Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout208-1141. 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: OA Down Squeeze
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:
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD):
13836' 5400'
Casing Collapse
Structural
Conductor
Surface
Intermediate
Production
Liner Slotted
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 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
(907) 265-6218
Staff Well Integrity Engineer
CRU CD2-467
4099' 4749' 3921' 4749', 4769'
N/A
Subsequent Form Required:
Suspension Expiration Date:
Will perfs require a spacing exception due to property boundaries?
Current Pools:
MPSP (psi): Plugs (MD):
17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval.
Authorized Name and
Digital Signature with Date:
Tubing Size:
Dusty.Freeborn@conocophillips.com
AOGCC USE ONLY
Tubing Grade: Tubing MD (ft):
343' MD and 343' TVD
368' MD and 368' TVD
4710' MD and 3902' TVD
N/A
Dusty Freeborn
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL0380075, ADL0387207
208-114
P.O. Box 100360, Anchorage, AK 99510 5010320579-00-00
Colville River Field Qannik Oil Pool
ConocoPhillips Alaska, Inc.
Length Size
Proposed Pools:
PRESENT WELL CONDITION SUMMARY
Qannik Oil Pool
TVD Burst
5260' MD
MD
114'
2384'
4077'
114'
2704'
16"
10-3/4"
78'
7-5/8"5365'
2668'
5399'
Slots: 5407-5681', 5763-8673', 9475-
9715', 10035-10316', 10674-11591',
11711-12111', 12513-12793', 12955-
13114', 13273-13633'
4-1/2"
4078-4084', 7082-4086', 4084-4080',
4081-4083', 4081-4079', 4078-4085',
4087-4089', 4089-4086', 4087-4086',
4087-4091'
Perforation Depth TVD (ft):
1/21/2026
13638'8385'
4-1/2"
4091'
Packer: P2P Patch Packer
Packer: P2P Patch Packer
Packer: Baker Premier Packer
SSSV: None
Perforation Depth MD (ft):
L-80
approval: Notify AOGCC so that a representative may witness Sundry Number:
BOP Test Mechanical Integrity Test Location Clearance
ons of Approval:
ection MIT Req'd? Yes No Subsequent Form Required:
Suspension Expiration Date:
AOGCC USE ONLY
quest: Abandon Plug Perforations Fracture Stimulate Reppair Well Operations shutdown
Suspend Perforate Other Stimulate Pulll Tubing Change Approved Program
Plug for Redrill Perforate New Pool Re-enter Susp Well Alteer Casing Other: OA Down Squeeze
ame:4.Current Well Class:5. Permit to Drill Number:
Exploratory Development
Stratigraphic Service 6. API Number:
g:8. Well Name and Number:
ation or Conservation Order governs well spacing in this pool?
Yes No
esignation (Lease Number):10. Field:
D (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD:Junk (MD):
5400'
g Collapse
al
or
e
ate
on
ed
SSSV Type:Packers and SSSV MD (ft) and TVD (ft):
nts: Proposal Summary Wellbore schematic 13. Well Class after proposed work:
ations Program BOP Sketch Exploratory Stratigraphic Development Service
Date for 15. Well Status after proposed work:
Operations:OIL WINJ WDSPL Suspended
proval:Date:GAS WAG GSTOR SPLUG
esentative: GINJ Op Shutdown Abandoned
Contact Name:
Contact Email:
Contact Phone:
e:
(907) 265-6218
Staff Well Integrity Engineer
CRU CD2-467
4099'4749'3921' 4749',4769'
N/A
quire a spacing exception due to property boundaries?
Current Pools:
MPSP (psi):Plugs (MD):
certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval.
me and
ure with Date:
Tubing Size:
Dusty.Freeborn@conocophillips.com
Tubing Grade: Tubing MD (ft):
343' MD and 343' TVD
368' MD and 368' TVD
4710' MD and 3902' TVD
N/A
Dusty Freeborn
75, ADL0387207
208-114
360, Anchorage, AK 99510 5010320579-00-00
Colville River Field Qannik Oil Pool
s Alaska, Inc.
Length Size
Proposed Pools:
PRESENT WELL CONDITION SUMMARY
Qannik Oil Pool
TVD Burst
5260' MD
MD
114'
2384'
4077'
114'
2704'
16"
10-3/4"
78'
7-5/8"5365'
2668'
5399'
, 5763-8673', 9475-
16', 10674-11591',
513-12793', 12955-
633'
4-1/2"
4078-4084', 7082-4086', 4084-4080',
4081-4083',4081-4079', 4078-4085',
4087-4089', 4089-4086', 4087-4086',
4087-4091'
Perforation Depth TVD (ft):
1/21/2026
13638'8385'
4-1/2"
4091'
Packer: P2P Patch Packer
Packer: P2P Patch Packer
Packer: Baker Premier Packer
SSSV:None
pth MD (ft):
L-80
Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
326-033
By Grace Christianson at 11:17 am, Jan 15, 2026
10-404
X
VTL 1/28/2026 DSR-1/16/26
X
TS 1/15/26JLC 1/29/2026
01/29/26
CD2-467 Page 1
Date:
Subject:
Network #:
Prepared By:
7 Jan 2026
CD2-467 OA Cement Shoe Procedure:
104633309: Diagnostics & Repair
Expense Base, CD2-467 OA Cement
Dusty Freeborn
Objective
Down squeeze 10-3/4x 7-5/8 OA to cement from surface to surface casing shoe to attempt to
repair the SC leak and potentially the IAxOA leak.
Cement Volume Calculations:
Volume in 10-3/4x 7-5/8 annulus: (2,704 ft; 2,384 TVD) x (0.0397 bbl/ft) = 108 bbl
Total volume: 215 bbls mixed (15.8 ppg) +40 bbls (dry) : 255 bbls
Backup: 10.8 ppg: 150 bbls
CRU CD2-467 (PTD#208-114) is a producer that was originally drilled and completed in 2008.
The well is currently shut-in for multiple barrier failures with known flow to surface.
CD2-467 is slated for the second quarter of 2026 RWO but the well conditions complicate
ability of the rig to access the well with the proper barriers. CD2-467 currently has two tubing
plugs installed with a tubing patch over a known TxIA leak at 355. A passing MIT-T suggests at
least one of the tubing plugs and tubing patch has integrity. The well also has a production
casing leak that is within the surface casing shoe allowing IAxOA communication. A surface
casing leak was repaired but during integrity testing an additional leak(s) were discovered. The
leak depth is unknown, but below the depth of 26 and above the conductor shoe as there are
returns to surface if pressure is applied to the OA. The tubing and IA have KWF (10.8ppg brine)
installed to manage the reservoir prior to the mechanical barriers being in place.
Surface casing LOT was 17.5 ppg when drilled in 2008. The goal of OA cementing is to mitigate
the surface casing leak and potentially mitigate the IAxOA communication.
Procedure
1. Verify 10-403 Sundry form has been approved for OA cement job.
2. Contact cement pumping services to schedule the OA cement job and allow time for
pilot testing.
3. Conduct safety meetings and identify all potential hazards. Inspect wellhead and pad
CD2-467 Page 2
condition to identify any pre-existing conditions and note in WSR as needed.
4. Install 1502 union and valves on the OA. Rig up hardline to the OA with an option to
divert to open top tank for wash up. (see setup picture #1 below)
5. Ensure Valve crew services OA valves and any additional hardline valves installed for
cementing job.
6. Install containment into cellar to contain any returns from surface casing leak during
pumping operations. Ensure vac truck on location with cement contaminant to take
returns from surface casing leak from cement pumping operations.
7. Rig-up cement pumping equipment and rig up 2 hardline to the circulation skid.
Stage equipment to minimize pumping stop time between stages.
8. LRS pump truck to be hooked to IA and increase pressure to mimic surface pressures
seen on OA to attempt to mitigate cross flow between tubing and IA during pumping
operations.
9. Be sure to monitor around wellhead, wellhouse, and conductor top during OA pumping.
There is a known surface casing leaks near the surface
10. PT lines and surface equipment to 3,000 psi.
11. Pumping the OA shoe recommendations:
a. Complete an Injectivity test and ensure that OA will take injection.
i. Lead with methanol and swap to diesel for injection test.
ii. Treat the injectivity test like a Leak off test.
1. Pump slow and low pressure
a. The goal is to find the target injection pressure and not
frac the OA shoe.
2. Gradually move up injection pressure to 1000 psi to find 1.5 BPM.
a. Max injection pressure of 1500 psi.
3. After injectivity tests gets to 1.5 BPM, end test and move to step
#2 in pump schedule.
b. At the beginning of the job, increase the pump pressure as necessary to break
over on injection.
i. Do not exceed 1,000 psi.
ii. Slowly pumping ~1 BPM up to a maximum of 1.5 BPM.
c. When cement gets to the shoe (108 bbls pump total after starting on cement),
slow pumps to a maximum of 1 BPM or 500 psi.
d. With 25 bbls of cement past the shoe (133 bbls after starting cement), shut-
down pumps and watch pressure.
e. Perform a 15-minute hesitation, then attempt to slowly squeeze another 10 bbls
at minimum rate.
f. Continue 15-minute hesitation steps with 10 bbls at minimum rates until well
locks-up.
i. If OA does not catch pressure after 183 bbls are pumped in OA, stop
pumping cement and swap to pump ~140 bbls of diesel to FP the OAP
and ensure OA shoe is open. Keep the shoe open and contact Wells
CD2-467 Page 3
Supervisor, production engineer and WI engineer.
g. Use cement composition on page #4-5.
12. Pump Schedule:
a. Complete injectivity test with methanol and swap to diesel.
i. 2 bbls methanol and 25-70 bbls diesel (stop after 1.5 BPM reached)
b. 10 bbls hot diesel per Wells Supv.
c. 65 bbls 90oF hot freshwater for flush of the OA.
d. 20 bbls CW100 surfactant wash.
e. 10 bbls freshwater spacer.
f. 15 bbls 15.8# Class G cement (neat).
g. 133 bbls 15.8# Class G cement with 2 lbs/bbl of CemNet/Artic slurry gas blocker.
i. Perform 15-minute hesitation.
h. 10 bbls of 15.8# Class G cement with 2 lbs/bbl of CemNet/Artic slurry gas
blocker.
i. Repeat 15-minute hesitation step
i. 10 bbls of 15.8# Class G cement with 2 lbs/bbl of CemNet/Artic slurry gas
blocker.
i. Repeat 15-minute hesitation step
j. 10 bbls of 15.8# Class G cement with 2 lbs/bbl of CemNet and gas blocker.
i. Repeat 15-minute hesitation step
k. 10 bbls of 15.8# Class G cement with 2 lbs/bbl of CemNet and gas blocker.
i. Repeat 15-minute hesitation step
l. 10 bbls of 15.8# Class G cement with 2 lbs/bbl of CemNet and gas blocker.
i. Repeat 15-minute hesitation step
m. If well locks up while pumping cement, go to next step.
Pump Schedule:
Volume (bbl): Fluid: Details:
Step 1 2 bbls/~25-50 Methanol and diesel Complete injectivity test with methanol and swap to diesel.
Step 2 10 Hot diesel 10 bbls hot diesel per Wells Supv.
Step 3 65 Hot Fresh water 65 bbls 90F hot freshwater for flush of the OA.
Step 4 20 CW100 Surfactant 20 bbls CW100 surfactant wash.
Step 5 10 Freshwater 10 bbls freshwater spacer.
Step 6 15 15.8# Cement (neat) 15 bbls 15.8# Class G cement (neat).
Step 7 133 15.8# Cement gas blocker/CemNet 148 bbls 15.8# Class G cement with 2 lbs/bbl of CemNet/Artic slurry gas blocker.
Step 8 Perform 15-minute hesitation.
Step 9 10 15.8# Cement gas blocker/CemNet 10 bbls of 15.8# Class G cement with 2 lbs/bbl of CemNet/Artic slurry gas blocker.
Step 10 Repeat 15-minute hesitation step
Step 11 10 15.8# Cement gas blocker/CemNet 10 bbls of 15.8# Class G cement with 2 lbs/bbl of CemNet/Artic slurry gas blocker.
Step 12 Repeat 15-minute hesitation step
Step 13 10 15.8# Cement gas blocker/CemNet 10 bbls of 15.8# Class G cement with 2 lbs/bbl of CemNet and gas blocker.
Step 14 Repeat 15-minute hesitation step
Step 15 10 15.8# Cement gas blocker/CemNet 10 bbls of 15.8# Class G cement with 2 lbs/bbl of CemNet and gas blocker.
Step 16 Repeat 15-minute hesitation step
Step 17 10 15.8# Cement gas blocker/CemNet 10 bbls of 15.8# Class G cement with 2 lbs/bbl of CemNet and gas blocker.
Step 18 Repeat 15-minute hesitation step
13. Close annulus, open the cement clean up line, and circulate to tanks to wash tree and
surface equipment. Top off OA with diesel for freeze protection and clear casing valve of
cement.
CD2-467 Page 4
14. Do not bleed the OA. Monitor the conductor top and downspout and vac out fluids if
needed.
15. Wash up cementing equipment, RDMO.
16. Send OA cement shoe field blend UCA results to dusty.freeborn@conocophillips.com
17. After the cement cures for 72 hours, perform OA drawdown test.
18. If DDT passes DHD to drop string line and verify top of cement.
19. Report well work to AOGCC on 10-404 form.
Equipment Setup Picture#1:
LRS:
Pump Truck with 25 bbls diesel
NES:
Transport with cement mix water
Must be clean water with functional paddles
With 75 bbls of ~90 degree freshwater from hot water plant mixed with
chemicals from SLB bulk plan in Deadhorse-SLB East camp.
Transport with 75 bbls of PowerVis to be located at K-pad Mud plan.
Alpine Wells Support
Dirty vac truck to evacuate cellar during pumping
Transport with 10.8 bbls NaCL/NaBl to be loaded at K-pad mud plant
Transport with 290 bbls of 90-degree freshwater to be loaded at K-pad mud plant.
SLB
Cementing crew, cement and associated equipment
Last Tag
Annotation Depth (ftKB)Wellbore End Date Last Mod By
Last Tag: CD2-467 lmosbor
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Install Patch CD2-467 8/20/2024 boehmbh
Notes: General & Safety
Annotation End Date Last Mod By
Note:Failed CMIT-TxIA suspect production casing leak. Unknown depth. 10.8 KWF in well 7/1/2024 kdodson
NOTE: SC HAS A LEAK AT ~26' 4" BELOW THE OA VALVE 4/20/2024 bsgreen
NOTE: SC HAS A 21' LONG SLEEVE COVERING THE HOLE AT 13' 5" (21' 10" TOTAL REPAIRED
AREA)
4/20/2024 bsgreen
Casing Strings
Csg Des OD (in)ID (in)Top (ftKB)
Set Depth
(ftKB)
Set Depth
(TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread
CONDUCTOR 16 15.25 36.0 114.0 114.0 62.50 H-40 Welded
SURFACE 10 3/4 9.95 36.3 2,704.0 2,383.8 45.50 L-80 BTC-M
INTERMEDIATE 7 5/8 6.87 33.9 5,399.0 4,076.9 29.70 L-80 BTCM
LINER Slotted 4 1/2 3.96 5,253.2 13,638.0 4,091.2 12.60 L-80 SLHT
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
31.1
Set Depth
5,260.0
Set Depth
4,063.4
String Max No
4 1/2
Tubing Description
TUBING
Wt (lb/ft)
12.60
Grade
L-80
Top Connection
IBT-M
ID (in)
3.96
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)
31.1 31.1 0.00 HANGER 11.000 FMC 4 1/2" Tubing Hanger FMC 3.970
2,696.5 2,378.0 38.60 NIPPLE 5.000 4 1/2" Nipple (3.813" ID) Camco DB 3.813
4,641.0 3,863.7 54.22 GAS LIFT 5.984 4 1/2" GLM (3.833" Drift ID")Camco KBG-2 3.938
4,710.4 3,902.2 58.78 PACKER 6.580 4 1/2" X 7 5/8" Packer Baker Premier 3.870
4,769.3 3,930.9 62.75 NIPPLE 5.000 4 1/2" nipple w/ 3.725" ID HES XN 3.725
5,238.7 4,061.1 83.65 WLEG 6.400 4 1/2",12.6#, IBT-Mod half mule
shoe w/WLEG and fluted No-Go
Baker WLEG 3.940
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)
343.0 343.0 0.91 PACKER -
PATCH - UPR
4-1/2" Paragon II Packer,
4800# shear. ALPP45028
8/20/2024 2.000
348.0 348.0 0.94 SPACER
PIPE
2-3/8" Spacer Pipe 8/20/2024 1.995
355.0 355.0 0.97 LEAK -
TUBING
Leak in Tubing ~355ft. LLR =
0.33GPM
3/2/2016 0.000
368.0 368.0 0.94 PACKER -
PATCH - LWR
4-1/2" Paragon II Packer
4800# Shear, ALPP45012
8/20/2024 2.000
4,749.0 3,921.4 61.44 RBP 4.5" PIIP PACKER/RBP
Overall Length 7.88'
TTS P2P ALPP
45013
7/2/2024 0.000
4,769.0 3,930.8 62.73 TUBING
PLUG
XXN PLUG W/ FILL EXT (OAL
55")
6/29/2024 0.000
5,400.0 4,077.0 85.74 FISH (Not in
Tubing)
DV DROPPED INTO 7"
CASING
10/6/2014
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)
4,641.0 3,863.7 54.22 1 GAS LIFT DMY BK 1 0.0 8/19/2024 0.000
Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°)Item Des
OD
Nominal
(in)Com Make Model
Nominal ID
(in)
5,253.2 4,062.7 83.93 SLEEVE 6.420 "HR" Liner Setting Sleeve 5.75" ID
(11.91' Inner Profile)
5.040
5,266.9 4,064.1 83.96 NIPPLE 6.080 "RS" Packoff Seal Nipple (4.875"
ID)
4.875
5,280.4 4,065.6 83.98 XO BUSHING 6.040 XO Bushing - 5 1/2" BTC X 4 1/2"
SLHT (3.97" ID)
4.940
Perforations & Slots
Top (ftKB)Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB)Linked Zone Date
Shot
Dens
(shots/ft)Type Com
5,407.0 5,681.0 4,077.5 4,083.6 8/6/2008 32.0 SLOTS ALL PERFORATIONS =
Slots 1/8x2.25", 8 slots/row,
4 rows/ft; no slots 3' from
box/pin
5,763.0 8,673.0 4,082.0 4,086.4 8/6/2008 32.0 SLOTS
9,475.0 9,715.0 4,084.5 4,080.2 8/6/2008 32.0 SLOTS
10,035.0 10,316.0 4,081.3 4,082.6 8/6/2008 32.0 SLOTS
10,396.0 10,514.0 4,081.3 4,078.6 8/6/2008 32.0 SLOTS
10,674.0 11,591.0 4,077.5 4,084.9 8/6/2008 32.0 SLOTS
11,711.0 12,111.0 4,087.0 4,089.1 8/6/2008 32.0 SLOTS
12,513.0 12,793.0 4,088.5 4,085.5 8/6/2008 32.0 SLOTS
12,955.0 13,114.0 4,086.8 4,086.4 8/6/2008 32.0 SLOTS
13,273.0 13,633.0 4,086.9 4,091.1 8/6/2008 32.0 SLOTS
HORIZONTAL, CD2-467, 1/14/2026 2:38:29 PM
Vertical schematic (actual)
LINER Slotted; 5,253.2-13,638.0
SLOTS; 13,273.0-13,633.0
SLOTS; 12,955.0-13,114.0
SLOTS; 12,513.0-12,793.0
SLOTS; 11,711.0-12,111.0
SLOTS; 10,674.0-11,591.0
SLOTS; 10,396.0-10,514.0
SLOTS; 10,035.0-10,316.0
SLOTS; 9,475.0-9,715.0
SLOTS; 5,763.0-8,673.0
SLOTS; 5,407.0-5,681.0
FISH (Not in Tubing); 5,400.0
INTERMEDIATE; 33.9-5,399.0
TUBING PLUG; 4,769.0
RBP; 4,749.0
PACKER; 4,710.4
Intermediate Casing Cement;
4,006.0 ftKB
GAS LIFT; 4,641.0
SURFACE; 36.3-2,704.0
NIPPLE; 2,696.5
Surface Casing Cement; 36.0
ftKB
PACKER - PATCH - LWR; 368.0
SPACER PIPE; 348.0
LEAK - TUBING; 355.0
PACKER - PATCH - UPR; 343.0
CONDUCTOR; 36.0-114.0
Conductor Cement; 36.0 ftKB
WNS INJ
KB-Grd (ft)
44.51
RR Date
8/8/2008
Other Elev
CD2-467
...
