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1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown
Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program
Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: ______________________
Development Exploratory
3. Address: Stratigraphic Service 6. API Number:
7. Property Designation (Lease Number): 8. Well Name and Number:
9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s):
11. Present Well Condition Summary:
Total Depth measured 7,521 feet N/A feet
true vertical 7,064 feet N/A feet
Effective Depth measured 7,434 feet 3,228 feet
true vertical 6,977 feet 2,995 feet
Perforation depth Measured depth See Schematic feet
True Vertical depth See Schematic feet
Tubing (size, grade, measured and true vertical depth) N/A N/A N/A N/A
Packers and SSSV (type, measured and true vertical depth) Liner Top Pkr; N/A 3,228' MD 2,995' TVD N/A; N/A
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure: N/A
13a.
Prior to well operation:
Subsequent to operation:
13b. Pools active after work:
15. Well Class after work:
Daily Report of Well Operations Exploratory Development Service Stratigraphic
Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL
Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG
Sundry Number or N/A if C.O. Exempt:
Authorized Name and
Digital Signature with Date: Contact Name:
Contact Email:
Authorized Title: Contact Phone:
Chad Helgeson, Operations Engineer
324-354
Sr Pet Eng:
7,500psi
Sr Pet Geo: Sr Res Eng:
WINJ WAG
677
Water-BblOil-Bbl
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Noel Nocas, Operations Manager 907-564-5278
N/A
chelgeson@hilcorp.com
907-777-8405
measured
true vertical
Packer
Representative Daily Average Production or Injection Data
Casing Pressure Tubing Pressure
14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283)
0
Gas-Mcf
MD
0
Size
120'
3 01988
0 741
597
measured
TVD
8,430psi
4-1/2"
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
222-117
50-283-20187-00-00
3800 Centerpoint Drive, Suite 1400
Anchorage, Alaska 99503
Hilcorp Alaska, LLC
N/A
5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work:
ADL 21128 / ADL 58831
Beluga River / Sterling-Beluga Gas
Beluga River Unit (BRU) 214-13
Plugs
Junk measured
Length
Production
Liner
3,224'
4,302'
Casing
Structural
2,991'
4-1/2"
3,224'
7,517' 7,061'
120'Conductor
Surface
Intermediate
16"
7-5/8"
120'
3,418'
7,500psi
2,980psi
6,880psi
8,430psi
3,418' 3,162'
Burst Collapse
1,410psi
4,790psi
p
k
ft
t
Fra
O
s O
6. A
G
L
PG
,
Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov
By Grace Christianson at 12:11 pm, Oct 14, 2024
Page 1/1
Well Name: BRU 214-13
Report Printed: 10/2/2024www.peloton.com
Alaska Weekly Report - Operations
Jobs
Actual Start Date:7/2/2024 End Date:
Report Number
1
Report Start Date
7/2/2024
Report End Date
7/3/2024
Last 24hr Summary
PJSM, Crew travel to location, Spot in & rig up, Pressure test 250/3000-good, Build guns & test switches, Stab on well & run in hole, Correlate, Perf H2 5584-5588,
Run down & perf 5593-5599, Pull out of hole, Pick up run #2, Run in hole & correlate, Perf H sands 5554-5560, Pull out of hole & flow.
Report Number
2
Report Start Date
8/21/2024
Report End Date
8/21/2024
Last 24hr Summary
Tag fill @ 5519'kb p/t survey
Report Number
3
Report Start Date
9/13/2024
Report End Date
9/14/2024
Last 24hr Summary
PTW/PJSM, PT 250/3000. Perforate Beluga H sand while flowing from 5524'-5530'. SI well & perforate G9 sand from 5428'-5438'.
Report Number
4
Report Start Date
9/14/2024
Report End Date
9/15/2024
Last 24hr Summary
AK E-line PTW/PJSM. RU and PT 250/3000 psi. Perforate with well flowing (670 psi/1500mcfd) the Bel G9 (5428'-5448'), G5 (5349'-5353'), G4 (5305'-5306'), G2
(5262'-5266'), G1 (5233'-5237') & (5207'-5218'). Reduce flow rate, build FTP to 1056 psi and perforate Bel F10 interval (5167'-5175'). Secure well, SDFN and turn
over to production.
Field: Beluga River
Sundry #: 324-354
State: Alaska
Rig/Service:Permit to Drill (PTD) #:222-117Permit to Drill (PTD) #:222-117
Wellbore API/UWI:50-283-20187-00-00
Updated by DMA 10-02-24
SCHEMATIC
Beluga River Unit
BRU 214-13
PTD: 222-117
API: 50-283-20187-00-00
PBTD = 7,432 MD / 6,977 TVD
TD = 7,521 MD / 7,064 TVD
RKB to GL = 18.5
CASING DETAIL
Size Type Wt Grade Conn. ID Top Btm
16 Conductor Driven
to Set Depth 84 X-56 Weld 15.01 Surf 120'
7-5/8" Surf Csg 29.7 L-80 USS-CDC 6.875 Surf 3,418
4-1/2" Prod Tieback 12.6 L-80 JFE LION 3.958 Surf 3,224
4-1/2" Prod Lnr 12.6 L-80 JFE LION 3.958 3,215 7,517
3
16
7-5/8
9-7/8
hole
4-1/2
JEWELRY DETAIL
No. Depth ID OD Item
1 490 3.800 6.090 Chemical Injection Mandrel
2 3,217 4.790 6.340 Seal Stem (11 into tieback receptacle)
3 3,228 3.850 6.530 Liner hanger / LTP Assembly
OPEN HOLE / CEMENT DETAIL
7-5/8" TOC @ Surface (45 bbls to surface 10/2/22)
4-1/2 CBL TOC @ 3260 (10/23/22)
6-3/4
hole
2
1
PERFORATION DETAIL
Zone Top MD Btm MD Top TVD Btm TVD FT Date Status
Bel F10 5,167' 5,175' 4,766' 4,383' 8' 9/14/2024 Open
Bel G1 5,207' 5,218' 4,805 4,419' 11' 9/14/2024 Open
Bel G1 5,233' 5,237' 4,830 4,443 4' 9/14/2024 Open
Bel G2 5,262' 5,266' 4,858 4,470 4' 9/14/2024 Open
Bel G4 5,305' 5,306' 4,900 4,509 1' 9/14/2024 Open
Bel G5 5,349' 5,353' 4,043 3,721 4' 9/14/2024 Open
Bel G9 5,428' 5,438' 5,020 4,624 10' 9/13/2024 Open
Bel H 5,524' 5,530' 5,113' 4,714 6' 9/13/2024 Open
Bel H 5,554 5,560 5,143' 4,743' 6 7/2/2024 Open
Bel H2 5,584 5,588 5,172 4,771 4 7/2/2024 Open
Bel H2 5,593 5,599 5,181 4,780 6 7/2/2024 Open
Bel H3 5,629 5,635 5,216 5,222 6 12/1/2022 Open
Bel H4 5,660 5,670 5,245 5,255 10 12/1/2022 Open
Bel H5 5,716 5,726 5,300 5,310' 10 12/1/2022 Open
Bel H11 5,932 5,951 5,510 5,529 19 11/8/2022 Open
Bel I1 6,256 6,276 5,825 5,834 10 11/8/2022 Open
Bel J4 7,025 7,038 6,576 6,589 13 11/7/2022 Open
H11
I1
J4
H4
H5
H3
F10-H2
Nolan Vlahovich Hilcorp Alaska, LLC
Geotech 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: (907) 564-4558
E-mail: nolan.vlahovich@hilcorp.com
Please acknowledge receipt by signing and returning one copy of this transmittal.
Received By: Date:
Date: 10/04/2024
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
SFTP DATA TRANSMITTAL T#20241004
Well API #PTD #Log Date Log Company Log Type AOGCC
Eset#
BRU 214-13 50283201870000 222117 9/26/2024 AK E-LINE Perf
END 2-72 50029237810000 224016 8/26/2024 HALLIBURTON COILFLAG
END 2-72 50029237810000 224016 8/29/2024 HALLIBURTON COILFLAG
END 2-72 50029237810000 224016 8/29/2024 HALLIBURTON RBT
MPI 2-16 50029218850000 188134 9/9/2024 AK E-LINE Perf
MPI 2-16 50029218850000 188134 9/20/2024 AK E-LINE Perf
MPU B-16 50029213840000 185149 9/28/2024 READ CaliperSurvey
MPU B-24 50029226420000 196009 8/20/2024 HALLIBURTON PERF
MPU B-28 50029235660000 216027 9/28/2024 HALLIBURTON TUBINGCUT
MPU I-01 50029220650000 190090 8/17/2024 HALLIBURTON PERF
MPU R-103 50029237990000 224114 9/20/2024 AK E-LINE Hoist
MRU M-02 50733203890000 187061 9/23/2024 AK E-LINE Perf
PBU 02-21B 50029207810200 211033 9/30/2024 HALLIBURTON RBT
PBU L2-10 50029217460000 187085 8/23/2024 HALLIBURTON RBT
PBU L-212 50029232520000 205030 9/24/2024 HALLIBURTON IPROF
PBU L-254 50029237520000 223030 9/20/2024 HALLIBURTON IPROF
PBU P1-17 50029223580000 193051 9/7/2024 HALLIBURTON RBT
PBU S-09A 50029207710100 214097 8/21/2024 HALLIBURTON RBT
PBU Z-235 50029237600000 223055 9/19/2024 HALLIBURTON IPROF
Please include current contact information if different from above.
T39619
T39620
T39620
T39620
T39621
T39621
T39622
T39623
T39624
T39625
T39626
T39627
T39628
T39629
T39630
T39631
T39632
T39633
T39634
BRU 214-13 50283201870000 222117 9/26/2024 AK E-LINE Perf
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2024.10.04 15:10:24 -08'00'
Nolan Vlahovich Hilcorp Alaska, LLC
Geotech 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: (907) 564-4558
E-mail: nolan.vlahovich@hilcorp.com
Please acknowledge receipt by signing and returning one copy of this transmittal.
Received By: Date:
Date: 9/27/2024
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
SFTP DATA TRANSMITTAL T#20240927
Well API #PTD #Log Date Log
Company Log Type AOGCC
Eset#
BCU 14B 50133205390200 222057 8/14/2024 YELLOWJACKET GPT-PERF
BCU 19RD 50133205790100 219188 8/18/2024 YELLOWJACKET PERF
BRU 214-13 50283201870000 222117 9/13/2024 AK E-LINE Perf
BRU 221-26 50283202010000 224098 9/9/2024 AK E-LINE CBL
BRU 222-26 50283201950000 224035 8/20/2024 AK E-LINE Perf
BRU 233-23T 50283202000000 224088 9/14/2024 AK E-LINE CBL
END 1-61 50029225200000 194142 9/11/2024 READ CaliperSurvey
KBU 32-06 50133206580000 216137 8/6/2024 YELLOWJACKET PERF
MPU B-24 50029226420000 196009 9/9/2024 READ CaliperSurvey
MPU L-03 50029219990000 190007 9/18/2024 READ CaliperSurvey
MPU R-103 50029237990000 224114 9/16/2024 AK E-LINE TubingCut
MPU R-103 50029237990000 224114 9/19/2024 AK E-LINE TubingCut
MRU M-02 50733203890000 187061 9/17/2024 AK E-LINE Plug
NCIU A-19 50883201940000 224026 9/20/2024 AK E-LINE Perf
NCIU A-19 50883201940000 224026 9/13/2024 AK E-LINE Perf
NCIU A-19 50883201940000 224026 9/15/2024 AK E-LINE Perf
NCIU A-19 50883201940000 224026 8/18/2024 AK E-LINE CBL
NCIU A-20 50883201960000 224065 9/11/2024 AK E-LINE PPROF
NCIU A-20 50883201960000 224065 8/26/2024 READ MemoryRadialCementBondLog
PBU 09-27A 50029212910100 215206 9/13/2024 AK E-LINE CBL/TubingPunch
PBU 09-34A 50029213290100 193201 12/31/2023 YELLOWJACKET PL
PBU 13-24B 50029207390200 224087 8/21/2024 YELLOWJACKET CBL-PERF
PBU 13-24B 50029207390200 224087 8/23/2024 YELLOWJACKET CBL
PBU 13-26 50029207460000 182074 8/13/2024 YELLOWJACKET CCL
PBU NK-26A 50029224400100 218009 7/20/2024 YELLOWJACKET PPROF
Please include current contact information if different from above.
T39593
T39594
T39595
T39596
T39597
T39598
T39599
T39600
T39601
T39602
T39603
T39603
T39604
T39605
T39605
T39605
T39605
T39606
T39606
T39607
T39608
T39609
T39609
T39610
T39611
BRU 214-13 50283201870000 222117 9/13/2024 AK E-LINE Perf
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2024.09.27 14:47:28 -08'00'
Nolan Vlahovich Hilcorp Alaska, LLC
Geotech 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: (907) 564-4558
E-mail: nolan.vlahovich@hilcorp.com
Please acknowledge receipt by signing and returning one copy of this transmittal.
Received By: Date:
Date: 7/11/2024
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
SFTP DATA TRANSMITTAL T#20240711
Well API #PTD #Log Date Log
Company Log Type AOGCC Eset#
BCU 19RD 50133205790100 219188 6/28/2024 AK E-LINE Perf
BRU 214-13 50283201870000 222117 7/2/2024 AK E-LINE Perf
IRU 44-36 50283200890000 193022 6/28/2024 AK E-LINE TubingCut
Pearl 11 50133207120000 223032 6/25/2024 AK E-LINE GPT/Plug
Pearl 11 50133207120000 223032 7/8/2024 AK E-LINE Perf
SRU 13-09 50133203430000 181098 6/9/2024 AK E-LINE CBL/CIBP/PUNCH
Revision Explanation: There are additional images added to the final report and a few new .las
files. In the Emeraude folder there are 2 new .las files and in the Field Data folder the RIH and
POOH are new .las files
Please include current contact information if different from above.
T39171
T39172
T39173
T39174
T39174
T39175
BRU 214-13 50283201870000 222117 7/2/2024 AK E-LINE Perf
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2024.07.11 13:30:29 -08'00'
1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown
Suspend Perforate Other Stimulate Pull Tubing Change Approved Program
Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________
2. Operator Name:4. Current Well Class: 5. Permit to Drill Number:
Exploratory Development
3. Address:Stratigraphic Service
6. API Number:
7. If perforating:8. Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool?
Yes No
9. Property Designation (Lease Number):10. Field:
11.
Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD):
7,521'N/A
Casing Collapse
Structural
Conductor 1,410 psi
Surface 4,790 psi
Intermediate
Production 7,500 psi
Liner 7,500 psi
Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft):
12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work:
Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service
14. Estimated Date for 15. Well Status after proposed work:
Commencing Operations:OIL WINJ WDSPL Suspended
16. Verbal Approval:Date: GAS WAG GSTOR SPLUG
AOGCC Representative: GINJ Op Shutdown Abandoned
Contact Name:
Contact Email:
Contact Phone:
Authorized Title:
Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number:
Plug Integrity BOP Test Mechanical Integrity Test Location Clearance
Other Conditions of Approval:
Post Initial Injection MIT Req'd? Yes No
APPROVED BY
Approved by: COMMISSIONER THE AOGCC Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
jake.flora@hilcorp.com
907-777-8442
Noel Nocas, Operations Manager 907-564-5278
Suspension Expiration Date:
Will perfs require a spacing exception due to property boundaries?
Current Pools:
MPSP (psi):Plugs (MD):
17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval.
Authorized Name and
Digital Signature with Date:
Tubing Size:
PRESENT WELL CONDITION SUMMARY
Jake Flora, Operations Engineer
AOGCC USE ONLY
8,430 psi
Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft):
Subsequent Form Required:
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL 21128 / ADL 58831
222-117
50-283-20187-00-00
Hilcorp Alaska, LLC
Proposed Pools:
N/A
TVD Burst
N/A
8,430 psi
3,162
Size
120
3,418
MD
4-1/2"
See Schematic
2,980 psi
6,880 psi
120120
3,418
July 3, 2024
7,5174,302
N/A
7,061
3,224
Perforation Depth MD (ft):
3800 Centerpoint Drive, Suite 1400
Anchorage, Alaska 99503
Beluga River Unit (BRU) 214-13CO 802
Same
2,9914-1/2"
~2320psi
3,224
N/A
Length
Liner Top Pkr; N/A 3,228' MD/2,995' TVD; N/A
7,064'7,434'6,977'
Beluga River Sterling-Beluga Gas
16"
7-5/8"
See Schematic
m
n
P
s
66
t
_
N
Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
Digitally signed by Noel
Nocas (4361)
DN: cn=Noel Nocas (4361)
Date: 2024.06.19 14:07:31 -
08'00'
Noel Nocas
(4361)
10-404
DSR-6/21/24BJM 6/24/24 A.Dewhurst 21JUN24*&:JLC 6/24/2024
Brett W. Huber, Sr.
Digitally signed by Brett W. Huber,
Sr.
