Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
Loading...
HomeMy WebLinkAbout221-0807. 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 V-105L1
Isolate Borealis
Hilcorp North Slope, LLC
3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503
221-080
50-029-23097-60-00
9795
Conductor
Surface
Intermediate
Production
Liner
8658
80
2944
7725
7710
20"
9-5/8"
7"
6598
29 - 109
28 - 2972
25 - 7750
29 - 109
28 - 2752
25 - 6637
None
470
3090
5410
7710
1490
5750
7240
7750 - 9795
4-1/2" 12.6# x 3-1/2" 9.2# L-80 23 - 7613
6637 - 8658
Structural
4-1/2" Baker Premier Packer
7555, 6445
5211, 7555
4273, 6445
Torin Roschinger
Operations Manager
Tyson Shriver
tyson.shriver@hilcorp.com
907-564-4542
PRUDHOE BAY, Schrader Bluff Oil, Orion Dev Area / Borealis 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 0028240
23 - 6502
N/A
N/A
654
Not On Injection
300
50
1139
0
N/A
13b. Pools active after work:Schrader Bluff Oil, Orion Dev Area / Borealis Oil
4-1/2" Baker S-3 Packer
5211, 4273
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
Digitally signed by Torin
Roschinger (4662)
DN: cn=Torin Roschinger (4662)
Date: 2025.05.19 13:37:45 -
08'00'
Torin Roschinger
(4662)
By Grace Christianson at 2:13 pm, May 19, 2025
RBDMS JSB 052325
JJL 6/13/25
DSR-6/3/25
ACTIVITY DATE SUMMARY
2/9/2025
T/I/O=500/100/500 (Freeze Protect) Pumped 3 bbls of neat meth down the PWI line
to FP to the header. Pumped 1 bbl of neat meth followed by 40 bbls of crude down
the TBG to FP to 2500' TVD. Flags and tags hung. PO notified of well status
FWHPS=1500/100/500
2/9/2025
***WELL INJECTING ON ARRIVAL*** (IPROF)
MURU HES 1122
PT PCE 300PSI LOW, 2500PSI HIGH
LOG IPROF / WARM BACK PASSES PER PROCEDURE
RD HES 1122
***WELL S/I ON DEPARTURE***
2/25/2025
***WELL S/I UPON ARRIVAL*** (sidetrack)
R/U HES 759 SLICKLINE UNIT SLICKLINE UNIT
***CONT WSR ON 2/26/25***
2/26/2025
***CONT WSR FROM 2/25/25*** (iprof)
DRIFTED W/ 10' x 2 7/8" DUMMY GUN (2.66" rings), 2.78" CENT, TEL, 1.75"
SAMPLE BAILER
--LOC TT @ 7,574' SLM / 7,611' ELMD (37' corr). LIGHTLY TAG WINDOW/WHIP
AT 7,713' SLM
RAN HES 40 ARM CALIPER FROM 7,710' SLM TO SURFACE (good data)
***WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS***
3/5/2025
****WELL S/I ON ARRIVAL***
MIRU HES
HEATSOCK RIPPED NEEDED TO RD AND REPAIR
TOOLS BECAME DAMAGED AND WILL NEED TO RETURN TO SHOP FOR
REPAIRS
LAYDOWN FOR THE DAY AND SECURE WELL
WILL RETURN THE NEXT DAY
***CONTINUED ON 6-MAR-24 WSR***
3/6/2025
***CONTINUED FROM 5-MAR-25***
STATIC SPINNER TEST AT 7700': NO CROSS FLOW DETECTED
DSO PUT WELL ON INJECTION; 1500 BWPD @ 1142 PSI
IMPUSE TESTS AT 7700', 7620', 7500', 7000', 6500' 5610', 5560', 5450'
DOWNWARD FLOW DETECTED
FINAL INJECTION RATE 1550 BWPD AT 1122 PSI
WELL SHUT IN
RD TOOLS AND PCE FOR FREEZE PROTECT
SECURE WELL AND LOCATION
***CONTINUE ON 7-MAR-25 WSR***
3/6/2025
T/I/O=500/225/500 TFS Unit 1 Pumped 3 BBLS 60/40 and 37 BBLS of DSL to Freeze
Protect TBG to 2500ft. Pumped 3 BBLS of 60/40 to Freeze Protect V-105 Flowline.
Pressured FL to 2100 psi per PAd Op. Flags and Tags hung on Pit Valves and Wing
Valve upon Departure. FWHP= 1195/200/500
Daily Report of Well Operations
PBU V-105
Daily Report of Well Operations
PBU V-105
3/7/2025
***CONTINUED FROM 6-MAR-25 WSR*** (PLUG SET)
RU PCE AND PT 300/3000PSI
RIH WITH BAKER IBP AND CORRELATE TO READ CALIPER DATED 23JAN22
PLUG DID NOT INFLATE AFTER 2 ATTEMTS DOWNHOLE
POOH TROUBLESHOOT AT SURFACE
LAY DOWN AND SECURE WELL TO ATTEMPT NEXT DAY
***CONTINUE ON 8-MAR-25 WSR***
3/8/2025
***CONTINUED FROM 7-MAR-25 WSR***
PICK UP PCE
MIRU BAKER CHECK TOOLS AND PT
CCL FAILED DOWNHOLE PULL TO SURFACE AND TROUBLESHOOT
SWAP TO OTHER CCL
RIH TO SET DEPTH
PLUG DID NOT SET
STANDBY FOR PUMP TRUCK AND TANKER
MIRU T-BIRD
LOAD WELL WITH 150 BBL SEAWATER AT 39 OF FREEZE PROTECT
RDMO T-BIRD
ATTEMPT TO SET PLUG BUT PLUG DIDNOT SET
POOH
***CONTINUED ON 9-MAR-25 WSR***
3/8/2025
T/I/O= 1400/180/500 TFS Unit 1 Assist E-Line (Load and Kill) Pumped a total of 6
BBLS of 60/40 150 BBLS of SeaWater and 36 BBLS of Diesel to Load and Freeze
Protect the Tubing to 2500ft. E-Line in control of Well upon Departure. Freeze Protect
Tag on Wing Valve. FWHP=1400/240/500
3/9/2025
***CONTINUED FROM 8-MAR-25 WSR***
CONTINUE POOH
RDMO BAKER
LAYDOWN FOR REST
RETURN TO RDMO HES
5/6/2025
LRS CTU 1 w/ 1.5" x .134" wall thickness DC-110.
Job Objective: Set IBP
MIRU. Standby on high winds. Complete rig up. Begin weekly BOP test 250/4000 psi.
***Continued to WSR on 5/7/25***
5/7/2025
LRS CTU 1 w/ 1.5" x .134" wall thickness DC-110.
Job Objective: Set IBP
Continue weekly BOP test 250/4000 psi. Trim 30' CT. M/U 2.4" GR/CCL logging
carrier with 3-1/2" nipple locator and 2.65" JSN drift. Tie-in at nipples and RIH to
7746' CTMD and log up to 7300', painting tie-in flag at 7650'. POOH. Load well with
slick 1% KCl. RIH with Baker 2.5" IBP. Tie-in at flag and circulate ball over
gooseneck. Let BHT stabilize for 3 hours before inflating with 1% KCl. Set IBP at
7710' MD (differential rating of ~2200 psi). Pressure test tubing and IBP to 1611 psi
WHP (1000 psi differential) and loss 58 psi in 10 mins. POOH pumping pipe
displacement down coil to finish freeze protect.
...Continued on WSR 5-8-25....
Daily Report of Well Operations
PBU V-105
5/8/2025
LRS CTU #1 - 1.50" Blue Coil ***Cont. from WSR 5-7-25***
Job Objective - Set IBP
Cont. to POOH pumping pipe displacement. Tubing Freeze protect complete. Rig
down CTU.
***Job Complete***
DATA SUBMITTAL COMPLIANCE REPORTAPI No.50-029-23097-60-00Well Name/No.PRUDHOE BAY UN BORE V-105L1Completion StatusWAGINCompletion Date2/2/2022Permit to Drill2210800OperatorHilcorp North Slope, LLCMD9795TVD6606Current StatusWAGIN8/19/2022UICNoWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:MWD/GR/RESNoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleDF3/30/20227655 9795 Electronic Data Set, Filename: PBU V-105L1 Gamma Res.las36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1 Gamma Res.ASC36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1_ PWD Log Run 01.ASC36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1_ PWD Log Run 02.ASC36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1_ PWD Log Run 03.ASC36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1_ PWD Log Run 04.ASC36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1_ PWD Log Run 05.ASC36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1_ PWD Log Run 06.ASC36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1_ PWD Log Run 07.ASC36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1_ PWD Log Run 08.ASC36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1_ PWD Log Run 09.ASC36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1_ PWD Log Run 10.ASC36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1_ PWD Log Run 11.ASC36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1 2MD.cgm36380EDDigital DataFriday, August 19, 2022AOGCC Page 1 of 4PBU V-105L1Gamma Res.las
DATA SUBMITTAL COMPLIANCE REPORTAPI No.50-029-23097-60-00Well Name/No.PRUDHOE BAY UN BORE V-105L1Completion StatusWAGINCompletion Date2/2/2022Permit to Drill2210800OperatorHilcorp North Slope, LLCMD9795TVD6606Current StatusWAGIN8/19/2022UICNoDF3/30/2022 Electronic File: PBU V-105L1 2TVDSS.cgm36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1 5MD.cgm36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1 5TVDSS.cgm36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1 Run 01 PWD.cgm36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1 Run 02 PWD.cgm36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1 Run 03 PWD.cgm36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1 Run 04 PWD.cgm36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1 Run 05 PWD.cgm36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1 Run 06 PWD.cgm36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1 Run 07 PWD.cgm36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1 Run 08 PWD.cgm36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1 Run 09 PWD.cgm36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1 Run 10 PWD.cgm36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1 Run 11 PWD.cgm36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1 2MD.PDF36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1 2TVDSS.PDF36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1 5MD.PDF36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1 5TVDSS.PDF36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1 Run 01 PWD.PDF36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1 Run 02 PWD.PDF36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1 Run 03 PWD.pdf36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1 Run 04 PWD.PDF36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1 Run 05 PWD.PDF36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1 Run 06 PWD.PDF36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1 Run 07 PWD.PDF36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1 Run 08 PWD.PDF36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1 Run 09 PWD.PDF36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1 Run 10 PWD.PDF36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1 Run 11 PWD.PDF36380EDDigital DataFriday, August 19, 2022AOGCC Page 2 of 4
DATA SUBMITTAL COMPLIANCE REPORTAPI No.50-029-23097-60-00Well Name/No.PRUDHOE BAY UN BORE V-105L1Completion StatusWAGINCompletion Date2/2/2022Permit to Drill2210800OperatorHilcorp North Slope, LLCMD9795TVD6606Current StatusWAGIN8/19/2022UICNoWell Cores/Samples Information:ReceivedStart Stop CommentsTotalBoxesSample SetNumberNameIntervalINFORMATION RECEIVEDCompletion ReportProduction Test InformationGeologic Markers/TopsY Y / NAYMud Logs, Image Files, Digital DataComposite Logs, Image, Data Files Cuttings SamplesY / NAYY / NADirectional / Inclination DataMechanical Integrity Test InformationDaily Operations SummaryYY / NAYCore ChipsCore PhotographsLaboratory AnalysesY / NAY / NAY / NADF3/30/2022 Electronic File: PBU V-105L1 2MD.tif36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1 2TVDSS.tif36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1 5MD.tif36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1 5TVDSS.tif36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1 Run 01 PWD.tif36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1 Run 02 PWD.tif36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1 Run 03 PWD.tif36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1 Run 04 PWD.tif36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1 Run 05 PWD.tif36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1 Run 06 PWD.tif36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1 Run 07 PWD.tif36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1 Run 08 PWD.tif36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1 Run 09 PWD.tif36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1 Run 10 PWD.tif36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1 Run 11 PWD.tif36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1_Definitive Surveys.pdf36380EDDigital DataDF3/30/2022 Electronic File: PBU V-105L1_Definitive Surveys.xlsx36380EDDigital DataFriday, August 19, 2022AOGCC Page 3 of 4
DATA SUBMITTAL COMPLIANCE REPORTAPI No.50-029-23097-60-00Well Name/No.PRUDHOE BAY UN BORE V-105L1Completion StatusWAGINCompletion Date2/2/2022Permit to Drill2210800OperatorHilcorp North Slope, LLCMD9795TVD6606Current StatusWAGIN8/19/2022UICNoComments:Compliance Reviewed By:Date:COMPLIANCE HISTORYDate CommentsDescriptionCompletion Date:2/2/2022Release Date:10/8/2021Friday, August 19, 2022AOGCC Page 4 of 4M. Guhl8/19/2022
David Douglas Hilcorp Alaska, 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 or fax to 907 564-4422.
