ~,09 '*"
62 ~ 6~ 20 .
79 S 61 55 W
1345
1429
1505
1575
59 S ~199
31S 2298
88 S 2405
57 $ 25i5
68 S 2614
43 S ~704
77 S 2787
59 S 2862
4 S 2929
7 S 2990
17 W 2501
58 W 9623
50 W ~756
25 w 2893
73 W 3017
97 W 3130
25 W 3232
O8 W 33~5
28W 3408
48 W 3481
25 S 61 32 W
83 S 61 10 W
41 S 60 46 W
12 $ 60 23 W
26 $ 60 3 W
31 S 59 46 W
81 S 59 33 W
62 S 59 23 W
.19 S 59 15W
71 $ 59 [1 W
1819,58 S 3048 71 W 3550 42 S 59 10 W
1853,84 S 3102 71W 3614 36 S 59 8 W
1885,23 S 3152 10 W 3672 85 S 59 7 W
1913'68 S 3198 04 w 3726 88 S 59 6 W
1929,70 S 3223 92 W 3757 31 S 59 5 W
ARCO ALASKA, INC,
KUP~Rt!K
NOR?H SLOPE,ALASKA
~ARKER
TOP UPPER SAND
BASF UPPER SAND
TOP bOWER SAND
BASE LOWER SAND
PRTD
TD
COMPUTATIOh DATE~ 26-APR-85
INTERPOLATED VALUES FOR CHOSEN HORIZONS
MEASURED DEPTH
BELOW KB
7419 00
75~8 O0
7676 O0
7768 O0
7878 O0
PAGE; 6
DATE OF SURVEY'. ~2 APR 85
KELbY BUSHING EbEVATIONI BS,00 F~
ENGINEERS T, WEST
SURFACE bOCATZON
AT
ORIGIN= 228' FSb,802' FEb-SEC 16~T12N.RgE.[IM
TVD RECTANGUbAR COORDINATES
FROM K5 SUB-SEA NORTH/SOUTH EAST/WEST
5915,88
5946,35
6037,19
61.63 80
6244!56
6t41 35
5830 8~
586 35
595~ 19.
6078 80
6159 56
6256 35
1794.52
1805.60
1837,75
1878.95
1902,Je
1929.70
3008' 72 W
3142 *
ARCO Ab~SKA~ INC.
KUPhRUK
NORTH SLOPE~ALASKA
MARKER
TOP UPPDR SAND
BASE lIPPED SAND
TOP bOWeR SAND
BASF LOWER SAND
PBTD
TD
COMPUTATION
MEASURED DEPTH
BELOW KB
7382 O0
7419 O0
7528 O0
7676 O0
7768 O0
7878 O0
PAGE
DATE OF SURVEY~ 12 APR 85
KEbbY BUSHING EbEVATION~
ENGINEER~ T,: WEST
SURFACE bOCATION
,AT
OR~GIN= 228' FSb,802* FE~SEC 16~12NoR9EoU~
TVD RECTANGULAR COORDINATES
FRO~ KB SUB-SEA NORTH/SOUTH EAST/WEST
5915,88
5946 35
6t63.00
6244.56
63~1,35
5830,88
586 35
595~ ~q
6078 80
6159 56
6256 35
1794 52 $
805 60 $
837 ~5 $
1878 95 $
1929 70 S
3008,72 W
0 6
02"/7 '54 W
,48 W
85,00 F~
FINAL WE[,b 6DCATION AT TD~
T~UE SUB-SEA
NEASURED V~RTICAL VERTICAL
DEPTH DEPTH DEPTH
HORIZONTAl,, DEPARTURE
DISTANCE AZIMUTH
FEET DEG
7878,00 b341.3§ 6256,35 3757,31: $ 59 5 W
SCHLUMBEROER
O I RECT I ONIqL SURVEY
COMPANY ARCO ALASKA !NC
WELL :~B- ! 6
F ! ELD KUPARUK
COUNTRY USA
RUN ONE
DATE LOOOEO 12 APR 85
REFERENCE 0000?0336
WELL NAME: 3B- 1~
SURFACE LOCATION: 228' FSL, 802' FEL-~ S16, T12N, R9E, UM
--- , VERTICAL PROJECTION
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SO00
24~.
PROJECTION ON VERTICAL PLANE 243. - 6~. SCALED IN vERTICAL DEPTHS HORIZ SCALE = 1/1000 IN/FT
' WELL NAME: 3B- 16
SURFACE LOCATION: 228' FSL, 802' FEb, S16, T12N, R9E, UM
HORIZONTAL PROJECTION
NORTH 4000 R£F 0000?0336
3000
2000
1ooo
-1000
-2000
-3000
SOUTH -4000
-5000
5CRLE = l/lO00 IN/FT
-4000 -3000 -2000 - 1000 0 1000 ZOO0
9000
Suggested form to be inserted ~,a each "Active" well folder to check
for timely compliance with our regulations.
