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MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Friday, September 1, 2023
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Adam Earl
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
Hilcorp North Slope, LLC
W-40A
PRUDHOE BAY UNIT W-40A
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 09/01/2023
W-40A
50-029-21776-01-00
222-103-0
W
SPT
8360
2221030 2090
1344 1343 1343 1344
0 0 0 0
INITAL P
Adam Earl
7/11/2023
Initial MIT-IA Tested as per Sundry 323-100 post conversion
30 MinPretestInitial15 Min
Well Name
Type Test
Notes:
Interval P/F
Well
Permit Number:
Type Inj TVD
PTD Test psi
API Well Number Inspector Name:PRUDHOE BAY UNIT W-40A
Inspection Date:
Tubing
OA
Packer Depth
1080 2349 2270 2248IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitAGE230714082959
BBL Pumped:4 BBL Returned:4
Friday, September 1, 2023 Page 1 of 1
9
9
9
9
9
9
9 9
9 9
9
9Sundry 323-100 post conversion
James B. Regg Digitally signed by James B. Regg
Date: 2023.09.01 15:41:59 -08'00'
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Wednesday, April 26, 2023
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Adam Earl
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
Hilcorp North Slope, LLC
W-40A
PRUDHOE BAY UNIT W-40A
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 04/26/2023
W-40A
50-029-21776-01-00
222-103-0
N
SPT
8360
2221030 3500
1434 1722 1656 1581
0 0 0 0
OTHER P
Adam Earl
3/24/2023
MIT IA tested as per Sundry 323-100; pre-injection test to 3500psi
30 MinPretestInitial15 Min
Well Name
Type Test
Notes:
Interval P/F
Well
Permit Number:
Type Inj TVD
PTD Test psi
API Well Number Inspector Name:PRUDHOE BAY UNIT W-40A
Inspection Date:
Tubing
OA
Packer Depth
1024 3744 3671 3647IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitAGE230329090658
BBL Pumped:8.5 BBL Returned:8.5
Wednesday, April 26, 2023 Page 1 of 1
9
9
9
9
9
9
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9 9 9
&RQYHUVLRQWR:$*LQMHFWRU
9
9
Sundry 323-100;
James B. Regg Digitally signed by James B. Regg
Date: 2023.04.26 13:48:41 -08'00'
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-40A
Convert to WAG Injection
Hilcorp North Slope, LLC
3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503
222-103
50-029-21776-01-00
13000
Surface
Intermediate
Liner
Liner
Liner
8825
2626
9892
472
571
2960
12983
13-3/8"
9-5/8"
7"
4-1/2"
3-1/2" x 3-1/4" x 2-7/8"
8826
41 - 2667
39 - 9931
9671 - 10143
9572 - 10143
10040 - 13000
41 - 2667
39 - 8665
8474 - 8823
8403 - 8823
8746 - 8825
12973
2270
4760
7020
7500
10530
None
4930
6870
8160
8430
10160
11740 - 12650
4-1/2" 12.6# L-80 37 - 9620
8943 - 8840
Conductor 80 20" 42 - 122 42 - 122
4-1/2' Baker S-3 Perm Packer 9511, 8360
9511
8360
Torin Roschinger
Area Operations Manager
Claire Mayfield
Claire.Mayfield@hilcorp.com
907-564-4375
Prudhoe Bay, Prudhoe Bay 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
37 - 8437
N/A
N/A
81
Well Not Online
407 1296 1288
950
287
50
323-100
13b. Pools active after work:Prudhoe Bay Oil
No SSSV Installed
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 Kayla Junke at 10:56 am, Apr 13, 2023
Digitally signed by Torin
Roschinger (4662)
DN: cn=Torin Roschinger (4662),
ou=Users
Date: 2023.04.13 05:48:49 -08'00'
Torin Roschinger
(4662)
WCB 12-27-23
323-100
Development
PBU W-40A
222-103
Convert to WAG Injnection
RBDMS JSB 041323
DSR-4/13/23
ACTIVITY DATE SUMMARY
3/20/2023
*** WELL SHUT IN ON ARRIVAL ***
TAG DEPLOYMENT SLEEVE @ 10,039' SLM (10,040' MD)
SET 3.79" WHIDDON CATCHER ON DEPLOYMENT SLEEVE @10,034' SLM
(10,040' MD)
PULLED STA #1 RK-SO
PULLED STA # 2,3 & 4 RK-LGLV
***CONTINUE ON 3/21/23 ***
3/21/2023
***CONTINUE FROM 3/20/23***
SET RK-DGLV IN ST# 4, 3, 2, 1
PULL CATCHER @10,032' SLM
SET 3.81" PX PLUG BODY @ 9,544' SLM (9'535' MD)
*** CONTINUE ON 3/21/2023 ***
3/21/2023
T/I/O= 2000/1900/0 TFS unit 4 Assist SL (Load & Test) Loaded IA with 2 bbls 60/40
followed by 150 bbls 2% KCL followed by 344 bbls 2% Inhibited KCL followed by 134
bbls crude to FP. Loaded TBG with 1 bbl 60/40 followed by 213 bbls 2% KCL
followed by 40 bbls crude to FP. Freeze protect FL with 2 bbls 60/40 followed by 14
bbls crude. Pumped a additional 16 bbls crude to assist SL setting plug. ***Job
continued on 03/22/2023***
3/22/2023
***Job Continued from 03/22/2023*** TFS unit 4 Assist SL (Load & Test) Pumped 4
bbls crude to assist SL in setting Plug.
MIT-T ***PASSED*** to 3266 psi. pumped 3 bbls DSL to Achieve Max applied psi of
3500. 1st 15 min TBG lost 139 psi. 2nd 15 min TBG lost 67 psi. Total loss of 206 psi
in 30 min.
Lube and Bleed IA with 54 bbls DSL and 94 bbls crude.
MIT-IA **PASSED*** to 3342 psi. Pumped 24 bbls crude to Reach Max applied psi of
3500 psi. 1st 15 min IA lost 116 psi. 2nd 15 min IA lost 42 psi. Total loss of 158 psi in
30 min. Bleed TBG & IA back to 1000 psi. Tags hung on MV & IAC. FWHP=
950/990/0
3/22/2023
*** CONTINUE FROM 3/21/23 ***
RUN CHECK SET TO PX PLUG BODY at 9535' MD (sheared)
SET PX PRONG (=96" lih) @ 9535' MD
T-BIRD OBTAINS PASSING MIT-T
T-BIRD TO TROUBLESHOOT/MIT-IA
***WELL S/I ON DEPARTURE***
3/22/2023
T/I/O = 2200/1200/0. Temp = SI. Bleed IAP to CLP (Fullbore request). ALP = 1890
psi, SI @ CV. IA FL @ 2095' (HES X NIP, 112 bbls). Upon arival fullbore in control
of well. Bled IAP to W-38 production from 1200 psi to 430 psi in 1.5 hrs. IA FL
inflowed 1665'. TP decreased 400 psi. Did not monitor. Fullbore in control of well
upon departure. Final WHP's = 1800/430/0.
SV, WV = C. SSV, MV = O. IA, OA = OTG. 15:10
3/24/2023
T/I/O= 1434/1024/0. LRS 72 AOGCC (Adam Earl) MIT-IA to 3500 psi (3750 psi max
applied) PASSED at 3647 psi. IA lost 73 psi during the first 15 minutes and 24 psi
during the second 15 minutes. IA lost 97 psi during the 30 minute test. Pumped 8.5
bbls of 93*F diesel to achieve test pressure. Bled back 8.5 bbls to Final
T/I/O=1082/800/0.
3/25/2023
***WELL S/I ON ARRIVAL***
PULLED 4-1/2" PX-PLUG FROM 9,545' SLM / 9,535' MD
***JOB COMPLETE, WELL LEFT S/I ON DEPARTURE, PAD-OP NOTIFIED***
Daily Report of Well Operations
PBU W-40A
SET RK-DGLV IN ST# 4, 3, 2, 1
A passing MIT-IA to 3500 psi was a requirement of Sundry 323-100. -WCB
()
PULLED STA #1 RK-SO
TAG DEPLOYMENT SLEEVE @ 10,039' SLM (10,040' MD)@()
SET 3.79" WHIDDON CATCHER ON DEPLOYMENT SLEEVE @10,034' SLM
MIT-IA **PASSED*** to 3342 psi. Pumped 24 bbls crude to Reach Max applied psi of
3500 psi. 1st 15 min IA lost 116 psi. 2nd 15 min IA lost 42 psi. Total loss of 158 psi in
30 min.
Loaded IA with 2 bbls 60/40 ()
followed by 150 bbls 2% KCL followed by 344 bbls 2% Inhibited KCL followed by 134 yy
bbls crude to FP. Loaded TBG with 1 bbl 60/40 followed by 213 bbls 2% KCL
followed by 40 bbls crude to FP.
@
SET 3.81" PX PLUG BODY @ 9,544' SLM (9'535' MD)
AOGCC (Adam Earl) MIT-IA to 3500 psi (3750 psi max () (
applied) PASSED at 3647 psi. IA lost 73 psi during the first 15 minutes and 24 psi)
during the second 15 minutes.
PULLED STA # 2,3 & 4 RK-LGLV
g
MIT-T ***PASSED*** to 3266 psi.
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 thes pool?
Will planned perforations require a spacing exception?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
ServiceDevelopmentStrastigraphicExploratory
Authorized Name and
Digital Signature with Date:
Authorized Title:
Contact Name:
Contact Email:
Contact Phone:
AOGCC USE ONLY
Commission Representative:
Conditions of approval: Notify Commission so that a representative may witness Sundry Number:
Location ClearanceMechanical Integrity TestBOP TestPlug Integrity
Other:
Post Initial Injection MIT Req'd?
Spacing Exception Required?Yes
Yes No
No Subsequent Form Required:
Approved By:Date:
APPROVED BY
THE AOGCCCOMMISSIONER
PBU W-40A
Convert to WAG
Injection
Hilcorp North Slope, LLC
3800 Centerpoint Dr, Suite 1400, Anchorage, AK
99503
222-103
50-029-21776-01-00
341J
ADL 0028263, 0047452
13000
Surface
Intermediate
Liner
Liner
Liner
8825
2626
9892
472
571
2960
12983
13-3/8"
9-5/8"
7"
4-1/2"
3-1/2" x 3-1/4" x 2-7/8"
8826
41 - 2667
39 - 9931
9671 - 10143
9572 - 10143
10040 - 13000
2620
41 - 2667
39 - 8665
8474 - 8823
8403 - 8823
8746 - 8825
12973
2270
4760
7020
7500
10530
None
4930
6870
8160
8430
10160
11740 - 12650 4-1/2" 12.6# L-80 37 - 96208943 - 8840
Conductor 80 20" 42 - 122 42 - 122
4-1/2' Baker S-3 Perm Packer
No SSSV Installed
9511, 8360
Date:
Stan Golis
Sr. Area Operations Manager
Claire Mayfield
Claire.Mayfield@hilcorp.com
907-564-4375
Prudhoe Bay
3/3/2023
Current Pools:
Prudhoe Bay Oil
Proposed Pools:
Prudhoe Bay Oil
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 10/2022 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov
By Samantha Carlisle at 1:13 pm, Feb 16, 2023
323-100
Digitally signed by Stan Golis
(880)
DN: cn=Stan Golis (880),
ou=Users
Date: 2023.02.16 12:20:46 -09'00'
Stan Golis
(880)
MGR16FEB23 DLB 02/22/2023
Variance to 20 AAC 25.412(b) approved. Current packer placement is below the top of the PB oil pool confining
zones. Parent well W-40 demonstrated no out of zone injection from 1991 - 2007.
MIT-IA to 3500 psi. 24 hour notice for AOGCC to witness.
10-404 X
DSR-2/22/23GCW 02/23/23
JLC 2/23/2023
2/23/23Brett W. Huber, Sr.
Digitally signed by Brett W.
Huber, Sr.