Received By: Date:
Hilcorp North Slope, LLC
Date: 03/28/2022
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
DATA TRANSMITTAL – REVISED DISTRIBUTION
WELL: V-105L1 (Revised from V-105A)
PTD: 221-080
API: 50-029-23097-60-00 (Revised from 50-029-23097-01-00)
FINAL LWD FORMATION EVALUATION LOGS (01/24/2022 to 01/29/2022)
Multiple Propagation Resistivity & Gamma Ray
(2” & 5” MD/TVD Color Logs)
Final Definitive Directional Surveys
SFTP Transfer - Data Folders:
Please include current contact information if different from above.
221-080
T36380
Meredith Guhl Digitally signed by Meredith Guhl
Date: 2022.03.30 12:53:58 -08'00'
1a. Well Status:Oil SPLUG Other Abandoned Suspended
1b. Well Class:
20AAC 25.105 20AAC 25.110 Development Exploratory
GINJ WINJ WDSPL No. of Completions: _1 Service Stratigraphic Test
2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry:
Aband.:
3. Address: 7. Date Spudded: 15. API Number:
4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number:
Surface:
Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s):
GL: 53.8' BF:
Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation:
4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number:
Surface: x- y- Zone- 4
TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD:
Total Depth: x- y- Zone- 4
5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD:
Submit electronic information per 20 AAC 25.050 (ft MSL)
22.Logs Obtained:
23.
BOTTOM
20" H-40 109'
9-5/8" L-80 2,752'
7" L-80 6,637'
24. Open to production or injection? Yes No 25.
26.
Was hydraulic fracturing used during completion? Yes No
DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED
27.
Date First Production: Method of Operation (Flowing, gas lift, etc.):
Hours Tested: Production for Gas-MCF:
Test Period
Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr):
Press. 24-Hour Rate
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
CASING, LINER AND CEMENTING RECORD
List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion,
TUBING RECORD
7,555' / 6,445'
5,268'
5,268' - 7,613'
4-1/2" 12.6# L-80
SIZEIf Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date Perfd):
171 sx Class 'G', 304 sx 'G'
42"
28' 2,972' 488 sx PF 'L', 293 sx Class 'G'
260 sx Arctic Set (Approx.)
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
Hilcorp North Slope, LLC
WAG
Gas
3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503
2/2/2022
4859' FSL, 1693' FEL, Sec. 11, T11N, R11E, UM, AK
1924' FSL, 2325' FEL, Sec. 02, T11N, R11E, UM, AK
221-080
Borealis Oil/Schrader Bluff Oil, Orion Dev Area
82.3'
9,795' / 6,606'
Prudhoe Bay Field /
HOLE SIZE AMOUNT
PULLED
50-029-23097-60-00
PBU V-105L1
590607 5970107
1942' FSL, 1190' FEL, Sec. 02, T11N, R11E, UM, AK
CEMENTING RECORD
5972476
SETTING DEPTH TVD
5972444
BOTTOM TOP
8-3/4"
29'
12-1/4"28'
CASING WT. PER
FT.GRADE
591079
589945
TOP
SETTING DEPTH MD
29'
Per 20 AAC 25.283 (i)(2) attach electronic information
26# 25'
DEPTH SET (MD)
5,211' / 4,273'
PACKER SET (MD/TVD)
x 3-1/2" 9.2# L-80
91.5#
47#
109'
25' 7,750'
Gas-Oil Ratio:Choke Size:Water-Bbl:
PRODUCTION TEST
3/6/2022
Date of Test:
Flow Tubing
Oil-Bbl:
suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray,
caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation
record. Acronyms may be used. Attach a separate page if necessary
MI Injection
3-1/4" Open Hole 1/28/2022
7750' - 9795' 6637' - 6606'
MWD / GR / RES
Sr Res EngSr Pet GeoSr Pet Eng
Oil-Bbl: Water-Bbl:
1/28/2022
1/25/2022
ADL 028240
00-001
1900' (Approx.)
7,750' / 6,637'N/A
None
9,795' / 6,606'
Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment
By Meredith Guhl at 1:29 pm, Mar 14, 2022
Completion Date
2/2/2022
MDG
MGR18AUG2022 DLB 03/23/2022
DSR-3/14/22
G
RBDMS 3/14/2022 MDG
Conventional Core(s): Yes No Sidewall Cores:
30.
MD TVD
Top of Productive Interval 5392' 4430'
5206' 4269'
5392' 4430'
5903' 4891'
7440' 6332'
7651' 6539'
7740' 6627'
7748' 6635'
7750' 6637'
7911' 6760'
8240' 6748'
KUP C (From Base) 8240' 6748'
31. List of Attachments:
32. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Contact Name: Joe Lastufka
Contact Email:joseph.lastufka@hilcorp.com
Authorized Contact Phone: 777-8400
General:
Item 1a:
Item 1b:
Item 4b:
Item 9:
Item 15:
Item 19:
Item 20:
Item 22:
Item 23:
Item 24:
Item 27:
Item 28:
Item 30:
Item 31:
If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form,
if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071.
Authorized Name: Monty Myers
Authorized Title: Drilling Manager
Kalubik
Kuparuk D
Kuparuk C
Permafrost - Base
29. GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS
Permafrost - Top
HRZ
Schrader Bluff N
Schrader Bluff O
This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram
with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical
reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted.
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis,
paleontological report, production or well test results, per 20 AAC 25.070.
Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each
segregated pool is a completion.
TPI (Top of Producing Interval).
Yes No
Well tested? Yes No
28. CORE DATA
If yes, list intervals and formations tested, briefly summarizing test results.
Attach separate pages to this form, if needed, and submit detailed test
information, including reports, per 20 AAC 25.071.
NAME
Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical
laboratory information required by 20 AAC 25.071.
Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion,
suspension, or abandonment, whichever occurs first.
Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
Kicked off from Parent (V-105)
Formation at total depth:
Base OBf / Colville
Drilling and Completion Report, Definitive Directional Survey, Wellbore Schematic
Signature w/Date:
Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345),
and/or Easement (ADL 123456) number.
INSTRUCTIONS
The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements
given in other spaces on this form and in any attachments.
The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain).
Kuparuk B
Kuparuk C (Invert)
Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and
other tests as required including, but not limited to: core analysis, paleontological report, production or well test results.
Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29.
Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool.
If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the
producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,
showing the data pertinent to such interval).
Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit
detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity,
permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology.
Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment
3.14.2022Digitally 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: 2022.03.14 09:33:58 -08'00'
Monty M
Myers
Activity Date Ops Summary
1/21/2022 Continue spot rig.Connect PUTZ - Warm up rig - start steam - find master valve not holding - call grease crew and service all valves - continue NU BOP's.
1/22/2022 Finish rig up ops. Take on fluids. Nipple up BOPE. Begin fluid pack coil tubing. and surface lines. Verify valve alignment. PU test joint and tools. Begin initial
BOPE test - test witness was waived via email from AOGCC inspector Guy Cook on 1-19-2022 @ 08:12. Complete Test #1 - IRV, Pack off, C7, C9, C10, C11.
Complete Test #2 - B/S Rams, R2, B2, C13. Complete Test #3 - Annular, TIW #1, B1, B4. Complete Test #4 - Upper 2" P/S, TIW #2, B2, B3 Complete Test #5 -
Lower 2" P/S, C5, C8, TV #2. Complete Test #6 - Choke A, Choke C. Complete and time draw down test on Accumulator. Complete Test #7 - Upper 2" P/S, C1, C4
and TV #1. Complete Test #8 - 2 3/8" P/S, C2, C3 Clear and clean rig floor. Prep for initial nozzle run and fluid displacement of well. MU and PT PDL. MU QTS MU
BHA #1 - 2.75" JSN for well displacement. Confirm line to return tank is clear. Replace leaking chicksan and re-test. Load coil with 22 bbls of MeOH. Begin loading
coil with KCL.
1/23/2022 Load reel with 20 bbls Methanol. Tail with 1% Slick KCL. Troubleshoot out MM. Blow down and calibrate with freshwater. Zero circulating pressure transducer.
Pressure up to 5000 psi. Verify. -Initial Entry. Pressure up to 800 psi. Open well to closed choke. 770 psi on well. Break circulation 0.50 bpm. Rih to 7813' MD.
No sign of whipstock. Discuss with Drilling engineer. Circulate well over to 1% Slick KCL. Swap over to 8.7 ppg Powerpro. Start second gen. Increase rate to 3.81.
Circulate mud surface to surface. Burp lubricator to bleed tank. Bring returns inside. POOH OOH. LD 2.75" JSN BHA. MU PDL and prep to pressure deploy READ
40 arm caliper Pressure deploy READ 40 arm caliper logging BHA. RIH with BHA #2 - READ 40 arm caliper logging BHA @ 80 fpm slowing down for all restrictions
and jewelry. Log Tie-In from 7670'. Correct +8'. RIH to 7860'. PUH in tension to 7850' and wait for timer on caliper arms. Log from 7850' to 7630' @ 50 fpm with
caliper arms out. 35k up weight. Stop and wait for arm to retract. POOH.