TD
Act Btm (ftKB)
13,836.0
Well Attributes
Field Name
QANNIK
Wellbore API/UWI
501032057900
Wellbore Status
INJ
Max Angle & MD
Incl (°)
91.78
MD (ftKB)
9,283.86
WELLNAME WELLBORE
Annotation
Last WO:
End DateH2S (ppm)DateComment
SSSV: WRDP
Cement Squeezes
Top (ftKB)Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB)Des Com
Pump Start
Date
36.0 114.0 36.0 114.0 Conductor
Cement
2/27/2008
36.0 2,714.0 36.0 2,391.7 Surface
Casing
Cement
Cemented casing as follows Pumped 40 bbls Biozan
water w/ nut plug as marker w/ rig pump - switched
over to Dowell pumped 5 bbls water , pressure
tested lines to 3000 psi, - Dropped btm plug. --
pumped 50 bbls of MudPush at 12.5 ppg, ave. 4.9
bpm and 200 psi. - Mixed and pumped lead slurry
ASL @ 10.7 ppg - Observed nut plug marker @
shakers w/ 324 bbls lead pumped- Pumped down
surge can total of 336 bbls Lead - Switched over to
tail slurry Mixed & pumped 58 bbls Class G w/
additives @ 15..8 ppg @ 6 bbls/ min @ 239 psi -
Dropped top plug and Dowell pumped 20 bbls water
then turned over to the rig and rig finished. displacing
cmt with 231 bbls of 10.0 ppg mud, ave. 7 bpm, ICP
300 psi, max press. 650 psi, with 7 bbls and slowed
to 4 bpm at 630 psi. Bumped plug to 1100 psi. CIP
@ 1823 hrs. - had full returns thru out job, checked
floats and held. - 125 bbls 10.7 ppg cmt returns to
surface.
7/21/2008
4,006.0 5,409.0 3,411.1 4,077.6 Intermediate
Casing
Cement
Cemented casing as follows, pumped 5 bbls CW
100, pressure tested lines to 3,700 psi, fin. pumping
25 bbls (30 total) of CW 100 at 8.3 ppg, ave 3.3 bpm
at 209 psi., then pumped 30 bbls of MudPush at 12.5
ppg, ave. 5 bpm and 306 psi. Dropped btm plug.
Mixed and pumped 53.2 bbls (258 sxs) of class "G"
tail cmt at 15.8 ppg and 1.17 yield including
additives, ave 6.0 bpm at 260 psi. Dropped top plug
and Dowell pumped 20 bbls water then turned over
to the rig and rig fin. displacing cmt with 223.7 bbls of
9.8 ppg LSND mud, ave. 7 bpm, ICP 180 psi, max
press. 210 psi, with 30 bbls to go stopped
reciprocating pipe and slowed to 4.0 bpm at 320 psi.
Bumped plug to 960 psi. CIP @ 20:40 hrs.
Reciprocated pipe and had full returns thru out job,
checked floats and held. Calc TOC @ 4,500'.
7/25/2008
HORIZONTAL, CD2-467, 1/14/2026 2:38:31 PM
Vertical schematic (actual)
LINER Slotted; 5,253.2-13,638.0
SLOTS; 13,273.0-13,633.0
SLOTS; 12,955.0-13,114.0
SLOTS; 12,513.0-12,793.0
SLOTS; 11,711.0-12,111.0
SLOTS; 10,674.0-11,591.0
SLOTS; 10,396.0-10,514.0
SLOTS; 10,035.0-10,316.0
SLOTS; 9,475.0-9,715.0
SLOTS; 5,763.0-8,673.0
SLOTS; 5,407.0-5,681.0
FISH (Not in Tubing); 5,400.0
INTERMEDIATE; 33.9-5,399.0
TUBING PLUG; 4,769.0
RBP; 4,749.0
PACKER; 4,710.4
Intermediate Casing Cement;
4,006.0 ftKB
GAS LIFT; 4,641.0
SURFACE; 36.3-2,704.0
NIPPLE; 2,696.5
Surface Casing Cement; 36.0
ftKB
PACKER - PATCH - LWR; 368.0
SPACER PIPE; 348.0
LEAK - TUBING; 355.0
PACKER - PATCH - UPR; 343.0
CONDUCTOR; 36.0-114.0
Conductor Cement; 36.0 ftKB
WNS INJ CD2-467
...
WELLNAME WELLBORE
Casing Cementing Program
String: OA Down Squeeze
Well Name: CD2-467
Company: ConocoPhillips Alaska
Field:
Contact: Dusty Freeborn
State: AK
Proposal Number: 1
Date: 1/13/2026
Made By: Stephen Lauper
Service from District: Anchorage, AKA
District Phone:
Objective: Squeeze cement into 10-3/4 x 7-5/8in
OA to surface shoe with cement
remaining at surface
Acceptance Criteria: Pump per program (Rate, Volume,
Density)
Disclaimer Notice
SLB submits this document with the benefit of its judgment, experience, and good oilfield practices.
This information is provided in accordance with generally accepted industry practice, relying on facts or information provided by others, limitations, computer
models, measurements, assumptions, and inferences that are not infallible.
Calculations are estimates based on provided information. All proposals, recommendations, or predictions are opinions only.
NO WARRANTY IS GIVEN CONCERNING ACCURACY OR COMPLETENESS OF DATA, INFORMATION PRESENTED, EFFECTIVENESS OF MATERIAL, PRODUCTS OR
SUPPLIES, RECOMMENDATIONS MADE, OR RESULTS OF THE SERVICES RENDERED.
Freedom from infringement of any intellectual property rights of SLB or others is not to be inferred and no intellectual property rights are granted hereby.
2 of 18
Document Control
Once approved by SLB and the Operator, any deviation from this program requires document agreement (SLB QHSE
Standard S010 Management of Change and Exemption Standard)
Approvals
Name Signature Date
Author Stephen Lauper
SLB review Mitch Rice Via FDP pending
SLB Approval Marcela Terrazas Via FDP Pending
Customer Approval Dusty Freeborn
By signing this document (or confirmation email), I confirm I have reviewed and approved it as the basis for the well
cementing program.
Cementing Program Generated From
CEMENTICS File cd2-467 oa squeeze.jdcx
CEMENTICS Version 2024.1.41
Revision History
Date Version Description Author
1/13/2026 V1 Program per client plan slauper
3 of 18
Well Data Summary
The cementing program incorporates the following data:
Rig Type Land
Fluids Return to Rig Floor
BHST 58.7 degF
All depths take the rig floor as reference
Mud Line Depth 0.0 ft
Mud Return Depth 0.0 ft
Section MD 2709.0 ft
Section TVD 2387.8 ft
Tubulars and Casing Hardware
Top MD
ft
Bottom
MD
ft
OD
in
Joint
ft
Weight
lb/ft
ID
in
Grade Collapse
psi
Burst
psi
Thread
Prev Casing 0.0 108.0 16 40.0 109.0 14.688 C-95 3320 6820
0.0 2704.0 10 3/4 40.0 45.5 9 19/20 J-55 2090 3580
Casing 0.0 2709.0 7 5/8 40.0 29.7 6.393
M-65 4310 5590
Landing Collar 500.0 Serial number:
Float Shoe
4 of 18
Open Hole
Total Volume 0.4 bbl
Minimum Diameter 9.625 in
Maximum Diameter 9.625 in
Mean Diameter 9.625 in
Mean Annular Excess 0.0 %
Mean Equivalent Diameter 9.625 in
Formation
Top
MD
ft
Bottom
MD
ft
Bottom
TVD
ft
Frac
Top ED
lb/gal
Frac
Bottom ED
lb/gal
Pore
Top ED
lb/gal
Pore
Bottom ED
lb/gal
Lithology
Res.
Fluid
Name
0.0 855.0 853.5 17.50 17.50 8.00 8.00 Siltstone Permafrost
855.0 1000.0 994.7 17.50 17.50 8.00 8.00 Sandstone
1000.0 1500.0 1438.4 17.50 17.50 8.00 8.00 Sandstone
1500.0 2709.0 2387.8 17.50 17.50 8.00 8.00 Sandstone
Temperature
Name
Top MD
ft
Bottom MD
ft
Bottom TVD
ft
Temperature
degF
Gradient
degF/100ft
Relative
Gradient
degF/100ft
Surface 0.0 0.0 0.0 20.0 0.00
Rock 0.0 1200.0 1180.6 32.1 1.02 1.02
5 of 18
Temperature
Name
Top MD
ft
Bottom MD
ft
Bottom TVD
ft
Temperature
degF
Gradient
degF/100ft
Relative
Gradient
degF/100ft
BHST 1200.0 2709.0 2387.8 58.7 1.62 2.20
Rock 2709.0 3500.0 3178.8 76.1 1.76 2.20
6 of 18
Fluids Summary
Fluids
Type Name Density
lb/gal
Conditions K
lbf.s^n/ft2
n
Ty
lbf/100ft2
Drilling Fluid Seawater 8.60 Manual Surface 80.0
degF
6.27E-5 1.00 0.00
Wash Fresh Water 8.32 Manual Surface 80.0
degF
2.09E-5 1.00 0.00
Drilling Fluid Diesel 7.00 Manual Surface 120.0
degF
2.09E-5 1.00 0.00
Slurry Cold Temp D500
Slurry
15.80 Surface 75.0 degF 4.46E-2 0.48 15.88
Drilling Fluid MeOH 7.00 Manual Surface 80.0
degF
2.09E-5 1.00 0.00
Drilling Fluid 9.8 Brine 9.80 Manual Surface 80.0
degF
6.27E-5 1.00 0.00
Wash Wash Lead 8.30 Manual Surface 80.0
degF
2.09E-5 1.00 0.00
* Compressible Rheology Parameters and Densities are displayed at P = 1 atm and T = 20 degC (65 degF)
7 of 18
Fluid Placement
Surface Densities are computed at P = 1 atm and T=Surface Temperature (20.0 degF)
Fluid Placement in Annulus
Fluid Name Top MD
ft
Bottom MD
ft
Length
ft
Volume
bbl
Surface Density
lb/gal
9.8 Brine 0.0 0.0 0.0 0.0 9.80
Diesel 0.0 0.0 0.0 10.0 7.00
Fresh Water 0.0 0.0 0.0 65.0 8.32
Wash Lead 0.0 0.0 0.0 20.0 8.30
Fresh Water 0.0 0.0 0.0 7.9 8.32
Fresh Water 0.0 52.9 52.9 2.1 8.32
Cold Temp D500
Slurry
52.9 2709.0 2656.1 105.4 15.80
Fluid Placement in Pipe
Fluid Name Top MD
ft
Bottom MD
ft
Length
ft
Volume
bbl
Surface Density
lb/gal
Cold Temp D500
Slurry
0.0 2709.0 2709.0 107.6 15.80
8 of 18
Pumping Schedule
Pumping Schedule
Fluid Name
Duration
hr:mn
Volume
bbl
Pump
Rate
bbl/min
Injection
Temperature
degF
Comment
Cumulated
Time
hr:mn
Diesel 00:10 10.0 1.0 120.0 Diesel Ahead 00:10
Fresh Water 01:05 65.0 1.0 90.0 Pump Hot Fresh Water
Ahead
01:15
Wash Lead 00:20 20.0 1.0 80.0 Pump F103/U067 Wash 01:35
Fresh Water 00:10 10.0 1.0 80.0 Pump Fresh Water Spacer 01:45
Cold Temp D500 Slurry
:
04:48 213.0 Mix/Pump Slurry (1-3
BPM)- Rate per injection
and pressure limits per
company rep
> Cold Temp D500
Slurry
00:15 15.0 1.0 75.0 15-bbls Cement NEAT 02:00
> Cold Temp D500
Slurry
02:28 148.0 1.0 75.0 Mix/Pump Cement + 2-
lb/bbls CemNET
04:28
> Pause 00:15 Hesitate 04:43
> Cold Temp D500
Slurry
00:10 10.0 1.0 75.0 04:53
> Pause 00:15 Hesitate 05:08
> Cold Temp D500
Slurry
00:10 10.0 1.0 75.0 05:18
> Pause 00:15 Hesitate 05:33
> Cold Temp D500
Slurry
00:10 10.0 1.0 75.0 05:43
> Pause 00:15 Hesitate 05:58
> Cold Temp D500
Slurry
00:10 10.0 1.0 75.0 06:08
> Pause 00:15 Hesitate 06:23
> Cold Temp D500
Slurry
00:10 10.0 1.0 75.0 06:33
Maximum Required Hydraulic Horsepower (HHP) 5.3 hhp (at 06:33 hr:mn)
9 of 18
10 of 18
Well Security
Well Security
Status Description Min Differential
Pressure
psi
At Depth
ft
At Time
hr:mn
Success Fracturing 59 2709.0 06:33
Success Production/Influx 28 2704.0 02:46
Success Burst 5376 65.6 06:33
Success Collapse 3827 1148.3 02:46
11 of 18
Temperature Outputs
Temperature Summary Table
Static Temperature at TOC 20.5 degF Static Temperature at BH 58.7 degF
Simulated HCT at TOC 52.2 degF Simulated HCT at BH 70.7 degF
Max First SK Temperature 120.0 degF Max Last SK Temperature -459.7 degF
At time 00:00 hr:mn At time 00:00 hr:mn
12 of 18
13 of 18
Operator Summary
Volume Summary
Fluid Name
Pumped Volume
bbl
Prepared Fluid
Dead Volume
bbl
Prepared Fluid
bbl
Mix Fluid Dead
Volume
bbl
Silo dead volume
short ton
Cold Temp D500 Slurry 213.0 40.0 253.0 10.0 0
Fresh Water 75.0 0.0 75.0 0.0 0
Wash Lead 20.0 0.0 20.0 0.0 0
Material Summary
Additive Pumped
Quantity
Required
Quantity
Loadout
Quantity
Loadout
Items
Pack.
Name
Pack. Size Comment
Fresh Water 8340.53 gal 9512.56 gal 9512.56 gal 0.00 0.00 gal
Cold Temp D500 Slurry
Blend
94982.84 lb 112823.81 lb 112823.81
lb
0.00 bulk 0.00 lb
Mix Water 4390.53 gal 5562.56 gal 5562.56 gal 0.00 0.00 gal
D044 1826.46 lb 2169.53 lb 2169.53 lb 39.45 sack 55.00 lb
D047 49.53 gal 62.75 gal 62.75 gal 12.55 pail 5.00 gal
D185A 60.63 gal 76.81 gal 76.81 gal 1.54 drum 50.00 gal
D500 606.27 gal 768.11 gal 768.11 gal 14.49 drum 53.00 gal
D186 50.52 gal 64.01 gal 64.01 gal 12.80 pail 5.00 gal
D168 151.57 gal 192.03 gal 192.03 gal 38.41 pail 5.00 gal
F103 20.00 gal 20.00 gal 20.00 gal 0.36 drum 55.00 gal
U067 20.00 gal 20.00 gal 20.00 gal 4.00 pail 5.00 gal
14 of 18
Fluid Preparation
Cold Temp D500 Slurry
Pumped Volume: 213.0 bbl
Density: 15.80 lb/gal
SVF: 39.9 %
Yield: 1.18 ft3/sk
Dry Phase Concentration Pumped Quantity Required Quantity Loadout Quantity
Total Dry Phase 96809.31 lb 114993.35 lb
Cold Temp D500 Slurry
Blend:
94.00 lb per sack 94982.84 lb 112823.81 lb 112823.81 lb
- G 97.7 % BVOB 93120.43 lb 110611.58 lb 110611.58 lb
- D053 2.0 % BWOC 1862.41 lb 2212.23 lb 2212.23 lb
D044 5.0 % BWOW 1826.46 lb 2169.53 lb 2169.53 lb
Liquid Phase Concentration Pumped Quantity Required Quantity Loadout Quantity
Mix Fluid 5.254 gal/sk VBWOB 5309.06 gal 6726.28 gal
Mix Water 4.345 gal/sk VBWOB 4390.53 gal 5562.56 gal 5562.56 gal
Fresh Water 4.345 gal/sk VBWOB 4390.53 gal 5562.56 gal 5562.56 gal
D047 0.050 gal/sk VBWOC 49.53 gal 62.75 gal 62.75 gal
D185A 0.060 gal/sk VBWOB 60.63 gal 76.81 gal 76.81 gal
D500 0.600 gal/sk VBWOB 606.27 gal 768.11 gal 768.11 gal
D186 0.050 gal/sk VBWOB 50.52 gal 64.01 gal 64.01 gal
D168 0.150 gal/sk VBWOB 151.57 gal 192.03 gal 192.03 gal
Fresh Water
Pumped Volume: 75.0 bbl
Density: 8.32 lb/gal
Base Fluid Concentration Pumped Quantity Required Quantity Loadout Quantity
Total Liquid Phase 1.0 bbl/bbl BVOWash 3150.00 gal 3150.00 gal
Fresh Water 1.0 bbl/bbl BVOWash 3150.00 gal 3150.00 gal 3150.00 gal
Wash Lead
Pumped Volume: 20.0 bbl
Density: 8.30 lb/gal
Base Fluid Concentration Pumped Quantity Required Quantity Loadout Quantity
Total Liquid Phase 1.0 bbl/bbl BVOWash 840.00 gal 840.00 gal
Fresh Water 1.0 bbl/bbl BVOWash 800.00 gal 800.00 gal 800.00 gal
F103 1.0 gal/bbl BVOWash 20.00 gal 20.00 gal 20.00 gal
U067 1.0 gal/bbl BVOWash 20.00 gal 20.00 gal 20.00 gal
15 of 18
OA Down Squeeze
1. Confirm well data and calculations with Wellsite Rep., minimum but not limited to:
pipe tally (including centralization) and capacities, perforations depths, pumping schedule,
displacement fluid type and volume, anticipated pressures during the job and
contingencies.
