Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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From:Regg, James B (OGC)
To:NSK Wells Integrity Eng CPF2
Cc:Automation, AK Wells; Livingston, Erica J; Sullivan, Sean T (OGC)
Subject:RE: KRU 2L-326, 2L-327, 2L-328 (PTDs: 209-027, 207-008, 214-189) Gas Bubbling
Date:Friday, July 11, 2025 10:36:00 AM
Timeframe for receiving the results of sample analyses? CPAI’s inspection frequency while we
wait for the results?
Jim Regg
Supervisor, Inspections
AOGCC
333 W. 7th Ave, Suite 100
Anchorage, AK 99501
907-793-1236
From: NSK Wells Integrity Eng CPF2 <n2549@conocophillips.com>
Sent: Wednesday, July 9, 2025 10:19 AM
To: Regg, James B (OGC) <jim.regg@alaska.gov>
Cc: Automation, AK Wells <akwellsautomation@conocophillips.com>; Livingston, Erica J
<Erica.J.Livingston@conocophillips.com>
Subject: KRU 2L-326, 2L-327, 2L-328 (PTDs: 209-027, 207-008, 214-189) Gas Bubbling
Well Name: 2L-326
Facility: CFP2
PTD: 209-027
Well Type: Prod
AA Number (if applicable):
Internal Waiver (Yes/No if applicable):
Type of Issue: Plan Forward
Maximum Pressure (if applicable):
Date of Occurrence (if applicable):
Hi Jim,
I was informed that during State Witnessed SVS testing on 2L, Sully requested information
regarding gas bubbling in the cellars of 2L-326, 2L-327, and 2L-328 (PTD 209-027, 207-008,
214-189) . These wells are gas lifted production wells. CPAI conducts gas sampling of wells
which experience bubbling in cellars and conductors and compares the bubbling gas samples
to the lift gas samples and produced gas samples to confirm if the bubbling gases are coming
from the applied lift gas in the IA, the target reservoir, or are shallow thawing hydrates on the
pad. These wells have been sampled extensively in the past. The test results are attached.
New samples were taken but the results will not be available for some time. All well’s bubbling
gases have shallow thawing hydrate gas signatures marked by the lack of ethane and heavier
gases. CPAI intends to keep these wells online.
Please let me know if you have any questions or disagree with the plan.
Warmest regards,
Jaime Bronga
Well Integrity – CPF2 – ConocoPhillips Alaska
Cell: 907-229-8282
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2 +735 37
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23+735 37
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2 +735 37
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23+735 37
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2+,6+ 37
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2 :*5 37
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23:*5 37
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2 +735 37
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23+735 37
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2565
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2 <7 % 7,
<7 % 7, / 9
2 <7 % 7,
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%7, 07/67 * ,5 $.
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6/+,7 : 5?
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Inspector also called Matt Miller (CPAI KRU Ops Foreman) and provided
the details. He committed to CPAI getting a gas sample.
Deficiency resolved with info received from CPAI on 7/14/2025 (gas sample
analyses) demonstrating the gas bubbling is due to shallow hydrates
(history of this on KRU 2L-pad-- J. Regg; 7/15/2025
1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown
Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program
Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Replace Tubing
Development Exploratory
Stratigraphic Service 6. API Number:
7. Property Designation (Lease Number): 8. Well Name and Number:
9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s):
11. Present Well Condition Summary:
Total Depth measured 10519'feet None feet
true vertical 5358' feet None feet
Effective Depth measured 10212'feet 9874', 9999'feet
true vertical 5097' feet 4831', 4923'feet
Perforation depth Measured depth
True Vertical depth
Tubing (size, grade, measured and true vertical depth) 3-1/2"
3-1/2"
L-80
L-80
9993'
10052'
4919'
4965'
Packers and SSSV (type, measured and true vertical depth)9874'
9999'
N/A
4831'
4923'
N/A
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure: N/A
13a.
Prior to well operation:
Subsequent to operation:
13b. Pools active after work: Tarn Oil Pool
15. Well Class after work:
Daily Report of Well Operations Exploratory Development Service Stratigraphic
Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL
Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG
Sundry Number or N/A if C.O. Exempt:
Authorized Name and
Digital Signature with Date: Contact Name:
Contact Email:
Authorized Title: Contact Phone:
3107' 2406'
Burst Collapse
Production 10477'
Casing
5350'10509'
3072'
114'Conductor
Surface
16"
10-3/4"
78'
measured
TVD
7-5/8"
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
209-027
50-103-20597-00-00
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:
ADL0380052, ADL0380054
Kuparuk River Field/ Tarn Oil Pool
KRU 2L-326
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)
0
Gas-Mcf
MD
~
Size
114'
0 00
Shut-In ~~
0
323-237
Sr Pet Eng: Sr Pet Geo: Sr Res Eng:
WINJ WAG
~
Water-BblOil-Bbl
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
N/A
Packer: Baker Premier
Packer: Baker FHL
SSSV: None
Adam Klem
adam.klem@conocophillips.com
(907) 263-4517Staff RWO/CTD Engineer
10227'-10237'
5110'-5118'
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 9:01 am, Jul 13, 2023
Page 1/6
2L-326
Report Printed: 7/10/2023
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
6/14/2023
03:00
6/14/2023
04:00
1.00 MIRU, MOVE MOB P Clean up around well. Pull mats and
herculite.
6/14/2023
04:00
6/14/2023
08:00
4.00 MIRU, MOVE RGRP T Replace 4ea broke wheel studs on
moving system. Move office and hi line
trailer T/ 2L. Prepping road with rig
mats from 2N to 2L.
6/14/2023
08:00
6/14/2023
12:30
4.50 MIRU, MOVE WAIT P Waiting on road prep, setting additional
mats. Stage contingency dunnage on
2N & 2L.
6/14/2023
12:30
6/14/2023
15:30
3.00 MIRU, MOVE MOB P Moving sub to 2L.
6/14/2023
15:30
6/14/2023
16:30
1.00 MIRU, MOVE MOB T Rig fell through road on 2L access road
on colvert. Crib up under tire. Pull onto
pad.
6/14/2023
16:30
6/14/2023
17:45
1.25 MIRU, MOVE MOB P Stage sub on pad and hang tree in
cellar.
6/14/2023
17:45
6/14/2023
22:30
4.75 MIRU, MOVE MOB P Spot rig over well and center up. Berm
up Cellar. Pad Op pumped open SSV.
R/U Stairs and landings. Set mud
shack. Set cuttings box. Set Tiger
Tank. Spot highline trailer. Build
contaiment and set open top tank. R/U
hardline and hoses to manifold and tree
in cellar. R/U hardline out to tanks, IA
valves, and cellar circ manifold. IA
valves not holding. Grease crew
serviced IA valves and tree. IA valves
still not holding. Call hardline crew to
hot shot 2 1/16" valve and 1502 integral
for IA.
6/14/2023
22:30
6/15/2023
00:00
1.50 MIRU, WELCTL COND P Accept rig @ 22:30. Take on 10.3#
NaCl/NaBr brine into pits. Build 40 bbl
Deep Clean Pill in pill pit. Initial
Pressures (T/IA/OA) = 225 / 805 / 240
psi.
6/15/2023
00:00
6/15/2023
01:30
1.50 MIRU, WELCTL COND P Cont. to take on 10.3# NaCl/NaBr into
rig pits. Round trip vac trucks to reload
10.3# brine. Build lay down. Install new
2 1/16"casing valve and 1502 integral
on IA. Finish hardline RU.
6/15/2023
01:30
6/15/2023
02:00
0.50 MIRU, WELCTL PRTS P Flood and PT cellar manifold and
hardline to tanks to 250 / 2500 psi.
6/15/2023
02:00
6/15/2023
02:30
0.50 MIRU, WELCTL SFTY P PJSM w/ rig crew on free gas bleeding
and well kill.
6/15/2023
02:30
6/15/2023
06:45
4.25 MIRU, WELCTL KLWL P Bleed free gas from TBG and IA. Initial
Pressures after bleeding free gas
(T/IA/OA) = 225 / 805 / 240 psi. Pump
40 bbls Deep Clean followed by 530
bbls 10.3# Brine down Tubing taking
returns from IA out to tanks @ 3 BPM
(645 PSI). Monitoring returns adjusting
choke to maintain 1:1 returns. Total
Pumped = 570 bbls. 10.3 PPG returns
to surface. Total Returns = 570 bbls.