1/24/2022 Un-deploy BHA#2. Lay down READ caliper. Download Data. Good Data. Send off for process. Make up whipstock. READ report arrived. Casing looked to be in
great shape. Pressure deploy whipstock BHA. Rih BHA#3. Rate in: 0.38 bpm, Rate out: 0.37 bpm. Circ pressure: 1413 psi. MW in 8.67 ppg / MW out 8.66 ppg Log
tie in with a -11' correction. Log across remaining formation and set depth. +1' correction. PUH to 7600' MD. Log CCL down from 7600' to 7850' Collars on
depth. PUH above set depth. Rih to 7754.82'. PU to neutral weight. Whipstock top 7746' MD. Pinch Point 7750' MD. Set whipstock. Close EDC. Start pressure up
1500 differential. WOB increased. Then sheared out. Stack 7K on whipstock. Good set. Pick off clean. POOH Pressure un-deploy NS whipstock setting tool. PU
and deploy BHA #4 - Window mill with 2.80" mill and string reamer RIH with BHA #4. Log tie-in from 7690' @ 5fpm. Correct -10' PUH and WT CK 35k. Close EDC
and orient for high side exit. Dry tag @ 7750' with 1.4k down wt. Bring pumps on and establish free spin. In MW = 8.68ppg, Out MW = 8.67ppg. In Rate = 1.75
bpm, Out Rate = 1.61 bpm. Circ Pressure = 3655 psi Begin time milling window per NS rep from 7750'. In MW = 8.66ppg, Out MW = 8.66ppg. In Rate = 1.78 bpm,
Out Rate = 1.60 bpm. Circ Pressure = 3735 psi. Continue milling window from 7751.8'.
1/25/2022 Continue time milling window per NS rep from 7751.8'. In MW = 8.65ppg, Out MW = 8.66ppg. In Rate = 1.78 bpm, Out Rate = 1.60 bpm. Circ Pressure = 3678 psi.
Continue milling window from 7751.8'. Stalled at 7752.16' MD. In MW = 8.65ppg, Out MW = 8.66ppg. In Rate = 1.78 bpm, Out Rate = 1.60 bpm. Circ Pressure =
3735 psi. Continue milling window from 7751.8' to 7752.3' MD. Exited casing. Work string reamer down across exit point. Drill rathole to 7763' md. Rate in: 1.51
bpm in, Rate out: 1.59 bpm Circ pressure: 3648 psi. MW in: 8.65 ppg, MW out: 8.66 ppg. Window ECD: 11.33ppg. WOB: 0.6K. Perform reaming passes 15 deg
LOHS,15 deg ROHS Dry drift. Tag on wings. Bring pump up to rate. Work mill and reamer down at 0 deg. Minor motor work. Motor work at 7749.3' with minimal
weight. Stack 7753.3' MD. Taking weight. Clean up top of window. Still taking weight. Stalled at 7753.44' shut pump down. Overpull 2K. Stage weight down.
Looks to be cleaning up. 100 psi motor work. Milling off. Have to work lip on. Stall at bottom of window. Run cleanly to 7770' MD. PUH without issue. Looks like we
either rolled off and tracking casing. Discuss with Drilling engineer. Pooh for Build BHA. Rate in: 0.78 bpm, Rate out: 0.97 bpm. MW in: 8.67 ppg, MW out: 8.69
ppg. Pressure un-deploy window milling BHA. Window mill 2.78" no-go. String Reamer 2.79" no-go MU swizzle stack to jet stack. Replace injector pack-offs. PT
pack offs to 3500 psi. Good. Jet stack. Pressure deploy Build BHA #5. 2 3/8" X-Treme motor and 2.75° AKO and 2.74" x 3.25" Bi-Center bit RIH with BHA #5. Log
Tie In from 7680' @ 5fpm. Correct -9' Close EDC. WT CK 34k RIH to dry tag @ 15fpm. Tag @ 7756.5k (7758.5k with 6k down weight). Discuss plan forward with
Drilling Engineer. Will plan on beginning drilling as close to tag depth as possible and watch near bit inclination. Tag @ 7756'. PUH to neutral weight. Bring on
pumps to 1.5 bpm. 3400 psi free spin Drilling build section f/7774' t/7847'. In MW = 8.70ppg, Out MW = 8.69ppg. In Rate = 1.50 bpm, Out Rate = 1.56 bpm. Circ
Pressure = 3578 psi. Continue drilling build section from 7847'. In MW = 8.58 ppg, Out MW = 8.71 ppg. In Rate = 1.43 bpm, Out Rate = 1.41 bpm. Circ Pressure =
3544 psi.
1/26/2022 Continue drilling build section from 7847'. In MW = 8.71 ppg, Out MW = 8.71 ppg. In Rate = 1.62 bpm, Out Rate = 1.62 bpm. Circ Pressure = 3871 psi Drilling
build section from 7847' to 7976' MD (6691.1 TVDss) Landed build. Start making turn. In MW = 8.74 ppg, Out MW = 8.75 ppg. In Rate = 1.61 bpm, Out Rate =
1.63 bpm. Circ Pressure = 4150 psi. Drilling build. In MW = 8.75 ppg, Out MW = 8.77 ppg. In Rate = 1.61 bpm, Out Rate = 1.63 bpm. Circ Pressure = 4146 psi
Window ECD: 11.41 ppg. Perform 150' wiper. Drilling build to 8236'. In MW = 8.78 ppg, Out MW = 8.79 ppg. In Rate = 1.62 bpm, Out Rate = 1.69 bpm. Circ
Pressure = 4225 psi Window ECD: 11.39 ppg. Pump 5 bbls lo / hi vis sweeps at 8230' ROP slows, do a short pickup from 8236'. Clean pass up and down. Pump
another 5 bbls lo / hi vis sweeps. Drill to 8262'. POOH for BHA change. Clean pass to window. Perform 50' jog below window. Pull through window at 0.3 bpm, 0
TF, 25 ft/min, see 1k on DWOB. Perform jog above window then open EDC. Pump 2.8 bpm / 5900 psi while pulling slowly through 7". PJSM with crews then
undeploy BHA #5. Lay down BHA #5. Move cart over and check CT for wear spots. Spot with 25% wall loss is found. Remove UQC and CT connector. Cut off 20'
of pipe. Install new CT connector, pull test is good. Install UQC and PT, good. Perform weekly Function test BOPs.
50-029-23097-01-00API #:
Well Name:
Field:
County/State:
PBW V-105A
Prudhoe Bay West
Hilcorp Energy Company Composite Report
, Alaska
Dry tag @ 7750'
window from 7751.8' to 7752.3' MD
1/27/2022 PJSM, Make up BHA#6 with agitator. Pressure deploy BHA#6 Rih w/ BHA#6. Rate in: 0.51 bpm, Rate out: 0.78 bpm. MW in: 8.84 ppg, MW out: 8.84 ppg out. Circ
Pressure: 2179 psi. Window ECD: 11.4 ppg. Log tie in with -8' correction. Sat down at 7758' twice. Discuss with drilling engineer options. Come online at drilling
rate and 0 deg toolface. Work way into old hole. Drop rate back to min. Continue in the hole. Drilling 3.25" Lateral from 8261' MD to 8301' MD. Free Spin: 4740 psi
@ 1.63 bpm. Rate in: 1.66 bpm, Rate out: 1.68 bpm. MW in: 8.63 ppg, MW out: 8.83 ppg out Circ Pressure: 5003 psi. WOB: Window ECD: 11.4 ppg. Drilling
3.25" Lateral from 8300' MD.- Free Spin: 4270 psi @ 1.64 bpm. Rate in: 1.64 bpm, Rate out: 1.68 bpm. MW in: 8.58 ppg, MW out: 8.68 ppg out. Circ Pressure:
4340 psi. WOB: 2.75K. Window ECD: 11.4 ppg. Drilling 3.25" Lateral from 8386' MD. Free Spin: 4385 psi @ 1.65 bpm. Rate in: 1.64 bpm, Rate out: 1.68 bpm.
MW in: 8..61 ppg, MW out: 8.62 ppg out Circ Pressure: 4686 psi. WOB: 2.8K Window ECD: 11.4 ppg. Pump 5 /5 LoVis, HiVis sweep. BHA wiper from 8385' Drill
to 8432'. BHA wiper here is clean both ways, continue drilling. Free spin 4650 psi @ 1.75 bpm. MW in 8.56 ppg MW out 8.64 ppg. 100' pickup at 8492' is clean
both ways. ROP varies 15 - 35 ft/hr. At 8540' pump 5/5 bbls lo / hi vis. Drill to 8650'. Pull 100' wiper from 8650'. Clean pass up and down. At 8670' pump 5/5 bbls
lo/hi vis sweeps. Drill to 8700'. Wiper trip from 8700'. Clean pass back to window. 50' jog below window then pull through window at 25 ft/min, 0 TF, 0.4 bpm
nothing seen. Perform jog above window then open EDC. Pump 2.8 bpm / 5600 psi while pull slowly through 7". While cleaning 7" one rig gen goes down, then the
other. Shut in well at choke, monitor stripper and shaker. Restart gens. Restart acquisition systems. Troubleshoot generators, pump min rate maintain 11.4# ECD
and move pipe slowly in casing. Resume circulating 2.5 bpm / 5000 psi. Pump 5/5 bbls lo/hi vis sweeps around. Tie-in depth while pumping sweeps. RIH pass
through window at 0 TH, 0 pump tag at 7766'. Go to 0.5 bpm and MAD pass build 10 ft/min. Stacking wt, adjust logging speed and pump to keep CT moving.
Continue RIH to bottom. Drill from 8701'. - 1.79 / 1.81 bpm @ 4900 psi free spin. MW 8.64 / 8.65 ppg In / Out. Initial ROP is 100 - 130 ft/hr with 2.k DWOB. ECD is
11.43 ppg with 590 psi WHP.
1/28/2022 Drill from 8701' MD to 9230 MD. 4900 psi @ 1.80 bpm. Rate In: 1.80 bpm, Rate out: 1.83 bpm Circ Pressure: 5044 psi. MW in: 8.69 ppg, MW out: 8.74 ppg.
Pump 5/5 sweep. Long wiper. Rate In: 1.83 bpm, Rate out: 1.83 bpm. Circ Pressure: 5111 psi. MW in: 8.71 ppg, MW out: 8.74 ppg. PUW: 37K. Perform jog below
window. Pull through at min rate. Jet 7" up to tubing tail. Log tie in +3' correction. CCL log for liner top. PUH to 7440' MD. Log CCL from 7450' MD to 7740' MD Drill
from 9230' MD to 9327' MD. Free Spin: 4895 psi @ 1.79 bpm. Rate In: 1.80 bpm, Rate out: 1.83 bpm. Circ Pressure: 5044 psi. MW in: 8.71 ppg, MW out: 8.71
ppg. WOB: 1.9K, Window ECD 11.46 ppg w/ 556 psi choke. Drill from 9327' MD to 9600'. 5012 psi @ 1.80 bpm. Rate In: 1.80 bpm, Rate out: 1.87 bpm Circ
Pressure: 5041 psi. MW in: 8.71 ppg, MW out: 8.71 ppg. WOB: 1.5K, Window ECD 11.41 ppg w/ 500 psi choke. 100' pickup at 9568'. Drill from 9600' to 9792'. -
Frequent pickups for wt transfer, some overpulls. 100' wiper at 9670'. Pump 5/5 bbls lo/hi vis sweeps at 9700' and 9750'. Drill to 9776', stacking weight pull 200'
wiper trip. Call TD at 9792'. Wiper back to 7800'. Sweeps are just exiting bit. MW 8.73 / 8.76 ppg In / Out. Mostly clean pass, some drag below window. Turn
around at 7800'. RIH to bottom at 0.5 bpm, clean pass. Pump 5/5 lo/hi vis sweeps around on bottom. Pull back to window 1.8 bpm / 4900 psi. Keep 11.43# ECD
with 471 psi WHP. 4k overpull at 7834'. Perform jog below window. Pull through window 0.4 bpm, 0 TF, 25 ft/min nothing seen. Jog above window then open EDC.