2. Conduct a meeting with the tool hand, the rig and SLB personnel involved in the
operation, reviewing safety, operational procedure, task assignments and contingency
plans.
3. Flush surface treating line to the mud pits with +/-5bbls of water.
4. Rig up on the tubing and annular as per WS STD 5. Note: A squeeze manifold may be
necessary.
5. Pressure test treating lines to 1000 psi above the maximum expected treating pressure
6. Close the back side (annuli) and pressure test to ensure proper seal of the stinger (500psi)
7. Adjust the volume of cement to be pumped, if needed, and prepare mix fluid.
Consider dead volumes and peer-check additives calculations.
8. Execute the following pumping schedule
Maximum Required Hydraulic Horsepower
(HHP)
5.3 hhp (at 06:33 hr:mn)
Fluid Name
Duration
hr:mn
Volume
bbl
Pump
Rate
bbl/min
Comment
Cumulated
Time
hr:mn
Diesel 00:10 10.0 1.0 Diesel Ahead 00:10
Fresh Water 01:05 65.0 1.0 Pump Hot Fresh Water
Ahead
01:15
Wash Lead 00:20 20.0 1.0 Pump F103/U067 Wash 01:35
Fresh Water 00:10 10.0 1.0 Pump Fresh Water Spacer 01:45
Cold Temp D500
Slurry :
04:48 213.0 Mix/Pump Slurry (1-3
BPM)- Rate per injection
and pressure limits per
company rep
> Cold Temp D500
Slurry
00:15 15.0 1.0 15-bbls Cement NEAT 02:00
> Cold Temp D500
Slurry
02:28 148.0 1.0 Mix/Pump Cement + 2-
lb/bbls CemNET
04:28
> Pause 00:15 Hesitate 04:43
16 of 18
> Cold Temp D500
Slurry
00:10 10.0 1.0 04:53
> Pause 00:15 Hesitate 05:08
> Cold Temp D500
Slurry
00:10 10.0 1.0 05:18
> Pause 00:15 Hesitate 05:33
> Cold Temp D500
Slurry
00:10 10.0 1.0 05:43
> Pause 00:15 Hesitate 05:58
> Cold Temp D500
Slurry
00:10 10.0 1.0 06:08
> Pause 00:15 Hesitate 06:23
> Cold Temp D500
Slurry
00:10 10.0 1.0 06:33
CONTINGENCIES
Situation Action
Slurry density variation exceeding +/- 0.2ppg Stop pumping and regain density control in the mixing
tub before going downhole
Unexpected Shut down Do not exceed 20min unless previously lab tested
9. Optional: For block squeeze hesitate until reaching squeeze closure.
Do not exceed the thickening time
10. Bleed off pressure and reverse circulate clean
11. Rig down and wash the equipment
17 of 18
18 of 18
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: Tubing Patch
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 13836'feet 4749', 4769'feet
true vertical 4099' feet 5400' feet
Effective Depth measured 4749'feet 343', 368', 4710'feet
true vertical 3921' feet 343', 368', 3902' feet
Perforation depth Measured depth
True Vertical depth
Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 5260' MD 4063' TVD
Packers and SSSV (type, measured and true vertical depth) 343' MD
368' MD
4710' MD
N/A
343' TVD
368' TVD
3902' TVD
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: Qannik 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:
2704' 2384'
Burst Collapse
Production
Slotted Liner
5365'
8385'
Casing
4077'
4-1/2"
5399'
13638' 4091'
2668'
114'Conductor
Surface
Intermediate
16"
10-3/4"
78'
measured
TVD
7-5/8"
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
208-114
50-103-20579-00-00
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:
ADL0380075, ADL0387207
Colville River Field/ Qannik Oil Pool
CRU CD2-467
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
MD
~
Size
114'
~ ~~
INJECTOR ~~
~
324-334
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: PIIP Patch Packer
Packer: PIIP Patch Packer
Packer: Baker Premier Packer
SSSV: None
Mark Shulman
mark.shulman@conocophillips.com
(907) 263-3782Senior Well Interventions Engineer
Slotted Liner: 5407-13633' MD
Slotted Liner: 4077-4091' TVD
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 11:20 am, Sep 18, 2024
DTTMSTART JOBTYP SUMMARYOPS
7/10/2024 REPAIR WELL SET 4 1/2" TTS TEST PACKER & ATTEMPT TO TEST @ @ 4733', 4721', 4715', &
4670' RKB (TESTING BETWEEN TEST PACKER & RBP @ 4749' RKB) LEAK RATE
VARIES AT DIFFERENT TEST POINTS. LINEAR LEAK OF 10 PSI PER MIN AT LAST
TEST POINT.
SET TEST PACKER ABOVE GLM @ 4621' RKB & LOAD IA W/ 145 bbls of 10.8
NaCl/NaBr. UNSEAT TEST PACKER AND LOAD TUBING WITH 80 BBL OF 10.8 PPG
NaCl/NaBr. JOB COMPLETE.
7/10/2024 ACQUIRE DATA (AC-EVAL) T, IA & OA DDT (COMPLETE)
8/19/2024 REPAIR WELL SET 1" DMY VLV W/ BK LATCH @ 4641' RKB. LOG WITH 40 ARM CALIPER FROM
4719' SLM. GOOD DATA ON CALIPER. JOB IN PROGRESS.
8/20/2024 REPAIR WELL RIG UP SLB ELINE TO SET QUADCO PATCH IN 4-1/2" TUBING. LOWER PACKER
SETTING DEPTH = 371'. CCL TO MID ELEMENT = 10', CCL STOP DEPTH = 361'.
UPPER PACKER SETTING DEPTH = 346'. PATCH OAL = 25.03' ELEMENT TO
ELEMENT. JOB COMPLETE.
8/20/2024 REPAIR WELL (AC EVAL) MITT PASSED TO 1500 PSI , DDT PASSED
CD2-467 Patch
Summary of Operations
Last Tag
Annotation Depth (ftKB)Wellbore End Date Last Mod By
Last Tag:CD2-467 lmosbor
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Install Patch CD2-467 8/20/2024 boehmbh
Notes: General & Safety
Annotation End Date Last Mod By
Note:Failed CMIT-TxIA suspect production casing leak. Unknown depth. 10.8 KWF in well 7/1/2024 kdodson
NOTE: SC HAS A LEAK AT ~26' 4" BELOW THE OA VALVE 4/20/2024 bsgreen
NOTE: SC HAS A 21' LONG SLEEVE COVERING THE HOLE AT 13' 5" (21' 10" TOTAL REPAIRED
AREA)
4/20/2024 bsgreen
Casing Strings
Csg Des OD (in)ID (in)Top (ftKB)
Set Depth
(ftKB)
Set Depth
(TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread
CONDUCTOR 16 15.25 36.0 114.0 114.0 62.50 H-40 Welded
SURFACE 10 3/4 9.95 36.3 2,704.0 2,383.8 45.50 L-80 BTC-M
INTERMEDIATE 7 5/8 6.87 33.9 5,399.0 4,076.9 29.70 L-80 BTCM
LINER Slotted 4 1/2 3.96 5,253.2 13,638.0 4,091.2 12.60 L-80 SLHT
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
31.1
Set Depth
5,260.0
Set Depth
4,063.4
String Max No
4 1/2
Tubing Description
TUBING
Wt (lb/ft)
12.60
Grade
L-80
Top Connection
IBT-M
ID (in)
3.96
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)
31.1 31.1 0.00 HANGER 11.000 FMC 4 1/2" Tubing Hanger FMC 3.970
2,696.5 2,378.0 38.60 NIPPLE 5.000 4 1/2" Camco "DB" Nipple (3.813"
ID)
CAMCO DB
Nipple
3.813
4,641.0 3,863.7 54.22 GAS LIFT 5.984 4 1/2"Camco KGB2 GLM (3.833"
Drift ID")
CAMCO KBG-2 3.938
4,710.4 3,902.2 58.78 PACKER 6.580 4 1/2" X 7 5/8" Baker Premier
Packer
Baker Premier 3.870
4,769.3 3,930.9 62.75 NIPPLE 5.000 4 1/2" HES " XN" nipple w/ 3.725" ID HES XN
Nipple
3.725
5,238.7 4,061.1 83.65 WLEG 6.400 4 1/2",12.6#, IBT-Mod half mule
shoe w/WLEG and fluted No-Go
Baker WLEG 3.940
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)
343.0 343.0 0.91 PACKER -
PATCH - UPR
4-1/2" Paragon II Packer,
4800# shear. ALPP45028
8/20/2024 2.000
348.0 348.0 0.94 SPACER
PIPE
2-3/8" Spacer Pipe 8/20/2024 1.995
355.0 355.0 0.97 LEAK -
TUBING
Leak in Tubing ~355ft. LLR =
0.33GPM
3/2/2016 0.000
368.0 368.0 0.94 PACKER -
PATCH - LWR
4-1/2" Paragon II Packer
4800# Shear, ALPP45012
8/20/2024 2.000
4,749.0 3,921.4 61.44 RBP 4.5" PIIP PACKER/RBP
Overall Length 7.88'
TTS P2P ALPP
45013
7/2/2024 0.000
4,769.0 3,930.8 62.73 TUBING
PLUG
XXN PLUG W/ FILL EXT (OAL
55")
6/29/2024 0.000
5,400.0 4,077.0 85.74 FISH (Not in
Tubing)
DV DROPPED INTO 7"
CASING
10/6/2014
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)
4,641.0 3,863.7 54.22 1 GAS LIFT DMY BK 1 0.0 8/19/2024 0.000
Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°)Item Des
OD
Nominal
(in)Com Make Model
Nominal ID
(in)
5,253.2 4,062.7 83.93 SLEEVE 6.420 "HR" Liner Setting Sleeve 5.75" ID
(11.91' Inner Profile)
5.040
5,266.9 4,064.1 83.96 NIPPLE 6.080 "RS" Packoff Seal Nipple (4.875"
ID)
4.875
5,280.4 4,065.6 83.98 XO BUSHING 6.040 XO Bushing - 5 1/2" BTC X 4 1/2"
SLHT (3.97" ID)
4.940
Perforations & Slots
Top (ftKB)Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB)Linked Zone Date
Shot
Dens
(shots/ft)Type Com
5,407.0 5,681.0 4,077.5 4,083.6 8/6/2008 32.0 SLOTS ALL PERFORATIONS =
Slots 1/8x2.25", 8 slots/row,
4 rows/ft; no slots 3' from
box/pin
5,763.0 8,673.0 4,082.0 4,086.4 8/6/2008 32.0 SLOTS
9,475.0 9,715.0 4,084.5 4,080.2 8/6/2008 32.0 SLOTS
10,035.0 10,316.0 4,081.3 4,082.6 8/6/2008 32.0 SLOTS
10,396.0 10,514.0 4,081.3 4,078.6 8/6/2008 32.0 SLOTS
10,674.0 11,591.0 4,077.5 4,084.9 8/6/2008 32.0 SLOTS
11,711.0 12,111.0 4,087.0 4,089.1 8/6/2008 32.0 SLOTS
12,513.0 12,793.0 4,088.5 4,085.5 8/6/2008 32.0 SLOTS
12,955.0 13,114.0 4,086.8 4,086.4 8/6/2008 32.0 SLOTS
13,273.0 13,633.0 4,086.9 4,091.1 8/6/2008 32.0 SLOTS
HORIZONTAL, CD2-467, 9/17/2024 10:17:27 AM
Vertical schematic (actual)
LINER Slotted; 5,253.2-13,638.0
SLOTS; 13,273.0-13,633.0
SLOTS; 12,955.0-13,114.0
SLOTS; 12,513.0-12,793.0
SLOTS; 11,711.0-12,111.0
SLOTS; 10,674.0-11,591.0
SLOTS; 10,396.0-10,514.0
SLOTS; 10,035.0-10,316.0
SLOTS; 9,475.0-9,715.0
SLOTS; 5,763.0-8,673.0
SLOTS; 5,407.0-5,681.0
FISH (Not in Tubing); 5,400.0
INTERMEDIATE; 33.9-5,399.0
TUBING PLUG; 4,769.0
RBP; 4,749.0
PACKER; 4,710.4
GAS LIFT; 4,641.0
SURFACE; 36.3-2,704.0
NIPPLE; 2,696.5
PACKER - PATCH - LWR; 368.0
SPACER PIPE; 348.0
LEAK - TUBING; 355.0
PACKER - PATCH - UPR; 343.0
CONDUCTOR; 36.0-114.0
WNS INJ
KB-Grd (ft)
44.51
RR Date
8/8/2008
Other Elev
CD2-467
...
TD
Act Btm (ftKB)
13,836.0
Well Attributes
Field Name
QANNIK
Wellbore API/UWI
501032057900
Wellbore Status
INJ
Max Angle & MD
Incl (°)
91.78
MD (ftKB)
9,283.86
WELLNAME WELLBORE
Annotation
Last WO:
End DateH2S (ppm)DateComment
SSSV: WRDP
Originated: Delivered to:12-Sep-24
Alaska Oil & Gas Conservation Commiss 12Sep24-NR
ATTN: MeredithGuhl
333 W. 7th Ave., Suite 100
600 E 57th Place Anchorage, Alaska 99501-3539
Anchorage, AK 99518
(907) 273-1700 main (907)273-4760 fax
WELL NAME API #
SERVICE ORDER
# FIELD NAME
SERVICE
DESCRIPTION
DELIVERABLE
DESCRIPTION DATA TYPE DATE LOGGED
CD2-58 50-103-20457-00-00 203-085 Colville River WL SBHPS-RBP FINAL FIELD 16-Aug-24
CD2-21 50-103-20504-00-00 204-245 Colville River WL Patch FINAL FIELD 18-Aug-24
CD2-467 50-103-20579-00-00 208-114 Colville River WL Patch FINAL FIELD 20-Aug-24
1B-07 50-029-20616-00-00 181-089 Kuparuk River WL MechCutter FINAL FIELD 24-Aug-24
2A-11 50-103-20057-00-00 186-003 Kuparuk River WL Isealate Patch FINAL FIELD 27-Aug-24
3F-11 50-029-21482-00-00 185-272 Kuparuk River WL IPROF FINAL FIELD 29-Aug-24
2A-20 50-103-20196-00-00 193-151 Kuparuk River WL IPROF FINAL FIELD 30-Aug-24
3F-20 50-029-22947-00-00 199-079 Kuparuk River WL IPROF FINAL FIELD 2-Sep-24
3J-18 50-029-22701-00-00 196-147 Kuparuk River WL Lee-PPROF FINAL FIELD 3-Sep-24
2U-12 50-029-21304-00-00 185-041 Kuparuk River WL PPROF FINAL FIELD 4-Sep-24
1D-39 50-029-22997-00-00 200-216 Kuparuk River WL Punch-Cut FINAL FIELD 9-Sep-24
2P-448A 50-103-20396-01-00 202-005 Kuparuk River WL Punch FINAL FIELD 10-Sep-24
2P-432 50-103-20420-00-00 202-091 Kuparuk River WL Punch FINAL FIELD 11-Sep-24
2P-434 50-103-20467-00-00 203-153 Kuparuk River WL Punch FINAL FIELD 11-Sep-24
Transmittal Receipt
________________________________ X_________________________________
Print Name Signature Date
Please return via courier or sign/scan and email a copy to Schlumberger.
Nraasch@slb.com SLB Auditor -
TRANSMITTAL DATE
TRANSMITTAL #
A Delivery Receipt signature confirms that a package (box, envelope,
etc.) has been received. The package will be handled/delivered per
standard company reception procedures. The package's contents have
not been verified but should be assumed to contain the above noted
media.