6/15/2023
06:45
6/15/2023
07:30
0.75 MIRU, WELCTL OWFF T OWFF flowing at tank. Shut in TBG=40,
IA=40. Diesel observed at IA.
Processing 3 1/2" DP string.
6/15/2023
07:30
6/15/2023
08:00
0.50 MIRU, WELCTL KLWL T Pump additional 25 Bbls fluid quickly
went to 10.3 PPG returns.
6/15/2023
08:00
6/15/2023
09:00
1.00 MIRU, WELCTL OWFF T OWFF flowing at tank. Shut in TBG=40,
IA=40. Consult with town. Decision
made to increase KWF T/ 10.6 PPG.
Rig: NORDIC 3
RIG RELEASE DATE 6/22/2023
Page 2/6
2L-326
Report Printed: 7/10/2023
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
6/15/2023
09:00
6/15/2023
12:30
3.50 MIRU, WELCTL WAIT T Order 12.5 PPG NaBr spike fluid from
1B. Order load of 10.7 NaCl/NaBr from
mud plant. Waiting on fluids to arrive.
6/15/2023
12:30
6/15/2023
15:00
2.50 MIRU, WELCTL COND T Spiked fluid in pits F/ 10.3 PPG T/ 10.7
PPG w/ 12.5 PPG spike fluid. Load pill
pit w/ 25 Bbls of spike fluid. Truck load
of 10.7 PPG arrived from mud plant.
6/15/2023
15:00
6/15/2023
15:30
0.50 MIRU, WELCTL SFTY T PJSM w/ rig crew on well kill w/ 10.7
PPG NaCl/NaBr.
6/15/2023
15:30
6/15/2023
18:00
2.50 MIRU, WELCTL KLWL T Pump 10.7# Brine down Tubing taking
returns from IA out to tanks @ 3 BPM
(730 PSI). Monitoring returns adjusting
choke to maintain 1:1 returns. Total
Pumped = 510 bbls. 10.7 PPG returns
to surface. Total Returns = 510 bbls
6/15/2023
18:00
6/15/2023
19:00
1.00 MIRU, WELCTL OWFF P Shut down pumps. Let well
exhaust/stabilize to tanks. Close choke.
Shut in cellar manifold. Open monitor
gauges. 10 psi. Bleed Tubing and IA
until static. Well static @ 18:30.
Monitor well for flow for 30 minutes.
6/15/2023
19:00
6/15/2023
19:30
0.50 MIRU, WELCTL RURD P Blow down lines to tiger and open top
tanks. Blow down cellar lines, choke,
and kill lines.
6/15/2023
19:30
6/15/2023
20:30
1.00 MIRU, WELCTL MPSP P P/U T-Bar. Set HP BPV.
6/15/2023
20:30
6/15/2023
21:00
0.50 MIRU, WELCTL PRTS P Perform rolling test under BPV for 10
minutes. Observe IA. Good Test.
6/15/2023
21:00
6/15/2023
22:00
1.00 MIRU, WHDBOP RURD P RD testing hoses and blow down cellar
lines. L/D T-bar. Bleed off adapter void
and verify 0 psi on IA.
6/15/2023
22:00
6/15/2023
23:30
1.50 MIRU, WHDBOP NUND P N/D tree and tubing head adapter.
Inspect hanger neck threads. Threads
are in good shape. Install tree test dart,
7 turns. Function LDS.
6/15/2023
23:30
6/16/2023
00:00
0.50 MIRU, WHDBOP SFTY P PJSM. Discuss N/U BOP operations.
6/16/2023
00:00
6/16/2023
05:30
5.50 MIRU, WHDBOP NUND P N/U BOP. M/U choke and kill lines and
hoses. Purge air from system. Prep for
shell test. Measure RKB. Cont. to
process 3 1/2" Drill Pipe.
6/16/2023
05:30
6/16/2023
15:30
10.00 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE at
250/3500 PSI for 5 Min each, Tested
annular, UVBR's, LVBRs w/ 3 1/2" test
joints. Test blinds rams. Choke valves
#1 to #7 & #9 to #13, upper and lower
top drive well control valves. Test 3 1/2"
IF FOSV and IBOP. Test 3 ½ & EUE
FOSV. Test 2" rig floor Demco kill valve
MM #13. Test manual and HCR kill
valves & manual and HCR choke
valves. Test two ea 2 1/6" gate auxiliary
valves below LPR. Test hydraulic and
manual choke valves to 1500 PSI and
demonstrate bleed off. Test gas
detectors, PVT and flow show. Witness
waived by AOGCC rep Sean Sullivan.
Fail/Pass on LVBR's, functioned and
passed retest.. Choke valve #8 failed.
Rig: NORDIC 3
RIG RELEASE DATE 6/22/2023
Page 3/6
2L-326
Report Printed: 7/10/2023
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
6/16/2023
15:30
6/16/2023
23:00
7.50 MIRU, WHDBOP BOPE T Manual choke, Choke valves, #2 & #5
were serviced while identifying Choke
valve #8 as failure. Choke valve #8 was
rebuilt and passed retest. . LVBR's
failed initial test, functioned and passed
retest Changed out 4 way valve on
accumulator. Function test Koomey.
Electric pump cavitating. C/O electric
pump check valve on discharge line.
Function test. Perform accumulator
test. Initial pressure= 3,000 PSI, after
closure = 1650 PSI, 200 PSI attained =
29 sec, full recovery attained = 207 sec.
UVBR's= 4 sec, LVBRs= 4 sec.
Annular = 15 sec. Simulated blinds = 4
sec. HCR choke & kill = 1 sec each. 4
back up nitrogen bottles average =1987
PSI. Witness waived by AOGCC rep
Sean Sullivan.
6/16/2023
23:00
6/17/2023
00:00
1.00 MIRU, WHDBOP RURD P Blow down lines. Drain stack. RD
testing equipment. L/D 3 1/2" EUE test
joint. Prep floor for pulling 3 1/2" tubing.
PU T-bar.
6/17/2023
00:00
6/17/2023
01:45
1.75 COMPZN, RPCOMP MPSP P Cont. to prep floor to pull 3 1/2" tubing.
Pull test dart and BPV.
6/17/2023
01:45
6/17/2023
02:00
0.25 COMPZN, RPCOMP SFTY P PJSM. Discuss pulling completions
operations and risks.
6/17/2023
02:00
6/17/2023
03:00
1.00 COMPZN, RPCOMP PULL P MU 3 1/2" EUE landing joint to hanger
threads. Set 10K down. BOLDS. PU
and mark pipe at neutral weight. Unseat
hanger @ 84K. Tubung came free @
125K (89K over). Weight fell off to
62K. Cont. to pull hanger to rig floor
dragging 87-90K.
9,996.0 9,966.0
6/17/2023
03:00
6/17/2023
05:00
2.00 COMPZN, RPCOMP CIRC P Fill MGS. Circulate BU @ 3 BPM (240
psi) watching for packer gas. Kicked
approx. 10 bbls outside (diesel
contaminated brine) before taking
returns to active system.
9,966.0 9,966.0
6/17/2023
05:00
6/17/2023
05:30
0.50 COMPZN, RPCOMP OWFF P OWFF for 30 minutes. 9,966.0 9,966.0
6/17/2023
05:30
6/17/2023
06:00
0.50 COMPZN, RPCOMP PULD P L/D hanger and landing joint. B/D top
drive.
9,966.0 9,966.0
6/17/2023
06:00
6/17/2023
06:30
0.50 COMPZN, RPCOMP SFTY P Crew change out. PJSM on L/D
completion string
9,966.0 9,966.0
6/17/2023
06:30
6/17/2023
11:45
5.25 COMPZN, RPCOMP PULL P L/D 3 1/2" completion F/ 9996' T/ 4960',
PUW=85K. No packer drag seen,
assume pulled from seals.
9,966.0 4,960.0
6/17/2023
11:45
6/17/2023
12:00
0.25 COMPZN, RPCOMP SFTY P Kick while tripping drill. Swap rig over to
high line power.
4,960.0 4,960.0
6/17/2023
12:00
6/17/2023
17:00
5.00 COMPZN, RPCOMP PULL P Cont L/D 3 1/2" completion F/.4960' T/
Surface, PUW=65K. Seals recovered.
Small holes in joints # 266, 270, 273,
281. Paraffin on external joints below
lowest GLM.
Seals will be stripped and reran.