Date: 2024.06.24 15:23:58 -08'00'06/24/24
RBDMS JSB 062524
Well Prognosis
Well Name: BRU 214-13 API Number: 50-283-20187-00-00
Current Status: Gas Producer Permit to Drill Number: 222-117
First Call Engineer: Jake Flora (907) 777-8442 (O) (720) 988-5375 (C)
Second Call Engineer: Chad Helgeson (907) 777-8405 (O) (907) 229-4824 (C)
Maximum Expected BHP: ~ 2978 psi @ 6589’ TVD (0.452 psi/ft gradient to bottom perf)
Max. Potential Surface Pressure: ~2320 psi (Max expected BHP minus gas to surface)
Well Status:
Online Gas Producer: Last well test - 700 MCFD / 3 BWPD / 165#
Brief Well Summary
BRU 214-13 is a 2022 grass roots well currently completed in the Beluga H – J sands, the well is right at
unloading rates for 4-1/2” tubing.
The objective of this sundry is to increase rate by adding perforations.
Last Downhole Operation
03-28-24 2.21 GR to 6983’
12-19-22 Logged PLT, max depth 7100’
Current Open Perfs: Beluga H3 – J4 5629-7038’ MD (5216 – 6589’ TVD)
Procedure
1. Review approved COAs
2. MIRU E-line, PT BOPE to 3000 psi
3. Perforate Beluga sands within the below interval while flowing:
Beluga F10 – H15 5166’ – 6154’ MD 4765’ – 5726’ TVD
a. If any zone produces sand and/or water or needs isolated, RIH and set plug above the perforations OR
patch across the perforations.
b. Frac Calcs: Using 12.7 ppg EMW FIT (0.66 psi/ft) frac gradient taken at surface casing shoe
c. Shallowest Allowable Perf TVD = MPSP/(0.66-0.1) = 2320 psi / 0.56 = 4143‘ TVD
4. Return to production
Attachments:
1. Actual Schematic
2. Proposed Schematic
Updated by CJD 12-7-22
SCHEMATIC
Beluga River Unit
BRU 214-13
PTD: 222-117
API: 50-283-20187-00-00
PBTD = 7,432’ MD / 6,977’ TVD
TD = 7,521’ MD / 7,064’ TVD
RKB to GL = 18.5’
CASING DETAIL
Size Type Wt Grade Conn. ID Top Btm
16” Conductor – Driven
to Set Depth 84 X-56 Weld 15.01” Surf 120'
7-5/8" Surf Csg 29.7 L-80 USS-CDC 6.875” Surf 3,418’
4-1/2" Prod Tieback 12.6 L-80 JFE LION 3.958” Surf 3,224’
4-1/2" Prod Lnr 12.6 L-80 JFE LION 3.958” 3,215’ 7,517’
3
16”
7-5/8”
9-7/8”
hole
4-1/2”
JEWELRY DETAIL
No. Depth ID OD Item
1 490’ 3.800” 6.090” Chemical Injection Mandrel
2 3,217’ 4.790” 6.340” Seal Stem (11’ into tieback receptacle)
3 3,228’ 3.850” 6.530” Liner hanger / LTP Assembly
OPEN HOLE / CEMENT DETAIL
7-5/8" TOC @ Surface (45 bbls to surface 10/2/22)
4-1/2” CBL TOC @ 3260’ (10/23/22)
6-3/4”
hole
2
1
PERFORATION DETAIL
Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status
Bel H3 5,629’ 5,635’ 5,216’ 5,222’ 6’ 12/1/22 Open
Bel H4 5,660’ 5,670’ 5,245’ 5,255’ 10’ 12/1/22 Open
Bel H5 5,716’ 5,726’ 5,300’ 5,310 10’ 12/1/22 Open
Bel H11 5,932’ 5,951’ 5,510’ 5,529’ 19’ 11/8/22 Open
Bel I1 6,256’ 6,276’ 5,825’ 5,834’ 10’ 11/8/22 Open
Bel J4 7,025’ 7,038’ 6,576’ 6,589’ 13’ 11/7/22 Open
H11
I1
J4
H4
H5
H3
Updated by DMA 06-19-24
PROPOSED
Beluga River Unit
BRU 214-13
PTD: 222-117
API: 50-283-20187-00-00
PBTD = 7,432’ MD / 6,977’ TVD
TD = 7,521’ MD / 7,064’ TVD
RKB to GL = 18.5’
CASING DETAIL
Size Type Wt Grade Conn. ID Top Btm
16” Conductor – Driven
to Set Depth 84 X-56 Weld 15.01” Surf 120'
7-5/8" Surf Csg 29.7 L-80 USS-CDC 6.875” Surf 3,418’
4-1/2" Prod Tieback 12.6 L-80 JFE LION 3.958” Surf 3,224’
4-1/2" Prod Lnr 12.6 L-80 JFE LION 3.958” 3,215’ 7,517’
3
16”
7-5/8”
9-7/8”
hole
4-1/2”
JEWELRY DETAIL
No. Depth ID OD Item
1 490’ 3.800” 6.090” Chemical Injection Mandrel
2 3,217’ 4.790” 6.340” Seal Stem (11’ into tieback receptacle)
3 3,228’ 3.850” 6.530” Liner hanger / LTP Assembly
OPEN HOLE / CEMENT DETAIL
7-5/8" TOC @ Surface (45 bbls to surface 10/2/22)
4-1/2” CBL TOC @ 3260’ (10/23/22)
6-3/4”
hole
2
1
PERFORATION DETAIL
Zone Top MD Btm MD Top TVD Btm TVD FT Date Status
Bel F10-H15 ±5,166' ±6,154' ±4,765' ±5,726' Proposed TBD
Bel H3 5,629’ 5,635’ 5,216’ 5,222’ 6’ 12/1/22 Open
Bel H4 5,660’ 5,670’ 5,245’ 5,255’ 10’ 12/1/22 Open
Bel H5 5,716’ 5,726’ 5,300’ 5,310 10’ 12/1/22 Open
Bel H11 5,932’ 5,951’ 5,510’ 5,529’ 19’ 11/8/22 Open
Bel I1 6,256’ 6,276’ 5,825’ 5,834’ 10’ 11/8/22 Open
Bel J4 7,025’ 7,038’ 6,576’ 6,589’ 13’ 11/7/22 Open
H11
I1
J4
H4
H5
H3
F10-H2
H7-H8
H12-H15
1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown
Suspend Perforate Other Stimulate Pull Tubing Change Approved Program
Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing
2. Operator Name:4. Current Well Class: 5. Permit to Drill Number:
Exploratory Development
3. Address: Stratigraphic Service
6. API Number:
7. If perforating:8. Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool?
Will planned perforations require a spacing exception?Yes No
9. Property Designation (Lease Number): 10. Field: Current Pools:
Beluga River Sterling-Beluga Gas Pool Same
11.
Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD):
7,521'N/A
Casing Collapse
Structural
Conductor 1,410 psi
Surface 4,790 psi
Intermediate
Production 7,500 psi
Liner 7,500 psi
Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft):
12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work:
Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service
14. Estimated Date for 15. Well Status after proposed work:
Commencing Operations:OIL WINJ WDSPL Suspended
16. Verbal Approval:Date: GAS WAG GSTOR SPLUG
AOGCC Representative: GINJ Op Shutdown Abandoned
Contact Name: Jake Flora
Contact Email:Jake.Flora@hilcorp.com
Contact Phone: 907 777-8442
Authorized Title:
Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number:
Plug Integrity BOP Test Mechanical Integrity Test Location Clearance
Other:
Post Initial Injection MIT Req'd? Yes No
Spacing Exception Required? Yes No Subsequent Form Required:
APPROVED BY
Approved by: COMMISSIONER THE AOGCC Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
7,061
4-1/2"
16"
7-5/8"
120
3,418
Perforation Depth MD (ft):
3,224
4-1/2"4,302
8,430 psi
MD
2,980 psi
6,880 psi
120
3,162
120
3,418
2,9913,224
Length Size
Proposed Pools:
TVD Burst
PRESENT WELL CONDITION SUMMARY
7,064'7,434'6,977'~2320psi N/A
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL 21128 / ADL 58831
222-117
3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-283-20187-00-00
Hilcorp Alaska, LLC
Beluga River Unit (BRU) 214-13
CO 802
Other:
8,430 psi
Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft):Tubing Size:
N/A N/A
6/15/2023
Liner Top Pkr; N/A 3,228' MD/2,995' TVD; N/A
See Schematic See Schematic
7,517
N/A
17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval.
Authorized Name and
Digital Signature with Date:
AOGCC USE ONLY
Operations Manager
m
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P
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66
t
Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
By Grace Christianson at 4:08 pm, Jun 01, 2023
323-324
Digitally signed by Noel
Nocas (4361)
DN: cn=Noel Nocas (4361)
Date: 2023.06.01 15:55:59 -
08'00'
Noel Nocas
(4361)
10-404
SFD 6/6/2023BJM 6/7/23 DSR-6/1/23
Perforate
GCW 06/08/2023
JLC 6/8/2023
Brett W.
Huber, Sr.
Digitally signed by Brett
W. Huber, Sr.
Date: 2023.06.08
10:42:51 -08'00'
RBDMS JSB 060823
Well Prognosis
Well Name: BRU 214-13 API Number: 50-283-20187-00-00
Current Status: Gas Producer Permit to Drill Number: 222-117
First Call Engineer: Jake Flora (907) 777-8442 (O) (720) 988-5375 (C)
Second Call Engineer: Chad Helgeson (907) 777-8405 (O) (907) 229-4824 (C)
Maximum Expected BHP: ~ 2978 psi @ 6589’ TVD (0.452 psi/ft gradient to bottom perf)
Max. Potential Surface Pressure: ~2320 psi (Max expected BHP minus gas to surface)
Well Status:
Online Gas Producer: Last well test - 2000 MCFD / 3 BWPD / 165#
Brief Well Summary
BRU 214-13 is a grass roots well drilling in the 2022 drilling season. Currently completed in the Beluga H – J
sands, the well is right at unloading rates for 4-1/2” tubing. The objective of this sundry is to increase rate by
adding perforations.
Last Downhole Operation
12-19-22 Logged PLT, max depth 7100’
Current Open Perfs: Beluga H3 – J4 5629-7038’ MD (5216 – 6589’ TVD)
Procedure
1. Review approved COAs
2. MIRU E-line, PT BOPE to 3000 psi
3. Perforate the below sands while flowing:
Formation Sand Top MD Bottom
MD Total Top TVD Bottom
TVD
Beluga E3 4534 4546 12 4167 4179
Beluga E4 4591 4597 6 4220 4226
Beluga F4 4795 4801 6 4410 4416
Beluga F4 4815 4830 15 4429 4444
Beluga F4 4833 4839 6 4447 4453
Beluga F5 4890 4900 10 4501 4511
Beluga F7 5076 5080 4 4680 4684
Beluga F7 5109 5117 8 4711 4719
Beluga F10 5166 5174 8 4765 4773
Beluga G1 5207 5218 11 4804 4815
Beluga G1 5232 5237 5 4829 4834
Beluga G2 5261 5266 5 4857 4862
Beluga G4 5303 5306 3 4899 4902
Beluga G9 5423 5450 27 5014 5041
Beluga H 5523 5530 7 5113 5120
Beluga H 5554 5559 5 5143 5148
Well Prognosis
Beluga H2 5583 5588 5 5171 5176
Beluga H2 5593 5599 6 5180 5186
Beluga H7 5775 5780 5 5358 5363
Beluga H7 5788 5793 5 5369 5374
Beluga H8 5826 5840 14 5407 5421
Beluga H12 5970 5975 5 5547 5552
Beluga H13 6035 6070 35 5610 5645
a. If any zone produces sand and/or water or needs isolated, RIH and set plug above the
perforations OR patch across the perforations.
b. Frac Calcs: Using 12.7 ppg EMW FIT (0.66 psi/ft) frac gradient taken at surface casing shoe
c. Shallowest Allowable Perf TVD = MPSP/(0.66-0.1) = 2320 psi / 0.56 = 4143‘ TVD
4. Return to production
Attachments:
1. Actual Schematic
2. Proposed Schematic
Shallowest Allowable Perf TVD = MPSP/(0.66-0.1) = 2320 psi / 0.56 = 4143‘ TVD
Updated by CJD 12-7-22
SCHEMATIC
Beluga River Unit
BRU 214-13
PTD: 222-117
API: 50-283-20187-00-00
PBTD = 7,432’ MD / 6,977’ TVD
TD = 7,521’ MD / 7,064’ TVD
RKB to GL = 18.5’
CASING DETAIL
Size Type Wt Grade Conn. ID Top Btm
16” Conductor – Driven
to Set Depth 84 X-56 Weld 15.01” Surf 120'
7-5/8" Surf Csg 29.7 L-80 USS-CDC 6.875” Surf 3,418’
4-1/2" Prod Tieback 12.6 L-80 JFE LION 3.958” Surf 3,224’
4-1/2" Prod Lnr 12.6 L-80 JFE LION 3.958” 3,215’ 7,517’
3
16”
7-5/8”
9-7/8”
hole
4-1/2”
JEWELRY DETAIL
No. Depth ID OD Item
1 490’ 3.800” 6.090” Chemical Injection Mandrel
2 3,217’ 4.790” 6.340” Seal Stem (11’ into tieback receptacle)
3 3,228’ 3.850” 6.530” Liner hanger / LTP Assembly
OPEN HOLE / CEMENT DETAIL
7-5/8" TOC @ Surface (45 bbls to surface 10/2/22)
4-1/2” CBL TOC @ 3260’ (10/23/22)
6-3/4”
hole
2
1
PERFORATION DETAIL
Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status
Bel H3 5,629’ 5,635’ 5,216’ 5,222’ 6’ 12/1/22 Open
Bel H4 5,660’ 5,670’ 5,245’ 5,255’ 10’ 12/1/22 Open
Bel H5 5,716’ 5,726’ 5,300’ 5,310 10’ 12/1/22 Open
Bel H11 5,932’ 5,951’ 5,510’ 5,529’ 19’ 11/8/22 Open
Bel I1 6,256’ 6,276’ 5,825’ 5,834’ 10’ 11/8/22 Open
Bel J4 7,025’ 7,038’ 6,576’ 6,589’ 13’ 11/7/22 Open
H11
I1
J4
H4
H5
H3
Updated by DMA 06-01-23
PROPOSED
Beluga River Unit
BRU 214-13
PTD: 222-117
API: 50-283-20187-00-00
PBTD = 7,432’ MD / 6,977’ TVD
TD = 7,521’ MD / 7,064’ TVD
RKB to GL = 18.5’
CASING DETAIL
Size Type Wt Grade Conn. ID Top Btm
16” Conductor – Driven
to Set Depth 84 X-56 Weld 15.01” Surf 120'
7-5/8" Surf Csg 29.7 L-80 USS-CDC 6.875” Surf 3,418’
4-1/2" Prod Tieback 12.6 L-80 JFE LION 3.958” Surf 3,224’
4-1/2" Prod Lnr 12.6 L-80 JFE LION 3.958” 3,215’ 7,517’
3
16”
7-5/8”
9-7/8”
hole
4-1/2”
JEWELRY DETAIL
No. Depth ID OD Item
1 490’ 3.800” 6.090” Chemical Injection Mandrel
2 3,217’ 4.790” 6.340” Seal Stem (11’ into tieback receptacle)
3 3,228’ 3.850” 6.530” Liner hanger / LTP Assembly
OPEN HOLE / CEMENT DETAIL
7-5/8" TOC @ Surface (45 bbls to surface 10/2/22)
4-1/2” CBL TOC @ 3260’ (10/23/22)
6-3/4”
hole
2
1
PERFORATION DETAIL
Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status
Bel E3 ±4,534' ±4,546' ±4,167' ±4,179' ±12' Proposed TBD
Bel E4 ±4,591' ±4,597' ±4,220' ±4,226' ±6' Proposed TBD
Bel F4 ±4,795' ±4,801' ±4,410' ±4,416' ±6' Proposed TBD
Bel F4 ±4,815' ±4,830' ±4,429' ±4,444' ±15' Proposed TBD
Bel F4 ±4,833' ±4,839' ±4,447' ±4,453' ±6' Proposed TBD
Bel F5 ±4,890' ±4,900' ±4,501' ±4,511' ±10' Proposed TBD
Bel F7 ±5,076' ±5,080' ±4,680' ±4,684' ±4' Proposed TBD
Bel F7 ±5,109' ±5,117' ±4,711' ±4,719' ±8' Proposed TBD
Bel F10 ±5,166' ±5,174' ±4,765' ±4,773' ±8' Proposed TBD
Bel G1 ±5,207' ±5,218' ±4,804' ±4,815' ±11' Proposed TBD
Bel G1 ±5,232' ±5,237' ±4,829' ±4,834' ±5' Proposed TBD
Bel G2 ±5,261' ±5,266' ±4,857' ±4,862' ±5' Proposed TBD
Bel G4 ±5,303' ±5,306' ±4,899' ±4,902' ±3' Proposed TBD
Bel G9 ±5,423' ±5,450' ±5,014' ±5,041' ±27' Proposed TBD
Bel H ±5,523' ±5,530' ±5,113' ±5,120' ±7' Proposed TBD
Bel H ±5,554' ±5,559' ±5,143' ±5,148' ±5' Proposed TBD
Bel H2 ±5,583' ±5,588' ±5,171' ±5,176' ±5' Proposed TBD
Bel H2 ±5,593' ±5,599' ±5,180' ±5,186' ±6' Proposed TBD
Bel H3 5,629’ 5,635’ 5,216’ 5,222’ 6’ 12/1/22 Open
Bel H4 5,660’ 5,670’ 5,245’ 5,255’ 10’ 12/1/22 Open
Bel H5 5,716’ 5,726’ 5,300’ 5,310 10’ 12/1/22 Open
Bel H7 ±5,775' ±5,780' ±5,358' ±5,363' ±5' Proposed TBD
Bel H7 ±5,788' ±5,793' ±5,369' ±5,374' ±5' Proposed TBD
Bel H8 ±5,826' ±5,840' ±5,407' ±5,421' ±14' Proposed TBD
Bel H11 5,932’ 5,951’ 5,510’ 5,529’ 19’ 11/8/22 Open
Bel H12 ±5,970' ±5,975' ±5,547' ±5,552' ±5' Proposed TBD
Bel H13 ±6,035' ±6,070' ±5,610' ±5,645' ±35' Proposed TBD
Bel I1 6,256’ 6,276’ 5,825’ 5,834’ 10’ 11/8/22 Open
Bel J4 7,025’ 7,038’ 6,576’ 6,589’ 13’ 11/7/22 Open
H11
I1
J4
H4
H5
H3
E3-H2
H7-H8
H12-H13
Kyle Wiseman Hilcorp Alaska, LLC
Geo Tech 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: (907) 564-4558
E-mail: Kyle.Wiseman@hilcorp.com
Please acknowledge receipt by signing and returning one copy of this transmittal.