Date: 2023.02.23 14:36:00 -09'00'
RBDMS JSB 022423
Conversion to Injector
WELL:W-40A
PTD:222-103
Well Name:W-40 API Number:500292177601
Current Status:Shut-In Producer Rig:Coil
Estimated Start Date:2/20/2023 Permit to Drill Number:222-103
First Call Engineer:Claire Mayfield 907-564-4375 (O)713-443-3631 M
Second Call Engineer:David Brodie Wages 713-380-9836 M
Current Bottom Hole Pressure:
Max Bottom Hole Pressure:
Max. Proposed Surface Pressure:
Last SI WHP:
Kill Weight Fluid
Min ID:
3500 psi @ 8,800’ TVD
3500 psi @ 8,800’ TVD
2620 psi
1760 psi
8.34ppg (1% KCL)
2.37” XO at 10,445’ MD
(Based on SBHPS on 7/25/21)
(Based on SBHPS on 7/25/21)
(Based on .1psi/ft gas gradient)
(Taken on 11/19/2022)
Brief Well Summary:
W-40A is a recent coil tubing sidetrack well intended to access Zone 4 stranded oil and, also, provide a point for
future water injection support. Its parent well, W-40, was also drilled as a pre-produced WAG injector. Jut prior
to the sidetrack, a SC leak was successfully repaired with a welded casing patch on 10/1/22 and passed a
subsequent OA integrity test on 10/3/22. W-40A CTD drilling began on 10/17/2022 and was completed on
10/26/2022. 510’ of perforations were shot with the rig, but due to a firing head malfunction they were shot
1,260’ off depth. After CTD rig moved off, coil tubing returned to shoot new perforations in the correct
intervals and squeezed the previously shot, off-depth perforations. The well was put on production, but
recently became uncompetitive due to high water cut and high gas lift requirements. The well is now planned
to be converted to a water injector to provide support to W-39A and W-45.
Notes Regarding Wellbore Condition:
x The well last had a passing warm and cold TIFLs on October 2018.
x 8/10/2009 RG-2041 “Blue Goo” treatment volume on conductor was 1.7 gallons/2” below conductor
landing.
x OA previously leaked off at ~.25BPM during MIT-OA to 2000 psi in 2005 but with no observable
bubbling at surface.
x Surface casing leak ~79” below the OA valve repaired on 10/1/22
x 10/28/22 CTD drilled a sidetracked and perforated ~1,260’ off target depth.
x Liner lap test failed on 10/28/2022 .55 BPM @1,115psi
x 11/26/22 CTU added perfs at target interval and squeezed perfs shot off depth
Objective:
Convert W-40A from Ivishak producer to Ivishak water injector, add perforations to provide optimal support to
W-39A and W-45. Target
Exemption:
Hilcorp requests an exemption for 20 AAC 25.412.(b) which requires “…The packer must be placed within 200
feet measured depth above the top of the perforations, unless the commission approves a different placement
depth as the commission considers appropriate given the thickness and depth of the confining zone.” The
current top open perforation is at 11,740’ MD (8941’ TVD) with the current production packer at 9511 MD
(8352’ TVD) making the packer 2229’ MD (464’ TVD) above the top perforation.
-00 DLB
Conversion to Injector
WELL:W-40A
PTD:222-103
Target well Cement Evaluation:
W-40 (parent well to W-40A) was a pre-produced WAG injector drilled in 1988. The 12-1/4” hole was drilled
without major issues. The 9-5/8” casing was run from surface to 9931’MD and cemented with 2119 cu. Ft of
class G cement. Cement and casing tested good to 3000psi.
After four years of being online as a producer, W-40 was converted to a gas injector. It was a gas cap injector in
the Ivishak from 1991-2001, and then became a gas cap water injector until 2007. In 2007, a RWO repaired
TxIA communication and brought the well back online as a producer. There were no evident issues with
confinement within the Ivishak while on injection.
Area of Review – PBU W-40A (PTD # 2220103)
Prior to the conversion of well W-40A from Ivishak producer to Ivishak injector, an Area of Review (AOR) has
been conducted. This AOR found four wells and former wells within ¼ mile of W-40A’s lateral in the reservoir.
TOCs were interpreted from logs or estimated using the daily drilling logs found in the original well files. See
attached table Area of Review W-40A for TOCs and zonal isolation of all wells within the AOR.
AOR Table
Well Name PTD API Status
Top of Oil
Pool
(Ivishak,
MD)
Top of Oil
Pool
(Ivishak,
TVD)
Top of Cmt
(MD)
Top of Cmt
(TVD)
Zonal
Isolation Comments
PBU W-40 187-135 50-029-21776-00-00
P&A'd -
sidetracked 10119' 8804' 4726 4699 Open
W-40/W-40A 9-5/8"
cemented with 2119 cu. ft.
class G. TOC estimated at
4726' MD w/ 30% washout.
PBU W-42 188-057 50-029-21816-00-00
Water
Injector 10294' 8778' 7550' 7218' Open
9-5/8" TOC logged with VDL
on 7/8/1988. Ivishak injector
open
PBU W-45 207-127 50-029-23369-00-00 Producer 9912' 8753' 6341' 5720' Open
Ivishak Producer open. 9-
5/8" cement with 169bbls
12.0ppg lead and 23.8bbls
glass G. No returns during
job. TOC estimated from
753psi net lift pressure.
PBU W-51 213-048 50-029-23488-00-00 Producer 9582' 8837' 4175' 4004' Open
Ivishak Producer open. 7"
TOC logged at 4,175' with
USIT on 6/23/2013.
Conversion to Injector
WELL:W-40A
PTD:222-103
AOR Map
Subsurface Scope:
Slickline:
1. MIRU Slickline Unit, pressure test
2. Drift to X nipple at 9535’ MD
3. Set plug in X nipple at 9535’ MD
4. Set catcher (WSL discretion)
5. Dummy all GLVs
6. Load IA with corrosion inhibited 2%KCl followed by freeze protect to 2500’
a. Total T + IA Vol to packer: 609 bbls
b. FP Vol: 160 bbl
7. MIT-T to 3500 psi
8. MIT-IA to 3500 psi
a. Give the AOGCC 24hrs notice to witness MIT-IA. Document and submit on State of Alaska form 10-
426.
9. Pull X plug
Surface Facilities Scope:
x Install new piping and tie-ins for water and MI injection (~175’ new 4” and 6” pipe, valves)
x Install I&E kit for MI and water injection service
Conversion to Injector
WELL:W-40A
PTD:222-103
Attachments:
x Current/Proposed Wellbore Schematic
x Sundry Change form
Conversion to Injector
WELL:W-40A
PTD:222-103
Wellbore Schematic
Conversion to Injector
WELL:W-40A
PTD:222-103
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
HAK
Prepared
By (Initials)
HAK
Approved
By
(Initials)
AOGCC Written
Approval
Received
(Person and
Date)
Approval:
Operations Manager Date
Prepared:
Operations Engineer Date
Post Office Box 244027
Anchorage, AK 99524-4027
3800 Centerpoint Drive
Suite 1400
Anchorage, AK 99503
Phone: (907) 564-4891
01/12/2023
Mr. Mel Rixse
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
Re: Prudhoe Bay Surface Casing by Conductor Annulus Top-offs of Cement, Corrosion Inhibitor
through 4Q 2022.
Dear Mr. Rixse,
Enclosed please find a copy of a spreadsheet with a list of Prudhoe Bay wells that were topped-off
with cement, corrosion inhibitor in the surface casing by conductor annulus through the end of 4Q
2022. Cement top-offs are executed as needed to mitigate the void space left at surface by minor
cement fallback during the primary surface casing by conductor cement job. The remaining void
space between the top of the cement and the top of the conductor is filled with a heavier than water
corrosion inhibitor to reduce the risk of external surface casing corrosion. The attached
spreadsheets include the well names, API and PTD numbers, treatment dates and volumes.
As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that
the treatments took place and meet the requirements of form 10-404 Report of Sundry Operations.
If you have any additional questions, please contact me at 564-4891 or
oliver.sternicki@hilcorp.com.
Sincerely,
Oliver Sternicki
Well Integrity Engineer
Hilcorp North Slope, LLC
By Samantha Carlisle at 3:53 pm, Jan 12, 2023
Digitally signed by Oliver Sternicki
(4525)
DN: cn=Oliver Sternicki (4525),
ou=Users
Date: 2023.01.12 14:52:49 -09'00'
Oliver Sternicki
(4525)
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: 11/29/2022
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
DATA TRANSMITTAL
WELL: W-40A
PTD: 222-103
API: 50-029-21776-01-00
FINAL LWD FORMATION EVALUATION LOGS (10/18/2022 to 10/25/2022)
Multiple Propagation Resistivity & Gamma Ray (2” & 5” MD/TVD Color Logs)
Pressure While Drilling (PWD)
Final Definitive Directional Surveys
SFTP Transfer - Data Folders:
Please include current contact information if different from above.
By Meredith Guhl at 2:53 pm, Nov 29, 2022
222-103
T37341
Meredith Guhl Digitally signed by Meredith Guhl
Date: 2022.11.29 14:54:00 -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-40A
Extended Perf w CTU, Squeeze Perfs
Hilcorp North Slope, LLC
3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503
222-103
50-029-21776-01-00
13000
Surface
Intermediate
Liner
Liner
Liner
8825
2626
9892
472
571
2960
12983
13-3/8"
9-5/8"
7"
4-1/2"
3-1/2" x 3-1/4" x 2-7/8"
8826
41 - 2667
39 - 9931
9671 - 10143
9572 - 10143
10040 - 13000
41 - 2667
39 - 8665
8474 - 8823
8403 - 8823
8746 - 8825
12973
2270
4760
7020
7500
10530
None
4930
6870
8160
8430
10160
11740 - 12650
4-1/2" 12.6# L-80 37 - 9620
8943 - 8840
Conductor 80 20" 42 - 122 42 - 122
4-1/2" Baker S-3 Perm Packer 9511, 8360
9511
8360
Stan Golis
Sr. Area Operations Manager
Josh Stephens
Josh.Stephens@hilcorp.com
970.779.1200
Prudhoe Bay, Prudhoe Bay 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
37 - 8437
Perforations 10480 - 10690 and 11090 - 11390
Squeeze 12.9-bbls of 15.8-ppg Class G cement into perforations with 1500-psi final squeeze pressure
89
226
411
800
3111
565
1773
1048
360
1150
322-634
13b. Pools active after work:PRUDHOE BAY OIL
No SSSV Installed
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
to the best of my know
December 13, 2022
By Anne Prysunka at 10:34 am, Dec 13, 2022
DSR-12/13/22WCB 12-2-2024
RBDMS JSB 121322
ACTIVITY DATE SUMMARY
11/19/2022
CTU 2 - 1.5" Blue coil, Job Objective: Extended adperf and squeeze perfs/liner lap
MIRU CTU 2. Bump test H2S and LEL alarms. Make up NS MHA and HES 2.200"
GR/CCL with 2.300" DJN. Load well with 1% KCL. Establish baseline injectivity:
4.7bpm @478psi. RIH w/HES Logging BHA, tagged high at 10,654' ctm. Online down
coil w/diesel and work logging BHA down to 10,720' ctm, unable to get deeper.
Discuss plan forward w/OE. Pooh w/logging BHA to pick up motor/mill. On surface
w/logging BHA. B/D HES Logging BHA and begin M/U BOT Milling BHA w/2.30" junk
mill.
***Job in Progress***
11/20/2022
CTU 2 - 1.5" Blue coil, Job Objective: Extended adperf and squeeze perfs/liner lap
M/U BOT Milling BHA w/2.13" motor & 2.30" junk mill. RIH w/BOT milling BHA, dry
tagged 10,753' ctm. Minimal motor work 10,753' to 11,500'. Dry drift to PBTD @
12,936' ctm. Pooh w/milling BHA. Make up HES logging tools and 2.300" DJN,
Tagged at 10653CTM and over pulled through 2 overtorqued connections ( 30'
apart). Make up and RIH with 2.200" HES GR/CCL and 2.25" DJN. Logged from
12,941' up to 9,450' @ 50 fpm. Painted flags 12,350' & 11,740'. Pooh w/logging BHA.