4,960.0 0.0
6/17/2023
17:00
6/17/2023
18:00
1.00 COMPZN, RPCOMP CLEN P Clean and clear RF and pipe shed. 0.0 0.0
6/17/2023
18:00
6/17/2023
19:30
1.50 COMPZN, RPCOMP RURD P Prep rig floor to run 3 1/2" DP. Kick out
drill collars. Load BHA #1 (String Mill +
Stinger) into pipe shed. Set wear ring.
RILDS (2) to hold in place.
0.0 0.0
6/17/2023
19:30
6/17/2023
21:30
2.00 COMPZN, RPCOMP BHAH P P/U BHA #1 (6 3/4" OD String Mill, 2
7/8" OD x 12' Mulesho stinger)
0.0 52.0
Rig: NORDIC 3
RIG RELEASE DATE 6/22/2023
Page 4/6
2L-326
Report Printed: 7/10/2023
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
6/17/2023
21:30
6/17/2023
22:00
0.50 COMPZN, RPCOMP SVRG P Service Rig. Grease TD, blocks, and
crown.
52.0 52.0
6/17/2023
22:00
6/17/2023
22:15
0.25 COMPZN, RPCOMP SFTY P PJSM. Discuss BHA M/U and running 3
1/2" DP.
52.0 52.0
6/17/2023
22:15
6/18/2023
00:00
1.75 COMPZN, RPCOMP PULD P TIH w/ BHA #1 to midnight depth of
2,600'.
52.0 2,600.0
6/18/2023
00:00
6/18/2023
04:15
4.25 COMPZN, RPCOMP PULD P Cont. TIH w/ BHA #1 from 2,600' to
5,524'.
2,600.0 5,524.0
6/18/2023
04:15
6/18/2023
05:00
0.75 COMPZN, RPCOMP SVRG P Torque sensor hose leaking. Replaced
with spare hose/load cell/gauge.
5,524.0 5,524.0
6/18/2023
05:00
6/18/2023
11:00
6.00 COMPZN, RPCOMP PULD P Cont. TIH w/ BHA #1 from 5,524' to
8,916', PUW=137K, SOW=80K
5,524.0 8,916.0
6/18/2023
11:00
6/18/2023
14:00
3.00 COMPZN, RPCOMP REAM P Adjust TD torque. Kelly up. Obtain
parameters. Pump @ 3 BPM, 620 PSI.
ROT @ 25 RPM, Free Tq= 7K.
PUW=110K. SOW=96K. ROT=105K.
Wash & Ream in hole w/ 6.125" sting
mill F/ 9800' T/ 9956'. No work
observed while reaming in.
8,916.0 9,972.0
6/18/2023
14:00
6/18/2023
14:30
0.50 COMPZN, RPCOMP WASH P Wash in hole @ 3 BPM, 640 PSI, w/ 12'
mule shoe F/ 9972' T/ 9988''. Tag No-go
@ 9972'. Set down 5K, PSI increase T/
800 PSI. Reconfirm tag.
9,972.0 9,988.0
6/18/2023
14:30
6/18/2023
15:30
1.00 COMPZN, RPCOMP CIRC P P/U above PBR Circulate BU @ 5
BPM, 1600 PSI. Paraffin seen @ BU.
Pump until shakers cleaned up.
9,988.0 9,972.0
6/18/2023
15:30
6/18/2023
16:30
1.00 COMPZN, RPCOMP RGRP T Drawworks problems. Replaced fuse in
PLC.
9,972.0 9,972.0
6/18/2023
16:30
6/18/2023
17:00
0.50 COMPZN, RPCOMP WASH P Reconfirm tag 9990' @ 3 BPM, 460 PSI.
Set 10K down pressure incresed T/ 800
PSI. Repeate w/ ROT @ 25 RPM.
9,972.0 9,990.0
6/18/2023
17:00
6/18/2023
17:30
0.50 COMPZN, RPCOMP TRIP P L/D single and POOH F/ 9990' T/ 9,410'. 9,990.0 9,410.0
6/18/2023
17:30
6/18/2023
18:00
0.50 COMPZN, RPCOMP SFTY P Crew C/O. Safety meeting. 9,410.0 9,410.0
6/18/2023
18:00
6/18/2023
22:30
4.50 COMPZN, RPCOMP TRIP P TOOH F/ 9,410' T/ 3,562' where power
tong lift ram failed.
9,410.0 3,562.0
6/18/2023
22:30
6/19/2023
00:00
1.50 COMPZN, RPCOMP RGRP T Lift ram on Spinners failed. Bring new
assembly to rig floor to begin swap out.
3,562.0 3,562.0
6/19/2023
00:00
6/19/2023
02:00
2.00 COMPZN, RPCOMP TRIP P Cont. to POOH w/ BHA #1 T/ surface. 3,562.0 52.0
6/19/2023
02:00
6/19/2023
02:15
0.25 COMPZN, RPCOMP SFTY P PJSM. Discuss BHA L/D and P/U. 52.0 52.0
6/19/2023
02:15
6/19/2023
03:00
0.75 COMPZN, RPCOMP BHAH P LD BHA #1 (String Mill w/ Stinger). No-
Go worn indicating good tag at PBR top.
52.0 0.0
6/19/2023
03:00
6/19/2023
03:45
0.75 COMPZN, RPCOMP BHAH P PU BHA #2 (Test Packer). Continue to
process 3 1/2" Tubing.
0.0 15.0
6/19/2023
03:45
6/19/2023
11:15
7.50 COMPZN, RPCOMP TRIP P TIH w/ BHA #2 F/ 15' T/ 9930',
PUW=147K, SOW=80K.
15.0 9,930.0
6/19/2023
11:15
6/19/2023
12:30
1.25 COMPZN, RPCOMP MPSP P M/U FOSV & TD. P/U work right hand
torque into string. Set test packer @
9920'. Break out TD
9,930.0 9,920.0
6/19/2023
12:30
6/19/2023
13:30
1.00 COMPZN, RPCOMP PRTS P PT IA T/ 2500 PSI for 30 Min against
test packer & UVBR's - good test.
9,920.0 9,920.0
6/19/2023
13:30
6/19/2023
14:30
1.00 COMPZN, RPCOMP MPSP P M/U T/D work right hand torque into
string. Release test packer. Allow
packer to relax for 10 Min. L/D single T/
9900', PUW=147K. Break out T/D &
FOSV.
9,920.0 9,900.0
6/19/2023
14:30
6/19/2023
15:00
0.50 COMPZN, RPCOMP RURD P B/D TD and kill line. 9,900.0 9,900.0
Rig: NORDIC 3
RIG RELEASE DATE 6/22/2023
Page 5/6
2L-326
Report Printed: 7/10/2023
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
6/19/2023
15:00
6/19/2023
15:30
0.50 COMPZN, RPCOMP SVRG P Service rig. Grease block & crown. 9,900.0 9,900.0
6/19/2023
15:30
6/20/2023
00:00
8.50 COMPZN, RPCOMP PULD P LDDP F/ 9900' (PUW=147K) T/ midnight
depth of 1,900'.
9,900.0 1,900.0
6/20/2023
00:00
6/20/2023
02:00
2.00 COMPZN, RPCOMP PULD P Cont. LDDP F/ 1900' T/ surface. 1,900.0 15.0
6/20/2023
02:00
6/20/2023
02:30
0.50 COMPZN, RPCOMP BHAH P LD BHA #2 (Test Packer). 15.0 0.0
6/20/2023
02:30
6/20/2023
04:30
2.00 COMPZN, RPCOMP RURD P Pull Wear Ring. Clean and Clear rig
floor. Prep handling equipment for 3
1/2" completions. Load completions into
pipe shed. Verify lengths and run order.
0.0 0.0
6/20/2023
04:30
6/20/2023
04:45
0.25 COMPZN, RPCOMP SFTY P PJSM. Discuss TIH w/ 3 1/2"
Completions Tubing and Jewelry
0.0 0.0
6/20/2023
04:45
6/20/2023
13:30
8.75 COMPZN, RPCOMP PUTB P RIH w/ 3 1/2", 9.3#, L-80, EUE-M
completion string. T/ 4976', SOW-55K.
Torque EUE T/ 2250 Ft/lbs. Run-n-seal
dope used.
0.0 4,976.0
6/20/2023
13:30
6/20/2023
14:00
0.50 COMPZN, RPCOMP SVRG P Service rig. Replace O rign on tubing
tong valve bank.