Received By: Date:
Date: 01/26/2023
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
SFTP DATA TRANSMITTAL T#20230126
Well API #PTD #Log Date Log Company Log Type AOGCC
Eset#
TBU M-10 50733205880000 209154 12/30/2022 AK E-LINE Perf
CLU 10RD 50133205530100 222113 12/29/2022 AK E-LINE GPT_Plug_Perf
NCI A-14 50883201250000 208096 11/6/2022 AK E-LINE Perf
BRU 214-13 50283201870000 222117 12/19/2022 AK E-LINE PPROF
BRU 233-23 50283201360100 222050 12/21/2022 AK E-LINE PPROF
SRU 224-10 50133101380100 222124 12/14/2022 AK E-LINE CBL
Please include current contact information if different from above.
By Meredith Guhl at 2:54 pm, Jan 26, 2023
T37473
T37474
T37475
T37476
T37477
T37478
BRU 214-13 50283201870000 222117 12/19/2022 AK E-LINE PPROF
Meredith Guhl Digitally signed by Meredith Guhl
Date: 2023.01.26 15:02:03 -09'00'
Kyle Wiseman Hilcorp Alaska, LLC
Geotechnician 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: (907) 564-4558
E-mail: Kyle.Wiseman@hilcorp.com
Please acknowledge receipt by signing and returning one copy of this transmittal.
Received By: Date:
Date: 12/28/2022
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
SFTP DATA TRANSMITTAL T#20221228
Well API #PTD #Log Date Log Company Log Type AOGCC
Eset#
BCU 14B 50133205390200 222057 11/27/2022 AK E-LINE GPT Fluid Sample
BRU 214-13 50283201870000 222117 11/9/2022 AK E-LINE Perf GPT
BRU 214-13 50283201870000 222117 12/2/2022 AK E-LINE Perf
BRU 222-34 50283201860000 222039 11/13/2022 AK E-LINE GPT
BRU 233-23 50283201360100 222050 11/10/2022 AK E-LINE GPT Plug Perf
BRU 244-27 50283201850000 222038 11/13/2022 AK E-LINE GPT
Please include current contact information if different from above.
By Meredith Guhl at 9:22 am, Dec 29, 2022
T37401
T37402
T37402
T37403
T37404
T37405
BRU 214-13 50283201870000 222117 11/9/2022 AK E-LINE Perf GPT
BRU 214-13 50283201870000 222117 12/2/2022 AK E-LINE Perf
Meredith Guhl Digitally signed by Meredith Guhl
Date: 2022.12.29 09:31:43 -09'00'
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): Beluga River Field
GL:78.1' BF:78.1'
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 N/A (ft MSL)
22. Logs Obtained:
23.
BOTTOM
16" X-56 120'
7-5/8" L-80 3,162'
4-1/2" L-80 7,060'
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
Sr Res EngSr Pet GeoSr Pet Eng
N/A
N/A
Oil-Bbl: Water-Bbl:
001070 0
11/13/2022 24
Flow Tubing
0
3158
N/A31580
46' FSL, 1101' FWL, Sec 13, T13N, R10W, SM, AK
Choke Size:
Surface
Per 20 AAC 25.283 (i)(2) attach electronic information
12.6# 2,983'
84#
29.7#
120'
Water-Bbl:
PRODUCTION TEST
11/9/2022
Date of Test: Oil-Bbl:
Flowing
*** Please see attached schematic for perforation detail ***
Gas-Oil Ratio:
AMOUNT
PULLED
324307
324469
TOP
SETTING DEPTH MD
suspension, or abandonment; or within 90 days of acquisition of the log, 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 only if necessary.
PACKER SET (MD/TVD)
Cond
BOTTOMCASINGWT. PER
FT.GRADE CEMENTING RECORD
2635384
SETTING DEPTH TVD
2635660
TOP HOLE SIZE
Mudlog, LWD (DGR, SP4, CTN, ALD), CBL 10-23-22, Perf Tie in logs, GPT.
N/A
N/A
N/A
3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503
323447 2633565
50-283-20187-00-00September 28, 2022
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
Hilcorp Alaska, LLC
WAG
Gas
11/7/2022 222-117 / 322-611
LOCI 22-005
BRU 214-13October 7, 20222071' FNL, 114' FWL, Sec 24, T13N, R10W, SM, AK
96.6'
Sterling-Beluga Gas Pool
ADL 21128 / ADL 58831
7,521' MD / 7,064' TVD
7,432' MD / 6,977' TVD
232' FNL, 944' FWL, Sec 24, T13N, R10W, SM, AK
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
L - 325 sx / T - 100 sx6-3/4"
9-7/8"
Driven
Surface L - 425 sx / T - 175 sx 45 bbls
Surface
4-1/2"
SIZE DEPTH SET (MD)
3,215' MD / 2,983' TVD
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date perf'd or liner run):
3,215' 7,517'
Surface
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
3,224'
3,418'
WINJ
SPLUGOther Abandoned Suspended
Stratigraphic Test
No
No
(attached) No
Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment
By James Brooks at 8:05 am, Dec 08, 2022
Completed
11/7/2022
JSB
RBDMS JSB 121622
G
222-117 / 322-611
BRU 214-13
DSR-1/3/23WCB 1-24-2025
Conventional Core(s): Yes No Sidewall Cores:
30.
MD TVD
Top of Productive Interval Bel H3 5,629' 5,216'
3,565' 3,292'
3,765' 3,472'
3,932' 3,622'
4,176' 3,841'
4,399' 4,043'
4,745' 4,363'
5,190' 4,789'
5,505' 5,095'
6,196' 5,766'
6,749' 6,305'
7,366' 6,911'
31. List of Attachments:
32. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Contact Name: Cody Dinger
Digital Signature with Date:Contact Email:cdinger@hilcorp.com
Contact Phone: 907-777-8389
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:
Beluga J
Wellbore Schematic, Drilling and Completion Reports, Definitive Directional Surveys, Csg and Cmt Reports
Authorized Title: Drilling Manager
Formation Name at TD:
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.
Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain).
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; or 90 days after log acquisition, whichever occurs first.
INSTRUCTIONS
Beluga J6
Beluga I
Beluga D
Sterling A
Beluga E
Beluga H
Sterling B
Sterling C
Beluga F
Beluga G
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.
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).
This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic
diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from
a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071.
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, 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).
Authorized Name and
Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if
needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired.
Yes No
Well tested? Yes No
28. CORE DATA
If Yes, list intervals and formations tested, briefly summarizing test results for
each. Attach separate pages if needed and submit detailed test info including
reports and Excel or ASCII tables per 20 AAC 25.071.
NAME
Permafrost - Top
Permafrost - Base
29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS
No
NoSidewall Cores: Yes No
Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov
12.7.2022
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: 2022.12.07 14:13:57 -09'00'
Monty M
Myers
Updated by CJD 12-7-22
SCHEMATIC
Beluga River Unit
BRU 214-13
PTD: 222-117
API: 50-283-20187-00-00
PBTD = 7,432’ MD / 6,977’ TVD
TD = 7,521’ MD / 7,064’ TVD
RKB to GL = 18.5’
CASING DETAIL
Size Type Wt Grade Conn. ID Top Btm
16” Conductor – Driven
to Set Depth 84 X-56 Weld 15.01” Surf 120'
7-5/8" Surf Csg 29.7 L-80 USS-CDC 6.875” Surf 3,418’
4-1/2" Prod Tieback 12.6 L-80 JFE LION 3.958” Surf 3,224’
4-1/2" Prod Lnr 12.6 L-80 JFE LION 3.958” 3,215’ 7,517’
3
16”
7-5/8”
9-7/8”
hole
4-1/2”
JEWELRY DETAIL
No. Depth ID OD Item
1 490’ 3.800” 6.090” Chemical Injection Mandrel
2 3,217’ 4.790” 6.340” Seal Stem (11’ into tieback receptacle)
3 3,228’ 3.850” 6.530” Liner hanger / LTP Assembly
OPEN HOLE / CEMENT DETAIL
7-5/8" TOC @ Surface (45 bbls to surface 10/2/22)
4-1/2” CBL TOC @ 3260’ (10/23/22)
6-3/4”
hole
2
1
PERFORATION DETAIL
Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status
Bel H3 5,629’ 5,635’ 5,216’ 5,222’ 6’ 12/1/22 Open
Bel H4 5,660’ 5,670’ 5,245’ 5,255’ 10’ 12/1/22 Open
Bel H5 5,716’ 5,726’ 5,300’ 5,310 10’ 12/1/22 Open
Bel H11 5,932’ 5,951’ 5,510’ 5,529’ 19’ 11/8/22 Open
Bel I1 6,256’ 6,276’ 5,825’ 5,834’ 10’ 11/8/22 Open
Bel J4 7,025’ 7,038’ 6,576’ 6,589’ 13’ 11/7/22 Open
H11
I1
J4
H4
H5
H3
Activity Date Ops Summary
9/25/2022 Cont RD throughout the rig, spotted crane and removed end windwalls from pit 1, tore out boiler, compressor pumps, HPU skids. LD and removed poorboy
degasser. Tore out pits and jig, offloaded excess fuel, tore out upright water tank, scoped down derrick and LD lower torque tube section, hung blocks;LD beaver
slide, transferred BOP stack to cradle, tore out gen skid and catwalk, spooled off drill line, LD mast. spotted cranes, scoped down doghouse, picked derrick off
carrier, carrier off sub, sub off pony walls, moved items off mats, start stacking mats and clean up liner/felt.;Cont stacking rig mats and clean up liner/felt. CCI
cleaned out gravel from 214-13 cellar box w/super sucker. Staged road grader for pad work. Bring in gravel and start leveling around cellar and rig footprint.;Lay
out felt and liner. Set rig mats.;Set pony sub and place test pump and starting head between pony sub walls. Spot sub on rig mats, spot cranes and set sub on
pony walls. Spot carrier, pick with cranes and pin in place. Pick derrick and set on carrier and pin in place. Spot rig water tank and dog house. Raise and pin
doghouse.
9/26/2022 Set the 3 pit mods, gen skid, both pump skids, compressor skid and HPU. Layed out felt and liner for catwalk. Powered up rig gen, set 40' connex and boiler
skid. Stood and installed poorboy degasser and set upright water tank. Cont stringing cords and install jumpers on mods. Prep and raised mast.;Staged starting
head in cellar, set catwalk and raised beaver slide, sent 48 hr notice to AOGCC and Quadco for diverter function test on Wednesday.;Cont RU interconnects,
spool drill line on drum, held PJSM with CCI welders and Vault Rep on conductor cutoff and starting head welding. Stage welding truck, angle iron and grating at
catwalk, assigned fire watch for cellar. Handy Berm berme din rig footprint, set service shacks, filled upright tank;Cont welding starting head on conductor, install
of 4" conductor outlets, and grating bracing. Scope derrick install lower torque tube, t-bars and turnbuckles. Fix steam lines and get boiler running. Run water
through pits and check for leaks.;Finish up welding on grating bracing and instlall grating. Bring top drive and extend frame up to rig floor. Pin TD to extend
frame. Install saver sub, service loop, kelly hose, bails and elevators. Remove shipping beams.
9/27/2022 Ran & R/U Pason cables through out the rig, R/U weight indicator. Plugged in cameras, M/U IR HYD hoses and electrical. Finished erecting handrails around
rig. Brought handing equip. to rig floor. Hung rig floor and door way tarps. R/U roughneck heater on floor.;Set DSA on well head, orientated 21-1/4" T so vent line
passed by sub wall. started N/U DSA to T. Built first batch of 8.8 ppg spud mud. Cont. working through rig acceptance check list.;Noticed water leak in cellar on
weld to conductor/cellar. Brought out welders to re-run bead around cellar to conductor boot. Cont. working on R/U and working through rig acceptance check
list. Started building second batch of spud mud. Serviced TD, crown, and IR.;Finished welding cellar to conductor boot. Nipple up diverter, hook up hydraulic
lines. Nipple up gun barrel. Finish up second batch of spud mud. Get bit and XO's to rig floor for surface BHA. Performed drop inspection of the mast. Energize
koomey and verified integrity of hydraulic system.;Align torque tube. Set 14" wear ring. Swap kick cylinder on catwalk. Functioned the annular and knife valve.
Pressure test surface lines to 3500psi (no leaks). Verify topdrive, tongs and roughneck torque values. P/U mule shoe and tag @ 131'.;Dragon boxes loaded 0
bbls
Total Dragon Boxes 0 bbls
Cuttings Totes Loaded 0 bbls
Total Cuttings Totes 0 bbls
ISO Tanks Loaded 0 bbls
ISO Tanks Total 0 bbls
Losses Downhole 0 bbls
Total 0 bbls
9/28/2022 Built and racked back 45 stds of 4.5" DP in derrick (tagged bottom at 131'). Quadco Rep flew into Beluga and bump tested gas alarms audio/visual (ok). Witness
was waved on diverter test by AOGCC rep Jim Regg. Accepted rig at 09:30 hrs.;Built and racked back 16 stds of 4.5" HWDP, jar std, and flex collars. Strap
and tally 7-5/8" surface casing. Loaded on to trailers.;Performed diverter test and koomey draw down test. Annular close time-34 sec Knife closing time-25 sec.