On surface w/logging BHA and good data, +41' correction approved by OE & Geo.
Load & Kill well w/255 bbls of 1% KCI. Flow check. Circulate KCI across flow cross
on surface while monitoring well through trip tank, losses > 1 bpm. Continuous hole
fill .5 bpm. Deploy 210' of HES 2" MaxForce Guns (6 spf, 60 deg, swell 2.171", 7
grams, 20.3" penetration). FP surface lines and put 10 bbl diesel cap on well. RIH
w/Gun Run # 2.
***Job in Progress***
11/21/2022
CTU 2 - 1.5" Blue coil, Job Objective: Extended adperf and squeeze perfs/liner lap
Continue RIH w/Gun Run # 2. At flag, corrected EOP = 11,768.89'. Adjust counter to
top shot = 11,784.36'. PUH & spot top shot = 11,740'. Load & launch 1/2" ball.
Perforate interval 11,740' - 11,950'.. Pooh w/Gun Run # 2. Kill well w/255 bbls of 1%
KCI. Flow check. Continuous hole fill .5 bpm. Un-deploy 210' of HES Gun Run # 2.
Deploy Gun Run # 1 - 300' of HES 2" guns. Correct depth at flag and perforate 12350-
12650 Reference Log BHI 2MD Final 18th-Oct-2022. POOH and kill well with 1%
KCL. Final injectivity 4.2bpm @ 1230psi. Lay down perf gun. Loss rate .5bpm.
Make up and RIH with NS 2.875" CBP. Set NS CBP @ 11,445' MD. Pooh w/BHA.
M/U cement BHA = CTC, 1.75" Stingers, 2" BDN. RIH w/2" BDN, swap well over to
diesel while RIH. On depth 9,975' ctm. PJSM w/LRS & HES for cement job.
***Job in Progress***
Daily Report of Well Operations
PBU W-40A
Perforate interval 11,740' - 11,950'
y g
Set NS CBP @ 11,445' MD.
perforate 12350-y
12650
Daily Report of Well Operations
PBU W-40A
11/22/2022
CTU 2 - 1.5" Blue coil, Job Objective: Extended adperf and squeeze perfs/liner lap.
On depth 10,000' ctm. Coil pre loaded w/3 bbls of MEOH. Execute cement down
squeeze as per program, pumped 22bbls 15.8ppg class G cement,. At 10,000' ctm,
initial WHP = 450 psi. Down squeeze cement into liner for initial 500 psi pressure
bump 450 psi to 950 psi. 8.5 bbls of cement behind pipe. PUH laying in remaining 5.6
bbls of cement 1:1 returns to trip tank. 4 bbls recovered in trip tank, WCTOC = 9,693'.
PUH to safety @ 9,280'. WHP slowly dropped to 400 psi. Hesitation squeeze 4.4 bbls
of cement into perfs. Final squeeze pressure = 1500 psi. 12.9 bbls of total cement
behind pipe. Perfs 10480-10690' and 11090-11390' squeezed. Contaminate cement
with powervis & cleanout down to 10,441' ctm, and could not jet any further. Chase
out at 80%, reciprocating across liner top and all jewelry. WOC. Make up and RIH
with 2.300" post mount PDC. Begin milling cement w/gel sweeps at 10,453' ctm.
***Job in Progress***
11/23/2022
CTU 2 - 1.5" Blue coil, Job Objective: Extended adperf and squeeze perfs/liner lap.
Mill cement / CBP.
Continue milling cement w/gel sweeps 10,720' - 11,072'. ROP slowed down
w/minimal motor work. Pooh w/milling BHA to inspect. PDC had missing insersts on
outer edge. Make up 2.30" parabolic insert mill and RIH. Continue milling hard
cement w/gel sweeps 11,093' ctm - 11,158'. Minimal penetration, 4k - 8k down,
minimal motor work, 94 degree deviation. Adjust rates, weights, pick up frequency, no
changes in ROP.
***Job in Progress***
11/24/2022
CTU 2 - 1.5" Blue coil, Job Objective: Extended adperf and squeeze perfs/liner lap.
Mill cement / CBP.
Continue milling @ 11,163' ctm. Adjust pump rates, weights, gel sweeps. Minimal
motor work and ROP. Pooh w/milling BHA to inspect, FP coil and surface lines
w/diesel. On surface w/BHA, Inspect 2.30" parabolic insert mill. Add tempress to BHA
& RIH w/BOT milling BHA. Mill from 11160-11198' CTMD with ROP as low as 3-4'/hr.
POOH to perform weekly BOP test. Completed weekly BOP testing 250 psi low /
4250 psi high. M/U BOT milling BHA w/1.69" motor and 2.30" parabolic insert mill.
RIH w/milling BHA. Continue milling cement 11,205' ctm - 11,265' ctm. ROP = 1 fpm.
***Job in Progress***
11/25/2022
CTU 2 - 1.5" Blue coil, Job Objective: Extended adperf and squeeze perfs/liner lap.
Mill cement / CBP.
Continue milling cement 1:1 with gel sweeps 11,265' ctm - 11,365' ctm. ROP = 1 fpm.
Broke through cement at 11,365' ctm, RIH to white flag 11,392' ctm (24' above CBP).
PUH to TOL. MIT-Tubing to 1500 psi, test failed multiple times. Dry tagged 11,405'
ctm. Pooh w/milling BHA. Decision to mill CIBP and push to bottom. Make up Milling
BHA with 2.30" 4-bladed junk mill and RIH. Tag cement at 11200' CTMD and dress
liner down to white tie-in flag. Tie-in at flag and mill CIBP. Push to 11813' MD until no
longer making progress, suspect tool issues. POOH to inspect BHA. On surface,
burst disc blown. Replace and change out 1.69" motor. RIH w/BOT milling BHA
w/2.30" 4-bladed junk mill. Begin milling and pushing NS CBP @ 11,800' ctm. ROP =
1 - 1.3 fpm. Unable to get motor work, pushing CBP @ 11,920' ctm.
***Job in Progress***
j
On depth 10,000' ctm. Coil pre loaded w/3 bbls of MEOH. Execute cement down
squeeze as per program, pumped 22bbls 15.8ppg class G cement,. At 10,000' ctm, g g
initial WHP = 450 psi. Down squeeze cement into liner for initial 500 psi pressure
bump 450 psi to 950 psi. 8.5 bbls of cement behind pipe
g
Continue milling hard g
cement w/gel sweeps 11,093' ctm - 11,158'. Minimal penetration,
g g
Begin milling and pushing NS CBP @ 11,800' ctm. ROP = jggg@
1 - 1.3 fpm. Unable to get motor work, pushing CBP @ 11,920' ctm
g
Continue milling cement 11,205' ctm - 11,265
jy
WOC. Make up and RIH gjy
with 2.300" post mount PDC. Begin milling cement w/gel sweeps at 10,453' ctm
Broke through cement at 11,365' ctm, RIH to white flag 11,392' ctm (24' above CBP)
Mill from 11160-11198' CTMD
Dry tagged 11,405'
(
g ygg
ctm. Pooh w/milling BHA. Decision to mill CIBP and push to bottom. Make up Millinggg
BHA with 2.30" 4-bladed junk mill and RIH. Tag cement at 11200' CTMD and dressjg
liner down to white tie-in flag. Tie-in at flag and mill CIBP. Push to 11813' MD until nog
longer making progress, su
PUH laying in remaining 5.6
bbls of cement 1:1 returns to trip tank
Hesitation squeeze 4.4 bblsy@ y
of cement into perfs. Final squeeze pressure = 1500 psi. 12.9 bbls of total cement
behind pipe.
Continue milling cement 1:1 with gel sweeps 11,265' ctm - 11,365' ctmgg
Daily Report of Well Operations
PBU W-40A
11/26/2022
CTU 2 - 1.5" Blue coil, Job Objective: Extended adperf and squeeze perfs/liner lap.
Mill cement / CBP.
Continue pushing CBP in hole @ 11,920' ctm. Push CBP down to 12973' CTMD.
Pump gel sweep & chase to surface. FP coil and well w/diesel. RDMO CTU.
****Job Complete***
11/27/2022
LRS Well Test Unit 6, Flowback SLBU, Begin WSR on 11/27/22. IL Well W-40, OL
Well W-39, Move in and spotted up unit. Rig-up, Pop well, Flow Stabilze. Continue
WSR on 11/28/22
11/28/2022
LRS Well Test Unit 6, Flowback SLBU, Begin WSR on 11/28/22. IL Well W-40, OL
Well W-39, Pop well, Allow Well to Stack out, POP to tanks, Flow Stabilze, Preform
HOT on TBG. Continue WSR on 11/29/22
11/28/2022
T/I/O=500/1600/0 Assist Test Unit (HOT OIL TREATMENT) 10 bbls 60/40 down tbg.
***Job Continued to 11/29/22***
11/29/2022
LRS Well Test Unit 6, Flowback SLBU, Continue WSR from 11/29/22. IL Well W-40,
OL Well W-39, Perform HOT on TBG, RePOP to tanks, Divert Fluid to Prod. Begin 8
HR PB WT, Continue WSR on 11/30/22
11/29/2022
***Job continued from 11/28/22*** ((HOT OIL TREATMENT) Assist Testing Uint.
Pumped 76 bbls 180* Crude down TBG. Final T/I/O=2277/1871/6. Well handed back
over to Testing Unit.
11/30/2022
LRS Well Test Unit 6, Flowback SLBU, Continue WSR from 11/29/22. IL Well W-40,
OL Well W-39, Complete 8 HR PB WT, De-inventory, Blow Down, RDMO, End WSR
on 11/30/22
11/30/2022
Freezez Protect for Well Testing on W-39 Flowline. Pumped 8 BBLS Crude to FP W-
39 FL.
Continue pushing CBP in hole @ 11,920' ctm. Push CBP down to 12973' CTMD
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Digitally signed by Jessie L.