4,976.0 4,976.0
6/20/2023
14:00
6/20/2023
20:00
6.00 COMPZN, RPCOMP PUTB P Cont RIH w/ 3 1/2" EUE-m completion
F/ 4976' T/9962 ' 64 K SOW. Torque
EUE T/ 2250 Ft/lbs. Run-n-seal dope
used.
4,976.0 9,962.0
6/20/2023
20:00
6/20/2023
21:00
1.00 COMPZN, RPCOMP PUTB P PJSM with crew. Make up cross over in
the top of joint 317. kelly up to joint.
obtain parameters without pumps.
Stage up pumps to 3 BPM @ 310 PSI,
and obtain parameters.
W/O pumps:
PUWT: 94 K
SOWT: 64 K
W/ Pumps at 3 BPM @ 310 PSI:
PUWT: 91K
SOWT: 61K
9,962.0 9,962.0
6/20/2023
21:00
6/20/2023
23:00
2.00 COMPZN, RPCOMP PUTB P Wash down from 9962' pumping 3 BPM
@ 310 PSI. Tag top of PBR @ 9980'.
P/U to break over and attempt to sting
into PBR. Tag again at 9980'. P/U to
break over plus 15'. Rotate string 90
degrees to the right, work string up and
down 20', and attempt to enter PBR
again tag @ 9980'. P/U 20' past break
over rotated string 90 degrees, and work
string 20' 2 times. 7K bobble seen and
200 PSI pressure increased when seal
assy entered PBR. P/U joint 318 slack
off, and tag and set down 10k @ 9992'.
P/U to break over, come back down and
tag at 9992' again to confirm setting
down 5K. P/U 2' past break over.
9,962.0 9,992.0
6/20/2023
23:00
6/21/2023
00:00
1.00 COMPZN, RPCOMP PUTB P Calculate space out. Lay down Joints
317, 316, and 315. P/U and make up
10.19', 10.2', and 5.14' pup joints. P/U
landing joint, make up to hanger and
M/U to string.
9,992.0 9,962.0
6/21/2023
00:00
6/21/2023
02:30
2.50 COMPZN, RPCOMP CRIH P Displace annulus to 10.75 PPG
Corrosion inhibited brine. Pumping 4
BPM @ 500 PSI.
9,962.0 9,962.0
6/21/2023
02:30
6/21/2023
03:00
0.50 COMPZN, RPCOMP RURD P Drain Stack, blow down choke, and kill
lines. Pull rotary bushings.
9,962.0 9,962.0
Rig: NORDIC 3
RIG RELEASE DATE 6/22/2023
Page 6/6
2L-326
Report Printed: 7/10/2023
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
6/21/2023
03:00
6/21/2023
03:30
0.50 COMPZN, RPCOMP THGR P Land tubing hanger on seat @ 9992.5'
ORKB. FMC rep verify hanger is
landed. FMC rep RILDS.
9,962.0 9,992.5
6/21/2023
03:30
6/21/2023
05:15
1.75 COMPZN, RPCOMP RURD P PJSM. Drop Ball and rod. Rig up high
pressure lines to IA, and tubing for
setting the packer/ pressure testing the
IA. Verify IA sensor reading pressure.
9,992.5 9,992.5
6/21/2023
05:15
6/21/2023
07:15
2.00 COMPZN, RPCOMP PRTS P Pressure up on tubing to set Premier
packer. Saw initial shear @ 1900 PSI,
final shear on packer @ 2575 PSI. PT
tubing T/ 3000 PSI for 30 Min. Bleed
tubing T/ 1500 PSI. PT IA T/ 2500 PSI
for 30 Min. Dump tubing pressure and
shear out SOV.
9,992.5 9,992.5
6/21/2023
07:15
6/21/2023
08:00
0.75 COMPZN, RPCOMP RURD P B/D, R/D tubing testing equipment. Pull
landing joint.
9,992.5 9,992.5
6/21/2023
08:00
6/21/2023
08:30
0.50 COMPZN, RPCOMP MPSP P Set HP BPV. 9,992.5 9,992.5
6/21/2023
08:30
6/21/2023
09:00
0.50 COMPZN, RPCOMP PRTS P PT BPV T/ 1000 PSI for 10 Min from
below.
9,992.5 0.0
6/21/2023
09:00
6/21/2023
09:30
0.50 COMPZN, WHDBOP RURD P B/D, R/D testing equipment. 0.0
6/21/2023
09:30
6/21/2023
09:45
0.25 COMPZN, WHDBOP SFTY P PJSM on change out rams.
6/21/2023
09:45
6/21/2023
14:15
4.50 COMPZN, WHDBOP NUND P Open up LPR. Pull 2 7/8" x 5" VBR's
out. Did not have components to load
w/ 7" fixed rams. Open up UPR and
inspect 2 7/8" x 5 1/2" VBR's.
Cleaning pits.
6/21/2023
14:15
6/21/2023
14:15
COMPZN, WHDBOP NUND P Nipple down BOP.
6/21/2023
14:15
6/21/2023
16:00
1.75 COMPZN, WHDBOP NUND P N/D BOP, rack back on pedestal.
6/21/2023
16:00
6/21/2023
17:00
1.00 COMPZN, WHDBOP NUND P Install blanking plug. N/U adaptor spool
and tree.
6/21/2023
17:00
6/21/2023
18:00
1.00 COMPZN, WHDBOP THGR P FMC rep rig up test pump and test
Hanger neck void and SBMS seal 250
low/ 5000 PSI high: good test.
6/21/2023
18:00
6/21/2023
19:00
1.00 COMPZN, WHDBOP RURD P Rig up lines for freeze protect. Rig up
little red services.
6/21/2023
19:00
6/21/2023
21:30
2.50 COMPZN, WHDBOP SEQP P PJSM. Pressure test tree to 250 low,
5000 PSI high 15 min: GOOD test. Pull
test dart and BPV
6/21/2023
21:30
6/21/2023
23:00
1.50 COMPZN, WHDBOP FRZP P PJSM. Test surface lines to 2000 PSI.
Line up and pump 85 BBLS of Diesel
into the annulus.
ICP: 200 PSI
FCP: 800 PSI.
6/21/2023
23:00
6/22/2023
00:00
1.00 DEMOB, MOVE FRZP P Line up annulus to tubing through Cellar
manifold. Allow Diesel to U-Tube for
one hour.
Rig down LRS, blow down and rig down
lines prepare rig for rig move.
RIG RELEASE 00:00 HRS.
