Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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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: 02/27/2023
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
SFTP DATA TRANSMITTAL T#20230227
Well API #PTD #Log Date Log
Company Log Type AOGCC
Eset#
BRU 233-23 50283201360100 222050 1/20/2023 AK E-LINE Perf
END 2-06 50029216990000 187018 1/23/2023 AK E-LINE Perf
PBU 04-22A 50029214540100 194097 1/10/2023 AK E-LINE PPROF
PBU 11-39 50029235180000 214099 2/8/2023 READ MultipleArrayProductionProfile
SRU 23-33 50133101630000 161019 1/3/2023 AK E-LINE Plug_Cement_Jet Cut
TBF A-01RD 50733100550100 190147 1/24/2023 AK E-LINE Tubing Punch
Please include current contact information if different from above.
BRU 233BRU 233-23 50283201360100 222050 1/20/2023 AK E-LINE Perf
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 7,446 See Schematic feet
true vertical 6,564 feet N/A feet
Effective Depth measured 7,360 feet 2,714 feet
true vertical 6,495 feet 2,714 feet
Perforation depth Measured depth See Schematic feet
True Vertical depth See Schematic feet
Tubing (size, grade, measured and true vertical depth) Tieback 4-1/2" 12.6# / L-80 2,721' MD 2,721' TVD
Packers and SSSV (type, measured and true vertical depth) Liner Top Pkr; N/A 2,714' MD/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:
Jake Flora, Operations Engineer
323-006
Sr Pet Eng:
16,769psi
Sr Pet Geo: Sr Res Eng:
WINJ WAG
1330
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
jake.flora@hilcorp.com
907-777-8442
N/A
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
108'
0 02486
0 2700
291
measured
TVD
17,693psi
7"
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
222-050
50-283-20136-01-00
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:
ADL021128
Beluga River / Sterling-Beluga Gas
Beluga River Unit (BRU) 233-23
Plugs
Junk measured
Length
Production
Liner
2,907'
4,736'
Casing
Structural
2,887'
4-1/2"
2,907'
7,446' 6,564'
108'Conductor
Surface
Intermediate
20"
9-5/8"
108'
2,851'
5,410psi
5,750psi
7,240psi
2,851' 2,832'
Burst Collapse
3,090psi
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 Samantha Carlisle at 12:19 pm, Feb 24, 2023
Digitally signed by Noel Nocas
(4361)
DN: cn=Noel Nocas (4361),
ou=Users
Date: 2023.02.24 11:53:28 -09'00'
Noel Nocas
(4361)
Rig Start Date End Date
1/18/23 1/20/23
02/02/2023 - Thursday
Evaluating for additional perforations.
Daily Operations:
Hilcorp Alaska, LLC
Well Operations Summary
API Number Well Permit Number
50-283-20136-01-00 222-050
Well Name
BRU 233-23
01/20/2023- Friday
AKE-line crew arrive at Hilcorp Kenai hanger, load equipment and fly to BRU. Clear units of snow and gather perf gun stock.
Build and assemble switch guns. Mobilize to location, layout ground cover and spot equipment. SDFN and return to camp.
Attend production meeting with AKE-line crew, obtain PTW and hold PJSM. Locate, mobilize and spot support equipment on
location. Complete RU. MU perf tool string including 3-1/8" Gun GammaRay/CCL, 2-3/4" shock sub, and 2-3/4" x 6' and 8'
(6spf/60D) switch gun.
Move tool string and PCE to well head and PT 250/2500 psi. Open swab, RIH w/ well flowing (253 psi / 1.1mmscfd. Tag PBTD
at 5920' and log correlation pass to 5500'. Confirm correlation and adjust (add 4'), resend and confirm. Position and shoot H4
interval at (5763' - 5769') (6'). Pull up, position and shoot the H2 interval (5660'-5668'). POOH. MU 10' gun, RIH and perforate
H1 (5646'-5656'). POOH. (FTP-270 psi). RIH with 5' and 6' switch guns. Position and shoot H interval (5613'-5618') (5'), pull up
hole and shoot the G5 interval (5342'- 5348') (6'). POOH. FTP - 297 psi.
RIH with 6' and 5' switch guns. Position and shoot G1 interval (5189'-5195') (6'), pull up and shoot G1 interval (5164'-5169')
(5'). POOH.
Close swab. FTP @ 305 psi. Secure well and rig down. Turn well over to production. Return unit and crane to D pad and fly
crew back to Kenai.
01/18/2023 - Wednesday
Travel to Beluga, assemble switchable perf guns and spot equipment on location.
01/19/2023 - Thursday
Updated by DMA 02-22-23
SCHEMATIC
Beluga River Unit
BRU 233-23 (212-24T ST)
PTD: 222-050
API: 50-283-20136-01-00
PBTD = 7,360 / TVD = 6,495
TD = 7,446 / TVD = 6,564
RKB to GL = 18.5
OPEN HOLE / CEMENT DETAIL
9-5/8 TOC @ Surface (Original BRU 212-24T)
7" TOC @ 2,860 (Original BRU 212-24T)
3-1/2 CBL TOC @ 2,900 (10/8/22)
CASING DETAIL
Size Type Wt Grade Conn. ID Top Btm
20 Conductor 154.19 X-65 Weld 19.13 Surf 108
9-5/8" Surf Csg 40.0 L-80 BTCM 8.835 Surf 2,851
7 Prod Csg 26.0 L-80 BTCM 6.276 Surf 2,907
(TOW)
4-1/2" Prod Lnr 12.6 L-80 JFELION 3.958 2,714 7,446
4-1/2" Prod Tieback 12.6 L-80 JFELION 3.958 Surf 2,721
20
9-5/8
12-1/4
hole
4-1/2
JEWELRY DETAIL
No. Depth ID OD Item
1 2,714 4.875 5.960 Flex-Lock V Liner Hanger, HRD-E HD ZXP, 5" x 7" Liner
Top Packer w/5.25" PBR
2 5,950 3.71 CIBP (11/10/22)
3 6,015 3.71 CIBP (11/01/22)
4 6,519 3.71 CIBP (10/26/22)
5 7,100 3.71 CIBP (10/25/22)
6-1/8
hole
1
4
8-1/2
hole
7
BRU 212-24T
(Abandoned)
I12
PERFORATION DETAIL
Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status
G1 5,164 5,169 4,788 4,792 5 1/20/2023 Open
G1 5,188' 5,194' 4,806' 4,811' 6' 11/12/2022 Open
G1 5,189 5,195 4,807 4,812 6 1/20/2023 Open
G2 5,211 5,226 4,824 4,835 15 11/12/2022 Open
G2 5,243 5,251 4,848 4,855 8 11/12/2022 Open
G3 5,268 5,277 4,868 4,875 9 11/12/2022 Open
G3 5,291 5,296 4,885 4,889 5 11/12/2022 Open
G5 5,342 5,348 4,924 4,929 6 1/20/2023 Open
G9 5,433' 5,439' 4,993' 4,998' 6' 11/11/2022 Open
H 5,578 5,582 5,104' 5,107' 5 11/11/2022 Open
H 5,604 5,610 5,185' 5,128' 6 11/11/2022 Open
H 5,613 5,618 5,130 5,134 5 1/20/2023 Open
H1 5,646 5,656 5,156 5,163 10 1/20/2023 Open
H2 5,685 5,705 5,185' 5,200' 20 11/11/2022 Open
H3 5,741 5,751 5,228' 5,235' 10 11/11/2022 Open
H4 5,763 5,769 5,245 5,249 6 1/20/2023 Open
H9 5,971 5,985 5,403' 5,415' 15 10/28/2022 Isolated
H10 6,027 6,047 5,447' 5,462' 20 10/28/2022 Isolated
I 6,483 6,497 5,792' 5,802' 10 10/26/2022 Isolated
I1 6,524 6,544 5,823' 5,838' 20 10/25/2022 Isolated
I12 7,149' 7,161' 6,314' 6,324' 12' 10/24/2022 Isolated
2
3
4
5
I1
I
H9-10
G1-H4
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 233-23 50283201360100 222050 12/21/2022 AK E-LINE PPROF
Meredith Guhl Digitally signed by Meredith Guhl
Date: 2023.01.26 15:02:03 -09'00'
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?
Will planned perforations require a spacing exception?Yes No
9. Property Designation (Lease Number): 10. Field: Current Pools:
11.
Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD):
7,446'N/A
Casing Collapse
Structural
Conductor
Surface 3,090psi
Intermediate
Production 5,410psi
Liner 16,769psi
Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft):
12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work:
Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service
14. Estimated Date for 15. Well Status after proposed work:
Commencing Operations:OIL WINJ WDSPL Suspended
16. Verbal Approval:Date: GAS WAG GSTOR SPLUG
AOGCC Representative: GINJ Op Shutdown Abandoned
Contact Name:
Contact Email:
Contact Phone:
Authorized Title:
Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number:
Plug Integrity BOP Test Mechanical Integrity Test Location Clearance
Other:
Post Initial Injection MIT Req'd? Yes No
Spacing Exception Required? Yes No Subsequent Form Required:
APPROVED BY
Approved by: COMMISSIONER THE AOGCC Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
7,240psi2,887'2,907'
17,693psi7,446'6,564'
108'
2,851'
Perforation Depth MD (ft):
2,907'
4-1/2"4,736'
7"
20"
9-5/8"
108'
2,851'5,750psi
108'
2,832'
Length Size
Proposed Pools:
TVD Burst
PRESENT WELL CONDITION SUMMARY
6,564'7,360'6,495'~1,785 psi See Schematic
MD
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL021128
222-050
50-283-20136-01-00
Beluga River Sterling/Beluga Gas Same
CO 802
Hilcorp Alaska, LLC
3800 Centerpoint Drive, Suite 1400
Anchorage, Alaska 99503
Beluga River Unit (BRU) 233-23
Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft):Tubing Size:
12.6# / L-80 2,721'
January 20, 2023
Liner Top Pkr; N/A 2,714' MD/ TVD: N/A
See Schematic See Schematic Tieback 4-1/2"
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
Jake Flora, Operations Engineer
jake.flora@hilcorp.com
907-777-8442
Noel Nocas, Operations Manager 907-564-5278
m
n
P
s
t
_
66
Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
323-006
By Meredith Guhl at 2:08 pm, Jan 09, 2023
Digitally signed by Noel Nocas
(4361)
DN: cn=Noel Nocas (4361),
ou=Users
Date: 2023.01.09 13:39:07 -09'00'
Noel Nocas
(4361)
10-404
BJM 1/12/23
SFD 1/9/2023 DSR-1/9/23
Brett W. Huber, Sr.