Hydro tested diverter stack (ok).;Held PJSM on P/U surface BHA #1. M/U 9-7/8" Kymera bit, mud motor w/ 1.5° bend, XO to 4.5" HWDP. RIH to tagged depth
of 131'. Displaced well over to 8.8 ppg spud mud. Circ. conductor clean.;Spudded well at 17:30 hrs. Drilled F/131'-T/218'. GPM-360 SPP-435 psi RPM-30 TQ-
2.5K ROP-120 fph. CBU 1.5.;POOH f/218' t/30' to P/U the rest of BHA #1. M/U DM collar and perform RFO. RFO= 272.80°. Cont M/U BHA #1 to Flex collars
and 1 stnd of HWDP wash stand down to bottom no fill.;Drill ahead f/218' t/ 413' GPM-460 PSI-860 RPM-60 TQ-3.4k WOB- 1-3k. ECD-8.8ppg.;Held PJSM with
rig crew. Cont. drilling ahead f/413' t/901 GPM-420 PSI-950 TQ-3.9k WOB- 1-3k ECD-9.4ppg Started sliding for build section at 450'. Sliding an average of 50' a
stand.;Dragon boxes loaded 0 bbls
Total Dragon Boxes 0 bbls
Cuttings Totes Loaded 57 bbls
Total Cuttings Totes 57 bbls
ISO Tanks Loaded 0 bbls
ISO Tanks Total 0 bbls
Losses Downhole 0 bbls
Total 0 bbls
n (LAT/LONG):
evation (RKB):
API #:
Well Name:
Field:
County/State:
BRU 214-13
Beluga River
Hilcorp Energy Company Composite Report
, Alaska
Contractor
AFE #:
AFE $:
Job Name:221-00099 BRU 214-13 Drilling
Spud Date:
pgpg ()
Built and racked back 16 stds of 4.5" HWDP, jar std, and flex collars. Strappg j p
and tally 7-5/8" surface casing. Loaded on to trailers.;Performed diverter test and koomey draw down test. Annular close time-34 sec Knife closing time-25 sec.yg y g
Hydro tested diverter stack (ok).;Held PJSM on P/U surface BHA #1. M/U 9-7/8" Kymera bit, mud motor w/ 1.5° bend, XO to 4.5"HWDP. RIH to tagged depthy() y
of 131'. Displaced well over to 8.8 ppg spud mud. Circ. conductor clean.;Spudded well at 17:30 hrs.
pg g g j p p
sent 48 hr notice to AOGCC and Quadco for diverter function test on Wednesday
Witness(
was waved on diverter test by AOGCC rep Jim Reggypgg
gg )
Accepted rig at 09:30 hrspg
9/29/2022 Cont. directional drilling 9-7/8" surface hole F/897'-T/1209'. P/U-47K S/O-47K ROT-47K GPM-460 SPP-1275 psi RPM-60 TQ-4K MW-8.7 ppg ECD-9.3
ppg.;CBU X2, GPM-460 SPP-1250 psi TQ-4K RPM-60.;Flow checked well (static). POOH F/1209'-T/340'. Had 30K over pull tight spot at 1129', attempted to
work through on elevators w/ no luck. M/U TD, pumped through with no issues GPM-298 SPP-632 psi. P/U-50K S/O-43K at 1200'.;Performed rig service-
Greased TD, blocks, crown, IR, DWKS, wash pipe, brake linkage, and drive shaft. Pressured up compensators and checked magnets on TD. Cleaned suction
screens on MP's. Monitored hole on TT, static loss rate .6 bph loss rate.;Crew change, held PTSM. RIH on elevators F/405'-T/1209', w/ no issues or fill after
washing last std down to bottom. GPM-300 SPP-650 psi RPM-32. Shot on bottom survey. Pumped 20 bbl Hi-Vis sweep, sweep came back on time w/ no
increase in cuttings.;Cont. directional drilling 9-7/8" surface hole F/1209'-T/1580'. P/U-51K S/O-45K ROT-50K GPM-456 SPP-1315 psi RPM-54 TQ-4.5K WOB-1-
3K MW-8.7 ppg ECD-9.7 ppg.;Directional drill 9-7/8" surface hole F/1580'-T/2187'. P/U-61K S/O-48K ROT-53K GPM-500 PSI-1670 RPM-60 TQ-5-6.5K WOB-1-
3K MW-8.75 ppg ECD-9.6 ppg.;Crew change PTSM. Cont. directional drilling 9-7/8" surface hole f/2187' t/2326' P/U-61K S/O-48K ROT-55K GPM-500 PSI-1650
RPM-60 TQ-6.1K WOB-1-3K MW-8.8 ppg ECD-9.6 ppg. Distance to plan: 3.32’ center to center 1.55’ low 2.94’left.;CBU x 2 GPM-500 PSI-1520 RPM-60 TQ-
5.7K.;Flow checked well (static). POOH F/2326'-T/1209' without issue. P/U-70K S/O-48K at 2326'.;Performed rig service- Greased TD, blocks, crown, IR,
DWKS, wash pipe, adjusted brake linkage, and drive shaft. Monitored hole on TT, static loss rate 1.36 bph loss rate.;RIH on elevators F/1209'-T/2327', w/ no
issues or fill after washing last std down to bottom. GPM-430 SPP-1240 psi RPM-50 TQ-6.1k.;CBU prior to pumping 20 bbl Hi-Vis sweep. . GPM-430 SPP-1240
psi RPM-50 TQ-6.1K.;Dragon boxes loaded 80 bbls
Total Dragon Boxes 80 bbls
Cuttings Totes Loaded 285 bbls
Total Cuttings Totes 342 bbls
ISO Tanks Loaded 0 bbls
ISO Tanks Total 0 bbls
Losses Downhole 0 bbls
Total 0 bbls
9/30/2022 Pumped 20 bbl Hi-Vis sweep at 2327', sweep came back on time w/ no increase in cuttings.;Resumed directional drilling 9-7/8" surface hole F/2327'-T/2700'.
P/U-74K S/O-50K ROT-60K GPM-500 SPP-1675 psi RPM-55 TQ-7K WOB-1-2K MW-8.7 ppg ECD-9.3 ppg. Gave AOGCC 48 hr. notice to initial BOP test.;Crew
change, held PTSM. Cont. directional drilling 9-7/8" surface hole as per wp07, F/2700'-T/3096'. P/U-79K S/O-51K ROT-60K GPM-498 SPP-1743 psi RPM-55
TQ-7K WOB-10K MW-8.8 ppg ECD-9.2 ppg.;Started building first 300 bbl batch of new 9.0 ppg 6% KCL PHPA mud in pre mix tanks. Parker casing hands and
WHR arrived in Beluga @ 15:00 hrs. for up and coming surface casing job. AOGCC Rep Brian Bixby will witness initial BOP testing.;Cont. directional drilling 9-
7/8" surface hole as per wp07, F/3096-T/3380'. P/U-78K S/O-61K ROT-60K GPM-515 SPP-1830 psi RPM-65 TQ-8.7K WOB-10K MW-8.8 ppg ECD-9.4
ppg.;CCI crew worked barge with Casing, Cement equipment, Mud product, XO's and shoe track for production hole.;Drill t/3403' where TD was called by town
geologist. GPM-515 SPP-1830 psi RPM-65 TQ-8.7K WOB-10K MW-8.9 ppg ECD-9.2 ppg. P/U-70K S/O-48K Rot-56K.;CBU while leveling the rig. GPM-500
SPP-1750 psi RPM-65 TQ-8.7K MW-8.9 ppg ECD-9.2 ppg. Bottoms up sample was all coal. Spoke with town geologist and decision was made to drill another
20'.;Drill f/3403' to TD at @ 3423' GPM-515 SPP-1830 psi RPM-65 TQ-8.7K WOB-10K MW-8.9 ppg ECD-9.2 ppg. ROP 83'/hr. Distance to plan: 11' ctc 9.72'
high 5.14' left.;CBU x 2 GPM-500 SPP-1750 psi RPM-65 TQ-9.2K MW-8.9 ppg ECD-9.2 ppg.;Flow check well (static). POOH on elevators t/2327' without issue.
Flow check well 2.3bbl/hr static loss rate. RIH on elevators to bottom at 3423'. P/U-82K S/0-56K.;CBU, pump flagged sweep. GPM-500 SPP-1750 psi RPM-65
TQ-9.2K MW-8.9 ppg ECD-9.2 ppg.;Dragon boxes loaded 245 bbls
Total Dragon Boxes 325 bbls
Cuttings Totes Loaded 0 bbls
Total Cuttings Totes 342 bbls
ISO Tanks Loaded 104 bbls
ISO Tanks Total 104 bbls
Losses Downhole 0 bbls
Total 0 bbls
10/1/2022 Finished circ. flag sweep OOH, sweep came back on time, w/ 0% increase in cutting at the shakers. Flow checked well (static).;POOH on elevators F/3423'-
T/709'-BHA #1 w/ no issues. Had calculated hole fill for the trip. L/D jar std and flex collars. P/U-56K S/O-82K @ 3400'. Plugged in and down loaded MWD
data.;Plugged in and down loaded MWD data from tools.;Crew change, held PTSM. L/D MWD tools, milked motor, B/O bit, 9-7/8" Kymera bit grade- in gauge
PDC: 1-1-WT-A-X-I-NO-TD - RC: 1-1-WT-A-E-I-NO-TD.;Pulled 14" wear ring and L/D same. Cleaned & cleared rig floor. P/U and Dummy hanger w/ WHR on
location.;R/U fill up line, Parker handling equip. and power tongs. Staged casing drive sub/TIW on rig floor. Loaded rack w/ 7-5/8" shoe track and casing jts.;Held
PJSM w/ Parker casing hands, rig crew, CCI, and DSM. P/U 7-5/8" casing shoe track, BakerLoc connections, Tested Floats (ok). Cont. RIH w/ 7-5/8" casing
F/119'-T/559' as per run tally, at 60-80 fpm. Filling on the fly and topping off every 10 jts. Keeping close eye on pipe displacement.;Cont. RIH w/ 7-5/8" casing
F/559'-T/1171' as per run tally, at 60-80 fpm. Filling on the fly and topping off every 10 jts. Set down 15k. Couldn't work past.;M/U XO and TD and break
circulation with pumps at idle. Stage up to 5bbl/ min and attempt to wash down with no luck. P/U 10' above rotate down at 10RPM 3k torque was able to get
past.;Cont. RIH w/ 7-5/8" casing F/1184'-T/2153' as per run tally, at 60-80 fpm. Filling on the fly and topping off every 10 jts.;M/U XO and TD and break
circulation with pumps at idle. Stage up to 5bbl/ min 75PSI with desco treated fluid and pump 1 x pipe volume.;Cont. RIH w/ 7-5/8" casing F/2153'-T/3393'' as
per run tally, at 60-80 fpm. Filling on the fly and topping off every 10 jts. R/U bail extensions, P/U Landing jnt, hanger and pup. Washed down at 3bbl/min 90PSI.
Land hanger on seat. P/U-110k S/O-58k.;Continue to circulate mud for cement job 5bbl/min 55PSI. R/D Parker casing . Spot and R/U Halliburton cementers.;MU
plug launcher and hardline, Halliburton loaded lines with 2 bbls water and checked for leaks. Halliburton pressure tested lines at 348 low 3000 high, good tests.
Halliburton pumped 58 bbls 10.5 ppg Tuned Spacer at 4.5 bpm- 230 psi, dropped bottom plug and pumped 180 bbls (423 sx) 12.0 ppg;Type I II lead cement at
4.5 bpm- 210 psi, followed by 33 bbls (175 sx) 15.8 ppg Type I II tail cement at 4.5 bpm-340psi falling to 255 psi. Halliburton dropped top plug, then displaced
with 8.9 ppg Spud Mud at 4.5 bpm 150 psi. Slowed pump to 2 bpm with 13 bbl to go. Did bump the plug at 155.5 bbls;into displacement (calculated 153.1 bbls).
Held 1360 psi (FCP of 890 psi) for 3 minutes, bled off and floats held. Bled back 1 bbls to truck. Had 55 bbls of Spacer returns to surface and 45 bbls lead
cement to surface. Added Bridge Maker LCM to lead cement at 2.4 pps. Mix water temp 73 deg.;Pumped 50% excess on both lead and tail. Lost 0 bbls
throughout the job. Did reciprocate. CIP at 06:04, 10/2/2022. RD and released Halliburton.;Dragon boxes loaded 245 bbls
Total Dragon Boxes 325 bbls
Cuttings Totes Loaded 0 bbls
Total Cuttings Totes 342 bbls
ISO Tanks Loaded 104 bbls
ISO Tanks Total 104 bbls
Losses Downhole 0 bbls
Total 0 bbls
g
Gave AOGCC 48 hr. notice to initial BOP test.
gygy
Loaded rack w/ 7-5/8" shoe track and casing jts
pyppp
Cont. directional drilling 9-7/8" surface hole F/1209'-T/1580'. P/U-51K S/O-45K ROT-50K GPM-456 SPP-1315 psi RPM-54 TQ-4.5K WOB-1-g g p
3K MW-8.7 ppg ECD-9.7 ppg.;Directional drill 9-7/8" surface hole F/1580'-T/2187'. P/U-61K S/O-48K ROT-53K GPM-500 PSI-1670 RPM-60 TQ-5-6.5K WOB-1-ppg ppg
3K MW-8.75 ppg ECD-9.6 ppg.;Crew change PTSM. Cont. directional drilling 9-7/8" surface hole f/2187' t/2326' P/U-61K S/O-48K ROfT-55K GPM-500 PSI-1650ppg ppg g
RPM-60 TQ-6.1K WOB-1-3K MW-8.8 ppg ECD-9.6 ppg
g
;Cont. directional drilling 9-g@ p ggj
7/8" surface hole as per wp07, F/3096-T/3380'. P/U-78K S/O-61K ROT-60K GPM-515 SPP-1830 psi RPM-65 TQ-8.7K WOB-10K MW-8.8 ppg ECD-9.4p p p ppg
ppg.;CCI crew worked barge with Casing, Cement equipment, Mud product, XO's and shoe track for production hole.;Drill t/3403' where TD was called by town ppg
geologist.
Had 55 bbls of Spacer returns to surface and 45 bbls lead
cement to surface
ppg p
AOGCC Rep Brian Bixby will witness initial BOP testingpyg
Pumped 50% excess on both lead and tail. Lost 0 bbls
p
throughout the job
()ppgyp
Halliburton dropped top plug, then displaced pp y ()ppgyp pp g p pp p p g p
with 8.9 ppg Spud Mud at 4.5 bpm 150 psi. Slowed pump to 2 bpm with 13 bbl to go. Did bump the plug at 155.5 bbls;into displacement (calculated 153.1 bbls).pg p (ppg p p p p p p
Held 1360 psi (FCP of 890 psi) for 3 minutes, bled off and floats heldp(
Cont. RIH w/ 7-5/8" casing
gj
gg g ()
F/119'-T/559' as per run tally, at 60-80 fpm. Filling on the fly and topping off every 10 jts. Keeping close eye on pipe displacement.;
g
Flow check well 2.3bbl/hr static loss rate
ppg ppg
Flow check well (static).
gg g g
P/U 7-5/8" casing shoe track, BakerLoc connections, Tested Floats (ok). g()
yj
Cont. RIH w/ 7-5/8" casing F/2153'-T/3393'' aspp gp
per run tally, at 60-80 fpm. Filling on the fly and topping off every 10 jts.
10/2/2022 B/O and L/D landing jt. L/D buddy bails, and casing elevators, installed DP elevators. M/U Johnny Wacker, flushed stack and annular with black water. Weren't
able to clear hanger flutes and hanger neck due to gravel behind neck of hanger, Decided to N/D diverter system before installing pack off.;N/D vent line, riser,
knife valve, annular, diverter T, and DSA. Cleaned ring groves, greased, and installed protective covers. Worked on cleaning mud pits 3-5 and finishing 1st
batch on new 6% KCL PHPA mud in pits 8-9.;Cleared gravel from around hanger neck, and flushed flutes. M/U DP jt to pack off running tool and pack off. Set
pack off, RILDs'.;Crew change, held PTSM. Tailed in B section and N/U as per WHR on well head. Tested P-seals and void on B section for 15 min T/3000 psi
(ok). Finished mixing 1st batch of new mud. Spotted crane. Picked BOPs out of cradle, Transferred off to bridge cranes in sub.;Bolted up choke & kill - manual
and HCR valves on BOP stack. M/U BOP stack to B section/well head. M/U choke & kill lines. Removed unneeded XO's & subs from rig floor. Transfer first
batch of new mud from premix pits too pits 3-5.;Install bell nipple, mud divider, flow line, and bleed off lines. Install gas buster hose. Hook up hydraulics on stack,
HCR and kill. House keeping in cellar and on catwalk. Grease choke manifold.;R/U and purge air from system for BOP test and perform a shell test to 5000PSI.
Rack strap and tally 4.5" DP. Build another batch of KCL mud. Clean boiler and koomey room. Prep diverter equipment for storage.;Dragon boxes loaded 85
bbls
Total Dragon Boxes 495 bbls
Cuttings Totes Loaded 19 bbls
Total Cuttings Totes 380 bbls
ISO Tanks Loaded 312 bbls
ISO Tanks Total 624 bbls
Losses Downhole 0 bbls
Total 0 bbls
10/3/2022 Strapped & tallied 4.5” DP on the racks. Cleaned boiler& koomey rooms. Prepped surface studs and diverter equip for storage. Finished building new production
section mud. AOGCC Rep Brian Bixby flew into Beluga at 09:30.;Performed initial BOP test as per AOGCC regulations. 250 psi Low/ 3500 psi High for 5/5 min.
zero FP's and 5.5 hr. test time.;Re-purged choke manifold and mud lines. Performed 7-5/8" surface casing test T/3500 psi on chart for 30 min (good test).
Pumped 3.58 bbls Bled back 3.00 bbls. Drained stack, vacuumed out choke manifold and mud lines, blew down same.;R/D testing equip. Drained stack,
vacuumed out choke manifold and mud lines, blew down same. Changed out wash pipe on TD (leaking).;Install wear bushing. M/U mule shoe, P/U and RIH 56
jnts of 4.5" CDS-40 DP POOH and R/B.;P/U BHA #2. M/U new 6.75" HDBS GTD54DM to a 4.75" SperryDrill bent at 1.50°. M/U DM collar and perform RFO.