Pump 2.7 bpm / 5700 psi while pull slowly through 7". Make 2 passes across 7". Pull wiper trip to surface. 2.5 bpm / 5200 psi keep 11.4# ECD at window.
1/29/2022 Pull wiper trip to surface. 2.5 bpm / 5200 psi keep 11.4# ECD at window. Tag up and correct depth at surface. Rih. Rate in: 2.5 bpm, Rate out: 2.76 bpm. MW in:
8.68 ppg, MW out: 8.69 ppg. Log tie in from 7675 to 7736.33' with a -10' correction. Work way through window to 7900' MD. Fell from there to a corrected TD of
9795' without issue. Circulate Beaded Liner running pill down. Lay in from bottom till 8000' MD. Lay 11.4 ppg KWF from through window. Open EDC. Finish
circulating 11.4 to surface. Perform 30 min flow check. Well static. Break circulation. Took 0.5 bbls to fill up. Pooh. Paint Orange Flag at 7500.93' BHI Bit Depth
(7422.66' CEOP). Paint White Flag at 5400.19' BHI Depth (5321.92' CEOP). Rate in: 0.99 bpm, Rate out: 0.59 bpm. MW in 11.4 ppg, MW out 11.3+ ppg. Some
light fluid seen coning back, RIH to window and circ B/U. Confirm 11.4# In / Out with micromotion and hydrometer. 30 min flow check is static. POOH. Repaint flags.
Tag stripper, 10 min flowcheck is good. Flush surface lines to KWF to prep for liner. L/D BHA #6. Bit is 1-3 with 2 missing cutters on shoulder. Change out floats on
UQC. Restart Orion job. Prep rig floor for liner. PT break in UQC, good. M/U liner with NS ORCA valve as per tally. M/U BHI CoilTrak on top of liner.
1/30/2022 Finish liner make up. Install Injector. Rih to white flag at 7607.7 MD. Correct depth to 7595.22' with a -12.5' correction. Rih. Run through window without issue.
Tagging up at 7770 MD area. Work ratchet. No joy. PUH to 7270' MD to change geometry of tools. Rih and continue working R&R tool. No issues going through
window. Start taking weight at 7765-66' MD'. Come off pump completely. Work ratchet around the dial with same results. Discuss with Drilling engineer. Decision to
pooh and lay liner down. Pooh with Liner. Perform 10 min flow check. Well static. Put well on minimal choke to combat swabbing coming out of hole. Rate in: 0.71
bpm, Rate out: 0.32 bpm. MW in: 11.49 ppg, MW out 11.44 ppg. At surface. Flow check. Static. Inspect pipe. Lay down Coil Trak . G-Spear, Deployment Sleeve.
Kick while tripping drill with new crew. AAR. Continue pulling liner. Lay down shoe track. Review new liner string. Make up liner BHA #8 with NS glide shoe and 1
deg bent sub + 12 jts. Make up CoilTrak on top of liner. Open EDC and RIH. Pump min rate. Tie-in depth, correct -9'. Stop at 7700' and close EDC. Pump min rate.
Pass window with no issues. Tag at 7771'. Pick up and ratchet tool all the way around 2x, still tagging 7771'. Total of 24 cycles. Try pumps on, pumps off, various
running speeds. Clean pickups each time. Not able to pass 7771'. Pick up and open EDC. POOH pump 1 bpm through EDC. Paint window flag at 5800.4' bit depth
(5348.6' EOP) Tag stripper, 10 min flowcheck is static. Trip sheet is -5.6 bbls for the trip. L/D BHI tool, L/D 12 jts of liner and shoe track. Clear rig floor. Pick up BHA
#9, cleanout BHA.
1/31/2022 Finish make up of cleanout BHA. Stab injector. Test QTS Rih w/ BHA#9. Rate in: 0.31 bpm, Rate out: 0.64 bpm. MW in: 11.51 ppg, MW out: 11.47 ppg. Circulating
Pressure: 250 psi. Log tie in from 7680' MD to 7724.24' with a -10' correction. Circulate wellbore over to Powerpro. Rate in: 0.35 bpm, Rate out: 0.31 bpm. MW in:
8.90 ppg, MW out: 11.47 ppg. Circulating Pressure: 250 psi Close EDC. Run through window. Run down to 7790' without issue. Near bit inclination staying at
original hole inclination. Puh to 7760' MD. Log RA tag on whipstock at 7752' MD. Inclination not climbing. Have MWD print log of near bit inclination of drilled hole.
Discuss with engineer. Roll tool face 20 deg LOHS. Tag at 7753' MD (Bottom of window). Roll tool face 10 deg LOHS. Tag at 7765' MD Taking weight. Near bit
inclination climbing off tray. Work as far as 7770' MD. Pooh w/ BHA#9. Rate in: 1.92 bpm, Rate out: 1.60 bpm. MW in: 8.96 ppg, MW out: 8.83 ppg. Circulating
Pressure: 4041 psi. Window ECD: 11.44 ppg. PJSM, Pressure un-deploy BHA. Maintain 11.4 ppg ECD. Deploy BHA #10, build BHA with 2.5 deg AKO. Update
fatigue modeling for this reel. RIH BHA #10. Tie-in depth, no correction. Stop above window and close EDC. Pass through window with no issues and go to min
rate. Keep as drilled TF. Tag at 7771', 2 times. Bring rate up to 0.8 bpm then 1 bpm to get past at 3 - 5 ft/min. RIH past 7774' adjust rate and ROP to keep CT
moving ahead. RIH to 7787' stacking here. Go to 1.4 bpm / 3 ft/min Continue RIH past 7798'. Pump 5 bbls hi-vis. At 7819' pull wiper trip back to 7770'. Turn around
and stacking wt right away, can't get back to 7819' with same TF. Indication from near bit inc of drilling new hole. Discuss with ODE. Pull through window and clean
7". Tie-in depth above window, correct +2'. Close EDC and pass through window. Go to 10-30L TF. Go to min rate stack wt at 7760'. Pick up go to 0.8 bpm.
Stacking wt 7772'. POOH. Pump 5 bbls hi-vis clean well to prep for cement job. Flag pipe at 6694' EOP. Tag stripper and space out. Undeploy BHA #10.
Call TD at 9792'.
Drill to 9776',
2/1/2022 Finish pressure undeploy of BHA. Service rig. Wait on decision of asset team. Decision came to circulate wellbore over to 1% KCL and freeze protect. Order fluids,
and Inform onsite team of plan forward. Attempt to circulate. Pressures high. Pull floats, No luck. Stab on and reverse circulate volume backwards. At five barrel
started moving fluids. Once over displacement. What appears to be a polymer wad came across shaker. Circulate forward. Cleaned up. Stab off. Make up floats and
test Rih w/ DFV, stinger, 2.75" JSN. Rate in: 0.49 bpm, Rate out: 0.65 bpm. MW in: 8.95 ppg, MW out: 8.96 ppg. Drive by flag. -12' correction. Stop with stinger at
7744' MD. Circulate well over to 1% Slick KCL from 7744' MD. Rate in: 1.99 bpm, Rate out: 2.15 bpm. MW in: 8.5 ppg, MW out: 8.96 ppg. Circulate 60/40
Methanol from 2500' TVD. Pooh pumping pipe displacement. Tag stripper, close MV. Bleed off pressure, pump remaining MeOH to tiger tank. Remove check
valves from UQC. PT break is good. Work through rig down checklists. Purge rig lines with air.
2/2/2022 Continue empty pits. Break return line (B6 line), pick up slack and rotate for more clearance in cellar. Continue rig down checklists. Rig Release 06:00. RDMO.
Decision came to circulate wellbore over to 1% KCL and freeze protect.
David Douglas Hilcorp Alaska, 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 or fax to 907 564-4422.
Received By: Date:
Hilcorp North Slope, LLC
Date: 02/28/2022
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
DATA TRANSMITTAL
WELL: V-105A
PTD: 221-080
API: 50-50-029-23097-01-00
FINAL LWD FORMATION EVALUATION LOGS (01/24/2022 to 01/29/2022)
Multiple Propagation Resistivity & Gamma Ray
(2” & 5” MD/TVD Color Logs)
Final Definitive Directional Surveys
SFTP Transfer - Data Folders:
Please include current contact information if different from above.
221-080
T36380
Meredith Guhl Digitally signed by Meredith Guhl
Date: 2022.02.28 16:17:51 -09'00'
From:Rixse, Melvin G (OGC)
To:Sean Mclaughlin; Brodie Wages
Cc:DOA AOGCC Prudhoe Bay
Subject:20220202 1057 V-105A (PTD 221-080) MIT-T and MIT-IA Request
Date:Wednesday, February 2, 2022 10:59:23 AM
Brodie,
As discussed, please perform an MIT-T (30 minute charted) to maximum expected header
injection pressure and an MIT-IA (to .25 psi/ft * TVD) before injection begins as per 20 AAC 25.412
(c). This should have been highlighted in the Permit to Drill. This was an oversight.
Within 2 weeks of stabilized injection, 24 hour notice for AOGCC to witness MIT-IA (to .25 psi/ft
*TVD).
Mel Rixse
Senior Petroleum Engineer (PE)
Alaska Oil and Gas Conservation Commission
907-793-1231 Office
907-223-3605 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).
cc. Sean McLaughlin, AOGCC Inspectors
From: Rixse, Melvin G (OGC)
Sent: Wednesday, February 2, 2022 8:54 AM
To: Sean Mclaughlin <Sean.Mclaughlin@hilcorp.com>
Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Joseph Lastufka
<Joseph.Lastufka@hilcorp.com>
Subject: 20220202 0851 V-105A (PTD 221-080) APPROVED to POI
Sean,
Hilcorp is approved to put well PTD221-080 (V-105A) on injection (POI). Please assure the 10-407
is submitted as normal.
Mel Rixse
Senior Petroleum Engineer (PE)
Alaska Oil and Gas Conservation Commission
907-793-1231 Office
907-223-3605 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
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.
in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov).
cc. Joe Lastufka, Bryan McLellan
From: Sean Mclaughlin <Sean.Mclaughlin@hilcorp.com>
Sent: Wednesday, February 2, 2022 8:08 AM
To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>
Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Joseph Lastufka
<Joseph.Lastufka@hilcorp.com>
Subject: V-105A (PTD 221-080)
Mel,
On V-105A the window was milled then the mill tracked casing for 21’ due to weak sand near
wellbore. The build and lateral sections were drilled as planned. Two attempts were made to run
liner however the liner was entering the sump where casing was tracked. Two cleanout runs were
made without establishing access to the drilled hole. The near wellbore region has washed out and
all assemblies are tracking casing.
The plan forward for V-105A is to leave an openhole completion and place the well on injection.
Hilcorp requests approval to place the well on injection ASAP in order to apply pressure to the
wellbore to maintain stability.