GCW 01/13/23JLC 1/13/2023
1/13/23
RBDMS JSB 011723
Well Prognosis
Well Name: BRU 233-23 API Number: 50-283-20136-00-00
Current Status: Gas Producer Permit to Drill Number: 222-050
First Call Engineer: Jake Flora (907) 777-8442 (O) (720) 988-5375 (C)
Second Call Engineer: Chad Helgeson (907) 777-8405 (O)
Maximum Expected BHP: 2310 psi @ 5251’ TVD (Based on 0.44 psi/ft gradient))
Max. Potential Surface Pressure: 1785 psi (Based on 0.1 psi/ft gas gradient to surface)
Well Status: Online gas producer currently making 1200 mcfd @ 266 psi
Brief Well Summary:
BRU 233-23 is a sidetrack of well BRU 212-24T drilled in September 2022 at Beluga River. The well was initially
completed in the Beluga G-I sands and has steadily declined. The objective of this sundry is to increase
productivity by adding additional Beluga sands.
Procedure
1. RU E-line, PT lubricator to 2500 psi
2. Perforate below Beluga sands from the bottom up:
Top Beluga F 4587’ MD 4350’ TVD
Bottom Beluga H 5769’ MD 5251’ TVD
a) All sands lie in the BELUGA RIVER, UNDEFINED GAS POOL
b) If any zone produces sand and/or water or needs isolated, RIH and set plug above the
perforations OR patch across the perforations.
c) Frac Calcs: Using 14.4 ppg EMW FIT at surface casing shoe (0.748 psi/ft frac grad)
d) Shallowest Allowable Perf TVD = MPSP/(0.748-0.1) = 1785 psi / 0.648 = 2754‘ TVD
E-line Procedure (Contingency if water is encountered after perforating):
1. MIRU E-Line, PT lubricator to 2500 psi
2. RIH and set plug above the perforations OR set patch over the wet perforations.
Attachments:
1. As-built Well Schematic
2. Proposed Well Schematic
Use deepest perf for calculation unless pressure data is presented to demonstrate deep perfs are depleted.
Using the deepest perf, shallowest allowable perf is +/-3300'. bjm
Updated by DMA 01-06-23
SCHEMATIC
Beluga River Unit
BRU 233-23 (212-24T ST)
PTD: 222-050
API: 50-283-20136-01-00
PBTD = 7,360’ / TVD = 6,495’
TD = 7,446’ / TVD = 6,564’
RKB to GL = 18.5’
OPEN HOLE / CEMENT DETAIL
9-5/8” TOC @ Surface (Original BRU 212-24T)
7" TOC @ 2,860’ (Original BRU 212-24T)
3-1/2” CBL TOC @ 2,900’ (10/8/22)
CASING DETAIL
Size Type Wt Grade Conn. ID Top Btm
20” Conductor 154.19 X-65 Weld 19.13” Surf 108’
9-5/8" Surf Csg 40.0 L-80 BTCM 8.835” Surf 2,851’
7” Prod Csg 26.0 L-80 BTCM 6.276” Surf 2,907
(TOW)
4-1/2" Prod Lnr 12.6 L-80 JFELION 3.958” 2,714’ 7,446’
4-1/2" Prod Tieback 12.6 L-80 JFELION 3.958” Surf 2,721’
20”
9-5/8”
12-1/4”
hole
4-1/2”
JEWELRY DETAIL
No. Depth ID OD Item
1 2,714 4.875” 5.960” Flex-Lock V Liner Hanger, HRD-E HD ZXP, 5" x 7" Liner
Top Packer w/5.25" PBR
2 5,950’ 3.71” CIBP (11/10/22)
3 6,015’ 3.71” CIBP (11/01/22)
4 6,519’ 3.71” CIBP (10/26/22)
5 7,100’ 3.71” CIBP (10/25/22)
6-1/8”
hole
1
4
8-1/2”
hole
7”
BRU 212-24T
(Abandoned)
I12
PERFORATION DETAIL
Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status
G1 5,188' 5,194' 4,806' 4,811' 6' 11/12/2022 Open
G2 5,211' 5,226' 4,824' 4,835' 15' 11/12/2022 Open
G2 5,243' 5,251' 4,848' 4,855' 8' 11/12/2022 Open
G3 5,268' 5,277' 4,868' 4,875' 9' 11/12/2022 Open
G3 5,291' 5,296' 4,885' 4,889' 5' 11/12/2022 Open
G9 5,433' 5,439' 4,993' 4,998' 6' 11/11/2022 Open
H 5,578’ 5,582’ 5,104' 5,107' 5’ 11/11/2022 Open
H 5,604’ 5,610’ 5,185' 5,128' 6’ 11/11/2022 Open
H2 5,685’ 5,705’ 5,185' 5,200' 20’ 11/11/2022 Open
H3 5,741’ 5,751’ 5,228' 5,235' 10’ 11/11/2022 Open
H9 5,971’ 5,985’ 5,403' 5,415' 15’ 10/28/2022 Isolated
H10 6,027’ 6,047’ 5,447' 5,462' 20’ 10/28/2022 Isolated
I 6,483’ 6,497’ 5,792' 5,802' 10’ 10/26/2022 Isolated
I1 6,524’ 6,544’ 5,823' 5,838' 20’ 10/25/2022 Isolated
I12 7,149' 7,161' 6,314' 6,324' 12' 10/24/2022 Isolated
2
3
4
5
I1
I
H9-10
G1-H3
Updated by DMA 01-06-23
PROPOSED
Beluga River Unit
BRU 233-23 (212-24T ST)
PTD: 222-050
API: 50-283-20136-01-00
PBTD = 7,360’ / TVD = 6,495’
TD = 7,446’ / TVD = 6,564’
RKB to GL = 18.5’
OPEN HOLE / CEMENT DETAIL
9-5/8” TOC @ Surface (Original BRU 212-24T)
7" TOC @ 2,860’ (Original BRU 212-24T)
3-1/2” CBL TOC @ 2,900’ (10/8/22)
CASING DETAIL
Size Type Wt Grade Conn. ID Top Btm
20” Conductor 154.19 X-65 Weld 19.13” Surf 108’
9-5/8" Surf Csg 40.0 L-80 BTCM 8.835” Surf 2,851’
7” Prod Csg 26.0 L-80 BTCM 6.276” Surf 2,907
(TOW)
4-1/2" Prod Lnr 12.6 L-80 JFELION 3.958” 2,714’ 7,446’
4-1/2" Prod Tieback 12.6 L-80 JFELION 3.958” Surf 2,721’
20”
9-5/8”
12-1/4”
hole
4-1/2”
JEWELRY DETAIL
No. Depth ID OD Item
1 2,714 4.875” 5.960” Flex-Lock V Liner Hanger, HRD-E HD ZXP, 5" x 7" Liner
Top Packer w/5.25" PBR
2 5,950’ 3.71” CIBP (11/10/22)
3 6,015’ 3.71” CIBP (11/01/22)
4 6,519’ 3.71” CIBP (10/26/22)
5 7,100’ 3.71” CIBP (10/25/22)
6-1/8”
hole
1
4
8-1/2”
hole
7”
BRU 212-24T
(Abandoned)
I12
PERFORATION DETAIL
Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status
F-H ±4,587’ ±5,769’ ±5,251’ ±4,350’ ±1,182’ Proposed TBD
G1 5,188' 5,194' 4,806' 4,811' 6' 11/12/2022 Open
G2 5,211' 5,226' 4,824' 4,835' 15' 11/12/2022 Open
G2 5,243' 5,251' 4,848' 4,855' 8' 11/12/2022 Open
G3 5,268' 5,277' 4,868' 4,875' 9' 11/12/2022 Open
G3 5,291' 5,296' 4,885' 4,889' 5' 11/12/2022 Open
G9 5,433' 5,439' 4,993' 4,998' 6' 11/11/2022 Open
H 5,578’ 5,582’ 5,104' 5,107' 5’ 11/11/2022 Open
H 5,604’ 5,610’ 5,185' 5,128' 6’ 11/11/2022 Open
H2 5,685’ 5,705’ 5,185' 5,200' 20’ 11/11/2022 Open
H3 5,741’ 5,751’ 5,228' 5,235' 10’ 11/11/2022 Open
H9 5,971’ 5,985’ 5,403' 5,415' 15’ 10/28/2022 Isolated
H10 6,027’ 6,047’ 5,447' 5,462' 20’ 10/28/2022 Isolated
I 6,483’ 6,497’ 5,792' 5,802' 10’ 10/26/2022 Isolated
I1 6,524’ 6,544’ 5,823' 5,838' 20’ 10/25/2022 Isolated
I12 7,149' 7,161' 6,314' 6,324' 12' 10/24/2022 Isolated
2
3
4
5
I1
I
H9-10
G1-H3
F-H
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 233-23 50283201360100 222050 11/10/2022 AK E-LINE GPT Plug 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: 74' BF: 74'
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
4-1/2" L-80 6,564'
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:
00291 0
11/28/2022 24
Flow Tubing
0
2635
N/A26350
N/A
2,907' MD / 2,887' TVD
N/A
7,446' MD / 6,564' TVD
5,950' MD / 5,390' TVD
2535' FNL, 630' FEL, Sec 23, T13N, R10W, SM, AK
1634' FSL, 1535' FEL, Sec 23, T13N, R10W, SM, AK
Choke Size:
2,695'
Per 20 AAC 25.283 (i)(2) attach electronic information
12.6# 7,446'
Water-Bbl:
PRODUCTION TEST
10/27/2022
Date of Test: Oil-Bbl:
Flowing
** Please see attached schematic for perforation detail **
Gas-Oil Ratio:
AMOUNT
PULLED
322699
321778
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.
BRU 233-23September 18, 20222054' FNL, 144' FWL, Sec 24, T13N, R10W, SM, AK
92.5'
BOTTOMCASINGWT. PER
FT.GRADE CEMENTING RECORD
2633106
SETTING DEPTH TVD
2632009
TOP HOLE SIZE
Mudlog, LWD (DGR, SP4, CTN, ALD), CBL 10-8-22, Perf, GPT, CIBP Tie in logs.
