Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout222-099DA
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7. Property Designation (Lease Number):
1. Operations
Performed:
2. Operator Name:
3. Address:
4. Well Class Before Work:5. Permit to Drill Number:
6. API Number:
8. Well Name and Number:
9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s):
Susp Well Insp
Install Whipstock
Mod Artificial Lift Perforate New Pool
Perforate
Plug Perforations
Coiled Tubing Ops
Other Stimulate
Fracture Stimulate
Alter Casing
Pull Tubing
Repair Well Other:
Change Approved Program
Operations shutdown
11. Present Well Condition Summary:
Casing Length Size MD TVD Burst Collapse
Exploratory
Stratigraphic
Development
Service
14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283)
16. Well Status after work:
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
OIL GAS
WINJ WAG GINJ
WDSPL
GSTOR Suspended SPLUG
Authorized Name and
Digital Signature with Date:
Authorized Title:
Contact Name:
Contact Email:
Contact Phone:
PBU W-06B
Extended Perf w CTU
Hilcorp North Slope, LLC
3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503
222-099
50-029-21822-02-00
15462
Surface
Intermediate
Liner
Liner
Liner
8987
2969
10744
2328
308
2521
15432
13-3/8"
9-5/8"
7"
4/1/2"
3-1/4" x 2-7/8"
8981
29 - 2998
28 - 10772
10599 - 12887
12679 - 12987
12941 - 15462
29 - 2692
28 - 7300
7179 - 8729
8534 - 8824
8780 - 8987
None
2260
4760
5410
7500
10530
None
5020
6870
7240
8430
8780
14630 - 15165
4-1/2" 12.6# L-80 25 - 12675
8830 - 8928
Conductor 80 20" 30 - 110 30 - 110
4-1/2" HES TNT Packer
12618, 8477
12470, 12618
8343, 8477
Torin Roschinger
Operations Manager
Tyson Shriver
tyson.shriver@hilcorp.com
907-564-4542
PRUDHOE BAY, Prudhoe Oil
Total Depth
Effective Depth
measured
true vertical
feet
feet
feet
feet
measured
true vertical
measured
measured
feet
feet
feet
feet
measured
true vertical
Plugs
Junk
Packer
Measured depth
True Vertical depth
feet
feet
Perforation depth
Tubing (size, grade, measured and true vertical depth)
Packers and SSSV
(type, measured and true vertical depth)
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure:
13a.Representative Daily Average Production or Injection Data
Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure
Prior to well operation:
Subsequent to operation:
15. Well Class after work:
Exploratory Development Service StratigraphicDaily Report of Well Operations
Copies of Logs and Surveys Run
Electronic Fracture Stimulation Data
Sundry Number or N/A if C.O. Exempt:
ADL 0028263, 0047452
25 - 8530
N/A
N/A
156
283
399
896
822
1698
1500
1450
320
320
324-197
13b. Pools active after work:Prudhoe Oil
4-1/2" Baker S3 Packer
12470, 8343
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
Sr Pet Eng: Sr Pet Geo:
Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov
Sr Res Eng:
Due Within 30 days of Operations
No SSSV Installed
By Grace Christianson at 3:53 pm, May 09, 2024
Digitally signed by Torin
Roschinger (4662)
DN: cn=Torin Roschinger (4662),
ou=Users
Date: 2024.05.08 12:25:03 -08'00'
Torin
Roschinger
(4662)
RBDMS JSB 051524
DSR-5/13/24
ACTIVITY DATE SUMMARY
4/29/2024
T/I/O=1800/1900/200 Temp=S/I (Assist Coil) Assist coil due to pump being down.
Pumped 5 bbls of 60/40 followed by 31 bbls of DSL down the backside of coil to
assist as needed. Pumped 32 bbls of DSL down the coil to assist as needed.
Released from job due to coil pump being fixed. Well left in control of coil upon
departure.
4/29/2024
LRS CTU #1, 1.5" Blue Coil
Objective: Extended Addperf
MIRU. Grease crew needed for valves. Function test BOPs. RIH w/ HES GR/CCL
(2.20" Carrier)/2.25"BDJSN (Max OD). LRS Tractor having mechanical issues, spot
in T-Bird pump truck while LRS tractor gets repaired. Bullhead 30bbls down backside
to check injectivity. Able to pump 5bpm and reduce WHP from 1700psi to 1200psi).
Continue RIH w/ logging tools. Drift to tag at 14929' and log up to 13185 before
pulling heavy. Yellow tie-in flag painted at 14550'. Jet with diesel down the coil and
able to pull back up above the liner, letting the diesel in the liner soak. Continue to
bleed IA before killing well. Bullhead 20 bbl spear of diesel followed by 1% KCl
w/SafeLube. Able to kill well at 4.5 bpm with stable final injectivity of 180 psi at 4.5
bpm. RIH to confirm drift of the liner after bullhead kill.
...Continued on WSR 4-30-24...
4/30/2024
LRS CTU #1, 1.5" Blue Coil, Objective: Adperf
Objective: Extended Addperf
RIH with drift/log BHA after bullhead kill and able to drift deeper to 15145 'CTMD. Due
to large change in weight and wellbore conditions re-log from 15145 up to 12900',
repainting the same tie-in flag. POOH maintaining hole fill above MCHF rate. Make
up Perf gun BHA with 150' of 2" Maxforce perf guns, 6 spf (122' loaded). RIH. Stop
at flag and correct depth to top shot. RIH and PU to put the guns on depth. Stop w/
top shot @ 14630'. Hold PJSM before launching ball. Launch ball and get good
indication of shots fired, POOH maintaining hole fill. Intervals perforated 14630'-
14690' and 14718' - 14780'. At surface. Hold PJSM. Confirm no flow and undeploy
guns, MCHF, confirm shots fired. FP well and begin rig down.
RDMO
...Job Complete...
Daily Report of Well Operations
PBU W-06B
7. If perforating:
1. Type of Request:
2. Operator Name:
3. Address:
4. Current Well Class:5. Permit to Drill Number:
6. API Number:
8. Well Name and Number:
9. Property Designation (Lease Number):10. Field:
Abandon
Suspend
Plug for Redrill Perforate New Pool
Perforate
Plug Perforations
Re-enter Susp Well
Other Stimulate
Fracture Stimulate
Alter Casing
Pull Tubing
Repair Well
Other:
Change Approved Program
Operations shutdown
What Regulation or Conservation Order governs well spacing in this pool?
Will perfs require a spacing exception due to property boundaries?Yes No
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD):
PRESENT WELL CONDITION SUMMARY
Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft):
Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft):
Casing Length Size MD TVD Burst Collapse
Exploratory
Stratigraphic
Development
Service
12. Attachments:
14. Estimated Date for
Commencing Operations:
13. Well Class after proposed work:
15. Well Status after proposed work:
16. Verbal Approval:
17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal.
Proposal Summary Wellbore schematic
BOP SketchDetailed Operations Program
OIL
GAS
WINJ
WAG
GINJ
WDSPL
GSTOR
Op Shutdown
Suspended
SPLUG
Abandoned
ServiceDevelopmentStratigraphicExploratory
Authorized Name and
Digital Signature with Date:
Authorized Title:
Contact Name:
Contact Email:
Contact Phone:
AOGCC USE ONLY
Commission Representative:
Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number:
Location ClearanceMechanical Integrity TestBOP TestPlug Integrity
Other Conditions of Approval:
Post Initial Injection MIT Req'd?Yes No
Subsequent Form Required:
Approved By:Date:
APPROVED BY
THE AOGCCCOMMISSIONER
PBU W-06B
Extended Perf w CTU
Hilcorp North Slope, LLC
3800 Centerpoint Dr, Suite 1400, Anchorage, AK
99503
222-099
50-029-21822-02-00
341J
ADL 0028263, 0047452
15462
Surface
Intermediate
Liner
Liner
Liner
8987
2969
10744
2328
308
2521
15432
13-3/8"
9-5/8"
7"
4/1/2"
3-1/4" x 2-7/8"
8981
29 - 2998
28 - 10772
10599 - 12887
12679 - 12987
12941 - 15462
2520
29 - 2692
28 - 7300
7179 - 8729
8534 - 8824
8780 - 8987
None
2260
4760
5410
7500
10530
None
5020
6870
7240
8430
8780
14790 - 15165 4-1/2" 12.6# L-80 25 - 126758853 - 8928
Conductor 80 20" 30 - 110 30 - 110
4-1/2" HES TNT Packer
4-1/2" Baker S3 Packer
12470, 8343
12618, 8477
Date:
Torin Roschinger
Operations Manager
Tyson Shriver
tyson.shriver@hilcorp.com
907-564-4542
PRUDHOE BAY
5/1/2024
Current Pools:
PRUDHOE OIL
Proposed Pools:
PRUDHOE OIL
Suspension Expiration Date:
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng
Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov
No SSSV Installed
Digitally signed by Torin
Roschinger (4662)
DN: cn=Torin Roschinger (4662),
ou=Users
Date: 2024.04.03 14:38:26 -08'00'
Torin
Roschinger
(4662)
By Grace Christianson at 3:50 pm, Apr 03, 2024
324-197
Perforate
10-404
SFD 4/10/2024MGR05APR24 DSR-4/12/24JLC 4/12/2024
Brett W.
Huber, Sr.
Digitally signed by Brett
W. Huber, Sr.
Date: 2024.04.12
15:35:29 -08'00'04/12/24
RBDMS JSB 041624
Extended Add Perf
W-06B
PTD:222-099
Well Name:W-06B API Number:50-029-21822-02
Current Status:Operable – PAL Rig:CTU
Estimated Start Date:5/1/2024 Estimated Duration:2day
Reg.Approval Req’std?10-403 Date Reg. Approval Rec’vd:
Regulatory Contact:Abbie Barker Permit to Drill Number:222-099
First Call Engineer:Tyson Shriver (907) 564-4542 (O)(406) 690-6385 (M)
Second Call Engineer:Aras Worthington (907) 564-4763 (O)(907) 440-7692 (M)
Current Bottom Hole Pressure:3,350 psi @ 8,800’ TVD (Based on Offset well data)
Maximum Expected BHP:3,400 psi @ 8,800’ TVD (Based on Offset well data)
Max. Anticipated Surface Pressure:2,520 psi (Based on 0.1 psi/ft gas gradient)
Last SI WHP:960 psi (Taken on 1/4/2023)
Kill Weight Fluid:7.43 ppg
Min ID:2.313” X-Nipple 12,943’ MD
Max Angle:101 Deg @ 13,571’ MD
Tie-in Log:
Brief Well Summary:
W-06B is a recently drilled Ivishak Z4 CTD sidetrack (10/2022) that was completed with 175’ of perforations in
the toe. The well initially came on at 1,239 bpd (8.5% WC) gross fluid but rates but quickly declined to 560 bpd
(22% WC). In January 2023 coil performed an RPM log and perforated an additional 200’ of Z4. The perforations
seemed to only add water but over a month the well cleaned up and was producing 1445 bpd (55% WC).
Production rates have again declined with the latest test showing 945 bpd (73% WC, 1.6k FGOR). There is still
Z4 footage left to exploit so another 122’ of perforations is being proposed.
Objective:Shoot 122’ of extended add perfs in Z4
Procedure:
Coiled Tubing
1. MU GR/CCL with ~2.25” JSN drift (Min ID through LTP is 2.31” X-nipple, max swell on 2” perf guns is
~2.23”). RIH to 15,200’ MD, past deepest perforation, to ensure liner is clear. If debris is encountered in
the liner, attempt to jet through fill.
a. Well has had a history of paraffin build up in the tubing and liner/perforations. Previous coil
intervention in January 2023 experienced poor injectivity initially and tagged near the bottom
of the toe perf interval on the drift run. A hot diesel wash of the perforations seemed to clear
things up. Tools still came back coated with a “thick tar” like substance. The subsequent
perforating run (200’ of 2” guns) did not experience any issues passing through the tubing
patch or top of liner.
2. PUH above top perforation and circulate HOT diesel down CT. Close CTBS when diesel is at nozzle and
RIH to 15,200’ MD jetting across perforations.
3. SD and let diesel soak for 30 minutes.
4. Check injectivity to ensure an adequate bullhead kill can be achieved. If not, KWF will need to be
circulated in prior to extended perforating run.
5. Pull tie-in log from 15,200’ MD up past top of liner to ~12,900’ MD. Flag pipe for subsequent extended
perforating run.
6. POOH. Correlate with READ Memory RBC Log, Dated 06-Jan-2023 (see attached annotated log). Correct
flag and send to Geo, Joe Syzdek (joseph.syzdek@hilcorp.com), and OE.
Extended Add Perf
W-06B
PTD:222-099
Coil – Extended Perforating
Notes:
x Remote gas monitoring for H2S and LELs are required for Open Hole Deployment Operations
x Due to the necessary open hole deployment of Extended Perforating jobs, 24-hour crew and WSS
coverage is required.
The well will be killed and monitored before making up the perf guns. This is generally done during the
drift/logging run. This will provide guidance as to whether the well will be killed by bullheading or circulating
bottoms up throughout the job. If pressure is seen immediately after perforating, it will either be killed by
bullheading while POOH or circulating bottoms up through the same port that opened to shear the firing head.
7. After MU MHA and pull testing the CTC, tag-up on the CT stripper to ensure BHA cannot pull through
the brass upon POOH with guns.
8. Bullhead 1.5X wellbore volume - 319 bbls 1% KCL/SW down tubing. Max tubing pressure 2500 psi.
(This step can be performed any time prior to open-hole deployment of the perf guns. Timing of the
well kill is at the discretion of the WSS.)
a. Wellbore volume to PBTD = 213 bbls
b. 4-1/2” Tubing – 12,934’ X .0152 bpf = 197 bbls
c. 3-1/4” Liner – 491’ X 0.0079 bpf = 4 bbls
d. 2-7/8” Liner – 2,007’ X .0058 bpf = 12 bbls
9. At surface, prepare for deployment of TCP guns.
10. Confirm well is dead. Bleed any pressure off to return tank. Kill well w/ KWF as needed. Maintain
hole fill taking returns to tank until lubricator connection is re-established. Fluids man-watch must
be performed while deploying perf guns to ensure the well remains killed and there is no excess flow.
11. Perform drill by picking up safety joint with TIW valve and space out before MU guns. Review well
control steps with crew prior to breaking lubricator connection and commencing makeup of TCP gun
string. Once the safety joint and TIW valve have been spaced out, keep the safety joint/TIW valve
readily accessible near the working platform for quick deployment if necessary.
a. At the beginning of each job, the crossover/safety joint must be physically MU to the perf guns
one time to confirm the threads are compatible.
12.Break lubricator connection at QTS and begin makeup of TCP guns per schedule below. Constantly
monitor fluid rates pumped in and fluid returns out of the well. Fluids man-watch must be performed
while deploying perf guns to ensure the well remains killed and there is no excess flow.
Perf Schedule
Use 2” Maxforce guns or similar
Perf Interval Perf Length Gun Length Weight of Gun
(lbs)
Run #1
14,630’ - 14,690’
14,718’ - 14,780’
122’ 150’ 840 lbs (5.6 ppf)
13. Make up QTS and PT same.
14. RIH with perf gun and tie-in to coil flag correlation. Pickup and perforate interval per Perf Schedule
above.
b. Note any tubing pressure change in WSR.
Extended Add Perf
W-06B
PTD:222-099
15. After perforating, PUH to top of liner or into tubing tail to ensure debris doesn’t fall in on the guns and
stick the BHA. Confirm well is dead and re-kill if necessary before pulling to surface.
16. Pump pipe displacement while POOH. Stop at surface to reconfirm well is dead. Kill well if necessary.
17. Review well control steps and Standing Orders with crew prior to breaking lubricator connection and
commencing breakdown of TCP gun string.
18. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA.
19. RDMO CTU.
20. Turn well over to Operations POP.
Attachments:
x Wellbore Schematic
x Proposed Schematic
x Tie-In Log
x BOPE Schematic
x Standing Orders
x Equipment Layout
x Sundry Change Form
Extended Add Perf
W-06B
PTD:222-099
Current Wellbore Schematic
Extended Add Perf
W-06B
PTD:222-099
Proposed Wellbore Schematic
Extended Add Perf
W-06B
PTD:222-099
Tie-In Log
Extended Add Perf
W-06B
PTD:222-099
Add Perforations:
14,630’ - 14,690’
14,718’ - 14,780’
Extended Add Perf
W-06B
PTD:222-099
BOP Schematic
Extended Add Perf
W-06B
PTD:222-099
Extended Add Perf
W-06B
PTD:222-099
Extended Add Perf
W-06B
PTD:222-099
Changes to Approved Sundry Procedure
Date:
Subject:
Sundry #:
Any modifications to an approved sundry will be documented and approved below. Changes to an
approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written
approval of the change is required before implementing the change.