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:Sean Mclaughlin
Cc:McLellan, Bryan J (OGC); Joseph Lastufka
Subject:20220202 0851 V-105A (PTD 221-080) APPROVED to POI
Date:Wednesday, February 2, 2022 8:54:08 AM
Sean,
Hilcorp is approved to put well PTD221-080 (V-105A) on injection (POI). Please assure the 10-407
is submitted as normal.
Mel Rixse
Senior Petroleum Engineer (PE)
Alaska Oil and Gas Conservation Commission
907-793-1231 Office
907-223-3605 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).
cc. Joe Lastufka, Bryan McLellan
From: Sean Mclaughlin <Sean.Mclaughlin@hilcorp.com>
Sent: Wednesday, February 2, 2022 8:08 AM
To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>
Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Joseph Lastufka
<Joseph.Lastufka@hilcorp.com>
Subject: V-105A (PTD 221-080)
Mel,
On V-105A the window was milled then the mill tracked casing for 21’ due to weak sand near
wellbore. The build and lateral sections were drilled as planned. Two attempts were made to run
liner however the liner was entering the sump where casing was tracked. Two cleanout runs were
made without establishing access to the drilled hole. The near wellbore region has washed out and
all assemblies are tracking casing.
The plan forward for V-105A is to leave an openhole completion and place the well on injection.
Hilcorp requests approval to place the well on injection ASAP in order to apply pressure to the
wellbore to maintain stability.
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.
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/Pool(s):
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 V-105A
Extended Perf w CTU
Hilcorp North Slope, LLC
3800 Centerpoint Dr, Suite 1400,
Anchorage, AK 99503
221-080
50-029-23097-01-00
ADL 0028240
~9839
Conductor
Surface
Intermediate
Production
Liner
~6595
80
2944
7724
2279
~9809
20"
9-5/8"
7"
2-3/8"
~6596
29 - 109
28 - 2972
25 - ~7749
~7560 - ~9839
3207
29 - 109
28 - 2752
25 - ~6636
~6450 - ~6595
None
3090
5410
11780
None
5750
7240
11200
None 4-1/2" 12.6# x 3-1/2" 9.2#L-80 23 - 7613None
Structural
4-1/2" Baker Premier Packer
4-1/2" Baker S3 Packer
5211, 4273
7555, 6445
Date:
Stan Golis
Sr. Area Operations Manager
Brodie Wages
David.Wages@hilcorp.com
907.564.5006
Prudhoe Bay Field, Borealis Oil Pool / Schrader Bluff Oil Pool, Orion Development Area
2/1/22
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 10/2021 Approved application is valid for 12 months from the date of approval.
By Samantha Carlisle at 4:07 pm, Nov 09, 2021
321-576
Digitally signed by Stan Golis
(880)
DN: cn=Stan Golis (880),
ou=Users
Date: 2021.11.09 15:57:20 -09'00'
Stan Golis
(880)
Condition of approval: 1.5 wellbore volumes of KWF available on location expected to be greater than 11.3 ppg
MGR22NOV21
3207
DSR-11/10/21
10-404
DLB 11/10/2021
X
dts 11/23/2021
Jessie L.
Chmielowski
Digitally signed by Jessie L.
Chmielowski
Date: 2021.11.23 14:17:53
-09'00'
RBDMS HEW 11/24/2021
Add Perf Procedure
V-105A
PTD:221-080
Well Name:V-105A API Number:50-029-23097-01-00
Current Status:WAG Rig:Service coil
Estimated Start Date:02/1/2022 Estimated Duration:6days
Regulatory Contact:Abbie Barker Permit to Drill Number:220-080
First Call Engineer:John Condio (602) 373-0659 (c)
Second Call Engineer:Brodie Wages (713) 380-9836 (c)
Current Bottom Hole Pressure:3867 psi @ 6600’ TVD (11.3 PPGE pattern estimate)
The well was shut in 10/27/21 in prep for the CTD sidetrack, updated BH pressure estimates will be
obtained during the sidetrack drilling and post rig as needed
Max. Anticipated Surface Pressure:3207 psi (Based on 0.1 psi/ft. gas gradient)
Last SI WHP:0 psi (Current SITP)
Min ID:2.813” ID, X Nip @ 7542’ MD
Max Angle:108 Deg @ 8538’
Reference Log: N/A
Brief Well Summary:
V-105a is a planned CTD sidetrack that will target the C sands in the Borealis reservoir. The V-105a injector will
support producers V-111, V-102 and V-106A. V-111 was recently frac’d and is in need of some injection
support.
Objective:
Ext Perf Add post CTD
Sundry Procedure (Approval Required to Proceed):
Note: Drilling mud weights/ECDs will be used to estimate mud weight needed for this perf 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.
Coil Tubing
1. MIRU Coiled Tubing Unit and support equipment.
2. MU & Run logging BHA w/ ~1.70” nozzle. Tag liner hanger or nipple, flag pipe for depth correction (flag
will be used to tie-in for perforating runs) .
a. Circulate in KWF as needed
b. Cerberus modelling does not indicate we need safelube
c. Confirm pickup weights as needed with OE/SLB coilcade
d. Use RIH/POH weights to inform CoilCADE models to ensure guns can make it to target depth
3. Prepare for deployment of TCP guns.
4.Pickup safety joint and 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”
5. Break lubricator connection at QTS and begin makeup of TCP guns and blanks per schedule below.
*Use 1.56”, 6 spf, 60° phasing (or equivalent) guns
8.3” Penetration, 0.23 EHD
x Calibrate friction factor on logging run.
x Consult OE if Run 2 needs to be split into 2 runs.
*
Maintain continuous hole fill taking returns to tank
until lubricator connection is reestablished. mgr
Note high BHP of 11.3 ppg. Assure 1 tubing volume of KWF available on
on site before breaking containment to PU guns.
Add Perf Procedure
V-105A
PTD:221-080
V-105A Add Perf Schedule
Perf Interval Perf
Length
Gun
Length
Weight of
Gun (lbs)
at 5.6 ppf
Comments
Run 1 TBD 100 250’
Final lengths TBD on CTD TD
Run 2 TBD 100 250’
This program assumes two perforating runs to complete the well as desired. Final perforation depths will be
determined after the well has been drilled.
6. RIH with perf gun and tie-in to coil flag correlate. Pickup and perforate interval per Perf Schedule
above, note any change in tubing pressure in WSR.
7. POOH. Stop at surface for flow check, reconfirm well dead and hole full.
a. Recalculate KWF weight as necessary and bullhead kill the well
8. Review well control stepswith crew prior to breaking lubricator connection and commencing breakdown
of TCP gun string. Ensure well is freeze protected while POOH on final run.
9. RDMO CTU.
10. Hand well over to operations for POI.
Attachments:
1. Current Wellbore Schematic
2. Proposed Schematic
3. Coil Tubing BOPE Schematic
4. Equipment Layout Diagram
5. Standing Orders for Open Hole Well Control during Perf Gun Deployment
6. Cerberus modelling
Make up PCE. Pressure test QTS. mgr
Standing orders flow chart included
with this sundry request.
*See note above regarding kill methods if pressure observed
at surface after perforating.
Add Perf Procedure
V-105A
PTD:221-080
Current Wellbore Schematic
Add Perf Procedure
V-105A
PTD:221-080
Proposed Schematic
Add Perf Procedure
V-105A
PTD:221-080
Coiled Tubing BOPs
Add Perf Procedure
V-105A
PTD:221-080
Equipment Layout Diagram
Add Perf Procedure
V-105A
PTD:221-080
Standing Orders for Open Hole Well Control during Perf Gun Deployment
Add Perf Procedure
V-105A
PTD:221-080
Cerberus Modelling:
Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Work Over Sundry ProcedureDate: November 9, 2021Subject: Changes to Approved Sundry Procedure for Well V-105ASundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the workover (WO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.StepPageDate Procedure ChangeHNSPreparedBy (Initials)HNSApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date
Alaska Oil and Gas
Conservation Commission
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, %RUHDOLV2LODQG6FKUDGHU%OXII2LO3RROV, PBU V-105A
Hilcorp North Slope, LLC
Permit to Drill Number: 221-080
Surface Location: 4859' FSL, 1693' FEL, Sec. 11, T11N, R11E, UM, AK
Bottomhole Location: 1912' FSL, 2316' FEL, Sec. 02, T11N, R11E, 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 well logs
run must be submitted to the AOGCCwithin 90 days after completion, suspension or abandonment
of this well.
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 October, 2021.
Jeremy
Price
Digitally signed by
Jeremy Price
Date: 2021.10.08
14:17:16 -08'00'
1a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for:
Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates
Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas
2. Operator Name: 5. Bond: Blanket Single Well 11. Well Name and Number:
Bond No.
3. Address: 6. Proposed Depth: 12. Field/Pool(s):
MD: 9,839' TVD: 6,595'
4a. Location of Well (Governmental Section): 7. Property Designation:
Surface:
Top of Productive Horizon:8. DNR Approval Number: 13. Approximate Spud Date:
Total Depth: 9. Acres in Property: 14. Distance to Nearest Property:
10,900'.
4b. Location of Well (State Base Plane Coordinates - NAD 27):10.KB Elevation above MSL (ft): 82.3'15.Distance to Nearest Well Open
Surface: x-590608 y- 5970107 Zone- 4 53.8' to Same Pool: 1,540'
16. Deviated wells: Kickoff depth: 7,749 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035)
Maximum Hole Angle: 108 degrees Downhole: Surface:
Hole Casing Weight Grade Coupling Length MD TVD MD TVD
3-1/4" 2-3/8" 6.5# L-80 Hyd511 2,279' 7,560' 6,450' 9,839' 6,595'
19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations)
Junk (measured):
None
TVD
29' - 109'
28' - 2,752'
25' - 7,124'
Hydraulic Fracture planned? Yes No
20. Attachments: Property Plat BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis
Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements
Contact Name: Trevor Hyatt
Monty Myers Contact Email:trevor.hyatt@hilcorp.com
Drilling Manager Contact Phone:777-8396
Date:
Permit to Drill API Number: Permit Approval
Number:Date:
Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales:
Samples req'd: Yes No Mud log req'd: Yes No
H2S measures: Yes No Directional svy req'd: Yes No
Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No
Post initial injection MIT req'd: Yes No
APPROVED BY
Approved by: COMMISSIONER THE COMMISSION Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
December 15, 2021
21. I hereby certify that the foregoing is true and the procedure approved herein will not be
deviated from without prior written approval.