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Date: 2022.11.08 13:48:52
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ŬŝůůĞĚĂŶĚƚŚĞƌĞŝƐŶŽĞdžĐĞƐƐĨůŽǁ͘
ϭϬ͘ WĞƌĨŽƌŵĚƌŝůůďLJƉŝĐŬŝŶŐƵƉƐĂĨĞƚLJũŽŝŶƚǁŝƚŚd/tǀĂůǀĞĂŶĚƐƉĂĐĞŽƵƚďĞĨŽƌĞDhŐƵŶƐ͘ZĞǀŝĞǁǁĞůů
ĐŽŶƚƌŽůƐƚĞƉƐ ǁŝƚŚĐƌĞǁƉƌŝŽƌƚŽďƌĞĂŬŝŶŐůƵďƌŝĐĂƚŽƌĐŽŶŶĞĐƚŝŽŶĂŶĚĐŽŵŵĞŶĐŝŶŐŵĂŬĞƵƉŽĨdWŐƵŶ
ƐƚƌŝŶŐ͘KŶĐĞƚŚĞƐĂĨĞƚLJũŽŝŶƚĂŶĚd/tǀĂůǀĞŚĂǀĞďĞĞŶƐƉĂĐĞĚŽƵƚ͕ŬĞĞƉƚŚĞƐĂĨĞƚLJũŽŝŶƚͬd/tǀĂůǀĞ
ƌĞĂĚŝůLJĂĐĐĞƐƐŝďůĞŶĞĂƌƚŚĞǁŽƌŬŝŶŐƉůĂƚĨŽƌŵĨŽƌƋƵŝĐŬĚĞƉůŽLJŵĞŶƚŝĨŶĞĐĞƐƐĂƌLJ͘
Ă͘ ƚƚŚĞďĞŐŝŶŶŝŶŐŽĨĞĂĐŚũŽď͕ƚŚĞĐƌŽƐƐŽǀĞƌͬƐĂĨĞƚLJũŽŝŶƚŵƵƐƚďĞƉŚLJƐŝĐĂůůLJDhƚŽƚŚĞƉĞƌĨŐƵŶƐ
ŽŶĞƚŝŵĞƚŽĐŽŶĨŝƌŵƚŚĞƚŚƌĞĂĚƐĂƌĞĐŽŵƉĂƚŝďůĞ͘
ϭϭ͘ ƌĞĂŬůƵďƌŝĐĂƚŽƌĐŽŶŶĞĐƚŝŽŶĂƚYd^ĂŶĚďĞŐŝŶŵĂŬĞƵƉŽĨdWŐƵŶƐƉĞƌƐĐŚĞĚƵůĞďĞůŽǁ͘ŽŶƐƚĂŶƚůLJ
ŵŽŶŝƚŽƌĨůƵŝĚƌĂƚĞƐƉƵŵƉĞĚŝŶĂŶĚĨůƵŝĚƌĞƚƵƌŶƐŽƵƚŽĨƚŚĞǁĞůů͘&ůƵŝĚƐŵĂŶͲǁĂƚĐŚŵƵƐƚďĞƉĞƌĨŽƌŵĞĚ
ǁŚŝůĞĚĞƉůŽLJŝŶŐƉĞƌĨŐƵŶƐƚŽĞŶƐƵƌĞƚŚĞǁĞůůƌĞŵĂŝŶƐŬŝůůĞĚĂŶĚƚŚĞƌĞŝƐŶŽĞdžĐĞƐƐĨůŽǁ͘
dĂďůĞ ϭ͗ tͲϰϬ WƌŽƉŽƐĞĚĚͲWĞƌĨ'ƵŶZƵŶƐ
ϭϮ͘ Z/,ǁŝƚŚƉĞƌĨŐƵŶĂŶĚƚŝĞͲŝŶƚŽĐŽŝůĨůĂŐĐŽƌƌĞůĂƚŝŽŶ͘WŝĐŬƵƉĂŶĚƉĞƌĨŽƌĂƚĞŝŶƚĞƌǀĂůƉĞƌƚĂďůĞĂďŽǀĞ͘
WKK,͘
ϭϯ͘ EŽƚĞĂŶLJƚƵďŝŶŐƉƌĞƐƐƵƌĞĐŚĂŶŐĞŝŶt^Z͘
ϭϰ͘ ĨƚĞƌƉĞƌĨŽƌĂƚŝŶŐ͕Wh,ƚŽƚŽƉŽĨůŝŶĞƌŽƌŝŶƚŽƚƵďŝŶŐƚĂŝůƚŽĞŶƐƵƌĞĚĞďƌŝƐĚŽŶŽƚĨĂůůŝŶŽŶƚŚĞŐƵŶƐĂŶĚ
ƐƚŝĐŬƚŚĞ,͘ŽŶĨŝƌŵǁĞůůŝƐĚĞĂĚĂŶĚƌĞͲŬŝůůŝĨŶĞĐĞƐƐĂƌLJ͕ďĞĨŽƌĞƉƵůůŝŶŐƚŽƐƵƌĨĂĐĞ͘
'ƵŶZƵŶη WĞƌĨdŽƉ WĞƌĨŽƚƚŽŵ WĞƌĨ>ĞŶŐƚŚ
ϭ ϭϮϯϱϬ͛ϭϮϲϱϬ͛ϯϬϬ͛
Ϯ ϭϭϳϰϬ͛ϭϭϵϱϬ͛ϮϭϬ͛
dŽƚĂů ϱϭϬ͛
0DNHXS3&(
WŽƐƚͲd
tĞůů͗tͲϰϬ
Wd͗ϮϮϮͲϭϬϯ
ϭϱ͘ WƵŵƉƉŝƉĞĚŝƐƉůĂĐĞŵĞŶƚǁŚŝůĞWKK,͘^ƚŽƉĂƚƐƵƌĨĂĐĞƚŽƌĞĐŽŶĨŝƌŵǁĞůůĚĞĂĚĂŶĚŚŽůĞĨƵůů͘
ϭϲ͘ ZĞǀŝĞǁǁĞůůĐŽŶƚƌŽůƐƚĞƉƐǁŝƚŚĐƌĞǁƉƌŝŽƌƚŽďƌĞĂŬŝŶŐůƵďƌŝĐĂƚŽƌĐŽŶŶĞĐƚŝŽŶĂŶĚĐŽŵŵĞŶĐŝŶŐ
ďƌĞĂŬĚŽǁŶŽĨdWŐƵŶƐƚƌŝŶŐ͘
ϭϳ͘ ŶƐƵƌĞƐĂĨĞƚLJũŽŝŶƚĂŶĚd/tǀĂůǀĞĂƐƐĞŵďůLJĂƌĞŽŶͲŚĂŶĚďĞĨŽƌĞďƌĞĂŬŝŶŐŽĨĨůƵďƌŝĐĂƚŽƌƚŽ>ŐƵŶ,͘
ϭϴ͘ ZĞƉĞĂƚƐƚĞƉƐ ϴͲϭϳ ĨŽƌŐƵŶƌƵŶηϮ
ŽŝůdƵďŝŶŐͲƐƋƵĞĞnjĞ;ŽŶƚŝŶŐĞŶƚͿ͗
ϭ͘ DhϮͲϳͬϴ͟W͕Z/,ĂŶĚƐĞƚ Ăƚ ϭϭ͕ϰϰϬ͛
Ă͘ ΕϱϬ͛ďĞůŽǁďŽƚƚŽŵƉĞƌĨƚŽďĞƐƋƵĞĞnjĞĚ
ď͘ /ĨĚĞƉƚŚĐŽƌƌĞĐƚŝŽŶƐŚĂǀĞďĞĞŶĐŽŶƐŝƐƚĞŶƚďĞƚǁĞĞŶƉĞƌĨƌƵŶƐ͕ ƐĞƚƉůƵŐďůŝŶĚ͕ŝĨƚŚĞƌĞ ĂƌĞ ĚŽƵďƚƐ
ĂďŽƵƚŚŝƚƚŝŶŐƚŚĞϯϱϬ͛ƐĞƚƚŝŶŐǁŝŶĚŽǁ ƌƵŶŶŝŶŐĂƚŝĞŝŶůŽŐŝƐƉĞ ƌŵŝƐƐŝďůĞ͘
Ϯ͘ DhĐĞŵĞŶƚŝŶŐŶŽnjnjůĞ͘
ϯ͘ Z/,ĂŶĚƚĂŐW
ϰ͘ ŽŶĨŝƌŵŝŶũĞĐƚŝǀŝƚLJ͕ǁŚŝůĞĨůƵŝĚƉĂĐŬŝŶŐǁĞůůĂŶĚƵŶĚĞƌďĂůĂŶĐŝŶŐǁŝƚŚĚŝĞƐĞů
Ă͘ >ŽĂĚŝŶŐƚŚĞǁĞůůǁŝƚŚ ĚŝĞƐĞůƐŚŽƵůĚĂĐŚŝĞǀĞĂΕϰϬϬƉƐŝƵŶĚĞƌďĂů ĂŶĐĞ
ϱ͘ WƵŵƉƉĞƌĨƐƋƵĞĞnjĞƉĞƌƚŚĞĨŽůůŽǁŝŶŐƐĐŚĞĚƵůĞĚŽǁŶƚŚĞd͘tŚĞŶĐĞŵĞŶƚƌĞĂĐŚĞƐƚŚĞŶŽnjnjůĞ͕ƉƵŵƉ ϭ
ďďůƐĂƌŽƵŶĚƚŚĞŶŽnjnjůĞ͘ĞŐŝŶůĂLJŝŶŐŝŶĐĞŵĞŶƚϭ͗ϭ Wh,ƚŽϭϬ͕ϬϬϬ͛
Ă͘ DĞƚŚƐƉĞĂƌ
ď͘ ϱďďů&tƐƉĂĐĞƌ
Đ͘ ϮϮ ďďůƐĐĞŵĞŶƚ
Ě͘ ϱ&t ƐƉĂĐĞƌĂŶĚĚŝƐƉůĂĐĞǁŝƚŚŝĞƐĞů;ŽƌĐŽŶƚĂŵŝĨǁĞĂƚŚĞƌƉĞƌŵŝƚƐͿ
ϲ͘ KŶĐĞĂƚϭϬ͕ϬϬϬ͛ĐůŽƐĞŝŶd^ĂŶĚƐƚĂƌƚĚŽǁŶƐƋƵĞĞnjŝŶŐĐĞŵĞŶƚƵŶƚŝůĂΕϱϬϬƉƐŝƉƌĞƐƐƵƌĞďƵŵƉŝƐ
ĂĐŚŝĞǀĞĚŽƌ ƵŶƚŝůϱďďůƐŽĨĐĞŵĞŶƚƌĞŵĂŝŶŝŶd͘
ϳ͘ >ĂLJŝŶƌĞŵĂŝŶŝŶŐĐĞŵĞŶƚϭ͗ϭĂŶĚWh,ƚŽƐĂĨĞƚLJ͘
Ă͘ WĞƌĨŽƌŵϭϱŵŝŶƵƚĞŚĞƐŝƚĂƚŝŽŶƐƋƵĞĞnjĞƐǁŽƌŬŝŶŐƉƌĞƐƐƵƌĞƵƉŝŶϮϱϬͲϱϬϬƉƐŝŝŶĐƌĞŵĞŶƚƐ
ď͘ dĂƌŐĞƚĂĨŝŶĂůƐƋƵĞĞnjĞƉƌĞƐƐƵƌĞŽĨϭ͕ϬϬϬƉƐŝ
Đ͘ /ĨƵŶĂďůĞƚŽďƵŝůĚƐƋƵĞĞnjĞƉƌĞƐƐƵƌĞŝŶĐƌĞĂƐĞŚĞƐŝƚĂƚŝŽŶƚŝŵĞƚŽϯϬŵŝŶƵƚĞƐ
Ě͘ &ŽƌŐŽƐƋƵĞĞnjĞĂƚƚĞŵƉƚƐŽŶĐĞdKŝƐϱϬ͛ĨƌŽŵƚŽƉƉĞƌĨ ĂƚϭϬ͕ϰϴϬ͛
Ğ͘ tĞǁŝůůŵŽƐƚůŝŬĞůLJďĞƐƋƵĞĞnjŝŶŐŽĨĨƚŚĞƚǁŽŽƉĞŶƉĞƌĨŝŶƚĞƌǀĂůƐĂŶĚƚŚĞůŝŶĞƌůĂƉ ;ůŝŶĞƌůĂƉƚĞƐƚ
ĨĂŝůĞĚĂƚ͘ϱďƉŵΛϭ͕ϭϬϬƉƐŝͿ͘
ϴ͘ ůĞĞĚt,WƚŽϭϬϬƉƐŝŽǀĞƌŝŶŝƚŝĂůƉƌĞƐƐƵƌĞ͘Z/,ĂŶĚĐŽŶƚĂŵŝŶĂƚĞĐĞŵĞŶƚǁŝƚŚƉŽǁĞƌǀŝƐĚŽǁŶ ƚŽ ƚŚĞ
W͘
ϵ͘ ƌŽƉďĂůůĂŶĚĐůĞĂŶŽƵƚĐĞŵĞŶƚĂƚϴϬйǁŚŝůĞWKK,͘ZĞĐŝƉƌŽĐĂƚĞĂĐƌŽƐƐĂůůũĞǁĞůƌLJĂŶĚKWƐ͘
Ă͘ DĂŝŶƚĂŝŶΕϭϬϬƉƐŝŽǀĞƌŝŶŝƚŝĂůƉƌĞƐƐƵƌĞǁŚŝůĞƐƚĂƌƚŝŶŐƚŚĞĐůĞĂŶŽƵƚ͘KŶĐĞǁĂƚĞƌŝƐŽŶƚŚĞd^
ƚŚĞt,WĐĂŶďĞĚƌŽƉƉĞĚĂĐĐŽƌĚŝŶŐůLJ͘
ϭϬ͘ tKƚŽƌĞĂĐŚϭ͕ϱϬϬƉƐŝĐŽŵƉƌĞƐƐŝǀĞƐƚƌĞŶŐƚŚ͕D/dͲdƐƋƵĞĞnjĞƚŽϭ͕ϱϬϬƉƐŝ
Ă͘ ŽŶƚĂĐƚK ǁŝƚŚD/dƌĞƐƵůƚƐ
ď͘ /ĨD/dĨĂŝůƐZ/,ǁŝƚŚŶŽnjnjůĞ,ĂŶĚƌĞĂƚƚĞŵƉƚƐƋƵĞĞnjĞ͘
ϭϭ͘ /ĨD/dƉĂƐƐĞƐDhŵŽƚŽƌĂŶĚŵŝůů͕Z/,ĂŶĚŵŝůůWĂŶĚƉƵƐŚƚŽd͘
/LPLWSUHVVXUHDWVDQGIDFH
WRSUHVVXUHEHORZIUDFWXUH
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tĞůů͗tͲϰϬ
Wd͗ϮϮϮͲϭϬϯ
ƚƚĂĐŚŵĞŶƚƐ͗
ϭ͘ ƐͲďƵŝůƚ^ĐŚĞŵĂƚŝĐ
Ϯ͘ WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ
ϯ͘ KW^ĐŚĞŵĂƚŝĐ
ϰ͘ ^ƚĂŶĚŝŶŐKƌĚĞƌƐĨŽƌKƉĞŶ,ŽůĞtĞůůŽŶƚƌŽůƵƌŝŶŐWĞƌĨ'ƵŶĞƉůŽLJŵĞŶƚ
ϱ͘ ƋƵŝƉŵĞŶƚ>ĂLJŽƵƚŝĂŐƌĂŵ
ϲ͘ dŝĞͲ/Ŷ>ŽŐ
ϳ͘ ĞŵĞŶƚ/ŶĨŽƌŵĂƚŝŽŶ
ϴ͘ ^ƵŶĚƌLJŚĂŶŐĞ&Žƌŵ
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tĞůů͗tͲϰϬ
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WŽƐƚͲd
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L-80/S00-95
18
By James Brooks at 10:44 am, Nov 04, 2022
Completed
10/29/2022
JSB
RBDMS JSB 110722
GDSR-11/15/22MGR05JUNE2023
11.3.2022
Digitally signed by Monty M Myers
DN: cn=Monty M Myers, c=US,
o=Hilcorp Alaska, LLC, ou=Technical
Services - AK Drilling,
email=mmyers@hilcorp.com
Reason: I am approving this document
Date: 2022.11.03 11:06:37 -08'00'
Monty M
Myers
Activity Date Ops Summary
10/16/2022 Move rig over from W-06 to W-40. Pad short. MU stomper and spot sub and mud module. Rig set down at 11:30. Accept Rig. PJSM, Begin going through rig up
checklists. Load tree. between master and cap. Attempt LTT. Master leaking by. Close SSV. Perform LTT between SSV and swab to 3500#. Good test. Making up
MPD line. Remove tree cap, set BOP stack down. Secure stack at tie-off points, torque bolts. Prep for BOP test. Grease choke and tree valves. Install nozzle BHA
(no floats) install new stripper element. Circulate and fluid pack lines. Line up valves for shell test Test BOPs as per Hilcorp and AOGCC regs. Test is witnessed by
AOGCC Inspector Brian Bixby. All tests 250 / 3500 psi. Test 1: IRV, Stripper, C7, C9, C10, C11 - Pass. Test 2: Blind/Shear, R2, BL2, C15 - Pass Test 3: Annular
(2-3/8"), TIW1, B1, B4 - FP on B4, rest pass. Test 4: Upper 2-3/8" Pipe/Slip, TIW2, B2, B3 - Pass. Test 5: Lower 2-3/8" Pipe/Slip, C5, C6, C8, TV2 Pass.
10/17/2022 Test 6: Choke A, Choke C- Pass. Accumulator Draw down Pass. Test 7: C1, C4, TV1 - Pass. Test 8: 3" Pipe/Slip, C2, C3 -Pass. Test Gas Alarms - Pass. Lay down