# Schlumberger-Private
T39555
T39556
T39557
T39558
T39559
T39560
T39561
T39562
T39564
T39565
T39566
T39567
T39668
T39563
Gavin Gluyas
Digitally signed by Gavin
Gluyas
Date: 2024.09.13 08:31:59
-08'00'
CD2-467 50-103-20579-00-00 208-114 Colville River WL Patch FINAL FIELD 20-Aug-24 T39557
C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\2024-08-19_16002_CRU_CD2-467_CaliperSurvey_LogData_Transmittal.docx
DELIVERABLE DISCRIPTION
Ticket # Field Well # API # Log Description Log Date
16002 CRU CD2-467 50-103-20579-00 Caliper Survey w/ Log Data 19-Aug-24
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
208-114
T39479
Gavin Gluyas
Digitally signed by Gavin
Gluyas
Date: 2024.08.23 11:06:35
-08'00'
New Plugback Esets
7/15/2024
Well Name API Number PTD
Number
ESet
Number
Date
CRU C1-07 PB2 50-103-20478-71-00 203-225 T39188 1-29-2007
CRU CD2-467 PB1 50-103-20579-70-00 208-114 T39189 10-31-2008
CRU CD4-12 PB1 50-103-20414-70-00 210-091 T39190 9-20-2010
CRU CD4-210A PB1 50-103-20533-70-00 211-072 T39191 9-9-2011
KRU 1B-15AL3 PB1 50-029-22465-72-00 207-067 T39192 11-23-2009
KRU 1E-12L1 PB1 50-029-20736-70-00 210-004 T39193 5-24-2010
KRU 1E-12L2-01 PB1 50-029-20736-72-00 210-007 T39194 5-24-2010
KRU 3H-12A PB1 50-103-20088-70-00 211-081 T39195 9-9-2012
KRU 3I-11AL2 PB1 50-029-21932-70-00 210-076 T39196 11-1-2010
ODSK-33 PB1 50-703-20562-70-00 207-183 T39197 6-20-2008
OI11-01 50-029-23430-70-00 210-106 T39198 11-2-2010
OP04-07 PB1 50-029-23409-70-00 208-199 T39200 7-6-2010
OP08-04 PB1 50-029-23424-70-00 210-041 T39201 7-28-2010
PBU 06-02A PB1 50-029-20282-70-00 211-026 T39202 7-25-2011
PBU 15-05B PB1 50-029-20731-71-00 211-057 T39203 8-20-2011
PBU 15-16B PB1 50-029-21115-70-00 210-020 T39204 7-8-2010
PBU 18-04B PB1 50-029-20875-70-00 201-090 T39205 12-6-2002
PBU J-16B PB1 50-029-20967-70-00 212-014 T39206 9-28-2012
PBU K-05D PB1 50-029-21418-71-00 211-077 T39207 1-20-2012
PBU V-204L1 50-029-23217-60-00 204-132 T39208 11-13-2006
PBU W-19B PB1 50-029-22006-72-00 210-065 T39209 1-13-2011
PBU W-19BL1 PB1 50-029-22006-73-00 210-066 T39210 1-18-1011
SP23-N03 PB1 50-629-23456-70-00 211-127 T39211 3-5-2012
TBU M-10 PB1 50-733-20588-70-00 209-154 T39212 4-23-2010
CRU CD2-467 PB1 50-103-20579-70-00 208-114 T39189 10-31-2008
CAUTION: This email originated from outside the State of Alaska mail system.
Do not click links or open attachments unless you recognize the sender and know
the content is safe.
From:Wallace, Chris D (OGC)
To:AOGCC Records (CED sponsored)
Subject:FW: CD2-467 PTD 208-114
Date:Monday, July 1, 2024 9:31:47 AM
From: WNS Integrity <WNSIntegrity@conocophillips.com>
Sent: Monday, July 1, 2024 9:08 AM
To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>
Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com>
Subject: CD2-467 PTD 208-114
Chris,
During patch setting Sline work on CD2-467 (PTD 208-114), operations reported fluid in the
conductor. T/I/O have been bled and diagnostics are ongoing. Depending on results, proper
notifications will be made as needed.
Let me know if you have any questions or disagree with this plan.
Thanks,
Kate Dodson | Senior Well Integrity Engineer
ConocoPhillips Alaska | AK Intervention & Integrity
O: 907-265-6181 | M: 435-640-7200 | Kate.Dodson@conocophillips.com
1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown
Suspend Perforate Other Stimulate Pull Tubing Change Approved Program
Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Set Tubing Patch
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):
13836'5400'
Casing Collapse
Conductor
Surface
Intermediate
Lower Lateral 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
Kate Dodson
kate.dodson@conocophillips.com
(907) 265-6181
Senior Well Integrity Engineer
Tubing Grade:Tubing MD (ft):
Packer: 4710'MD/3902'TVD
SSSV: None
Perforation Depth TVD (ft):Tubing Size:
L-80 5260'
6/20/2024
Packer: Baker Premier
SSSV: None
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL0380075, ADL0387207
208-114
P.O. Box 100360, Anchorage, AK 99510 50-103-20579-00-00
ConocoPhillips Alaska, Inc.
CRU CD2-467
Qannik Oil PoolQannik Oil Pool Coville River Unit
N/A
Length Size
Proposed Pools:
TVD Burst
PRESENT WELL CONDITION SUMMARY
4099'4769'3931'3000'4769'
MD
114'
2384'
4077'
114'
2704'
4091'13638'
5399'
16"
10-3/4"
78'
2668'
Perforation Depth MD (ft):
7-5/8"5365'
5407-5681'
5763-8673'
9475-9715'
10035-10316'
10396-10514'
10674-11591'
11711-12111'
12513-12793'
12955-13114'
13273-13633'
8385'
4078-4084'
4082-4086'
4085-4080'
4081-4083'
4081-4079'
4078-4085'
4087-4089'
4089-4086'
4087-4086'
4087-4091'
4-1/2"
4-1/2"
s
66
tc
Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
Digitally signed by Kate Dodson
DN: OU=Wells, O=ConocoPhillips, CN=Kate Dodson, E=
kate.dodson@conocophillips.com
Reason:
Location:
Date: 2024.06.06 11:39:39-08'00'
Foxit PDF Editor Version: 13.0.0
Kate Dodson
SFD 6/10/2024 DSR-6/7/24
Please use current version of form. SFD
X
vTL 6/24/2024
X 10-404
By Grace Christianson (grace.christianson@alaska.gov) at 12:06 pm, Jun 24, 2024
*&:JLC 6/24/2024
Brett W. Huber, Sr.
Digitally signed by Brett W. Huber,
Sr.
Date: 2024.06.24 15:20:22 -08'00'06/24/24
RBDMS JSB 062624
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
June 6, 2024
Commissioner Jessie Chmielowski
Alaska Oil & Gas Commission
333 West 7th Avenue, Suite 100
Anchorage, AK 99501
Dear Commissioner Chmielowski,
Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips
Alaska, Inc. CRU well CD2-467 (PTD 208-114). This request is for approval to install a
tubing patch for repair of tubing by inner annulus communication.
Please contact me at 265-6181 if you have any questions.
Sincerely,
Kate Dodson
Senior Well Integrity Engineer
ConocoPhillips Alaska, Inc.
CD2-467 Tubing Patch Running Procedure
1. Pull plug from XN nipple at 4769'.
2. Brush and flush patch set area of ~300' - 400' '.
3. Set lower PIIP mid-element at 369'.
4. Set PIIP test tool and sting into lower packer.
5. Perform CMIT TxIA to 3000 psi.
6. Pull test tool.
7. Set anchor latch, spacer pipe and upper PIIP mid element at 349'.
8. Perform MIT-IA to confirm patch and tubing integrity.
9. Submit 10-404 post repair.
Last Tag
Annotation Depth (ftKB)Wellbore End Date Last Mod By
Last Tag:CD2-467 lmosbor
Last Rev Reason
Annotation Wellbore End Date Last Mod By
REV REASON: Prep for SCR CD2-467 12/12/2021 boehmbh
Notes: General & Safety
Annotation End Date Last Mod By
NOTE: SC HAS A 21' LONG SLEEVE COVERING THE HOLE AT 13' 5" (21' 10" TOTAL REPAIRED
AREA)
4/20/2024bsgreen
NOTE: SC HAS A LEAK AT ~26' 4" BELOW THE OA VALVE 4/20/2024 bsgreen
NOTE: FISH DROPPED INTO 7" CASING, UNABLE TO RETREIVE DUE TO DEVIATION 10/6/2014 lehallf
NOTE: VIEW SCHEMATIC w/9.0 8/10/2008 lmosbor
Casing Strings
Csg Des OD (in)ID (in)Top (ftKB)
Set Depth
(ftKB)
Set Depth
(TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread
CONDUCTOR1615.2536.0 114.0 114.062.50 H-40 Welded
SURFACE 10 3/49.9536.32,704.0 2,383.8 45.50 L-80 BTC-M
INTERMEDIATE 7 5/86.8733.95,399.0 4,076.9 29.70 L-80 BTCM
LINER Slotted 4 1/2 3.96 5,253.2 13,638.0 4,091.2 12.60 L-80 SLHT
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
31.1
Set Depth …
5,260.0
Set Depth …
4,063.4
String Max No…
4 1/2
Tubing Description
TUBING
Wt (lb/ft)
12.60
Grade
L-80
Top Connection
IBT-M
ID (in)
3.96
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)
31.131.10.00 HANGER 11.000 FMC 4 1/2" Tubing Hanger FMC3.970
2,696.5 2,378.038.60 NIPPLE 5.000 4 1/2" Camco "DB" Nipple (3.813"
ID)
CAMCO DB
Nipple
3.813
4,641.03,863.7 54.22 GAS LIFT 5.9844 1/2"Camco KGB2 GLM (3.833"
Drift ID") w/2500 psi SOV
CAMCO KBG-23.938
4,710.4 3,902.2 58.78 PACKER 6.580 4 1/2" X 7 5/8" Baker Premier
Packer
Baker Premier 3.870
4,769.33,930.962.75 NIPPLE 5.000 4 1/2" HES " XN" nipple w/ 3.725" ID HES XN
Nipple
3.725
5,238.7 4,061.183.65WLEG6.400 4 1/2",12.6#, IBT-Mod half mule
shoe w/WLEG and fluted No-Go
Baker WLEG3.940
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)
4,769.0 3,930.8 62.73 PLUG XXN PLUG W/ FILL EXT (OAL
55")
12/12/2021
5,400.0 4,077.0 85.74 FISH (Not in
Tubing)
DV DROPPED INTO 7"
CASING
10/6/2014
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)
4,641.03,863.7 54.22 1 GAS LIFT DMY BK 1 0.02/19/2016 0.000
Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°)Item Des
OD
Nominal
(in)Com Make Model
Nominal ID
(in)
5,253.2 4,062.7 83.93 SLEEVE 6.420 "HR" Liner Setting Sleeve 5.75" ID
(11.91' Inner Profile)
5.040
5,266.9 4,064.1 83.96 NIPPLE 6.080 "RS" Packoff Seal Nipple (4.875"
ID)
4.875
5,280.4 4,065.683.98 XO BUSHING6.040 XO Bushing - 5 1/2" BTC X 4 1/2"
SLHT (3.97" ID)
4.940
Perforations & Slots
Top (ftKB)Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB)Linked Zone Date
Shot
Dens
(shots/ft)Type Com
5,407.0 5,681.0 4,077.5 4,083.68/6/2008 32.0SLOTS ALL PERFORATIONS =
Slots 1/8x2.25", 8 slots/row,
4 rows/ft; no slots 3' from
box/pin
5,763.0 8,673.0 4,082.0 4,086.4 8/6/2008 32.0 SLOTS
9,475.0 9,715.0 4,084.5 4,080.2 8/6/2008 32.0 SLOTS
10,035.010,316.0 4,081.3 4,082.68/6/2008 32.0SLOTS
10,396.010,514.0 4,081.3 4,078.68/6/2008 32.0SLOTS
10,674.011,591.0 4,077.5 4,084.98/6/2008 32.0SLOTS
11,711.0 12,111.0 4,087.0 4,089.1 8/6/2008 32.0 SLOTS
12,513.0 12,793.0 4,088.5 4,085.5 8/6/2008 32.0 SLOTS
12,955.0 13,114.0 4,086.8 4,086.4 8/6/2008 32.0 SLOTS
13,273.0 13,633.0 4,086.9 4,091.18/6/2008 32.0SLOTS
HORIZONTAL, CD2-467, 5/5/2024 1:46:09 PM
Vertical schematic (actual)
LINER Slotted; 5,253.2-13,638.0
SHOE; 13,633.1-13,638.0
SLOTS; 13,273.0-13,633.0
SLOTS; 12,955.0-13,114.0
SLOTS; 12,513.0-12,793.0
SLOTS; 11,711.0-12,111.0
SLOTS; 10,674.0-11,591.0
SLOTS; 10,396.0-10,514.0
SLOTS; 10,035.0-10,316.0
SLOTS; 9,475.0-9,715.0
SLOTS; 5,763.0-8,673.0
SLOTS; 5,407.0-5,681.0
FISH (Not in Tubing); 5,400.0
INTERMEDIATE; 33.9-5,399.0
FLOAT SHOE; 5,396.9-5,399.0
FLOAT COLLAR; 5,309.8-
5,310.8
XO BUSHING; 5,280.4-5,282.3
HANGER; 5,270.6-5,280.4
NIPPLE; 5,266.9-5,270.6
SLEEVE; 5,253.2-5,265.6
WLEG; 5,238.7
PLUG; 4,769.0
NIPPLE; 4,769.3
PACKER; 4,710.4
GAS LIFT; 4,641.0
SURFACE; 36.3-2,704.0
Float Shoe; 2,701.7-2,704.0
NIPPLE; 2,696.5
Float Collar; 2,620.6-2,621.7
CONDUCTOR; 36.0-114.0
Casing Hanger; 36.3-38.5
Other; 33.9-36.5
HANGER; 31.1
WNS INJ
KB-Grd (ft)
44.51
RR Date
8/8/2008
Other Elev…
CD2-467
...
TD
Act Btm (ftKB)
13,836.0
Well Attributes
Field Name
QANNIK
Wellbore API/UWI
501032057900
Wellbore Status
INJ
Max Angle & MD
Incl (°)
91.78
MD (ftKB)
9,283.86
WELLNAME WELLBORE
Annotation
Last WO:
End DateH2S (ppm)DateComment
SSSV: WRDP
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: SC Repair
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 13,836' feet 4,769' feet
true vertical 4,099' feet 5,400' feet
Effective Depth measured feet 4,710' feet
true vertical feet 3,902' feet
Perforation depth Measured depth 5,407' - 13,633' feet
True Vertical depth 4,082' - 4,091' feet
Tubing (size, grade, measured and true vertical depth)4 1/2" L-80 5,260 4,063'
Packers and SSSV (type, measured and true vertical depth)Packer: 4,710' MD 3,902' TVD
SSSV: N/A
12. Stimulation or cement squeeze summary:N/A
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:
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:
323-383
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.
Baker Premier Packer
Well Integrity Field Supervisor
Brennen Green & Roger Mouser
N1927@conocophillips.com
907-659-7506
COLVILLE RIV QANN CD2-467
14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283)
Gas-Mcf
MD
measured
true vertical
Packer
Representative Daily Average Production or Injection Data
Casing Pressure Tubing Pressure
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
208-114
50-103-20579-00-00
N/A
5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work:
ADL0380075 / ADL0387207
COLVILLE RIVER / QANNIK OIL
ConocoPhillips Alaska, Inc.
3. Address:
P.O. Box 100630, Anchorage, Alaska 99508
Plugs
Junk measured
N/A
Length
78'
2,671'
114'Conductor
Surface
Intermediate
16"
10 3/4"
Size
114'
Liner
5,365'
8,385'
Casing
4,077'
4 1/2"
5,399'
13,638'4,091'
7 5/8"
measured
TVD
2,704'2,384'
Burst Collapse
p
k
ft
t
Fra
O
s
208
6. A
G
L
PG
,
r
Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov
Digitally signed by Brennen Green
DN: C=US, O=ConocoPhillips, CN=Brennen Green, E=
n1927@conocophillips.com
Reason: I am the author of this document
Location:
Date: 2024.05.05 14:43:35-08'00'
Foxit PDF Editor Version: 13.0.0
Brennen Green
By Grace Christianson at 9:57 am, May 06, 2024
RBDMS JSB 051524
DSR-5/6/24VTL 8/15/2024
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
May 5, 2024
Commissioner Jessie Chmielowski
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, AK 99501
Commissioner Chmielowski,
Please find enclosed the 10-404 from ConocoPhillips Alaska Inc. for the attempted Surface
Casing repair on ALP CD2-467 (PTD 208-114).
Feel free to contact me or my alternate, Roger Mouser, at 659-7506 if you have any questions.
Sincerely,
Well Integrity Field Supervisor
N1927@conocophillips.com
ConocoPhillips Alaska, Inc.
Digitally signed by Brennen Green
DN: C=US, O=ConocoPhillips, CN=Brennen Green, E=n1927@
conocophillips.com
Reason: I am the author of this document
Location:
Date: 2024.05.05 14:42:36-08'00'
Foxit PDF Editor Version: 13.0.0
Brennen Green
Date Event Summary
Executive
Summary
Attempted SC Repair: Welded a 21' sleeve to the SC to repair the SC leak @ 13' 5" (21' 10" total
repaired area). Second Leak estimated at ~26' 4" or greater below the OA valve. Decided not to
attempt further excavation.
05/03/24 (SC REPAIR) INSTALLED THE CELLAR BOX (COMPLETE)
04/28/24 (SC REPAIR) PULL STAIRS AND SHORING BOX (COMPLETE) BACKFILL EXCAVATION (IN
PROGRESS)
04/25/24 (SC REPAIR) INSULATE THE CONDUCTOR (COMPLETE) RIG DOWN SCAFFOLDING
(COMPLETE)
04/24/24
(SC REPAIR) DENSO WRAP THE SC (COMPLETE) INSTALL AND WELD THE CONDUCTOR
"DONUT" (COMPLETE) INSTALL AND WELD THE CONDUCTOR (COMPLETE 22' 5" LONG X 16"
DIAMETER X 0.375 WALL)
04/20/24
(SC REPAIR) WELD SC SLEEVE (COMPLETE *21' 10" TOTAL REPAIRED AREA*) NDE SC
SLEEVE (PASS) AOGCC WITNESSED THE REPAIR AND BUBBLING IN THE CONDUCTOR (GUY
COOK) SCLD (SC LEAK @ ~26' 4" BELOW THE OA VALVE).
04/19/24 (SC REPAIR) WELD SC SLEEVE (IN PROGRESS)
04/18/24
(SC REPAIR) WELD A BAND COLLAR (COMPLETE) NDE A & B COLLAR WELDS (PASS) FLY IN
AND FIT 21' SC SLEEVE (COMPLETE)
"A" Band collar stack (X65 0.375 wall x 6")
Sleeve (21' long x 12" diameter x 0.500" wall X65)
04/17/24
(SC REPAIR) N2 PURGE, PRE HEAT WELL HEAD WITH MILLER HEAT, WELD "A" AND "B"
COLLARS, MISTRAS INSPECTED "B" COLLAR, WELDED SECOND COLLAR TO "B" COLLAR. "A"
COLLAR WRAPPED WITH INSULATED BLANKET AND ALLOWED TO COOL OVERNIGHT. "B"
band collar (X-65 0.500 wall x 10.5" L)
"A" band collar (X-65 0.500 wall x 11.0" L)
"B" band collar stack (X65 0.375 wall x 6" L)
04/10/24 (SC REPAIR) PURGED OA WITH N2
04/03/24 (SC REPAIR) OA FL 2.5' BELOW LOWER WELD POINT, PURGED OA WITH N2
04/02/24 (SC REPAIR) EVACUATED OF-FL TO 2.5' BELOW LOWER MOST WELD POINT.