Step Page Date Procedure Change
HNS
Prepared
By
(Initials)
HNS
Approved
By
(Initials)
AOGCC
Written
Approval
Received
(Person and
Date)
Approval:
Operations Manager Date
Prepared:
Operations Engineer Date
7. Property Designation (Lease Number):
1. Operations
Performed:
2. Operator Name:
3. Address:
4. Well Class Before Work:5. Permit to Drill Number:
6. API Number:
8. Well Name and Number:
9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s):
Susp Well Insp
Install Whipstock
Mod Artificial Lift Perforate New Pool
Perforate
Plug Perforations
Coiled Tubing Ops
Other Stimulate
Fracture Stimulate
Alter Casing
Pull Tubing
Repair Well Other:
Change Approved Program
Operations shutdown
11. Present Well Condition Summary:
Casing Length Size MD TVD Burst Collapse
Exploratory
Stratigraphic
Development
Service
14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283)
16. Well Status after work:
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
OIL GAS
WINJ WAG GINJ
WDSPL
GSTOR Suspended SPLUG
Authorized Name and
Digital Signature with Date:
Authorized Title:
Contact Name:
Contact Email:
Contact Phone:
PBU W-06B
Extended Perf w CTU
Hilcorp North Slope, LLC
3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503
222-099
50-029-21822-02-00
15462
Surface
Intermediate
Liner
Liner
Liner
8987
2969
10744
2328
308
2521
15432
13-3/8"
9-5/8"
7"
4-1/2"
3-1/4" x 2-7/8"
8981
29 - 2998
28 - 10772
10599 - 12887
12679 - 12987
12941 - 15462
29 - 2692
28 - 7300
7179 - 8729
8534 - 8824
8780 - 8987
None
2260
4760
5410
7500
10530
None
5020
6870
7240
8430
10160
14790 - 15165
4-1/2" 12.6# L-80 25 - 12675
8853 - 8928
Conductor 80 20" 30 - 110 30 - 110
4-1/2" HES TNT Packer 12470, 8343
12470, 12618
8343, 8477
Stan Golis
Sr. Area Operations Manager
Josh Stephens
Josh.Stephens@hilcorp.com
970.779.1200
PRUDHOE BAY, PRUDHOE OIL
Total Depth
Effective Depth
measured
true vertical
feet
feet
feet
feet
measured
true vertical
measured
measured
feet
feet
feet
feet
measured
true vertical
Plugs
Junk
Packer
Measured depth
True Vertical depth
feet
feet
Perforation depth
Tubing (size, grade, measured and true vertical depth)
Packers and SSSV
(type, measured and true vertical depth)
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure:
13a.Representative Daily Average Production or Injection Data
Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure
Prior to well operation:
Subsequent to operation:
15. Well Class after work:
Exploratory Development Service StratigraphicDaily Report of Well Operations
Copies of Logs and Surveys Run
Electronic Fracture Stimulation Data
Sundry Number or N/A if C.O. Exempt:
ADL 0028263, 0047452
25 - 8530
N/A
N/A
434
591
394
1919
126
1708
986
1203
278
287
322-639
13b. Pools active after work:PRUDHOE OIL
4-1/2" Baker S3 Packer 12618, 8477
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
Sr Pet Eng: Sr Pet Geo:
Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov
Sr Res Eng:
Due Within 30 days of Operations
No SSSV Installed
to the best of my knowl
January 18, 2023
By Samantha Carlisle at 1:32 pm, Jan 18, 2023
RBDMS JSB 012623
DSR-1/18/23
Extended Perf w CTUil d biCoiled Tubing Ops
222-099
Sundry Number
PBU W-06B
Perforate
PRUDHOE BAY, PRUDHOE OIL
322-639
WCB 11-2-2023
ACTIVITY DATE SUMMARY
1/4/2023
CTU#9 1.75" Coil Tubing - Job Scope: Drift/Tag, RPM log, SCMT log, contingent Ext
Adperf
MIRU CTU#9. Freeze protect flow line. MU BOT MHA and drift BHA and RIH.
*** Job Continued on 1/5/23***
1/5/2023 Weather Standby
1/5/2023
** ASSIST CTU ** Pumped 90 bbls 160* diesel down coil. taking returns to OTT. Coil
still on well at time of departure.
1/5/2023
CTU#9 1.75" Coil Tubing - Job Scope: Drift/Tag, RPM log, SCMT log, contingent Ext
Adperf
RIH with BOT CTC/MHA and SLB drift BHA. Pump 1% slick KCL to load well/help
with friction. Well not taking fluid easily. Tag at 15165'. Call and discuss with OE.
Perform hot diesel wash @ 160 degrees across the perfs. Improved injectivity, 1
bbl/m @ 1367 psi. Flag coil 15,110' ctmd. POOH. MU BOT RPM logging tools. RIH.
Stop at flag depth 15119 e/15142 m. Wait for tools to power up then POOH at 20'/min
logging to 12800'.
*** Job Continued on 1/6/23***
1/6/2023
CTU#9 1.75" Coil Tubing (.156 wall) Job Scope: Drift/Tag, RPM log, SCMT log, Ext
Adperf
Continue RPM log. Complete 1st pass from 15110' -12800'. RBIH. PUH and log 2nd
pass to 12800'. POOH. Good data at surface. MU BOT CTC and MHA with READ
gamma/ccl and CBL tool. RIH. RIH 50' past flag. Start CBL log from 15073' CTM
and log to 12800'.
***Job Contnued on 1/7/23***
1/7/2023
CTU#9 1.75" Coil Tubing (.156 wall) Job Scope: Drfit/tag, RPM log, SCMT log, Ext
Adperf
Continue SCMT log. POOH and check data. Confirm perf depths and lengths with
GEO. +62 correction. Confirm no-flow. Pump across top and deploy 200' of HES 2"
Millenium guns. RIH.
*** Job continued 1-8-23***
1/8/2023
CTU#9 1.75" Coil Tubing (.156 wall) Job Scope: Drfit/tag, RPM log, SCMT log, Ext
Adperf
Continue RIH with 200' of HES 2" Millenium guns. Correct depth to top shot at the
flag. RIH/PU and perforate from 14790-14990' MD. POOH. Freeze protect the well.
RDMO.
*** Job Complete***
Daily Report of Well Operations
PBU W-06B
Pump across top and deploy 200' of HES 2"
Millenium guns. RIH.
Flag coil 15,110' ctmd. POOH. MU BOT RPM logging tools. RIH. @
Stop at flag depth
Continue SCMT log. POOH and check data. Confirm perf depths and lengths withgg
GEO. +62 correction.
RIH with BOT CTC/MHA and SLB drift BHA. Pump 1% slick KCL to load well/help
with friction. Well not taking fluid easily. Tag at 15165'.
The new 200' of perfs are shown correctly on the new WBS, below. -WCB
MU BOT CTC and MHA with READ
gamma/ccl and CBL tool. RIH. RIH 50' past flag. Start CBL log from 15073' CTMg
and log to 12800'.
Scope: Drift/Tag, RPM log, SCMT log, contingent Ext
Adperf
Continue RIH with 200' of HES 2" Millenium guns. Correct depth to top shot at theg
flag. RIH/PU and perforate from 14790-14990' MD. POOH.
Continue RPM log. Complete 1st pass from 15110' -12800'. RBIH. PUH and log 2nd gg
pass to 12800'. POOH. Good data at surface
Perform hot diesel wash @ 160 degrees across the perfs. Improved injectivity@gjy
gyg
Kyle Wiseman Hilcorp Alaska, LLC
Geo Tech 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: (907) 564-4558
E-mail: Kyle.Wiseman@hilcorp.com
Please acknowledge receipt by signing and returning one copy of this transmittal.
Received By: Date:
Date: 01/23/2023
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
SFTP DATA TRANSMITTAL T#20230123
Well API #PTD #Log Date Log
Company Log Type AOGCC
Eset#
END 1-09A 50029217430100 197029 1/15/2023 HALLIBURTON MFC40
END 1-09A 50029217430100 197029 1/16/2023 HALLIBURTON MFC40
MPU C-41 50029230140000 201078 1/16/2023 HALLIBURTON COILFLAG
PBU W-06B 50029218220200 222099 1/6/2023 BAKER MRPM
Please include current contact information if different from above.
By Meredith Guhl at 7:48 am, Jan 24, 2023
T37460
T37460
T37461
T37462PBU W-06B 50029218220200 222099 1/6/2023 BAKER MRPM
Meredith Guhl Digitally signed by Meredith Guhl
Date: 2023.01.24 07:55:44 -09'00'
Kyle Wiseman Hilcorp Alaska, LLC
Geotechnician 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: (907) 564-4558
E-mail: Kyle.Wiseman@hilcorp.com
Please acknowledge receipt by signing and returning one copy of this transmittal.
Received By: Date:
Date: 01/10/2023
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
SFTP DATA TRANSMITTAL T#20230110
Well API #PTD #Log Date Log Company Log Type AOGCC Eset#
PBU E-102 50029230420000 201186 1/1/2023 READ MemoryCementBondLog
PBU W-06B 50029218220200 222099 1/6/2023 READ MemoryRadialCementBondLog
Please include current contact information if different from above.
By Meredith Guhl at 11:54 am, Jan 10, 2023
T37430
T37431PBU W-06B 50029218220200 222099 1/6/2023 READ MemoryRadialCementBondLog
Meredith Guhl Digitally signed by Meredith Guhl
Date: 2023.01.10 11:58:07 -09'00'
7. Property Designation (Lease Number):
1. Operations
Performed:
2. Operator Name:
3. Address:
4. Well Class Before Work:5. Permit to Drill Number:
6. API Number:
8. Well Name and Number:
9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s):
Susp Well Insp
Install Whipstock
Mod Artificial Lift Perforate New Pool
Perforate
Plug Perforations
Coiled Tubing Ops
Other Stimulate
Fracture Stimulate
Alter Casing
Pull Tubing
Repair Well Other:
Change Approved Program
Operations shutdown
11. Present Well Condition Summary:
Casing Length Size MD TVD Burst Collapse
Exploratory
Stratigraphic
Development
Service
14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283)
16. Well Status after work:
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
OIL GAS
WINJ WAG GINJ
WDSPL
GSTOR Suspended SPLUG
Authorized Name and
Digital Signature with Date:
Authorized Title:
Contact Name:
Contact Email:
Contact Phone:
PBU W-06B
Patch Tubing
Hilcorp North Slope, LLC
3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503
222-099
50-029-21822-02-00
15462
Surface
Intermediate
Liner
Liner
Liner
8987
2969
10744
2328
308
2521
15432
13-3/8"
9-5/8"
7"
4-1/2"
3-1/4" x 2-7/8"
8981
29 - 2998
28 - 10772
10599 - 12887
12679 - 12987
12941 - 15462
29 - 2692
28 - 7300
7179 - 8729
8534 - 8824
8780 - 8987
None
2260
4760
5410
7500
10530
None
5020
6870
7240
8430
10160
14990 - 15165
4-1/2" 12.6# L-80 25 - 12675
8895 - 8928
Conductor 80 20" 30 - 110 30 - 110
4-1/2" HES TNT Packer 12470, 8343
12470, 12618
8343, 8477
Stan Golis
Sr. Area Operations Manager
Wyatt Rivard
wrivard@hilcorp.com
907.777.8547
PRUDHOE BAY, PRUDHOE OIL
Total Depth
Effective Depth
measured
true vertical
feet
feet
feet
feet
measured
true vertical
measured
measured
feet
feet
feet
feet
measured
true vertical
Plugs
Junk
Packer
Measured depth
True Vertical depth
feet
feet
Perforation depth
Tubing (size, grade, measured and true vertical depth)
Packers and SSSV
(type, measured and true vertical depth)
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure:
13a.Representative Daily Average Production or Injection Data
Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure
Prior to well operation:
Subsequent to operation:
15. Well Class after work:
Exploratory Development Service StratigraphicDaily Report of Well Operations
Copies of Logs and Surveys Run
Electronic Fracture Stimulation Data
Sundry Number or N/A if C.O. Exempt:
ADL 0028263, 0047452
25 - 8530
N/A
N/A
1134
187
1932
236
105
30
1167
1295
277
283
N/A
13b. Pools active after work:PRUDHOE OIL
4-1/2" Baker S3 Packer 12618, 8477
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
Sr Pet Eng: Sr Pet Geo:
Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov
Sr Res Eng:
Due Within 30 days of Operations
By Anne Prysunka at 9:30 am, Dec 19, 2022
Digitally signed by Stan Golis
(880)
DN: cn=Stan Golis (880),
ou=Users
Date: 2022.12.16 17:06:17 -09'00'
Stan Golis
(880)
DSR-1/3/23WCB 11-26-2024
RBDMS JSB 122322
ACTIVITY DATE SUMMARY
11/16/2022
***WELL FLOWING ON ARRIVAL***
RAN 30' DRIFT FOR ELINE, DRIFTED FREELY TO 8,500' SLM (MAX OD = 3.68")
***JOB COMPLETE, WELL S/I ON DEPARTURE, PAD-0P NOTIFIED.***
11/17/2022
T/I/O = 280/380/40. Temp = 44°. IA FL (Ops request). ALP = 380 psi. IA FL @
8989' (Sta#4, SO).
SV = C. WV, SSV, MV = O. IA, OA = OTG. 11:15
11/19/2022
***WELL FLOWING ON ARRIVAL***
SET 4-1/2" X-CATCHER IN X NIP @ 12442' SLM.
BRUSH AND FLUSH TUBING TO STA#2 @ 11323' SLM W/ LRS PUMPING HOT
DIESEL (180bbls total).
ATTEMPT TO PULL STA# 2 @ 11323' MD
***CONT, WSR ON 11/20/2022***
11/19/2022
T/I/O=615/611/36 Assist Slickline w/B & F ( GLV C/O ) Pump 150 bbls 180* diesel
down tbg FWHPs=0/800/45
11/20/2022
Assist slickline (TBG patch) Pumped 8 bbls 60/40 down FL for fp. Slickline in
control of well per TFS departure
11/20/2022
T/I/O=500/800/0 Assist SL (Brush and flush) Pumped 145 bbls of crude down
Tbg Job continues next day
11/20/2022
***CONT, FROM 11/19/2022***
ATTEMPT SEVERAL TIMES TO PULL STA#2 @ 11323' MD.
RAN 1-1/4" LIB ON 4-1/2" OK-6 TO TRY AND OBTAIN IMPRESSION OF VALVE
LATCH IN STA#2 (inconclusive result).
ATTEMPT TO SET BK-OGLV IN STA#2 (came back w/ valve, valve slightly bowed)
RAN 4-1/2" OK-1, JK RUNNING TOOL ( w/ two brass pins to try and clean around
top of valve, inconclusive results)
BRUSH & FLUSH STA#6 THRU STA#2 W/ CRUDE. (145 bbls total).
***CONT, WSR ON 11/21/2022***
11/21/2022 Assist SL, Pump as directed job continued next day
11/21/2022
Job continued from previous day Assist SL (brush and flush) Pumped 17 bbls crude
down Tbg SL in control of well per TFS departure
11/21/2022
***CONT, FROM 11/20/2022***
MADE SEVERAL ATTEMPTS TO PULL STA#2 @ 11323' MD
ATTEMPT TO TROUBLE SHOOT STA#2 @ 11323' MD
PULL RK-OGLV FROM STA#4 @ 8989' MD
PULL RK-LGLV FROM STA# 5 @ 6977' MD
ATTEMPT TO PULL RK-LGLV FROM STA#6 @ 3671' MD
RAN 1.70" LIB ON 4-1/2" OM-1 TO STA#6 @ 3671' MD, OBTAINED IMPRESSION
OF OPEN POCKET.
SET RK-DMY GLV IN STA#6 @ 3671' MD
***CONT, ON 11/22/2022***
11/22/2022
Job continued from previous day Assist SL (GLV) Pumped 263 bbls crude down the
IA to fluid pack. Pumped 32 BBLS of crude down the IA to Reach MIT-IA test
pressure of 2250 psi. First 15 lost 17 psi. Second 15 minutes lost 7 psi. Total loss of
24 psi over 30 minutes MIT-IA ***PASSED*** Bled back 4 BBLS of crude to 1100 psi
on IA. Job continues next day
Daily Report of Well Operations
PBU W-06B
Daily Report of Well Operations
PBU W-06B
11/22/2022
***CONT, FROM 11/21/2022***
SET RK-DMY GLV IN STA# 6 @ 3671' MD.
SET RK- DMY GLV IN STA#5 @ 6677' MD.
STANDBY FOR T-BIRD TO CIRC OUT IA.
SET RK-DMY GLV IN STA#4 @ 8989' MD.
T-BIRD MITXIA ***SEE T-BIRD AWGRS FOR DETAILS PASS***
ATTEMPT TO PULL X-CATCHER @ 12442' MD (sat down in sta#2 unable to work
passed, 4-1/2" gr came back w/ metal marks on skirt)
RAN 3.70" LIB TO STA#2, IMPRESSION OF C SHAPE ON EDGE OF LIB, ( similar
to 1.5" rk latch).