O~ER~TOR,' I~L~ N~ ~ NI]KBER
Date
Required Date Received Remarks
Samples .'M~--? I' - - ' ~K
,,,, ,,
Core Chips .......
Core Description ~ ~
,, ,
Registered Survey Plat. /~3 ~--/~-~ ~¢~,,,.
Drill Stem Test Reports ~~~' ' ..... ~Z
Production Test Reports .. ~
y,igitized Data ye; ,
ARCO Alaska, Inc.
Post Office Box 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
i:~ETUI?N TO'
ARCO AI..A.2KA, INC,
AT'¥N: RI:':]COF(I)2 [;L. EI:(I(
ATO--t tt5B
F'.O, DOX t00S60
AN[]HOI"~AL;E, Al( 975t 0
F R ~ N 2 H T 1'7' ['" D I"11:.'-. R r..i; W 17' H A RI!..'. T I-'1E F' 0 I... L 0 ~ ~ N rJ 17' I.'-" N,.?,
F:'I...EASE ACI( t','DWLE:I)FJE
':;li[CI:T. IPT AND RETL!F;,'N ONE 2I(.';NIS. D COF'Y OF
;:l l::' [.:. N HOLE L. IZ T~I":"ES' I":"I...U..? L. ISTINg
?;CHi_L.INBEF,:gER (ONE COF:'Y OF' EACH)
-f
I Q-3 0~-S(-)-8_5' F;:Ui'4 :.":t
~l.l..- 8 0,3 ~ "~ :~:
· - ,:. 8 -' I:> .:> R U N t
2U-'9w/ 04-04-8'::; RLIN ¢:t
:2H.- t ,9,"'01 -28-1E.,'.5' RUN
~ B"" 1 1,,' ',":),1. - t ,.-5',-- 8.5 R Lli'4 :.': t
~L"¢-j 5F'0~-29-.85 RL!N :,",:t
~.B-t6'04-06-85 RUN
T H I 2 T R A N S 1't I 'r T A I_ ,
'::' '~ 0- I
..~,... t ,,'-.), 081 5
") 9 ~";
S6"" .5;
. (L-I, ..Y .,2 ~.) ·
:51 t 6 ':'
· - ~..~' ~ !'
3Z"~8 "'- '-'70;5
· ,, ..) '- f
· ., ~' , ,;-, ~,")-g463,
· '~ "z o
,. ,.,c., t , 5-7845,
CURR I ER
I lZ V F;; 0 N
ARCO Alaska, Ind~-'~
Post Office ,..~x 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
Hay 3, 1985
Mrs. Elaine Johnson
State of Alaska
Alaska Oil & Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, AK 99501
SUBJECT: Conductor As-Built Location Plats - 3B Pad
Wells 1-4, 13-16~r~=-T2-
Dear Elaine'
Enclosed are as-built location plats for the subject wells.
you have any questions, please call me at 263-4944.
Sincerely,
Gruber
Associate Engineer
JG/tw
GRU6/LI01
Enclosures
If
Alaska Oil & Gas Cons. Commission
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany
WELL t Y=5,991,896,45 Let. 70°23'20.5210''
I X= 518,178.72 Lor~ 149°51'07.673''
_~~ I OG. Elev. 49.6 Pad Elev. 54.6
776' ~L 852' ~L
I WELL 2 Y=5,~1,956.26 Lat. 7~2~'21.1094"
X= 518~172.79 Long. 149°51'0~84~''
~ 0.~ Elev. 49.5 Pad Elev. 54.2
' o5 WELL ~ Y=5,992,015.79 L~t 70°2~'21.695~''
3e o6 X= 518,167,27 Lon~ 149°51'08.~0"
2. i~07 ~ O.G. EIev 49.2 Pod Elev 54.6
~s o8 J 896' FSL 863' FEL
WELL 4 Y =~992,07~.65 Lot 70° 23'22. Z840"
X= 518,161.64 Long. 149° 51'08.161''
~ ~ O.G. EIev. 4,.0 P~d El,v. 53.9
955' FSL ~68' FEL
WELL t3 Y=5,991, 169.7t Lot. 70° 23'133712"
~ ~ x = 518,247.~ Long. 149° 51'05.6~
~& Etev. 4~.5 ~d Elev. ~4
49' FSL 786' FEL
o9 WELL ~4 Y:5,991,229.62 L~t. 70°2~'lS.9~7''
~ · o10
~5e o~t X= 518,242.16 Long. 149051'05.865'
~4 I QG.9~lev. 49.0 Pad Elev. ~.4
~ · o~z 16~ ~t5 ~0 FSL 792' FEL
~l~i 2~ ~22 WELL ~5 Y 5,~1,z89.13 L~t 70°23'14.5~"
X= 518,25~.44 Long. 149°51'06.0~"
O.G ~Le~.49.0 ~ Elev. ~.7
~ 6 9'FSL 797' F E L
WELL 16 Y=5,9~,~.~ Lat. 7002~' 15.13~"
X= 518,230.7~. L~g. 149°51'~.188'
OG. Elev, 49.0 Pad Elev 55.4
SCALE. N T S 228' FSL ~2' FEL
LOCATED IN PROTRACTED SECTION 16, TOWNSHIP 12N.,
RANGE 9 E., UMIAT MERIDIAN.