04/01/24 (SC-REPAIR) OA FL, REMOVE SNOW FROM EXCAVATION
03/26/24 (SC REPAIR) FINISH BUFF & NDE OF A & B BAND LOCATIONS
03/22/24 (SC REPAIR) BUFF / NDE A & B BANDS (IN PROGRESS)
03/19/24 (SC REPAIR) AOGCC WAIVED WITNESSING THE DAMAGE ON THE SC (ADAM EARL)
03/18/24 (SC Repair) : REMOVE RUST AND SCALE FROM SC (Complete).
03/17/24
(SC REPAIR) PURGE OA / CONDUCTOR (COMPLETE), CUT AND REMOVE 22' 3" OF
CONDUCTOR (COMPLETE). REMOVE CEMENT & IDENTIFY HOLE IN SURFACE CASING @ 13'
5", DRILL, TAP & PLUG HOLE IN SURFACE CASING (COMPLETE).
03/16/24 (SC REPAIR) PURGE OA / CONDUCTOR (IN PROGRESS)
03/15/24 (SC REPAIR) T DDT (PASS) IA DDT (PASS) OA DDT (PASS) CUT AND REMOVE THE
INSULATED CONDUCTOR (COMPLETE) REMOVE INSULATION (COMPLETE)
03/14/24 (SC REPAIR) T, IA, & OA DDT (IN PROGRESS)
03/13/24 (SC REPAIR) BUILD SCAFFOLDING & HOOCH (COMPLETE)
03/12/24 (SC REPAIR) BUILD SCAFFOLDING (IN PROGRESS)
03/10/24 (SC REPAIR) EXCAVATION (COMPLETE) SET SHORING BOX AND STAIRS (COMPLETE)
12/25/24 (SC REPAIR) EXCAVATION (IN PROGRESS. BROKE THROUGH ~5" OF ICE ON TOP OF
WATER)
12/20/24 (SC REPAIR) EXCAVATION (IN PROGRESS. EXCAVATED THE RAMP AND THE BENCH TO ~7'
*HITTING WATER*)
12/19/24 (SC REPAIR) EXCAVATION (IN PROGRESS EXCAVATED THE BENCH / PERIMETER TO ~3')
12/18/24 (SC REPAIR) EXCAVATION (IN PROGRESS EXCAVATED TO ~8' AROUND THE WELLHEAD)
12/17/24 (SC REPAIR) R&P Excavated to ~5' around the wellhead / cellar and AES Welders removed the
cellar box
12/15/24 MIstras inspected the SC inside of the conductor windows
12/09/24 ASRC Welders cut 2 large Inspection windows, chipped and removed cement for SC inspection.
10/28/23 (SEC) : DDT-T Passed, DDT-IA Passed.
01/14/22 (AC EVAL) : DDT-T Passed, DDT-IA Passed, DDT-OA Passed.
12/26/21 (SEC) CMIT-T X IA (PASSED TO 2500 PSI) T DDT (IN PROGRESS) IA DDT (IN PROGRESS) OA
DDT (IN PROGRESS)
12/11/21
PULLED A-1 INJECTION VALVE (SN: HSS-169) @ 2696' RKB; DRIFT TBG W/ 3.79" GAUGE RING
TO XN NIP @ 4769' RKB; SET 3.81" XXN PLUG W/ FILL EXTENSION @ 4769' RKB. READY FOR
DHD.
09/26/21 (AC EVAL) MIT IA TO 3000 PSI (PASSED), SCLD (COMPLETE, ESTIMATED LEAK BETWEEN 15' -
11')
Last Tag
Annotation Depth (ftKB)Wellbore End Date Last Mod By
Last Tag:CD2-467 lmosbor
Last Rev Reason
Annotation Wellbore End Date Last Mod By
REV REASON: Prep for SCR CD2-467 12/12/2021 boehmbh
Notes: General & Safety
Annotation End Date Last Mod By
NOTE: SC HAS A 21' LONG SLEEVE COVERING THE HOLE AT 13' 5" (21' 10" TOTAL REPAIRED
AREA)
4/20/2024bsgreen
NOTE: SC HAS A LEAK AT ~26' 4" BELOW THE OA VALVE 4/20/2024 bsgreen
NOTE: FISH DROPPED INTO 7" CASING, UNABLE TO RETREIVE DUE TO DEVIATION 10/6/2014 lehallf
NOTE: VIEW SCHEMATIC w/9.0 8/10/2008 lmosbor
Casing Strings
Csg Des OD (in)ID (in)Top (ftKB)
Set Depth
(ftKB)
Set Depth
(TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread
CONDUCTOR1615.2536.0 114.0 114.062.50 H-40 Welded
SURFACE 10 3/49.9536.32,704.0 2,383.8 45.50 L-80 BTC-M
INTERMEDIATE 7 5/86.8733.95,399.0 4,076.9 29.70 L-80 BTCM
LINER Slotted 4 1/2 3.96 5,253.2 13,638.0 4,091.2 12.60 L-80 SLHT
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
31.1
Set Depth …
5,260.0
Set Depth …
4,063.4
String Max No…
4 1/2
Tubing Description
TUBING
Wt (lb/ft)
12.60
Grade
L-80
Top Connection
IBT-M
ID (in)
3.96
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)
31.131.10.00 HANGER 11.000 FMC 4 1/2" Tubing Hanger FMC3.970
2,696.5 2,378.038.60 NIPPLE 5.000 4 1/2" Camco "DB" Nipple (3.813"
ID)
CAMCO DB
Nipple
3.813
4,641.03,863.7 54.22 GAS LIFT 5.9844 1/2"Camco KGB2 GLM (3.833"
Drift ID") w/2500 psi SOV
CAMCO KBG-23.938
4,710.4 3,902.2 58.78 PACKER 6.580 4 1/2" X 7 5/8" Baker Premier
Packer
Baker Premier 3.870
4,769.33,930.962.75 NIPPLE 5.000 4 1/2" HES " XN" nipple w/ 3.725" ID HES XN
Nipple
3.725
5,238.7 4,061.183.65WLEG6.400 4 1/2",12.6#, IBT-Mod half mule
shoe w/WLEG and fluted No-Go
Baker WLEG3.940
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)
4,769.0 3,930.8 62.73 PLUG XXN PLUG W/ FILL EXT (OAL
55")
12/12/2021
5,400.0 4,077.0 85.74 FISH (Not in
Tubing)
DV DROPPED INTO 7"
CASING
10/6/2014
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)
4,641.03,863.7 54.22 1 GAS LIFT DMY BK 1 0.02/19/2016 0.000
Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°)Item Des
OD
Nominal
(in)Com Make Model
Nominal ID
(in)
5,253.2 4,062.7 83.93 SLEEVE 6.420 "HR" Liner Setting Sleeve 5.75" ID
(11.91' Inner Profile)
5.040
5,266.9 4,064.1 83.96 NIPPLE 6.080 "RS" Packoff Seal Nipple (4.875"
ID)
4.875
5,280.4 4,065.683.98 XO BUSHING6.040 XO Bushing - 5 1/2" BTC X 4 1/2"
SLHT (3.97" ID)
4.940
Perforations & Slots
Top (ftKB)Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB)Linked Zone Date
Shot
Dens
(shots/ft)Type Com
5,407.0 5,681.0 4,077.5 4,083.68/6/2008 32.0SLOTS ALL PERFORATIONS =
Slots 1/8x2.25", 8 slots/row,
4 rows/ft; no slots 3' from
box/pin
5,763.0 8,673.0 4,082.0 4,086.4 8/6/2008 32.0 SLOTS
9,475.0 9,715.0 4,084.5 4,080.2 8/6/2008 32.0 SLOTS
10,035.010,316.0 4,081.3 4,082.68/6/2008 32.0SLOTS
10,396.010,514.0 4,081.3 4,078.68/6/2008 32.0SLOTS
10,674.011,591.0 4,077.5 4,084.98/6/2008 32.0SLOTS
11,711.0 12,111.0 4,087.0 4,089.1 8/6/2008 32.0 SLOTS
12,513.0 12,793.0 4,088.5 4,085.5 8/6/2008 32.0 SLOTS
12,955.0 13,114.0 4,086.8 4,086.4 8/6/2008 32.0 SLOTS
13,273.0 13,633.0 4,086.9 4,091.18/6/2008 32.0SLOTS
HORIZONTAL, CD2-467, 5/5/2024 1:46:09 PM
Vertical schematic (actual)
LINER Slotted; 5,253.2-13,638.0
SHOE; 13,633.1-13,638.0
SLOTS; 13,273.0-13,633.0
SLOTS; 12,955.0-13,114.0
SLOTS; 12,513.0-12,793.0
SLOTS; 11,711.0-12,111.0
SLOTS; 10,674.0-11,591.0
SLOTS; 10,396.0-10,514.0
SLOTS; 10,035.0-10,316.0
SLOTS; 9,475.0-9,715.0
SLOTS; 5,763.0-8,673.0
SLOTS; 5,407.0-5,681.0
FISH (Not in Tubing); 5,400.0
INTERMEDIATE; 33.9-5,399.0
FLOAT SHOE; 5,396.9-5,399.0
FLOAT COLLAR; 5,309.8-
5,310.8
XO BUSHING; 5,280.4-5,282.3
HANGER; 5,270.6-5,280.4
NIPPLE; 5,266.9-5,270.6
SLEEVE; 5,253.2-5,265.6
WLEG; 5,238.7
PLUG; 4,769.0
NIPPLE; 4,769.3
PACKER; 4,710.4
GAS LIFT; 4,641.0
SURFACE; 36.3-2,704.0
Float Shoe; 2,701.7-2,704.0
NIPPLE; 2,696.5
Float Collar; 2,620.6-2,621.7
CONDUCTOR; 36.0-114.0
Casing Hanger; 36.3-38.5
Other; 33.9-36.5
HANGER; 31.1
WNS INJ
KB-Grd (ft)
44.51
RR Date
8/8/2008
Other Elev…
CD2-467
...
TD
Act Btm (ftKB)
13,836.0
Well Attributes
Field Name
QANNIK
Wellbore API/UWI
501032057900
Wellbore Status
INJ
Max Angle & MD
Incl (°)
91.78
MD (ftKB)
9,283.86
WELLNAME WELLBORE
Annotation
Last WO:
End DateH2S (ppm)DateComment
SSSV: WRDP
2024-0420_Surface_Csg_Repair_CRU_CD2-467_gc
Page 1 of 3
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Jim Regg DATE: 4/21/2024
P. I. Supervisor
FROM: Guy Cook SUBJECT: Surface Casing Repair
Petroleum Inspector Alpine CD2-467
ConocoPhillips Alaska Inc.
PTD 2081140; Sundry 323-383
4/20/2024: I arrived on site and met with Brennen Green with ConocoPhillips. We
talked about the surface casing repair, and it was at this time he told me that they had
more than one leak. The first leak that they had identified and the one they had been
repairing was complete. The other leak was found deeper than they were and had not
been aware prior to the start of repairs, requiring more excavation to repair. Brennen is
still waiting on the decision to be made on how they are, or if they are, going to move
forward to repair the newly found leak. They suspect that the “new” leak is
approximately five feet deeper than the current excavation.
The repair that was done looked good. The welds were continuous, and I noticed no
areas in the repair that showed any signs of having issues with integrity. The total
length of the patch/repair is 21 feet 10 inches.
Attached photos show gas bubbling in the open conductor by surface casing annulus
below the casing repair. I also took a video of the repair and of the new leak –
electronic copy saved on the Inspection shared drive.
Attachments: Photos (3)
2024-0420_Surface_Csg_Repair_CRU_CD2-467_gc
Page 2 of 3
Surface Casing Repair – CRU CD2-467 (PTD 2081140)
Photos by AOGCC Inspector G. Cook
4/20/2024
2024-0420_Surface_Csg_Repair_CRU_CD2-467_gc
Page 3 of 3
Gas bubbling in the Conductor by
Surface casing annulus below the
casing patch
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?N/A
Yes No
9. Property Designation (Lease Number):10. Field:
11.
Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD):
13,836'5,400'
Casing Collapse
Conductor
Surface
Intermediate
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 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
COLVILLE RIV QANN CD2-467
COLVILLE RIVER QANNIK OIL N/A
4,099'4,769'
Subsequent Form Required:
Suspension Expiration Date:
Will perfs require a spacing exception due to property boundaries?
Current Pools:
MPSP (psi):Plugs (MD):
17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval.
Authorized Name and
Digital Signature with Date:
Tubing Size:
PRESENT WELL CONDITION SUMMARY
AOGCC USE ONLY
Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft):
Brennen Green & Roger Mouser
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL0380075 / ADL0387207
208-114
P.O. Box 100630, Anchorage, Alaska 99508 5010320579-0000
ConocoPhillips Alaska, Inc.
Other: SC Repair
Length Size
Proposed Pools:
L-80
TVD Burst
5,260'
MD
114'
2,384'
4,077'
114'
2,704'
16"
10 3/4"
78'
7 5/8"5,365'
2,671'
Packer: 4,710 MD / 3,902' TVD
Perforation Depth MD (ft):
5,399'
5,407' - 13,633'
4 1/2"
4,082' - 4,091'
SSSV: N/A
N1927@conocophillips.com
907-659-7506
Well Integrity Field Supervisor
11/20/2023
13,638'8,385'
4 1/2"
4,091'
SSSV: N/A
Packer: Baker Premier Packer
m
n
P
2
6
5
6
t
N
Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
Digitally signed by Brennen Green
DN: C=US, O=ConocoPhillips, CN=Brennen Green, E=n1927@
conocophillips.com
Reason: I am the author of this document
Location:
Date: 2023.07.11 08:40:48-08'00'
Foxit PDF Editor Version: 12.1.2
Brennen Green
By Grace Christianson at 11:03 am, Jul 11, 2023
323-384
VTL 11/1/2023
X
383
DSR-7/12/23SFD 9/19/2023
50-103-20579-00-00 SFD
X
Photo document all damage and repair
10-404
*&:
Brett W. Huber,
Sr.
Digitally signed by Brett W.
Huber, Sr.
Date: 2023.11.01 13:22:00 -08'00'11/01/23
RBDMS JSB 110223
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
July 11, 2023
Commissioner Jessie Chmielowski
Alaska Oil & Gas Commission
333 West 7th Avenue, Suite 100
Anchorage, AK 99501
Dear Commissioner Chmielowski,
Please find the enclosed 10-403 Application for Sundry Approval / renewal for
ConocoPhillips Alaska, Inc. well ALP CD2-467 (PTD 208-114) to repair the Surface
Casing.
Please contact Brennen Green or Roger Mouser at 659-7506 if you have any questions.
Sincerely,
Well Integrity Field Supervisor
ConocoPhillips Alaska, Inc.
Digitally signed by Brennen Green
DN: C=US, O=ConocoPhillips, CN=Brennen Green, E=
n1927@conocophillips.com
Reason: I am the author of this document
Location:
Date: 2023.07.11 08:40:25-08'00'
Foxit PDF Editor Version: 12.1.2
Brennen Green
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
ConocoPhillips Alaska, Inc.
ALPINE WELL CD2-467 (PTD 208-114)
SUNDRY NOTICE 10-403 APPROVAL REQUEST
July 11, 2023
This application for Sundry approval for Alpine well CD2-467 is for the inspection and repair of
surface casing with a suspected surface casing leak. Subsequent diagnostics indicate that the leak
is relatively shallow. ConocoPhillips requests approval to inspect and repair the surface casing.
With approval, inspection and repair of the surface casing will require the following general
steps:
1. Secure the well as needed with mechanical plug in the tubing.
2. Remove the floor grate, well house, flow lines, and other equipment as necessary from
around the wellhead.
3. Remove gravel around well head and excavate to ~24’.
4. Install nitrogen purge equipment for the conductor and OA (if needed) so that hot work may
be conducted in a safe manner.
5. Cut windows in the conductor casing and remove cement from the outside of the surface
casing for inspection. Remove additional conductor as necessary. Notify AOGCC Inspector
for opportunity to inspect.
6. CPAI Mechanical Engineers will determine type of patch or repair needed to return the
casing to operational integrity.