test equipment. Record RKB's. Blow down choke manifold. Install drilling risers and QTS. MU weight bar and swap No go's. Tilt mast and stab PDL on stack. PT
drilling risers and PDL to 3500#. Seat new valves in pump 1. Install floats in UQC. Test to 3500 psi. Good test. Make up stinger, nozzle. Break circulation. Pump e-
line forward at 3.0 bpm for a volume. Wait on 1%KCL to arrive. Test break on MPD line. Circulate reel to 130 deg KCL. Rih with BHA#1 (Nozzle). Rate in: 0.61
bpm, Rate out: 1.09 bpm. MW in: 8.4 ppg, MW out 7.42 ppg. Taking initial returns to tiger tank for bottom kill. Tag whipstock at 10139' MD. Bleed pressure off well.
let fluid fall in riser. Bring rate up to 3.0 bpm in / 3.01 bpm out. Come off line when truck empty. Let fluid in riser fall. Come online with 8.8 ppg Powerpro. Circulate.
Rate in: 3.0 bpm in, Rate out: 3.07 bpm out. MW in: 8.8 ppg, MW out: 8.37 ppg Mud back to surface, shut down pump purge riser with air from rig floor out to tiger
tank. Flow check at rig floor, good 10 min no-flow. POOH Tag stripper, 10 min no-flow. Lift injector off skid back. L/D nozzle BHA MU window milling BHA w/
CoilTrak and 2 jts 2-3/8" PH6, drift PH6. Reamer and mill are 3.80" Go 3.79" No-Go. MU injector. RIH BHA #2 window milling BHA. Tie-in depth from 9960' correct
+5.5'. Up wt at 10070' is 50k. Close EDC. Light tag dry at 10143'. Pick up and go to 2.8 bpm / 3540 psi. Ease down to engage 4-1/2" liner. Mill window from
10142.9' autodrill 1 ft/hr. 2.9 / 2.9 bpm In / Out. 8.84 / 8.93 ppg. Window ECD 9.98 ppg.
10/18/2022 Milling window 10145.4' to 10145.6'. Rate in: 2.86 bpm, Rate out: 2.90 bpm. MW in: 8.81 ppg, MW out: 8.92 ppg Window ECD 10.1 ppg. End stops trying to roll.
PU and roll toolface to other side of stops. Milling window 10145.6' to 10147.51. Free spin: 3423 psi @ 2.84 bpm. Rate in: 2.84 bpm, Rate out: 2.83 bpm. MW in:
8.80 ppg, MW out: 8.92 ppg Window ECD 10.1 ppg. Milling window 10147.51' to 10148.63'. Free spin: 3423 psi @ 2.84 bpm. Rate in: 2.79 bpm, Rate out: 2.81
bpm. MW in: 8.79 ppg, MW out: 8.91 ppg Window ECD 10.18 ppg WOB: 4.5 -5K. Milling window 10148.63' - 10149.59'. Free spin: 3423 psi @ 2.84 bpm. Rate in:
2.79 bpm, Rate out: 2.83 bpm. MW in: 8.79 ppg, MW out: 8.90 ppg Window ECD 10.15 pp WOB: 5 -5.5K. Milling window 10149.59' - 10152.0'. Free spin: 3423
psi @ 2.84 bpm. Rate in: 2.82 bpm, Rate out: 2.81 bpm. MW in: 8.78 ppg, MW out: 8.90 ppg Window ECD 10.15 ppg WOB: 4 -5K . Milling window at 10152.0'.
Likely casing exit at 10151.5' based on milling parameters. Continue 1 ft/hr to let reamer work on bottom of window. Drill rathole from 10152.5' to 10162'. 10161'
pump 5 bbls lo / hi vis. Well on seepage losses 1-2 bph. 10162' sample 50% sand 1st reaming pass up at 0L 1 ft/min 40 psi motor work 2 spots. Down 0L 1 ft/min
20 psi MW 10145'. 2nd up 15R 1 ft/min 20 psi MW 2 spots. Down 0L 1 ft/min 17 psi MW 10145'. 3rd up pass 15L 1 ft/min 20 psi MW 10143'. Down 0L 1 ft/min 15
psi MW 10145'. 4th pass up 0L 1 ft/min 13 psi MW 10143'. Down 0L 1 ft/min 15 psi MW 10145'. 5th pass up 0L 1 ft/min 12 psi MW 10143'. Down 0L 1 ft/min
clean. 6th pass up 0L 1 ft/min clean. Dry drift is clean, slight bobble outside window. Open EDC. Dynamic flow check on bottom is good, POOH 3.2 bpm. Tag
stripper, 10 min no-flow. Break injector off, skid back. L/D CoilTrak, L/D 2 jts PH6. Mill is 3.80" Go / 3.79" NG. Reamer is 3.79" Go / 3.78" NG MU BHA #3 Build
BHA. Skid injector over, MU injector. RIH BHA #3. Tie-in depth from 9940'.
10/19/2022 RIH BHA #3. Log tie in with a +6' correction. Close EDC. Pass through window without issue. PUW:54K / RIH: 21K. Drill 4.25 build from 10162 MD to 10369. Free
spin: 3478 psi, 2.82 bpm. Rate: 2.82 bpm in, 2.85 bpm out. Circ pressure: 3478 - 3971 psi. Mud weight: 8.80 ppg in, 8.93 ppg out, Window ECD: 10.15 ppg. ROP:
30-50 fph, WOB: 1.5- 3.0 KLBS. IA: 250 psi, OA: 0 psi. Drill 4.25 build from 10369'MD to 10450' MD. Free spin: 3414 psi, 2.81 bpm. Rate: 2.81 bpm in, 2.79 bpm
out. Circ pressure: 3414- 3971 psi. Mud weight: 8.82 ppg in, 8.98 ppg out, Window ECD: 10.17ppg. ROP: 30-50 fph, WOB: 1.5- 3.0 KLBS. IA: 276 psi, OA: 0 psi.
Perform wiper trip to window. Perform 100' jog prior to pulling through window. Rate: 2.80 bpm in, 2.62 bpm out. circ pressure: 3384 psi Window ECD: 10.13
ppg. Troubleshoot choke while opening EDC. Figure calibrations out. Pooh. Rate: 3.06 bpm in, 2.62 bpm out. Mud weight: 8.82 ppg in, 8.95 ppg out, Window ECD:
10.2 ppg OOH - dynamically flow check well. ~ 6 bph loss rate. Begin to pressure un deploy BHA #3. Maintain 10.2 ECD at window while pumping through MPD
line. Pressure deploy BHA #4. RIH with BHA #4. Close EDC and Test 3P ERT-Max agitator @ 500'. Slight vibration noted at 1.8 bpm, Increasing vibration noted at
2.8 bpm. Open EDC and continue RIH. Rate: .67 bpm in, .88 bpm out. Circ pressure: 1485 psi. Mud weight: 8.80 ppg in, 8.98 ppg out, Window ECD: 10.27 ppg.
IA: 0 psi, OA: 0 psi. Log tie in pass from 9940' @ 4 fpm. Correct +5' Close EDC and RIH through window. Log RA tag and confirm on depth. Drill 4.25 build from
10450' MD to 10568' MD. Free spin: 3531 psi, 2.81 bpm. Rate: 2.85 bpm in, 2.65 bpm out. Circ pressure: 3652 psi. Mud weight: 8.80 ppg in, 8.96 ppg out, Window
ECD: 10.15 ppg. ROP: 30-65 fph, WOB: 1.2- 3.0 KLBS. IA: 88 psi, OA: 0 psi Choke is wide open.