HORIZONTAL, POSITION PER LHD'S ON PAD PILING
CONTROL P S. .~,J~ ~gE 0~1 ,~ .... ~ u~:-,, ~.u~,l~ Il'
E 8+30 E 8+30 ...........
VERTI~L PORTION ~R LHD'S ALCAP T~'S 3B-~3B-12. ,
O.G ELEVATI~S INTERPOLATED FR~ S/C D~
CED-9BO0-300~
-I1[ i i
. ~ I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND
s 9 -~ lo ~ j LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF
v CPF {~. /
~ x ~ ~ ~ ~ '~- ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE
~-' ~ ;~~ UNDER MY DIRECT SUPERVISION AND THAT ALL DETAILS
ARE CORRECT AS OF MARCH 3,1~5 FOR WELLS I-4~13-16.
~ i
~7 , ARCO Alosko, Inc.
I CONDUCTOR. AS-BUILT
~ ' LOCATIONS
20 ~ Oate:~ht~t985 Scole' AS SHOWN
/
~--/ I Drawn By' ~.~ Dwg. No. NSK 9.~302d2
i
ARCO Alaska, Inc. ='
Post Office b,,x 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
May 15, 1985
Mr. C. V. Chatterton
Commi s s i one r
State of Alaska
Alaska Oil & Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, AK 99501
SUBJECT:
Dear Mr.
State Reports.
Chatterton'
Enclosed
are the April monthly reports for the following wells'
1 Q- 1 2 U- 10 2 V- 12 9- 28
1Q-2 2u-11 2V-13 3-16 (workover) 17-14
1R-5 2V-10 3B-2 9-16 (workover) L~-9
If you have any questions, please call me at 263-4944.
Sincerely,
d. Gruber
Associate Engineer
JG/tw
GRU6/LI06
Enclosures
Alaska 0;I & Gas Cons. OommJssior~
Anchore. ge
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany
STATE OF ALASKA ---.
ALASKA O,_ AND GAS CONSERVATION CON..,ISSION
MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS
· Drilling well E~ X Workover operation []
2. Name of operator 7. Permit No.
ARCO Alaska, Inc. 85-26
3. Address 8. APl Number
P. O. Box 100360, Anchorage, AK 99510 50- 029-21289
4. Location of Well
at surface
229' FSL, 802'
5. Elevationinfeet(indicateKB, DF, etc.)
85' RKB
FEL, Sec.16, T12N, R9E, UM
9. Unit or Lease Name
Kuparuk River Unit
6. Lease Designation and Serial No.
ADL 25633 ALK 2566
10. Well No.
3B-16
11. Field and Pool
Kuparuk River Field
Kuparuk River Oil Pool
For the Month of Apri 1 ,19 85
12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks
Spudded well ~ 0445 hfs, 03/31/85. Drld 12-1/4" hole to 3426'. Ran, cmt, & tstd 9-5/8"
csg. Drld 8-1/2" hole to 7878'TD as of 4/6/85. Ran OHL. Ran, cmtd, & tstd 7" csg. PBTD
= 7768'. ND BOP. NU tree. Secured well & RR ~ 1800 hfs, 4/7/85.
13. Casing or liner ru.n and quantities of cement, results of pressure tests
16" 62 5#/ft, H-40, weld conductor set ~ 97' Instld w/265 sx PF cmt
9-5/8" 36 O#/ft, J-55, BTC csg w/FS ~ 3409' Cmtd w/920 sx AS Ill + 360 sxs Class "G"
~, · · ·
7" 26.O#/ft, J-55, BTC csg w/FS ~ 7858'· Cmtd w/375 sx Class "G" cmt.
14. Coring resume and brief description
NONE
15. Logs run and depth where run
DIL/SFL/SP/GR f/7856' - 3409'
FDC/CNL f/7856' - 7150' 6500'
,
Cal f/7856' - 7150'
5000' 4600'
- 4300'
16. DST data, perforating data, shows of H2S, miscellaneous data
NONE
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
NOTE--Repo on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska
Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed.
Form 10-404 JMM2/MR02
Submit in duplicate
MEMORANDUM
Statu of Alaska
TO:
T~HRU:
C. V./~terton
ChairM~
Lonnie C. Smith '/"':" ~
Commissioner
FROM: Edgar W. SiPple, Jr -? SUBJECT:
Pe~role~q .Inspector
ALASKA OIL A~]D GAS CONSERVATION CO~.~4ISSION
DATE: April 9, 1985
F,LE NO: D.EWS. 22
TELEPHONE NO:
Witness BOPE Test on
ARCO' s Kupa~uk 3B-16,
Sec. 16, T12N,R9E,U},I,
Permit No. 85-26,
Parker Rig 141.