7. QA/QC will verify the repair for a final integrity check.
8. Perform a pressure test to confirm no fluid to surface.
9. Install anti-corrosion coating as specified by CPAI Corrosion Engineer.
10. Replace the conductor and fill the void with cement and top off with sealant.
11. Backfill as needed with gravel around the wellhead.
12. Remove plug(s) and return the well to Injection.
13. File 10-404 with the AOGCC post repair.
Last Tag
Annotation Depth (ftKB)Wellbore End Date Last Mod By
Last Tag:CD2-467 lmosbor
Last Rev Reason
Annotation Wellbore End Date Last Mod By
REV REASON: Prep for SCR CD2-467 12/12/2021 boehmbh
Notes: General & Safety
Annotation End Date Last Mod By
NOTE: FISH DROPPED INTO 7" CASING, UNABLE TO RETREIVE DUE TO DEVIATION 10/6/2014 lehallf
NOTE: VIEW SCHEMATIC w/9.0 8/10/2008 lmosbor
Casing Strings
Csg Des OD (in)ID (in)Top (ftKB)
Set Depth
(ftKB)
Set Depth
(TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread
CONDUCTOR1615.2536.0 114.0 114.062.50 H-40 Welded
SURFACE 10 3/49.9536.32,704.0 2,383.8 45.50 L-80 BTC-M
INTERMEDIATE 7 5/8 6.87 33.9 5,399.0 4,076.9 29.70 L-80 BTCM
LINER Slotted 4 1/2 3.96 5,253.2 13,638.0 4,091.2 12.60 L-80 SLHT
Tubing Strings: string max indicates LONGEST segment of string
Top (ftKB)
31.1
Set Depth …
5,260.0
Set Depth…
4,063.4
String Ma…
4 1/2
Tubing Description
TUBING
Wt (lb/ft)
12.60
Grade
L-80
Top Connection
IBT-M
ID (in)
3.96
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)
31.1 31.1 0.00 HANGER 11.000 FMC 4 1/2" Tubing Hanger FMC 3.970
2,696.5 2,378.038.60 NIPPLE 5.000 4 1/2" Camco "DB" Nipple (3.813"
ID)
CAMCO DB
Nipple
3.813
4,641.03,863.7 54.22 GAS LIFT 5.9844 1/2"Camco KGB2 GLM (3.833"
Drift ID") w/2500 psi SOV
CAMCO KBG-23.938
4,710.4 3,902.2 58.78 PACKER 6.580 4 1/2" X 7 5/8" Baker Premier
Packer
Baker Premier 3.870
4,769.33,930.962.75 NIPPLE 5.000 4 1/2" HES " XN" nipple w/ 3.725" ID HES XN
Nipple
3.725
5,238.7 4,061.183.65WLEG6.400 4 1/2",12.6#, IBT-Mod half mule
shoe w/WLEG and fluted No-Go
Baker WLEG3.940
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)
4,769.0 3,930.8 62.73 PLUG XXN PLUG W/ FILL EXT (OAL
55")
12/12/2021
5,400.0 4,077.0 85.74 FISH (Not in
Tubing)
DV DROPPED INTO 7"
CASING
10/6/2014
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)
4,641.03,863.7 54.22 1 GAS LIFT DMY BK 1 0.02/19/2016 0.000
Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°)Item Des
OD
Nominal
(in)Com Make Model
Nominal ID
(in)
5,253.2 4,062.7 83.93 SLEEVE 6.420 "HR" Liner Setting Sleeve 5.75" ID
(11.91' Inner Profile)
5.040
5,266.9 4,064.1 83.96 NIPPLE 6.080 "RS" Packoff Seal Nipple (4.875"
ID)
4.875
5,280.4 4,065.683.98 XO BUSHING6.040 XO Bushing - 5 1/2" BTC X 4 1/2"
SLHT (3.97" ID)
4.940
Perforations & Slots
Top (ftKB)Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB)Linked Zone Date
Shot
Dens
(shots/ft)Type Com
5,407.0 5,681.0 4,077.5 4,083.6 8/6/2008 32.0 SLOTS ALL PERFORATIONS =
Slots 1/8x2.25", 8 slots/row,
4 rows/ft; no slots 3' from
box/pin
5,763.0 8,673.0 4,082.0 4,086.4 8/6/2008 32.0 SLOTS
9,475.0 9,715.0 4,084.5 4,080.2 8/6/2008 32.0 SLOTS
10,035.0 10,316.0 4,081.3 4,082.6 8/6/2008 32.0 SLOTS
10,396.010,514.0 4,081.3 4,078.68/6/2008 32.0SLOTS
10,674.011,591.0 4,077.5 4,084.98/6/2008 32.0SLOTS
11,711.012,111.0 4,087.0 4,089.18/6/2008 32.0SLOTS
12,513.012,793.0 4,088.5 4,085.5 8/6/2008 32.0SLOTS
12,955.0 13,114.0 4,086.8 4,086.4 8/6/2008 32.0 SLOTS
13,273.0 13,633.0 4,086.9 4,091.1 8/6/2008 32.0 SLOTS
HORIZONTAL, CD2-467, 6/13/2023 2:50:03 PM
Vertical schematic (actual)
LINER Slotted; 5,253.2-13,638.0
SLOTS; 13,273.0-13,633.0
SLOTS; 12,955.0-13,114.0
SLOTS; 12,513.0-12,793.0
SLOTS; 11,711.0-12,111.0
SLOTS; 10,674.0-11,591.0
SLOTS; 10,396.0-10,514.0
SLOTS; 10,035.0-10,316.0
SLOTS; 9,475.0-9,715.0
SLOTS; 5,763.0-8,673.0
SLOTS; 5,407.0-5,681.0
FISH (Not in Tubing); 5,400.0
INTERMEDIATE; 33.9-5,399.0
PLUG; 4,769.0
PACKER; 4,710.4
GAS LIFT; 4,641.0
SURFACE; 36.3-2,704.0
NIPPLE; 2,696.5
CONDUCTOR; 36.0-114.0
WNS INJ
KB-Grd (ft)
44.51
RR Date
8/8/2008
Other Elev…
CD2-467
...
TD
Act Btm (ftKB)
13,836.0
Well Attributes
Field Name
QANNIK
Wellbore API/UWI
501032057900
Wellbore Status
INJ
Max Angle & MD
Incl (°)
91.78
MD (ftKB)
9,283.86
WELLNAME WELLBORE
Annotation
Last WO:
End DateH2S (ppm)DateComment
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321-587
Travis T. Smith Digitally signed by Travis T. Smith
Date: 2021.11.16 08:40:15 -09'00'
DSR-11/16/21SFD 11/17/2021
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dts 11/18/2021 JLC 11/18/2021
Jeremy
Price
Digitally signed by Jeremy Price
Date: 2021.11.18 10:42:56 -09'00'
RBDMS HEW 11/19/2021
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
13 November 2021
Commissioner Jessie Chmielowski
Alaska Oil & Gas Commission
333 West 7th Avenue, Suite 100
Anchorage, AK 99501
Dear Commissioner Chmielowski,
Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips
Alaska, Inc. well ALP CD2-467 (PTD 208-114) to pull a retrievable tubing patch to
secure the well for a surface casing.
Please contact me at 670-4014 if you have any questions.
Sincerely,
Travis Smith
WNS Intervention & Integrity Engineer
ConocoPhillips Alaska, Inc.
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
ConocoPhillips Alaska, Inc.
ALPINE WELL CD2-467 (PTD 208-114)
SUNDRY NOTICE 10-403 OVERVIEW
November 13, 2021
This application for Sundry approval for Alpine well CD2-467 is for pulling a retrievable tubing
patch in order to secure the well for a surface casing repair. Following the completion of the
surface casing repair work, a tubing patch will be re-set over the tubing leak. The surface casing
repair work is covered in a different 10-403 Sundry application (already submitted).
A verbal approval was sought and granted on November 13, 2021 by Victoria Loepp to begin the
work described below.
Procedure overview steps:
1. Pull retrievable tubing patch set at 349’ RKB.
2. Pull A-1 injection valve.
3. Secure well with downhole tubing plug to perform surface casing repair work.
4. Proceed with surface casing repair per 10-403 application filed separately. After surface
casing repair is completed:
5. Pull downhole tubing plug.
6. Re-set injection valve.
7. Re-set new retrievable tubing patch across tubing leak at approximately 355’ RKB.
8. File 10-404 with the AOGCC.
State witnessed MIT-IA required after stabilized injection
VTL 11/18/21
From:Carlisle, Samantha J (OGC)
To:Smith, Travis T
Cc:Loepp, Victoria T (OGC)
Subject:RE: CRU CD2-467 (PTD# 208-114) 10-403 Pull Patch
Date:Monday, November 15, 2021 7:45:32 AM
Please re-submit using the current form available on our website here
https://www.commerce.alaska.gov/web/aogcc/Forms.aspx. This will not be processed as
it.
From: Smith, Travis T <Travis.T.Smith@conocophillips.com>
Sent: Saturday, November 13, 2021 1:54 PM
To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov>
Cc: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>
Subject: CRU CD2-467 (PTD# 208-114) 10-403 Pull Patch
Hello—
Attached, please find a 10-403 form for CRU well CD2-467 (PTD#208-114). Let me know if you have
any questions.
Thanks,
Travis Smith
WNS Intervention & Integrity Engineer
907-670-4014
Travis.T.Smith@conocophillips.com
1
Smith, Travis T
From:Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>
Sent:Saturday, November 13, 2021 8:12 AM
To:Smith, Travis T
Cc:Rixse, Melvin G (CED)
Subject:[EXTERNAL]Re: CRU CD2-467 (PTD#208-114) Secure for SC Repair
Attachments:CD2-467.pdf
CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you
recognize the sender and know the content is safe.
Travis,
Verbal approval is granted to retrieve the tubing patch however please submit a 10-403 for this work today.
Thanx,
Victoria
Sent from my iPhone
On Nov 13, 2021, at 9:07 AM, Smith, Travis T <Travis.T.Smith@conocophillips.com> wrote:
Hello Victoria—
We have submitted a 10-403 for CRU injection well CD2-467 (PTD#208-114) to repair the surface casing
by excavation.
Yesterday we were doing preliminary work to secure the well and found that the A-1 injection valve was
not holding during a test. There is a shallow tubing patch at ~ 349’ RKB (above the A-1 injection,
schematic attached). In order to secure the tubing in the well (and eventually replace the A-1 injection
valve) we will need to pull the shallow tubing patch. We will re-set this patch at the end of the surface
casing work.
We have an opportunity to start pulling the patch and securing the well with slickline today. Could we
get approval to proceed with pulling the retrievable tubing patch as part of securing the well?
I’ve copied Mel here per your message to me.
Thank you very much!
Travis
Travis Smith
WNS Intervention & Integrity Engineer
907-670-4014
From:Smith, Travis T
To:Loepp, Victoria T (OGC)
Cc:Rixse, Melvin G (OGC)
Subject:CRU CD2-467 (PTD#208-114) Secure for SC Repair
Date:Saturday, November 13, 2021 8:07:04 AM
Attachments:CD2-467.pdf
Hello Victoria—
We have submitted a 10-403 for CRU injection well CD2-467 (PTD#208-114) to repair the surface
casing by excavation.
Yesterday we were doing preliminary work to secure the well and found that the A-1 injection valve
was not holding during a test. There is a shallow tubing patch at ~ 349’ RKB (above the A-1 injection,
schematic attached). In order to secure the tubing in the well (and eventually replace the A-1
injection valve) we will need to pull the shallow tubing patch. We will re-set this patch at the end of
the surface casing work.
We have an opportunity to start pulling the patch and securing the well with slickline today. Could
we get approval to proceed with pulling the retrievable tubing patch as part of securing the well?
I’ve copied Mel here per your message to me.
Thank you very much!
Travis
Travis Smith
WNS Intervention & Integrity Engineer
907-670-4014
Travis.T.Smith@conocophillips.com
INJ VALVE; 2,696.0
NIPPLE; 2,696.5
SURFACE; 36.3-2,704.0
GAS LIFT; 4,641.0
PACKER; 4,710.4
NIPPLE; 4,769.3
WLEG; 5,238.7
5,270.6
4,064.5
83.96
HANGER
Baker Flex Lock Liner f
5,280.4
4,065.6
83.98
XO BUSHING
XO Bushing - 5 1/2" BT
Tubing Strings
Tubing Description
TUBING
String Ma...
41/2
I ID (in)
3.958
Top (ftKB)
31.1
Set Depth (ft...
5,260.01
ISet Depth (TV[
4,0
Completion Details
Top (ftK6)
Top (TVD) (ftK6)
Top Incl {°)
Item Des
31.1
31.1
0.00
HANGER
FMC 4 1/2" Tubing Hanger
2,696.5
2,378.0
38.60
NIPPLE
4 1/2" Camco "DB" Nipple
4,710.4
3,902.2
58.78
PACKER
4 1/2" X 7 5/8" Baker Prem
4,769.3
3,930.9
62.75
NIPPLE
4 1/2" HES " XN" nipple w/
61 Deg.
5,238.7
4,061.1
83.65
WLEG
4 1/2",12.6#, IBT-Mod half
No -Go
Other In Hole
(Wireline retrievable plugs, valves, pumps, fish, etc.
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°)
Des
Com
349.0
349.0
0.94
PATCH
4.5" PARAGON II PACKER(ALPP450
LATCH SEAL ASSEMBLY(ALPAL00,
369.0
369.0
0.93
PATCH
Statewide lower retrievable paragon II
ALPP45003
2,696.0
2,377.6
38.60
INJ VALVE
A-1 INJECTION VALVE(SN; HSS -169
LOCK @ 2696'RKB
5,400.0
4,077.0
85.74
FISH (Not in
Tubing)
DV DROPPED INTO 7" CASING
1
Guhl, Meredith D (CED)
From:Wallace, Chris D (CED)
Sent:Tuesday, September 28, 2021 11:21 AM
To:AOGCC Records (CED sponsored)
Subject:FW: CRU CD2-467 (PTD# 208-114) Surface Casing Leak
From: Smith, Travis T <Travis.T.Smith@conocophillips.com>
Sent: Monday, September 27, 2021 4:40 PM
To: Wallace, Chris D (CED) <chris.wallace@alaska.gov>
Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>
Subject: CRU CD2‐467 (PTD# 208‐114) Surface Casing Leak
Chris—
Over the weekend, CRU Well CD2‐467 (PTD# 208‐114) was found with low pressure on the OA. DHD performed initial
diagnostics and found a leak at an approximate depth of 11’. The well was shut‐in and freeze protected and passed
additional diagnostics including wellhead packoff testing and an MITIA. We will evaluate repair plans for the well and
submit the appropriate Sundry paperwork as these are developed. In the meantime the well will remain shut‐in.
Please 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,June 11,2018
P.I.Supervisor ‘0,Ci 311 SUBJECT: Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA,INC.
CD2-467
FROM: Brian Bixby COLVILLE RIV QANN CD2-467
Petroleum Inspector
Src: Inspector
Reviewed By:
P.I.Supry JJ
NON-CONFIDENTIAL Comm
Well Name COLVILLE RIV QANN CD2-467 API Well Number 50-103-20579-00-00 Inspector Name: Brian Bixby
Permit Number: 208-114-0 Inspection Date: 6/6/2018
Insp Num: mitBDB180611054951
Rel Insp Num:
Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min
Well CD2-467 - 1Type Inj W `TVD 3902 Tubing 1571 ' 1575 " 1574- 1572
PTD
2081140 JType Test SPT Test psi 1500 - IA 260 2300 - 2240 2230 -
BBL Pumped: 1.9 BBL Returned: 1.6 OA 610 - 820 • 820 - 820 -
Interval4YRTST
TST P/F P
Notes:
SCANNED JUN 2 2 cu li;
Monday,June 11,2018 Page 1 of 1
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STATE OF ALASKA
AV OIL AND GAS CONSERVATION COM ISSION
REPORT OF SUNDRY WELL OPERATIONS
1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown fl
Performed: Suspend r Perforate r Other StimulateAlter Casing Change Approved Program
Rug for Redrill r Perforate New Pool fl Repair Well Re-enter Susp Well Other: 'P0' 3\tas _ N7''
tr7i pqf,.
2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill NumbeV.
ConocoPhillips Alaska, Inc. Development f' Exploratory r 208-1140
3.Address: 6.API Number:
P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic Service 50-103-20579-00
7.Property Designation(Lease Number): 8.Well Name and Number:
ADL0380075IADL0387207 CRU CD2-467
9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s):
Colville River Field/Qannik Oil Pool
11.Present Well Condition Summary:
Total Depth measured 13836 feet Plugs(measured) None
true vertical 4099 feet Junk(measured) None
Effective Depth measured 13,633' feet Packer(measured) 344, 369,4710
true vertical 4091' feet (true vertical) 344, 369, 3902
Casing Length Size MD TVD Burst Collapse
CONDUCTOR 78' 16 114' 114'
SURFACE 2668' 10 3/4 2704' 2384'
INTERMEDIATE 5365' 7 5/8 5399' 4077'
RECEIVED
Perforation depth: Measured depth: 5407'- 13,633'
5co�ED FEB 2,11€, JUL 1 201
True Vertical Depth: 4077'-4091'
AOGCC
Tubing(size,grade,MD,and TVD) 4 1/2 ,L-80, 5239 MD,4061 TVD
Packers&SSSV(type,MD,and TVD) NIPPLE=4 1/2"Camco"DB"Nipple (3.813"ID)@ 2697 MD and 2378 TVD
PATCH =4.5"PARAGON II PACKER(ALPP45004), 15'TBG, LATCH SEAL ASSEMBLY(ALPAL003) (OAL=
PATCH =STATEWIDE LOWER RETRIEVABLE PARAGON II PACKER ALPP45003 @ 369 MD and 369 T\
PACKER=4 1/2"X 7 5/8"BAKER PREMIER PACKER @ 4710 MD and 3902 TVD
12.Stimulation or cement squeeze summary:
Intervals treated(measured):
Treatment descriptions including volumes used and final pressure:
13. Representative Daily Average Production or Injection Data
Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure
Prior to well operation
Subsequent to operation
14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work:
Daily Report of Well Operations p Exploratory fl Development r Service 17 Stratigraphic r
Copies of Logs and Surveys Run 16.Well Status after work: Oil fl Gas r WDSPL r
Printed and Electronic Fracture Stimulation Data l GSTOR f WINJ I— WAG 17 GINJ E SUSP fl SPLUG fl
17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt:
316-239
Contact Jan Byrne/Dusty Freeborn Email: n1617(a�conocophillips.com
Printed Name Jan Byrne Title: Problem Wells Supervisor
Signature 0.,,. � . Phone:659-7126 Date: 7-7-16
vr1-- /O/b�`�' �„ l��l_ 1 1 2016
Form 10 404 Revised 5/2015 A f <`Ol� RBDMS Submit Original Only
• •
ConocoPhillips REC'EIVED
Alaska JUL 11 2016
P.O. BOX 100360
ANCHORAGE,ALASKA 99510-0360 OGC
C
July 7th, 2016
Ms. Cathy Foerster
Alaska Oil & Gas Commission
333 West'7th Avenue, Suite 100
Anchorage, AK 99501
Dear Commissioner Foerster,
Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips
Alaska, Inc. well CRU CD2-467 (PTD 208-114) for tubing patch repair.
Please call Dusty Freeborn or myself at 659-7126 or Brent Rogers/Kelly Lyons at 659-
7224 if you have any questions.
Sincerely,
Jan yrne
Problem Wells Supervisor
Attachments
•
CD2-467
DESCRIPTION OF WORK COMPLETED
SUMMARY
Date Event Summary
After locating a tubing leak at 355' on CD2-467 sundry#316-239 was approved and a 20' long
4.5" Paragon tubing patch was installed and tested. A state witnessed MITIA was completed
after the well was BOI and stabilized. The work performed is copied below.
4/27/2016
Received approved Sundry#316-239 for tubing patch repair.
6/18/2016
RUN 1: RIH with Statewide lower retrievable paragon II packer. Set ME at 369 FT (ELINE
Depth).
6/20/2016
SET PACKER TEST TOOL IN PARAGON PACKER @ 369'SLM. PERFORM PASSING
COMBO MIT. SET UPPER PACKER & PATCH(22.1') @ SAME. PERFORM PASSING MIT-IA.
JOB COMPLETE.