Sterling-Beluga Gas Pool
ADL 21128
3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503
323477 2633581
50-283-20136-01-00September 12, 2022
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
Hilcorp Alaska, LLC
WAG
Gas
10/24/2022 222-050 / 322-560
N/A
PACKER SET (MD/TVD)
6-1/8" L - 250 sx / T - 70 sx2,714'
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date perf'd or liner run):
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
CASING, LINER AND CEMENTING RECORD
List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion,
TUBING RECORD
2,721'4-1/2"
SIZE DEPTH SET (MD)
2,714' MD / 2,695' TVD
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
Received by James Brooks at 3:20 PM on 12/6/2022
Completed
10/24/2022
JSB
RBDMS JSB 121622
GDSR-1/3/23
BRU 233-23
222-050 / 322-560
WCB 1-23-2025
Conventional Core(s): Yes No Sidewall Cores:
30.
MD TVD
N/A N/A
Top of Productive Interval Bel G1 5,188' MD 4,806'
3,295' 3,261'
3,482' 3,441'
3,641' 3,590'
3,888' 3,807'
5,157' 4,778'
5,496' 5,036'
5,554' 5,080'
6,014' 5,432'
6,458' 5,768'
7,115' 6,281'
7,178' 6,333'
7,205' 6,356'
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:
INSTRUCTIONS
Bel J1
Bel G10
Bel H
Bel I12
Bel J
Wellbore Schematic, Drilling and Completion Reports, Definitive Directional Surveys, Csg and Cmt report.
Authorized Title: Drilling Manager
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.
Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
Bel I
Bel D
Sterling A
Bel G1
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.
Bel H10
Sterling B
TPI (Top of Producing Interval).
Authorized Name and
Sterling C
Formation Name at TD:
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
12.6.2022
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: 2022.12.06 15:07:23 -09'00'
Monty M
Myers
Updated by CJD 12-6-22
SCHEMATIC
Beluga River Unit
BRU 233-23 (212-24T ST)
PTD: 222-050
API: 50-283-20136-01-00
PBTD = 7,360’ / TVD = 6,495’
TD = 7,446’ / TVD = 6,516’
RKB to GL = 18.5’
OPEN HOLE / CEMENT DETAIL
9-5/8” TOC @ Surface (Original BRU 212-24T)
7" TOC @ 2,860’ (Original BRU 212-24T)
3-1/2” CBL TOC @ 2,900’ (10/8/22)
CASING DETAIL
Size Type Wt Grade Conn. ID Top Btm
20” Conductor 154.19 X-65 Weld 19.13” Surf 108’
9-5/8" Surf Csg 40.0 L-80 BTCM 8.835” Surf 2,851’
7” Prod Csg 26.0 L-80 BTCM 6.276” Surf 2,907
(TOW)
4-1/2" Prod Lnr 12.6 L-80 JFELION 3.958” 2,714’ 7,446’
4-1/2" Prod Tieback 12.6 L-80 JFELION 3.958” Surf 2,721’
20”
9-5/8”
12-1/4”
hole
4-1/2”
JEWELRY DETAIL
No. Depth ID OD Item
1 2,714 4.875” 5.960” Flex-Lock V Liner Hanger, HRD-E HD ZXP, 5" x 7" Liner
Top Packer w/5.25" PBR
2 5,950’ 3.71” CIBP (11/10/22)
3 6,015’ 3.71” CIBP (11/01/22)
4 6,519’ 3.71” CIBP (10/26/22)
5 7,100’ 3.71” CIBP (10/25/22)
6-1/8”
hole
1
4
8-1/2”
hole
7”
BRU 212-24T
(Abandoned)
I12
PERFORATION DETAIL
Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status
G1 5,188' 5,194' 4,806' 4,811' 6' 11/12/2022 Open
G2 5,211' 5,226' 4,824' 4,835' 15' 11/12/2022 Open
G2 5,243' 5,251' 4,848' 4,855' 8' 11/12/2022 Open
G3 5,268' 5,277' 4,868' 4,875' 9' 11/12/2022 Open
G3 5,291' 5,296' 4,885' 4,889' 5' 11/12/2022 Open
G9 5,433' 5,439' 4,993' 4,998' 6' 11/11/2022 Open
H 5,578’ 5,582’ 5,104' 5,107' 5’ 11/11/2022 Open
H 5,604’ 5,610’ 5,185' 5,128' 6’ 11/11/2022 Open
H2 5,685’ 5,705’ 5,185' 5,200' 20’ 11/11/2022 Open
H3 5,741’ 5,751’ 5,228' 5,235' 10’ 11/11/2022 Open
H9 5,971’ 5,985’ 5,403' 5,415' 15’ 10/28/2022 Isolated
H10 6,027’ 6,047’ 5,447' 5,462' 20’ 10/28/2022 Isolated
I 6,483’ 6,497’ 5,792' 5,802' 10’ 10/26/2022 Isolated
I1 6,524’ 6,544’ 5,823' 5,838' 20’ 10/25/2022 Isolated
I12 7,149' 7,161' 6,314' 6,324' 12' 10/24/2022 Isolated
2
3
4
5
I1
I
H9-10
G1-H3
Activity Date Ops Summary
9/4/2022 Final report for BRU 222-34. Released rig, moved to well BRU 233-23 AFE @ 12:00 hrs.;Brought in CCI crane, spotted, picked, and installed BOP’s in cradle.
Loaded out and hauled off boiler #1 and diesel auxiliary tank. Got pod #1 on MP #2 removed. Pulled rotary table cover, cleaned, and replaced broken off grease
fitting make it easer to lock table.;R/D the TD torque bushing. Hauled off MWD shack and 400 bbl vertical water tank to staging pad. Installed transport beams in
sub base. Performed EAM's on misc. rig equip. Changed oil in floor motor. R/D boiler and change conex. Disabled catwalk HYD control;valve bank and capped
lines. Prepped mud pits for transport. Removed equalizer lines in pits. Removed shaker rubbers, metal brackets, and inspected shaker beds for cracks (ok).
Prepped rig floor for scoping derrick.;Continue to work on Mud pump #2. R/D move mud lab and geolog shack. R/D and L/D topdrive and put in cradle. Adjust
travel distance on rig tongs. R/D change house. Clean out vacuum degasser and adjust cables. Replaced rubbers on shaker beds. Clear remaining tools and
equipment from rig floor.;Remove stand pipe hard lines, Pressure wash pits, Pull expendables out of MP #1 for inspection. Fixed hydraulic leak and added
nitrogen to a bottle in koomey. Pressure wash rig floor and equipment.;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
9/5/2022 Spot cane L/D poor boy. Move crane over by MP #2 P/U and install manifold and pulsation dampener and finish putting it together. Remove H2S/LEL sirens
and unplug and roll up pason cables.;Replaced 4’ discharge valve to trip tank, free up the gun lines on pits 6,8,9. Re-installed valve bank on pipecat, connect all
the lines and pressure test. Prepped rig floor and derrick to scope down. Scoped derrick.;Inspect valves and suction rubbers in all pits. Prepped rig floor and
derrick to scope down. Scoped derrick. Clean mezzanine and cellar areas. Remove lower section of torque tube. Secure boom line. Lower roofs on pits 2 and 3.
Fold up derrick board. Power was the outside of all the rig components.;Inspect MP #2 pod #1 removed hydraulic lines from sub and secured. Secure kelly hose
and service loop for move. Remove jumper hoses from sub to pit. Clean pit walls and pipe skate.
9/6/2022 Secure BOP hoist. Remove brake handle driveshaft. Re-wire trip tank pump. Rig down pits for move to K pad. Grease crown. Added foot chain for brake handle.
Put nitrogen in Accumulator bottles. Organize inventory. Clean generator 2 radiator.;Drill holes in catwalk gates for retention pins, lower dog runs on pit roofs.
Clean frac tank #2.;Pressure wash rig matts and catwalk, modify JSA's for rigging down/up derrick board. R/D controls for pipe cat;Complete EAM's, organize
parts conex. Cont. modifying JSA's , Repair centrifuge discharge line, suck out containments and cont. washing rig
9/7/2022 Continue to clean rig and location. Repair centrifuge discharge line. Recharge koomey bottles. Change fuel filter on boiler. Grease HP valves in pump houses.
Organize 40' connex. Grease both MP transmissions. Remove lights from top of pits. Create JSA for operating skate.;Lay down catwalk and derrick prepping rig
for move. R/D coms and offices and start moving to K pad. Set rig matts and spot expeditor-DSM and Gen shacks. Assist with pad leveling;Cont. setting matts
and placing pusher trailer- change room and meeting trailer on K pad. Dig down shifting and burying 1 in pipe next to 233-23 for rig matt placement. Noticed
freshly finished cellar on BRU 214-13 looked high. Measurement confirmed top of cellar box was 5 inches above pad level.;Discussion with town and decision
was made to cut and lower cellar box to pad level.;Moved and set 2nd change room to K pad, Back filled first 4ft of BRU 214-13 cellar box with dirt. Sucked rain
water out of containment around rig. Staged felt and rig matts on K pad for rig move. Conducted Pre-spud meeting with night crew.
9/8/2022 Continue perform general maintenance, clean and organize rig modules and prep to move, Rig movers tear out cat walk and pits and pump modules, pull water
tank and gen skid, pull top drive HPU, Clean up location, pull mats and load out on trailers, stage modules on J pad, clean up liner and felt.;Welders cutting 6''
off cellar and rewelding grating supports, Coms up and running, Notify AOGCC of upcoming BOP Test 9/8/2022 3:39 PM.;Continue welding on cellar, continue
cleaning all trash and debris from F pad, compact k pad extension, Finish welding cellar, back fill and grade location.;Continue grade and compact location,
transport mats to K-pad and lay felt around well.;Lay liner and set rig mats around well. Move light plant back to F-pad and set up for rigging down derrick and
sub. Cont working on JSA modifications for rig move operations.;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
n (LAT/LONG):
evation (RKB):
API #:
Well Name:
Field:
County/State:
BRU 233-23
Beluga River
Hilcorp Energy Company Composite Report
, Alaska
Contractor
AFE #:
AFE $:
Job Name:221-00070 BRU 233-23 Drilling
Spud Date:
Released rig, moved to well BRU 233-23
9/9/2022 Spot in cranes around sub, un pin and hoist derrick off sub on to trailer and secure for transport, hoist draw works skid onto trailer, Pick sub off pony walls and
load on to bed truck, load mats and pony subs onto trailer and ship to K pad, pick up remaining mats and clean up location, set pony;subs over well, spot in
cranes and set sub on pony subs, hoist draw works into position, spot in test pump, AOGCC waived witness of BOP Test @ 9/9/2022 8:35 AM.;Set derrick on
sub and pin, spot in water tank, Raise derrick and pin, raise dog house, fold out landings and install handrails, hook up electrical, Spot in pit modules #1 & #2
set jig in place, spot in pump #1 , Raise pit rooves fold down landings and walk ways, fold out grasshopper, set pump #2.;roll out felt and liner for catwalk, set
mats in place for catwalk, spot in bubble for pump house, spot in gen set, set in top drive HPU building, spot in gas buster.;Spot in boiler and 40' parts conex,
spot in catwalk, plug in electrical and hydraulics throughout rig, install outer lights and gas alarms. Make up jumper hoses from pump house to pits and hoppers
as well has mud lines to rig floor.;Spot up right water tank, plug in pason . Install centrifuge and set cuttings box. Spot mud engineer and mud logger
shacks.;Cont. to plug in pason, set sperry shack and power up third party shacks . Install dog nut and spool drilling line onto draw works, Install lower section of
torque tube, Scope up derrick- install turnbuckles and T-bar. Bridle down, rig up to top drive and P/U to rig floor.