10/20/2022 Drill 4.25 lateral from 10568' MD - 10745' MD. Free spin: 3531 psi, 2.81 bpm. Rate: 2.83 bpm in, 2.69 bpm out. Circ pressure: 3531 psi to 3893 psi. Mud weight:
8.83 ppg in, 9.02 ppg out, Window ECD: 10.21 ppg. ROP: 65 -110 fph, WOB: 1.2- 3.0 KLBS. IA: 183 psi, OA: 0 psi Choke is wide open Start losing fluid at 10745',
on 50% losses by 10761'. Lose all WOB and go to 130 fph. Drill 4.25 lateral from 10745' MD - 10879' MD. Free spin: 3531 psi, 2.81 bpm. Rate: 2.83 bpm in, 2.08
bpm out. Circ pressure: 3531 psi to 3893 psi. Mud weight: 8.85 ppg in, 9.03 ppg out, Window ECD: 10.08 ppg. ROP: 65 -110 fph, WOB: 1.2- 3.0 KLBS. IA: 127
psi, OA: 0 psi Choke is wide open Lost comms with tools. Pooh to window. Lock out reel and verify everything at surface. All tested. Either head or tools shorted.
Pooh. Rate in: 2.90 bpm, Rate out: 1.94 bpm. MW in: 8.86 ppg, MW out: 9.03 ppg Well on losses. BHA swap conventionally. Perform flow check. Well taking 18
bph. Remove injector, Pull BHA out. Close swab. Put well on MPD at 10.2 ppg equivalent. Check e-line and UQC. Good test. MWD failure. Swap BHA. Increase
AKO to 1.4 deg. RIH with BHA #5. Rate: .73 bpm in, .46 bpm out. Circ pressure: 1341 psi. - Mud weight: 8.76 ppg in, 9.03 ppg out, Window ECD: 9.93 ppg. Log
Tie In pass from 9940' @ 5 fpm. -Correct +7'. RIH through window. Drill 4.25 lateral from 10882' MD to 11056' MD. Free spin: 3347 psi, 2.81 bpm. Rate: 2.77 bpm
in, 2.65 bpm out. Circ pressure: 3532 psi to 3893 psi. Mud weight: 8.79 ppg in, 8.98 ppg out, Window ECD: 9.94 ppg. ROP: 30 - 150 fph, WOB: 1.2- 3.0 KLBS. IA:
0 psi, OA: 0 psi Choke is wide open Drill 4.25 lateral from 11056' MD to 11145' MD. Free spin: 3347 psi, 2.81 bpm. Rate: 2.79 bpm in, 2.77 bpm out. Circ
pressure: 3509 psi to 3893 psi. Mud weight: 8.69 ppg in, 8.87 ppg out, Window ECD: 9.88 ppg. ROP: 30 - 40 fph, WOB: 1.2- 4.2 KLBS. IA: 76 psi, OA: 0 psi
Choke is wide open.
50-029-21776-01-00API #:
Well Name:
Field:
County/State:
PBW W-40A
Prudhoe Bay West
Hilcorp Energy Company Composite Report
, Alaska
10/18/2022Spud Date:
10/21/2022 Drill 4.25 lateral from 11145' MD to 11188' MD. Free spin: 3378 psi, 2.83 bpm. Rate: 2.81 bpm in, 2.78 bpm out. Circ pressure: 3378 psi to 3493 psi. Mud weight:
8.72 ppg in, 8.85 ppg out, Window ECD: 9.83 ppg. ROP: 30 - 40 fph, WOB: 1.2- 4.2 KLBS. IA: 268 psi, OA: 0 psi Choke is wide open Drill 4.25 lateral from 11188'
MD to 11235' MD. Free spin: 3807 psi, 3.08 bpm. Rate: 3.08 bpm in, 3.05bpm out. Circ pressure: 3807 psi to 3954 psi. Mud weight: 8.71 ppg in, 8.85 ppg out,
Window ECD: 9.95 ppg. ROP: 0-10 fph, WOB: 1.2- 3.0 KLBS. IA: 285 psi, OA: 0 psi Choke is wide open. Drill 4.25 lateral from 11235' MD - 11330' MD. Free spin:
3807 psi, 3.08 bpm. Rate: 3.08 bpm in, 3.02 bpm out. Circ pressure: 3807 psi to 4021 psi. Mud weight: 8.71 ppg in, 8.90 ppg out, Window ECD: 9.90 ppg. ROP:
35-75 fph, WOB: 1.5- 2.0 KLBS. IA: 424 psi, OA: 0 psi Choke is wide open Perform long wiper to window. Rate: 3.08 bpm in, 2.79 bpm out. Circ pressure: 3833 psi
. Mud weight: 8.71 ppg in, 8.90 ppg out, Window ECD: 9.90 ppg. Overpulls at 11101' MD Overpulled and stalled at 10448'MD. Perform jog below window. Pull
through. Trap pressure. Open EDC. Jet liner up to tie in depth of 9940' MD. Log tie in while pumping sweeps out of hole. Log tie in with +4' correction. Rih to
window. Trap pressure. Close EDC. Run to bottom. Drill 4.25 lateral from 11330' MD to 11,460' MD. Free spin: 3863 psi, 3.11 bpm. Rate: 3.11 bpm in, 3.02 bpm
out. Circ pressure: 3863 psi to 4011 psi. Mud weight: 8.75 ppg in, 8.88 ppg out, Window ECD: 9.99 ppg. ROP: 35-75 fph, WOB: 1.5- 2.0 KLBS. IA: 299 psi, OA: 0
psi Choke is wide open Drill 4.25 lateral from 11,460' MD to 11,745' MD. Free spin: 3863 psi, 3.07 bpm. Rate: 3.11 bpm in, 2.84 bpm out. Circ psi 3783. MW: 8.77
ppg in, 8.92 ppg out, ECD: 10.01 ppg. ROP: 35-90 fph, WOB: 1.5- 2.0 KLBS. IA: 488 psi, OA: 0 psi Brief losses at 11,615' crossing Fault #. Drill 4.25 lateral from
11,745' MD to 11,800' MD. Free spin: 3863 psi, 3.07 bpm. Rate: 3.08 bpm in, 2.78 bpm out. Circ psi 3926. MW: 8.72 ppg in, 8.85 ppg out, ECD: 9.91 ppg. ROP:
35-90 fph, WOB: 1.5- 3.2 KLBS. IA: 462 psi, OA: 0 psi Perform long wiper to window from 11,800'. Rate: 3.11 bpm in, 2.73 bpm out. Circ pressure: 3956 psi. Mud
weight: 8.72 ppg in, 8.86 ppg out, Window ECD: 10.06ppg. Overpull at 11115' MD Overpulled and stalled at 10451'MD. Perform jog below window. Pull through
clean. Trap pressure and Open EDC. Jet liner up to tie in depth of 9940' MD. Log tie in while pumping sweeps out of hole. Log tie in with +4' correction. RIH to
window. Trap pressure. Close EDC
RIH to bottom. Drill 4.25 lateral from 11,800' MD. Free spin: 3964 psi, 3.07 bpm. Rate: 3.09 bpm in, 2.78 bpm out. Circ psi 3926. MW: 8.72 ppg in, 8.85 ppg out,
ECD: 10.13 ppg. ROP: 35-90 fph, WOB: 1.5- 3.2 KLBS. IA: 238 psi, OA: 0 psi.
10/22/2022 Rih to bottom. Choke started plugging on trip in. Dime size shale pieces coming back. Black and tan shale coming back. Roughly 1/2 bbl come across shaker. Opt
to wiper to window prior to drilling to clear open hole. Fought way out of hole with pack offs at surface and in open hole. Perform jog at window. Pull through and trap
pressure. Open EDC. Come online 3.4 bpm. Wiper up to 6500' MD. About 7400' well unloaded shale. Pump 15 bbls of HiVis and circulate to surface. Turn around
at 6500' and run in hole. HiVis brought back steady amount of shale while running in. Log tie in with +5' correction. Rih at min rate. 10971' bobble, 11032' 5K set
down. PU and go by. 11219' bobble. Nothing else seen. Drill 4.25 lateral from 11,800' MD to 11950' MD. Free spin: 3306 psi, 2.84 bpm. Rate: 2.83 bpm in, 2.67
bpm out. Circ psi 3405. MW: 8.65 ppg in, 8.82 ppg out, ECD: 9.89 ppg. ROP: 35-45 fph, WOB: 1.5- 3.2 KLBS. IA: 100 psi, OA: 0 psi. Wiper to 11335' MD. Perform
BHA jog. Finish pumping OH volume . 100' jog. Drop rate to 0.38 bpm. Minor pulls on bottom hole. Discussed with drilling engineer. Turn around at 10798'. Drill
4.25 lateral from 11948' MD to 12190' MD. Free spin: 3893 psi, 3.07 bpm. Rate: 3.07 bpm in, 2.86 bpm out. Circ psi 3924. MW: 8.68 ppg in, 8.79 ppg out, ECD:
10.07 ppg. ROP: 35-45 fph, WOB: 1.5- 3.2 KLBS. IA: 34 psi, OA: 0 psi. Drill 4.25 lateral from 12190' MD to 12250' MD. Free spin: 3893 psi, 3.04 bpm. Rate: 3.08
bpm in, 2.92 bpm out. Circ psi 3931. MW: 8.70 ppg in, 8.91 ppg out, ECD: 10.01 ppg. ROP: 35-80 fph, WOB: 1.5- 3.2 KLBS. IA: 410 psi, OA: 0 psi. Long wiper trip
to window from 12250' MD. Reverse jog 100' at 11335'. Drop rate to .45 bpm and pull through trouble area. Pump 5:5 sweeps during trip. 11,163' slight over pull.
10,408' over pull. Pull through window clean. Trap WHP and open EDC. Pump max rate and chase sweeps to surface. Log Tie In from 9940' @ 4 fpm. Correct
+6.5'. Bobble at 10,971', 11032' Drill 4.25 lateral from 12250' MD. Free spin: 3921 psi, 3.07 bpm. Rate: 3.09 bpm in, 2.92 bpm out. Circ psi 3931. MW: 8.67 ppg in,
8.87 ppg out, ECD: 10.08 ppg. ROP: 35-80 fph, WOB: 1.5- 3.2 KLBS. IA: 271 psi, OA: 0 psi.
10/23/2022 Drill 4.25 lateral from 12262' MD to 12383' MD. Free spin: 3783 psi, 3.07 bpm. Rate: 3.09 bpm in, 2.98 bpm out. Circ psi 3783 - 4000'. MW: 8.68 ppg in, 8.88 ppg
out, ECD: 9.8 ppg. ROP: 35 fph, WOB: 1.5- 3.2 KLBS. IA: 429 psi, OA: 0 psi Drill 4.25 lateral from 12383' MD to 12509' MD. Free spin: 3830 psi, 3.07 bpm. Rate:
3.09 bpm in, 2.98 bpm out. Circ psi 3783 - 4117' . MW: 8.68 ppg in, 8.88 ppg out, ECD: 9.8 ppg. ROP: 35 fph, WOB: 1.5- 2.2 KLBS. IA: 429 psi, OA: 0 psi Drill
4.25 lateral from 12509' MD - 12700' MD. Free spin: 3822 psi, 3.08 bpm. Rate: 3.08 bpm in, 2.97 bpm out. Circ psi 3783 - 4229 psi. MW: 8.72 ppg in, 8.91 ppg
out, ECD: 9.96 ppg. ROP: 35-70 fph, WOB: 1.5- 3.2 KLBS. IA: 327 psi, OA: 0 psi. Perform long wiper to window. Rate: 3.08 bpm in, 2.98 bpm out. Circ psi 3890
psi. MW: 8.73 ppg in, 8.88 ppg out, ECD: 10.11 ppg. Perform jog below shale. Drop to min rate. Pull to window. Minimal overpulls. Trap pressure. Open EDC. Jet
whipstock tray. Wiper up to logging depth. Log tie in with +4' correction. Pump sweeps to surface. Close EDC. RIH pumping min rate. Set down at 12,473' and work
though on 2nd attempt. Drill 4.25 lateral from 12700' MD to 12850' MD. Free spin: 3822 psi, 3.07 bpm. Rate: 3.07 bpm in, 2.97 bpm out. Circ psi 3883 - 4229 psi.