***CONT, WSR ON 11/23/2022***
11/23/2022
***CONT, FROM 11/22/2022***
FISHED MISSING RK-LGLV FROM STA#6 OUT OF STA#2 @ 11323' MD
PULLED 4-1/2" X-CATCHER SUB @ 12442' MD
SET 2-7/8" XX @ 12544' MD
T-BIRD MITxT (failed) ***SEE T-BIRD AWGRS FOR DETAILS***
SET WHIDDON CATCHER @ 12554' SLM.
PULL BK-DMY GLV IN STA#2 @ 11323' MD
***CONT, ON 11/24/2022***
11/23/2022
Job continued from previous day Assist SL (GLV) MIT-T @ 2250 psi ***FAIL***
Pumped 2 bbls 60/40 down TBG followed by 19 bbls crude19 bbls crude to assist SL
Pumped 2 bbls Crude down TBG to reach test pressure. 1st 15 min lost 42 psi. 2nd
15 min lost 30 psi. Job continues next day
11/24/2022
***CONT, FROM 11/23/2022***
PULL RK- DGLV /SET RK-LGLV STA# 2 @ 11323' MD
PULL RK-DGLV / SET RK-LGLV STA# 3 @ 10236' MD
PULL RK-DGLV / SET RK-LGLV STA# 4 @ 8989' MD
PULL RK-DGLV / SET RK-LGLV STA# 5 @ 6977' MD
PULL BK-DGLV / SET BK-OGLV STA# 6 @ 3671' MD
T-BIRD MITxT (FAIL) ***SEE T-BIRD AWGRS FOR DETAILS***
***CONT, ON 11/25/2022***
11/24/2022
Job continues from previous day. Assist Sickline (GLV Change) MIT-T ***Fail***
Attempetd t MIT-T to 3600 max applied psi. 1st 15 min TBG lost 37 psi. 2nd 15 min
TBG lost 29 psi. Bleed Back TBG to 500 psi. Start rig down ***Job continued on
11/25/2022***
11/25/2022
***Job continued from 11/24/2022*** TFS unit 4 Assist SL (GLV Changeout) Rig
down, Road to TFS Yard. SL In control of well @ departure. FWHP= 716/776/0
11/25/2022
***CONT, FROM 11/24/2022***
PULL WCS @ 12554' SLM
HES UNIT 759 R/D
***JOB COMPLETE, WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED OF
STATUS***
11/26/2022
***WELL S/I ON ARRIVAL***
RAN PINNED RUNNING TOOL TO STA's 6 (3761' MD) & 5 (6977' MD). BOTH
VALVES IN POCKET.
***WSR CONTINUED ON 11-27-22***
Daily Report of Well Operations
PBU W-06B
11/26/2022
*** WELL S/I ON ARRIVAL *** OBJECTIVE: SET 3.70'' BAKER PATCH
RIG UP YJ ELINE.
PT PCE 300 PSI LOW /3000 PSI HIGH
RIH W/CH/2.75'' CCL/BAKER #10 SETTING TOOL/3.70'' BAKER PATCH MAX OAL
35.9'
TAG WITH THE PATCH AT 6968' CCL MD AT THE FIRST DOWN PASS , CCL
OFFSET TO BOTTOM OF THE PATCH 34.0' MD PUTS BOTTOM OF MULE SHOE
AT 7002' MD. APPEARS TO BE COLLAR OF BOTTOM PUP JT.
SECOND TAG THE CCL @ 6951' ON DOWN PASS + 34' = 6985'. APPEARS TO
BE BELLY OF MANDREL #5. TRIED MULTIPLE TIMES WITH NOT SUCCES AND
POOH
RDMO YELLOWJACKET ELINE
***WELL S/I ON DEPARTURE***
11/27/2022
***WSR CONTINUED FROM 11-26-22***
RAN 29' x 3.68" KB PACKER DRIFT (3 1/2" spacer pipe); S/D @ 6933' SLM. ABLE
TO TAP THROUGH.
RAN UPPER & LOWER 3.68" KB PACKER DRIFT (9' OAL); S/D @ 6973' SLM.
ABLE TO TAP THROUGH.
RAN 4 1/2" BRUSH & 3.80" GAUGE RING, BRUSHED TUBING DOWN TO 8,450'
SLM
RAN 29' x 3.68" KB PACKER DRIFT (3 1/2" spacer pipe): W/ SAME RESULTS
RAN 29' x 3.68" KB PACKER DRIFT (2 7/8" spacer pipe): W/ SAME RESULTS
**RAN 45 KB LOWER DRIFT W/ BAITSUB & GR (7' x 3.68"), ABLE TO BOBBLE
PAST 6,973' SLM @ 50, 100 & 150 FPM**
RAN 20' x 3.70" DUMMY WHIPSTOCK, SIT DOWN @ 6,973' SLM, ABLE TO TAP
THROUGH.
**RAN 10' x 3.70" DUMMY WHIPSTOCK, S/D @ 6973' SLM, BUT FALL THROUGH
WITHOUT TAPPING. **
***WELL S/I ON DEPARTURE***
12/3/2022
***WELL SHUT IN ON ARRIVAL***
PRESSURE TEST PCE TO 200#LP-3,000#HP
RIH W/ 1 7/16" CHD (1" FN), 2" WEIGHT BAR, 1 11/16" GR/CCL, BKR #10
SETTING TOOL, BKR 45 FLO-GARD PACKER (7.10' LIH LENGTH)
TOP OF PACKER SET @ 8,380.6'
***WELL LEFT SHUT IN***
12/4/2022
T/I/O=889/950/0 Temp=S/I (TFS Unit 4 MIT-T)
****MIT-T PASSED***** Max Applied Pressure= 2500. Target Pressurre= 2250.
Pumped 1 bbl of Crude to reach Max applied psi of 2501 psi. 1st 15 Min TBG lost 96
psi. 2nd 15 Min TBG lost 36 psi. TBG lost 132 psi in a 30 min Test. Bled back ~ 1.1
bbls.
Well Secure, tags hung.
Final WHPS= 1200/950/0
12/4/2022
***WELL S/I UPON ARRIVAL*** (patch tubing/liner)
SET UPPER BKR 45KB FLO-GARD PATCH ASSY IN LOWER ANCHOR @ 8380'
MD.
TOP OF PATCH AT 8356 MD
***WELL S/I ON DEPARTURE, PAD-OP NOTIFIED OF WELL STATUS***
(g)
SET UPPER BKR 45KB FLO-GARD PATCH ASSY IN LOWER ANCHOR @ 8380'
MD.
TOP OF PATCH AT 8356 MD
TOP OF PACKER SET @ 8,380.6'
Patch is shown correctly on the WBS below. -WCB
Daily Report of Well Operations
PBU W-06B
12/7/2022
***WELL S/I ON ARRIVAL*** (Patch tubing / Liner)
EQUALIZE & PULL 2-7/8" XX PLUG BODY FROM NIPPLE REDUCER AT 12,544'
MD.
***WELL S/I ON DEPARTURE, NOTIFIED PAD OPERATOR OF WELL STATUS***
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By Anne Prysunka at 4:26 pm, Nov 07, 2022
'65
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Jessie L.
Chmielowski
Digitally signed by Jessie L. Chmielowski
Date: 2022.11.09 08:40:33 -09'00'
RBDMS JSB 110922
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ϭ͘ D/Zhdh͕Wd
Ϯ͘ DhϮ͘ϯ͟ŶŽnjnjůĞĚƌŝĨƚ,ĂŶĚĚƌŝĨƚǁĞůůƚŽd
Ă͘ &ůĂŐƉŝƉĞŽĨĨďŽƚƚŽŵƚŽĂǀŽŝĚĚĂŵĂŐŝŶŐůŽŐŐŝŶŐƚŽŽůƐ
ϯ͘ Dh ZWD ůŽŐŐŝŶŐ ƚŽŽůƐ
ϰ͘ Z/,ƚŽĂďŽǀĞ ƚĂŐĚĞƉƚŚ
Ă͘ >Θ<ǁĞůůǁŝƚŚϮϱϬϭй<>ǁŚŝůĞZ/,
ď͘ DĂŝŶƚĂŝŶĂƉƵŵƉƌĂƚĞŽĨΕ͘ϮϱͲ͘ϱWDƚŽĂǀŽŝĚŐĂƐĞŶƚƌLJŝŶƚŽůŝŶĞƌĚƵƌŝŶŐůŽŐŐŝŶŐũŽď
ϱ͘ >ŽŐZWDŝŶŐĂƐǀŝĞǁƉĞƌƚĂďůĞďĞůŽǁ
ϲ͘ WKK,ĂŶĚĚŽǁŶůŽĂĚĚĂƚĂ͘KŶĐĞŐŽŽĚĚĂƚĂŝƐĐŽŶĨŝƌŵĞĚDh^DdůŽŐŐŝŶŐƚŽŽůƐĂŶĚZ/,͘
Ă͘ WĞƌĨŽƌŵZƉŝƉĞŵĂŶĂŐĞŵĞŶƚĂƐŶĞĞĚĞĚƐŽƚŚĂƚ^DdƌƵŶĐĂŶƐĞƌǀĞĂƐĨůĂŐƌƵŶ ĨŽƌƉĞƌĨƐ
ď͘ ^ĞŶĚZWDĚĂƚĂƚŽZ ĂƐƐŽŽŶĂƐĂǀĂŝůĂďůĞ
Đ͘ >Θ<ǁĞůůǁŝƚŚϮϱϬďďůƐŽĨϭй<>ǁŚŝůĞZ/,
Ě͘ DĂŝŶƚĂŝŶĂƉƵŵƉƌĂƚĞŽĨΕ͘ϮϱͲ͘ϱWDƚŽĂǀŽŝĚŐĂƐĞŶƚƌLJŝŶƚŽůŝŶĞƌĚƵƌŝŶŐůŽŐŐŝŶŐ
ϳ͘ >ŽŐ^DdĨƌŽŵdƚŽdK>ĂƚϭϮϵϬϬ͛
Ă͘ &ůĂŐƉŝƉĞĨŽƌƉĞƌĨƌƵŶǁŚŝůĞůŽŐŐŝŶŐKK,͘ŽŶƐƵůƚǁŝƚŚZ ŽŶƉŽƚĞŶƚŝĂůƉĞƌĨŝŶƚĞƌǀĂůƐ
ď͘ WĞƌĨŽƌŵƌĞƉĞĂƚƉĂƐƐĨƌŽŵϭϯ͕ϲϬϬͲ ϭϮ͕ϵϬϬ͛
ϴ͘ WKK,ǁŝƚŚ^DdĂŶĚĚŽǁŶůŽĂĚĚĂƚĂ
Ă͘ ^ĞŶĚƌĞƐƵůƚƐƚŽZ ǁŝƚŚĨŝĞůĚƉŝĐŬŽĨdK
/ . /RDGDQG.LOOZLWKEEOVRI.&/ PJU
tĞůů͗ tͲϬϲ
ƵƌƌĞŶƚ Wd͗ ϮϮϮͲϬϵϵ
ZWD>ŽŐŐŝŶŐdĂďůĞ͗
DŽĚĞ ŝƌĞĐƚŝŽŶ ^ƉĞĞĚ /ŶƚĞƌǀĂů >ĞŶŐƚŚ EŽƚĞƐ
'ĂƐsŝĞǁ hƉ ϮϬĨƉŵ ϭϮ͕ϵϬϬ͛Dϭϱ͕ϰϯϮ͛DϮϱϯϮ͛DĂŝŶƚĂŝŶƉƵŵƉƌĂƚĞĂƚ͘ϱWDŽĨ
<> ƚŽ ĂǀŽŝĚ ŐĂƐ ĞŶƚĞƌŝŶŐ ƚŚĞ
ǁĞůůďŽƌĞ ĨŽƌ ƚŚĞ ĞŶƚŝƌĞƚLJ ŽĨ ƚŚĞ
ůŽŐŐŝŶŐũŽď͘
'ĂƐsŝĞǁ hƉ ϮϬĨƉŵ ϭϮ͕ϵϬϬ͛Dϭϱ͕ϰϯϮ͛DϮϱϯϮ͛ΕϳϬ ďďůƐŬĐůŶĞĞĚĞĚƉĞƌŐĂƐǀŝĞǁ
ƌƵŶ
^ĞƌǀŝĐĞŽŝů ʹ džƚĞŶĚĞĚĚWĞƌĨ;ŽŶƚŝŶŐĞŶƚͿ
^ƵŶĚƌLJWƌŽĐĞĚƵƌĞ;ƉƉƌŽǀĂůZĞƋƵŝƌĞĚƚŽWƌŽĐĞĞĚͿ
ŽŝůdƵďŝŶŐ ʹ džƚĞŶĚĞĚĚĚWĞƌĨ͕ ŽŶƚŝŶŐĞŶƚ^ƋƵĞĞnjĞ
EŽƚĞƐ
x ZĞŵŽƚĞŐĂƐŵŽŶŝƚŽƌŝŶŐĨŽƌ,Ϯ^ĂŶĚ> >ƐĂƌĞƌĞƋƵŝƌĞĚĨŽƌKƉĞŶ,ŽůĞ ĞƉůŽLJŵĞŶƚKƉĞƌĂƚŝŽŶƐ
x ƵĞƚŽƚŚĞŶĞĐĞƐƐĂƌLJŽƉĞŶŚŽůĞĚĞƉůŽLJŵĞŶƚŽĨ džƚĞŶĚĞĚWĞƌĨŽƌĂƚŝŶŐũŽďƐ͕ϮϰͲŚŽƵƌĐƌĞǁĂŶĚt^^
ĐŽǀĞƌĂŐĞŝƐƌĞƋƵŝƌĞĚ͘
x dŚĞǁĞůůǁŝůůďĞŬŝůůĞĚĂŶĚŵŽŶŝƚŽƌĞĚďĞĨŽƌĞŵĂŬŝŶŐƵƉƚŚĞŝŶŝƚŝĂůƉĞƌĨƐŐƵŶƐ͘dŚŝƐŝƐŐĞŶĞƌĂůůLJĚŽŶĞ
ĚƵƌŝŶŐƚŚĞĚƌŝĨƚͬůŽŐŐŝŶŐƌƵŶ͘ dŚŝƐǁŝůůƉƌŽǀŝĚĞŐƵŝĚĂŶĐĞĂƐƚŽǁŚĞƚŚĞƌƚŚĞǁĞůůǁŝůůďĞŬŝůůĞĚďLJ
ďƵůůŚĞĂĚŝŶŐŽƌĐŝƌĐƵůĂƚŝŶŐďŽƚƚŽŵƐƵƉƚŚƌŽƵŐŚŽƵƚƚŚĞũŽď͘ /ĨƉƌĞ ƐƐƵƌĞŝƐƐĞĞŶŝŵŵĞĚŝĂƚĞůLJĂĨƚĞƌ
ƉĞƌĨŽƌĂƚŝŶŐ͕ŝƚǁŝůůĞŝƚŚĞƌďĞŬŝůůĞĚďLJďƵůůŚĞĂĚŝŶŐǁŚŝůĞWKK,ŽƌĐŝƌĐƵůĂƚŝŶŐďŽƚƚŽŵƐƵƉƚŚƌŽƵŐŚƚŚĞ
ƐĂŵĞƉŽƌƚƚŚĂƚŽƉĞŶĞĚƚŽƐŚĞĂƌƚŚĞĨŝƌŝŶŐŚĞĂĚ͘
ϭ͘ WƵůůƚĞƐƚŝŶŐƚŚĞd͕ƚĂŐͲƵƉŽŶƚŚĞdƐƚƌŝƉƉĞƌƚŽĞŶƐƵƌĞ,ĐĂŶŶŽƚƉƵůůƚŚƌŽƵŐŚƚŚĞďƌĂƐƐƵƉŽŶWKK,
ǁŝƚŚŐƵŶƐ͘͘
Ϯ͘ ŽŶĨŝƌŵĐŽƌƌĞĐƚĞĚdŝĞŝŶǁŝƚŚK ĨƌŽŵ^DdƌƵŶ
ϯ͘ ƵůůŚĞĂĚ ϮϳϬ ďďůƐŽĨ<t&͕ ϭй<> ĚŽǁŶƚŚĞƚƵďŝŶŐƚŽƚŚĞĨŽƌŵĂƚŝŽŶ͘
Ă͘ dŚŝƐƐƚĞƉĐĂŶďĞƉĞƌĨŽƌŵĞĚĂŶLJƚŝŵĞƉƌŝŽƌƚŽŽƉĞŶͲŚŽůĞĚĞƉůŽLJŵĞŶƚŽĨƚŚĞƉĞƌĨŐƵŶƐ͘dŝŵŝŶŐŽĨ
ƚŚĞǁĞůůŬŝůůŝƐĂƚƚŚĞĚŝƐĐƌĞƚŝŽŶŽĨƚŚĞt^>͘
ď͘ tĞůůďŽƌĞǀŽůƵŵĞƚŽ d с Ϯϭϯ ďďůƐ
ϰ͘ WƌĞƉĂƌĞĨŽƌ ĚĞƉůŽLJŵĞŶƚŽĨdWŐƵŶƐ͘
ϱ͘ ŽŶĨŝƌŵǁĞůůŝƐĚĞĂĚ͘ůĞĞĚĂŶLJƉƌĞƐƐƵƌĞŽĨĨƚŽƌĞƚƵƌŶƚĂŶŬ͘<ŝůůǁĞůůǁͬ<t&ĂƐŶĞĞĚĞĚ͘DĂŝŶƚĂŝŶ
ĐŽŶƚŝŶƵŽƵƐŚŽůĞĨŝůůƚĂŬŝŶŐƌĞƚƵƌŶƐƚŽƚĂŶŬƵŶƚŝůůƵďƌŝĐĂƚŽƌĐŽ ŶŶĞĐƚŝŽŶŝƐƌĞͲĞƐƚĂďůŝƐŚĞĚ͘
Ă͘ &ůƵŝĚƐŵĂŶͲǁĂƚĐŚŵƵƐƚďĞƉĞƌĨŽƌŵĞĚǁŚŝůĞĚĞƉůŽLJŝŶŐƉĞƌĨŐƵŶƐƚŽĞŶƐƵƌĞƚŚĞǁĞůůƌĞŵĂŝŶƐ
ŬŝůůĞĚĂŶĚƚŚĞƌĞŝƐŶŽĞdžĐĞƐƐĨůŽǁ͘
ϲ͘ WĞƌĨŽƌŵĚƌŝůůďLJƉŝĐŬŝŶŐƵƉƐĂĨĞƚLJũŽŝŶƚǁŝƚŚd/tǀĂůǀĞĂŶĚƐƉĂĐĞŽƵƚďĞĨŽƌĞDhŐƵŶƐ͘ZĞǀŝĞǁǁĞůů
ĐŽŶƚƌŽůƐƚĞƉƐǁŝƚŚĐƌĞǁƉƌŝŽƌƚŽďƌĞĂŬŝŶŐůƵďƌŝĐĂƚŽƌĐŽŶŶĞĐƚŝŽŶĂŶĚĐŽŵŵĞŶĐŝŶŐŵĂŬĞƵƉŽĨdWŐƵŶ
ƐƚƌŝŶŐ͘KŶĐĞƚŚĞƐĂĨĞƚLJũŽŝŶƚĂŶĚd/tǀĂůǀĞŚĂǀĞďĞĞŶƐƉĂĐĞĚŽƵƚ͕ŬĞĞƉƚŚĞƐĂĨĞƚLJũŽŝŶƚͬd/tǀĂůǀĞ
ƌĞĂĚŝůLJĂĐĐĞƐƐŝďůĞŶĞĂƌƚŚĞǁŽƌŬŝŶŐƉůĂƚĨŽƌŵĨŽƌƋƵŝĐŬĚĞƉůŽLJŵĞŶƚŝĨŶĞĐĞƐƐĂƌLJ͘
Ă͘ ƚƚŚĞďĞŐŝŶŶŝŶŐŽĨĞĂĐŚũŽď͕ƚŚĞĐƌŽƐƐŽǀĞƌͬƐĂĨĞƚLJũŽŝŶƚŵƵƐƚďĞƉŚLJƐŝĐĂůůLJDhƚŽƚŚĞƉĞƌĨŐƵŶƐ
ŽŶĞƚŝŵĞƚŽĐŽŶĨŝƌŵƚŚĞƚŚƌĞĂĚƐĂƌĞĐŽŵƉĂƚŝďůĞ͘
ϳ͘ ƌĞĂŬůƵďƌŝĐĂƚŽƌĐŽŶŶĞĐƚŝŽŶĂƚYd^ĂŶĚďĞŐŝŶŵĂŬĞƵƉŽĨdWŐƵŶƐ͘ &ŝŶĂůƉĞƌĨĚĞƉƚŚƐǁŝůůďĞĐŽŶƚŝŶŐĞŶƚ
ŽŶƌĞƐƵůƚƐŽĨZWDůŽŐ͕ĂŶĚĐĞŵĞŶƚŝŶƚĞŐƌŝƚLJ͘ ŽŶƐƚĂŶƚůLJŵŽŶŝƚŽƌĨůƵŝĚƌĂƚĞƐƉƵŵƉĞĚŝŶĂŶĚĨůƵŝĚƌĞƚƵƌŶƐ