9/10/2022 Continue Rigging up top drive, install torque bushing, hook up service loops and kelly hose, install S pipe on stand pipe, hook up mud lines, Crane setting wind
walls and gas buster,. hook up pason lines, power up and rig up third party shacks, Handi Berm Rigging up containment around rig, work on;welding projects
around rig, agitator guides in pit bottoms worn out, fix broken bracket on stand pipe, build mud docks and stage mud product on docks, dress top drive Saver
sub and bails, bring handling equipment to floor remove shipping beams in cellar, transfer BOP stack to bridge cranes.;Finish rig acceptance checklist, finish
welding projects in pits, fill with water and check for leaks, Continue N/D Dry hole tree and repositioning annulus valves, N/U BOP stack, N/U Choke and Kill
lines, Hook up Koomey Hoses.;Cont. N/U Choke, Kill and Koomey hoses, Installed chain binders flow line and hole fill line. Build mud. Flood all surface lines
with water checking for leaks. Grease fitting cracked - replaced and PT surface lines.;Bring subs, XO's and well control valves to rig floor. Test TQ on iron
roughneck and top drive.;Obtain RKB's, Rig up testing equipment, install test plug on 4.5" test jt. and run in 2 LDS, Fill all surface equipment and purge air from
system. Perform shell test. Cont to build mud in pits.;Test BOP's on 4.5" test JT as per AOGCC regulations. 250 psi Low/3500 psi High for 5/5 min.. Bring drill
pipe and HWDP tubs to location and set staging racks. Cont. to build mud in pits. Rig accepted at 02:00 hrs.;Dragon Boxes Loaded 0 bbls
Total Dragon Boxes 0 bbls
Cuttings Totes Loaded 0 bbls
Total Cuttings Totes 0 bbls
ISO Tanks Loaded 104 bbls
ISO Tanks Total 104 bbls
Losses Downhole 0 bbls
Total 0 bbls
9/11/2022 Continue Testing BOP's w/ 4.5'' test Jt t/ 250/3500 psi Test CMV 1-13, Upper Lower and Blind rams, TIW and Dart, HCR and Man Choke and Kill valves,
outside kill line valve, Auto and Man IBOP, Annular t/ 250/2500 psi Perform Accumulator Draw down test 28 sec t/ 200 psi 93 sec t/ full pressure, State;Inspector
Jim Regg Waived witness, had three fail passes, Blinds - Replace Elements retest pass, Annular- Function retest pass, Lower pipe rams - Function retest
pass.;Blow down lines and R/D test equipment, pull test plug set wear ring, Load strap and tally DP.;P/U Clean Out BHA, Mule shoe float and 6.125'' upper
string mill HWDP and Jars, Single in the hole P/U DP tagging TOC @ 3524' with 5K down 2 times, Picked up to 3518', worked pipe F/2867' T/2930' 35 RPM,
3.5K TQ while RIH.;Displace well from produced water to 9.3 PPG 6% KCL PHPA mud, 8 BPM, 404 PSI. Monitor well= static.;POOH on elevators F/3518'
T/surface - L/D Mule shoe float and upper 6.125" string mill.;Rig up Alaska E-line sheaves and run E-line, M/U CCL and Gamma tools, rig up to CIBP, Zero at rig
floor, RIH on E-line @ 150 Ft/min to 3250' tying in with gamma and ccl logs from 212-24T CBL. Locate collar at 2929' and set CIBP @ 2924'.;Let rest for 5 min
pick up 10' running back down and tagging plug verifying plug set. POOH and R/D E-line.;Close the blinds rig up and pressure test CSG/CIBP to 3200 PSI for 30
min- good test. Pumped 57.5 gal bleeding back 57.5 gal. R/D testing equipment and blow down choke and kill lines.;M/U window mill, lower mill, flex pup and
upper mill, on btm of flex collar, M/U DM-Scribe DM to slide with a 221.9 Deg offset. M/U TM and perform shallow hole test. P/U whipstock and M/U with 35K
shear screw. RIH with whip stock to 588'.;Dragon Boxes Loaded 0 bbls
Total Dragon Boxes 0 bbls
Cuttings Totes Loaded 0 bbls
Total Cuttings Totes 0 bbls
ISO Tanks Loaded 104 bbls
ISO Tanks Total 104 bbls
Losses Downhole 0 bbls
Total 0 bbls
9/12/2022 Continue RIH w/whipstock BHA f/588' to 2878', filled pipe and orient whipstock t/31°L slack off and tag CIBP @ 2924' DPM, set anchor w/10k SOW, sheared
whipstock bolt w/ 23k SOW. Up wt 55K, dwn wt 50K.;Begin milling window in 7" casing from 2907' (TOW) to 2920' (BOW), 1-3K wob, 250 gpm-850 psi, 100 rpm-
3400 ft/lbs torque, 1 to 6 ft/hr ROP. At 2920' milling ahead 3K wob, 193 gpm-556 psi, 10 to 15 ft/hr ROP, at 2925' 7 to 8K wob, 190 gpm-890 psi, 4-5 ft/hr ROP.
Milled rathole;from 2920' to 2941'. Mudloggers seeing good show of cement and claystone on shakers.;At 2920' pumped a 20 bbl hi-vis nutplug sweep around at
189 gpm-887 psi, 90 rpm-2500 ft/lbs off bott torque. Worked mills through window as per Baker Rep.;Racked back 1 std to 2896', Rig up test equipment, Purge
air from system and Perform FIT at 2887' TVD to 782 psi- 14.4 ppg EMW holding for 10 min bleeding down to 710 psi, pumped 14.4 gal. beld back 13.5 gal., Rig
down test equipment and blow down kill line.;Pumped dry job and POOH F/2896' T/494' observing Calculated displacement, monitor well - static.;Rack back 8
stds of HWDP, L/D Float-TM collar and DM collar one piece. Break down mill assembly and L/D flex collar. Upper and Lower mill in gauge, Starter mill 3/16"
under gauge.;M/U Jet sub and flush stack, drain stack and pull wear ring cleaning off profile and wear ring, reinstall wear ring and RILDS.;Pick up mud motor (
1.5 deg Bend ) and M/U DM and TM, M/U 6 1/8" bit and scribe motor to DM with a 341.96 Deg offset. M/U 2 Flex collars and RIH with 8 plus jar stand of HWDP
to 675'. Shallow hole test @ 250 gpm, 950 psi.;Single in the hole F/675' T/2530', PU 52K, SO 46K.;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 208 bbls
Losses Downhole 0 bbls
Total 0 bbls
Continue Testing BOP's w/ 4.5'' test Jt t/ 250/3500 psi Test CMV 1-13, Upper Lower and Blind rams, TIW and Dart, HCR and Man Choke and Kill valves,gppp
outside kill line valve,Auto and Man IBOP, Annular t/ 250/2500 psi Perform Accumulator Draw down test 28 sec t/ 200 psi 93 sec t/ full pressure, State;Inspector ppp
Jim Regg Waived witness, had three fail passes, Blinds - Replace Elements retest pass, Annular- Function retest pass, Lower pipe rams - Function retest
pass.
pg p py
AOGCC waived witness of BOP Test @ 9/9/2022 8:35 AM
pg
Cont. to build mud in pits. Rig accepted at 02:00 hrs
Continue RIH w/whipstock BHA f/588' to 2878', filled pipe and orient whipstock t/31°L slack off and tag CIBP @ 2924' DPM, set anchor w/10k SOW, shearedppppg@
whipstock bolt w/ 23k SOW. Up wt 55K, dwn wt 50K.;Begin milling window in 7" casing from 2907' (TOW) to 2920' (BOW), 1-3K wob, 250 gpm-850 psi, 100 rpm-ppg g g()()gp p p
3400 ft/lbs torque, 1 to 6 ft/hr ROP. At 2920' milling ahead 3K wob, 193 gpm-556 psi, 10 to 15 ft/hr ROP, at 2925' 7 to 8K wob, 190 gpm-890 psi, 4-5 ft/hr ROP. q
Milled rathole;from 2920' to 2941'.
pp
P/U whipstock and M/U with 35K pp
shear screw. RIH with whip stock to 588
9/13/2022 Cont PU single in hole with CDS-40 DP from 2530' to 2901'.;Serviced rig and topdrive.;Filled pipe at 2901', oriented motor to exit window and shut down pump,
S/O and once bit cleared bottom of window resumed pumping and washed down from 2922' to 2941'. No issue exiting window. Drilled from 2941' to 3212',
sliding wob 4-5K, 245 gpm-1393 psi, 265 psi diff, 114 ft/hr ROP,;rot wob 1-4K, 246 gpm-1451 psi, 50 rpm-6000 ft/lbs on bott torque, 225 ft/hr ROP to get
separation from original wellbore, MW 9.3/vis 46. Max gas 3 units.;Pumped a 20 bbl hi-vis nutplug sweep around at 270 gpm-1544 psi, 60 rpm-4494 ft/lbs off
bott torque. Sweep back on time, no significant increase in cuttings. Shut down and flow checked, well static.;POOH from 3212' to surface. No issue pulling BHA
into window. Racked back HWDP, jars and NM flex DC's. Pulled bit through table and inspected same. Graded a 1-1 and in gauge. Recovered a rusty steel pin
5/16's thick, 1.5 inch long that was riding on clay, top of bit. May have been;sitting outside of 7" casing when we milled window. Photo's in "O" drive photo folder.