MW: 8.72 ppg in, 8.86 ppg out, ECD: 10.05 ppg. ROP: 35-70 fph, WOB: 1.5- 3.2 KLBS. IA: 23 psi, OA: 0 psi. Drill 4.25 lateral from 12850' MD to 12956' MD. Free
spin: 3822 psi, 3.07 bpm. Rate: 3.07 bpm in, 2.97 bpm out. Circ psi 3883 - 4229 psi. MW: 8.74 ppg in, 8.88 ppg out, ECD: 10.12 ppg. ROP: 35-70 fph, WOB: 1.5-
3.2 KLBS. IA: 408 psi, OA: 0 psi.
10/24/2022 Drill 4.25 lateral from 12956' MD to 12979' MD. Free spin: 3836 psi, 3.07 bpm. Rate: 3.07 bpm in, 2.97 bpm out. Circ psi 3883 - 4229 psi. MW: 8.76 ppg in, 8.90
ppg out, ECD: 10.10 ppg. ROP: 35-70 fph, WOB: 1.5- 3.2 KLBS. IA: 483 psi, OA: 0 psi. 200' BHA wiper. Drill 4.25 lateral from 12979' MD to 13000' MD. Free spin:
3836 psi, 3.07 bpm. Rate: 3.04 bpm in, 2.95 bpm out. Circ psi 3836 - 4006 psi. MW: 8.76 ppg in, 8.95 ppg out, ECD: 10.01 ppg. ROP: 21-35 fph, WOB: 1.5- 2.5
KLBS -10K drilling weight. IA: 483 psi, OA: 0 psi. 200' BHA wiper. Called TD. Wiper Trip. Rate: 3.04 bpm in, 2.95 bpm out. Circ psi 3836 psi. MW: 8.76 ppg in,
8.95 ppg out, ECD: 10.01 ppg. Perform jog below shale at 11250' MD. Drop rate to 0.4 bpm. Bring rate back up at 10908' MD. Wiper to window. Perform jog below
window. Pull though window, Come back online. Jet tubing while pulling at 40 fpm. Pumping multiple sweeps. Perform jog at 1000' md. Bypass HP screens. Pump
10 bbl beaded pill through agitator. Tag up. Reset depth. Rih. Rate: 0.35 bpm in, 0.81 bpm out. Circ psi 1340 psi. MW: 8.68 ppg in, 8.84 ppg out, ECD: 9.8 ppg.
Log tie in with +6.5' correction. Tag and run past 10,476', 11,117'. Tag and confirm TD @ 13,000'. Begin laying in liner running pill with 1.5ppb MI Alpine Drilling
Beads. Lay in 9.8 ppg NaBR KWF from 10,650'. Confirm 9.8 ppg at surface, flow check well. No flow. POOH and paint TD and Window flags. Yellow TD flag
painted at 9787.7'(9700' EOP). Continue POOH. Function test annular and both sets of 2-3/8" rams @ 7171'. White Window flag painted at 6887.7'(6800' EOP).
OOH - Flow check well and confirm no flow. L/D BHA #5. Fill hole 6 bph to keep full. Drift CTC with 7/8" ball. M/U PH6 for pumping eline slack out of coil. Pump
313' of eline out. Pump and recover 7/8" drift ball. L/D nozzle BHA. LTT tree valves. Prep to swap BOP rams.
10/25/2022 Function test Blind / Shear rams. Lock out koomey. Remove 3" pipe/slips. Install 2-3/8" x 3.5" Variable ram. Fill stack to test. Door seals leaking Replace door seal.
Test 2-3/8" x 3.5" Variable ram 250# / 3500# Witness was waived by Austin McCleod AOGCC. Test:1 2-3/8" test joint Pass. Test: 2 3.5" test joint Pass. Swap
back to drilling risers. Replace pack-offs. Make up BOT swivel, and x-over. nozzle. Test riser and packoff. 250# / 3500#. Make up 2 7/8" 6.5#, 13Cr, HYD511
production liner. Fill well every 10 jts with 9.8 ppg NaBR. Conduct unannounced well control drill with night crew. Good response and well secured in 3m 13s. Hang
liner off with 2 3/8" rams per Nabors procedure. M/U liner with BOT liner swivel. Strip down injector over liner assembly. RIH with 2 7/8" 6.5#, 13Cr BOT liner
assembly. In Rate .31 bpm, Out Rate .77 bpm. In MM 8.77 ppg, Out MM 9.93 ppg. IA 0, OA 0. Stop at window flag and correct +5.11'. WT CK 57K. RIH through
window clean. Circulate out 9.8 NaBr KWF from 10,650'. In Rate = 1.91 bpm , Out Rate = 1.59 bpm. In MM = 8.77ppg, Out MM = 9.91 ppg All 9.8ppg NaBr KWF
recovered. RIH with liner pumping min rate. Stack liner at 12,357'. Begin working liner with different pump rates and running speeds. Continue working liner to
bottom from 12,309'. Pump 10 bbl 1% KCL, 48 bbl LVT, 10 bbl 1% KCL stage. Pump 20 bbls LVT around liner and begin working towards TD. Work liner to
12,708'.
10/26/2022 Continue to work 2 7/8" liner down from 12,850'. Pumping min rate with LVT around liner. Work liner down to 12,980' without any further progress. Discuss forward
plan with drilling engineer and decide to pump ball and release from liner. Set down 10k and pump 2 bpm to confirm 1:1 returns. PUW = 68k. Drop 3/4" steel ball to
disconnect liner per BOT rep. Ball landed at 47 bbls away. Sheared @ 4700 psi. P/U and see weight break over at 12,963' and 58k PUW. Displace remaining LVT
from well to tiger tank. Pump min rate while keeping 10k wt down on liner Displace CT & Well to 1% Slick KCl w/ SafeLube and offload 8.6 ppg drilling mud. Clean
KCl at surface, hold a PJSM with Nabors & HES Crews to pump CMT. Derrickman needs a little more time to set up pits, rig & camp move to M-Pad delayed some
of the trucks. PT HES CMT Line, good PT. Pits ready to go, start mixing CMT. CMT Wet at 15:52, thickening time is 4:14 = 20:06. Online with 5 bbls of Exhaust Pill
then shut down the pump. Open up to HES CMT Pump and pump 37.2 bbls of 15.3ppg CMT into the reel. 37.2 bbls pumped, shut down HES pump and back flush
CMT line with exhaust pill. Line up the rig pump and displace CMT with rig pump. 84 bbls away, zero the Out MM for CMT volume behind pipe. 100.2 bbls away,
shut down the pump and PU and set down and pump the Peewee Dart on seat. PU and exhaust 3 bbls of CMT & 3 bbls of Exhaust Pill. 6 bbls exhausted, set back
down Pressure up to 2000psi, zero the In MM. Shear the LWP at 4300psi and displace LWP to latch collar. LWP landed at 17.8 bbls (17.9 calculated) at 2900psi,
pressure up to 4000psi and hold. Plug is holding, bleed off and check floats, floats are holding. Cement in Place - 17:40. Pressure to 1300psi and PU to pressure
drop then increase rate to clean TOL. Pit strap 36 bbls minus 6 bbls for side exhaust = 30 bbls CMT behind pipe, WCTOC = 12,285'. Clean out with exhaust pill to
12250' then RIH to TOL. Return rate is right at 1:1. POOH saw 2 intervals of CMT in returns Tag stripper, Good 10 min no-flow. Lift injector and skid back, about 8'
e-line present. L/D 1 jt PH-6, L/D 8 jts 3-1/8" collars and liner running tools. 3/4" ball recovered. M/U nozzle, jet stack flush dead legs in flow path. Purge MPD
choke and Out MM with air. RU floor to run perf guns. Load running equipment to floor, R/U single joint elevators. Review shot layout with TCP rep. PJSM with
HES TCP crew and rig crew. M/U 58 perf guns. Program firing head. Interface box from PC to firing head is not working, get another from Deadhorse. Finish
program firing head failsafe parameters. Swap elevators for 1-1/4". M/U 70 jts 1-1/4" drift and rattle each jt.
10/27/2022 Continue MU 1-1/4" CSH to perf guns. 70 jts of CSH ran, MU upper BHA. Perf BHA MU, RIH at min rate. 10,000' stop and perform Lap test to 2400psi. CMT UCA
shows CMT at 17-hrs is at ~1750psi compressive strength. Pressure built up to 1194psi then started dropping off, continue pumping to see if we are compressing
an air bubble. Pressure dropped to 1036psi then started building pressure. Pressure built up to 1143 psi then slowly dropped off to 1115 psi. Holding pretty steady
at 1115 psi at 0.55 bpm. Lap Test failed, 1115 psi at 0.55 bpm, total of 9 bbls pumped. Slowly bleed off pressure. WHP bled off, online at min rate, get up WT then
RIH to PBTD. 48k Up WT, 28k RIH WT. Tag at 12981.44' PU WT = 53k, RIH and retag to verify depth. Tag same depth, PU to 47k and stop, correct depth to
12,982.44' (+6.2'). PBTD = 12983.46', Bullnose to BTM Shot = 1.02'. PUH to 12500' and start firing sequence. #1 - Sequence completed, RIH to 12670' then PU to
12650' bottom shot depth. No indication the guns fired, PU and restart firing sequence. #2 - Sequence completed, RIH to 12670' then PU to 12650' bottom shot
depth. No indication the guns fired, PU and restart firing sequence. #3 - Sequence completed, RIH to 12670' then PU to 12650' bottom shot depth. No indication the
guns fired, RIH and try PUH firing sequence. #4 - Sequence completed, PUH to 12650'. No indication the guns fired, RIH and try PUH firing sequence #5 -
Sequence completed, PUH to 12650'. No indication the guns fired. Fail-Safe Parameter for temperature may have been set a little low. RIH to PBTD and circulate to
bring the bottom hole temp down into range. Circ 1.5x BU until Out MM temp steady. Tag bottom and PU to 47k. Reset depth to 12982.44' bottom shot depth =
PBTD - Bullnose Length. #6 - Pick up and try to activate Maxfire head again, with upward motion. No indication of shots. #7 - Try pump across kill line, downward
motions, no indication. POOH, take precautions against swabbing in case guns have gone off. Keep 250 WHP while inside liner pump 1.5 bpm through CT. While
POOH at 11390' indication of perf guns firing from loss of WHP and recoil felt. Discuss with ODE and TCP supervisor, continue trip OOH. Keep 250 psi WHP until
at liner top. Stop at liner top, bleed off WHP. 30 min flow check is good, no flow. Fill well with 2.4 bbls continue POOH on open choke. Perform jog at surface. Some
light returns seen during jog circ out to tiger tank. Tag up and pump B/U. Shut down and purge CT riser out to tank. 10 min no flow, good. Fill well 1.2 bbls. Lift
injector off, break off at swivel, skid back. L/D 2 jts PH6. L/D 1-1/4" CSH. After 6 jts CSH conduct D1 drill w/ Eric Gregory crew. Well secured 3m 40s. AAR. Pull
final jt 1-1/4" CSH with firing head. Shots fired. Break off firing head, change elevators. L/D perf guns. Perforated Intervals: 10480 - 10690, 11090 - 11390.
10/28/2022 Continue laying down perf guns and load out. All Shots fired. MU Nozzle BHA with CV's. RIH to Freeze Protect the well from 2500' TVD. LRS is on location pulling
diesel off a transport for our FP. PJSM with LRS & Nabors crews to pump diesel. Load 50 bbls of diesel in the reel. POOH laying in diesel. OOH, flow check well
and close the Master & Swab Valves. Hold a PJSM with HES N2 & Nabors Crews to blow down the reel. PU injector and remove DFCV's. Stab on and displace coil
wit 40 bbls of freshwater, 30 bbls inhibited water and 5 bbls of neat methanol. Online with N2 at1800 sqft/min for 15 min Reel is blown down, bleed off residual
pressure. WHP bled off, allow grease crew to service the Master & Swab Valves. PT Master & Swab, good PT Suspend OPS while NES has the access road into W-
Pad closed to extract the LRS Truck form the side road Access road it clear, prep to unstab coil and suck out stack to swap VBR's to 3" Combi Rams Remove VBRs
from lower combis install 3" pipe / slip rams. Shell test BOP door seals 250 / 3500 psi, good visual. Vac out stack down to MV, dump MeOH on top of MV and close
SSV. Prep to unstab pipe. Install grapple and pull test, good. Pull CT out of injector back to reel, secure it at shipping spool. Cut off tail ahead of clamp.