tĞůů͗ tͲϬϲ
ƵƌƌĞŶƚ Wd͗ ϮϮϮͲϬϵϵ
ŽƵƚŽĨƚŚĞǁĞůů͘&ůƵŝĚƐŵĂŶͲǁĂƚĐŚŵƵƐƚďĞƉĞƌĨŽƌŵĞĚǁŚŝůĞĚĞƉůŽLJŝŶŐƉĞƌĨŐƵŶƐƚŽĞŶƐƵƌĞƚŚĞǁĞůů
ƌĞŵĂŝŶƐŬŝůůĞĚĂŶĚƚŚĞƌĞŝƐŶŽĞdžĐĞƐƐĨůŽǁ͘
dĂďůĞ ϭ͗ tͲϬϲ WƌŽƉŽƐĞĚĚͲWĞƌĨ'ƵŶZƵŶƐ
ϴ͘ Z/,ǁŝƚŚƉĞƌĨŐƵŶĂŶĚƚŝĞͲŝŶƚŽĐŽŝůĨůĂŐĐŽƌƌĞůĂƚŝŽŶ͘WŝĐŬƵƉĂŶĚƉĞƌĨŽƌĂƚĞŝŶƚĞƌǀĂůƉĞƌ Z ͬK ͘WKK,͘
ϵ͘ EŽƚĞĂŶLJƚƵďŝŶŐƉƌĞƐƐƵƌĞĐŚĂŶŐĞŝŶt^Z͘
ϭϬ͘ ĨƚĞƌƉĞƌĨŽƌĂƚŝŶŐ͕Wh,ƚŽƚŽƉŽĨůŝŶĞƌŽƌŝŶƚŽƚƵďŝŶŐƚĂŝůƚŽĞŶƐƵƌĞĚĞďƌŝƐĚŽŶŽƚĨĂůůŝŶŽŶƚŚĞŐƵŶƐĂŶĚ
ƐƚŝĐŬƚŚĞ,͘ŽŶĨŝƌŵǁĞůůŝƐĚĞĂĚĂŶĚƌĞͲŬŝůůŝĨŶĞĐĞƐƐĂƌLJ͕ďĞĨŽƌĞƉƵůůŝŶŐƚŽƐƵƌĨĂĐĞ͘
ϭϭ͘ WƵŵƉƉŝƉĞĚŝƐƉůĂĐĞŵĞŶƚǁŚŝůĞWKK,͘^ƚŽƉĂƚƐƵƌĨĂĐĞƚŽƌĞĐŽŶĨŝƌŵǁĞůůĚĞĂĚĂŶĚŚŽůĞĨƵůů͘
ϭϮ͘ ZĞǀŝĞǁǁĞůůĐŽŶƚƌŽůƐƚĞƉƐǁŝƚŚĐƌĞǁƉƌŝŽƌƚŽďƌĞĂŬŝŶŐůƵďƌŝĐĂƚŽƌĐŽŶŶĞĐƚŝŽŶĂŶĚĐŽŵŵĞŶĐŝŶŐ
ďƌĞĂŬĚŽǁŶŽĨdWŐƵŶƐƚƌŝŶŐ͘
ϭϯ͘ ŶƐƵƌĞƐĂĨĞƚLJũŽŝŶƚĂŶĚd/tǀĂůǀĞĂƐƐĞŵďůLJĂƌĞŽŶͲŚĂŶĚďĞĨŽƌĞďƌĞĂŬŝŶŐŽĨĨůƵďƌŝĐĂƚŽƌƚŽ>ŐƵŶ,͘
ƚƚĂĐŚŵĞŶƚƐ͗
ϭ͘ ƐͲďƵŝůƚ^ĐŚĞŵĂƚŝĐ
Ϯ͘ WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ
ϯ͘ KW^ĐŚĞŵĂƚŝĐ
ϰ͘ ^ƚĂŶĚŝŶŐKƌĚĞƌƐĨŽƌKƉĞŶ,ŽůĞtĞůůŽŶƚƌŽůƵƌŝŶŐWĞƌĨ'ƵŶĞƉůŽLJŵĞŶƚ
ϱ͘ ƋƵŝƉŵĞŶƚ>ĂLJŽƵƚŝĂŐƌĂŵ
ϲ͘ ^ƵŶĚƌLJŚĂŶŐĞ&Žƌŵ
'ƵŶZƵŶη WĞƌĨdŽƉ WĞƌĨŽƚƚŽŵ WĞƌĨ>ĞŶŐƚŚ
ϭ d͛d͛ϮϬϬ͛Dy
dŽƚĂů ϮϬϬ͛Dy
0DNHXS3&(
ϮϬϬ͛Dy
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ϮϬϬ͛Dy
PJU
tĞůů͗ tͲϬϲ
ƵƌƌĞŶƚ Wd͗ ϮϮϮͲϬϵϵ
ƐͲďƵŝůƚ^ĐŚĞŵĂƚŝĐ͗
tĞůů͗ tͲϬϲ
ƵƌƌĞŶƚ Wd͗ ϮϮϮͲϬϵϵ
WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ͗
tĞůů͗ tͲϬϲ
ƵƌƌĞŶƚ Wd͗ ϮϮϮͲϬϵϵ
KW^ĐŚĞŵĂƚŝĐ
tĞůů͗ tͲϬϲ
ƵƌƌĞŶƚ Wd͗ ϮϮϮͲϬϵϵ
tĞůů͗ tͲϬϲ
ƵƌƌĞŶƚ Wd͗ ϮϮϮͲϬϵϵ
tĞůů͗ tͲϬϲ
ƵƌƌĞŶƚ Wd͗ ϮϮϮͲϬϵϵ
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David Douglas Hilcorp North Slope, LLC
Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: (907) 777-8337
E-mail: david.douglas@hilcorp.com
Please acknowledge receipt by signing and returning one copy of this transmittal.
Received By: Date:
Hilcorp North Slope, LLC
Date: 11/03/2022
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
DATA TRANSMITTAL
WELL: W-06B + W-06BPB1
PTD: 222-099
API: 50-029-21822-02-00 (W-06B)
50-029-21822-71-00 (W-06BPB1)
FINAL LWD FORMATION EVALUATION LOGS (09/28/2022 to 10/09/2022)
Multiple Propagation Resistivity & Gamma Ray (2” & 5” MD/TVD Color Logs)
Pressure While Drilling (PWD)
Final Definitive Directional Surveys
SFTP Transfer - Data Main Folders:
SFTP Transfer - Data Sub-Folders:
Please include current contact information if different from above.
PTD:222-099
W-06B T37225
W-06B PB1 T37226
Kayla Junke
Digitally signed by Kayla
Junke
Date: 2022.11.03 11:32:23
-08'00'
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RECEIVED By James Brooks at 1:34 pm, Oct 26, 2022
Completed
10/16/2022
JSB
RBDMS JSB 103122
G
DSR-11/3/22MGR12NOV22
For Monty Myers
Joseph Engel (2493)
2022.10.26 10:29:45
-08'00'
Joseph Engel
(2493)
Activity Date Ops Summary
9/25/2022 Remove Jeeps off sub and pits. Position sub on dance floor Disconnect truck and RU stomper. Spot sub. Start spotting mud pits with trucks. Disconnect truck and
RU stompers. Spot pit module and set down. Accept rig at 17:30. Safe out rig and set down landings. Connect PUTZ. Repair cross beam in coil reel. LTT both
Swab and Master. Install fusable cap on SSV. Remove tree cap and flange. N/U BOPE. N/U MPD Line. N/U Cellar and steam lines Continue N/U BOP's. R/U to
reverse eline for pressure bulkhead. Grease and service all valves. Work on MIRU checklist.
9/26/2022 Reverse circulate to load reel with freshwater. Once reel full. Surge rate in attempts to get e-line to move. Minimal movement heard. Make multiple attempts. Hitting
pressure limits at 3.4 bpm. Add DR204 to freshwater. Pressure came down. Increase rate to 4.5 bpm. Surge multiple times Order up 150 deg slick water. Stand
back injector. Install test cap. Start prepping for BOPE test. Fluid pack everything for Test#1 without IRV and packoff Begin Initial BOPE test Test gas alarms. All
pass. Test:1 C9, C10, C11 Pass. Test: 2 Blind / Shear (10sec), R2, BL2, C15 Pass. Install Test Joint. Test:3 (2-3/8") Annular, TIW#1, B1, B4 B1/B4 are Fail
/Grease/ Pass. Test:4 Upper 2-3/8" Pipe / Slip, TIW#2, B2, B3 Test 5: Lower 2 3/8" Pipe/Slips, C5, C6, C8, TV2. Test 6: Choke A, Choke C. Drawdown test on
accumulator. Test 7: C1, C4, TV1. Test 8: 3" Pipe/Slips, C3, C3. R/D test lubricator. R/U drilling lubricator. Test IRV and Stripper Prep eline and inner reel iron for
pumping slack. R/U hose and diffuser on reel end. Pump 150 degree slick freshwater and try to move eline back into reel Recover additional 12' of eline in reel.
Prep to make up pressure bulkhead. Nabors electrician installing eline pressure bulkhead in reel.
9/27/2022 Electrician installing pressure bulkhead. Crew finish securing hardline in reel. Secondary restraints. Check continuity 2200 ohm. Begin troubleshooting bulkhead.
Install PDL. Pressure test to 3500# for 5 min. Good test. Break bulkhead apart. and UQC. Get down to e-line. Test line. Good. BHI Flow sub bad. Replace.
Electrician ran to get parts from shop to replace. Install new flow sub. Finish bulkhead. Continuity 59.1 ohms. Good test. Check continuity 59.1. Meg test good.
Unlock reel. Install test cap on coil. Fluid pack SR manifold, customer line. Pressure test SR manifold and customer line to 4200 psi. Pass
Pressure test to 6700 psi on inner reel iron, SR manifold with cement MM bypassed. Fail. Tighten 1502 on bulkhead Re-test inner reel iron, SR manifold with
cement MM bypassed to 6700 psi. Pass. Test with pump #2 and seat new valve seats during high pressure test. Test to 6566 psi. Pass. R/D test equipment. Rig
back injector and install BHI floats with 3.10" nozzle BHA. Test BHI float valves to 3800 psi. Pump max rate with slick KCL and 0.6% safe lube. Load 10 bbls of
methanol and follow with slick KCL w/0.6% safe lube. With methanol at nozzle, open well. Initial tubing pressure = 165 psi. IA = 0, OA = 0 RIH pumping .5 bpm
and holding 100 psi on choke. Notify Pad operator we are taking returns from the well. WT CK at 12,900' = 56k. 26k RIH WT. RIH and tag CIBP @ 13,007'
uncorrected. Displace well with 1% KCL followed by 24 bbls HiVis Pill and then PowerPro mud system. Check reel hubs and re-tighten/check torque. In Rate = 2.9
bpm, Circ pressure = 3085 psi. Choke pressure = 170 psi. Continue well displacement to PowerPro drilling mud system from 12,972'. In Rate = 3.9 bpm, Out Rate
= 2.9 bpm. In MM = 8.60 ppg, Out MM = 8.40 ppg. Circ pressure = 3487 psi Dynamic flow check of well. In Rate = .5 bpm , Out Rate = .3 bpm. In MM = 8.57 ppg,
Out MM = 8.58 ppg. POOH for whipstock BHA from 12,972'. In Rate = 1.6 bpm, Out Rate = .8 bpm. In MM = 8.57 ppg, Out MM = 8.69 ppg. Circ pressure = 1360
psi.
9/28/2022 Continue POOH for whipstock BHA from 5960'. In Rate = 1.6 bpm, Out Rate = 1.0 bpm. In MM = 8.57 ppg, Out MM = 8.70 ppg. Circ pressure = 1295 psi. OOH -
flow check well and confirm no flow. L/D nozzle BHA. M/U Baker 4.5" monobore whipstock. RIH with Baker 4.5" monobore whipstock. Open EDC and minimum rate.
In Rate = .4 bpm , Out Rate = .4 bpm. In MM = 8.58 ppg, Out MM = 8.67 ppg. Circ pressure = 680 psi. IA = 0, OA = 0 Log shale marker from 10200' to 10373',
correct depth +7' based on PDC Log. RIH to 12630 to relog closer to WS set depth, correct depth +8' (+15' total). RIH and tag CIBP at 13,034', PUH to CCL Log
collars to verify we are on depth with log in the program. CCL is not on depth with Ref Log Upper part of the PDC log is off depth with a gap from 12600 - 12850',
lower part of PDC is on depth. Log from 12700 to 13000' to tie both logs together. Correct depth -2', verify correction to ref log is good. RIH to 12999.45' bit depth,
TOWS @ 112987', PU to 5k <up WT, close EDC and set WS WS oriented to 20 degrees LOHS. Set and sheared at 3800psi, set down 5k WOB with no
movement. POOH for window milling BHA OOH - Flow check well and confirm no flow. L/D Baker whipstock setting tool. M/U Baker motor and window milling BHA.