Rig: NORDIC 3
RIG RELEASE DATE 6/22/2023
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Pulled SOV, Set OV, Pulled B&R and RHC 2L-326 6/28/2023 rogerba
Notes: General & Safety
Annotation End Date Last Mod By
NOTE: DRILLED AS INJECTOR 2010; STILL PRE-PRODUCING 7/19/2012 osborl
NOTE: View Schematic w/ Alaska Schematic9.0 1/22/2010 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 24"
Insulated
16 15.25 36.0 114.0 114.0 62.50 H-40 WELDED
SURFACE 10 3/4 9.95 35.1 3,107.0 2,405.8 45.50 L-80 BTC
PRODUCTION 7 5/8 6.87 32.4 10,509.2 5,349.8 29.70 L-80 BTCM
Tubing Strings: string max indicates LONGEST segment of string
Top (ftKB)
30.1
Set Depth
9,992.5
Set Depth
4,918.6
String Ma
3 1/2
Tubing Description
Tubing Completion Upper
Wt (lb/ft)
9.30
Grade
L-80
Top Connection
EUE-M
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)
30.1 30.1 0.00 Hanger 10.880 FMC Gen V 11" Tubing Hanger, 3
1/2" EUE Box x Box
FMV Gen V 3.060
536.0 534.4 9.44 Nipple - No Go 4.496 3.5" x 2.813" X-Nipple HES X Nipple 2.813
2,208.4 2,020.6 51.23 Mandrel GAS
LIFT
5.890 3 1/2" x 1.5" MMG, GLM SLB MMG 2.920
9,814.3 4,789.2 46.52 Mandrel GAS
LIFT
5.890 3 1/2" x 1.5" MMG, GLM. SLB MMG 2.920
9,873.8 4,830.8 44.78 Packer 6.875 3 1/2" x 7 5/8" Baker Premier
Packer, TCII BxP
Baker Premier 2.870
9,931.5 4,872.6 42.37 Nipple - No Go 4.500 3 1/2" x 2.813" X-Nipple HES X Nipple 2.813
9,979.6 4,908.7 40.18 Locator 4.510 4.51" No-Go OD x 2.985" ID Locator Baker 80-40 2.985
9,980.7 4,909.5 40.13 Shoe - Mule 4.000 Baker 80-40 Seal Assembly
(elements removed, non-sealing)
(4.5' from fully located)
Baker 80-40
(no
seals)
2.940
Top (ftKB)
9,985.2
Set Depth
10,051.5
Set Depth
4,964.9
String Ma
3 1/2
Tubing Description
Tubing Completion Lower
Wt (lb/ft)
9.30
Grade
L-80
Top Connection
EUE 8rd
ID (in)
2.87
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)
9,985.2 4,913.0 39.93 PBR 5.870 PBR Baker 80-40 3.000
9,998.5 4,923.2 39.35 PACKER 6.670 BAKER FHL PACKER Baker FHL 2.920
10,043.4 4,958.5 37.38 NIPPLE 4.520 CAMCO D NIPPLE w/ 2.75
PROFILE
Camco D 2.750
10,051.0 4,964.5 37.05 WLEG 4.520 WIRELINE ENTRY GUIDE 2.992
Mandrel Inserts : excludes pulled inserts
Top (ftKB)
Top (TVD)
(ftKB)
Top
Incl (°)
St
ati
on
No
/S Serv
Valve
Type
Latch
Type
OD
(in)
TRO Run
(psi) Run Date Com Make Model
Port
Size (in)
2,208.4 2,020.6 51.23 1 GAS LIFT DMY RK 1 1/2 6/21/2023 SLB MMG
9,814.3 4,789.2 46.52 2 GAS LIFT OV RK 1 1/2 0.0 6/28/2023 SLB MMG 0.313
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
10,227.0 10,237.0 5,109.7 5,118.1 T-3, S-5, 2L-326 1/16/2010 6.0 IPERF 2.5" HSD HJ, 60 degree
phase
Stimulation Intervals
Top (ftKB) Btm (ftKB)
Inter
val
Num
ber Type Subtype Start Date
Proppant
Designed (lb)
Proppant
Total (lb)
Vol Clean
Total (bbl)
Vol Slurry
Total (bbl)
10,227.0 10,237.0 1 FRAC 1/21/2010 0.0 0.00 0.00
IPERF; 10,227.0-10,237.0
FRAC; 10,227.0
PACKER; 9,998.5
Nipple - No Go; 9,931.5
Packer; 9,873.8
Mandrel GAS LIFT; 9,814.3
SURFACE; 35.1-3,107.0
Mandrel GAS LIFT; 2,208.4
Nipple - No Go; 536.0
CONDUCTOR 24" Insulated;
36.0-114.0
Hanger; 30.1
1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown
Suspend Perforate Other Stimulate Pull Tubing Change Approved Program
Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing
2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number:
Exploratory Development
3. Address: Stratigraphic Service
6. API Number:
7. If perforating:8. Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool?
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):
10519'None
Casing Collapse
Conductor
Surface
Production
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
10227-10237'
10477'
5110-5118' 3-1/2"
7-5/8"
16"
10-3/4"
78'
3072'
Perforation Depth MD (ft):
MD
114'
2406'
114'
3107'
5350'10509'
Length Size
Proposed Pools:
TVD Burst
PRESENT WELL CONDITION SUMMARY
5358' 10212' 5097' 2082 None
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL080052, ADL0380054
209-027
P.O. Box 100360, Anchorage, AK 99510 50-029-20895-00-00
ConocoPhillips Alaska, Inc.
KRU 2L-326
Tarn River Oil PoolTarn Oil PoolKuparuk River Field
N/A
Tubing Grade: Tubing MD (ft):
Packer: 9999'MD/4923'TVD
SSSV: None
Perforation Depth TVD (ft): Tubing Size:
J-55 10052'
5/13/2023
Packer: Baker FHL
SSSV: None
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
Adam Klem
adam.klem@conocophillips.com
(907) 263-4597
RWO/CTD Engineer
Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
323-237
By Kayla Junke at 10:22 am, Apr 19, 2023
Adam Klem Digitally signed by Adam Klem
Date: 2023.04.19 07:36:59 -08'00'
SFD
DSR-4/20/23
X
VTL 4/24/2023
10-404
50-103-20597-00-00
SFDADL0380052
BOP test to 3500 psig
Annular preventer to 2500 psig
X
SFD 4/21/2023GCW 04/24/23
JLC 4/24/2023
04/24/2023
Brett W. Huber,
Sr.
Digitally signed by Brett W.
Huber, Sr.
Date: 2023.04.24 12:17:51
-08'00'
RBDMS JSB 042523
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
April 13, 2023
Commissioner
State of Alaska
Alaska Oil & Gas Conservation Commission
333 West 7th Avenue Suite 100
Anchorage, Alaska 99501
Dear Commissioner:
Adam Klem
Staff CTD/RWO Engineer
CPAI Drilling and Wells
ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Producer 2L-326 (PTD#
209-027).
Well 2L-326 was drilled and completed in 2010 by Doyon 14 as a Tarn oil producer. The well failed a TIFL in 2022. It
was then discovered to have multiple tubing leaks as well as a potential packer leak. It was decided then that the well
would move to RWO.
If you have any questions or require any further information, please contact me at 907-263-4529
The tubing will be pulled and replaced with new gas lift upper completion with a poor boy overshot and stacked packer.
2L-326 RWO Procedure
Tarn Producer
P&R Tubing
PTD #209-027
Page 1 of 2
Completed Pre-Rig Work
1. T-PPPOT, T-POT, IC-POT, IC-PPOT tests. (Passed 3/17/23)
2. SCLD. (Passed 3/20/23)
3. Pull CA-2 Plug set @ 10043’ RKB (Completed 4/2/23)
4. SBHP (Completed 4/2/23)
Remaining Pre-Rig Work
5. Open lowest GLM in upper completion, dummy off rest.
6. If internal risk assessment is approved internally and reviewed and agreed by AOGCC, no BPV will be installed
on Nordic 3 for MIRU/RDMO
7. Prepare well within 48 hrs of rig arrival.
Rig Work
MIRU
1. MIRU Nordic 3 on 2L-326. Pull BPV if one was installed
2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete
30-minute NFT. Verify well is dead. Circulate KWF as needed.
3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/3,500 psi. Test annular 250/3,500
psi.
Retrieve Tubing from seals
4. Pull BPV, MU landing joint and BOLDS.
5. Pull 3-1/2” tubing down from seals at 9985’ MD
Cleanout Run and Pressure test
6. Perform a cleanout run with casing scraper to clean casing and stinger assembly able to cleanout polish bore.
7. RIH with test packer to planned stacked packer depth and pressure test casing above test packer to 2500psi.
Install in 3-½” Tubing with Gas Lift Completion
8. MU and RIH with 3 ½” completion with poor boy overshot, packer, nipples and GLM.
9. Once on depth, circulate in CI, space out as needed.
10. Drop ball and rod
11. Pressure test tubing to 3000 psi for 5 minutes.
12. Pressure test inner annulus to 2500 psi for 30 minutes on chart.
ND BOP, NU Tree
13. Confirm pressure tests, then shear out SOV with pressure differential.
14. Install BPV.
15. ND BOPE. NU tree.
16. Pull BPV, freeze protect well, and set BPV if necessary.
17. RDMO.
Post-Rig Work
18. Pull BPV
30 min
2L-326 RWO Procedure
Tarn Producer
P&R Tubing
PTD #209-027
Page 2 of 2
General Well info:
Wellhead type/pressure rating: FMC Gen 5, 5K rated
Production Engineer: Natalie Dye
Reservoir Development Engineer: Sayeed Abbas
Estimated Start Date: 5/13/2023
Workover Engineer: Adam Klem 907-263-4529 adam.klem@conocophillips.com
Current Operations: This well is currently shut in.