Tuesday, April 2, 1985: I traveled this date from ARCO's Kuparuk
~J~U-~'9 (SUb~j~et.:°~'~'anO~'~er report) to ARCO's Kuparuk 3B-16, Parker
Rig 141 to witness a BOPE test. The drilling contractor was in the
process of running casing.
The BOPE test commenced at 10:45 am and was concluded at 12:25 pm.
There was one failure. The check valve failed, a new rubber was
installed on the flapper and it tested to 3,000 pounds satisfac-
torily.
I filled out the AOGCC BOPE inspection report which is attached to
this report.
In summary, I witnessed the BOPE test on ARCO's Kuparuk 3B-16,
Parker Rig 141.
Attachment
02-00IA(Rev. 10/79)
: .
O&G #4
'?5/84
STATE OF ALASKA
ALASKA OIL & GAS CONSERVATION COMMISSION
~ ' B.O.P.E. 'inSpection Report
Operator
Location: Sec /~
Drilling Contractor
Location, General
General Housekeeping _~ .~.Rig
Reserve Pit
Mud Systems
Trip Tank
Pit Gauge
Flow Monitor
Gas Detectors
Visual Audio
Z,~, 0~r,eCT,
BOPE Stack
Preventer
L~e Valves
Test Pressure
Date
Representative
f YfCasing Set
Ri ~//~/ Representative
ACC~LATOR SYST~
Full Charge Pressure ~ I ~¢),~
Pressure After Closure /~'~
Pump incr. clos. pres. 200 psig
psig 3foo ,,
psig. l ~ ~
/ min~sec.
~ min / / sec.
Full Charge Pressure Attained:
Controls: Master g~/ ~ ~ 8//~2 ~
Remote ~J Blinds switch cover,
Kelly and Floor Safety, Valves
Upper Kelly ~ ~st PresSure _~
Lower Kelly 0~~est Pressure 3~
Ball Type ~2':~,.. ~est Pressure ~
Inside BOP ~/Test Pressure
Choke Manifold ~'~ Test Pressure
No. Valves * .~ ~~~
Test Results: Failures
Repair or Replacement of failed equipment to be made within days and Inspector/
Commission office notified.
Remarks: ....
No. flanges .~
Adjustable Chokes
HydraUically operated choke
....... Test Time / hr"s
Distribution
orig. - AO&GCC
cc - Operator
cc - Supervisor
12: ~/~--
Inspector~~
SOHIO ALASKA PETROLEUM COMPANY
3111 "C" STREET,
ANCHORAGE, ALASKA
TELEPHONE (907) 561-5111
MAIL: POUCH 6-612
ANCHORAGE, ALASKA 99502-0612
March 6, 1985
Alaska Oil and Gas Conservation Commission
3001 Porcupine Drive
Anchorage, Alaska 99501
Well B-16 (21-32~11~14) PBU
Attention: Mr. C. V. Chatterton
Gentlemen:
Enclosed, in triplicate, is Form 10-403, Sundry Notices and Reports
on Wells, for the above-named well. This contains our proposal to
perform a 135 bbl EDTA matrix treatment on this well.
JAB / ~?'h
,J~H/jmw
Yours very truly,
A Bragg'~~~/~ eer
Petroleum Engin (Acting)
Enclosures
cc: A. E. Leske
Well Records (LR2-1)
Drilling Well File #17
I ECFIV ED
Gas Co~'~s. Commission
Anchorage
STATE OF ALASKA '-~
ALASKA OIL AND GAS CONSERVATION COMMISSION
SUNDRY NOTICES AND REPORTS ON WELLS
1. DRILLING WELL []
COMPLETED WELL []
OTHER []
2. Name of Operator 7. Permit No.
Sohio Alaska Petroleum Company 79-25
3. Address 8. APl Number
Pouch 6-612, Anchorage, Alaska 99502 50-029-20365
4. Location of Well
At Surface:
1410' SNL, 1605' WEL, Sec. 31, TllN, R14E, UPM
5. Elevation in feet (indicate KB, DF, etc.)
KBE = 65.32' AMSL
61 Lease Designation and Serial No.
ADL 28310
9. Unit or Lease Name
Prudhoe Bay Unit
10. Well Number
B-16 (21-32-11-14) PBU
11. Field and Pool
Prudhoe Bay
Prudhoe Oil Pool
12.
Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data
NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF:
(Submit in Triplicate) (Submit in Duplicate)
Perforate [] Alter Casing [] Perforations [] Altering Casing []
Stimulate ~ Abandon [] Stimulation [] Abandonment []
Repair Well [] Change Plans [] Repairs Made [] Other []
Pull Tubing [] Other [] Pulling Tubing []
(Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.)
13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any
proposed work, for Abandonment see 20 AAC 25.105-170).