LD DM and TM HOC collars. Functioned blind rams and lower 4 1/2" rams. Racked and tallied additional 4 1/2" CDS-40 DP during trip. Up wt 62K, dwn wt 58K
coming off bottom.;PU and MU new DM and slim phase 4 collars, scribed for an RFO of 128.03°. PU and MU ALD?CTN, PWD and TM HOC collars. Plugged in
and downloaded MWD tools. Shallow pulse tested, held PJSM and loaded sources, ran NM flex DC's, HWDP and jars to 732'.;PU and singled in hole with 4 1/2"
DP from 732' to 2409' and filled pipe, cont TIH on stands to 2904', oriented motor for window exit. S/O and exited window with no issue. Cont. RIH T/2992'. Cal
Disp= 34.66 bbls, Act Disp= 27.85 bbls, Diff= 6.81 bbls.;Mad pass F/2992' T/3212', 266 gpm, 1355 psi, 50 rpm, 4.2K TQ, 180 Ft/HR. PU 60K, SO 50K, ROT
54K.;Resume drilling 6 1/8" hole F/3212' T/3521', sliding 245 gpm, 1375 psi, 166 diff, 1-4K wob, 120 ft/hr ROP, rotating 245 gpm, 1325 psi, 60 rpm, 5.1K TQ,
120 ft/hr ROP MW 9.3/vis 45. ECD's- 10.8 ppg, Max gas 60 units. PU 62K, SO 54K, ROT 58K, Holding 15 PPB background LCM with 5 PPB black
product.;Distance to plan 57.14', 24.33' High, 51.71' Right.;Dragon Boxes Loaded 0 bbls
Total Dragon Boxes 0 bbls
Cuttings Totes Loaded 0 bbls
Total Cuttings Totes 0 bbls
ISO Tanks Loaded 104 bbls
ISO Tanks Total 312 bbls
Losses Downhole 15 bbls
Total 15 bbls
9/14/2022 Cont drilling 6 1/8" hole from 3521' to 3884'. Rot wob 1-2K, 250 gpm-1387 psi, 60 rpm-5085 ft/lbs on bott torque, 120 ft/hr ROP. Sliding wob 1K, 252 gpm-1478
psi, 162 psi diff, 118 ft/hr ROP. MW 9.3/vis 42, ECD's at 10.9 ppg, BGG 4 units, max gas 24 units.;Cont drilling 6 1/8" hole from 3884' to 4202'. Sliding wob 3-4K,
261 gpm-1725 psi, 297 psi diff, 114 ft/hr ROP. Rot wob 1-8K, 261 gpm-1628 psi, 60 rpm-5700 ft/lbs on bott torque, 120 ft/hr ROP. MW 9.3/vis 50, ECD's at 11.2
ppg, BGG 9 units, max gas 94 units..;CBU at 251 gpm-1670 psi, 60 rpm-5685 ft/lbs off bott torque. Obtained SPR's at 4202' md/4057' tvd, flow check =
static;Pulled up hole 17 stands on elevators from 4202' to 3146', up wt 61K, S/O and parked at 3209'. Cal Disp= 7.1 bbls, Act Disp= 10.4 bbls, Diff= 3.3
bbls;Serviced rig and topdrive.;TIH on elevators from 3209' to 4142', dwn wt 55K, MU topdrive and filled pipe, washed/reamed last stand down to bottom at
4202'. No fill, Cal Disp= 18.9 bbls, Act Disp= 16.4 bbls, Diff= 2.5 bbls;Pumped a 20 bbl hi-vis nutplug sweep around, 250 gpm-1550 psi, 50 rpm-5500 ft/lbs off
bott torque. At B/U 20% increase in cuttings sweep back on time with 15% increase in cuttings.;Resumed drilling 6 1/8" hole from 4202' to 4344', Rot wob 8K,
250 gpm-1932 psi, 60 rpm-5247 ft/lbs on bott torque, 30-80 ft/hr ROP. Sliding wob 10-12K, 252 gpm-2016 psi, 175 psi diff, 65 ft/hr ROP. MW 9.4/vis 54, ECD's
at 11.4 ppg, BGG 11 units, max gas 123 units, PU 69K, SO 58K, ROT 62K;Cont. drilling 6 1/8" hole from 4344' to 4565', Rot wob 5-8K, 250 gpm-1936 psi, 50
rpm-5326 ft/lbs on bott torque, 20-70 ft/hr ROP. MW 9.3/vis 50, ECD's at 11.3 ppg, BGG 11 units, max gas 235 units, Distance to plan 56.15', 29.91' Low,
47.53' Right;Dragon Boxes Loaded 84 bbls
Total Dragon Boxes 84 bbls
Cuttings Totes Loaded 0 bbls
Total Cuttings Totes 0 bbls
ISO Tanks Loaded 0 bbls
ISO Tanks Total 312 bbls
Losses Downhole 0 bbls
Total 15 bbls
9/15/2022 Cont drilling 6 1/8" hole from 4565' to 4784'. Rot wob 5K, 216 gpm-1634 psi, 60 rpm-5752 ft/lbs on bott torque, 11-80 ft/hr ROP. MW 9.3/vis 52, ECD's at 11.3
ppg, BGG 7 units, max gas 192 units. Obtained SPR's at 4700' md/4434' tvd.;Cont drilling 6 1/8" hole from 4784' to 5070'. Rot wob 8 to 12K, 305 gpm-2697 psi,
65 rpm-5579 ft/lbs on bott torque, 15 to 90 ft/hr ROP, MW 9.4/vis 55, ECD's at 12.2 ppg, BGG 10 units, max gas 185 units. *At 4886' we had 10 units connection
gas, at 4823' we had 38 units connection gas.;Bumped MW up to 9.4 ppg. At 4823' we increased gpm from 220 to 300.;Cont drilling 6 1/8" hole from 5070' to
5194'. 306 gpm-2880 psi, 70 rpm-5626 ft/lbs on bott torque, 8-12K wob, 30-100 ft/hr ROP, MW 9.4/vis 55, ECD's at 12.3 ppg, PU 75K, SO 60K, ROT 64K, BGG
15 units, max gas 161 units. Observing 17 units connection gas;CBU 304 gpm, 2976 psi, 65 rpm, 6.2K tq, ECD's- 12.1 ppg, max gas 93 units, Acquire SPR's
5194'/4810' TVD 30 spm= 571/563 psi, 40 spm= 702/712 psi, monitor well- slight seepage.;POOH on elevators F/5194' T/4142', PU 78K, Cal Disp= 6.3 bbls,
Act Disp= 8.6 bbls, Diff= 2.3 bbls;Service rig and topdrive;RIH on elevators F/4142' T/5133', SO 56K, wash down last std to 5194'- no fill. Cal Disp= 18.9 bbls,
Act Disp= 16.7 bbls, Diff= 2.2 bbls;Circulate Hi-vis/walnut sweep around 220 gpm, 1788 psi, 55 rpm, 7.5K tq, ECD's= 11.7 ppg, MW 9.4 ppg/Vis-55, Observed
15% increase in cuttings and Max gas of 511 units at BU, Sweep back on time with 10% increase in cutting returns.;Cont drilling 6 1/8" hole from 5194' to 5478'.
280 gpm-2690 psi, 70 rpm-7177 ft/lbs on bott torque, 7-11K wob 40-100 ft/hr ROP, MW 9.45/vis 52, ECD's at 12.1 ppg, PU 78K, SO 56K, ROT 66K, BGG 20
units, max gas 117 units. Observing minimal to no connection gas;Distance to plan 31.52', Low 20.01', Right 24.35';Dragon Boxes Loaded 168 bbls
Total Dragon Boxes 252 bbls
Cuttings Totes Loaded 0 bbls
Total Cuttings Totes 0 bbls
ISO Tanks Loaded 0 bbls
ISO Tanks Total 312 bbls
Losses Downhole 0 bbls
Total 15 bbls
pg p gp pp
Resumed drilling 6 1/8" hole from 4202' to 4344',
Cont drilling 6 1/8" hole from 4565' to 4784'.
Cont drilling 6 1/8" hole from 3521' to 3884
9/16/2022 Cont drilling 6 1/8" hole from 5478' to 5818'. Rot wob 7-10K, 280 gpm-2626 psi, 65 rpm-7200 ft/lbs on bott torque, 40 to 100 ft/hr ROP, MW 9.5/vis 46, ECD's at
12.1 ppg, BGG 20 units, max gas 148 units.;Cont drilling 6 1/8" hole from 5818' to 6185', Rot wob 7-10K, 285 gpm-2775 psi, 65 rpm-7200 ft/lbs on bott torque,
30 to 90 ft/hr ROP, MW 9.5/vis 49, ECD's at 12.4 ppg, BGG 12 units, max gas 208 units.;CBU at 277 gpm-2316 psi, 60 rpm-8081 ft/lbs off bott torque, MW
9.5+/vis 50, ECD's at 12.4 ppg, BGG 20 units. Flow check = 1 bph loss rate;Pull up hole on elevators from 6185' to 2965'- 45' outside window. Intermittent 10-
15K drag F/6185' T/5000' pulling clean F/5000' up. PU 60K, Cal Disp= 21 bbls, Act Disp= 28.2 bbls, Diff= 7.2 bbls;Service rig and topdrive, fixed leaking cylinder
on ODS link tilt, monitor well via TT observing 1 bph loss rate;RIH on elevators F/2965' T/6124', washing down last std to 6185', 150 gpm, 1464 psi, 30 rpm,
8.4K TQ tagging 20' of fill. Encountered tight spot 10-15K down @ 5971' picking up and setting back down 10-15K seeing no overpull while working through
tight spot T/5989',;Cal Disp= 63 bbls, Act Disp= 59.4, Diff= 3.6 bbls;Circulate 20 bbl Hi-vis/walnut sweep around, 260 gpm, 2160 psi, 50 rpms, 6.9-7.5K TQ,
ECD's= 12.1 ppg, Max gas= 136 units, Halfway through BU observed 20% increase in cutting until BU was achieved, sweep came back on time with 10%
increase in cuttings;Resume drilling 6 1/8" hole from 6185' to 6308'. Rot wob 7-11K, 256 gpm-2363 psi, 70 rpm-7835 ft/lbs on bott torque, 50 to 100 ft/hr ROP,
MW 9.6/vis 52, ECD's at 12.1 ppg, BGG 17 units, max gas 56 units. Distance to plan 14.56', Low 14.56', Left 0.81';Dragon Boxes Loaded 84 bbls
Total Dragon Boxes 336 bbls
Cuttings Totes Loaded 0 bbls
Total Cuttings Totes 0 bbls
ISO Tanks Loaded 0 bbls
ISO Tanks Total 312 bbls
Losses Downhole 0 bbls
Total 15 bbls
9/17/2022 Cont drilling 6 1/8" hole from 6308' to 6621'. Rot wob 11K, 250 gpm-2261 psi, 70 rpm-8100 ft/lbs on bott torque, 40 to 90 ft/hr ROP, MW 9.6/vis 46, ECD"s at
12.1 ppg, BGG 10 units, max gas 124 units.;Cont drilling from 6621' to 6866'. Rot wob 10K, 264 gpm-2448 psi, 70 rpm-8700 ft/lbs on bott torque, 40 to 80 ft/hr
ROP. MW 9.6+/vis 50, ECD's at 12.3 ppg, BGG 12 units, max gas 136 units. Started our drop in inclination at 6865' from 40° to 23° at 3°/100' as per directional
plan.;Cont drilling from 6866' to 7069', Rot wob 8-11K, 252 gpm-2633 psi, 70 rpm-8600 ft/lbs on bott torque, 40 to 80 ft/hr ROP. MW 9.6/vis 49, ECD's at 12.4
ppg, BGG 33 units, max gas 137 units. sliding wob 4-10K, 244 gpm-2235 psi, 120-180 psi diff, 15-30 ft/hr ROP;Cont drilling from 7069' to 7360', Rot wob 8-11K,
242 gpm-2651 psi, 70 rpm-9600 ft/lbs on bott torque, 40 to 80 ft/hr ROP. MW 9.55/vis 45, ECD's at 12.4 ppg, BGG 35 units, max gas 110 units. Distance to plan
18.32', Low 12.48', Left 13.42';Dragon Boxes Loaded 170 bbls
Total Dragon Boxes 506 bbls
Cuttings Totes Loaded 0 bbls
Total Cuttings Totes 0 bbls
ISO Tanks Loaded 0 bbls
ISO Tanks Total 312 bbls
Losses Downhole 0 bbls
Total 15 bbls
9/18/2022 Cont drilling 6 1/8" hole from 7360' to TD at 7446' md/6565' tvd. Rot wob 11K, 253 gpm-2778 psi, 65 rpm-9500 to 10,000 ft/lbs on bott torque, 70 ft/hr ROP, MW
9.6/vis 46, ECD's at 12.4 ppg, BGG 17 units, max gas 82 units. TD'd 19.24' high and 13.82' left of the line.;CBU x 2 at 250 gpm-2213 psi, 65 rpm-9750 ft/lbs off
bott torque. ECD's at 12.3 ppg, BGG 15 units. Flow check showed slight seepage.;Pulled up hole on elevators from 7446' to 6094' on alternate breaks. Up wt
105K. No issue pulling up hole. S/O and parked at 6152'. Calc hole fill = 10.45 bbls, act hole fill = 10.80 bbls.;Serviced rig, topdrive and crown. Hole on trip tank.