Well Type: Producer
Scope of Work: Pull the existing 3-1/2” completion down to seal assembly, install new tubing and jewelry with new
stacked packer
BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram
Following subject to change/be updated with pre-rig work:
MIT results:
MIT-T Failed
CMIT-TxIA Failed
IC POT &PPPOT PASSED – 3/17/23
TBG POT &PPPOT PASSED – 3/17/23
MPSP: 2082 psi using 0.1 psi/ft gradient
Static BHP: 2591 psi / 5087’ TVD measured on 4/2/23
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag: RKB 10,212.0 2L-326 6/21/2022 freebd
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Pulled OV, Catcher, & Plug 2L-326 4/2/2023 zembaej
Notes: General & Safety
Annotation End Date Last Mod By
NOTE: DRILLED AS INJECTOR 2010; STILL PRE-PRODUCING 7/19/2012 osborl
NOTE: View Schematic w/ Alaska Schematic9.0 1/22/2010 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 24"
Insulated
16 15.25 36.0 114.0 114.0 62.50 H-40 WELDED
SURFACE 10 3/4 9.95 35.1 3,107.0 2,405.8 45.50 L-80 BTC
PRODUCTION 7 5/8 6.87 32.4 10,509.2 5,349.8 29.70 L-80 BTCM
Tubing Strings: string max indicates LONGEST segment of string
Top (ftKB)
30.1
Set Depth …
10,051.5
Set Depth …
4,964.9
String Ma…
3 1/2
Tubing Description
TUBING
Wt (lb/ft)
9.30
Grade
L-80
Top Connection
EUE 8rd
ID (in)
2.87
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)
30.1 30.1 0.00 HANGER 8.000 FMC HANGER 3.500
509.8 508.5 8.74 NIPPLE 4.520 CAMCO DS NIPPLE w/ 2.875"
PROFILE
Camco DS 2.875
3,085.0 2,399.0 71.85 GAS LIFT 5.390 #1 - GLM - Camco KBMG with
dummy valve
Camco KBMG 2.920
6,617.9 3,595.2 70.95 GAS LIFT 5.390 #2 - GLM - Camco KBMG with
dummy valve
Camco KBMG 2.920
9,008.5 4,398.0 71.85 GAS LIFT 5.390 #3 - GLM - Camco KBMG with
dummy valve
Camco KBMG 2.920
9,883.8 4,837.9 44.49 GAS LIFT 5.390 #4 - GLM - Camco KBMG with DCK-
2 Shear Valve
Camco KBMG 2.920
9,934.9 4,875.0 42.22 SLEEVE 4.500 BAKER CMU SLIDING SLEEVE w/
2.813" DS PROFILE
Baker CMU 2.813
9,982.9 4,911.2 40.04 LOCATOR 4.500 LOCATOR ASSEMBLY Baker 80-40 3.000
9,985.2 4,913.0 39.93 PBR 5.870 PBR Baker 80-40 3.000
9,998.5 4,923.3 39.35 PACKER 6.670 BAKER FHL PACKER Baker FHL 2.920
10,043.5 4,958.5 37.38 NIPPLE 4.520 CAMCO D NIPPLE w/ 2.75
PROFILE
Camco D 2.750
10,051.0 4,964.5 37.05 WLEG 4.520 WIRELINE ENTRY GUIDE 2.992
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top (ftKB)
Top (TVD)
(ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in)
8,308.0 4,167.1 70.14 LEAK LEAK IDENTIFIED BY EL LDL
AT 8308' RKB ON 10/19/22
10/19/2022 2.992
8,500.0 4,232.2 70.17 LEAK LEAK IDENTIFIED BY EL LDL
AT 8500' RKB ON 10/19/22
10/19/2022 2.992
8,606.0 4,268.5 69.98 LEAK LEAK IDENTIFIED BY EL LDL
AT 8606' RKB ON 10/19/22
10/19/2022 2.992
8,689.0 4,296.4 70.72 LEAK LEAK IDENTIFIED BY EL LDL
AT 8689' RKB ON 10/19/22
10/19/2022 2.992
8,734.0 4,311.2 70.95 LEAK LEAK IDENTIFIED BY EL LDL
AT 8734' RKB ON 10/19/22
10/19/2022 2.992
9,852.0 4,815.4 45.42 LEAK LEAK IDENTIFIED BY EL LDL
AT 9852' RKB ON 10/19/22
10/19/2022 2.992
9,985.0 4,912.8 39.94 LEAK -
TUBING
LEAK IDENTIFIED BY EL LDL
AT 9985' RKB ON 12/12/22
12/12/2021 0.000
10,000.0 4,924.4 39.28 LEAK LEAK IDENTIFIED BY EL LDL
AT 10.000' RKB ON 10/19/22
10/19/2022 2.992
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)
3,085.0 2,399.0 71.85 1 GAS LIFT DMY BK-5 1 0.0 1/5/2010 0.000
6,617.9 3,595.2 70.95 2 GAS LIFT DMY BK-5 1 0.0 1/5/2010 0.000
9,008.5 4,398.0 71.85 3 GAS LIFT DMY BK-5 1 0.0 1/5/2010 0.000
9,883.8 4,837.9 44.49 4 GAS LIFT OPEN OPEN 1 0.0 4/1/2023 0.000
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
10,227.0 10,237.0 5,109.7 5,118.1 T-3, S-5, 2L-326 1/16/2010 6.0 IPERF 2.5" HSD HJ, 60 degree
phase
HORIZONTAL, 2L-326, 4/3/2023 8:53:07 AM
Vertical schematic (actual)
PRODUCTION; 32.4-10,509.2
FRAC; 10,227.0
IPERF; 10,227.0-10,237.0
WLEG; 10,051.0
NIPPLE; 10,043.5
PACKER; 9,998.5
LEAK; 10,000.0
PBR; 9,985.2
LEAK - TUBING; 9,985.0
LOCATOR; 9,982.9
SLEEVE; 9,934.9
GAS LIFT; 9,883.8
LEAK; 9,852.0
GAS LIFT; 9,008.5
LEAK; 8,734.0
LEAK; 8,689.0
LEAK; 8,606.0
LEAK; 8,500.0
LEAK; 8,308.0
GAS LIFT; 6,617.9
SURFACE; 35.1-3,107.0
GAS LIFT; 3,085.0
NIPPLE; 509.8
CONDUCTOR 24" Insulated;
36.0-114.0
HANGER; 30.1
KUP PROD
KB-Grd (ft)
-85.28
RR Date
1/6/2010
Other Elev…
2L-326
...
TD
Act Btm (ftKB)
10,519.0
Well Attributes
Field Name
TARN PARTICIPATING AREA
Wellbore API/UWI
501032059700
Wellbore Status
PROD
Max Angle & MD
Incl (°)
72.14
MD (ftKB)
3,215.72
WELLNAME WELLBORE2L-326
Annotation
Last WO:
End DateH2S (ppm)
60
Date
12/6/2016
Comment
SSSV: NIPPLE
Stimulation Intervals
Top (ftKB) Btm (ftKB)
Inter
val
Num
ber Type Subtype Start Date
Proppant
Designed (lb)
Proppant
Total (lb)
Vol Clean
Total (bbl)
Vol Slurry
Total (bbl)
10,227.0 10,237.0 1 FRAC 1/21/2010 0.0 0.00 0.00
HORIZONTAL, 2L-326, 4/3/2023 8:53:08 AM
Vertical schematic (actual)
PRODUCTION; 32.4-10,509.2
FRAC; 10,227.0
IPERF; 10,227.0-10,237.0
WLEG; 10,051.0
NIPPLE; 10,043.5
PACKER; 9,998.5
LEAK; 10,000.0
PBR; 9,985.2
LEAK - TUBING; 9,985.0
LOCATOR; 9,982.9
SLEEVE; 9,934.9
GAS LIFT; 9,883.8
LEAK; 9,852.0
GAS LIFT; 9,008.5
LEAK; 8,734.0
LEAK; 8,689.0
LEAK; 8,606.0
LEAK; 8,500.0
LEAK; 8,308.0
GAS LIFT; 6,617.9
SURFACE; 35.1-3,107.0
GAS LIFT; 3,085.0
NIPPLE; 509.8
CONDUCTOR 24" Insulated;
36.0-114.0
HANGER; 30.1
KUP PROD 2L-326
...