The following intervals in this well will be treated with 135 bbls of EDTA
solution during March/April 1985. The treatment will be conducted through
coiled tubing as a single stage job and the well will be shut-in for 24 hours
after the treatment. The SSSV will be removed prior to stimulation and reset
after the job at 2016'.
10,117'-10,144' BKB (Ref. BHCS/GR, 6/20/79)
10,154'-10,164' BKB ( " )
10,214'-10,234' BKB ( " )
REC£1VEB
'Alaska Oil & Gas Co[~s, Commission
...... -. ~ Anchorage
.ereby certify that the foregoing is true and correct to the best of my knowledge.
' ~/~/'~/,P-,O ~ 0/~_. ~. ~'~~ ACting District
~;~'ned Title Petroleum Engineer
/~ne spa/q~el~w for Commission
C°ndi~s of Approval, if any:
Approv~
iRIB~AL SIg~D ~Return~
B~ LON~I[ C. SUITH
Approved by COMMISSIONER the Commission
Date.
Date
Form 10-403
Submit "Intentions" in Triplicate
and "Subsequent Reports" in Duplicate
February 19, 1985
Mr. J. B. Kewin
Area Drilling Engineer
ARCO Alaska, Inc.
P. O. Box 100360
Anchorage, Alaska 99510-0360
Re: Kuparuk River Unit 3B- 16
ARCO Alaska, Inc.
Permit No. 85-26
Sur. Loc. 229'FSL, 802'FEL, Sec. ].6, T12N, R9E, ~.
Btm~hole Loc. !447'FNL, !060'~L, Sec. 21, T12N, RgE, ~.
Dear Mr. Kewin:
Enclosed is the approved application for permit to drill the
above referenced well.
If coring is conducted, a brief description of each core and a
one cubic inch size chip from each foot of recovered core is
required. Samples of drill cuttings and a mud log are not
required. A continuous directional Survey is required as per
20 AAC 25.050(b)(5). If available, a tape containing the
'digitized log information shall be submitted on all logs for
copying except experimental logs, velocity surveys and dipmeter
surveys.
Many rivers in Alaska and their drainage systems have been
=' important for the spawning or migration of
clas si.,~, zed as
anadromous fish. Operations in these areas are subject to
AS 16.05.870 and the regulations promulgated thereunder (Title 5,
Alaska Administrative Code). Prior to commencing operations you
may be contacted by the Habitat Coordinator's Office, Department
of Fish and Game.
Pollution of any waters of the State is prohibited by AS 46,
Chapter 3, Article 7 and the regulations promulgated thereunder
(Title 18, Alaska Administrative Code, Chapter 70) and by the
Federal Water Pollution Control Act, as amended. Prior to
commencing operations you may be contacted by a representative of
the Department of Environmental Conservation.
Mr. Jeffrey B. Ke~__~
Kuparuk River Unit 3B-!6
-2-
February 19, 1985
To aid us in scheduling field work, please notify this office 24
hours prior to commencing installation of the blowout prevention
equipment so that a representative of the Commission may be
present to witness testing of the equipment before the surface
casing shoe is drilled. %.Yhere a diverter system is required,
please also notify this office 24 hours prior to commencing
equipment installation so that the Commission may witness testing
before drilling below the shoe of the conductor pipe.
In the event of suspension or abandonment, please give this
office adequate advance notification so that we may have a
witness present.
Ve~y_~t ruly Mo~urs,
C.'~ V. C~a-~t~rt'gn/
Chaiman of
Alaska Oil and Gas Conse~ation Comission
BY ORDER OF ~dE COPR,{ISSION
be
Enclosure
CC:
Department of Fish & Game, Habitat Section w/o encl.
Department of Environmental Conservation w/o encl.
Mr. Doug L. Lowery
ARCO Alaska, Inc.
Post Office Bo.. ,00360
Anchorage, Alaska 99510
Telephone 907 276 1215
February 11, 1985
Mr. C. V. Chatterton
Commissioner
State of Alaska
Alaska Oil & Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, AK 99501
SUBJECT' Kuparuk 3B-16
Dear Mr. Chatterton'
Enclosed are:
We estimate spudding this well on April 2, 1985.
questions, please call me at 263-4970.
Sincerely,
.~B~./j~ rea Drilling ~
JBK/TEM/tw
PD/L35
Attachments
An application for Permit to Drill Kuparuk 3B-16, along with
a $100 application fee
Diagrams showing the proposed horizontal and vertical
projections of the wellbore
A proximity plat
A diagram and description of the surface hole diverter
system
A diagram and description of the BOP equipment
If you have any
RECEIVED
FEB 1 4 1985
Alaska 0il & I~as Cons. Commission
Anchorage
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany
?'-" STATE OF ALASKA
ALASKA L.... AND GAS CONSERVATION CO,,,MISSION
PERMIT TO DRILL
20 AAC 25.005
la. Type of work.