Surface
Perforation Depth TVD (ft):
GL / BF Elevation above MSL (ft):
Perforation Depth MD (ft):
2,944'
260 sx Arctic Set (Approx.) 29' - 109'
28' - 2,972'9-5/8" 488 sx PF 'L', 293 sx Class 'G'
Effect. Depth MD (ft): Effect. Depth TVD (ft):
Authorized Title:
Authorized Signature:
171 sx Class 'G, 304 sx Class 'G'Production
Liner
8,218'
Intermediate
Authorized Name:
5,392' - 7,806'
Conductor/Structural 20"80'
8,255'7,136'
LengthCasing
None
Cement Volume MDSize
Plugs (measured):
(including stage data)
73 sx Class 'G'
8,157' 7,039'
2560
18. Casing Program: Top - Setting Depth - BottomSpecifications
3,867
Total Depth MD (ft): Total Depth TVD (ft):
107205344
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
20 AAC 25.005
3,207
1942' FSL, 1190' FEL, Sec. 02, T11N, R11E, UM, AK
1912' FSL, 2316' FEL, Sec. 02, T11N, R11E, UM, AK
00-001
3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503
Hilcorp North Slope, LLC
4859' FSL, 1693' FEL, Sec. 11, T11N, R11E, UM, AK ADL 028240
PBU V-105A
Prudhoe Bay Field
Borealis Oil Pool / Schrader Bluff
Oil Pool, Orion Development Area
Cement Quantity, c.f. or sacks
Commission Use Only
See cover letter for other
requirements.50-029-23097-01-00
4,430' - 6,692'
25' - 8,243'7"
Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g)
9.30.2021
By Meredith Guhl at 8:55 am, Sep 30, 2021
X X
DLB221-080
DLB 10/04/2021
X
MGR07OCT2021
X
DSR-9/30/21
X
X
Separate sundry required for post rig extended perforating.
Variance to 20 AAC 25.112(i) approved for alternate plug
placement.
BOPE test to 3500 psi.
X
dts 10/8/2021
JLC 10/8/2021
10/8/21
Jeremy Price Digitally signed by Jeremy Price
Date: 2021.10.08 14:17:40
-08'00'
Well Name PTD API StatusTop of Oil Pool(Top Kuparuk,MD)Top of Oil Pool(Top Kuparuk,TVD)Top of class G Cmt(MD)Top of Cmt (TVD)Top ofCementDeterminedByReservoirStatusZonal IsolationCmt OpsSummaryMechanicalIntegrityV-07 207-141 50-029-23372-00-00OfflineOperableProducer7633 6571' 4770' 3996' 2007 USIT Un-perfedTOC above TVD of Kuparukzone489 sxLiteCrete, 188sx Class G7/6/2012 TIFLpassedV-05 208-093 50-029-23391-00-00OperableOnline Injector7882 6590' 3500' 3125' 2008 USIT Un-perfedTOC above TVD of Kuparukzone418 sxLiteCrete, 242sx Class G3/28/2020 MIT-IAto 3334 psi pass1st Stage: 7000' MD 1st Stage: 5907' TVD3/2/2021 MIT-T to3500 psi pass,2nd Stage: Above3960' (USIT logstopped at 3960')2nd Stage: Above3372' (USIT logstopped at 3372')2/13/2021 MIT-IAto 2814 psi passStage 1 cement job isolatesKuparuk, Stage 2 cementisolates Shrader interval171 sx Class G,304 sx Class Gtwo stageArea of Review PBU V-105202-131 50-029-23097-00-00V-105OfflineOperableInjector7740 6627' 2002 USIT Perforated
To: Alaska Oil & Gas Conservation Commission
From: Trevor Hyatt
Drilling Engineer
Date: September 29, 2021
Re: PBU V-105A Permit to Drill
Approval is requested for drilling a CTD sidetrack lateral from well PBU V-105A with the
Nabors CDR2 Coiled Tubing Drilling.
Proposed plan for V-105A Injector:
See the V-105 Sundry request for complete pre-rig details - Prior to drilling activities, a 3-1/2" x 7" Whipstock will
be set pre-rig with E-line in the 7" casing. The parent Kuparuk perforations and whipstock will be cemented pre-
rig (Schrader perfs will be behind tubing and dummied GLMs).
A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 rig. The rig will move in, test BOPE and kill the
well. A single string window exit (7” casing) + 10’ of rathole will be milled. The well will kick off in the Kuparuk C,
build through the C and land in Kuparuk B. The well will build back up and complete the lateral in Kuparuk C to
TD. The proposed sidetrack will be completed with a 2-3/8” L-80 solid liner, cemented in place and selectively
perforated post rig. This completion will completely isolate and abandon the parent Kuparuk perforations but will
NOT isolate and abandon the Schrader perfs.
The following describes the work planned. A wellbore schematic of the current well and proposed sidetrack is
attached for reference.
Pre-Rig Work:
x Reference PBU V-105 Sundry submitted in concert with this request for full details.
x General work scope of Pre-Rig work:
1.Slickline: Dummy WS drift and dummy GLMs
2.E-line: Set 3-1/2” x 7” whipstock
3.Service Coil: Cement whipstock*
4. Fullbore: MIT-IA
Rig Work (Estimated to start in December 2021):
1. MIRU and test BOPE to 3500 psi. MASP with gas (0.10 psi/ft) to surface is 3,207 psi
a. Give AOGCC 24hr notice prior to BOPE test
b. Test against swab and master valves (No TWC)
c. Load pits with drilling fluid
d.Open well and ensure zero pressure
2.Mill 2.80” single string window (out of 7”) plus 10’ of rathole.
a.Top of window (whipstock pinch point) at 7,749’ MD.
b.Mill window with 1.0° bend motor
c. Hold 11.8 ppg MPD while milling window
3. Drill – Build & Lateral
a. 2-3/8” BHA with GR/RES / Bi-center Bit (3.25”)
b.42° DLS build section – 418’ / Planned TD 8,167’ MD
c. 12° DLS lateral section – 1,672’ / Planned TD 9,839’ MD
d.Drill with a constant bottom hole pressure for entire sidetrack
e.Pressure deployment will be utilized
f.After TD and on the last trip out of hole lay in completion/kill weight fluid in preparation for liner run
g.No flow test prior to laying down drilling BHA
PTD 221-080
Sundry
p,py
This completion will completely isolate and abandon the parent Kuparuk perforations but willppg
NOT isolate and abandon the Schrader perfs.
pp
4. Run and Cement 2-3/8” L-80 solid liner
a. Have 2-3/8” safety joint with TIW valve ready to be picked up while running liner
b.Release from liner and come out of hole.
c. Make up cementing BHA and sting into liner shoe. Swap the well over to 2% KCl.
d.Cement liner with 15 bbls, 15.3 ppg Class G (TOC to TOL).*
e.Freeze protect well from ~2200’ MD (min)
f. RDMO
Post Rig:
1. V: Valve & tree work
2. S: SBHPS, set LTP* (if necessary). Set live WFRVs.
3.C: Post rig perforate (~500’).
* Approved alternate plug placement per 20 AAC 25.112(i)
Managed Pressure Drilling:
The history of CTD at KRU in the Kuparuk reservoir, has demonstrated the benefits of a managed pressure
drilling technique. Due to uncertainties about the bottom hole pressures to be encountered as this sidetrack is
drilled, managed pressure drilling techniques will be employed on this well. The intent is to provide constant
bottom hole pressure by using minimum 8.6 ppg drilling fluid in combination with annular friction losses and
applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability.
Applying annular friction and choke pressure also allow use of lighter drilling fluid and minimizes fluid losses
and/or fracturing at the end of the long well bores. A MPD choke for regulating surface pressure is located
between the WC choke manifold and the mud pits and will be independent of the WC choke.
Deployment of the BHA under trapped wellhead pressure will be necessary. Pressure deployment of the BHA will
be accomplished utilizing 3” (bighole) & 2-3/8” (slimhole) pipe/slip rams (see attached BOP configurations). The
annular preventer will act as a secondary containment during deployment and not as a stripper.
Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements
while drilling and shale behavior. The following scenario is expected:
MPD Pressure at the Planned Window (7,749’ MD - 6,554’ TVD)
Pumps On Pumps Off
A Target BHP at Window (ppg)4,022 psi 4,022 psi
11.8
B Annular friction - ECD (psi/ft)697 psi 0 psi
0.09
C Mud Hydrostatic (ppg)2,931 psi 2,931 psi
8.6
B+C Mud + ECD Combined 3,628 psi 2,931 psi
(no choke pressure)
A-(B+C)Choke Pressure Required to Maintain 393 psi 1,091 psi
Target BHP at window and deeper
Operation Details:
Reservoir Pressure:
x The maximum reservoir pressure is expected to be 3,867 psi at 6,600’ TVD (11.3 ppg equivalent).
x Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 3207 psi.
End of PTD221-080
Separate sundry required for perforating.
Minimum EMW required = 8.6 ppg. MPD used to maintain constant BHP for CTD well. DLB
Mud Program:
x Drilling: Minimum MW of 8.6 ppg KCL with Geovis for drilling. Managed pressure used to maintain
constant BHP.
x KWF will be stored on location. The tankage will contain 1.5 wellbore volumes of KWF to exceed the
maximum possible BHP to be encountered as the lateral is drilled. Adjust with real time BHP monitoring.
x Completion: A minimum MW 11.4 ppg KWF to be used for liner deployment. Will target 11.8 ppg to
match managed pressure target.
Disposal:
x All Class l & II non-hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4 or
Pad 3 at DS 6.
x Fluids >1% hydrocarbons or flammables must go to Pad 3.
x Fluids >15% solids by volume must go to GNI.
x Fluids with solids that will not pass through 1/4” screen must go to GNI.
x Fluids with PH >11 must go to GNI.
Hole Size:
x 3.25” hole for the entirety of the production hole section.
Liner Program:
x 2-3/8”, 6.5#, L-80 solid/cemented liner: 7,560’ MD – 9,839’ MD (2,279’ liner)
x The primary barrier for this operation: Kill Weight Fluid to provide overbalance as necessary
x A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole.
Well Control:
x BOP diagram is attached. MPD and pressure deployment is planned.
x Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi.
x The annular preventer will be tested to 250 psi and 3,500 psi.
x An X-over shall be made up to a 2-3/8” safety joint including a TIW valve for all tubulars ran in hole.
x 1.5 wellbore volumes of KWF will be on location at all times during drilling operations.
Directional:
x Directional plan attached. Maximum planned hole angle is 108°. Inclination at kick off point is 9°.
x Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run.
x Distance to nearest property line – 10,900’
x Distance to nearest well within pool – 1,540’
Logging:
x MWD directional, Gamma Ray, and Resistivity will be run through the entire open hole section.
x Real time bore pressure to aid in MPD and ECD management.
Perforating:
x ~500’ perforated post rig.
Anti-Collision Failures:
x No failures
Hazards:
x PBU V-pad is an H2S pad. The highest recorded H2S well on the pad was from V-117 (300 ppm) in 2007.
x No major fault crossings expected.
x Low lost circulation risk.