RIH with BHA #3 - BOT motor and window mill. In Rate = 1.6 bpm , Out Rate = 1.9 bpm. In MM =8.58 ppg , Out MM = 8.68 ppg. Circ pressure = 1452 psi. IA = 0,
OA = 0. Set down at 12,436' near x nipple. Run past Log GR Tie In from 12,880' @ 5 fpm. Correct -8'. Tag pinch point @ 12,989'. PUW = 56k, RIW = 26k. Begin
time milling window from 12,987.8'. In Rate = 2.5 bpm, Out Rate = 2.4 bpm. In MM = 8.59, Out MM = 8.70. Circ pressure = 2691' Continue time milling window
from 12,991'. In Rate = 2.5 bpm, Out Rate = 2.3 bpm. In MM = 8.59, Out MM = 8.70. Circ pressure = 2688 psi. 3.8k WOB. Continue time milling window from
12,993.1' to 12,993.9'. In Rate = 2.5 bpm, Out Rate = 2.4 bpm. In MM = 8.59, Out MM = 8.70. Circ pressure = 2448 psi. 1 - 3.8k WOB. 6 - 10 bph loss rate.
9/29/2022 12994.5' window mill exited the bottom of the window, continue milling at 1 fph to dress the bottom of the window with the string mill. Mill Rat hole to 13,005'.
Formation samples from - 12997' 5%, 13,000' 85%. Make 3 ream passes at 1 fpm then dry drift Dry drift is clean in both directions, open EDC and POOH OOH,
flow check well. Good no flow, fill well, took 0.6 bbls. PU injector and LD the milling BHA. BHA OOH. Mills in gauge, Window 3.79 Go 3.78 No Go, String 3.80 Go
3.79 No Go MU Build BHA and RIH. 12830' log tie in. Drill build from 13,005'. In Rate 2,8 bpm, Out Rate = 2.7 bpm. In MM = 8.59 ppg, Out MM = 8.75 ppg. Circ
pressure 2953 psi. Continue drilling build from 13,139'. In Rate 2,8 bpm, Out Rate = 2.7 bpm. In MM = 8.59 ppg, Out MM = 8.75 ppg. Circ pressure 2953 psi. WOB
= 1 - 3.5k. ROP = 30 - 50 fph Continue drilling build from 13,184' with some differential sticking. PUW = 64k. In Rate 2,8 bpm, Out Rate = 2.6 bpm. In MM = 8.60
ppg, Out MM = 8.76 ppg. Circ pressure 2907 psi. WOB = 1 - 4 k. ROP = 50 - 110 fph. Pump 5x5 sweep. Drill to 13,197' and unable to get clean surveys. PUH and
investigate. Re-input surveys and verify. Resume drilling build from 13,209'. In Rate 2.8 bpm, Out Rate = 2.6 bpm. In MM = 8.62 ppg, Out MM = 8.76 ppg. Circ
pressure 3041 psi. WOB = 1 - 4 k. ROP = 50 - 110 fph. Land build @ 13,350'. Wiper trip to window. 57k wt off bottom. Jog below window and then pull through
clean. Open EDC. POOH pumping at max rate. In Rate 3.5 bpm, Out Rate = 3.1 bpm. In MM = 8.65 ppg, Out MM = 8.81 ppg. Circ pressure 3088 psi.
50-029-21822-02-00API #:
Well Name:
Field:
County/State:
PBW W-06B
Prudhoe Bay West
Hilcorp Energy Company Composite Report
, Alaska
9/29/2022Spud Date:
9/30/2022 Continue POOH from landing build for lateral BHA OOH, flow check well, hold PJSM to LD & MU tools. PU injector and inspect coil, good, LD BHA. Bit grade = 1-1
and will rerun for the lateral section. MU the HOT, USR and DGS RIH with the lateral BHA w/Res & Agitator. Shallow Test Agitator, good test, RIH increasing WHP
to apply 9.8 ECD at the window. Log tie in, correct depth -8' and RIH. 12260' choke plugged off, PUH slow and blow down choke. Back on bottom drilling at 13350'.
In Rate 2.8 bpm, Out Rate = 2.8 bpm. In MM = 8.56 ppg, Out MM = 8.75 ppg. Circ pressure 3160 psi, ECD = 9.8 ppg. WOB = 1 - 3.5 k. ROP = 50 - 110 fph.
Continue drilling ahead from 13,568' to 13,800'. In Rate 2.7 bpm, Out Rate = 2.7 bpm. In MM = 8.60 ppg, Out MM = 8.76 ppg. Circ pressure 3262 psi, ECD = 9.8
ppg. WOB = 1 - 3.5 k. ROP = 50 - 110 fph. Long wiper trip to window from 13,800'. In Rate 2.8 bpm, Out Rate = 2.5 bpm. In MM = 8.64 ppg, Out MM = 8.83 ppg.
Circ pressure 3298 psi, ECD = 9.85 ppg. Jog below window and pull through clean. Log Tie In and correct +4'. Open EDC and circulate bottoms up with well
unloading. RIH to resume drilling. Drill ahead from 13,803' to 13,813'. In Rate 2.8 bpm, Out Rate = 2.7 bpm. In MM = 8.64 ppg, Out MM = 8.78 ppg. Circ pressure
3407 psi, ECD = 9.75 ppg. WOB = 1 - 3.5 k. ROP = 50 - 110 fph Drill to 13,819' and pull 80k. Unable to move coil. Increase traction pressure on injector. Pump 5:5
sweep and relax coil. Pull free after sweep around BHA. BHA wiper and resume drilling. Drill ahead from 13,819' to 13,860'. In Rate 2.7 bpm, Out Rate = 2.7 bpm. In
MM = 8.64 ppg, Out MM = 8.80 ppg. Circ pressure 2988 psi, ECD = 9.71 ppg. WOB = 1 - 3.5 k. ROP = 50 - 110 fph.
10/1/2022 Continue drilling ahead from 13,885'. In Rate 2.8 bpm, Out Rate = 2.8 bpm. In MM = 8.65 ppg, Out MM = 8.82 ppg. Circ pressure 3245 psi, ECD = 9.81 ppg. WOB
= 1 - 3.5 k, ROP = 60 - 110 fph Continue drilling ahead from 14,050'. In Rate 2.9 bpm, Out Rate = 2.9 bpm. In MM = 8.64 ppg, Out MM = 8.81 ppg. Circ pressure
3321 psi, ECD = 9.75 ppg. WOB = 1.5 - 3.5 k, ROP = 40 - 125 fph. 14055' starting to see some fluctuations on in the Out Rate, losing a little returns then comes
back. 14060' Out Rate dropped to 1.2 bpm slowly increasing. 14065' stall, loses at 1.5 bpm or 90 bph, continue drilling. 835 bbls of mud on the rig ~9-hrs, call out
for another load of mud. Drilled 14081' lost all returns, PU and monitor returns. Slowly getting returns back. Back on bottom continue drilling - In Rate = 2.9 bpm,
Out Rate = 1.6 bpm. Geo say's this is the mapped fault they projected at 14263'. 14,156' PUH above fault to 14,000' and verify the wellbore is clean behind us,
wellbore is clean. Continue drilling ahead from 14,156'. In Rate 2.8 bpm, Out Rate = 2.4 bpm loss rate = 24 bph. In MM = 8.62 ppg, Out MM = 8.80 ppg. Circ
pressure 3186 psi, ECD = 9.65 ppg. WOB = 1.5 - 3.75 k, ROP = 50 - 80 fph. Drilled 450', pull wiper to the window. Jog below window and pull through clean. Open
EDC and pump bottoms up at max rate. Log Tie In from 12,850' at 5 fpm. Correct +7'. Drilling ahead from 14,250' to 14,385'. In Rate 2.8 bpm, Out Rate = 2.4 bpm.
In MM = 8.62 ppg, Out MM = 8.77 ppg. Circ pressure 3365 psi, ECD = 9.73 ppg. WOB = 1.5 - 3.5 k, ROP = 40 - 80 fph. Drilling ahead from 14,385' to 14,411'. In
Rate 2.8 bpm, Out Rate = 2.4 bpm. In MM = 8.64 ppg, Out MM = 8.80 ppg. Circ pressure 3297 psi, ECD = 9.74 ppg. WOB = 1.5 - 3.5 k, ROP = 40 - 60 fph. Wiper
trip to window after heavy overpulls. In Rate 2.9 bpm, Out Rate = 2.6 bpm. In MM = 8.62 ppg, Out MM = 8.78 ppg. Heavy cuttings noted on bottoms up. Drilling
ahead from 14,411' to 14,465'. In Rate 2.6 bpm, Out Rate = 2.3 bpm. In MM = 8.65 ppg, Out MM = 8.78 ppg. Circ pressure 3359 psi, ECD = 9.74 ppg. WOB = 1.5 -
3.5 k, ROP = 40 - 110 fph. Differential sticking off bottom with heavy overpulls.
10/2/2022 Continue drilling ahead from 14,470'. In Rate 3.0 bpm, Out Rate = 2.7 bpm, Loss Rate = 18 bph. In MM = 8.62 ppg, Out MM = 8.79 ppg. Circ pressure 3530psi,
ECD = 9.80 ppg. WOB = 1.5 - 3.5 k, ROP = 30 - 110 fph Drilled to 14580', PUH from drill off. RIH stacking WT off bottom, PU and we are diff stuck. Work pipe to
90-100k with no movement, pump Low & High Vis Pills. No movement, pump 10 bbl HV 20 bbl LVT, 10 HV. 10:45 - 5 bbls out, shut down pump and allow to soak
while in tension. Pulled free, circ remaining LVT out and increase LSRV from 58k to 65k. Continue drilling ahead from 14,580'. In Rate 3.0 bpm, Out Rate = 2.7
bpm, Loss Rate = 18 bph. In MM = 8.63 ppg, Out MM = 8.71 ppg. Circ pressure 3594psi, ECD = 9.89 ppg. WOB = 1.5 - 2.5 k, ROP = 40- 75 fph. Continue drilling
ahead from 14,700'. Call for vac trucks to swap to new mud. In Rate 3.0 bpm, Out Rate = 2.8 bpm, Loss Rate = 12 bph. In MM = 8.63 ppg, Out MM = 8.79 ppg. Circ
pressure 3621 psi, ECD = 9.93 ppg. WOB = 1.5 - 2.75 k, ROP = 45 - 75 fph 14725' Swap to new mud taking returns outside to the TT. New mud at the bit, wiper
trip to the window. Bring returns back inside with new mud at surface. Pull through window clean. Open EDC and pump max rate. Log Tie In and correct +10.5'.
Reciprocate coil and pump bottoms up with well unloading. Drilling ahead from 14,725' to 14,886'. In Rate 2.8 bpm, Out Rate = 2.7 bpm, Loss Rate ~ 10 bph. In
MM = 8.59 ppg, Out MM = 8.74 ppg. Circ pressure 3571 psi, ECD = 9.78 ppg. WOB = 1.5 - 4 k, ROP = 40- 110 fph. Drilling ahead from 14,886' to 14,955'. In Rate
2.8 bpm, Out Rate = 2.6 bpm, Loss Rate ~ 10 bph. In MM = 8.61 ppg, Out MM = 8.77 ppg. Circ pressure 3323 psi, ECD = 9.82 ppg. WOB = 1.5 - 4 k, ROP = 40-
80 fph. Drill from 14,955' to 14,998'. In Rate 2.8 bpm, Out Rate = 2.7 bpm, Loss Rate ~ 10 bph. In MM = 8.63 ppg, Out MM = 8.78 ppg. Circ pressure 3223 psi,
ECD = 9.80 ppg. WOB = 1.5 - 4.5 k, ROP = 40- 60 fph.
10/3/2022 Continue drilling lateral from 14,999'. In Rate 3.0 bpm, Out Rate = 2.7 bpm, Loss Rate ~ 18 bph. In MM = 8.64 ppg, Out MM = 8.77 ppg. Circ pressure 3301psi,
ECD = 9.90 ppg. WOB = 1.5 - 3.8 k, ROP = 25 - 80 fph Continue drilling lateral from 15120'. In Rate 2.8 bpm, Out Rate = 2.6 bpm, Loss Rate ~ 12 bph. In MM =
8.63 ppg, Out MM = 8.79 ppg. Circ pressure 3332psi, ECD = 9.92 ppg. WOB = 3.0 -4.0 k, ROP = 30 - 70 fph Drilled 450' to 15175', wiper to the window. Over pull
15k with -4.5k WOB at 14,089'. Pull above window, open the EDC, wash across WS tray then PUH 500' at max rate. RIH 500' at max speed and rate to clean up the
tangent section of the well. Log tie in with a +8' correction. Got a lot of cuttings back before and after bottoms up. Clean returns, shut down pumps. Perform Weekly
Function Test on both sets of 2-3/8" Combi's. Function Test Blind Shears and Annular on next trip OOH. Close EDC and RIH through window to continue drilling.
Tag at 14,112 3x. PU and orient to 100° LOHS. Tag at 14,221' Continue drilling lateral from 15175' to 15247'. In Rate 2.8 bpm, Out Rate = 2.7 bpm, Loss Rate ~ 6
bph. In MM = 8.63 ppg, Out MM = 8.79 ppg. Circ pressure 3443 psi, ECD = 9.99 ppg. WOB = 3.0 -4.0 k, ROP = 30 - 70 fph. Continue drilling lateral from 15247'
to 15267'. In Rate 2.8 bpm, Out Rate = 2.7 bpm, Loss Rate ~ 6 bph. In MM = 8.63 ppg, Out MM = 8.78 ppg. Circ pressure 3493 psi, ECD = 9.97 ppg. WOB = 3.0 -
4.0 k, ROP = 30 - 70 fph. Drill past 15267' and returns drop to 1 bpm. PUH and monitor. Return slowly come back to over 2 bpm. Drill past and returns back to 2.5
bpm. Drill ahead from 15267'. In Rate 2.8 bpm, Out Rate = 2.5 bpm, Loss Rate ~ 20bph. In MM = 8.66 ppg, Out MM = 8.83 ppg. Circ pressure 3396 psi, ECD =
10.0 ppg. Drill to 15,420' and unable to move coil. Pump 10 bbl Hi/Lo sweep. In Rate 2.8 bpm, Out Rate = 2.6 bpm, Loss Rate ~ 12 bph. In MM = 8.47 ppg, Out
MM = 8.83 ppg. Circ pressure 3345 psi, ECD = 10.0 ppg. Pump 10 bbl Hi, 20 bbl LVT, 10 bbl Hi. Pump 5bbls LVT out and let soak.
10/4/2022 Continue circulating LVT out at 15365'. 15297' pulling heavy no WOB change, RIH is clean PUH. 15290' pulling heavy no WOB change, RIH is clean continue
PUH. 15208' pulling heavy 97k with -4.6k WOB, RIH is clean. PUH slow and pulled past, continue POOH until it cleans up. Pulling clean, RIH to increase AV's to
clean up behind us. 2x OH volume pumped RIH WT looks good. Reduce rate at 14950' to pass through shales down to TD. Tag at 15214' start of a 150api shale,
PU and RIH. Made it past but was a little ratty from 15207 - 15235'. Continue drilling lateral as per Geo dropping angle to find the OWC from 15415'. In Rate 2.8
bpm, Out Rate = 2.6 bpm, Loss Rate ~ 12 bph. In MM = 8.66 ppg, Out MM = 8.82 ppg. Circ pressure 3442 psi, ECD = 10.11 ppg. WOB = 2.0 -4.0 k, ROP = 30 -
60 fph. Continue drilling lateral as per Geo from 15535'. In Rate 2.9 bpm, Out Rate = 2.6 bpm, Loss Rate ~ 18 bph. In MM = 8.68 ppg, Out MM = 8.83 ppg. Circ
pressure 3442 psi, ECD = 10.19 ppg. WOB = 2.0 -4.0 k, ROP = 30 - 60 fph. Continue drilling lateral as per Geo from 15,600'. In Rate 2.8 bpm, Out Rate = 2.6
bpm, Loss Rate ~ 18 bph. In MM = 8.69 ppg, Out MM = 8.84 ppg. Circ pressure 3430 psi, ECD = 10.22 ppg. WOB = 2.0 -4.0 k, ROP = 30 - 60 fph. 15600' Geo's
hardline not to drill past. Continue drilling to 15625'. TD called at 15625'. Wiper Trip to window. 8k over pulls at 15283 & 15269' no WOB. Clean wiper to the
window, jog below window and pull through. Open EDC and pump at max rate and wash across WS tray. Circulate a bottoms up then POOH to surface. POOH at
2100' and choke plugging off. Blowdown choke and find large siltstone cuttings. Geo suspects from 15,210' - 15,270' area. Clear choke and continue POOH at max
rate. In Rate = 3.1 bpm, Out Rate = 2.7 bpm. In MM = 8.7 ppg, Out MM = 8.83 ppg OOH - Correct depth to 88.22'. Pump 10 bbls liner running pill with 1.5 ppb MI
Alpine Drilling Beads as trial for TerraPULSE agitator. Close EDC with 2 bbls to pump. Pump @ 2.8 bpm bead pill through TerraPULSE. Good test RIH with open
EDC pumping max rate. In Rate = 3.0 bpm, Out Rate = 3.4 bpm. In MM = 8.75 ppg, Out MM = 8.83 ppg. Circ pressure = 3082 psi Log Tie In from 12,850' at 5 fpm.