Loss rate just under 1 bph.;TIH on elevators from 6152', down wt 58K. Set down twice at 6370' 15K, then went right through (small slide and small coal). Set
down twice 15K at 7273' then went right through (claystone). Set down twice at 7378' so MU topdrive, filled pipe, washed/reamed down to bottom at
7446';Pumped a 20 bbl hi-vis nutplug sweep around at 266 gpm-2660 psi, 70 rpm-10,900 ft/lbs off bott torque. Had a max of 359 units gas at bottoms up and
50% increase in cuttings. No increase in cuttings with on time sweep to surface. Had added 1 drum NXS lube to suction pit and chased sweep.;Slight seepage
on flow check, POOH on elevators from 7446', up wt 98K to 171' Saw nothing as jars and smart tools pulled into window. Racked back HWDP and jars;PJSM on
BHA and source handling with rig crew and MWD sperry rep. L/D 2 flex collars, M/U top drive orient and remove sources. Perform download as per sperry rep.
Cont. L/D TM, CTN, ALD and Phase 4 collars. Drain and flush motor with water. Functioned blinds and break bit.;Bit grade 1-1-CT-A-I-CT-TD, Cal Disp= 52.6
bbls, Act Disp= 62.4 bbls, Diff= -10.2 bbls, Loss rate 1.1 bbls/hr while downloading.;Clear and clean rig floor, Change elevator direction, install jets and gage
bit.;M/U crossover, bit sub and tri-cone button bit on bottom of first std of HWDP. RIH from surface T/2860' filling pipe at 1500', PU 50K, SO 48K;Circulate STS
at 260 gpm, 575 psi, no rotation. Obtain SPR's prior to going in open hole.;Grease topdrive, drawworks, blocks, crown, and wash pipe. Inspect and grease brake
linkage, check oil in top drive and floor motor prior to going out of window.;Resume TIH F/2860' T/4156', observed no drag going through window, pump OH
volume every 1300' while emptying TT. PU 65K, SO 55K;Dragon Boxes Loaded 0 bbls
Total Dragon Boxes 506 bbls
Cuttings Totes Loaded 0 bbls
Total Cuttings Totes 0 bbls
ISO Tanks Loaded 0 bbls
ISO Tanks Total 312 bbls
Losses Downhole 0 bbls
Total 15 bbls
9/19/2022 Cont TIH on elevators from 4156' to 5336'. Down wt 55K. MU topdrive.;Filled pipe and circulated annular volume at 161 gpm-648 psi with a max of 12 units gas
at bottoms up. Cont TIH from 5336' to 6569', dwn wt 58K. MU topdrive and filled pipe. Circulated annular volume at 190 gpm-1164 psi, max gas 136 units.;Cont
TIH from 6569' to 7408', dwn wt 65K, MU topdrive and filled pipe, washed/reamed down to 7446' at 160 gpm-1020 psi, 40 rpm-8300 to 10,000 ft/lbs off bott
torque. Had a spike of 209 units prior to bottoms up.;Staged pump rate up to 193 then 251 gpm-1375 psi and CBU at 40 rpm-8900 to 10,000 ft/lbs torque. Had a
max of 834 units gas at bottoms up that dropped off quick, 50% increase in cuttings. Followed bott up with a 20 bbl;hi-vis nut plug sweep. No increase in gas or
cuttings, sweep back on time.;Obtained SPR's with this BHA then cont circ at reduced pump rate of 200 gpm-997 psi, alternated rotating every 30 minutes at 40
rpm-8200 to 10,000 ft/lbs torque. Heated upright water tank for cement water, scrubbed derrick from;board to rig floor, scrubbed topdrive and blocks.;Cont. circ
at 200 gpm-980 psi, alternated rotating every 30 minutes at 40 rpm-10,100 ft/lbs torque racking back a stand once at connection height. Pressure test rebuilt
IBOP double valve assembly to 3500 psi, work on cleaning parts connex. Pressure wash cellar and BOP's;Cont. circ at 200 gpm-980 psi, alternated rotating
every 30 minutes at 40 rpm-10,100 ft/lbs torque racking back stand once at connection height. At 7320' RIH back to BTM and repeat process. Cont. pressure
washing cellar and BOP's, paint dog house floor, Clean BOP bolts and parts connex.;Dragon Boxes Loaded 0 bbls
Total Dragon Boxes 506 bbls
Cuttings Totes Loaded 0 bbls
Total Cuttings Totes 0 bbls
ISO Tanks Loaded 0 bbls
ISO Tanks Total 312 bbls
Losses Downhole 0 bbls
Total 15 bbls
Cont drilling 6 1/8" hole from 6308' to 6621
Cont drilling 6 1/8" hole from 5478' to 5818
gyg
Resume drilling 6 1/8" hole from 6185' to 6308'.
Cont drilling 6 1/8" hole from 7360' to TD at 7446' md/6565' tvd.
9/20/2022 Cont circulating at 200 gpm-958 psi, occasional rotate at 40 rpm-9100 to 10,900 ft/lbs off bottom torque, working string from 7446’ up to 7320’ keeping bit below
coals at 7290’. Crews cont cleaning and painting throughout the rig. CCI and expediter prepping items for tomorrows out going barge.;Latched up stand and cont
circulating at 200 gpm-958 psi, every 30 min rotate at 40 rpm-9100 to 10,900 ft/lbs off bott torque, from 7407' to 7446'. Paint choke manifold and handrails.;Cont
circulating at 200 gpm-958 psi, every 30 min rotate at 40 rpm-9100 to 10,900 ft/lbs off bott torque, from 7407' to 7446'. P/U-110k S/O-65k ROT-74K. Drops
inspections and overhead hazards. Finish painting handrails. CCI brought in and staged pipe tubs at end of catwalk.;Dragon Boxes Loaded 0 bbls
Total Dragon Boxes 506 bbls
Cuttings Totes Loaded 0 bbls
Total Cuttings Totes 0 bbls
ISO Tanks Loaded 104 bbls
ISO Tanks Total 416 bbls
Losses Downhole 31 bbls
Total 46 bbls
9/21/2022 Cont circulating at 202 gpm-975 psi, occasinal rotating at 40 rpm-9800 to 10,500 ft/lbs off bott torque, and work pipe from 7398’ to 7446’. MW 9.6+/vis 48, BGG
2 units.;Pulled up hole to 7377', L/D single, did 5 min flow check, fluid dropped 1', cont to POOH 5 stands, up wt 105K, dropped hollow 2.39" drift with wire, cont
POOH racking back DP to the window at 2922'. Pulled at 45 ft/minute with no issues in open hole. Pipe pulled dry.;Turned elevators, cont POOH L/D singles
from 2922' to BHA at 564'. CCI running water wizard in each joint then vacuuming wiper ball through joint, doping threads and installing thread protectors.;RIH
17 stands from 564' to 1596'.;POOH L/D singles from 1596' to HWDP at 564', running water wizard in each joint then vac wiper ball, dope threads and install
protectors. Barge made landing and offloaded Baker equipment.;Had to replace hydraulic hose on iron roughneck. Called out Parker casing crew. Baker Rep
on location at 17:30 to inspect his equipment.;Cont POOH racked back 8 stands HWDP, L/D single HWDP and jars, XO, bit sub and bit. Tri-cone bit graded 0-0
and in gauge.;Staged centralizers, RU casing tongs, elevators and torque turn equipment, staged shoe track and liner on pipe racks. RU fill up line and staged
XO's/drive sub. Held PJSM with rig crew and casing crew.;MU shoe track, filled same and checked floats (OK). Cont PU single in hole with 4 1/2" 12.6# L-80
JFELion liner pipe, torqued to 6690 ft/lbs using torque turn computer system. Filling on the fly, topping off every 10 jnts. Stopped at 2887' and MU circ
swedge.;CBU staging up to 3 bpm-120 psi.;Exited bottom of window at 2920' and cont single in open hole to 3425'.;Dragon Boxes Loaded 85 bbls
Total Dragon Boxes 506 bbls
Cuttings Totes Loaded 0 bbls
Total Cuttings Totes 0 bbls
ISO Tanks Loaded 104 bbls
ISO Tanks Total 416 bbls
Losses Downhole 32 bbls
Total 78 bbls
9/22/2022 Cont PU single in hole with 4 ½” JFELion liner from 3425’ to 4705’, total 149 jnts. Using torque turn system. Down wt 40K.;C/O elevators, PU liner hanger,
installed XO's and wiper plug, MU assembly on stump, torqued XO's then torque turned JFELion connection to stump. S/O, mixed and poured pal mix. RIH one
stand HWDP and MU topdrive at 4824'.;Eased into circ staging up to 3 bpm-340 psi and had a max of 105 units gas at bottoms up. Up wt 54K, dwn wt 48K, did
not obtain rotating parameters due to weak link BTC connections at bottom of liner hanger. No plan to rotate on bottom.;Cont TIH from 4824' with 7 more stands
HWDP then 4 1/2" DP to 6547' and MU topdrive. Sent notification to AOGCC for upcoming MIT-T and MIT-IA.;Filled pipe and staged up to 3 bpm-608 psi for
one pipe volume, up wt 76K, dwn wt 60K. Had a max of 79 units gas.;Cont TIH on stands from 6547' to 7419', dwn wt 60K. PU single jnt DP, MU topdrive, filled
pipe then washed down and tagged bottom 3' deep at 7449' with liner string twice. Washed down at 85 gpm-568 psi. PU 2' off bottom and shut down pump.;PU
and MU Baker cement head, lo-torque valve and cement hose. Cont to circ at 154 gpm-725 psi while cementers staged trucks and RU. Had a max of 192 units
gas at bottoms up. Held PJSM with cementers and rig team.;Halliburton pumped 2 bbls water to flush lines, then 3 bbls to fill lines. Shut in at Baker cement head
and PT lines at 680 psi low 4550 psi high. Lined up Baker cement head to Halliburton, pumped 30 bbls 10.5 ppg Tuned Prime spacer at 3.5 bpm-750 psi,
followed with 103.5 bbls (250 sx) 12.0 ppg;Type I II Lead cement at 3.5 bpm- 680 to 60 psi, followed with 14.3 bbls (70 sx) 15.3 ppg Type I II Tail cement at 2.5
bpm- 90 to 160 psi. Added 2 pps of Bridge Maker LCM to lead cement. Baker released dart, Halliburton then displaced with 10 bbls of water followed by 9.6 ppg
6% KCL mud at 5 bpm-180;psi. 32.5 bbls into displacement saw dart latch wiper plug. With 5 bbls to go, reduced rate to 3 bpm-1300 psi and bumped
plug/landing collar 100 bbls into displacement (calculated at 106 bbls). FCP 1513 psi. Halliburton increased to and held 1975 psi (462 over fcp) for 3 minutes,
then bled back;½ bbl to truck to check floats, floats held. CIP at 20:15 on 9-22-22. Lost 8 bbls throughout the job.;Increased pressure to 2460 psi for 1 minute.