RFO=221.71°. Continue to M/U BHA to TM collar. Screw in P/U to Slim phase 4, plug in and download MWD tools. Perform Shallow pulse test GPM-200 PSI-
630. Load sources.;P/U Flex collars, RIH 2 stnds HWDP and P/U Jars and single of HWDP. Cont. toRIH out of derrick with 6 stnds of HWDP. Single in hole
t/2412' with 4.5" DP.;Dragon boxes loaded 85 bbls
Total Dragon Boxes 580 bbls
Cuttings Totes Loaded 0 bbls
Total Cuttings Totes 380bbls
ISO Tanks Loaded 104 bbls
ISO Tanks Total 104 bbls
Losses Downhole 728 bbls
Total 0 bbls
10/4/2022 Cont. singling in the hole w/ 4.5" DP F/2412'-T/2974' P/U-70K S/O-50K.;M/U TD, broke circ. CBU. Washed and reamed F/2974', started reaming cement
stringers at 3332'. Tagged plugs at 3337'.;Drilled up plugs, shoe track, and 20' of new formation. P/U-68K S/O-50K ROT-58K GPM-200 Spp-1150 psi RPM-30
TQ-6K MW-9.0 ppg ECD-9.6 ppg.;CBU. Caught BU sample. Pumped spacer, and displaced well over to new 6% KCL PHPA mud. GPM-200 SPP-730 psi RPM-
30.;Crew change, held PTSM. CBU X2 w/ new mud. Pulled into shoe at 3418'.;R/U testing equip. and performed FIT to EMW 12.7 ppg -608 psi.;Obtained
SPR's. Resumed 6-3/4" directional drilling ahead as per wp07 F/3443'-T/3713'. P/U-78K S/O-52K ROT-62K GPM-250 SPP-1145 psi RPM-60 TQ-2K WOB-1/2K
ROP-120 MW-9.0 ppg ECD-10.0 ppg. Max gas 106 units.;Cont. Drilling 6 3/4" production hole F/3713' T/4224', P/U-81K S/O-56K ROT-64K GPM-250 SPP-
1275 psi RPM-60 TQ-7.7K WOB-2/4K ROP-120 MW-9.1 ppg ECD-10.1 ppg. Max gas 90 units, Performing maintenance slides as needed.;Cont. Drilling 6 3/4"
production hole F/4224' T/4447', P/U-82K S/O-56K ROT-66K GPM-250 SPP-1240 psi RPM-60 TQ-8.1K WOB-2/4K ROP-120 MW-9.0 ppg ECD-9.9 ppg. Max
gas 110 units, Performing maintenance slides as needed. Distance to plan 16.24', High 15.12', Left 5.92'. Obtain SPR's.;CBU, GPM-250 SPP-1060 psi RPM-
60 TQ-7.6K, ECD-9.8 ppg. Max gas 164 units, Monitor well- slight seepage.;POOH F/4447' T/3394' with no issues, PU 90K off BTM, PU at shoe 72K, Disp Cal=
6.0 bbls, Disp Act= 7.0 bbls, Diff= 1 bbls.;Service top drive, drawworks and rig floor pipe handling equipment, change out dies in grabber box. Stab FOSV, hang
off blocks and top drive, Slip-N-Cut drilling line ( 9 wraps, 40 ft ).;Dragon boxes loaded 170 bbls
Total Dragon Boxes 750 bbls
Cuttings Totes Loaded 0 bbls
Total Cuttings Totes 380 bbls
ISO Tanks Loaded 208 bbls
ISO Tanks Total 936 bbls
Losses Downhole 0 bbls
Total 0 bbls
10/5/2022 Finished slip & cut, re-calibrated weight indicator. Static loss rate = .7 bph.;RIH on elevator F/3393'-T/4382' w/ no issue, washed last to bottom, no fill. P/U-70K
S/O-50K.;CBU, pumped 20 bbl Hi-Vis sweep w/ walnut, sweep came back on time w/ 10% increase in cuttings.;Cont. Drilling 6 3/4" production hole F/4447'
T/4634', P/U-82K S/O-58K ROT-70K GPM-250 SPP-1250 psi RPM-65 TQ-7K WOB-2/3K ROP-120 MW-9.0ppg ECD-9.9 ppg. Max gas 127 units @ 4575'.
Performing maintenance slides as needed.;Crew change, held PTSM. Cont. Drilling 6 3/4" production hole F/4634' T/5004', P/U-82K S/O-58K ROT-70K GPM-
251 SPP-1480 psi RPM-51 TQ-8.5K WOB-2/8K ROP-130 MW-9.0ppg ECD-10.1 ppg. Max gas 268 units @ 4819'.;Cont. Drilling 6 3/4" production hole F/5004'
T/5437', P/U-94K S/O-58K ROT-70K GPM-250 SPP-1480 psi RPM-65 TQ-9.3K WOB-4/10K ROP-75-130 MW-9.0ppg ECD-10.3 ppg. Max gas 307 units @
5252'.;CBU, GPM-250 SPP-1477 psi RPM-65 TQ-8.6K MW-9.1ppg ECD-10.2 ppg. Max gas 145 units, Monitor well= slight seepage. Obtained SPR's.;POOH
F/5437' T/4386', 5-10K drag F/5437' T/5000' then cleaned up. PU 100K, SO 64K off BTM, PU 90K, SO 58K @ 4386', Cal Disp= 7.2 bbls, Act Disp=8.7 bbls, Diff-
1.5 bbls.;Grease blocks, top drive, crown and wash pipe. Grease draw works, break linkage floor motor and checked oil in top drive.;RIH on elevator F/4386'
T/5378' setting 10-15K down F/5195' T/5224', washed last to bottom, no fill. P/U-100K S/O-60K, Cal Disp= 18.9 bbls, Act Disp=16.8 bbls, Diff= 2.1 bbls.;Pump
Hi-vis/walnut sweep STS- GPM-250 SPP-1290 psi RPM-65 TQ-9.4K MW-9.1ppg ECD-10.1 ppg. Max gas 500 units, Sweep back on time with 15% increase in
cutting. At BU observed 30% increase in cuttings.;Resume drilling 6 3/4" production hole F/5437' T/5506', P/U-98K S/O-58K ROT-72K GPM-250 SPP-1450 psi
RPM-65 TQ-9.2K WOB-4/6K ROP-110 MW-9.1ppg ECD-10.1 ppg. Max gas 154 units. Distance to plan 17.24', High 14.44', Left 9.43'.;Dragon boxes loaded 85
bbls
Total Dragon Boxes 835 bbls
Cuttings Totes Loaded 0 bbls
Total Cuttings Totes 380 bbls
ISO Tanks Loaded 0 bbls
ISO Tanks Total 936 bbls
Losses Downhole 0 bbls
Total 0 bbls
Cont. Drilling 6 3/4"production hole F/4447'
T/4634',ppg p
Cont. Drilling 6 3/4" production hole F/4634' T/5004'
Tagged plugs at 3337'.;Drilled up plugs, shoe track, and 20' of new formation
p
Cont. Drilling 6 3/4" production hole F/3713' T/4224',
Strapped & tallied 4.5” DP on the racks. Cleaned boiler& koomey rooms. Prepped surface studs and diverter equip for storage. Finished building new production pp ypp qp
section mud. AOGCC Rep Brian Bixby flew into Beluga at 09:30.;Performed initial BOP test as per AOGCC regulations
ppp p
Pulled into shoe at 3418'.;R/U testing equip. and performed FIT to EMW 12.7 ppg
10/6/2022 Cont. Drilling 6 3/4" production hole F/5506' T/5811', P/U-104K S/O-62K ROT-70K GPM-250 SPP-1800 psi RPM-65 TQ-9K WOB-6/10K ROP-75-130 MW-
9.1ppg ECD-10.15 ppg. Max gas 224 units @ 5748'.;Crew change, held PTSM. Cont. Drilling 6 3/4" production hole F/5811'- T/6121', P/U-101K S/O-61K ROT-
79K GPM-267 SPP-1865 psi RPM-62 TQ-10.5K WOB-6/10K ROP-75-130 MW-9.1ppg ECD-10.5 ppg. Max gas 156 units @ 5988'.;Loaded boiler #2 module out
w/ winch truck and prepped to send across to East side. Coil hands laid liner on driller side of rig. Moved in spotted coil unit, crane, and preceded to R/U on
BRU 233-23. Off line cont. to load out misc. non essential equip. onto floats to be barged across.;Cont. Drilling 6 3/4" production hole F/6121'- T/6432', P/U-
103K S/O-62K ROT-78K GPM-280 SPP-1870 psi RPM-70 TQ-10.8K WOB-3/10K ROP-80 MW-9.15ppg ECD-10.6 ppg. Max gas 101 units @ 6371'. Acquire
survey, Distance to Plan 28.17', High 25.63', Left 11.68'.;CBU, GPM-280 SPP-1630 psi RPM-70 TQ-11.2K, MW-9.15ppg ECD-10.5 ppg. Max gas 94 units,
Obtain SPR's and Monitor well= static.;POOH F/6432' T/3395', PU 120K, SO 68k off BTM, PU 70K @ 3395'. Cal Disp= 19.7 bbls, Act Disp= 28.8 bbls, Diff= 9.1
bbls.;Grease crown, blocks, wash pipe, topdrive and drawworks. Check oil on drawworks, topdrive and floor motor. Grease brake linkage, Monitor well- no gain
no loss.;RIH F/3395' T/6247' with no issues filling pipe every 1500', PU 120k, SO 55K.;Dragon boxes loaded 255 bbls
Total Dragon Boxes 1090 bbls
Cuttings Totes Loaded 0 bbls
Total Cuttings Totes 380 bbls
ISO Tanks Loaded 0 bbls
ISO Tanks Total 936 bbls
Losses Downhole 0 bbls
Total 0 bbls
10/7/2022 Cont. RIH on elevators F/6247'-T/6295'. Set down 30K @ 6295'. Attempted to work through on elevators w/ no luck. P/U-120K S/O-55K. Had calculated pipe
displacement for the trip.;M/U TD, washed/reamed F/6295' to bottom, GPM-273 SPP-1629 psi RPM-40 TQ-9.5K. Hole unloaded at BU. Max gas 668 units.
Circulated additional BU. Pumped 20 bbl Hi-Vis sweep w/ walnut, sweep came back on time w/ 5% increase in cutting.;Cont. Drilling 6 3/4" production hole
F/6432'- T/6527', P/U-103K S/O-63K ROT-79K GPM-280 SPP-1875 psi RPM-70 TQ-11K WOB-2/8K ROP-111 MW-9.2 ppg ECD-10.3 ppg. Max gas 22 units @
6464'. Attempted to slide for 10' after wiper trip/sweep.;F/6431'-T/6439' w/ no real success. Rotated out std. Added 1 drum on NXS lube to suction pit @ 6495',
attempted to slide again while lube was coming around the end of the bit. Slid F/6495'-T/6523' w/ much better results.;Gave AOGCC 48 hr. notice on running
casing and cementing.;Crew change, held PTSM. Cont. directional drilling 6 3/4" production hole F/6527'- T/6862', P/U-112K S/O-66K ROT-82K GPM-280 SPP-
1830 psi RPM-66 TQ-12K WOB-4/8K ROP-130 MW-9.2 ppg ECD-10.4 ppg. Max gas 28 units @ 6748'.;Cont. drilling 6 3/4" production hole F/6862'- T/7298',
P/U-118K S/O-68K ROT-85K GPM-260 SPP-1750 psi RPM-50 TQ-12.9K WOB-4/7K ROP-130 MW-9.3 ppg ECD-10.8 ppg. Max gas 340 units @ 7100'. Started
observing connection gas at 7100' after changing out shaker screens with pumps off for 7 min.;Turned pumps off for 4 min observing 60 units of connection gas
at BU @ 7223'. Dusted MW up to 9.35 observing minimal to no more connection gas. At 7258' pipe stalled and pressure spiked- slowed down rotated through
observing no change in cuttings at BU.;Cont. drilling 6 3/4" production hole F/7298' to TD at 7521', P/U-135K S/O-67K ROT-89K GPM-275 SPP-2380 psi RPM-
60 TQ-13K WOB-2/6K ROP-130 MW-9.35 ppg ECD-11.0 ppg. Max gas 68 units. Obtain final survey, Distance to plan 16.01', Low 13.79', Right 8.14'.;CBU,
GPM-275 SPP-1980 psi RPM-60 TQ-13.1K, MW-9.35 ppg ECD-10.9 ppg. Max gas 23 units, Acquire SPR's and monitor well= static.;POOH F/7523' T/6372'
picking last stand up high and running back in hole T/ 6427' with 10-15K drag the hole trip. PU 140K, SO 78K off BTM, PU 125K, SO 65K @ 6372'. Pulled 30K
over @ 6878' wiped with no other issues. Cal Disp= 7.2 bbls, Act Disp= 8 bbls, Diff= .8 bbls.;Dragon boxes loaded 170 bbls
Total Dragon Boxes 1260 bbls
Cuttings Totes Loaded 0 bbls
Total Cuttings Totes 380 bbls
ISO Tanks Loaded 104 bbls
ISO Tanks Total 1040 bbls
Losses Downhole 0 bbls
Total 0 bbls
10/8/2022 Cont. RIH F/6427'-T/7521'. Washed last std down, had 6' of fill on bottom. P/U-120K S/O-65K ROT-80K GPM-180 SPP-1750 psi RPM-30 TQ-13.2K MW-9.4
ppg ECD-11 ppg.;CBU and hole unloaded with 50% in cuttings GPM-280 SPP-1800 psi RPM-70 TQ-13.5K MW-9.4 ppg ECD-10.8 ppg Max gas 500 units.
Pumped 20 bbl Hi-Vis sweep w/ walnut, sweep cam back on time w/ a 5% increase in cuttings. Dusted up mud weight to 9.5 ppg.;Flow checked well for 30 min
on trip tank while working pipe every 10 min (static).;CBU to check for gas. GPM-280 SPP-1800 psi RPM-70 TQ-13.5K MW-9.4 ppg ECD-10.9 ppg Max gas 9
units. Added 1 drum on NXS lube to suction pit and spotted on back side of DP in open hole. Flow checked well for 10 min (static).;POOH on elevators F/7521'-
T/6925' racking back in the derrick (10 stds.) P/U-140K S/O-72K. Pumped 20 bbl dry job 2 lbs over MW.;Crew change, held PTSM. Cont. POOH L/D singles
F/6925'-T/6893'. Had 30K over pull @ 6893' (coal), attempted to work through on elevators w/ no luck.;M/U TD, washed & reamed the full std. F/6893'-T/6861'.
P/U-134K S/O- 67K ROT-80K GPM-256 SPP-1411 psi RPM-62 TQ-13.2K.;Cont. POOH on elevators L/D singles F/6861'-T/4141'. P/U- 80K S/O-58K Running
pressure washer Wessel through pipe, cleaning & re-doping threads, and installing thread protectors on tight on the cat walk.;Cont. POOH on elevators L/D
singles F/4141'-T/3457'. Running pressure washer Wessel through pipe, cleaning & re-doping threads, and installing thread protectors on tight on the cat walk.,
Cal Disp= 25.72 bbls, Act Disp=36.89 bbls, Diff= 11.17 bbls.;POOH racking back in the derrick F/3457' T/733'. Dropped 2.39" drift in the top of std 44.;Rack back
8 stds of HWDP laying down jar std F/733' T/171'.;L/D 2 NM flex collars, hold PJSM for removing sources, Pull sources and perform download as per MWD rep.
L/D remaining pieces of BHA to mud motor flushing and cleaning with water. Close blinds and break bit- L/D mud motor. Bit grade 1-1- 1/16" under gauge.;Clear
and clean rig floor, Set TQ on top drive to 8K.;Rig up Parker CSG. power tongs and pipe handling equipment. Rig up fill up hose and bring centralizers to rig
floor. TQ coupler on JFELion to BTC XO for floor valve. Stage 4.5" shoe and liner on catwalk and loading arms.;Hold PJSM for running liner, Baker lock shoe
track and check floats- floats good, make up BTC x JFELion crossover JT. and RIH to 145', RIH with 4.5" 12.6# , L-80 JFELion liner T/362' installing centralizers
on every jt.;Dragon boxes loaded 255 bbls
Total Dragon Boxes 1515 bbls
Cuttings Totes Loaded 0 bbls
Total Cuttings Totes 380 bbls
ISO Tanks Loaded 104 bbls
ISO Tanks Total 1144 bbls
Losses Downhole 0 bbls
Total 0 bbls
p ppg
Flow checked well for 10 min (static).;
ggpp
Cont.drilling 6 3/4" production hole F/7298' to TD at 7521
p gpp gqpgpp gg
Stage 4.5" shoe and liner on catwalk and loading arms.;Hold PJSM for running liner, Baker lock shoe p
track and check floats- floats good
p
Cont. Drilling 6 3/4"production hole F/5811'- T/6121',
Cont. Drilling 6 3/4" production hole F/5506' T/5811',
Cont. drilling 6 3/4" production hole F/6862'- T/7298',
10/9/2022 Cont. running 4.5" 12.6# L-80 JFE Lion liner F/362'-T/3392'. P/U-40K S/O-38K Gave AOGCC 48 hr notice on MIT testing.;M/U XO, screw in TD, Broke
circulation. Staged up MP. CBU GPM-210 SPP-150 psi. Obtained rotary parameters- RPM-10 =3K RPM-20 =3.3K RPM-30 =3.7K.;Crew change, held PTSM
and weekly safety meeting w/ rig crew. Cont. running 4.5" 12.6# L-80 JFE Lion liner F/3392''-T/4268'. P/U-44K S/O-40K Pipe displacement Cal=18.2 bbls
Act=15.6 bbls Diff=-2.6 bbls.;C/O handling equip. P/U & M/U HRD-E HD ZXP liner top packer / Flex lock V liner hanger 5.5" X 7.63" as per BOT Rep. Mixed &
poured Zanplex into liner hanger top. Ran in hanger on 1 std of HWDP.;M/U TD, staged up MP to 5 bpm, and CBU. P/U-44K S/O-40K GPM-210 SPP-305
psi.;RIH w/ 4.5" liner on DP F/4268'-T/6004'. Pipe displacement Cal = 16.52 bbls Act = 14.27 bbls Diff = -2.25 bbls.;M/U TD, staged up MP to 5 bpm, and CBU.