Correct -20.5' Log RA tag and confirm on depth. RIH to confirm TD. In Rate = .4 bpm, Out Rate = .5 bpm. In MM = 8.75 ppg, Out MM = 8.86 ppg. Circ pressure =
1448 Tag at 15,235' with 6k down in siltstone/fracture interval. Overpulls to 88k. PUH and build High Vis system for clean out. Work through 15,230' with HiVis
sweeps. Overpulls to 90k and stalling as we attempt to run past. PUH and clean OOH Continue to attempt to work through 15,200' with heavy overpulls and set
downs. Wiper trip to window to clean OOH. In Rate = 2.9 bpm, Out Rate = 2.8 bpm. In MM = 8.75 ppg, Out MM = 8.87 ppg. Circ pressure 4068 psi. Unable to move
coil at 15,195' with 90k overpulls.
10/5/2022 Pulled free, POOH to window circulating pills down to clean up the OH to the window. Jog below window then pull through. Choke packing off, bypass choke and
blow down Choke cleaned out, POOH chasing debris & pills to surface. Choke plugged off at 2140', RIH while lining up on bypass. Well unloading a lot of large and
small chunks of shale. RIH to 3000. (52°) and pump at max rate while POOH to surface. Flow check well, good no flow, blow down all return lines Remove the
injector and LD the BHA. BHA OOH Function test Annular, Blind Shears and 3" Combi's. Prep floor to MU Liner Top Billet BHA and MU BHA. BHA MU MWD RIH
with Liner Top Billet BHA. Up wt at 12900' is 57k. Pass window no issues. Tie-in depth from 13600' correct -18.5'. Close EDC. RIH mostly clean to 15212', start to
push. Push down to 15232' see +2.5k on DWOB ~4k surface wt. Pump off liner leave top billet 14413.46'. Up wt 53k. Dynamic flow check on bottom is good,
POOH Pull through window and up wt is 58k at 0.5 bpm, same as RIH wt check. Not clear from CT weight if liner is still on, RIH to confirm. Get up wt at 14390' =
58k DWOB -1k. RIH tag 14408' up wt 64k DWOB -4k. Pump off up wt now 55k, POOH. POOH pump 1.5/1.1 bpm well on slight losses ECD = 10.21# at window.
Pull through window, open EDC. Choke plugging, purge at 12900' continue POOH. Jog at 1600'. At surface, good no flow. Lift off injector and inspect 50' of CT. Flat
spot is seen with 43.7% wall loss (0.107" wall thickness vs. 0.190" new). L/D BHA. Cut off CT connector and 10' of CT to remove the flat spot. Dress CT and install
new connector.
10/6/2022 Continue MU up CTC. Pull test CTC to 50k, MU BHI UQC. MU Nozzle for testing BOPE. Close Swab to monitor well through MPD Line with continuous hole fill with
mud. PT Swab to 250 low and 3500 high, good PT. Displace coil and surface lines with freshwater. Grease Choke and stack valves Begin Bi-Weekly BOP Test as
per PTD 250 psi low and 3500 psi high. Test:1 IRV, Packoff C7, C9, C10, C11 - Pass. Test: 2 Blind / Shear, R2, BL2, C15 - Pass (#1 Ram close time 8 sec). Install
Test Joint. Test:3 (2-3/8") Annular, TIW#1, B1, B4 - Pass (Ann close time 8 sec). Test:4 Upper 2-3/8" Pipe / Slip, TIW#2, B2, B3 - Pass (#2 Ram close time 3 sec).
Test 5: Lower 2 3/8" Pipe/Slips, C5, C6, C8, TV2 - Pass (#4 Ram close time 3 sec). Test 6: Choke A, Choke C - Pass. Accumulator Drawdown Test - Pass. Test 7:
C1, C4, TV1 - Pass. Test Gas Alarms Test 8: 3" Pipe/Slips, C3, C3 - Pass (#3 Ram close time 3 sec). BOP test completed in 4.5-hrs, no failures. RD test equipment
and swap out risers Install BHI DFCV's and test connections, good PT. Stab on riser and PT the risers and DFCV's, good PT. Displace coil to drilling mud, open
swab well is full M/U BHA #8. Lateral / kickoff BHA with FVS and DBV. RIH BHA #7. Test Terra-Pulse at 200', working good at 2 bpm. Continue RIH. Tie-in depth
from 12875' correct -22'. Close EDC. Pass window 20L, 0 pump no issues. Pump 0.5 bpm through build, clean to billet. Light tag on billet at 14408', pick up and
repeat, same depth. Start pumps, start KO billet procedure from 14407' at 170R. Drill 1 ft/hr for 1 ft then 2 ft/hr. Stall at 14409.8' 2x up wt 62k clean. Time drill to
14410.5' then start pushing. Drill from 14411' at 10 ft/hr. 8.74 / 8.90 ppg In / Out. 2.84 / 2.79 bpm. Circ P 4150 - 4200 psi. Window ECD = 10.32 ppg. 14420' 5 bbls
lo / hi vis followed by new mud Drill to 14426' and pick up above billet at 0.5 bpm, clean. Dry drift back to bottom is clean, continue drilling. Drill from 14426' at 60-
70 ft/hr 2-3k DWOB. With new mud Circ P 3500 - 3700 psi. Window ECD = 9.97 ppg. Drill to 14550' Pull 100' wiper trip from 14550', clean pass up and down. Drill
from 14550'. 8.68 / 8.85 ppg In / Out. 2.78 / 2.85 bpm. Circ P 3500 - 3600 psi. Window ECD = 9.95 ppg.
10/7/2022 Differentially stuck on bottom at 14619'. Pull 2x to max WT with no movement. Shut down pump to relax the formation. Pull 2x to 100k with no movement. Pump 10
HV, 20 LVT, 10 HV Pumped 6 bbls out, shut down pump and negative WOB went to 0, PU and we are free. Stay close to bottom to circ out pills then chase up to
14450' just below the billet then RIH to continue drilling. Continue drilling ahead shallower at 14,610' (pipe stretch). In Rate 2.8 bpm, Out Rate = 2.8 bpm. In MM =
8.65 ppg, Out MM = 8.73 ppg. Circ pressure 3469psi, ECD = 8.99 ppg. WOB = 1 - 3.5 k, ROP = 30-60 fph. Drilled to 14615' and got stuck again, relax OH and
prep to pump LVT Pumps down for 20 min, pull 100k 2x with no movement. Pump 10 HV, 10 LVT, 10 HV. 5 bbls LVT out allow to soak. Pulled free, circ out
remaining LVT and chase OOH to the window to tie in. ~9' of pipe stretch from pulling heavy the first time and just pulled more so PUH to the window and tie in to
get on depth. Pulling a little heavy at 13,808'. Looks like we are cleaning up the heel of the build to the window Pump a HVP above the window, open the EDC and
circ a bottom's up while tying in. Correct depth +11'. Bottoms up fair amount of cuttings and a lot of aluminum. Close EDC and RIH to continue drilling. Set down at
12998' PU RIH with a bobble in WT but passed through. Clean pass through the billet Back on bottom drilling at 14622'. In Rate 2.8 bpm, Out Rate = 2.8 bpm. In
MM = 8.61 ppg, Out MM = 8.78 ppg. Circ pressure 3628 psi, ECD = 10.1 ppg. WOB = 1 - 3.5 k, ROP = 25-50 fph. Drilling is more consistent with better PU WT's.
Drilling lateral at 14700'. In Rate 2.7 bpm, Out Rate = 2.7 bpm. In MM = 8.63 ppg, Out MM = 8.79 ppg. Circ pressure 3602 psi, ECD = 10.15 ppg. WOB = 2 - 4.5 k,
ROP = 25-65 fph. Up wt 14734' is 61k clean. Frequent pickups. Drill from 14750' with frequent pickups, diff sticking. Pump 5 bbls lo / hi vis sweeps. Rate 2.7 / 2.7
bpm. 8.65 / 8.81 ppg In / Out. Circ pressure 3670 - 3800 psi. Window ECD = 10.20 ppg. Drill to 14850'. Pull 100' wiper trip from 14850', clean pass up and down.
Drill from 14850' with frequent pickups. Rate 2.7 / 2.7 bpm. 8.67 / 8.87 ppg In / Out. Circ pressure 3700 - 3950 psi. Window ECD = 10.29 ppg. 14900' pump 5 bbls
lo / hi vis. Drill to 14963'. Wt drill off at 14963'. Can't pick up, differentially stuck. Work pipe 3x to max wt, no movement. Pump 10 HV, 20 LVT, 10 HV. Pump 10
bbls out, shut down SI well. Work pipe, seeing DWOB change. Pump 2 more bbls out pulls free. Circ LVT and spacers out. Maintain 10.2# ECD at window. Wiper
trip to window. Jog below billet, pull past at 0.5 bpm nothing seen. Dragging from 13800 to 13700 slow pulling speed, do a jog. No indication of packoff. Turn
around and overpull, pump 5 bbls lo/hi vis sweeps. Continue RIH. Pick up 20 ft/min past 13800', weight slowly falls continue wiper trip. Jog below window and pull
through 0.5 bpm, nothing seen. Jog above window and open EDC. 10 bbls lo / hi vis. Circulate tubing 3.2 / 3.1 bpm. Tie-in depth correct +7'. Trap pressure and
purge MP choke with air. Close EDC. Pass window 20L, 0 pump nothing seen. Pump 0.5 bpm through build. RIH back to bottom, tag and drill from 14962'.
10/8/2022 Continue drilling lateral at 14975'. In Rate: 2.7, Out Rate: 2.7 bpm at 3740 psi. MW In: 8.67, MW Out: 8.84, Window ECD 10.3 ppg. ROP 50 - 75 ft/hr with 2-4k
WOB. IAP = 515 psi, OAP = 0 psi. Continue drilling lateral at 15175'. In Rate: 2.8, Out Rate: 2.6 bpm at 3698 psi. MW In: 8.70, MW Out: 8.92, Window ECD 10.48
ppg. ROP 50 - 105 ft/hr with 2-4k WOB. IAP = 515 psi, OAP = 0 psi. Continue drilling lateral at 15310'. In Rate: 2.7, Out Rate: 2.7 bpm at 3728 psi. MW In: 8.7,4
MW Out: 8.94, Window ECD 10.48 ppg. ROP 50 - 105 ft/hr with 2-4k WOB. IAP = 759 psi, OAP = 0 psi. Drilled 450' to 15400' wiper trip to window. Jog below the
billet and pull through. Jog below the window and pull through. Open EDC and wash across tray at max rate. Circ bottom up while tying in, correct depth +8. Close
EDC and RIH Continue RIH pass billet nothing seen. Reduce pump past troublesome siltstone and 45N shale. Near bottom Gen 1 goes down. Pull slow wiper with
reduced pump rate. Get Gen 1 going, continue trip to bottom. Drill from 15403' with frequent pickups. In Rate: 2.7, Out Rate: 2.7 bpm at 3720 - 3850 psi. MW In:
8.73, MW Out: 8.89, Window ECD 10.29 ppg. ROP 50 - 60 ft/hr with 2-3k WOB. IAP = 714 psi, OAP = 0 psi. 15460' pump 5 bbls lo / hi vis. TD called at 15461'.
Pull wiper to window. Reduce rate past troublesome siltstone. Jog below billet and pull past, nothing seen. Jog below window and pull through 20L, 0.5 bpm about
3k surface drag. Jog above window and open EDC. Clean pass to window. Pump 10 bbls lo / hi vis sweep. Jet whipstock tray. Wiper trip to surface 3.6 / 3.3 bpm.
Maintain 10.3# ECD at window. At 2100' start getting back coarse-grained materials. At 500' jog then tag stripper. Reset depth, RIH.
10/9/2022 Continue RIH from clean out to surface at 12,175'. Correct depth -23', bobble at the bottom of the window, clean pass through the billet. Set down at 14942, orient to
as drilled and passed through clean Tag at 15462, retag at same depth, Dynamic flow check well. Good FC, lost 0.8 bbls in 10 min, add beads to liner pill. Pump
liner pill followed by inhibited brine. POOH laying in liner pill, clean pass through billet. Lay in inhibited brine from 13250' to the window. Open EDC and displace
well to 9.8 brine. Good 9.8 brine at surface, shut down pumps and flow check well. Good no flow, well took 1 bbl in 10 min or 6 bph, POOH. Paint Yellow TD flag at
12688.24' (EOP = 12600.00'). Paint White Window Flag at 10188.24' (EOP = 10,100.00') OOH shut down pumps and flow check well. Good no flow, well took 0.8
bbls in 10 min or 4.8 bph. PU injector and LD the BHA. BHA OOH, bit grade = 1-1. Remove BHI UQC and boot Eline. MU 1 jt of 2-3/8" PH6, stab on well and pump
slack out. Pump out 287' of cable, records indicate about 172' cable could still be in reel. Get on well and pump forward again 4.3 bpm with 9.8# brine. 1' of
additional cable recovered. Will run enough PH6 to cover any remaining cable in the reel. Jet stack, get good LTT on SV and MV. LO/TO on Koomey Open MV and
use continuous hole fill while swapping out rams. Install Baker CTC, pull test to 50k good. Recharge Koomey. Fill stack and shell test, good. Test VBRs 250 / 3500
psi. 2-3/8" - Pass. 3-1/2" - Pass. Put drilling risers back on and PT, good. PT connector 4k, good. M/U swivel and ball catcher nozzle, get on well. Launch 7/8" ball
and pump it around. Ball is recovered. Rig up floor to run liner. Inspect and grease top drive. M/U liner as per approved summary.
10/10/2022 Continue running liner, on jt 43 of 68 2-7/8". Crew change - Verify joint count before continuing to run liner. Count is good, continue running liner filling pipe every
10 jts. Liner MU, MU upper BHA w/6 joints of 2-38" PH6. Upper BHA MU, correct depth to 2729.65', set pump trips at 500psi and RIH pumping at 0.5 bpm. Stop at
12,864.19' (Window Flag = 10,100) Liner & BHA length = 2729.65'. Correct depth to 12829.65', WT CK = 66k, RIH WT = 24k. Stop at 12950' and displace coil to
mud Coil displaced to mud, RIH to bottom of build and displace the liner and well back to drilling mud. Clean pass through the window, stop at 13250'. Online with
pump, 10 bbls above, PUH to the window and displace the well over to mud. Maintain 10.3# ECD while displacing. Well swapped to drilling mud, shut down pump
and get new WT's, PU Wt = 62k, RIH WT = 24k. Online at 0.3 bpm and RIH, not able to make it past 14680' with clean PU's, prep to pump LVT. Continue trying
working liner past 45N shale. Try different pump rates and running speeds. Mix hi vis spacers for LVT. Pump 10 HV 20 LVT 10 HV. Pump 5 LVT out shoe and
close choke, squeeze 1 bbl LVT ahead and try to work past. Can't work past 14682'. Unable to get past 45N shale at 14682' with various pump rates, RIH speed
and WHP. Solid tag each time at the same depth. POOH continue circ LVT to surface. Discuss with ODE will L/D liner and do a cleanout run. Pull through window
and circ LVT to surface. Prep pits to displace with 9.8#. Start inhibited 9.8# brine down CT. RIH to 13250'. Circ in 9.8# brine from 13250'. Pull through window and
pump 9.8# to surface. After 9.8# to surface 10 min flow check - good no flow. Fill well 0.4 bpm then POOH. Surface, 10 min flow check, good no flow. Break off
swivel slide injector back. L/D 6 jts PH6. L/D Liner running tools, 3-1/4" and 2-7/8" liner.
10/11/2022 Continue LD liner, LD the last 3-1/4" joint then let crews change out. Continue LD liner. Liner OOH, prep to pump slack back into the reel, heard good wire
movement. Remove CTC and RU the pipe cutter to cut 368' for 2% slack. Cut 368' and no wire, prep coil and MU CTC. Pull test CTC to 50k, good pull test. Head
up BHI UQC and install floats. PT CTC and UQC connection, good PT. Pump 1 circulation forward to move slack to the downhole end. Remove injector and MU the
clean out BHA RIH with clean out BHA pumping slack forward at 1.5 bpm. Start mud down CT. Tie-in depth from 12840' correct -24.5'.