10/29/2022 Purge surface lines w/ air. Purge MPD line. Install BOP test risers. Remove BOP stack, install tree cap and test. RDMO 06:00.
WELL NAME
Date :
Shoe @ :FC @ :Top Liner @ :
Type:
Type :
Type :
Type :
Type :
XYes No
Yes X No Yes X No
X Yes No X Yes No
Date :
Volume lost during displacement (bbls) :
Density (ppg) : 8.4 Volume pumped (bbls) : 235
W-40A CEMENT REPORT
26-Oct-22 Hole Size :4.25 Casing Size :3-1/2 x 3-1/4 x 2-7/8
Lead Slurry
Density (ppg) :
Tail Slurry
Volume (bbls) : Density (ppg) :
Yield : Sacks : Mixing / Pumping Rate (bpm) :
Post Flush (Spacer)
1.5 ppb Geovis Density (ppg) : 8.34 Rate (bpm) :
Bump press :
Volume : 200
Displacement :
1.5 ppb Geovis Density (ppg) : 8.34 Rate (bpm) : 1.5 Volume (actual / calculated) : 17.8 / 17.9
3.5
Method Used To Determine TOC : Calculated
4000
Casing Rotated? Reciprocated? % Returns during job :
Cement returns to surface? Spacer returns? Vol to Sur : 99
FCP (psi) : 3650 Pump used for disp : GD Plug Bumped?
Cement In Place At : 17:40 10/26/2022 Estimated TOC : 10,040
1.20
Remarks:
FI
R
S
T
S
T
A
G
E
13,000 12986 / 12997 10040
Preflush (Spacer)
1% KCl
Class G Volume (bbls): 37.2 15.3
Yield : 1.63 Sacks : 128 Mixing / Pumping Rate (bpm) : 2.5
1
Regg, James B (OGC)
From:Alaska NS - CTD DSM <AlaskaNS-CTD-DSM@hilcorp.com>
Sent:Tuesday, October 25, 2022 4:18 PM
To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC)
Cc:Robert Coyne; Nathan Wheeler; Henson, Thomas; Williams, Wade; Henson, James; Alaska NS - CTD
DSM
Subject:PBU W-40A Nabors CDR2 Variable ram test
Attachments:Nabors CDR2AC 10-25-2022.xlsx
John Perl
Sr. Drilling Foreman – Nabors CDR2
Rig (907) 670‐3097
Personal Cell (907) 355‐5815
H# 4169
Positional Email AlaskaNS‐CTD‐DSM@hilcorp.com
Alternate: Mark Igtanloc
Hilcorp Alaska, LLC
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.
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-40A
PTD 2221030
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:10/25/22
Rig Rep.:Rig Email:
Operator:
Operator Rep.:Op. Rep Email:
Well Name:PTD #2221030 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 0 NA
Permit On Location P Hazard Sec.P Lower Kelly 0 NA
Standing Order Posted P Misc.NA Ball Type 2 NA
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"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 0 NA
#5 Rams 0 NA
#6 Rams 0 NA ACCUMULATOR 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 0 NA 200 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 1 NA
Hydraulic Chokes 1 NA Control System Response Time:Time (sec)Test Result
CH Misc 0 NA Annular Preventer NA
#1 Rams NA
Coiled Tubing Only:#2 Rams NA
Inside Reel valves 1 NA #3 Rams NA
#4 Rams NA
Test Results #5 Rams NA
#6 Rams NA
Number of Failures:0 Test Time:1.0 HCR Choke NA
Repair or replacement of equipment will be made within NA days. HCR Kill NA
Remarks:
AOGCC Inspection
24 hr Notice Yes Date/Time 10/24/22 07:35
Waived By
Test Start Date/Time:10/25/2022 10:30
(date)(time)Witness
Test Finish Date/Time:10/25/2022 11:30
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Austin McLeod
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 / T. Henson
Hilcorp
J.Perl / R. Burnett
PBU W-40A
Test Pressure (psi):
robert.coyne@nabors.com
AlaskaNS-CTD-DSM@hilcorp.com
Form 10-424 (Revised 08/2022)2022-1025_BOP_Nabors_CDR2AC_VBR_PBU_W-40A
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 11:19:38 AM
Attachments:2022-1025_BOP_Nabors_CDR2AC_VBR_PBU_W-40A.pdf
PBU W-40A (PTD 2221030) – VBR only
Jim Regg
Supervisor, Inspections
AOGCC
333 W. 7th Ave, Suite 100
Anchorage, AK 99501
907-793-1236
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 W40A
Hilcorp North Slope, LLC
Permit to Drill Number: 222-103
Surface Location: 3854' FSL, 1454' FEL, Sec. 21, T11N, R12E, UM, AK
Bottomhole Location: 906' FNL, 1877' FWL, 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,
Jeremy M. Price
Chair
DATED this ___ day of August, 2022.
Jeremy
Price
Digitally signed by
Jeremy Price
Date: 2022.08.10
14:07:32 -08'00'
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By Samantha Carlisle at 12:57 pm, Aug 03, 2022
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Date: 2022.08.10 14:07:19 -08'00'
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10000True Vertical Depth (500 usft/in)3000 3250 3500 3750 4000 4250 4500 4750 5000 5250 5500 5750 6000 6250 6500
Vertical Section at 144.92° (500 usft/in)
W-40A wp05 CP2
W-40A wp05 CP1
W-40A wp05 CP4
W-40A wp05 CP5
W-40A wp05 CP6
W-40A wp05 CP7
W-40A wp05 CP8
W-40A wp05 CP9
W-40A wp05 CP10
W-40A geopolygon950010000 1050010612W-40
7" TOW
2 7/8" x 4 1/2"10500110001150012000125001300013019W-40A wp07KOP : Start Dir 9º/100' : 10144' MD, 8823.76'TVD : 0° RT TFStart Dir 20º/100' : 10164' MD, 8838.51'TVDStart Dir 12º/100' : 10439.36' MD, 8973.61'TVDTotal Depth : 13019' MD, 8846.02' 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-40
Ground Level: 53.20
+N/-S +E/-W
Northing Easting Latitude Longitude
0.00 0.00 5958827.02 611789.00 70° 17' 47.2937 N 149° 5' 41.1464 W
SURVEY PROGRAM
Date: 2022-05-09T00:00:00 Validated: Yes Version:
Depth From Depth To Survey/Plan Tool
100.00 10144.00 W-40 Srvy 1 GCT-MS (W-40) 3_Gyro-CT_pre-1998_Csg
10144.00 13019.00 W-40A wp07 (Plan: W-40A) 3_MWD
FORMATION TOP DETAILS
No formation data is available
REFERENCE INFORMATION
Co-ordinate (N/E) Reference:Well Plan: W-40, True North
Vertical (TVD) Reference:KB @ 92.29usft
Measured Depth Reference:KB @ 92.29usft
Calculation Method:Minimum Curvature
Project:Prudhoe Bay
Site:W
Well:Plan: W-40
Wellbore:Plan: W-40A
Design:W-40A wp07
CASING DETAILS
TVD TVDSS MD Size Name
8824.51 8732.22 10145.00 7 7" TOW
8846.02 8753.73 13019.00 2-7/8 2 7/8" x 4 1/2"
SECTION DETAILS
Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation
1 10144.00 41.60 172.85 8823.76 -3226.97 1080.98 0.00 0.00 3262.02 KOP : Start Dir 9º/100' : 10144' MD, 8823.76'TVD : 0° RT TF
2 10164.00 43.40 172.85 8838.51 -3240.38 1082.66 9.00 0.00 3273.96 Start Dir 20º/100' : 10164' MD, 8838.51'TVD
3 10439.36 79.75 123.82 8973.61 -3424.00 1217.53 20.00 -65.00 3501.75 Start Dir 12º/100' : 10439.36' MD, 8973.61'TVD
4 10554.36 79.93 109.80 8993.99 -3474.92 1318.29 12.00 -90.50 3601.33
5 10665.51 93.07 107.50 9000.76 -3510.31 1423.18 12.00 -10.00 3690.56
6 10775.51 92.99 94.28 8994.92 -3531.02 1530.81 12.00 -90.00 3769.37
7 11075.51 92.42 130.32 8980.29 -3642.88 1803.48 12.00 90.00 4017.63
8 11234.74 90.00 111.36 8976.90 -3724.10 1939.54 12.00 -97.00 4162.29
9 11309.74 90.00 102.36 8976.90 -3745.83 2011.24 12.00 -90.00 4221.29
10 11559.74 90.00 132.36 8976.90 -3859.42 2230.75 12.00 90.00 4440.40
11 11759.74 90.00 108.36 8976.90 -3959.77 2402.06 12.00 -90.00 4620.98
12 12084.74 111.16 141.92 8915.87 -4137.14 2659.79 12.00 55.00 4914.26
13 12284.74 94.93 123.69 8870.51 -4267.73 2802.29 12.00 -130.00 5103.03
14 12434.74 94.07 141.73 8858.65 -4368.75 2911.70 12.00 92.00 5248.57
15 12609.74 92.73 120.73 8848.16 -4483.22 3042.35 12.00 -93.00 5417.34
16 12784.74 90.04 141.57 8843.88 -4597.72 3173.33 12.00 97.00 5586.32
17 12909.74 89.27 126.59 8844.63 -4684.43 3262.87 12.00 -93.00 5708.74
18 13019.00 89.29 139.70 8846.02 -4758.98 3342.40 12.00 90.00 5815.46 Total Depth : 13019' MD, 8846.02' TVD
-6325
-6050
-5775
-5500
-5225
-4950
-4675
-4400
-4125
-3850
-3575
-3300
-3025
-2750
South(-)/North(+) (550 usft/in)0 275 550 825 1100 1375 1650 1925 2200 2475 2750 3025 3300 3575 3850
West(-)/East(+) (550 usft/in)
W-40A geopolygon
W-40A wp05 CP10
W-40A wp05 CP9
W-40A wp05 CP8
W-40A wp05 CP7
W-40A wp05 CP6
W-40A wp05 CP5
W-40A wp05 CP4
W-40A wp05 CP1
W-40A wp05 CP2
8 25 0
8 5 0 0
8 7 5 0
9 0 0 0
9 1 7 1
W-40
7" TOW
2 7/8" x 4 1/2"90008846W-40A wp07
KOP : Start Dir 9º/100' : 10144' MD, 8823.76'TVD : 0° RT TF
Start Dir 20º/100' : 10164' MD, 8838.51'TVD
Start Dir 12º/100' : 10439.36' MD, 8973.61'TVD
Total Depth : 13019' MD, 8846.02' TVD
CASING DETAILS
TVD TVDSS MD Size Name
8824.51 8732.22 10145.00 7 7" TOW
8846.02 8753.73 13019.00 2-7/8 2 7/8" x 4 1/2"
Project: Prudhoe Bay
Site: W
Well: Plan: W-40
Wellbore: Plan: W-40A
Plan: W-40A wp07
WELL DETAILS: Plan: W-40
Ground Level: 53.20
+N/-S +E/-W Northing Easting Latitude Longitude
0.00 0.00 5958827.02 611789.00 70° 17' 47.2937 N 149° 5' 41.1464 W
REFERENCE INFORMATION
Co-ordinate (N/E) Reference:Well Plan: W-40, True North
Vertical (TVD) Reference:KB @ 92.29usft
Measured Depth Reference:KB @ 92.29usft
Calculation Method:Minimum Curvature
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