P/U-78K S/O-52K GPM-210 SPP-620 psi.;Cont. RIH w/ 4.5" liner on DP F/6004'-T/7437' setting down 20K, M/U topdrive and wash down @ 3 BPM, 540 psi
observing pressure spikes up to 1050 psi. F/7437' T/7503'. PU 105K, SO 65K.;P/U cement head-15' and 5" pups and M/U to top drive torqueing through. Wash
down @ 3 BPM, 547 psi F/7503' T/7517' setting 10-20K down multiple times, staged pumps up to 5 BPM, 670 psi attempting to wash down past hard tag @
7517' with no success. Good indication shoe was on BTM.;CBU 2x conditioning mud for cement job at 5 BPM, 809 psi with a max gas of 881 units. Hold PJSM
for cement job.;Halliburton pumped 5 bbls to fill lines. Shut in at Baker cement head and PT lines at 312 psi low 4445 psi high. Good test. Lined up Baker
cement head to Halliburton, pumped 30 bbls 10.5 ppg spacer at 4.4 bpm-590 psi.;followed with 133 bbls (325 sx) 12 ppg Type I II Lead cement at 4.4 bpm, 525
to 186, followed with 19 bbls (100 sx) 15.3 ppg Type I II Tail cement at 2.2 bpm-120 psi. Added 2 pps Bridge Maker LCM to lead cement. Washed up lines
across cement head back to cuttings box.;Baker released dart, Halliburton then displaced with 9.5 ppg 6% KCL mud at 4.5 bpm-90 ICP. 30 bbls into
displacement reduced rate to 3 bpm observing dart latch wiper plug 41 bbls pumped. With 10 bbls to go, reduced rate to 3 bpm and bumped plug/landing collar
105 bbls into displacement.;(calculated at 104.7 bbls). FCP 1490 psi. Halliburton increased to and held 2007 psi (517 over fcp) for 2 minutes. Checked floats
bleed back .5 bbl, then pressured up to 2840 psi for 1 min. Slacked off on blocks from 85K to 20K, giving us a good indication hanger set. CIP at 23:30 on 10-9-
22.;Halliburton pressured up to 3600 psi with good indication at surface packer set/sheared @ 3515 psi. Held pressure for 1 min, bleed off and picked up 3’ with
60K pick up weight indicating tool released. Set in slips and blew down all surface lines.;Rig down hoses and L/D cement head. Screwed into stump and turned
pumps on at idol to pump stall @ 635 psi picking up slowly observing flow and pressure drop, increased pump rate to 8 BPM, 450 psi- CBU with 45 bbls of
cement to surface dumping to cuttings box.;L/D 15’ pup and E-kelly Jt., screwed in and pumped nerf/wiper ball STS @ 8 BPM, 450 psi.;POOH F/3200' T/surface
observing calculated displacement. Break running tool into 2 pieces as per baker rep and L/D packer running tool. PU 58K, SO 48K @ 3200'.;Flush and clean
stack with black water, break off 15' pup from E-kelly jt. Remove XO's and pups on top/bottom of cement head.;Pick up TBR polish mill assembly and M/U to first
std of HWDP. RIH F/surface T/1820'. PU 44K, SO 40K.;Dragon boxes loaded 0 bbls
Total Dragon Boxes 1515 bbls
Cuttings Totes Loaded 0 bbls
Total Cuttings Totes 380 bbls
ISO Tanks Loaded 208 bbls
ISO Tanks Total 1352 bbls
Losses Downhole 0 bbls
Total 0 bbls
10/10/2022 Cont. polishing PBR and dressing off liner top @ 3214' MD. GPM-147 SPP- 200-520 psi RPM-20-60 TQ-5.5/7K.;Held PJSM on displacement while CBU. GPM-
314 SPP-349.;Pumped 20 bbl Hi-Vis spacer, follow by 3% inhibited KCL brine at 8.4 ppg. GPM-357 SPP-400 psi.;Shut down and perform flow check for 30 min.
Cleaned out TT and under shaker beds while flow checking well.;POOH L/D 4.5" DP F/3210'-T/1000' P/U58K S/O-52K. Running pressure washer Wessel
through pipe, cleaning & re-doping threads, and installing thread protectors on tight on the cat walk. AOGCC Jim Regg waved witness of MIT tests.;Crew
change, held PTSM. Cont. POOH L/D 4.5" DP F/1000'-T/515'. Ran remaining 10 stands out of derrick in the hole T/1135'. POOH L/D remainder of 4.5" DP,
HWDP, and Baker polishing mills.;With 546' of DP / HWDP to lay down. Noticed anomaly in drilling. Discussed situation with rig superintendent. Decision was
made to slip & cut 500' of drill line ( 87 wraps).;Resumed L/D DP, HWDP, and Baker polishing mills assy. F/546'-T/surface.;Blow down top drive through MP's,
pick up test jt drain stack and pull wear ring.;R/U and purge lines, close blinds and PT casing to 3500 for 30 charted min- good test. Pumped 117.5 gal - bled
back 117.5 gal.;Rig up Parker casing tongs and pipe handling equipment, load pipe on catwalk and rack. M/U XO for floor valve.;P/U and inspect bullet seal
assembly as per baker rep. RIH with 4.5" 12.6# L-80 JFELion Tbg. to 544', At 382' had to shut down for 15 min due to pin on back side of buggy cable fell out.
Re-pinned and test ran.;Cont. to RIH with 4.5" 12.6# L-80 JFELion Tbg. F/544' T/2717', Rig up pollard spool and sheave for control line, M/U Chem Injection Sub
install control line- PT to 2500 psi- good test. Bled down to 1000 psi and cont. RIH F/2717' T/3183' installing 2 ss bands per jt.;Perform space out tagging mule
shoe @ 3224.5'. L/D 3 singles and M/U pups ( 1.76', 5.77', 7.76' ). Pick up last jt. and hanger. Bleed off pressure to control line and terminate control line at the
hanger as per WHR. At 0440 hrs 10 gallons of KCL/Polymer mud was spilled onto;gravel pad while emptying pit # 6 into dragon box. Notifications made and
spill was cleaned up.;Dragon boxes loaded 400 bbls
Total Dragon Boxes 1915 bbls
Cuttings Totes Loaded 0 bbls
Total Cuttings Totes 380 bbls
ISO Tanks Loaded 624 bbls
ISO Tanks Total 1976 bbls
Losses Downhole 0 bbls
Total 0 bbls
10/11/2022 Terminated control line through tubing hanger, S/O and land hanger in wellhead, applied 500 psi on seal assembly to verify in place, RILD's, B/O and L/D
landing joint.;RU test equipment and chart recorder, flooded surface lines and stack, function rams to expel air from cavities, purge air from test hoses, closed
blinds, installed gauge on OA, applied 3140 psi on tubing and liner, held 30 min on chart, good test. Pressure dropped 44 psi over 30 min. Pumped 1.25;bbls,
bled back 1.25 bbls. Saw 25 psi on OA. RU test equipment on 7 5/8" OA, installed gauge on mezz kill to monitor tubing, applied 2665 psi on 7 5/8" x 4 1/2" OA
and held 30 min on chart, good test, pressure dropped 10 psi over 30 minutes. Pumped 1 bbl, bled back 1 bbl. Saw 165 psi on tubing.;RD test equipment.
Released Pollard Rep, night mud Engineer and Baker Rep.;Built 100 bbls BaraKlean in pre-mix and pumped same through all surface lines, topdrive, BOP
stack, choke manifold, poorboy degasser, both pumps, choke/kill, bleeders and pop-off's. Chased same with 100 bbls fresh water then 100 bbls of BaraCor 100.
Blew everything down, 4 bolted stack.;SIMOPS: RD Quadco gas detection equipment and boxed up for shipping, changed oil in topdrive and checked end play,
removed saver sub, bails and wash pipe from topdrive, brought in Production pressure washer.;Removed flow line, flow riser, choke and kill lines, removed BOP
stack from wellhead and staged at cellar entrance.;Brought in dry hole tree, installed same on wellhead with Vault Rep, terminated control line at tree. Torqued
flange and PT hanger neck seals and hanger void to 5000 psi for 15 min each- good tests. Flushed pit tanks with BaraKlean/BaraCor 100 pills and empty
pits.;Cleaning pits, went through fluid end of both MP's inspecting valves-seats-swabs and liners, changing 2 swabs in MP #2 mods 1 & 2, dry out fluid end of
pumps and coat with LPS and re-assemble for storage. Pull rams and cleaning ram cavities and ram bodies drying and coating with LPS for storage.;Rig was
released at 00:00 hrs.;Dragon boxes loaded 0 bbls
Total Dragon Boxes 1915 bbls
Cuttings Totes Loaded 0 bbls
Total Cuttings Totes 380 bbls
ISO Tanks Loaded 0 bbls
ISO Tanks Total 1976 bbls
Losses Downhole 0 bbls
Total 0 bbls
Cont. running 4.5" 12.6# L-80 JFE Lion liner F/362'-T/3392'.Gave AOGCC 48 hr notice on MIT testing
gp
AOGCC Jim Regg waved witness of MIT tests.
applied 3140 psi on tubing and liner, held 30 min on chart, good test
Terminated control line through tubing hanger, S/O and land hanger in wellhead,
gqp
Ran in hanger on 1 std of HWDP
Cont. polishing PBR and dressing off liner top @ 3214' MD
POOH L/D remainder of 4.5" DP,g
HWDP, and Baker polishing mills
g@
Hold PJSMgj pg
for cement job.;Halliburton pumped 5 bbls to fill lines. Shut in at Baker cement head and PT lines at 312 psi low 4445 psi high. Good test. Lined up Baker jpp ppg p
cement head to Halliburton,pumped 30 bbls 10.5 ppg spacer at 4.4 bpm-590 psi.;followed with 133 bbls (325 sx) 12 ppg Type I II Lead cement at 4.4 bpm, 525p p ppg p p p ()ppgyp p
to 186, followed with 19 bbls (100 sx) 15.3 ppg Type I II Tail cement at 2.2 bpm-120 psi. Added 2 pps Bridge Maker LCM to lead cement. Washed up lines( ) ppg yp p p pp g p
across cement head back to cuttings box.;Baker released dart, Halliburtron then displaced with 9.5 ppg 6% KCL mud at 4.5 bpm-90 ICP. 30 bbls into g pppg p
displacement reduced rate to 3 bpm observing dart latch wiper plug 41 bbls pumped. With 10 bbls to go, reduced rate to 3 bpm and bumped plug/landing collarppgppgppgpppg g
105 bbls into displacement.;(calculated at 104.7 bbls). FCP 1490 psi. Halliburton increased to and held 2007 psi (517 over fcp) for 2 minutes. Checked floatsp()p p( p)
bleed back .5 bbl, then pressured up to 2840 psi for 1 min. Slacked off on blocks from 85K to 20K, giving us a good indication hanger set.
gg pp gq
RIH with 4.5" 12.6# L-80 JFELion Tbg
pyp
Cont. running 4.5" 12.6# L-80 JFE Lion liner F/3392''-T/4268'.
g
Good indication shoe was on BTM
Activity Date Ops Summary
10/22/2022 PJSM and PTW
SLB crews waiting on weather to fly to Beluga,Warm up crane and mobilize Cruz crane to K pad and set wellhouse on BRU 233-23
R/U crane on 214-13, Crane maintenance,SLB coil arrives . PJSM and PTW.
Mobilize equipment to K pad.,Set containment, rain for rent tanks, and RU SLB coil unit.
Haul 250BBL water and add to supply tank.,Test coil BOPE's to 250psi/3000psi - Test good. AOGCC witness waived by Jim Regg via E-mail 10/20/22 @
15:06hrs.,NU BOPE's. Secure well and SDFN.
10/23/2022 PJSM and PTW
Warm up equipment,Pick up lubricator and MU cleanout BHA. 2-7/8" CTC and pull test to 25k. MU DFCV and disconnect, PT to 3,000psi. MU 3.5" stabilizer, 6ft
weight bar and 2.5" nozzle.
Go to well and PT to 250/3000psi - Test good,RIH and dry tag at 7,430ft (PBTD 7,433ft). Online with pump at 1.5BPM, cannot jet any deeper than 7,430ft.
Reciprocate across the bottom 200ft of well. Continue circulating out drilling mud at 1.5BPM while POOH.,Laydown nozzle, BHA, and coil lubricator.
Set down injector
PJSM and PTW w/ AK E-line
RU and MU CBL tools,RIH and tag at 7,433ft (PBTD 7,433ft)
Pull CBL log to liner top (3,228ft). TOC ~ 3430ft.
Pull repeat pass and POOH,RD AK E-line.
Secure well and SDFN.
10/24/2022 PJSM and PTW
Warm up equipment,Pick up the lubricator and MU BHA. 2-1/8" CTC, DFCV, and 2.5" nozzle.
Return line from flow cross to tank has water trapped and is frozen. Wrap tree and hardline with visqueen and heater trunks to thaw.
PT lubricator to 250/3000 psi.,Open well and RIH. Start pumping N2 at 1000 scf/m at 7000' ctmd. Tag at 7433' ctmd and wait on bottom while pumping N2 until
N2 is out nozzle.
POOH chasing returns to surface until all water has been recovered. Recover 113 bbls tubing + 32 bbls coil volume of water.
Pressure up tubing to 1486 psi and lose prime on N2 pump. Shut downN2 pump.,Coil at surface. Close swab and trap 1486 psi of N2 on tubing.
Laydown coil BHA, lubricator and set down injector on back deck.
RD hardline. Secure well with night cap on BOP's. SDFN.
10/25/2022 SLB coil hold TBT and approve PTW.
RDMO coil equipment from location. Stage equipment at barge landing.
SLB crew depart Beluga for Dillon platform.,Cleanout and manifest fluids from return tank. Move tanks to barge landing.
11/7/2022 AK Eline on location. Open PTW & PJSM. Spot in equipment. Remove tree cap and find an ice plug from swab valve to tree cap.,Locate heater and wrap tree.
Begin to melt ice plug. Tie new cable head (6/2) & make up lubricator.,Ice plug clear, stab on WLV's & lubricator w/ BHA #1. Jump start triplex as battery was
dead. PT lubricator to 250/3000 per sundry. Pass.,SITP = 1376. RIH w/ 7' x 1.69" WB, 5' x 3.125" GR/CCL, Shock sub, 13' x 2 7/8" Geodynamics Razor perf guns
(9.8' CCL to top shot). Perform tie in pass from 7200' - 6700'. Send to Geo. On depth. Shoot the Beluga J4 zone from 7025' - 7038' (CCL stop depth 7015.2').
Shooting pressure = 1376 psi, 5 min = 1380, 10 min = 1381, 15 min = 1381. POOH and lay day perf guns. All shots fired.,Lay down lubricator and secure well for
the night. Plug in equipment.
11/8/2022 AK Eline on location. Open PTW & PJSM. Rig up w/ GPT tool and stab on lubricator. Open up to WH pressure @ 1707 psi.,RIH w/ 12' x 1.69" WB, 7' x 1.69" GPT
w/ CCL. Find FL @ 7080'. POOH to 6000'. Wrap tree w/ heater. Bleed tubing pressure from 1741 psi to 1203 psi. RIH and find FL @ 7076'. POOH.,SITP = 1261.
RIH w/ 3 1/8" GR/CCL, 2 3/4" shock sub, 20' x 2 7/8" Geo Razor guns. CCL to top shot = 9'. Pull correlation pass and send to Geo, on depth. Shoot the Beluga I1
from 6256' - 6276' (CCL stop depth = 6247') Shooting pressure = 1278 psi, 5 min = 1284 psi, 10 min = 1284 psi, 15 min = 1285 psi. POOH all shots fired.,SITP =
1311. RIH w/ 3 1/8" GR/CCL, 2 3/4" shock sub, 19' x 2 7/8" Geo Razor guns. CCL to top shot = 10'. Pull correlation pass and send to Geo, on depth. Shoot the
Beluga H11 from 5932' - 5951' (CCL stop depth = 5922') Shooting pressure = 1325 psi, 5 min = 1339 psi, 10 min = 1352 psi, 15 min = 1369 psi. POOH all shots
fired.,Lay down guns and lubricator. SI well at the swab valve. Prep for GPT run in the morning. Secure well for the night.
11/9/2022 PTW and PJSM. Pickup lubricator and GPT logging tools. SITP 1549 psi. RIH and find fluid level at 7076'. POOH. Lay down lubricator and secure tree with night
cap. SDFN. Turn well over to production to bring well online.
11/30/2022 AKE-line crew fly to BRU with perf guns. Begin applying heat and jump-starting e-line equipment on F pad.
RD and MIRU on K pad (BRU 214-13). Complete moving support equipment to K pad.
n (LAT/LONG):
evation (RKB):
API #:
Well Name:
Field:
County/State:
BRU 214-13
Beluga River
Hilcorp Energy Company Composite Report
, Alaska
Contractor
AFE #:
AFE $:
Job Name:221-00099 BRU 214-13 Completion
Spud Date:
g(
Pull CBL log to liner top (3,228ft). TOC ~ 3430ft. gp()
Pull repeat pass and POOH,RD AK E-line.
Shoot the Beluga I1
from 6256' - 6276'
RU SLB coil unit.