Circ mud to surface max rate keep ECD < 10.5# Close EDC, pass window 20L, 0 pump nothing seen. Keep 10.3# ECD while doing cleanout. RIH clean through
build and lateral. Wt check at 14000' is 56k clean. Pass billet 0 pump, 170R nothing seen. Wt check at 14600' is 56k clean. Go to 2.5 bpm 5 ft/min to ease past 45N
shale as drilled TF. Tag 14696' and push through pump 5 bbls lo / hi vis. Tag 14716' up wt 61k. Work past 45N continue RIH. Wt check 14900' is 58k clean. Tag
TD 15462' Wiper trip above 45N shale. Overpull at 15060' nothing on DWOB. RIH and work pipe, pull past. Pump 5 bbls lo / hi vis
Continue wiper, overpull at 14996'. RIH and pull through clean. Clean up pass through 45N at 2.8 bpm. RIH from 14550' at 1 bpm to test 45N pass through. Clean
pass to 14750', one TF bobble. POOH. Continue wiper to window. Jog below window and pull through. Jog above window and open EDC. Pump 10 bbls lo / hi vis
around to surface to clean tubing. Follow with 9.8# inhibited brine. Close EDC and RIH to 13250' lay in 9.8#. Pull through window and jog, open EDC. Jet whipstock
tray. Circ 9.8# to surface. With 9.83 at surface, 10 min flow check - good no flow. POOH flag pipe at 12600' and 10100' (EOP).
10/12/2022 Continue POOH with cleanout BHA. Flow check and lay down BHA Remove UQC. Boot e-line. Pickup and install joint of 2-3/8" PH6. Performed weekly BOPE
function test. Pump slack out of reel. Recovered 352' of e-line. Installed nozzle. Pump 7/8" drift ball. Recovered ball. Verified liner running with Team. Make up
sacrificial motor and 4-125" x 3.75" BOT BiCenter bit. 5K burst sub, and shoe track. Blue Loctite shoe track and first two joints. 52 joints of 67 ran of 2-7/8" Liner.
Continue M/U liner. During MU 3-1/4" conduct D1 drill and following AAR with McGrath crew. Well is secured in 3 min 30 sec. Continue MU liner. MU deployment
sleeve + 6 jts PH6 Skid injector over, partially displace CT with mud off the well. Fill liner again. Make up XO to PH6, MU swivel. MU injector. Circ a liner volume
near surface then RIH, pump 0.25 bpm. Stop at first flag correct -27.2' to 12823'. RIH to window. Up wt at window is 62k. Pump 5 bbls mud out shoe then RIH
through window. Pass window 0 pump nothing seen. Pump 0.5 bpm through build clean pass. Pump 1.0 bpm through lateral. Start adding WHP as mud comes up
backside. Weight bobbles 14687' (45N), 14750', 14900' Tag 15110' up wt 63k. Push past continue RIH. Work liner past 15080'. Go to 2 bpm try various running
speeds. Work down to 15456' solid tag. Pick up and repeat, same depth. Up wt 75k. Get reel into ball drop position, establish circulation 2.5 bpm / 5400 psi.
10/13/2022 PJSM for releasing from liner. Verify ball size. 3/4" Ball. Load and launch. Slow pump rate to 1 bpm. Ball didn't land on volume. Surge. No Luck. Pick liner up 50' off
bottom. Rih and tag. Surge. Ball landed. Sheared at 4200#. Pick up to verify released from liner twice. Circulate well over to 1% SL KCL w/ safelube. Rate in: 1.9
bpm, Rate out: 1.9 bpm. MW in: 8.45 ppg, MW out 8.50 ppg. Pump 15 bbls FW to calibrate cement micro motion. Pump forward while offloading fluids and
prepping pits for cement job. PJSM for pumping liner cement job. Cementer push 3 bbls FW to coil. Cementers PT to 5000#. Good test. Cement wet: 13:00. Load
reel with 32.2 bbls of 15.3 ppg cement. Chase with 1.5 ppb Powervis exhaust pill with Lube776. Zero out MM and take to dedicated pit at 83.0 bbls away. Shut
down at 96.6 bbls away (13.7 bbls behind pipe). Launch Pee wee dart. PT to 1500 over. Pick up to pressure drop. Exhaust 3.7 bbls cement. Open pump bleeds
and set back down. Pressure up to 2000#. Zero In MM. Pressure up to shear wiper plug. Went at 4700#. Pump at 1.0 bpm @ 3500 to 3800#. Wiper plug landed at
15.4 bbls away. (15.4 bbls calc). Bleed down and check floats. Floats good. Cement in place 14:52. Pressure up to 2000 psi. PU to pressure drop. Immediately
come online at 3.0 bpm for 20 bbls. Slowly un-sting from liner top. Pull at 10' min up to were cement could of come at ~12000'. At 112 bbls returned. Density as
high as ~10.8. Stop. Paint blue flag (12127.6' CEOP) Take liner of depth. POOH pump 2.9 / 2.4 bpm. Tag stripper, good no flow. LD 6 jts of 2-3/8" PH6. LD liner
running tools, recover 3/4" ball. Tools have functioned normally. Cut 17' of e-line and boot. MU nozzle for jetting stack. Jet stack, flush and inspect dead legs for
cement residue. PT hardline that was inspected. Lift off well, remove nozzle. Bring TCP toolboxes to floor and RU floor to run perf guns. Review gun layout with
TCP rep. PJSM with TCP crew and rig crew. MU perf guns. MU 80 jts 1-1/4" CSH, drift and rattle each jt. Stop at 40 jts MU and circ through string. Continue MU 1-
1/4" CSH.
10/14/2022 MU remaining 2 joints of 1-1/4" CSH. DFCV, Disconnect (3/4" ball). (2) 2-3/8" PH6. Clear rig floor. Blow down standpipe. Stab injector. Circulate surface to surface.
Rih with perf guns. Rate in: 0.6 bpm, Rate out: 1.0 bpm. MW in: 8.34 ppg, MW out: 8.45 ppg. PUW 52K / RIH 25K @ 12900' MD. PUW 64K / RIH 24K @ 15355'
MD. Tag PBTD at 15454' MD multiple times. Breakover at 15445' Multiple times. PU shy of breakover. Correct depth to bottom shot of 15431.11'. PUH to bottom
shot depth of 15165'. Bring wellhead up to 1000 psi. Liner lap slowly bleeding off. Fail. Perform pump commands down CT x T Annulus. Hold 350 psi. Small
pressure drop indication of guns firing. Break circulation down coil. Well losing fluid. Increase circulation to catch fluid. Put well on 200 psi choke. Pooh circulating
clean 1% KCL w/ 0.6% safelube in. Interval 14990' - 15165'. Stop above liner top at 12900' MD. Bleed choke pressure off. Perform 10 min flow check. Well losing
2.5 bph. Pooh. Circulating clean 1% KCL in. Perform 1000' jog once at 100'. Pooh and tag up. Perform 10 min flow check. Good. Lift injector off, skid back. LD 2 jts
2-3/8" PH6, 80 jts 1-1/4" CSH to marker pup. Fill every 30 min. PJSM with TCP and Nabors crew for LD perf guns. LD 9 perf guns, all shots fired. Top 4' of shots
don't line up with the gun scallops, rest are ok. Clean and clear rig floor. Offload perf guns and handling equipment. Spot in rig up LRS for freeze protect. MU nozzle
+ DBPV for freeze protect. MU injector to well. RIH with freeze protect BHA to 2500'. Load reel with diesel followed by MeOH. Lay in diesel from 2500 MeOH across
stack. Tag stripper, close MV, SSV. Circ remaining FP fluid out to tiger tank.
10/15/2022 Complete circulation out to tiger tank. PT SSV / MV to 3400#. Good test. Break off. Pull DFCV off. Reverse circulate slack into reel with freshwater. RU hydraulic
cutter. Cut 360' of pipe to accomplish 2.0% slack. Dress coil for coil connector. Install coil connector. Pull test to 50K. Good Install 5' stinger / Nozzle. Pump e-line
forward for UQC. BHI MU UQC w/o floats. Begin locking out Koomey for ram swap. Swap rams from Variables to 3" Pipe / Slip. Shell test door seal breaks to 3800#.
No leaks. Begin blowing down rig. Vac stack out down to SSV. Remove MPD line. Install original IA, OA gauges. Remove BOPs Install tree cap, pump MeOH into
MPD line out tree cap. PT tree cap 3500 psi, good. Complete RDMO checklists. Purge steam lines. Secure BOP stack.
10/16/2022 Break connections in interconnect. Release rig at 02:00.
WELL NAME
Date :
Shoe @ :FC @ :Top Liner @ :
Type:
Type :
Type :
Type :
Type :
x Yes No
Yes X No Yes X No
x Yes No x Yes No
Date :
Volume lost during displacement (bbls) : 1.00
Remarks:
Cement In Place At : 14:52 10/13/2022 Estimated TOC : 12,941
Method Used To Determine TOC : Calculated
4500
Casing Rotated? Reciprocated? % Returns during job : 100
Cement returns to surface? Spacer returns? Vol to Sur : 125
FCP (psi) : 4200 Pump used for disp : GD Plug Bumped? Bump press :
Volume : 85
Displacement :
1.5 ppb Geovis Density (ppg) : 8.34 Rate (bpm) : 1.5 Volume (actual / calculated) : 15.4 / 15.4
Post Flush (Spacer)
1.5 ppb Geovis Density (ppg) : 8.34 Rate (bpm) : 3
Yield : Sacks : Mixing / Pumping Rate (bpm) :
Tail Slurry
Volume (bbls) : Density (ppg) :
Lead Slurry
FI
R
S
T
S
T
A
G
E
15462 15435 / 15445 12941
Preflush (Spacer)
1% KCL Density (ppg) : 8.4 Volume pumped (bbls) : 250
PBU W-06B CEMENT REPORT
14-Oct-22 Hole Size :4.25 Casing Size :3-1/2 x 3-1/4 x 2-7/8
Class G Volume (bbls): 32.2 Density (ppg) :15.3
Yield : 1.63 Sacks : 110 Mixing / Pumping Rate (bpm) : 1.5
1
Regg, James B (OGC)
From:Brooks, Phoebe L (OGC)
Sent:Wednesday, October 26, 2022 4:55 PM
To:Mark Igtanloc
Cc:Regg, James B (OGC)
Subject:RE: Nabors CDR2SAC 10-6-22 10-424 Form
Attachments:Nabors CDR2AC 10-06-22 Revised.xlsx
Mark,
Attached is a revised report, changing the formatting for PTD #2220990, removing the sundry # from this drilling report,
and changing the test type to initial as this is the first drilling report for W‐06B. I also moved the bottle precharge 1045
to the remarks. Please update your copy.
Thank you,
Phoebe
Phoebe Brooks
Research Analyst
Alaska Oil and Gas Conservation Commission
Phone: 907‐793‐1242
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas
Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential
and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you
are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the
mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov.
From: Mark Igtanloc <Mark.Igtanloc@hilcorp.com>
Sent: Friday, October 7, 2022 4:39 PM
To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>;
Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>
Cc: Alaska NS ‐ CTD DSM <AlaskaNS‐CTD‐DSM@hilcorp.com>
Subject: Nabors CDR2SAC 10‐6‐22 10‐424 Form
All,
Attached is the bi‐weekly BOP Test Form for W‐06B
Mark Igtanloc
Sr. Drilling Foreman – CTD
Rig (907) 670‐3097
Cell (907) 268‐9140
Positional Email AlaskaNS‐CTD‐DSM@hilcorp.com
Alternate: John Perl
Hilcorp Alaska, LLC
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.
PBU W-06B
PTD 2220990
2
The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named
above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this
email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed
above, then promptly and permanently delete this message.
While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission,
opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and
the recipient should carry out such virus and other checks as it considers appropriate.
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
*All BOPE reports are due to the agency within 5 days of testing*
Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov
Rig Owner:Rig No.:CDR2AC DATE:10/6/22
Rig Rep.:Rig Email:
Operator:
Operator Rep.:Op. Rep Email:
Well Name:PTD #2220990 Sundry #
Operation:Drilling:X Workover:Explor.:
Test:Initial:X Weekly:Bi-Weekly:Other:
Rams:250 /3500 Annular:250 /3500 Valves:250 /3500 MASP:2644
MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES:
Test Result/Type Test Result Quantity Test Result
Housekeeping P Well Sign P Upper Kelly 0 NA
Permit On Location P Hazard Sec.P Lower Kelly 0 NA
Standing Order Posted P Misc.NA Ball Type 2 P
Test Fluid Water Inside BOP 0 NA
FSV Misc 0 NA
BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm
Stripper 1 2-3/8"P Trip Tank P P
Annular Preventer 1 7-1/16" GK P Pit Level Indicators P P
#1 Rams 1 Blind / Shear P Flow Indicator P P
#2 Rams 1 2-3/8" Pipe / Slip P Meth Gas Detector P P
#3 Rams 1 3" Pipe / Slip P H2S Gas Detector P P
#4 Rams 1 2-3/8" Pipe / Slip P MS Misc 0 NA
#5 Rams 0 NA
#6 Rams 0 NA ACCUMULATOR SYSTEM:
Choke Ln. Valves 1 2-1/16"P Time/Pressure Test Result
HCR Valves 2 2-1/16"P System Pressure (psi)2950 P
Kill Line Valves 1 2-1/16"P Pressure After Closure (psi)2250 P
Check Valve 0 NA 200 psi Attained (sec)19 P
BOP Misc 2 2.0" Piper P Full Pressure Attained (sec)50 P
Blind Switch Covers:All stations Yes
CHOKE MANIFOLD:Bottle Precharge:P
Quantity Test Result Nitgn. Bottles # & psi (Avg.):10 & 1950 P
No. Valves 12 P ACC Misc 0 NA
Manual Chokes 1 P
Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result
CH Misc 0 NA Annular Preventer 8 P
#1 Rams 8 P
Coiled Tubing Only:#2 Rams 3 P
Inside Reel valves 1 P #3 Rams 3 P
#4 Rams 3 P
Test Results #5 Rams 0 NA
#6 Rams 0 NA
Number of Failures:0 Test Time:4.5 HCR Choke 1 P
Repair or replacement of equipment will be made within NA days. HCR Kill 1 P
Remarks:
AOGCC Inspection
24 hr Notice Yes Date/Time 10/6/22 06:13
Waived By
Test Start Date/Time:10/6/2022 9:30
(date)(time)Witness
Test Finish Date/Time:10/6/2022 14:00
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Austin McLeod
Nabors
Test all rams & Valves to 250 psi low and 3500 psi high, no failures. Bottle precharge 1045 psi.
N.W heeler / W. Williams
Hilcorp
M.Igtanloc / T. Kavanagh
PBU W-06B
Test Pressure (psi):
nathan.wheeler@naabors.com
AlaskaNS-CTD-DSM@hilcorp.com
Form 10-424 (Revised 08/2022)2022-1006_BOP_Nabors_CDR2AC_PBU W-06B
======Hilcorp North Slope LLC
J. Regg; 11/28/2022
From:Regg, James B (OGC)
To:AOGCC Records (CED sponsored)
Subject:BOP - Nabors CDR2AC
Date:Monday, November 28, 2022 11:32:53 AM
Attachments:2022-1006_BOP_Nabors_CDR2AC_PBU W-06B.pdf
PBU W-06B (PTD 2220990)
Jim Regg
Supervisor, Inspections
AOGCC
333 W. 7th Ave, Suite 100
Anchorage, AK 99501
907-793-1236
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STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
*All BOPE reports are due to the agency within 5 days of testing*
SSu b m i t t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov
Rig Owner: Rig No.:CDR2AC DATE: 10/9/22
Rig Rep.:Rig Email:
Operator:
Operator Rep.: Op. Rep Email:
Well Name:PTD #2220990 Sundry #N/A
Operation: Drilling: X Workover: Explor.:
Test: Initial: Weekly: Bi-Weekly: Other: X
Rams:250 /3500 Annular:N/A Valves:N/A MASP:2644
MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES:
Test Result/Type Test Result Quantity Test Result
Housekeeping P Well Sign P Upper Kelly 0NA
Permit On Location P Hazard Sec.P Lower Kelly 0NA
Standing Order Posted P Misc.NA Ball Type 2NA
Test Fluid Water Inside BOP 0NA
FSV Misc 0NA
BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm
Stripper 1 2-3/8"NA Trip Tank NA NA
Annular Preventer 1 7-1/16" GK NA Pit Level Indicators NA NA
#1 Rams 1 Blind / Shear NA Flow Indicator NA NA
#2 Rams 1 2-3/8" Pipe / Slip NA Meth Gas Detector NA NA
#3 Rams 1 2-3/8" x 3-1/2" VBR P H2S Gas Detector NA NA
#4 Rams 1 2-3/8" Pipe / Slip NA MS Misc 0NA
#5 Rams 0NA
#6 Rams 0NAACCUMULATOR SYSTEM:
Choke Ln. Valves 1 2-1/16"NA Time/Pressure Test Result
HCR Valves 2 2-1/16"NA System Pressure (psi)NA
Kill Line Valves 1 2-1/16"NA Pressure After Closure (psi)NA
Check Valve 0NA200 psi Attained (sec)NA
BOP Misc 2 2.0" Piper NA Full Pressure Attained (sec)NA
Blind Switch Covers: All stations Yes
CHOKE MANIFOLD:Bottle Precharge:NA
Quantity Test Result Nitgn. Bottles # & psi (Avg.):NA
No. Valves 12 NA ACC Misc NA
Manual Chokes 1NA
Hydraulic Chokes 1NA Control System Response Time:Time (sec) Test Result
CH Misc 0NA Annular Preventer NA
#1 Rams NA
Coiled Tubing Only:#2 Rams NA
Inside Reel valves 1NA #3 Rams NA
#4 Rams NA
Test Results #5 Rams NA
#6 Rams NA
Number of Failures:0 Test Time:1.5 HCR Choke NA
Repair or replacement of equipment will be made within NA days. HCR Kill NA
Remarks:
AOGCC Inspection
24 hr Notice No Date/Time 10/9/22 03:46
Waived By
Test Start Date/Time:10/9/2022 22:30
(date) (time)Witness
Test Finish Date/Time:10/10/2022 0:00
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Lou Laubenstein
Nabors
This was single ram test. We removed the 3" Pipe / Slip rams and installed 2-3/8" x 3-1/2" VBRs. We then tested the VBRs with
a 2-3/8" and a 3-1/2" test joint.