Trevor Hyatt CC: Well File
Drilling Engineer Joseph Lastufka
907-223-3087
PBU V-pad is an H2S pad. The highest recorded H2S well on the pad was from V-117 (300 ppm) in 2007.DLB
6WDQGDUG3URSRVDO5HSRUW
6HSWHPEHU
3ODQ 9$ZSD
+LOFRUS$ODVND//&
3UXGKRH%D\
9
3ODQ 9
3ODQ 9
60006100620063006400650066006700680069007000True Vertical Depth (200 usft/in)-3700 -3600 -3500 -3400 -3300 -3200 -3100 -3000 -2900 -2800 -2700 -2600 -2500 -2400 -2300 -2200 -2100 -2000 -1900 -1800Vertical Section at 200.00° (200 usft/in)V-105A wp04 tgt03V-105A wp04 tgt02V-105A wp04 tgt01V-105A wp04 polygon75008000V-1057" TOW2 3/8" x 3 1/4"80008 5 0 0
9 000
950 0
98 39V-105A wp08aKOP: Start Dir 9º/100' : 7749' MD, 6636.02'TVD : 120° LT TFStart Dir 42º/100' : 7769' MD, 6655.77'TVDStart Dir 42.19º/100' : 7967.67' MD, 6771.81'TVDStart Dir 12º/100' : 8167.67' MD, 6756.4'TVDTotal Depth : 9839' MD, 6595.05' TVDHilcorp Alaska, LLCCalculation Method:Minimum CurvatureError System:ISCWSAScan Method: Closest Approach 3DError Surface: Ellipsoid SeparationWarning Method: Error RatioWELL DETAILS: Plan: V-105Ground Level: 53.80+N/-S +E/-WNorthingEastingLatitudeLongitude0.000.005970107.31590607.90 70° 19' 41.0418 N 149° 15' 54.5721 WSURVEY PROGRAMDate: 2021-09-23T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool199.09 7749.00 Survey #1 (V-105) 3_MWD (BP MWD+IFR+MS-WOCA)7749.00 9839.00 V-105A wp08a (Plan: V-105) 3_MWDREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: V-105, True NorthVertical (TVD) Reference:KB @ 82.30usft (ORIG KELLY BUSHING)Measured Depth Reference:KB @ 82.30usft (ORIG KELLY BUSHING)Calculation Method: Minimum CurvatureProject:Prudhoe BaySite:VWell:Plan: V-105Wellbore:Plan: V-105Design:V-105A wp08aCASING DETAILSTVD TVDSS MD SizeName6637.01 6554.71 7750.00 7 7" TOW6595.05 6512.75 9839.00 2-3/8 2 3/8" x 3 1/4"SECTION DETAILSSec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation1 7749.00 9.45 6.27 6636.02 3145.77 667.27 0.00 0.00 -3184.28 KOP: Start Dir 9º/100' : 7749' MD, 6636.02'TVD : 120° LT TF2 7769.00 8.56 356.28 6655.77 3148.90 667.35 9.00 -120.00 -3187.24 Start Dir 42º/100' : 7769' MD, 6655.77'TVD3 7967.67 92.00 356.28 6771.81 3288.26 658.28 42.00 0.00 -3315.10 Start Dir 42.19º/100' : 7967.67' MD, 6771.81'TVD4 8167.67 95.18 271.75 6756.40 3414.76 527.77 42.19 -84.99 -3389.33 Start Dir 12º/100' : 8167.67' MD, 6756.4'TVD5 8537.67 107.63 228.13 6679.79 3296.75 195.52 12.00 -70.00 -3164.806 8837.67 93.06 194.55 6624.52 3048.11 46.50 12.00 -110.01 -2880.207 9012.67 91.78 215.53 6617.05 2890.60 -27.10 12.00 93.00 -2707.018 9162.67 91.70 233.54 6612.46 2784.17 -131.82 12.00 90.00 -2571.189 9337.67 91.58 212.53 6607.40 2657.02 -250.53 12.00 -90.00 -2411.1010 9597.67 91.35 243.74 6600.56 2485.70 -441.70 12.00 90.00 -2184.7211 9797.67 91.24 219.73 6595.98 2362.78 -597.55 12.00 -90.00 -2015.9112 9839.00 91.32 224.69 6595.05 2332.19 -625.31 12.00 89.00 -1977.67 Total Depth : 9839' MD, 6595.05' TVD
200021252250237525002625275028753000312532503375350036253750South(-)/North(+) (250 usft/in)-1250 -1125 -1000 -875 -750 -625 -500 -375 -250 -125 0 125 250 375 500 625 750 875 1000 1125West(-)/East(+) (250 usft/in)V-105A wp04 polygonV-105A wp04 tgt01V-105A wp04 tgt02V-105A wp04 tgt03400042504500475050005250550057506000625065007136V-1057" TOW2 3/8" x 3 1/4"V-105A wp08aKOP: Start Dir 9º/100' : 7749' MD, 6636.02'TVD : 120° LT TFStart Dir 42º/100' : 7769' MD, 6655.77'TVDStart Dir 42.19º/100' : 7967.67' MD, 6771.81'TVDStart Dir 12º/100' : 8167.67' MD, 6756.4'TVDTotal Depth : 9839' MD, 6595.05' TVDCASING DETAILSTVDTVDSS MDSize Name6637.01 6554.71 7750.00 7 7" TOW6595.05 6512.75 9839.00 2-3/8 2 3/8" x 3 1/4"Project: Prudhoe BaySite: VWell: Plan: V-105Wellbore: Plan: V-105Plan: V-105A wp08aWELL DETAILS: Plan: V-105Ground Level: 53.80+N/-S +E/-WNorthing Easting Latitude Longitude0.000.005970107.31590607.9070° 19' 41.0418 N149° 15' 54.5721 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: V-105, True NorthVertical (TVD) Reference:KB @ 82.30usft (ORIG KELLY BUSHING)Measured Depth Reference:KB @ 82.30usft (ORIG KELLY BUSHING)Calculation Method:Minimum Curvature
3URMHFW
&RPSDQ\
/RFDO&RRUGLQDWH5HIHUHQFH
79'5HIHUHQFH
6LWH
+LOFRUS$ODVND//&
3UXGKRH%D\
9
6WDQGDUG3URSRVDO5HSRUW
:HOO
:HOOERUH
3ODQ 9
3ODQ 9
6XUYH\&DOFXODWLRQ0HWKRG 0LQLPXP&XUYDWXUH
.%#XVIW 25,*.(//<%86+,1*
'HVLJQ 9$ZSD
'DWDEDVH 1257+86&$1$'$
0'5HIHUHQFH .%#XVIW 25,*.(//<%86+,1*
1RUWK5HIHUHQFH
:HOO3ODQ 9
7UXH
0DS6\VWHP
*HR'DWXP
3URMHFW
0DS=RQH
6\VWHP'DWXP 866WDWH3ODQH ([DFWVROXWLRQ
1$' 1$'&21&2186
3UXGKRH%D\1RUWK6ORSH81,7('67$7(6
$ODVND=RQH
0HDQ6HD/HYHO
8VLQJ:HOO5HIHUHQFH3RLQW
8VLQJJHRGHWLFVFDOHIDFWRU
6LWH3RVLWLRQ
)URP
6LWH
/DWLWXGH
/RQJLWXGH
3RVLWLRQ8QFHUWDLQW\
1RUWKLQJ
(DVWLQJ
*ULG&RQYHUJHQFH
975
XVIW
0DS XVIW
XVIW
6ORW5DGLXV
1
:
:HOO
:HOO3RVLWLRQ
/RQJLWXGH
/DWLWXGH
(DVWLQJ
1RUWKLQJ
XVIW
(:
16
3RVLWLRQ8QFHUWDLQW\
XVIW
XVIW
XVIW*URXQG/HYHO
3ODQ 9
XVIW
XVIW
:HOOKHDG(OHYDWLRQ XVIW
1
:
:HOOERUH
'HFOLQDWLRQ
)LHOG6WUHQJWK
Q7
6DPSOH'DWH 'LS$QJOH
3ODQ 9
0RGHO1DPH0DJQHWLFV
%**0
3KDVH 9HUVLRQ
$XGLW1RWHV
'HVLJQ 9$ZSD
3/$1
9HUWLFDO6HFWLRQ 'HSWK)URP 79'
XVIW
16
XVIW
'LUHFWLRQ
(:
XVIW
7LH2Q'HSWK
,QFOLQDWLRQ
$]LPXWK
(:
XVIW
7RRO)DFH
16
XVIW
0HDVXUHG
'HSWK
XVIW
9HUWLFDO
'HSWK
XVIW
'RJOHJ
5DWH
XVIW
%XLOG
5DWH
XVIW
7XUQ
5DWH
XVIW
3ODQ6HFWLRQV
79'
6\VWHP
XVIW
30 &203$66%XLOG (3DJH
3URMHFW
&RPSDQ\
/RFDO&RRUGLQDWH5HIHUHQFH
79'5HIHUHQFH
6LWH
+LOFRUS$ODVND//&
3UXGKRH%D\
9
6WDQGDUG3URSRVDO5HSRUW
:HOO
:HOOERUH
3ODQ 9
3ODQ 9
6XUYH\&DOFXODWLRQ0HWKRG 0LQLPXP&XUYDWXUH
.%#XVIW 25,*.(//<%86+,1*
'HVLJQ 9$ZSD
'DWDEDVH 1257+86&$1$'$
0'5HIHUHQFH .%#XVIW 25,*.(//<%86+,1*
1RUWK5HIHUHQFH
:HOO3ODQ 9
7UXH
0HDVXUHG
'HSWK
XVIW
,QFOLQDWLRQ
$]LPXWK
(:
XVIW
0DS
1RUWKLQJ
XVIW
0DS
(DVWLQJ
XVIW
16
XVIW
3ODQQHG6XUYH\
9HUWLFDO
'HSWK
XVIW
79'VV
XVIW
'/6
9HUW6HFWLRQ
685)$&(&$6,1*
30 &203$66%XLOG (3DJH
3URMHFW
&RPSDQ\
/RFDO&RRUGLQDWH5HIHUHQFH
79'5HIHUHQFH
6LWH
+LOFRUS$ODVND//&
3UXGKRH%D\
9
6WDQGDUG3URSRVDO5HSRUW
:HOO
:HOOERUH
3ODQ 9
3ODQ 9
6XUYH\&DOFXODWLRQ0HWKRG 0LQLPXP&XUYDWXUH
.%#XVIW 25,*.(//<%86+,1*
'HVLJQ 9$ZSD
'DWDEDVH 1257+86&$1$'$
0'5HIHUHQFH .%#XVIW 25,*.(//<%86+,1*
1RUWK5HIHUHQFH
:HOO3ODQ 9
7UXH
0HDVXUHG
'HSWK
XVIW
,QFOLQDWLRQ
$]LPXWK
(:
XVIW
0DS
1RUWKLQJ
XVIW
0DS
(DVWLQJ
XVIW
16
XVIW
3ODQQHG6XUYH\
9HUWLFDO
'HSWK
XVIW
79'VV
XVIW
'/6
9HUW6HFWLRQ
.23 6WDUW'LU
0'
79' /77)
72:
30 &203$66%XLOG (3DJH
3URMHFW
&RPSDQ\
/RFDO&RRUGLQDWH5HIHUHQFH
79'5HIHUHQFH
6LWH
+LOFRUS$ODVND//&
3UXGKRH%D\
9
6WDQGDUG3URSRVDO5HSRUW
:HOO
:HOOERUH
3ODQ 9
3ODQ 9
6XUYH\&DOFXODWLRQ0HWKRG 0LQLPXP&XUYDWXUH
.%#XVIW 25,*.(//<%86+,1*
'HVLJQ 9$ZSD
'DWDEDVH 1257+86&$1$'$
0'5HIHUHQFH .%#XVIW 25,*.(//<%86+,1*
1RUWK5HIHUHQFH
:HOO3ODQ 9
7UXH
0HDVXUHG
'HSWK
XVIW
,QFOLQDWLRQ
$]LPXWK
(:
XVIW
0DS
1RUWKLQJ
XVIW
0DS
(DVWLQJ
XVIW
16
XVIW
3ODQQHG6XUYH\
9HUWLFDO
'HSWK
XVIW
79'VV
XVIW
'/6
9HUW6HFWLRQ
6WDUW'LU
0'
79'
6WDUW'LU
0'
79'
30 &203$66%XLOG (3DJH
3URMHFW
&RPSDQ\
/RFDO&RRUGLQDWH5HIHUHQFH
79'5HIHUHQFH
6LWH
+LOFRUS$ODVND//&
3UXGKRH%D\
9
6WDQGDUG3URSRVDO5HSRUW
:HOO
:HOOERUH
3ODQ 9
3ODQ 9