DRILL
REDRILL
DEEPEN
lb. Type of well
EXPLORATORY []
DEVELOPMENT OIL [~X
DEVELOPMENT GAS []
SERVICE [] STRATIGRAPHIC ~
SINGLE ZONE []
MULTIPLE ZON E)~
2. Name of operator
ARCO Alaska, Inc.
3. Address
P. 0. Box 100360, Anchorage, Alaska 99510
4. Location of well at surface
229' FSL, 802' FEL, Sec.16, T12N, R9E, UN
At top of proposed producing interval
1262' FNL, 1437' FWL, Sec.21, T12N, R9E, UN
At total depth
1447' FNL, 1060' FWL, Sec.21, T12N, RgE, UN
5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no.
RKB 85', PAD 55' ADL 25633 ALK 2566
12. Bond information (see 20 AAC 25.025) Federal Insurance Company
Type Statewide Surety and/or number #8088-26-27
9. Unit or lease name
Kuparuk River Unit
10. Well number
3B-16
11. Field and pool
Kuparuk River Field
Kuparuk River 0il Pool
Amount $500,000
15. Distance to nearest drilling or completed
3B-15well 60' ~ surface feet
18. Approximate spud date
04/02/85
13. Distance and direction from nearest town 14. Distance to nearest property or lease line
30 mi. NW of Deadhorse miles 229' (~ surface feet
16. Proposed depth (MD & TVD) 17. Number of acres in lease
7854' MD, 6321' TVD feet 12560
19. If deviated (see 20 AAC 25.050)
KICK OFF POINT 1849 feet. MAXIMUM HOLE ANGLE 46 o
21
20. Anticipated pressures 2787
(see 20 AAC 25.035 (c) (2) 31g~
psig@ RO°F Surface
psig@ 6!82 _ft. TD (TVD)
Proposed Casing, Liner and Cementing Program
SIZE SETTING DEPTH QUANTITY OF CEMENT
Hole Casing
24" J 16"
12-1/4" 9-5/8"
8-1/2" 7"
22. Describe proposed
Weight
62.5#
36.0#
26.0#
program:
CASING AND LINER
Grade Coupling
H-40 Weld I
J-55 BTC
m
HF-ERW
J-55 BTC J
HF-ERW
Length
MD TOP TVD
80' 29' I 29'
3358' 29' I 29'
I
7826'
I
I
28' I 28'
MD BOTTOM TVD
109'I 109'
3387'I 3226'
7854'1 6321'
I
(include stage data)
± 200 cf
825 sx AS Ill &
460 sx Class G
260 sx Class G blend
ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7854' MD (6321'
TVD). A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole.
The 9-5/8" casing will be set through the West Sak sands at approximately 3387' MD(3226' TVD). A 13-5/8", 5000
psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and
weekly thereafter. Test pressure will be 3000 psig. Expected maximum surface pressure is 2787 psi. Pressure
calculations are based on latest reservoir pressure. Surface pressure is calculated with an unexpanded gas
bubble at surface, including temperature effects. Selected intervals will be logged. The well will be completed
by the workover rig with 3-1/2", 9.2#, J-55, 8rd tbg. Non-freezing fluids will be left in uncemented annuli
through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported
on subsequent reports. A downhole safety valve will be (see attached sheet)
23. I hereby certij,f.y~hat the foregoing is true and correct to the best of my knowledge
//
SIGNED TITLE Area Drilling Engineer
The space bel~ for (~om~nis~n use
CONDITIONS OF APPROVAL
Samples required Mud log required Directional Survey required APl number
[~YES .t~L,~O E]YES ~NO ~¢-~ES E}NO 50- ~'L. ~ ''L. J ). '~ ~/
SEE COVER LETTER FOR OTHER REQUIREMENTS
Permit number
~or-----~ ~0-40----~ ('r[~) P~/P~37
Approval date
,-///-/.,/.? ....
,COMMISSIONER DATE February 19; 198.5
by order of the Commission
Submit in triplicate
PERMIT TO DRILL
3B-16
installed and tested upon completion of the job. 3B-16 will be 60' away from 3B-15 at the surface. There are
no other close wellbores or crossings anywhere downhole. Top of cement for the production string will be placed
at 6271'MD, approximately IO00'MD above the top of the Kuparuk Sands. Reserve pit fluids will be disposed of
down the 9-5/8" x 7" annulus. The 9-5/8" x 7" annulus will be left with a non-freezing fluid during any
interruptions in the disposal process. After the workover rig has moved off location, this well will be
fracture stimulated.
A~as~,a Oil & Gas Cons, Comm~sstor~
AncY~o~ge
ARCO ALASKAI! ltlC~,! H
t:'6D~ 3B;,i I4ELL i NO,~~ 16l
~:U:PARUK' FIt
SLOPE
' i I
5000~
SURFACE
FS
-t
TVD,,,G042
'TrlO~?451
FNL;II;320'
'I
MI(X) kLASKA, IN{
P~:i 30. laELL NO" ,6, PROPOSED
_____K~HII_MK_FIELQ_- NORTH...SLCIPE. ALASKA
£AITIMII VI4ZI"$TOCIK,. ZK.