CMIT-TXIA
INITIAL-3012/3020/49
15 MIN-2940/2948/50
30 MIN-2919/2927/51
MIT-IA
INITIAL-695/3018/63
15 MIN-693/2899/63
30 MIN-693/2870/62
7/6/2016
(SW) STATE WITNESSED (Guy Cook) POST PATCH MITIA PASSED TO 2300 PSI
Initial T/I/O = 1557/790/374 IA FL @ NS
Pressured IA with 1.1 bbls diesel to TWO = 1558/2300/532
15 min T/I/O = 1556/2230/533 (-70 psi)
30 min T/I/O = 1556/2225/529 (-5 psi) LRS Bled back 1.3 bbls
Final T/I/O = 1556/625/360
0 0
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
Mechanical Integrity Test
Submit to: jim.reoaaalaska.gov AOGCC.InspectorstSalaska.00v phoebe.brooksc8alaska.dov chris.wallace(Ealaska.gov
OPERATOR: ConocoPhillips Alaska,Inc
FIELD/UNIT/PAD: Alpine/CRU/CD2 Pad
DATE: 07/06/16
OPERATOR REP: Byrne/Van Camp
AOGCC REP: Guy Cook
Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
Well CD2-467 Type Inj. W TVD 3,902' Tubing 1,557 1,558 1,556 1,556 Interval O
P.T.D. 2081140 Type test P Test psi 1500 Casing 790 2,300 2,230 2,225 P/F P
Notes: Post patch SW MITIA required per Sundry#316-239 OA 374 532 533 529
1.1 bbls diesel
Well Type lnj. TVD Tubing Interval
P.T.D. Type test Test psi Casing P/F
Notes: OA
Well Type Inj. TVD TubingInterval
P.T.D. Type test Test psi Casing P/F
Notes: OA
Well Type Inj. TVD Tubing Interval
P.T.D. Type test Test psi Casing P/F
Notes: OA
Well Type lnj. TVD Tubing Interval
P.T.D. Type test Test psi Casing P/F
Notes: OA
TYPE INJ Codes TYPE TEST Codes INTERVAL Codes
D=Drilling Waste M=Annulus Monitoring I=Initial Test
G=Gas P=Standard Pressure Test 4=Four Year Cycle
I=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Variance
N=Not Injecting A=Temperature Anomaly Survey 0=Other(describe in notes)
W=Water D=Differential Temperature Test
Form 10-426(Revised 11/2012) MIT CRU CD2-467 07-06-16.xls
ii WNS INJ • CD2-467
ConocoPhillips Well Attributes Max An.le&MD TD
Alaska,Inc Wellbore APNWOI Field Name Wellhore Statue linci(•) MD MKS) AM Elfin(NKR)
L:org4'fiPhMlps 501032057900 OANNIK INJ 91.78 9,283,86 13,836,0
-- J Comment KS(ppm) Dale Annotation End Date KB-Grd(ft) Rig Releeae Date
HORIZONTAL-002.407,62020162:40:04 PM SSSV:WRDP Last WO: 44.51 8/8/2008
Vertical schematic(actual)
Annotation Depth(ftKB) End Date Annotation Last Mod By End Date
Leet Tag: Rev Reason:SET PATCH pproven 6!20/2016
HANGER;31.1"-' it
Casing Strings
1 III
Cooing Deacrlptlon OD(In) ID(In) Top inks) Set Depth(ttKB) Set-Depth(TVD)...ZPtILen(I...Grade Top Thread
CONDUCTOR 16 15.250 36.0 114.0 114.0 62.50 11.40 Welded
L Casing Description OD(In) ID(In) Top(RKB) Set Depth(RKB) Set Depth(TVD)...WI/Len(I...Grade Top Thread
SURFACE 103/4 9.950 36.3 2,704.0 2,383.8 45.50 1-80 BTC-M
Casing Description OD(In) 10(in) Top(ttKB) Set Depth(ttKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread
CONDUCTOR;36.0-114.0 INTERMEDIATE 75/8 6.875 33.9 5,399.0 4,076,9 29.70 L-80 BTCM
Casing Description OD(In) ID(In) Top(ttKB) Set Depth(ttKB) Sat Depth(ND)...WtiLen(I...Grade Top Thread
PATCH:394.0 LINER Slotted 4 1/2 3.958 5,253.2 13.638.0 4,091.2 12.60 L-80 SLHT
(Liner Details
PATCH;369.0
Top(MB) Top(TVD)(ttKB) Top Ina/(•) Item Dee com NomIn) Ip
(In)
5,253.2 4,062.7 83.93 SLEEVE "HR"Liner Setting Sleeve 5.75"ID(11.91'Inner 5.040
Profile)
5,266.9 4,064.1 83.96 NIPPLE ' "RS"Packoff Seal Nipple(4.875"ID) 4.875
INJ VALVE:2,696.0 -35,270.6 4,064.5 83.96 HANGER Baker Flex Lock Liner Hanger(Drifted)/4.826') 4.960
NIPPLE;2,696.5 5,280.4 4,065.6 83.98 XO BUSHING XO Bushing-5 1/7'BTC X 4 1/7'SLHT(3.97"ID) 4.940
,f-r.
Tubing Strings
Tubing Description i String Ma...ID(In) Top(11KB) Set Depth(ft..Set Depth(IVO)(...)Wt(Ibift) IGreda !Top Connection
SURFACE:36.3-2,704.0 I - TUBING 41/2! 3.958! 31.11 5,260.0 4,063.41 12,601L-80 IBT-M
Completion Details
GAS LIFT;4.641.0III Top 111651 Top(TVD)(RKS) Top Leel(•) Item Dee Corn No(In'I ID
31.1 31.1 0.00 HANGER FMC 4 1/2"Tubing Hanger 3,970
2,696.5 2,378.0 38.60 NIPPLE 4 1/2"Cameo"DB"Nipple (3.813"ID) 3.813
II ' 4,710,4 3,902,2 58,78 PACKER 41/2"X75/8"Baker Premier Packer 3,870
PACKER;4,7104 -'' 4,769.3 3,930.9 62,75 NIPPLE 412"HES"XN"nipple w/3.725"ID,(W/RCH plug)@ 3.725
meg.
I 5,238.7 4,061.1 83.66 WLEG 4 1-2/2",,1 12.6H,IBT-Mod half mule shoe wANLEG and fluted
No-Go 3.940
NIPPLE;4,769.1a.
• Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.)
Top(TVD) Top 1501
WLEG;5.238) I Top(11681 I116B) (°) Dee Com Run Date 101(n)
344.0 344.0 0.92 PATCH 4.5"PARAGON II PACKER(ALPP45004),15'TBG, 6/19/2016 2.000
,� LATCH SEAL ASSEMBLY(ALPAL0O3)(OAL=22.1')
369.0 369.0 0.93 PATCH Statewide lower retrievable paragon II packer 6/182016 2.000
ALPP46003
-V"
2,696.0 2,377.6 38.60 INJ VALVE A-1 INJECTION VALVE(SN;HSS-169)ON 3,81"DB 22/2016 1.250
LOCK @ 269611169
5,400.0 4,077.0 85.74 FISH(Nat in DV DROPPED INTO 7"CASING 10/6/2014
Tubing)
Perforations&Slots
Shot
Dens
INTERMEDIATE;33.9-5,399.0 l Top(TVD) Btm(TVD) (e hotWf
Top(ttKB) atm(MEI)(MEI) MB) (11681 Zone Date 1) Type Corn -
FISH(Not in Tubing);5,400.0 5,407.0 5,681.0 4,077.5 4,083.6 8/6/2008 32.0 SLOTS ALL PERFORATIONS=
Slats 1/802.25",8 I
slots/row,4 rows/ft;no
SLOTS;5,407.0-5.681.0- - slots 3'from box/pin
5,763.0 8,673.0 4,082.0 4,086.4 8/6/2008 32.0 SLOTS
9,475.0 9,715.0 4,084.5 4,080.2 8/6/2008 32.0 SLOTS
10,035.0 10,318.0 4,081.3 4,082.6 8/612008 32.0 SLOTS
SLOTS 5,783.0-8,873.0---
,763.0.6,873.0 - - 10,396.0 10,514.0 4,081.3 4,078.6 8/6/2008 32.0 SLOTS
-- 10,674.0 11,691,0 4,077.5 4,084,9 8/6/2008 32.0 SLOTS
SLOTS:9.475.0.9,715.0
- - 11,711.0 12,111.0 4,087.0 4,089.1 8/6/2008 32.0 SLOTS
- - 12,513.0 12,793.0 4,088.5 4,085.5 8/6/2008 32.0 SLOTS
12,955.0 13,114.0 4,086.8 4,086.4 8/6/2008 32.0 SLOTS
SLOTS;to,o35.0.18,116.0 13,273.0 13,633.0 4,086.9 4,091,1 8/6/2008 32.0 SLOTS
- Mandrel Inserts
Sr
SLOTS;10,796.0.10.514.0 - - on l
N Top(7VD1 Valve Latch Pod Size TRO Run
Top(11KB) (11KB) Maks Model OD(In) Sere Type Type (In) (Fel) Run Date Corn
1 4,641.0 3,863.7 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 • 0.0 2/19/2016
- - Notes:General&Safety
SLOTS;10,674.0.4 1.591.0 -r - End Date Annotation
-1 - 8/10/2008 NOTE:VIEW SCHEMATIC w/9,0
- - 10/6/2014 NOTE:FISH DROPPED INTO 7"CASING,UNABLE TO RETREIVE DUE TO DEVIATION
SLOTS;11,711.0-12,111.0 - -
- -
STS;12,513.0-12,793.0
LA
I
SLOTS:12,955.0-13.114.0 1
- i-
SLOTS;13,273.0-13,633.0---.".
LINER Molted;5,253.2-13,838.0
• •
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
TO: / DATE: Monday,July 11,2016
Jim Regger �h��q Z/ifr. SUBJECT: Mechanical Integrity Tests
P.I.Supervisor l `
CONOCOPHILLIPS ALASKA INC
CD2-467
FROM: Guy Cook COLVILLE RIV QANN CD2-467
Petroleum Inspector
Src: Inspector
Reviewed By::7aa
P.I.Supry JR/L.--
NON-CONFIDENTIAL Comm
Well Name COLVILLE RIV QANN CD2-467 API Well Number 50-103-20579-00-00 Inspector Name: Guy Cook
Permit Number: 208-114-0 Inspection Date: 7/6/2016
Insp Num: mitGDC160707175803
Rel Insp Num:
Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min
Well I CD2-467 . Type Inj 7 W TVD 3902 " Tubing 1557 - 1558 " 1556 - 1556 -
PTD 2081140 - IType Test SPT Test psi 1500 ' IA 790 2300 . 2230 - 2225
Interval OTHER PAF' ,/`� OA 374 532 - 533 - 529
Notes: MITIA to confirm no more Tubing to IA communication after Conoco installed a retrievable patch in the tubing.
St, '' ;< NOV 2 2201
Monday,July 11,2016 Page 1 of 1
RECEIVED 2-12:1 44
JUN 0 8 2011
WELL LOG TRANSMITTAL
MDGC:13
To: Alaska Oil and Gas Conservation Comm. June 3, 2016
Attn.: Makana Bender
333 West 7th Avenue, Suite 100
DATA LOGGED
Anchorage, Alaska 99501 co ick/201Gi
.f K.BENDER
RE: Leak Detect Log with ACX: CD2-467
Run Date: 3/2/2016
The technical data listed below is being submitted herewith. Please address any problems or
concerns to the attention of:
Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518
CD2-467
Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom
50-103-20579-00
Leak Detect Log with ACX 1 Color Log
50-103-20579-00
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE
TRANSMITTAL LETTER TO THE ATTENTION OF:
Halliburton
Wireline &Perforating
Attn: Fanny Sari
6900 Arctic Blvd.
Anchorage, Alaska 99518 iC.ANNED j . ! 6 6 2j17,
Office: 907-275-2605
Fax: 907-273-3535
FRS_ANC@halliburton.com
Date: Signed: MAL.....47)
2-A- \,1
RECEIVED • • �-� t`�
MAY 0 6 2016
WELL LOG TRANSMITTAL#903186900
AOG C
To: Alaska Oil and Gas Conservation Comm. April 28, 2016
Attn.: Makana Bender
333 West 7th Avenue, Suite 100
Anchora e, Alaska 99501 DATA LOGGED
g 5n%i2o1cb
M.K.BENDER
RE: Multi-Finger Caliper: CD2-467
Run Date: 3/12/2016
The technical data listed below is being submitted herewith. Please address any problems or
concerns to the attention of:
Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518
CD2-467
Digital Data in LAS format, Digital Log Image file 1 CD Rom
50-103-20579-00
Multi-Finger Caliper 1 color log
50-103-20579-00 SCOW
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE
TRANSMITTAL LETTER TO THE ATTENTION OF:
Halliburton
Wireline &Perforating
Attn: Chris Gullett
6900 Arctic Blvd.
Anchorage, Alaska 99518
Office: 907-273-3527
Fax: 907-273-3535
FRS_ANC@halliburton.com
Date: Signe .e c.
i
•
yor�Ty� THE STATE
• :,.., �-,s,, Alaska Oil and Gas
641,.. -4-..-- :" .: 11 oALA�,`T!ZConservation Commission
\
�ftriti: � 333 West Seventh Avenue
-107.114.7 GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572
0 >>*h p. Main: 907.279.1433
ALAS Fax: 907.276.7542
www.aogcc.alaska.gov
Jan Byrne
NSK Problem Wells Supervisor
J, ,,
ConocoPhillips Alaska, Inc. 5CIAM°
P.O. Box 100360
Anchorage, AK 99510
Re: Colville River Field, Qannik Oil Pool, CRU CD2-467
Permit to Drill Number: 208-114
Sundry Number: 316-239
Dear Mr. Byrne:
Enclosed is the approved application for sundry approval relating to the above referenced well.
Please note the conditions of approval set out in the enclosed form.
As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further
time as the AOGCC grants for good cause shown, a person affected by it may file with the
AOGCC an application for reconsideration. A request for reconsideration is considered timely if
it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working
day if the 23rd day falls on a holiday or weekend.
Sincerely,
P ,,,,,,Z.-
Cathy . Foerster
Chair
DATED this 2b day of April, 2016.
RBDMS L L APR 29 2016
• STATE OF ALASKA r RECEIVED
. ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS APR 20 2016
20 AAC 25.280 97r5 412-404
1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Repair Well - AQGGS�hutdow n [—
Suspend
Suspend r Perforate r Other Stimulate r Pull Tubing r Change Approved Progranir
Rug for Redrill r Perforate New Pool r Re-enter Susp Well r Alter Casing r Ot er J gpa
1"
2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number:
ConocoPhillips Alaska, Inc. - Exploratory r Development r 208-1140 '
3.Address: Stratigraphic r Service 6.API Number:
P. O. Box 100360,Anchorage,Alaska 99510 50-103-20579-00 •
7.If perforating, 9,1111 8.Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool? itiA'
Will planned perforations require spacing exception? Yes r No (-7 CRU CD2-467'
9.Property Designation(Lease Number): 10.Field/Pool(s):
ADL03800751ADL0387207 Colville River Field/Qannik Oil Pool -
11. PRESENT WELL CONDITION SUMMARY
Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD):
13836 - 4099 . 13,633' • 4091'- 3000
Casing Length _ Size MD TVD Burst Collapse
CONDUCTOR 78' 16 114' 114'
SURFACE 2668' _ 10 3/4 2704' 2384' _
INTERMEDIATE 5365' 7 5/8 5399' 4077'
Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft):
5407'-13,633' - 4077'-4091' 4 1/2 L-80 5239
Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft)
NIPPLE=4 1/2"Camco"DB"Nipple (3.813"ID) MD=2697 TVD=2378 •
PACKER=4 1/2"X 7 5/8"BAKER PREMIER PACKER MD=4710 TVD=3902
12.Attachments: Proposal Summary ili WellBore Schematic r✓ 13. Well Class after proposed work:
Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service
14.Estimated Date for 15. Well Status after proposed work:
Commencing Operation 5/9/2016 OIL r WINJ WDSPL r Suspended r
16.Verbal Approval: Date: GAS r WAG r GSTOR r SPLUG r
Commission Representative: GINJ r Op Shutdow n r Abandoned r
17.I hereby certify that
the foregoing is true Contact: Jan Byrne/Dusty Freeborn
Printed Name Jan Byrne Phone:659-7126 Email: n1617(a�conocophillips.com
Title: NSK Problem Wells Supervisor
Signature �- 5 Date:4/18/16
Commission Use Only
Conditions of approval: Notify Commission so that a representative may witness Sundry Number: _
3 \ �
Rug Integrity r BOP Test r Mechanical-hIntegrity Test V Location Clearance r /
Other: ��7 t ',�/ f v!f!�SZ�1 .M / T—1/4" /"Q Gf Gr, 7 7`..0✓ ht k,I 1 cy�O'- i yV'.c 1/'z .
Post Initial Injection MIT Req'd? Yes7. No E (/ D
Spacing Exception Required? Yes r No 17' Subsequent Form Required: m _40/f RBDMS Lt- APR L 4 2013
pAPPROVED BY /Approved by: COMMISSIONER "`� THE COMMISSION Date: 4..-24, -[4
irri— 4/7 5// f� `ll�V'/l�' (J /��
//�/�/ Submit Form and
Form 10-403 Revised 11/2015 ofife+N.A
lid for 12 months from the date of approval. Attachments in Duplicate
• •
ConocoPhillips RECEIVED
Alaska APR 2 0 2016
P.O. BOX 100360
ANCHORAGE,ALASKA 99510-0360 AOGCC
April 18, 2016
Ms. Cathy Foerster
Alaska Oil & Gas Commission
333 West 7th Avenue, Suite 100
Anchorage, AK 99501
Dear Commissioner Foerster,
Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips
Alaska, Inc. CRU well CD2-467 (PTD 208-114). This request is for approval to install a
tubing patch for repair of tubing by inner annulus communication.
Please call Dusty Freeborn or myself at 659-7126 or Brent Rogers/Kelly Lyons at 659-
7224 if you have any questions.
Sincerely,
Jan me
Problem Wells Supervisor
Attachments
- WNS INJ CD2-467
ConocoPhilhps- Ai WNS
Well Attributes Max Angle&MD TD
Naska.Inc. Weilbore API/UWI Field Name Wetmore Status nd(°) MD(ftKB) Act Elm(ftKB)
• C ptyp, 501032057900 OANNIK INJ 91.78 9,283.86 18836.0
`
- Comment 1125(ppm) Date Annotation End Date K0-Grd(1t) Rig Release Date
HORIZONTAL-CD2-407,3/2800168'20'.51 AM SSSV:WRDP Last WO: 44.51 8/8/2008
•
Vertical schematic(actual) .