WELLNAME WELLBORE2L-326
2L-326 Proposed RWO Completion
COMPLETION
INFO
MD
(ft RKB)
TVD
(ft RKB)
OD
(in)
Nom. ID
(in)
Weight
(lb/ft)Grade Thread
(top)
Thread
(btm)
Conductor 16
Surface 9.625
Production/
Intermediate 7
Liner
Tubing 3.5 x 2.875
PROPOSED COMPLETION
3-1/2" 9.3# L-80 EUE 8rd Tubing to surface
3-½" X landing nipple at ~2000' RKB (2.813" min ID)
3-1/2" Camco MMG gas lift mandrels @ TBD
3.5" x 7.0" Packer @ ~9,900' RKB (4" ID)
3-½" X landing nipple at ~9,950' RKB (2.813" min ID)
3-1/2" Non-sealing Overshot
REMAINING COMPLETION LEFT IN HOLE
PBR
3.5" x 7.0" FHL Packer @ 9,998.5' RKB
2.75" D nipple @ 10,0435.5' RKB
WLEG @ 10,051' RKB
Surface Casing
Production/Intermediate
Casing
Conductor
Tarn Perfs
C:\Users\mdguhl\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\LCF4WGUY\2022-12-10_15891_KRU_2L-326_LeakPointSurvey_Transmittal.docx
DELIVERABLE DISCRIPTION
Ticket #Field Well #API #Log Description Log Date
15891 KRU 2L-326 50-103-20597-00 LeakPoint Survey 10-Dec-22
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
By Meredith Guhl at 7:40 am, Dec 20, 2022
209-027
T37392
Meredith Guhl Digitally signed by Meredith Guhl
Date: 2022.12.20 07:41:24 -09'00'
C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-08-08_21092_KRU_2L-326_LeakPointSurvey_Transmittal.docx
DELIVERABLE DISCRIPTION
Ticket # Field Well # API # Log Description Log Date
21092 KRU 2L-326 50-103-20597-00 LeakPoint Survey 08-Aug-22
DELIVERED TO
Company & Address
DIGITAL FILE
# of Copies
LOG PRINTS
# of Prints
CD’s
# of Copies
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:209-027
T36879
Kayla
Junke
Digitally signed by
Kayla Junke
Date: 2022.08.17
09:07:39 -08'00'
•
• • -Ck ZL -��
Regg, James B (DOA) r ` 07
From: NSK Prod Engr Specialist <n1139@conocophillips.com>
Sent: Friday, August 11, 2017 4:00 PM
To: Bixby, Brian D (DOA) -QIUt Z'17
Cc: Regg,James B (DOA) 7
Subject: 170701 KRU 2L-Pad Deficiency Report
Attachments: 2L AOGCC Deficiency Report - Completed File - 08-11-2017.pdf
Brian,
Please see the completed deficiency report for 2L. The paperwork, photo and lab reports have all been combined into a
single file for simplicity. If you prefer separate files or need anything additional from us please let me know.
Cheers,
Matt
Matthew Raiche/Darrell Humphrey
Production Engineering Specialist
ConocoPhillips
AlaskaCANNED r
Ph:907.659.7535 I Pg:924 I Mail: NSK 69
Original Message
From: NSK Prod Engr Specialist
Sent: Sunday,July 02, 2017 9:22 AM
To: Bixby, Brian D (DOA)<brian.bixby@alaska.gov>
Subject,RE: [EXTERNAL] Emailing: 170701 KRU 2L-Pad Deficiency Report.pdf
Brian-enclosed is a signed copy of the AOGCC Deficiency Report for your records. We will follow up on this and send you
documentation of the corrective actions taken when completed.
Thanks,
Darrell Humphrey
907-659-7535
Original Message
From: Bixby, Brian D (DOA) [mailto:brian.bixby@alaska.gov]
Sent: Sunday,July 02, 2017 7:20 AM
To: NSK Prod Engr Specialist<n1139@conocophillips.com>
Subject: [EXTERNAL] Emailing: 170701 KRU 2L-Pad Deficiency Report.pdf
Darrell,
Please print this, sign it and send it back to me.
Thanks,
•
• •
Brian
Brian Bixby
Petroleum Inspector
Cell 509-998-3683
brian.bixby@alaska.gov
CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil
and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may
contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may
violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or
forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Brian Bixby at (907) 279-1433
or brian.bixby@alaska.gov.
2
• •
State of Alaska
Oil and Gas Conservation Commission
Deficiency Report
Location: KI u ZL•314 Date: uty ter zai
PTD: .I1-1 -OAS
Operator: ecp/•1Q(-d�/""1L1.1♦}S ALAcVA-. Type Inspection:sus -r1 i(..1
Operator Rep:`-f::4gg,(ke,L VpAtaRei Inspector"-FDRIp,,,} lykr,�1
Position:-"a0 GiGiw ,2 a ,�R..sST— 11
Op.Phone: q G59-/G?, c Correct by(date): '5 p r
Op.Email: n 13RC7cc c coNILLtm. Follow Up Req`d:
Detailed Description of Deficiencies Date Corrected
v Z L -314 /her, 4 lA/ LL'S 4.1_,/srALLet 7///7/7-
KU ,2 f;-3Z 11 '3Z-1°1'3271
ALL. u) -L S ,"1-14 �
__ is ,As .�t si..1.iN up Ito 664_444,41 Atalir?.
i o UP "T-LP J "T46 FLu'res O#—k AJC-u-S . 9 .ttAstz
!nl vFaTIC TE � y;iP O.i- 'ME C--r As I Pos rn•..1
a ,,t01.1iK6 Sr..1Rd 'r !S NOT" 0tb rn r"44° ►_
Attachments: &pro of Ihs\ted WM c' n[2L-3I11)j LAs repor+5 -gas analysis
Signatures:
/ Operator Rep 7; 2./7,
Af4 osy AOGCC Inspector
*After signing,a copy of this form is to be left with the operator.
Follow-up Instructions
Return a copy of this Deficiency Report to AOGCC(Attention:Inspection Supervisor)within 7 days of receipt. Include the"Date
Corrected"and attach supporting documentation for each corrective action implemented to address the deficiencies. If a follow-up
inspection was performed by AOGCC,include the date and name of Inspector. Extensions for corrective actions taking longer than
the"correct by"date must be requested and accompanied by justification(Attention:Inspection Supervisor).Documentation of
deficiences that are outside of AOGCC regulatory jurisdiction will be forwarded to the appropriate authority for follow-up action.
Revised 2/2016
-��� ���
�L-���� •���
. . r
���»;�7'7�
'u
~./ ^^�v ConocoPhillips
Alaska
AOGCC EXCEPTION REPORT
Location: 2L Date: 07/01U7 AOGCC Inspector: Brian Bixby
Correct by: September 1st 2017
Instructions: All exceptions listed below must be corrected by date noted on the AOGCC Deficiency
Report. Documentation of the work performed is to be entered into the 'Action Taken'section below.
Note - Failure to comply with these instructions may constitute a violation of SOA regulations and may
be subject to enforcement action under 20 AAC 25.535
EXCEPTIONS NOTED:
2L'314 - a well sign needs to be installed -Confirm sign is in place with a photo.
2L Wells-All wells need to be inspected for gas bubbling up through the cellars and Flutes. A gas sample
is requested to determine the source. See AOGCC deficiency report,
Action Taken to Correct Problem:
Gas samples from the bubbling conductors/cellars as well as the
IA's were taken from wells 2L-327 and 2L-326 on 7/6/17 (the OA
FLs for both wells were at surface; therefore no OA gas sample
could be obtained). Lab analysis of the composition of the gas
samples from conductor/cellars showed they were methane and N2
primarily(as would be expected from natural ground sources with Date: 07/17/17 Initials: KAL
air contamination). They did not match the annulus gases which
contain significant quantities of ethane/propane/butane/Dentne.
On 2 separate occasions we attempted to obtain cellar/conductor
samples from 2L-321 (bubbling had been observed from that well
on the day of the inspector visit). However no bubbling was present
on either day, which supports our understanding that the natural
ground source gas liberation tends to be intermittent.
A new sign with pertinent well information was installed on the Date: 08/11/17 Initials: MCR
outside of the well house. Please see attached photo.