BASE PERI4AFROST
1'¥D-1616
KOP TVD'1849 T1'10-1849 DEP-O
~_0~ s TeF-~SNOG--t'VD-2036*-T-t'E)-2036-DEP-9
TL13 . I~R IO~ FT
,~ Tm.. s~ ~es Tvo-~7,s T.D-~7~
~ '~,1~- EO¢ (CSG PT) . TVD-3225 TI'rD-3387 D£P-587
>~-,_ ............. ;.-'i'~. X ^YER^GE AHCLE '
· ___%,.__TOP UI~R ~ TYD-5017 rl'tO-?2?l D£P-33~7'
· ' Tot k.o~ sNDs '~v.e,-6ee.,,. 'r~-7'~6e
lk~E Kt,'~ S1408 TYD-e182 TI'ID'?6~4 DEP'-~3663
.................. TD fJ, O~ PT)
I I
TVD-6321 TI'ID~?854:DEI~r3~)7- -,-:-
..
..... ZoOO { -~ ~
o i 000 20OO
.............. VER-~ICAL
RECEIVED
Alaska Oil & Gas Cons. Commission
Anchorage
I iii ii iii
Surface Diverter System
1. 16"-2000 psi Tankco starting head.
2. Tankco quick connect assy.
16" X 20" 2000 psi double studded adapter.
20" 2000 psi drilling spool w/10" side outlets.'
5. 10" ball valves~ hydraulically actuated~ w/10" lines
to reserve pit. Valves to open automatically upon
closure of annular preventer.
6. 20" 2000 psi annular preventer.
7. 20" bell nipple.
m i mlmi im
4
·
_
mi n I
Maintenance & Operation
1. Upon initial instal.lation close annular preventer and
verify Ehat ball valves have opened properly.
2. Close annular preventer and blow a(r through diverter
lines every 12 hours.
Close annular preventer in the event that gas or fluid
flow to surface is detected. If necessary, manually
override and close ball valve to upwind diverter line.
Do not shut in well under any circumstances.
Conductor
RECEIVED
F EE. 1 4 IB85
Oil & Gas Cons. Commission
Anchorage
,,
7
, i
--9I AGR/~ #1
15--5/8' 5. _.,) PS! RSRRA BOP STACK
I. 16' - 2O(X) PSI TPi'~CO STARTII~ tEN:)
2. II' - 5000 PSI CASING ~E. AD
3. II' - 5000 PSI X 15-5/8'-- 5000 PSI 'SPACER
-4. 13--5/8" - 5000 PSI PIPE RN4S
5, 15'-5/8" - 5C00 PSI DRILLING SPOOL V~/CHOKE AhD
KILL LIliES
6, 15-5/8" - 5CCX) PSI DOLBLE RAM'N/PIPE RAlvS ON Tap,
7. 15-5/8". - 5000 PSI AhNIAR ·
ACOJVlIATOR CAPACITY TEST
I. Q-ECK ~ FILL ACCUMJ.ATOR RESERVOIR TO PROPER
LEVEL WITH HYDRAULIC FLUID.
2. ASSUI;E THAT ACOJMJLATCR PRESSURE IS 30CIO PSI WITH
1500 PSI DIS'6~TREAM Cl' THE RE(i.LATOR.
3. CBSE~ TIKE. TFEN CLOSE ALL UNITS SIMJLT/~EOUSLY
AJ~D EECOED THE TI~ AhD P~ E~WRINING AFTE~
ALL U~TS AJ;E CLOSED WITH CHAEGING ~ OFF.
4. IBEC~ ON hl~ EEPORTo TFE ACTABLE LO~ LIMIT
IS 45 SEC~ CLOSING TIbE ~ 1200 PSI t~INING
5
,!
4
ECEtVE.
14.
FEB 1 191 5
15-5/8" BOP STACK TEST
I. FILL BCP STACK AN3 a-EKE IvtN~FCLD WITH ARCTIC
DIESEL.
2. Q-ECl( THAT ALL LOCi( EX)iN SCi~t~ IN I'EL. LHE/~ ARE
FLLLY I:~TRACTED. SEAT TEST PLUG IN 1/~E. LL~
WITH ~ING JT /V~ ~ IN L~ SCRD~,
5. CLOSE ~ PI;EVE~ ~ MANJAL KILL ~ (]-O<E
LII~E VALVl-r.S ADJACENT TO BCP STACK. ~ OTI-ER
4. PRESSt.I;~ UP TO 250 PSI MD HaLD FOR I0 MIN. IN-
~ PR~~ TO 3000 PSI ~ HOLD FOR I0 MIN.
BLEED PRESSLRE TO 0 PSI.