6XUYH\&DOFXODWLRQ0HWKRG 0LQLPXP&XUYDWXUH
.%#XVIW 25,*.(//<%86+,1*
'HVLJQ 9$ZSD
'DWDEDVH 1257+86&$1$'$
0'5HIHUHQFH .%#XVIW 25,*.(//<%86+,1*
1RUWK5HIHUHQFH
:HOO3ODQ 9
7UXH
0HDVXUHG
'HSWK
XVIW
,QFOLQDWLRQ
$]LPXWK
(:
XVIW
0DS
1RUWKLQJ
XVIW
0DS
(DVWLQJ
XVIW
16
XVIW
3ODQQHG6XUYH\
9HUWLFDO
'HSWK
XVIW
79'VV
XVIW
'/6
9HUW6HFWLRQ
6WDUW'LU
0'
79'
30 &203$66%XLOG (3DJH
3URMHFW
&RPSDQ\
/RFDO&RRUGLQDWH5HIHUHQFH
79'5HIHUHQFH
6LWH
+LOFRUS$ODVND//&
3UXGKRH%D\
9
6WDQGDUG3URSRVDO5HSRUW
:HOO
:HOOERUH
3ODQ 9
3ODQ 9
6XUYH\&DOFXODWLRQ0HWKRG 0LQLPXP&XUYDWXUH
.%#XVIW 25,*.(//<%86+,1*
'HVLJQ 9$ZSD
'DWDEDVH 1257+86&$1$'$
0'5HIHUHQFH .%#XVIW 25,*.(//<%86+,1*
1RUWK5HIHUHQFH
:HOO3ODQ 9
7UXH
0HDVXUHG
'HSWK
XVIW
,QFOLQDWLRQ
$]LPXWK
(:
XVIW
0DS
1RUWKLQJ
XVIW
0DS
(DVWLQJ
XVIW
16
XVIW
3ODQQHG6XUYH\
9HUWLFDO
'HSWK
XVIW
79'VV
XVIW
'/6
9HUW6HFWLRQ
7RWDO'HSWK
0'
79'[
30 &203$66%XLOG (3DJH
3URMHFW
&RPSDQ\
/RFDO&RRUGLQDWH5HIHUHQFH
79'5HIHUHQFH
6LWH
+LOFRUS$ODVND//&
3UXGKRH%D\
9
6WDQGDUG3URSRVDO5HSRUW
:HOO
:HOOERUH
3ODQ 9
3ODQ 9
6XUYH\&DOFXODWLRQ0HWKRG 0LQLPXP&XUYDWXUH
.%#XVIW 25,*.(//<%86+,1*
'HVLJQ 9$ZSD
'DWDEDVH 1257+86&$1$'$
0'5HIHUHQFH .%#XVIW 25,*.(//<%86+,1*
1RUWK5HIHUHQFH
:HOO3ODQ 9
7UXH
7DUJHW1DPH
KLWPLVVWDUJHW
6KDSH
79'
XVIW
1RUWKLQJ
XVIW
(DVWLQJ
XVIW
16
XVIW
(:
XVIW
7DUJHWV
'LS$QJOH
'LS'LU
9$ZSWJW
SODQPLVVHVWDUJHWFHQWHUE\XVIWDW XVIW0' 79' 1 (
3RLQW
9$ZSWJW
SODQPLVVHVWDUJHWFHQWHUE\XVIWDW XVIW0' 79'1 (
3RLQW
9$ZSSRO\JRQ
SODQPLVVHVWDUJHWFHQWHUE\ XVIWDWXVIW0' 79' 1 (
3RO\JRQ
3RLQW
3RLQW
3RLQW
3RLQW
3RLQW
3RLQW
3RLQW
3RLQW
3RLQW
3RLQW
3RLQW
3RLQW
3RLQW
3RLQW
9$ZSWJW
SODQPLVVHVWDUJHWFHQWHUE\XVIWDW XVIW0' 79' 1(
3RLQW
9HUWLFDO
'HSWK
XVIW
0HDVXUHG
'HSWK
XVIW
&DVLQJ
'LDPHWHU
+ROH
'LDPHWHU
1DPH
&DVLQJ3RLQWV
72:
[
0HDVXUHG
'HSWK
XVIW
9HUWLFDO
'HSWK
XVIW
(:
XVIW
16
XVIW
/RFDO&RRUGLQDWHV
&RPPHQW
3ODQ$QQRWDWLRQV
.23 6WDUW'LU
0'
79' /77)
6WDUW'LU
0'
79'
6WDUW'LU
0'
79'
6WDUW'LU
0'
79'
7RWDO'HSWK
0'
79'
30 &203$66%XLOG (3DJH
&OHDUDQFH6XPPDU\$QWLFROOLVLRQ5HSRUW6HSWHPEHU+LOFRUS$ODVND//&3UXGKRH%D\93ODQ 93ODQ 9 9$ZSD5HIHUHQFH'HVLJQ 93ODQ 93ODQ 99$ZSD&ORVHVW$SSURDFK'3UR[LPLW\6FDQRQ&XUUHQW6XUYH\'DWD +LJKVLGH5HIHUHQFH :HOO&RRUGLQDWHV 1 (
1
: 'DWXP+HLJKW .%#XVIW 25,*.(//<%86+,1* 6FDQ5DQJH WR XVIW0HDVXUHG'HSWK*HRGHWLF6FDOH)DFWRU$SSOLHG9HUVLRQ %XLOG (6FDQ5DGLXVLV8QOLPLWHG&OHDUDQFH)DFWRUFXWRIILV8QOLPLWHG0D[(OOLSVH6HSDUDWLRQLVXVIW*/2%$/),/7(5$33/,(' $OOZHOOSDWKVZLWKLQ
RIUHIHUHQFH6FDQ7\SH 6FDQ7\SH
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
0.001.002.003.004.00Separation Factor7800 7900 8000 8100 8200 8300 8400 8500 8600 8700 8800 8900 9000 9100 9200 9300 9400 9500 9600 9700Measured Depth (200 usft/in)V-05V-07V-105No-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.WELL DETAILS:Plan: V-105 NAD 1927 (NADCON CONUS)Alaska Zone 04Ground Level: 53.80+N/-S +E/-W Northing EastingLatitudeLongitude0.000.005970107.31 590607.9070° 19' 41.0418 N149° 15' 54.5721 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: V-105, True NorthVertical (TVD) Reference:KB @ 82.30usft (ORIG KELLY BUSHING)Measured Depth Reference:KB @ 82.30usft (ORIG KELLY BUSHING)Calculation Method: Minimum CurvatureSURVEY PROGRAMDate: 2021-09-23T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool199.09 7749.00 Survey #1 (V-105) 3_MWD (BP MWD+IFR+MS-WOCA)7749.00 9839.00 V-105A wp08a (Plan: V-105) 3_MWD0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)7800 7900 8000 8100 8200 8300 8400 8500 8600 8700 8800 8900 9000 9100 9200 9300 9400 9500 9600 9700Measured Depth (200 usft/in)GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference7749.00 To 9839.00Project: Prudhoe BaySite: VWell: Plan: V-105Wellbore: Plan: V-105Plan: V-105A wp08aLadder / S.F. PlotsCASING DETAILSTVD TVDSS MD Size Name6637.01 6554.71 7750.00 7 7" TOW6595.05 6512.75 9839.00 2-3/8 2 3/8" x 3 1/4"
Well Slimhole Date
Quick Test Sub to Otis -1.1 ft
Top of 7" Otis 0.0 ft
Distances from top of riser
Excluding quick-test sub
Top of Annular 6.0 ft
Top of Annular Element 6.7 ft
Bottom Annular 8.0 ft
CL Blind/Shears 9.3 ft
CL 2" Pipe/Slips 10.1 ft
B1 B2 B3 B4 Choke Line
Kill Line
CL 2-3/8" Pipe/Slips 12.6 ft
CL 2" Pipe/Slips 13.4 ft
CL of Top Swab 16.0 ft
Swab Test Pump Hose
T1 T2
Swab 1
CL of Flow Cross 17.4 ft
Master
CL of Master 18.8 ft
LDS
IA
OA
LDS
Ground Level
CDR2-AC 4 Ram BOP Schematic 21-Nov-17
CDR2 Rig's Drip Pan
7-1/16" 5k Flange X 7" Otis Box
Hydril 7 1/16"
Annular
2" Pipe/Slips
7-1/16"
5k Mud
Cross
2" Pipe/Slips
Blind/Shear
7-1/16"
5 Mud
Cross
2-3/8" Pipe/Slips
Revised 2/2015
TRANSMITTAL LETTER CHECKLIST
WELL NAME: ______________________________________
PTD: _____________________________________________
___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional
FIELD: ____________________________ POOL: ______________________________________
Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter
CHECK OPTIONS TEXT FOR APPROVAL LETTER
MULTI
LATERAL
(If last two digits
in API number are
between 60-69)
The permit is for a new wellbore segment of existing well Permit
No. _____________, API No. 50-_______________________.
Production should continue to be reported as a function of the original
API number stated above.
Pilot Hole
In accordance with 20 AAC 25.005(f), all records, data and logs
acquired for the pilot hole must be clearly differentiated in both
well name (_______________________PH) and API number
(50-_____________________) from records, data and logs acquired for
well (name on permit).
Spacing
Exception
The permit is approved subject to full compliance with 20 AAC 25.055.
Approval to produce/inject is contingent upon issuance of
a conservation order approving a spacing exception.
(_____________________________) as Operator assumes the liability
of any protest to the spacing exception that may occur.
Dry Ditch Sample
All dry ditch sample sets submitted to the AOGCC must be in no greater
than 30' sample intervals from below the permafrost or from where
samples are first caught and 10' sample intervals through target zones.
Non-
Conventional
Well
Please note the following special condition of this permit:
Production or production testing of coal bed methane is not allowed for
well ( ) until after ( )
has designed and implemented a water well testing program to provide
baseline data on water quality and quantity.
(________________________) must contact the AOGCC to obtain
advance approval of such water well testing program.
Well Logging
Requirements
Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types
of well logs to be run. In addition to the well logging program proposed
by (_______________________________) in the attached application,
the following well logs are also required for this well:
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071,
composite curves for well logs run must be submitted to the AOGCC
within 90 days after completion, suspension or abandonment of this
well.
PBU V-105A
X
Prudhoe Bay Unit
X
Borealis Oil/Schrader Bluff Oil
X
221-080
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