AK Eline on location
12/1/2022 Permit & PJSM.,Travel to well site. Warm up equipment. Snow removal.,Rig up AK E-line.,Arm gun and stab on to well.,Pressure test 250 / 3000 PSI. Test
good.,Run in hole w/ 10' x 2-7/8" gun for H5 zone.,Tie in and send log to town for approval. Was given 10' correction depth change from town to correlate. Made
adjustment and resent tie in corrected log and town approved.,Spotted gun. Fired 10' x 2-7/8" gun at H5 zone 5716' to 5726' (CCL to top shot 10' placing CCL at
5706' at time of shot). Good weight loss when gun fired. POOH. PSI start:1107 / 1119 When gun fired / 5 Min 1129 / 10 Min 1151 / 15 Min 1195 / 20 Min
1213.,Out of hole. All shots fired. End cap dry. Make up and arm next 10' x 2-7/8" gun for H4 zone.,Run in hole w/ 10' x 2-7/8" gun for H4 zone.,Tie in and send
log to town for approval. Town approved.,Spotted gun. Fired 10' x 2-7/8" gun at H4 zone 5660' to 5670' (CCL to top shot 10' placing CCL at 5650' at time of shot).
No weight change when fired. PSI has been dropping on well prior to shot and continuing to drop. POOH. PSI start:1378 / 1376 When gun fired / 5 Min 1356 / 10
Min 1328 / 15 Min 1314.,Out of hole. All shots fired. End cap dry. Make up and arm next 6' x 2-7/8" gun for H3 zone.,Run in hole w/ 6' x 2-7/8" gun for H3
zone.,Tie in and send log to town for approval. Town approved.,Spotted gun. Fired 6' x 2-7/8" gun at H3 zone 5629' to 5635' (CCL to top shot 10' placing CCL at
5619' at time of shot). Good weight loss when gun fired. POOH. Well PSI gradually built from 1247 to 1258 over 20 minutes.,Out of hole. All shots fired. Lay down
lubricator and install night cap. Prep GPT tool for tomorrow morning run. Production to flow well overnight and for GPT run.
g
Fired 6' x 2-7/8" gun at H3 zone 5629' to 5635' (
p g
Fired 10' x 2-7/8" gun at H4 zone 5660' to 5670'
Rig up AK E-line
pp g p
Fired 10' x 2-7/8" gun at H5 zone 5716' to 5726
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A
Benjamin Hand Digitally signed by Benjamin Hand
Date: 2022.10.11 12:02:37 -08'00'Chelsea Wright Digitally signed by Chelsea Wright
Date: 2022.10.12 08:36:11 -08'00'
TD Shoe Depth: PBTD:
Jts.
2
81
Yes X No X Yes No 60
Fluid Description:
Liner hanger Info (Make/Model): Liner top Packer?: Yes No
Liner hanger test pressure:X Yes No
Centralizer Placement:
Preflush (Spacer)
Type: Density (ppg) Volume pumped (BBLs)
Lead Slurry
Type:Sacks: Yield:
Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm):
Tail Slurry
Type:Sacks: Yield:
Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm):
Post Flush (Spacer)
Type: Density (ppg) Rate (bpm): Volume:
Displacement:
Type: Density (ppg) Rate (bpm): Volume (actual / calculated):
FCP (psi): Pump used for disp: X Yes No
Casing Rotated? Yes X No Reciprocated?X Yes No % Returns during job
Cement returns to surface?X Yes No Spacer returns?X Yes No Vol to Surf:
Cement In Place At: Date: Estimated TOC:
Method Used To Determine TOC:
Casing (Or Liner) Detail
Bullnose Shoe 8 5/8
Rotate Csg Recip Csg Ft. Min. PPG8.9
Shoe @ 3418.26 FC @ Top of Liner3,339.20
Floats Held
Spud Mud
CASING RECORD
County State Alaska Supv.J Richardson / J Gruenberg
Hilcorp Energy Company
CASING & CEMENTING REPORT
Lease & Well No.BRU 214-13 Date Run 1-Oct-22
Setting Depths
Component Size Wt. Grade THD Make Length Bottom Top
BTC Frontier 1.78 3,418.26 3,416.48
Csg Wt. On Hook:54,000 Type Float Collar:Frontier No. Hrs to Run:9.5
8.9 4.5
100
890
FI
R
S
T
S
T
A
G
E
10.5Tuned Spacer 58
155.5/153.1
1360
45
Halliburton
15.8 33
Bump press
Cement to Surface
Bump Plug?
6:04 10/2/2022 0
3,418.263,423.00 3,337.55
CEMENTING REPORT
Csg Wt. On Slips:39,000
Spud Mud
12 180
Type of Shoe:Frontier Bullnose Casing Crew:Parker
www.wellez.net WellEz Information Management LLC ver_04818br
4.5
Casing 7 5/8 29.7 L-80 CDC USS 77.28 3,416.48 3,339.20
Float Collar 8 5/8 BTC Frontier 1.65 3,339.20 3,337.55
Casing 7 5/8 29.7 L-80 CDC USS 3,312.78 3,337.55 24.77
Pup 7 5/8 29.7 L-80 CDC USS 3.87 24.77 20.90
Hanger 13 5/8 BTC 1.10 20.90 19.80
Type I II 425 2.44
Type I II 175 1.16
4.5
TD Shoe Depth: PBTD:
Jts.
1
1
1
1
131
Yes X No X Yes No
Fluid Description:
Liner hanger Info (Make/Model): Liner top Packer?:X Yes No
Liner hanger test pressure:X Yes No
Centralizer Placement:
Preflush (Spacer)
Type: Density (ppg) Volume pumped (BBLs)
Lead Slurry
Type:Sacks: Yield:
Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm):
Tail Slurry
Type:Sacks: Yield:
Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm):
Post Flush (Spacer)
Type: Density (ppg) Rate (bpm): Volume:
Displacement:
Type: Density (ppg) Rate (bpm): Volume (actual / calculated):
FCP (psi): Pump used for disp: X Yes No
Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job
Cement returns to surface? Yes X No Spacer returns? Yes X No Vol to Surf:
Cement In Place At: Date: Estimated TOC:
Method Used To Determine TOC:
1/2 325 2.39
1/2 100 1.24
4.4
3,214.57
7,371.45 3,248.17
Hanger 6 JFELion Baker 33.60 3,248.17
29.32 7,400.77 7,371.45
Casing 4 1/2 12.6 L-80 JFELion USS 4,123.28
Crossover 4 1/2 12.6 L-80 JFELion USS
7,431.93
Casing 4 1/2 12.6 L-80 BTC USS 31.16 7,431.93 7,400.77
7,472.93 7,432.99
Landing collar 5 Jhobbs 1.06 7,432.99
1.30 7,474.23 7,472.93
Casing 4 1/2 12.6 L-80 BTC USS 39.94
Float Collar 5 Innovex
Centralizer on every JT. for the first 130 jts
Casing 4 1/2 12.6 L-80 BTC USS 41.42 7,515.65 7,474.23
HRD-E HD ZXP 5" x 7"
www.wellez.net WellEz Information Management LLC ver_04818br
4.4 3010.5Spacer
2.2
Type of Shoe:Innovex Casing Crew:Parker
12 133
7,515.007,521.00 7,432.00
CEMENTING REPORT
Csg Wt. On Slips:
KCL/Polymer
23:30 10/9/2022 3260'
15.3 19
Bump press
CBL
Bump Plug?
105/104.7
2007
45
Cement truck
FI
R
S
T
S
T
A
G
E
9.5 4.5
16
1490
Csg Wt. On Hook: Type Float Collar:Innovex No. Hrs to Run:16
Innovex 1.35 7,517.00 7,515.65
Setting Depths
Component Size Wt. Grade THD Make Length Bottom Top
Hilcorp Energy Company
CASING & CEMENTING REPORT
Lease & Well No.BRU 214-13 Date Run 9-Oct-22
CASING RECORD
County State Alaska Supv.J Richardson / C Yearout
Floats Held3500
KCL/Polymer
Rotate Csg Recip Csg Ft. Min. PPG9.5
Shoe @ FC @ Top of Liner
Casing (Or Liner) Detail
Float Shoe 5
David Douglas Hilcorp Alaska, LLC
Sr. GeoTechnician 3800 CenterPoint Drive, Suite 1400
Anchorage, AK 99503 1 tz Z
Tele: (907) 777-8337 U
Hill irp .Ua%ka, 1.1A E-mail: david.douglas@hilcorp.com
Date: 12/01/2022 RECEIVED
To: Alaska Oil & Gas Conservation Commission
Petroleum Geology Assistant
333 W 7th Ave Ste 100 o 2��
Anchorage, AK 99501
DATA TRANSMITTAL AOGCC
BRU 214-13
- PTD 222-117
- API 50-283-20187-00-00
Washed and Dried Well Samples (09/28/2022 to 10/08/2022)
B Set (3 Boxes):
WELL
BOX
SAMPLE INTERVAL (FEET / MD)
BRU 214-13
BOX 1 OF 3
3360' - 4800' MD
BRU 214-13
BOX 2 OF 3
4800' - 6360' MD
BRU 214-13
BOX 3 OF 3
6360' - 7521' MD (TD)
Please include current contact information if different from above.
Please acknowledge receipt by signing and returning one copy of this transmittal.
Receive ey: Al J�JkyDate: l2
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.
Received By: Date:
Date: 11/15/2022
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
SFTP DATA TRANSMITTAL T#20221115
Well API #PTD #Log Date Log
Company Log Type AOGCC
Eset#
BRU 233-23 50283201360100 222050 10/8/2022 Halliburton RCBL
BRU 212-24 50283200370000 172015 8/15/2022 AK E-Line CBL/PERF
BRU 214-13 50283201870000 222117 10/23/2022 AK E-Line CBL
Please include current contact information if different from above.
T37258
T37259
T37260BRU 214-13 50283201870000 222117 10/23/2022 AK E-Line CBL
Kayla
Junke
Digitally signed by Kayla Junke
Date: 2022.11.15 15:32:43 -09'00'
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
Received By: Date:
DATE: 11/08/2022
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
DATA TRANSMITTAL
WELL: BRU 214-13
PTD: 222-117
API: 50-283-20187-00-00
MUDLOGS - EOW DRILLING REPORTS (09/28/2022 to 10/08/2022)
1. FINAL EOW REPORT
2. DAILY REPORTS
3. SHOW REPORTS
4. DIGITAL DATA (LAS)
5. MUDLOG PRINTS (2” and 5” MD and TVD COLOR PRINTS – TIFF AND PDF FORMATS)
Formation Log
LWD Combo Log
Gas Ratio Log
Drilling Dynamics Log
SFTP Transfer - Data Folders:
Please include current contact information if different from above.
PTD:222-117
T37243
Kayla Junke
Digitally signed by
Kayla Junke
Date: 2022.11.08
15:12:15 -09'00'
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.
Received By: Date:
Date: 11/07/2022
To: Alaska Oil & Gas Conservation Commission
Natural Resources Technician
333 W. 7th Ave. Ste#100
Anchorage, AK 99501
DATA TRANSMITTAL
WELL: BRU 214-13
PTD: 222-117
API: 50-283-20187-00-00
FINAL LWD FORMATION EVALUATION LOGS (09/28/2022 to 10/08/2022)
ROP, DGR, ADR, EWR-Phase 4, ALD, CTN (2” & 5” MD/TVD Color Logs)
Final Definitive Directional Survey
Folder Contents:
Please include current contact information if different from above.
PTD:222-117
T37243
Kayla
Junke
Digitally signed by
Kayla Junke
Date: 2022.11.08
15:10:36 -09'00'
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:McLellan, Bryan J (OGC)
To:Jacob Flora
Cc:Ryan Thompson
Subject:RE: Beluga River BRU 214-13 CBL (Sundry 322-611) (PTD 222-117)
Date:Thursday, November 3, 2022 10:44:00 AM
Jake,
Cement looks good. Hilcorp has approval to proceed with the perfs per Sundry 322-611.
Bryan McLellan
Senior Petroleum Engineer
Alaska Oil & Gas Conservation Commission
333 W 7th Ave
Anchorage, AK 99501
Bryan.mclellan@alaska.gov
+1 (907) 250-9193
From: Jacob Flora <Jake.Flora@hilcorp.com>
Sent: Thursday, November 3, 2022 8:55 AM
To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Cc: Ryan Thompson <Ryan.Thompson@hilcorp.com>
Subject: RE: Beluga River BRU 214-13 CBL (Sundry 322-611) (PTD 222-117)
Log attached!
From: Jacob Flora
Sent: Thursday, November 3, 2022 8:54 AM
To: bryan.mclellan@alaska.gov
Cc: Ryan Thompson <Ryan.Thompson@hilcorp.com>
Subject: RE: Beluga River BRU 214-13 CBL (Sundry 322-611) (PTD 222-117)
Good Morning Bryan,
When you can please take a look at this CBL, we will be looking to perforate starting Sunday. I think
it’s straightforward, with cement to just below the liner top.
Thanks,
Jake
From: Jacob Flora
Sent: Monday, October 24, 2022 8:56 AM
1
Regg, James B (OGC)
From:Karson Kozub - (C) <kkozub@hilcorp.com>
Sent:Monday, October 24, 2022 5:22 PM
To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC)
Cc:Brad Gathman - (C); Juanita Lovett; Donna Ambruz
Subject:Schlumberger 13 CTU BOPE Test Form 10-22-22
Attachments:Schlumberger 13 10-22-22.xlsx
Good Afternoon,
Attached is the BOPE test report for Schlumberger 13 CTU 10‐22‐2022.
Beluga River BRU 214‐13 (PTD 222‐117) (Sundry 322‐611).
Regards,
Karson Kozub
Mobile: +1 (907) 570-1801
kkozub@hilcorp.com
The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named
above. If you are 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.
Beluga River Unit 214-13
PTD 2221170
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.:13 DATE:10/22/22
Rig Rep.:Rig Email:
Operator:
Operator Rep.:Op. Rep Email:
Well Name:PTD #2221170 Sundry #322-611
Operation:Drilling:Workover:x Explor.:
Test:Initial:x Weekly:Bi-Weekly:Other:
Rams:250/3000 Annular:N/A Valves:250/3000 MASP:2315
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.NA Lower Kelly 0 NA
Standing Order Posted P Misc.NA Ball Type 0 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 1.75"P Trip Tank NA NA
Annular Preventer 0 NA Pit Level Indicators NA NA
#1 Rams 1 B/S P Flow Indicator NA NA
#2 Rams 1 B/S P Meth Gas Detector NA NA
#3 Rams 1 1.75 SLIPS P H2S Gas Detector NA NA
#4 Rams 1 1.75 PIPES P MS Misc 0 NA
#5 Rams 0 NA
#6 Rams 0 NA ACCUMULATOR SYSTEM:
Choke Ln. Valves 2 2"P Time/Pressure Test Result
HCR Valves 0 NA System Pressure (psi)2900 P
Kill Line Valves 2 2"P Pressure After Closure (psi)1625 P
Check Valve 1 2" 1502 P 200 psi Attained (sec)13 P
BOP Misc 3 EQ Ports P Full Pressure Attained (sec)50 P
Blind Switch Covers:All stations YES
CHOKE MANIFOLD:Bottle Precharge:P
Quantity Test Result Nitgn. Bottles # & psi (Avg.):NA NA
No. Valves 5 P ACC Misc 0 NA
Manual Chokes 2 P
Hydraulic Chokes 0 NA Control System Response Time:Time (sec)Test Result
CH Misc 0 NA Annular Preventer 0 NA
#1 Rams 18 P
Coiled Tubing Only:#2 Rams 17 P
Inside Reel valves 1 P #3 Rams 8 P
#4 Rams 9 P
Test Results #5 Rams 0 NA
#6 Rams 0 NA
Number of Failures:0 Test Time:3.5 HCR Choke 0 NA
Repair or replacement of equipment will be made within days. HCR Kill 0 NA
Remarks:
AOGCC Inspection
24 hr Notice YES Date/Time 10/20/22 13:08hrs
Waived By
Test Start Date/Time:10/22/2022 16:00
(date)(time)Witness
Test Finish Date/Time:10/22/2022 19:30
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Jim Regg
Schlumberger
Accumulator system 4 bottles at 1400psi.
Glen Smith
Hilcorp Alaska
Karson Kozub
BRU 214-13
Test Pressure (psi):
gsmith31@slb.com
kkozub@hilcorp.com
Form 10-424 (Revised 08/2022)2022-1022_BOP_SLB13_BRU_214-13
J. Regg; 11/25/2022
From:Regg, James B (OGC)
To:AOGCC Records (CED sponsored)
Subject:BOP - SLB CTU 13
Date:Friday, November 25, 2022 2:03:57 PM
Attachments:2022-1022_BOP_SLB13_BRU_214-13.pdf
Beluga River Unit 214-13 (PTD 2221170)
Jim Regg
Supervisor, Inspections
AOGCC
333 W. 7th Ave, Suite 100
Anchorage, AK 99501
907-793-1236
To: bryan.mclellan@alaska.gov
Subject: FW: Beluga River BRU 214-13 CBL
Hi Bryan,
Please see attached CBL for BRU 214-13.