Date: Initials:
Date: Initials:
Date: Initials:
Date: Initials:
Return completed form to Prod. Engr. Specialist:
• n1139(c7r,conocophillips.com •
Distribution: CPF DSLT
CPF OPS Supv
Prod. Engr. Specialist
C.C. CPF1&2 Ops Supt
CPF3 Ops & DOT Pipelines Supt
NSK Fieldwide Operations Supt
• S
KUPARUK LAB ANALYTICAL REPORT *
907-659-7214 n1020@cop.com COnaFh�lll
ps
Sample Number:5-170713-00228
Sample Name:Conductor Flutes
Location: Area:KUPARUK Unit:DS2L Sample Point:21-326 ( 421-D ZLgo Z-7
Sampled Date: 7/6/2017 9:00:00AM
Matrix Id: GAS-MISC
Reviewed By: Carville, Daniele Date:07/16/2017
Analysis Results:
Test Parameter Result UOM
D-1945*N2(NITROGEN)
N2(NITROGEN) 1.206 Mole%
D-1945*CARBON DIOXIDE
CARBON DIOXIDE 0.000 Mole%
D-1945*METHANE
METHANE 98.636 Mole%
0-1945*ETHANE
ETHANE 0.035 Mole%
D-1945*PROPANE
PROPANE 0.017 Mole%
D-1945*I-BUTANE
I-BUTANE 0.004 Mole%
D-1945*N-BUTANE
N-BUTANE 0.010 Mole%
D-1945*I-PENTANE
I-PENTANE 0.002 Mole%
D-1945*N-PENTANE
N-PENTANE 0.002 Mole%
0-1945*TOTAL C6S
TOTAL CBS 0.000 Mole%
D-1945*TOTAL C7S
TOTAL C7S 0.005 Mole%
D-1945*C6 HEAVIER
C6 HEAVIER 0.087 Mole%
D-1945*C8 HEAVIER
C8 HEAVIER 0.082 Mole%
0-1945*NET HEAT OF COMBUSTION
NET HEAT OF COMB 898.5 Btu/SCF
D-1945*AVERAGE MOL WT
AVERAGE MOLECULAR WT 16.29 g/mol
D-1945*SP GRAV IDEAL
SPECIFIC GRAY IDEAL 0.5625
D-1945*SP GRAV REAL
SPECIFIC GRAV REAL 0.5633
D-1945*COMP FACTOR
COMPRESSIBILITY 0.9980
0-1945*BTU/IDEAL CF(DRY)
BTU/IDEAL CF(DRY) 1003.2 Btu/SCF
D-1945*BTU/REAL CF(DRY)
BTU/REAL CF(DRY) 1002.1 Btu/SCF
0-1945*BTU/REAL CF(SAT)
• •
KUPARUK LAB ANALYTICAL REPORT
Conoco(chilli
907-659-7214 n1020@cop.com
Sample Number:S-170713-00228
Sample Name:Conductor Flutes
Location: Area:KUPARUK Unit:DS2L Sample Point:21-326
Sampled Date: 7/6/2017 9:00:00AM
Matrix Id: GAS-MISC
Reviewed By: Carville,Daniele Date:07/16/2017
Analysis Results:
Test Parameter Result uom
BTU/REAL CF(SAT) 984.5 Btu/SCF
D-1945*BTU/IDEAL CF(SAT)
BTU/IDEAL CF(SAT) 988.1 Btu/SCF
Sample Notes/Comments
• •
KUPARUK LAB ANALYTICAL REPORT
ConocoPhillips
907-659-7214 n1020@cop.com
Sample Number:S-170713-00225
Sample Name:Cellar Gas Bubbling from Cellar Floor
Location: Area:KUPARUK Unit: DS2L Sample Point:2L-326
Sampled Date: 7/6/2017 8:45:00AM
Matrix Id: GAS-MISC
Reviewed By: Carville,Daniele Date:07/16/2017
Analysis Results:
Test Parameter Result UOM
0-1945*N2(NITROGEN)
N2(NITROGEN) 23.686 Mole%
0-1945•CARBON DIOXIDE
CARBON DIOXIDE 0.576 Mole%
D-1945*METHANE
METHANE 75.636 Mole%
D-1945*ETHANE
ETHANE 0.011 Mole%
0-1945*PROPANE
PROPANE 0.003 Mole%
D-1945*I-BUTANE
I-BUTANE 0.003 Mole%
D-1945*N-BUTANE
N-BUTANE 0.011 Mole%
D-1945*I-PENTANE
I-PENTANE 0.006 Mole%
D-1945*N-PENTANE
N-PENTANE 0.007 Mole%
D-1945*TOTAL C6S
TOTAL C6S 0.013 Mole%
D-1945*TOTAL C75
TOTAL C7S 0.016 Mole%
0-1945*C6 HEAVIER
C6 HEAVIER 0.060 Mole%
D-1945*C8 HEAVIER
C8 HEAVIER 0.031 Mole%
D-1945*NET HEAT OF COMBUSTION
NET HEAT OF COMB 689.6 Btu/SCF
0-1945*AVERAGE MOL WT
AVERAGE MOLECULAR WT 19.11 g/mol
D-1945*SP GRAV IDEAL
SPECIFIC GRAV IDEAL 0.6598
D-1945*SP GRAV REAL
SPECIFIC GRAV REAL 0.6605
D-1945*COMP FACTOR
COMPRESSIBILITY 0.9985
D-1945*BTU/IDEAL CF(DRY)
BTU/IDEAL CF(DRY) 768.6 Btu/SCF
D-1945*BTU/REAL CF(DRY)
BTU/REAL CF(DRY) 767.3 Btu/SCF
D-1945*BTU/REAL CF{SAT)
••
KUPARUK LAB ANALYTICAL REPORT
OlocAkhlli
ps
907-659-7214 n1020@cop.com
Sample Number:S-170713-00225
Sample Name:Cellar Gas Bubbling from Cellar Floor
Location: Area:KUPARUK Unit:DS2L Sample Point:2L-326
Sampled Date: 7/6/2017 8:45:00AM
Matrix Id: GAS-MISC
Reviewed By: Carville, Daniele Date:07/16/2017
Analysis Results:
Test Parameter Result VOM
BTU/REAL CF(SAT) 753.9 Btu/SCF
D-1945*BTU/IDEAL CF(SAT)
BTU/IDEAL CF(SAT) 757.0 Btu/SCF
Sample Notes/Comments
•
• •
KUPARUK LAB ANALYTICAL REPORT onoc chilli
ps
907-659-7214 n1020@cop.com
Sample Number;S-170711-00283 •
Sample Name:DS2L Well-326 IA Casing Valve
Location: Area:KUPARUK Unit:DS2L Sample Point:2L-326
Sampled Date: 7/6/2017 8:15:00AM
Matrix Id: GAS-MISC
Reviewed By: Carville,Daniele Date:07/16/2017
Analysis Results:
Test Parameter Result UOM
D-1945*N2(NITROGEN)
N2(NITROGEN) 0.325 Mole%
D-1945*CARBON DIOXIDE
CARBON DIOXIDE 1.167 Mole%
D-1945*METHANE
METHANE 81.609 Mole%
D-1945*ETHANE
ETHANE 8.358 Mole%
D-1945*PROPANE
PROPANE 4.707 Mole%
D-1945*I-BUTANE
I-BUTANE 0.973 Mole%
0-1945*N-BUTANE
N-BUTANE 2.044 Mole%
D-1945*I-PENTANE
I-PENTANE 0.321 Mole%
D-1945*N-PENTANE
N-PENTANE 0.319 Mole%
D-1945*TOTAL C65
TOTAL CGS 0.104 Mole%
D-1945*TOTAL C7S
TOTAL C7S 0.050 Mole%
0-1945*C6 HEAVIER
C6 HEAVIER 0.178 Mole%
D-1945*C8 HEAVIER
C8 HEAVIER 0.024 Mole%
D-1945*NET HEAT OF COMBUSTION
NET HEAT OF COMB 1105.4 Btu/SCF
D-1945*AVERAGE MOL WT
AVERAGE MOLECULAR WT 20.67 g/mol
0-1945*SP GRAV IDEAL
SPECIFIC GRAV IDEAL 0.7136
D-1945*SP GRAV REAL
SPECIFIC GRAV REAL 0.7157
0-1945*COMP FACTOR
COMPRESSIBILITY 0.9966
D-1945*BTU/IDEAL CF(DRY)
BTU/IDEAL CF(DRY) 1223.6 Btu/SCF
D-1945*BTU/REAL CF(DRY)
BTU/REAL CF(DRY) 1223.9 Btu/SCF
0-1945*BTU/REAL CF(SAT)
• •
KUPARUK LAB ANALYTICAL REPORTf i�hillI
ps
907-659-7214 n1020@cop.com
Sample Number:S-170711-00283
Sample Name:DS2L Well-326 IA Casing Valve
Location: Area:KUPARUK Unit:DS2L Sample Point:2L-326
Sampled Date: 7/6/2017 8:15:00AM
Matrix Id: GAS-MISC
Reviewed By: Carville, Daniele Date:07/16/2017
Analysis Results:
Test Parameter Result UOM
BTU/REAL CF(SAT) 1202.5 Btu/SCF
D-1945*BTU/IDEAL CF(SAT)
BTU/IDEAL CF(SAT) 1205.1 Btu/SCF
ONLINE*PRESSURE
LINE PRESSURE 900 psi
Sample Notes/Comments