Slacked off on blocks from 80K to 20K, giving us a good indication hanger is set. Increased pressure to 2700 psi, seen packer set. Applied 4170 psi and held 1
minute to shift HRD-E and release run tool. Bled off to 2500 and PU at 46K, good indication;running tool was released from hanger. R/D & L/D Baker cement
head. PU 7’ to clear the dogs from hanger top, S/O and set down to 20K (applied 30K), no indication of packer movement, PU and rotated at 10 rpm-2800 ft/lbs
torque, S/O to 15K twice with no movement.;Closed upper rams, lined up on kill line with rig pump and pressured up on annulus to 950 psi and held 5 minutes.
Pressure held, good indication HRDE ZXP liner top packer is set. Bled off annulus and opened rams.;Pressured up to 600 psi on drill string and PU slowly 17’.
Once psi started dropping, rig started pumping and did one full circ at 297 gpm-459 psi. Had 30 bbls spacer 30 bbls cement to surface that was diverted
overboard to cuttings box.;Shut down pump, racked back one stand, installed wiper ball in drill string, MU topdrive and pumped second circulation at 285 gpm-
440 psi.;POOH from 2645' to surface racking back in derrick and L/D liner running tool.;Drain stack and flush with black water. Function stack and flush
again.;Grease TD, roughneck, and crown. Check oil in drawworks and TD. Change oil filters on floor motor.;M/U polish mill and RIH from derrick t/2687' to
polish pbr. Screw in and set depth. Pump at 1.5bbl/min 130PSI. 5' in and set down 6k on liner top at 2723' (no-go @ 2714') drill pipe depth. P/U above liner top
establish rotary and dress liner top and pbr. P/U 48k S/O 46K ROT 44k;PJSM w/ Bariod and rig team. Displace well at 4bbl/min 255psi to 3% KCL inhibited
brine. Pumped until got good clean brine out of the hole. Over boarded 20bbl spacer and 18 bbl brine;Dragon Boxes Loaded 170 bbls
Total Dragon Boxes 676 bbls
Cuttings Totes Loaded 0 bbls
Total Cuttings Totes 0 bbls
ISO Tanks Loaded 208 bbls
ISO Tanks Total 624 bbls
gp
Sent notification to AOGCC for upcoming MIT-T and MIT-IA
g pp
Lined up Baker cement head to Halliburton, pumped 30 bbls 10.5 ppg Tuned Prime spacer at 3.5 bpm-750 psi, ppgp pp ppg p pp
followed with 103.5 bbls (250 sx) 12.0 ppg;Type I II Lead cement at 3.5 bpm- 680 to 60 psi, followed with 14.3 bbls (70 sx) 15.3 ppg Type I II Tail cement at 2.5()ppgyp p p ()ppg yp
bpm- 90 to 160 psi. Added 2 pps of Bridge Maker LCM to lead cement. Baker released dart, Halliburton then displaced with 10 bbls of water followed by 9.6 ppg ppppg p
6% KCL mud at 5 bpm-180;psi. 32.5 bbls into displacement saw dart latch wiper plug. With 5 bbls to go, reduced rate to 3 bpm-1300 psi and bumped pp p ppg g p pp
plug/landing collar 100 bbls into displacement (calculated at 106 bbls). FCP 1513 psi. Halliburton increased to and held 1975 psi (462 over fcp) for 3 minutes, pg g p()p
then bled back;½ bbl to truck to check floats, floats held. CIP at 20:15 on 9-22-22. Lost 8 bbls throughout the job.;
9/23/2022 Clean out trip tank and shakers after displacing upper 2714' of wellbore to 3% KCL inhibited brine, monitor well for any flow, fill trip tank with brine, blow down
surface equipment and lines.;POOH from 2700’ LD DP and polish mill. Vac'd wiper ball, doped threads and re-installed protectors on pipe while on pipe
rack.;MU muleshoe, TIH with remainder of stands in derrick to 1239’.;Cut and slipped 124' of drill line, checked crown saver, calibrated hook load.;POOH LD 40
jnts DP from 1239', vac'd wiper ball, doped threads and re-installed protectors on pipe rack.;RU test hoses and chart recorder, purged air, closed blinds,
pressured up to 3000 psi on chart, lost 75 psi over 15 minutes. Bled off, functioned blinds and rams, purged air, pressured up to 3000 psi, lost 100 psi over20
minutes. Bled off, checked chart sensor and pumped up.;Functioned rams, purged air from hoses, closed blinds, pressured up to 3000 psi, still bleeding off,
found couple gland nuts leaking, tightened those. Pressure up to 3200 psi, lost over 100 psi over 20 minutes and still bleeding off. Stated trouble shooting and
isolating sections of the test system.;Replaced bladder in chart pressure sensor, changed chart tester pressured up manifold and still bleeding off pressure.
Discussed with town engineer plan forward if we couldn't get a good test on the test chart we would test with mud pumps;and chart on pason. Replaced valves
on the test manifold and got a good pressure test on it Pressured up to 3200 psi again with test pump and bleed off again and would not stabilize. Lined up on
hole with mud pumps and fluid packed lines, closed blinds and pressured up to 3300psi.;Mud was aired up and bleed off 120 psi in first 10 minutes then
stabilized at a 3-5 psi drop a min for next 30 min. Discussed with town engineer and was good with test and decision was made to move forward and run
tieback.;R/D test equipment. R/U parker casing equipment, get XO's and seal assembly to rig floor. load pipe rack with 4.5" JFELion tubing.;Held PJSM with rig
team, parker casing hands and Baker tool hand. Make up Bullet seal assembly and XO's to bottom of first joint of tubing. RIH as per tally @ 142'.
9/24/2022 Cont PU single in hole with 4 1/2" tieback string from 142' to 2214', using torque turn system on JFELion pipe. PU and MU chemical injection mandrel.;Held
PJSM with Pollard Rep, hung sheave and string 3/8" control line, MU same on mandrel, Pollard Rep tested line to 2500 psi, good test, bled control line to 1000
psi for TIH.;Cont PU single in hole to 2702' installing 2 bands per jnt (1 at collar, 1 mid jnt), up wt 52K, dwn wt 52K. 85 jnts as per tally. PU extra jnt, S/O and
tagged no-go on liner top at 2714' twice. L/D 2 singles, PU 3 pup jnts (27.27' total), eased in hole seeing seals enter SBR.;MU 4 1/2" 8 rnd EUE box by 4 1/2"
MCA sub on landing jnt, MU landing jnt on hanger. Bled off control line and terminated same through hanger. Drained stack, pulled bushings, S/O 16.8' and
landed hanger on depth. Ran 37 SS bands. RILD's, tested hanger void at 5K f/15 min, good test.;L/D landing jnt, RU test equipment and chart recorder, flooded
surface lines and stack, function upper rams and blinds 7 times, functioned kill HCR 7 times to purge air, closed blinds, installed gauge on IA, applied 3120 psi
on 4 1/2" tubing and liner, held 30 min on chart, good test.;Pressure dropped 5 psi over 30 min, pumped 50 gallons, bled back 48 gallons. RU test equipment on
7" IA, installed gauges on mezz kill valve junction and OA, applied 2580 psi on 4 1/2" x 7" IA and held 30 min on chart, good test. Pressure dropped 30 psi over
30 min, pumped 27.5 gallons,;bled back 27 gallons. Saw 0 psi on OA. RD test equipment. Released Pollard Rep, mud Engineers and casing Reps.;Wellhead
Rep installed 2 way check in hanger.;Flush surface lines with Baraclean and blow down. Break down cement head. Open ram doors clean cavities and inspect.