Thanks,
Jake
From: Karson Kozub - (C) <kkozub@hilcorp.com>
Sent: Sunday, October 23, 2022 9:32 PM
To: Jacob Flora <Jake.Flora@hilcorp.com>; Benjamin Siks <bsiks@hilcorp.com>
Subject: Beluga River BRU 214-13 CBL
Gents,
Attached it the uncorrected CBL from BRU 214-13.
We got all the way down to the landing collar 7,433ft so they must have bumped the plug during the
cement job. (PBTD 7,433ft)
It looks like the TOC ~ 3430ft.
Regards,
Karson KozubMobile: +1 (907) 570-1801kkozub@hilcorp.com
The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the
individual or entity named above. If you are 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 responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate.
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Digitally signed by Jessie L.
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Date: 2022.10.20 11:50:39
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RBDMS JSB
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1
Regg, James B (OGC)
From:Rance Pederson - (C) <rpederson@hilcorp.com>
Sent:Tuesday, October 11, 2022 2:28 PM
To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC); Wallace, Chris D (OGC)
Subject:MIT Test Report
Attachments:MIT Hilcorp 147 10-11-22.xlsx; BRU 214-13 MIT-T and MIT-OA Chart.pdf
Please see the attached MIT form and chart for BRU 214 13.
Rance Pederson
Drilling Foreman
Beluga River Unit
907 776 6776
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
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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.
Submit to:
OPERATOR:
FIELD /UNIT /PAD:
DATE:
OPERATOR REP:
AOGCC REP:
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD 2221170 Type Inj N Tubing 0 3140 3112 3096 Type Test P
Packer TVD 2999 BBL Pump 1.3 IA Interval I
Test psi 3000 BBL Return 1.3 OA 0 25 25 25 Result P
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD 2221170 Type Inj N Tubing 0 165 162 159 Type Test P
Packer TVD 2999 BBL Pump 1.0 IA Interval I
Test psi 2500 BBL Return 1.0 OA 0 2665 2660 2655 Result P
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes
W = Water P = Pressure Test I = Initial Test P = Pass
G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail
S = Slurry V = Required by Variance I = Inconclusive
I = Industrial Wastewater O = Other (describe in notes)
N = Not Injecting
Notes:
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
Mechanical Integrity Test
jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov
Notes:7.625" x 4 1/2" outer annulus. ZXP liner top packer at 2999' tvd. Witness waived by Jim Regg on 10-10-22 at 12:56 pm.
Notes:
Notes:
Hilcorp Alaska, LLC
Beluga River Field, Beluga River Unit, K Pad
Rance Pederson / Chris Yearout
10/11/22
Notes:4 1/2" tieback string and liner. ZXP liner top packer at 2999' tvd. Witness waived by Jim Regg on 10-10-22 at 12:56 pm.
Notes:
Notes:
Notes:
BRU 214-13
BRU 214-13
Form 10-426 (Revised 01/2017)2022-1011_MITP_BRU_214-13_2tests
7.625" x 4 1/2" outer annulus.
4 1/2" tieback string and liner.
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
BOPE Test Report for:
Reviewed By:
P.I. Suprv
Comm ________BELUGA RIV UNIT 214-13
JBR 12/09/2022
MISC. INSPECTIONS:
FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK:
ACCUMULATOR SYSTEM:MUD SYSTEM:
P/F P/F
P/FP/FP/F
Visual Alarm
QuantityQuantity
Time/Pressure
SizeQuantity
Number of Failures:0
Tested all Gas Alarms and PVT's, Tested with 4 1/2 test joint. Precharge bottles = 5@950psi, 6@975psi, 1@1000psi,
3@1050psi. Good Test
Test Results
TEST DATA
Rig Rep:John Van-EveraOperator:Hilcorp Alaska, LLC Operator Rep:J. Richardson
Rig Owner/Rig No.:Hilcorp 147 PTD#:2221170 DATE:10/3/2022
Type Operation:DRILL Annular:
250/3500Type Test:INIT
Valves:
250/3500
Rams:
250/3500
Test Pressures:Inspection No:bopBDB221004075929
Inspector Brian Bixby
Inspector
Insp Source
Related Insp No:
INSIDE REEL VALVES:
Quantity P/F
(Valid for Coil Rigs Only)
Remarks:
Test Time 5.5
MASP:
2183
Sundry No:
Control System Response Time (sec)
Time P/F
Housekeeping:P
PTD On Location P
Standing Order Posted P
Well Sign P
Hazard Sec.P
Test Fluid W
Misc NA
Upper Kelly 1 P
Lower Kelly 1 P
Ball Type 1 P
Inside BOP 1 P
FSV Misc 0 NA
13 PNo. Valves
1 PManual Chokes
1 PHydraulic Chokes
0 NACH Misc
Stripper 0 NA
Annular Preventer 1 11"P
#1 Rams 1 2 7/8"x5"P
#2 Rams 1 Blinds P
#3 Rams 1 4 1/2"P
#4 Rams 0 NA
#5 Rams 0 NA
#6 Rams 0 NA
Choke Ln. Valves 1 3 1/8"P
HCR Valves 2 2 1/16",3 1/8"P
Kill Line Valves 1 2 1/16"P
Check Valve 0 NA
BOP Misc 0 NA
System Pressure P3150
Pressure After Closure P1800
200 PSI Attained P24
Full Pressure Attained P91
Blind Switch Covers:PYES
Bottle precharge P
Nitgn Btls# &psi (avg)P4@2438
ACC Misc NA0
P PTrip Tank
P PPit Level Indicators
P PFlow Indicator
P PMeth Gas Detector
P PH2S Gas Detector
0 NAMS Misc
Inside Reel Valves 0 NA
Annular Preventer P17
#1 Rams P4
#2 Rams P4
#3 Rams P4
#4 Rams NA0
#5 Rams NA0
#6 Rams NA0
HCR Choke P2
HCR Kill P2
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37'
Date: 9/28/2022 Development: X Exploratory:
Drlg Contractor: Rig No. 147 AOGCC Rep:
Operator:Oper. Rep:
Field/Unit/Well No.:Rig Rep:
PTD No.: 2221170 Rig Phone:
Rig Email:
MMISCEL L ANEOUS:DIVERTER SYSTEM:
Location Gen.: P Well Sign: P Designed to Avoid Freeze-up? P
Housekeeping: P Drlg. Rig. P Remote Operated Diverter? P
Warning Sign P Misc: NA No Threaded Connections? P
24 hr Notice: P Vent line Below Diverter? P
AACCUMUL ATOR SYSTEM:Diverter Size: 21-1/4" in.
Systems Pressure: 3000 psig P Hole Size: 9-7/8" in.
Pressure After Closure: 1650 psig P Vent Line(s) Size: 16" in. P
200 psi Recharge Time: 28 Seconds P Vent Line(s) Length: 102' ft. P
Full Recharge Time:109 Seconds P Closest Ignition Source: 79.5' ft. P
Nitrogen Bottles (Number of): 4 Outlet from Rig Substructure: 91' ft. P
Avg. Pressure: 2450 psig P
Accumulator Misc: NA
Vent Line(s) Anchored: P
MMUD SYSTEM:Visual Alarm Turns Targeted / Long Radius: NA
Trip Tank: P P Divert Valve(s) Full Opening: P
Mud Pits: P P Valve(s) Auto & Simultaneous:
Flow Monitor: P P Annular Closed Time: 34 sec P
Mud System Misc: 0 NA Knife Valve Open Time: 25 sec P
Diverter Misc: NA
GGAS DETECTORS:Visual Alarm
Methane: P P
Hydrogen Sulfide: P P
Gas Detectors Misc: 0 NA
Total Test Time: 1.5 hrs Non-Compliance Items: 0
Remarks:
Submit to:
SSTATE OF AL ASK A
AAL ASK A OIL AND GAS CONSERVATION COMMISSION
DDi v er t er Sys t em s In s p ec t i o n Rep o r t
GGENERAL INFORMATION
WaivedHilcorp
**Al l Di verter rep o r t s ar e d u e t o t h e ag en c y w i t h i n 5 d ays o f t est i n g *
jesrichardson@hilcorp.com
TTEST DATA
J Van-Evera / G Vanwulfen
phoebe.brooks@alaska.gov
Hilcorp Alasak, LLC
Function tested annular and knife valve with a joint of 4 1/2" DP in the hole. Verified annular was holding by slck off of blocks. Performed draw
down of koomey unit. Quadco Rep tested audio and visual gas alarms on 9-28-22. Measured vent line and outlet from sub base. Function tested
PVT and flow show alarms both audio and visual. We have two "well on diverter signs posted. One at pad entrance, one on drillers side of rig,
Off side of rig is blocked off to vehicle access.
0
Richardson / Gruenberg
0
907-776-6776
TTEST DETAIL S
jim.regg@alaska.gov
AOGCC.Inspectors@alaska.gov
Beluga River Field, Beluga River Unit, BRU 214-13
Form 10-425 (Revised 05/2021)2022-0928_Diverter_Hilcorp147_BRU_214-13
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333 West Seventh Avenue
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Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
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0
475
950
1425
1900
2375
2850
3325
3800
4275
4750
5225
5700
6175
6650
7125True Vertical Depth (950 usft/in)-1425 -950 -475 0 475 950 1425 1900 2375 2850 3325 3800 4275 4750 5225
Vertical Section at 24.98° (950 usft/in)
BRU 214-13 Tgt 2
7 5/8" x 9 7/8"
4 1/2" x 6 3/4"
5 00
1 0 0 0
1 5 0 0
2 0 00
2 5 00
3 0 0 0
3 5 0 0
4 0 0 0
4 50 0
5 0 0 0
5 5 0 0
6 0 0 0
6 5 0 0
7 0 0 0
7 5 0 07514BRU 214-13 wp07
Start Dir 3º/100' : 450' MD, 450'TVD
Start Dir 4º/100' : 650' MD, 649.63'TVD
End Dir : 1151.71' MD, 1129.87' TVD
Start Dir 3º/100' : 4586.87' MD, 4222.34'TVD
End Dir : 5014.02' MD, 4624.38' TVD
Total Depth : 7514.02' MD, 7060.31' TVD
BRU_ST_A1_COAL
STERLING_B
STERLING_C
BELUGA_D
BELUGA_E
BELUGA_F
BELUGA_G
BELUGA_H
BELUGA_I
BRU_BELUGA_J
BRU_BELUGA_J6
Hilcorp Alaska, LLC
Calculation Method:Minimum Curvature
Error System:ISCWSA
Scan Method: Closest Approach 3D
Error Surface: Ellipsoid Separation
Warning Method: Error Ratio
WELL DETAILS: Plan: BRU 214-13
78.10
+N/-S +E/-W Northing Easting Latitude Longitude
0.00 0.00 2633565.090 323447.710 61° 12' 16.2852 N 151° 0' 3.9324 W
SURVEY PROGRAM
Date: 2022-09-09T00:00:00 Validated: Yes Version:
Depth From Depth To Survey/Plan Tool
18.50 3451.00 BRU 214-13 wp07 (BRU 214-13) 3_MWD+AX+Sag
3451.00 7514.02 BRU 214-13 wp07 (BRU 214-13) 3_MWD+AX+Sag
FORMATION TOP DETAILS
TVDPath TVDssPath MDPath Formation
3263.60 3167.00 3521.89 BRU_ST_A1_COAL
3443.60 3347.00 3721.83 STERLING_B
3592.60 3496.00 3887.35 STERLING_C
3821.60 3725.00 4141.72 BELUGA_D
4030.60 3934.00 4373.88 BELUGA_E
4345.60 4249.00 4721.60 BELUGA_F
4790.60 4694.00 5184.60 BELUGA_G
5085.60 4989.00 5487.36 BELUGA_H
5762.60 5666.00 6182.17 BELUGA_I
6300.60 6204.00 6734.32 BRU_BELUGA_J
6919.60 6823.00 7369.60 BRU_BELUGA_J6
REFERENCE INFORMATION
Co-ordinate (N/E) Reference:Well Plan: BRU 214-13, True North
Vertical (TVD) Reference:BRU 214-13 @ 96.60usft
Measured Depth Reference:BRU 214-13 @ 96.60usft
Calculation Method:Minimum Curvature
Project:Beluga River
Site:BRU K-Pad
Well:Plan: BRU 214-13
Wellbore:BRU 214-13
Design:BRU 214-13 wp07
CASING DETAILS
TVD TVDSS MD Size Name
3200.00 3103.40 3451.24 7-5/8 7 5/8" x 9 7/8"
7060.31 6963.71 7514.02 4-1/2 4 1/2" x 6 3/4"
SECTION DETAILS
Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation
1 18.50 0.00 0.00 18.50 0.00 0.00 0.00 0.00 0.00
2 450.00 0.00 0.00 450.00 0.00 0.00 0.00 0.00 0.00 Start Dir 3º/100' : 450' MD, 450'TVD
3 650.00 6.00 10.00 649.63 10.30 1.82 3.00 10.00 10.11 Start Dir 4º/100' : 650' MD, 649.63'TVD
4 1151.71 25.81 24.94 1129.87 136.46 52.94 4.00 19.09 146.05 End Dir : 1151.71' MD, 1129.87' TVD
5 4586.87 25.81 24.94 4222.34 1492.66 683.53 0.00 0.00 1641.68 Start Dir 3º/100' : 4586.87' MD, 4222.34'TVD
6 5014.02 13.00 26.00 4624.38 1620.69 744.05 3.00 178.92 1783.30 End Dir : 5014.02' MD, 4624.38' TVD
7 7514.02 13.00 26.00 7060.31 2126.15 990.58 0.00 0.00 2345.59 BRU 214-13 Tgt 2 Total Depth : 7514.02' MD, 7060.31' TVD
0
125
250
375
500
625
750
875
1000
1125
1250
1375
1500
1625
1750
1875
2000
2125
2250
2375
South(-)/North(+) (250 usft/in)-250 -125 0 125 250 375 500 625 750 875 1000 1125 1250 1375 1500
West(-)/East(+) (250 usft/in)
BRU 214-13 Tgt 2
7 5/8" x 9 7/8"
4 1/2" x 6 3/4"
750
1000
1250
1500
1750
2000
2250
2500
2750
3000
3250
3500
3750
4000
4250
4500
4750
5000
5250
5500
5750
6000
6250
6500
6750
7060
BRU 214-13 wp07
Start Dir 3º/100' : 450' MD, 450'TVD
Start Dir 4º/100' : 650' MD, 649.63'TVD
End Dir : 1151.71' MD, 1129.87' TVD
Start Dir 3º/100' : 4586.87' MD, 4222.34'TVD
End Dir : 5014.02' MD, 4624.38' TVD
Total Depth : 7514.02' MD, 7060.31' TVDCASING DETAILS
TVD TVDSS MD Size Name
3200.00 3103.40 3451.24 7-5/8 7 5/8" x 9 7/8"
7060.31 6963.71 7514.02 4-1/2 4 1/2" x 6 3/4"
Project: Beluga River
Site: BRU K-Pad
Well: Plan: BRU 214-13
Wellbore: BRU 214-13
Plan: BRU 214-13 wp07
WELL DETAILS: Plan: BRU 214-13
78.10
+N/-S +E/-W Northing Easting Latitude Longitude
0.00 0.00 2633565.090 323447.710 61° 12' 16.2852 N 151° 0' 3.9324 W
REFERENCE INFORMATION
Co-ordinate (N/E) Reference:Well Plan: BRU 214-13, True North
Vertical (TVD) Reference:BRU 214-13 @ 96.60usft
Measured Depth Reference:BRU 214-13 @ 96.60usft
Calculation Method:Minimum Curvature
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0.001.503.004.50Separation Factor0 550 1100 1650 2200 2750 3300 3850 4400 4950 5500 6050 6600 7150 7700 8250 8800 9350 9900 10450Measured DepthNo-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.WELL DETAILS:Plan: BRU 214-13 NAD 1927 (NADCON CONUS)Alaska Zone 0478.10+N/-S +E/-W Northing EastingLatitudeLongitude0.000.002633565.090 323447.71061° 12' 16.2852 N151° 0' 3.9324 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: BRU 214-13, True NorthVertical (TVD) Reference:BRU 214-13 @ 96.60usftMeasured Depth Reference:BRU 214-13 @ 96.60usftCalculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2022-09-09T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool18.50 3451.00 BRU 214-13 wp07 (BRU 214-13) 3_MWD+AX+Sag3451.00 7514.02 BRU 214-13 wp07 (BRU 214-13) 3_MWD+AX+Sag0.0035.0070.00105.00140.00175.00Centre to Centre Separation (60.00 usft/in)0 550 1100 1650 2200 2750 3300 3850 4400 4950 5500 6050 6600 7150 7700 8250 8800 9350 9900 10450Measured DepthBRU 212-24BRU 222-24BRU 223-24BRU 232-23BRU 212-24TBRU 233-23 wp06GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference18.50 To 7514.02Project: Beluga RiverSite: BRU K-PadWell: Plan: BRU 214-13Wellbore: BRU 214-13Plan: BRU 214-13 wp07Ladder / S.F. PlotsCASING DETAILSTVD TVDSS MD Size Name3200.00 3103.40 3451.24 7-5/8 7 5/8" x 9 7/8"7060.31 6963.71 7514.02 4-1/2 4 1/2" x 6 3/4"
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