Annotation Depth(ftKB) End Date Annotation Last Mod By End Date
..._ ... .. .. ................ .. .._Last Tag: Rev Reason:FIXXED FISH DEPTH pproven 3/28/2016
a_e
HANGER:3E1
Casing Strings
v� L Geeing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread
/1 ,-. + CONDUCTOR 16 15.250 36.0 114.0 114.0 62.50 H-40 Welded
\ Casing Deuription OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WULen(I...Grade Top Thread
V .1.,, 41 y SURFACE 103/4 9.950 36.3 2,704.0 2,383.8 45.50 L-80 BTC-M
•` .'_,4004,Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth ITVD).,.Wt/Len(I...Grade Top Thread
CONDUCTOR;36.0-114.S INTERMEDIATE 75/8 6.875 33.9 5,399.0 4,076.9 29.70 L-80 BTCM
Casing Description OD(In) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread
LINER Slotted 4 1/2 3.958 5253.2 13,638.0 4,091.2 1260 L-80 SLHT
Liner Details
Nominal ID
NIPPLE:2,696 5 Top(ftKB) Top(TVD)(nKB) Top Incl(°) Item Des Com (In)
5,253.2 4,062.7 83.93 SLEEVE "HR"Liner Setting Sleeve 5.75"ID(11.91'Inner 5.040
Profile)
SURFACE:36.3-2,704.0 _ 5,266.9 4,064.1 83.96 NIPPLE '"RS"Packoff Seal Nipple(4.875"ID) ' 4.875
5,270.6' 4,064.5 83.96 HANGER Baker Flex Lock Liner Hanger(Drifted V 4.826') 4.960
5,280.4 4,065.6 83.98 XO BUSHING XO Bushing-51/7 ETC X41/2'SLHT(3.97"ID) 4.940
GAS LIFT:4,641.0 El Tubing Strings
Tubing Description String Ma...ID(In) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection
TUBING 41/2 3.958, 31.1 5,260.0 4,063.4 12.60 L-80 IBT-M
Completion Details
PACKER:4.7104 Nominal ID
Top(ftKB) Top(TVD}(ftKB) lop Incl(°) Item Des Com (In)
31.1 31.1 0.00 HANGER FMC 4 1/2"Tubing Hanger 3.970
7
2,696.5 2,378.0 38.60 NIPPLE 4 1/2"Camco"DB"Nipple (3.8171D) 3.813
NIPPLE;4,769.3 4,710.4 3,902.2 58.78 PACKER 4 1/2"X 75/7 Baker Premier Packer 3.870
4,769.3 3,930.9 62.75 NIPPLE 41/2"HES"XN"nipple w/3.725"ID,(W/RCH plug)@ 3.725
61 Deg.
WLEG;5.239.7 5,238.7 4,061.1 83.65 WLEG 41/7.12.68.IBT-Mod half mule shoe w/WLEG and fluted 3.940
L7A
No-Go
Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.)
Top(TVD) Top Incl
Top Mel (ftKB) 1°1 Des Com Run Date ID(in)
5,400.0 4.077.0 85.74 FISH(Not in DV DROPPED INTO 7'CASING 10/6/2014
Tubing)
Perforations&Slots
Shot
Dens
Top(TVD) Bent(TVD) (shots/f
Top(ftKB) Bun(ftKB) MKS) (ftKB) Zone Dale 1) Type Com
I 5,407.0 5.681.0 4,077.5 4,083.6 8/6/2008 32.0 SLOTS ALL PERFORATIONS=
Ill Slots 1/8x2.25",8
INTERMEDIATE;33.9-5,399.0 slots/row,4 rows/ft;no
slots Thorn box/pin
FISH(Not in Tubing);5,400.0 5,763.0 8,673.0 4,082.0 4,086.4 8/6/2008 32.0 SLOTS
9,475.0 9,715.0 4,084.5 4,080.2 8/6/2008 32.0 SLOTS
SLOTS 5.407.0-5,061.0 i 0
10,035.0 10.316.0 4,081.3 4,082.6 8/6/208 32.0 SLOTS
10,396.0 10,514.0 4,081.3 4,078.6 8/6/2008 32.0 SLOTS
10,674.0 11,591.0 4,077.5 4,084.9 8/6/2008 32.0 SLOTS
- -
11.711.0 12,111.0 4,087.0 4,089.1 8/6/2008 32.0 SLOTS
54,070-5.703.0-0,073.0 12,513.0 12,793.0 4,088.5 4,085.5 8/6/2008 32.0 SLOTS
12,955.0 13,114.0 4,086.8 4,086.4 8/6/2008 32.0 SLOTS
SLOTS:9,475.0.9.715.0 13,273.0 13,633.0 4,086.9 4,091.1 8/6/2008 32.0 SLOTS
Mandrel Inserts
- -
St
MI
on Top(TVD) Valve Latah Pon Sloe TRO Run
SLOTS;10.035.0-10.316.0 N. Top(ftKB) (nKB) Make Model ,OD(In) Sery Type Type (In) (psi) Run Date Corn
1 4,641.0 3,863.7 CAMCO KBG-2 1 GAS LIFT DMV BK 0.000 0.0 2/19/2016
Notes:General&Safety
End Date Annotation
-
SLOTS;10,398.0-10,514.0-- 8/10/2008 NOTE:VIEW SCHEMATIC w/9.0
10/6/2014 NOTE:FISH DROPPED INTO 7"CASING,UNABLE TO RETREIVE DUE TO DEVIATION
SLOTS:10,674.0-11,591.0= -
_
SLOTS 11,711.0-12.111.0
SLOTS;12,513.0-12,793.0
SLOTS;12,955.0-13.114.0 -
- -
SLOTS;13,273.0-13,633.0 -
LINER Slotted;5,2532-13,638.0
• CD2-467 •
DESCRIPTION SUMMARY
OF PROPOSAL
Proposal
CPAI seeks approval to install a tubing patch in CRU WINJ CD2-467 (PTD 208-114). A leak was found on
March 2, 2016 by an ACX log, which located the tubing leak at 355'. CPAI intends to install a 20', 4.5"
retrievable patch over the leak to return integrity to the tubing. Once the tubing patch has been installed an MIT-
IA will be performed to confirm that the patch has repaired the leak and returned integrity to the tubing.
Repair Plan
1. Set a 20'4.5" Statewide Oilfield Services retrievable patch over the tubing leak at 355'.
2. Perform an MIT-IA to confirm patch and tubing integrity.
3. Bring well on injection as per AIO 35.000.
4. Submit 10-404 post repair.
• •
Wallace, Chris D (DOA)
From: Wallace, Chris D (DOA)
Sent: Tuesday, January 19, 2016 9:12 AM
To: 'NSK Problem Well Supv'
Cc: Senden, R.Tyler
Subject: RE: CRU CD2-467 (PTD 208-114) Report of plan forward
Dusty,
20 AAC 25.265 (j) When required by a tubing workover, well intervention, or by routine well pad
or platform operations,
(1) the subsurface safety valve may be temporarily blocked or removed; however, the
subsurface safety valve must be made operable not later than 14 days after the date that the
well is returned to service, and be tested not later than five days after installation in accordance
with (h) of this section; and (2) the surface safety valve and the mechanical or electrical
detection device may be temporarily removed or defeated; however, unless otherwise
authorized by the commission, the well pad or platform must be continuously manned, or the
well must be shut-in, until the surface safety valve and mechanical or electrical detection device
are made operable; well pads, platforms, islands, or similar groups of wells are continuously
manned if sufficient responsible personnel are physically on-site and manually able to provide a
level of protection equivalent to the removed or defeated safety valve system equipment.
Approved to remove the SSSV for the duration of injection required to perform the leak detect log. Please note the
requirements and time restraints associated with the SSSV removal and return to service.
Thanks and Regards,
Chris Wallace
Sr. Petroleum Engineer
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue SCANNED JUN 0 2 2016
Anchorage,AK 99501
(907)793-1250(phone)
(907)276-7542(fax)
chris.wallace@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 Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov.
From: NSK Problem Well Supv [mailto:n1617@conocophillips.com]
Sent: Monday, January 18, 2016 7:59 PM
To: Wallace, Chris D (DOA)
Cc: Senden, R. Tyler; NSK Problem Well Supv
Subject: RE: CRU CD2-467 (PTD 208-114) Report of plan forward
Chris,
1
• •
CRU water injection well CD2-467 (PTD 208-114)was brought online for a 60 day water injection period in an attempt
activate a suspected IA leak. The leak has proven to be active and CPAI intends to perform a leak detect log as soon as
reasonably possible. Because the leak appears to be active only while the well is online it will be necessary to pull the A-
1 injection valve that is set at 2697'to allow access to the remainder of the well bore with the leak detecting tools. The
well will be returned to injection without a subsurface safety valve for logging purposes only and will be shut in when
the logging has been completed.
CPAI is seeking approval to have CD2-467 (PTD 208-114) on water injection without a subsurface safety valve installed to
allow access to the wellbore to perform a leak detect log. Please verify if approval is granted.
Attached are a current 90 day TIO plot and a well bore schematic.
Cheers,
Dusty Freeborn /Jan Byrne
Well Integrity Supervisor
ConocoPhillips Alaska, Inc.
Office phone: (907)659-7126
Cell phone: (907)943-0450
44,4WELLS TEAM
ConocoPhillips
From: NSK Problem Well Supv
Sent: Sunday, December 20, 2015 10:26 AM
To: Wallace, Chris D (DOA)
Cc: Senden, R. Tyler; NSK Problem Well Supv
Subject: CRU CD2-467 (PTD 208-114) Report of plan forward
Chris,
CRU water injection well CD2-467 (PTD 208-114) has been shut in since 10-27-14 due to IA pressurization that was
insufficient to be located with current technology at that time.
It is believed that present day leak detection tools now have the capabilities to locate the minimal pressure
communication if it still exists. CPAI intends to bring CD2-467 on water injection for a 60 day monitor period to
determine whether the pressure communication will reactivate. If so, diagnostics will be performed and the best suited
leak detection tools will be run in attempt to determine the leak point. Once the log is complete the well will be shut in
and freeze protected until a plan for repair has been formulated. Further correspondence with the AOGCC will be made
at that time. Attached is a 90 day TIO trend and wellbore schematic.
Please contact us if you disagree or have any questions with this plan.
Regards,
Jan Byrne/ Dusty Freeborn
Problem Wells Supervisor
ConocoPhillips Alaska, Inc.
Desk Phone (907) 659-7126
Pager(907) 659-7000 pgr. 123
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• •
Wallace, Chris D (DOA)
From: NSK Problem Well Supv <n1617@conocophillips.com>
Sent: Sunday, December 20, 2015 10:26 AM
To: Wallace, Chris D (DOA)
Cc: Senden, R.Tyler; NSK Problem Well Supv
Subject: CRU CD2-467 (PTD 208-114) Report of plan forward
Attachments: CD2-467 90 day TIO trend 12-20-15.JPG; CD2-467.pdf
Chris,
CRU water injection well CD2-467 (PTD 208-114) has been shut in since 10-27-14 due to IA pressurization that was
insufficient to be located with current technology at that time.
It is believed that present day leak detection tools now have the capabilities to locate the minimal pressure
communication if it still exists. CPAI intends to bring CD2-467 on water injection for a 60 day monitor period to
determine whether the pressure communication will reactivate. If so, diagnostics will be performed and the best suited
leak detection tools will be run in attempt to determine the leak point. Once the log is complete the well will be shut in
and freeze protected until a plan for repair has been formulated. Further correspondence with the AOGCC will be made
at that time. Attached is a 90 day TIO trend and wellbore schematic.
Please contact us if you disagree or have any questions with this plan.
Regards,
Jan Byrne/ Dusty Freeborn
p SEP 1 9 2016
Problem Wells Supervisor
ConocoPhillips Alaska, Inc.
Desk Phone (907) 659-7126
Pager(907) 659-7000 pgr. 123
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` WNS INJ • CD2-467
ConocoPhillips `7 Well Attributes Max Angle&MD TD
Alaska,Inc. Wenbore APVUWI Field Name Wellbore Status ncl(°) MD IRKS) Act Btm(ftKB)
,,,,,,,. II,I,,, 501032057900 QANNIK INJ 91.78 9,283.86 13,836.0
•- Comment H23(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date
HORIZONTAL-CD2-467,10/16/20149:14;46 AM SSSV:WRDP Last WO: 44.51 8/8/2008
Veracel schematic(actual) Annotation Depth(RKB) End Date Annotation Let Mod By End Date
Last Tag: Rev Reason:PULLED PLUG,SET VALVE lehallf 10/16/2014
HANGER;31.1 ' a IE
Casing Strings
Casing Description OD(In) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread
CONDUCTOR 16 15.250 36.0 114.0 114.0 62.50 H-40 Welded
Casing Description OD(in) ID(in) Top(RKB) Set Depth(RKB) Set Depth)TVD)...Wt/Len(I...Grade Top Thread
J4SURFACE 103/4 9.950 36.3 2,704.0 2,383.8 45.50 L-80 BTC-M
_ • _ _ _ _• Caning Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread
INTERMEDIATE 75/8 6.875 33.9 5,399.0 4,076.9 29.70 L-80 BTCM
CONDUCTOR;38.0-114.0- CasingDescription OD(in) ID in To RKB Set Depth(ftKB) Set Depth WtlLen(I...Grade TopThread
ption 1 1 P I ) pt l 1 p �I...
LINER Slotted 4 1/2 3.958 5,253.2 13,638.0 4,091.2 12.60 L-80 SLHT
Liner Details
Nominal ID
VALVE; ,888 5 _
NIPPLE;2,96.5 Top(RKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in)
5,253.2 4,062.7 83.93 SLEEVE "HR"Liner Setting Sleeve 5.75"ID(11.91'Inner 5.040
Profile)
SURFACE;363-2,7040 5,266.9 4,064.1 83.96 NIPPLE "RS"Packoff Seal Nipple(4.875"ID) 4.875
5,270.6 4,064.5 83.96 HANGER Baker Flex Lock Liner Hanger(Drifted U 4.826") 4.960
5,280.4 4,065.6 83.98 XO BUSHING XO Bushing-5 1/2"BTC X 4 1/2"SLHT(3.97"ID) 4.940
GAS LIFT;4.6a1.o 111, Tubing Strings
Tubing Description String Ma...ID(In) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Iblft) Grade Top Connection
TUBING 41/2 3.958 31.1 5,260.0 4,063.4 12.60 L-80 IBT-M
Completion Details
Nominal ID
PACKER;4,710.4 C e Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in)
31.1 31.1 0.00 HANGER FMC 4 1/2"Tubing Hanger 3.970
2,696.5 2,378.0 38.60 NIPPLE 4 1/2"Camco"DB"Nipple (3.813"ID) 3.813
NIPPLE,4,7693 - 4,710.4 3,902.2 58.78 PACKER 4 1/2"X 7 5/8"Baker Premier Packer 3.870
4,769.3 3,930.9 62.75 NIPPLE 41/2"HES"XN"nipple w/3.725"ID,(W/RCH plug)@ 3.725
FISH;5,2220 _ 61Deg.
5,238.7 4,061.1 83.65 WLEG 4 1/2",12.6#,IBT-Mod half mule shoe w/VVLEG and fluted 3.940
No-Go
WLEG;9,238.7 ' Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.)
Top(TVD) Top lel
II Top(ftKB) (ftKB) 1") o.*
Com Run Date ID(in)
2,696.5 2,378.0 38.60 VALVE A-1 INJECTION VALVE(HAAS-444) 10/15/2014 1.250
5,222.0 4,059.2' 83.13 FISH DV DROPPED INTO 7"CASING 10/6/2014
Perforations&Slots
Shot
Dens
Top(TVD) Btm(TVD) (ahots/f
Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com
5,407.0 5,681.0 4,077.5 4,083.6 8/6/2008 32.0 SLOTS ALL PERFORATIONS=
Slots 1/8x2.25",8
slots/row,4 rows/ft;no
slots 3'from box/pin
INTERMEDIATE;33.9-5,389.0 5,763.0 8,673.0 4,082.0 4,086.4 8/6/2008 32.0 SLOTS
_ _ 9,475.0 9,715.0 4,084.5 4,080.2 8/6/2008 32.0 SLOTS
SLOTS;5.407.0-5,881.0 I I10,035.0 10,316.0 4,081.3 4,082.6 8/6/2008 32.0 SLOTS
-( I_
10,396.0 10,514.0 4,081.3 4,078.6 8/6/2008 32.0 SLOTS
_ _ 10,674.0 11,591.0 4,077.5 4,084.9 8/6/2008 32.0 SLOTS
_ 11,711.0 12,111.0 4,087.0 4,089.1 8/6/2008 32.0 SLOTS
SLOTS;5,763.0-8,6730 _ I- 12,513.0 12,793.0 4,088.5 4,085.5 8/6/2008 32.0 SLOTS
_ _ 12,955.0 13,114.0 4,086.8 4,086.4 8/6/2008 32.0 SLOTS
SLOTS.3,475.0-9,715.0--. - 13,273.0 13,633.0 4,086.9 4,091.1 8/6/2008 32.0 SLOTS
-1 - Mandrel Inserts
St
all
{ on Top(TVD) Valve Latch Port Size TRO Run
SLOTS;10,035.0-10,316.0----._
1 - N Top(ftKB) (MB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com
1' 4,641.0 3,863.7 CAMCO 'KBG-2 1 GAS LIFT DMY 'BK 0.000 0.0"10/8/2014
Notes:General&Safety
-h
SLOTS;10,398.0-10,514.0 End Date Annotation
t I- 8/10/2008 NOTE:VIEW SCHEMATIC w/9.0
10/6/2014 NOTE:FISH DROPPED INTO 7"CASING,UNABLE TO RETREIVE DUE TO DEVIATION
SLOTS,10874.0-11,591.0 1
-I
-1 (-
SLOTS;11,711.0-12,111.0 I 11
1 i
I
SLOTS;12,513.0-12,793.0 -.I -
SLOTS;12,055.0-13,114.0
-I
SLOTS;13,273.0-13,633.0-. I I
LINER Slotted;5,253.2-13,638.0
• •
WELL LOG TRANSMITTAL
To: Alaska Oil and Gas Conservation Comm. July 27, 2011
Attn.: Howard Okland
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
RE: SpectraFlow Log / Water Flow Log: CD2 -467
Run Date: 7/12/2011
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
CD2 -467
Digital Data in DLIS format, Digital Log Image file I t4 3 7 1 1 CD Rom
50 -103- 20579 -00
SpectraFlow Log / Water Flow Log 1 Color Log
50 -103- 20579 -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: cf �- 11 Signed: Q