5, OPEN /~NJLAR PREVENTER ~ ~ KILL ~ CHCI<E
LIllE VALVES. CLOSE Tap PIPE RAMS AI~Z) I-K:R VALVES
ON KILL ~ Q-K]d~ LI~ES.
6, TEST TO 250 PSI /~D 5000 PSI AS IN STEP 4.
% cavTIN.E TESTING ALL VALVES, LI~=S, ~ CHa<ES
WITH A 250 PSI LOW ~ 3000 PSI HIGH. TEST AS IN
STEP 4. DO NIT pRE~ TEST ANY C'NO<E THAT IS
mT /~ F~k C~JNG POSIT,~VE SEAL C~;XE. ON.Y
FONCTIC~ T~S~ 'CHa~ES THA~ m kO~ FULLY CLOSE.
8. apEN TaP PIPE R~ AN) CLCa~ BOTTOM PIPE RAMS.
TEST BOTTOM PIPE RAIV~ TO 250 PSI ~ 3000 PSI.
g. OPEN BOTTOM PIPE ~ BACK OIJT ~N(~ JT ~
PULL CUT OF HOLE.
I0. CLOSE BLIN) RAMS ~ TEST TO 250 PSI ~
PSI.
I~I~iIFCLD ~ LIliES ~ FLLL OF NON-FREEZING
FLUID. SET ALL VALVES IN DRILLING POSITICN.
12. TEST SI'~IPE VALVES, KELLY, KELLY COCKS, DRILL
PIPE S~FETY VALVE° ~ INSIDE Bap TO 250 PSI
3000 PSI.
RE~ TEST II~F~TION CN BLONIJT PREVENTER TEST
FORM, SIGN, ~ SE~D TO DRILLING SUPERVISOR.
YEEKLY TI-EI;EAFTER F~TICNALLY OPERATE BapE i~ILY.
~t~.~ 0il & 6as Cons. Cot-mission
Anchorage
510084001
I~V I
ITEM APPROVE DATE
Fee
~ thru 8) 3.
4.
5.
6.
7.
8.
(5) BOPE ~ J~~
(22 thru' 26)
CHECK.LIST FOR NEW WELL PER~TS Company
Lease
&
Well
No.
YES NO
Is the pemit fee attached .........................................
Is well to be located in a defined pool ...........................
Is well located proper distance from property line ................
Is well located proper distance from other wells ...................
Is sufficient undedicated acreage available in this pool ...........
Is well to be deviated and is wellbore plat included ...............
Is operator the only affected party ................................
Can permit be approved before ten-day wait .........................
9. Does operator have a bond in force ..................................
I0. Is a conservation order needed ......................................
11. Is administrative approval needed. .............................. ~...
12. Is the lease number appropriate .. ., ..........
13. Is conductor string provided ........................................
14. Is enough cement used to circulate on conductor and surface ......... ~/~
15. Will cement tie in surface and intermediate or production strings ...
16. Will cement cover all known productive horizons ..... ~..; .............
17. Will surface casing protect fresh water zones ..............
18. Will all casing give adequate safety in collapse, tension and burst..
19. Is this well to be kicked off from an existing wellbore .............
20. Is old wellbore abandonment procedure included on 10-403 ............
21. Is adequate wellbore separation proposed ............................
22. Is a diverter system required ........................................
23. Are necessary diagrams of diverter and BOP equipment attached .......
24. Does BOPE have sufficient pressure rating - Test to ~ psig .. fl.~
25. Does the choke manifold comply w/API RP-53 (Feb.78) ..................
26. Is the presence of H2S gas probable .................................
27. Additional requirements .............................................
Additional Remarks: ~)~-AA ,.~B~A ~)l],~ ~U ~0~ F~/~7 ~-I~ ~/'~ ~,o,~_~ 7'~ ~-zr~/TV~I~ ,
REMARKS
Geology'. Engineering. ~;.'
HWK /LC~BEW~
JAL~Z ~/'
rev: 10/29/84
6. C~T
INITIAL GEO. UNIT ON/OFF
FOOL CLASS STATUS AREA NO. SHORE
Well History File
APPENDIX
Information of detailed nature that is not
particularly germane to the Well Permitting Process
but is part of the history, file.
To improve the readability of the Well History file and to
simplify finding information, information of this
nature is accumulated at the end of the file under APPENDIX. ,
No special effort has been made to chronologically
organize this category of information.
,
VMR!FIC~TIO~I ~ISTINC
T, VP 01~,~,i09 VEPi~'ICATit'qN LTST!N(L.; PAGE I
** TApE }~EAD~R **
SERVTCr ~.!A~E
DATE :~5/04/!4
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EOF
44.0000
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4.58o8
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CALl
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SE~VTC? NA~E :~blT
BAWE :~b/04/14
ORIGIN :0000
TAP~ NA~F :0276
CON~INI;ATI~N ~
CO~MEN~S :
SERV!C~ NA~E .~EI~
DATE :~5/04/~4
CONTINUATION
~EYT RFE!, ~A~E
COMMENTS :