R. Coyne / W. Williams
Hilcorp
M. Igtanloc / T. Kavanagh
PBU W-06B
Test Pressure (psi):
robert.coyne@nabors.com
AlaskaNS-CTD-DSM@hilcorp.com
Form 10-424 (Revised 08/2022) 2022-1009_BOP_Nabors_CDR2AC_ram-change_PBU_W-06B
1RUWK6ORSH//&9
9
9
9
9
9
9
9
9
-5HJJ
removed the 3" Pipe / Slip rams and installed 2-3/8" x 3-1/2" VBRs.
From:Regg, James B (OGC)
To:AOGCC Records (CED sponsored)
Subject:BOP - Nabors CDR2AC Ram Change
Date:Wednesday, November 16, 2022 4:46:51 PM
Attachments:2022-1009_BOP_Nabors_CDR2AC_ram-change_PBU_W-06B.pdf
PBU W-06B (PTD 2220990)
Jim Regg
Supervisor, Inspections
AOGCC
333 W. 7th Ave, Suite 100
Anchorage, AK 99501
907-793-1236
From:Davies, Stephen F (OGC)
To:Carlisle, Samantha J (OGC)
Cc:Rixse, Melvin G (OGC)
Subject:FW: Sidetrack W-06B (222-099)
Date:Thursday, October 6, 2022 4:48:46 PM
Sam,
Please include a copy of the email below in this well history record.
Thanks and stay safe,
Steve
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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov.
From: Rixse, Melvin G (OGC)
Sent: Thursday, October 6, 2022 2:41 PM
To: Sean McLaughlin <Sean.Mclaughlin@hilcorp.com>
Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Boyer, David L (OGC)
<david.boyer2@alaska.gov>
Subject: RE: Sidetrack W-06B (222-099)
Sean,
Thanks for the notice.
Mel Rixse
Senior Petroleum Engineer (PE)
Alaska Oil and Gas Conservation Commission
907-793-1231 Office
907-297-8474 Cell
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 Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov).
From: Sean McLaughlin <Sean.Mclaughlin@hilcorp.com>
Sent: Thursday, October 6, 2022 11:19 AM
To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>
Cc: Joseph Lastufka <Joseph.Lastufka@hilcorp.com>
Subject: Sidetrack W-06B (222-099)
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.
Mel,
CDR2 will be sidetracking W-06B due hole stability concerns. The well was drilled to a TD of 15,625’
and a shale ~15,200’ became troublesome during the final cleanout run. A liner top billet was run
and placed at 14,413’. The sidetrack will attempt to stay below the problematic shale.
Regards,
sean
Sean McLaughlin
Hilcorp Alaska, LLC
Drilling Engineer
Sean.McLaughlin@hilcorp.com
Cell: 907-223-6784
The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby
notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please
immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete
this message.
While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the
onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility
is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate.
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:Rixse, Melvin G (OGC)
To:AOGCC Records (CED sponsored)
Subject:20221005 1600 APPROVAL to POP under eval 30 days W-06B (PTD# 222-099)
Date:Wednesday, October 5, 2022 4:04:16 PM
Attachments:image001.png
From: Rixse, Melvin G (OGC)
Sent: Wednesday, October 5, 2022 4:02 PM
To: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>
Cc: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>
Subject: RE: W-06B (PTD# 222-099) request to POP Under eval with TxIA communication for 30 days
Oliver,
Hilcorp is approved to POP W-06B (PTD222-099) under eval for 30 days.
Mel Rixse
Senior Petroleum Engineer (PE)
Alaska Oil and Gas Conservation Commission
907-793-1231 Office
907-297-8474 Cell
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 Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov).
From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>
Sent: Wednesday, October 5, 2022 3:15 PM
To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>
Cc: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>
Subject: W-06B (PTD# 222-099) request to POP Under eval with TxIA communication for 30 days
Mel,
CDR-2 is currently drilling a coil sidetrack on what will be W-06B (PTD# 222-099). The well was recently worked over in June with
new 4-1/2” 13CR tubing. The well passed an MIT-IA to 2500 psi on 6/4/22 and CMIT-TxIA to 2500 psi on 6/5/22 on rig but failed an
initial MIT-T to 3500 psi with a low but consistent leak-off rate of ~75psi/15min.
A post rig acoustic leak detect log found 2 small tubing thread leaks in collars at 2394’ MD and 8373’ MD. Subsequent MIT-Ts and
MIT-IAs showed similar 75 psi/15min leak-off regardless of direction of testing. We had an additional passing CMIT-TxIA up to 3500
psi on 8/26/22. Our long-term plan is to install two tubing patches over these thread leaks and obtain a passing MIT-T.
In the near term, CDR-2 is currently wrapping up drilling of W-06B lateral. They have experienced higher than expected losses and
logged high resistivity mid liner than expected. They are currently only planning to shoot 200ft of the lateral. We would like to then
POP the well under eval for 30 days and perform additional CBL and RPM logging before submitting a sundry and returning to
extended perforate an additional 200-700’ of the lateral. We would like to hold off on setting the two tubing patches until after this
UE period to maximize the usable ID of the wellbore for coil access for perforating or if any liner squeeze work is identified.
Gas lift will be needed for the Under Eval period.
Thanks,
Oliver Sternicki
Hilcorp Alaska, Hilcorp North Slope LLC
Well Integrity Engineer
Office: (907) 564 4891
Cell: (907) 350 0759
Oliver.Sternicki@hilcorp.com
The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are notan intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have
received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this
message.
While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of thismessage and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus
and other checks as it considers appropriate.
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
Monty M. Myers
Drilling Manager
Hilcorp North Slope, LLC
3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU W-06B
Hilcorp North Slope, LLC
Permit to Drill Number: 222-099
Surface Location: 1367' FNL, 1193' FEL, Sec. 21, T11N, R12E, UM, AK
Bottomhole Location: 1183' FSL, 310' FEL, Sec. 27, T11N, R12E, UM, AK
Dear Mr. Myers:
Enclosed is the approved application for the permit to drill the above referenced well.
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well
logs run must be submitted to the AOGCC within 90 days after completion, suspension, or
abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first.
This permit to drill does not exempt you from obtaining additional permits or an approval required
by law from other governmental agencies and does not authorize conducting drilling operations
until all other required permits and approvals have been issued. In addition, the AOGCC reserves
the right to withdraw the permit in the event it was erroneously issued.
Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska
Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply
with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code,
or an AOGCC order, or the terms and conditions of this permit may result in the revocation or
suspension of the permit.
Sincerely,
Jessie L. Chmielowski
Commissioner
DATED this ___ day of August, 2022. 4
Jessie L.
Chmielowski
Digitally signed by Jessie L.
Chmielowski
Date: 2022.08.04 16:37:59
-08'00'
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8325
8550
8775
9000
9225True Vertical Depth (450 usft/in)7200 7425 7650 7875 8100 8325 8550 8775 9000 9225 9450 9675 9900 10125 10350
Vertical Section at 142.33° (450 usft/in)
W-06B wp04 Tgt2
W-06B wp04 Tgt1
W-06B wp04 Tgt3
W-06B wp04 Tgt6
W-06B wp04 Tgt7
W-06B wp04 Tgt8W-06B wp04 Tgt4
W-06B wp04 Tgt5
W-06B wp04 Tgt9
W-06B wp04 geopolygon
1 1 0 0 0
1150012000125001300013455W-061100011500
1 2 0 0 0
1 2 5 0 0
1 3 0 0 0
1 3 4 2 5W-06A
2 7/8" x 4 1/4"
1 3 0 0 0
135001400014500150001550015988W-06B wp04KOP : Start Dir 9º/100' : 12987' MD, 8823.76'TVD : 20° LT TFStart Dir 35º/100' : 13007' MD, 8842.64'TVDStart Dir 12º/100' : 13397.72' MD, 8925.79'TVDTotal Depth : 15987.94' MD, 9002.76' TVDHilcorp North Slope, LLC
Calculation Method:Minimum Curvature
Error System:ISCWSA
Scan Method: Closest Approach 3D
Error Surface: Ellipsoid Separation
Warning Method: Error Ratio
WELL DETAILS: Plan: W-06
Ground Level: 53.06
+N/-S +E/-W
Northing Easting Latitude Longitude
0.00 0.00 5958890.13 612048.90 70° 17' 47.876 N 149° 5' 33.544 W
SURVEY PROGRAM
Date: 2022-05-09T00:00:00 Validated: Yes Version:
Depth From Depth To Survey/Plan Tool
101.06 3001.06 W-06 Srvy 1 GCT MS (W-06PB1) 3_Gyro-CT_pre-1998_Csg
3101.06 10701.06 W-06 Srvy 1 GCT MS (W-06) 3_Gyro-CT_pre-1998_Csg
10772.00 12884.00 W-06A Srvy 1 MWD (W-06A) 3_MWD
12926.59 12987.00 W-06A Srvy 2 EMS (W-06A) 3_EMS
12987.00 15987.94 W-06B wp04 (Plan: W-06B) 3_MWD
FORMATION TOP DETAILS
No formation data is available
REFERENCE INFORMATION
Co-ordinate (N/E) Reference:Well Plan: W-06, True North
Vertical (TVD) Reference:KB @ 82.76usft (W-06A)
Measured Depth Reference:KB @ 82.76usft (W-06A)
Calculation Method: Minimum Curvature
Project:Prudhoe Bay
Site:W
Well:Plan: W-06
Wellbore:Plan: W-06B
Design:W-06B wp04
CASING DETAILS
TVD TVDSS MD Size Name
9002.76 8920.00 15987.94 2-7/8 2 7/8" x 4 1/4"
SECTION DETAILS
Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation
1 12987.00 18.38 209.92 8823.76 -6896.03 3782.03 0.00 0.00 7769.86 KOP : Start Dir 9º/100' : 12987' MD, 8823.76'TVD : 20° LT TF
2 13007.00 20.08 208.13 8842.64 -6901.79 3778.84 9.00 -20.00 7772.47 Start Dir 35º/100' : 13007' MD, 8842.64'TVD
3 13222.72 90.00 164.93 8961.69 -7062.58 3791.28 35.00 -45.00 7907.35
4 13397.72 111.75 106.11 8925.79 -7181.14 3902.96 35.00 -65.00 8069.44 Start Dir 12º/100' : 13397.72' MD, 8925.79'TVD
5 13582.72 111.56 130.02 8856.65 -7261.31 4053.26 12.00 86.00 8224.75
6 13792.72 86.36 130.02 8824.19 -7393.64 4210.84 12.00 -180.00 8425.79
7 13942.72 86.54 148.06 8833.55 -7506.23 4308.57 12.00 90.00 8574.63
8 14092.72 96.87 133.29 8829.07 -7621.76 4403.16 12.00 -55.00 8723.88
9 14300.65 90.00 109.24 8816.44 -7728.48 4579.24 12.00 -105.00 8915.96
10 14375.65 89.53 118.23 8816.75 -7758.64 4647.83 12.00 93.00 8981.74
11 14555.65 69.30 110.49 8849.70 -7831.55 4807.88 12.00 -160.00 9137.25
12 14755.65 91.25 100.59 8883.35 -7883.43 4996.54 12.00 -25.00 9293.60
13 14905.65 100.90 85.29 8867.40 -7891.23 5144.87 12.00 -57.00 9390.41
14 15155.65 85.31 111.04 8853.68 -7926.69 5389.08 12.00 120.00 9567.71
15 15315.65 76.64 93.68 8878.94 -7960.63 5542.61 12.00 -118.00 9688.38
16 15447.83 92.50 93.68 8891.41 -7969.04 5673.50 12.00 0.00 9775.02
17 15522.83 92.47 84.67 8888.16 -7967.96 5748.35 12.00 -90.00 9819.90
18 15622.83 92.42 96.68 8883.88 -7969.13 5848.07 12.00 90.00 9881.76
19 15987.94 48.60 96.68 9002.76 -8008.19 6181.65 12.00 180.00 10116.52 W-06B wp04 Tgt9 Total Depth : 15987.94' MD, 9002.76' TVD
-9675
-9450
-9225
-9000
-8775
-8550
-8325
-8100
-7875
-7650
-7425
-7200
-6975
-6750
South(-)/North(+) (450 usft/in)3150 3375 3600 3825 4050 4275 4500 4725 4950 5175 5400 5625 5850 6075 6300
West(-)/East(+) (450 usft/in)
W-06B wp04 geopolygon
W-06B wp04 Tgt9
W-06B wp04 Tgt5
W-06B wp04 Tgt4
W-06B wp04 Tgt8
W-06B wp04 Tgt7
W-06B wp04 Tgt6
W-06B wp04 Tgt3
W-06B wp04 Tgt1
W-06B wp04 Tgt2
8 5 0 0
8 75 0
9 0 0 0
9 1 7 6
W-06
82
5
0
8500
8750
9245
W-06A
2 7/8" x 4 1/4"9003W-06B wp04
KOP : Start Dir 9º/100' : 12987' MD, 8823.76'TVD : 20° LT TF
Start Dir 35º/100' : 13007' MD, 8842.64'TVD
Start Dir 12º/100' : 13397.72' MD, 8925.79'TVD
Total Depth : 15987.94' MD, 9002.76' TVD
CASING DETAILS
TVD TVDSS MD Size Name
9002.76 8920.00 15987.94 2-7/8 2 7/8" x 4 1/4"
Project: Prudhoe Bay
Site: W
Well: Plan: W-06
Wellbore: Plan: W-06B
Plan: W-06B wp04
WELL DETAILS: Plan: W-06
Ground Level: 53.06
+N/-S +E/-W Northing Easting Latitude Longitude
0.00 0.00 5958890.13 612048.90 70° 17' 47.876 N 149° 5' 33.544 W
REFERENCE INFORMATION
Co-ordinate (N/E) Reference:Well Plan: W-06, True North
Vertical (TVD) Reference: KB @ 82.76usft (W-06A)
Measured Depth Reference:KB @ 82.76usft (W-06A)
Calculation Method:Minimum Curvature
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0.001.002.003.004.00Separation Factor13125 13300 13475 13650 13825 14000 14175 14350 14525 14700 14875 15050 15225 15400 15575 15750 15925 16100 16275Measured Depth (350 usft/in)W-06AW-05AW-07W-07ANo-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.WELL DETAILS:Plan: W-06 NAD 1927 (NADCON CONUS)Alaska Zone 04Ground Level: 53.06+N/-S +E/-W Northing EastingLatitudeLongitude0.000.005958890.13612048.9070° 17' 47.876 N149° 5' 33.544 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: W-06, True NorthVertical (TVD) Reference: KB @ 82.76usft (W-06A)Measured Depth Reference:KB @ 82.76usft (W-06A)Calculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2022-05-09T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool101.06 3001.06 W-06 Srvy 1 GCT MS (W-06PB1) 3_Gyro-CT_pre-1998_Csg3101.06 10701.06 W-06 Srvy 1 GCT MS (W-06) 3_Gyro-CT_pre-1998_Csg10772.00 12884.00 W-06A Srvy 1 MWD (W-06A) 3_MWD12926.59 12987.00 W-06A Srvy 2 EMS (W-06A) 3_EMS12987.00 15987.94 W-06B wp04 (Plan: W-06B) 3_MWD0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)13125 13300 13475 13650 13825 14000 14175 14350 14525 14700 14875 15050 15225 15400 15575 15750 15925 16100 16275Measured Depth (350 usft/in)GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference12987.00 To 15987.94Project: Prudhoe BaySite: WWell: Plan: W-06Wellbore: Plan: W-06BPlan: W-06B wp04CASING DETAILSTVD TVDSS MD Size Name9002.76 8920.00 15987.94 2-7/8 2 7/8" x 4 1/4"
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