N/D BOP. R/D boiler for transport. Clean pit modules;Install dryhole tree, test hanger neck and void to 5k for 15min test good. Test tree to 5k for 15min test
good. Pull 2 way check.;Clear rig floor of subs an pipe handling equipment. Begin R/D topdrive and pit modules for transport. CCI staged on location BOP, top
drive and iron roughneck cradle.;Cont to R/D and L/D topdrive and extend frame. R/D torque tube. Rig released at 06:00;Dragon boxes loaded 170 bbls
Total Dragon Boxes 846 bbls
Cuttings Totes Loaded 0 bbls
Total Cuttings Totes 0 bbls
ISO Tanks Loaded 104 bbls
ISO Tanks Total 1352 bbls
Losses Downhole 0 bbls
Total 78 bbls
Activity Date Ops Summary
10/6/2022 Arrive at Kenai Hilcorp Hanger for Otter flight. Mobilize to Beluga.
Check into camp and start equipment. Hold TBT and approve PTW. Meet with Rig 147 DSM and discuss rig up options.
Layout pit liner on pad and spot Cruz crane, SLB coil unit and pump truck.
CCI spot supply tank and BOP/iron trailer.,Test BOPE to 250 psi low / 3000 psi high. Jim Regg with AOGCC waived witness via e-mail on 10/4/22 at
14:51.,Secure location and SDFN.
10/7/2022 NU BOPs and Function test. Pick up lubricator and MU cleanout BHA.,MU 2-1/8" CTC and pull test to 25K. MU DFCV's and disconnect and PT to 4000 psi. MU
3.74" nozzle.
Go to the well and PT to 250/3000 psi.,RIH and tag at 2734'. Try pumping and setting down weight, unable to get through. POOH.,MU 2.75" nozzle and RIH.
Pass through liner hanger without any issues.
Tag at 7298' ctmd. Online with pump at 1.5 bpm and 3780 psi. Jet down to 7306' ctmd and cannot get deeper.
POOH 30' to 7276' ctmd and paint Flag for memory log. Reciprocate across bottom 100'.
Continue circulating out drilling mud while POOH.,Laydown nozzle BHA and lubricator. Set down injector and secure well with night cap on BOPs.
SDFN.
10/8/2022 SLB coil, Halliburton, Cruz meet at office, hold TBT and approve PTW.
Travel to location and warm up equipment. MU Halliburton memory CBL toolstring.
PT lubtricator 250/3000 psi.,RIH with Halliburton memory CBL. Stop at Flag (7294') and wait for 10 minutes.
Log up at 40 ft/min to 2500'. Stop and wait 10 minutes. POOH to surface.
Laydown logging BHA and MU 2.75" nozzle.
Confirm CBL data is good. Estimated TOC = 2900'.,RIH with 2.75" nozzle. Start pumping N2 at 4000'. Tag at 7306' ctmd. PUH to 7300' and pump N2 at 1200
scfm.
Once N2 at surface, start to POOH with coil. Recover all fluid to surface and shut in choke.
Pressure up tubing to 1725 psi with N2. Coil at surface, shut-in swab.,Laydown nozzle BHA and stack down lubricator. Set down injector on back deck.
De-mob coil unit, pump truck, N2 truck.
SDFN.
10/9/2022 SLB coil, Cruz meet at office, hold TBT and approve PTW.
RD and De-mob equipment from K pad.
10/24/2022 PJSM and PTW,Troubleshoot Crane.,MU Gun gamma and 12' of 2-7/8" Geodymanics gun, 6spf, 15gm (CCL to top shot 10.8')
PT lubricator to 250 psi low / 3000 psi high. Open well, tubing = 1700 psi.
RIH, pull correlation log and send to town - shift 27' down and re-send log to RE/GEO.
Confirm on depth.,Pull on depth and perforate Beluga I12 from 7,149-7,161'. POOH. Bull plug has a little water and a little sand.
SITP
0min - 1700 psi
5min - 1700 psi
10min - 1700 psi
15min - 1700 psi,Wireline at surface. Close swab and bleed off pressure.
Lay down gun and confirm all shots fired. Lay down lubricator.
Secure well with night cap on wireline valves.
SDFN.
10/25/2022 AK E-line hold TBT and approve PTW.
Start and warm up equipment. Change out grease drum. Grease hose is frozen, use heater and visqueen to thaw.
Twin Otter arrive with GPT and setting tool.,MU & RUH with GPT toolstring with empty 2.5" gun on bottom to catch fluid sample.
Find fluid level at 6558' which is 591' above top perf. Surface pressure = 1000 psi.,MU & RIH with 3.71" CIBP. GR to top of plug = 13.2'. Set top of plug at 7100'.
Log off plug and set back down to verify plug is set. POOH.,MU & RIH with 2-7/8" x 20' perf gun. Send correlation log to RE/GEO and shift down 2'.
Perforate I1 interval from 6524-6544.
Initial pressure = 1000 psi. 5, 10, 15 minute pressure = 1000 psi.
All shots fired. Bull plug had a little water.,Laydown perf gun and lubricator.
Secure well with night cap on wireline valves.
SDFN.
n (LAT/LONG):
evation (RKB):
API #:
Well Name:
Field:
County/State:
BRU 233-23
Beluga River
Hilcorp Energy Company Composite Report
, Alaska
Contractor
AFE #:
AFE $:
Job Name:221-00070 BRU 233-23 Completion
Spud Date:
10/26/2022 AK E-line hold TBT and approve PTW.
Start and warm up equipment. Clear snow from around equipment and wellhouse.
MU GPT toolstring with empty perf gun to collect fluid sample.,RIH and find fluid level at 6290', which is 234' above top perf. Tubing pressure = 570 psi.
Log up from 6600' to confirm no fill at perfs. POOH.,RIH with 3.71" CIBP and set at 6519'.
Set down weight on plug to confirm set. POOH.
Run jumper line from another well and pressure up tubing to 941 psi.,RIH with 2-7/8" x 14' gun. Send correlation data to RE/GEO and confirm on depth.
Perforate Beluga I sand from 6483-6497'.
Initial pressure, 5 min, 10 min, 15 min pressures all remained the same at 941 psi.
All shots fired. Bull plug on gun was slightly wet, no sand.,Laydown gun and lubricator. Secure well with night cap on wireline valves. Re-head.
Handover well to operations to bring on-line.
SDFN.
10/27/2022 AK E-line hold TBT and approve PTW.
MU GPT toolstring with empty gun to catch fluid sample.,RIH with GPT and find fluid level at 6200', which is 283' above top perf. Tubing pressure = 1305 psi.
Perfs are clear, tag plug at 6519'. POOH.,Laydown GPT toolstring and obtain fluid sample.
Laydown lubricator and secure well with night cap on wireline valves.
Handover well to operations to flow.,Swap out Pollard crane with AK E-line crane that arrived at Beluga via barge.
Load lubricator racks and grease drums onto AK E-line crane.
SDFN
10/28/2022 AK E-line hold TBT and approve PTW.
MU GPT toolstring and PU lubricator and stab onto wireline valves.,RIH with GPT and find fluid level at 6150', which is 333' above the top perf. Tubing pressure =
1227 psi. Tag CIBP at 6519.
POOH.,MU 20' 2-7/8" HSC gun. Arm and RIH. Pull correlation log, send to town, make 3' shift per Geo. Perforate the H10 from 6027'-6047'. POOH. POOH.
Pressure data: initial - 1295 psi, 5 min - 1305 psi, 10 min - 1307 psi, 15 min - 1308 psi. All shots fired, gun was dry.,MU 14' 2-7/8" HSC gun. Arm and RIH. Pull
correlation log, send to town, make 2' shift per Geo. Perforate the H9 from 5971'-5985'. POOH. Pressure data: initial - 1326 psi, 5 min - 1315 psi, 10 min - 1305
psi, 15 min - 1295 psi. All shots fired, gun was dry. Install night cap on top of wireline valves. Turn well over to production to flow the well. Lay down lubricator and
SDFN.
10/29/2022 Meet with AK EL. PJSM and PTW. Arrive on location and warm up equipment. MU and run GPT logging tools. Find fluid level at 2620' while RIH. Tag at 6489' (30'
above CIBP). POOH and find fluid level at 2375'. Collect fluid sample. RDMO off well for now.
10/31/2022 AK EL arrive at office. PJSM and PTW. Arrive on location, warm up equipment. MIRU on BRU 233-23. Re-head EL. PU wireline valves and lubricator. MU GPT
toolstring. PT lubricator to 250 psi / 3000 psi. RIH and find fluid level at 3756' with WHP at 982 psi. Jumper well to neighboring well to depress fluid level.,WHP
pressure increased to 1250 psi. Find fluid level at 4070'. Fluid depressing at a rate of ~120'/hr. POOH with GPT tools and secure tree. SDFN. Continue to
depress fluid level over night.
11/1/2022 AK EL arrive at office. PTW and PJSM. Arrive at wellsite, warm up equipment. Run GPT log. WHP 1310 psi. Find fluid level at 4400'. POOH.,MU and run 3.75"
gauge ring/drift for CIBP. Could not drift pass liner lap at 2710'. Tried multiple times at different speeds. Overpulling 200 lbs to come free. POOH. MU and RIH
with 3.71" CIBP. Could not drift pass liner lap at 2710'. POOH. Contact AK EL and get a special clearance CIBP on its way to location.,MU 3.50" special
clearance CIBP. RIH. No issues going through the liner lap. Correlate, send to town. Set CIBP at 6015' between H10 and H9 zones. Tag plug, on depth at 6015'.
POOH. Lay down lubricator. Secure tree. Hand well over to production to flow H9 zone overnight. SDFN.
11/2/2022 On weather standby due to ~15 inches of snow and no flights.
11/3/2022 AK Eline on location. Open PTW & PJSM. Snow removal from worksite. Rig up and stab onto WLV's w/ lubricator and GPT tool. Open up to wellbore pressure,
277 psi.,SITP = 277 psi. RIH w/ 7 'x 1.69" WB, 9.5' x 1.69" GPT w/ CCL (7.5' from CCL to bottom of tool). RIH and find Fluid Level @ 4002'. Tag CIBP @ 6015'
(no fill). POOH.,Rig down Eline and install tree cap (Swab shut to monitor SITP on the flowline). Spot equipment at edge of pad. and turn well over to operations.
11/8/2022 SLB N2 on location. Open PTW & PJSM. Rig up to flowline 1502 connection. Spot in flatbed with N2 pods. PT to 250/3000 psi. Pass,SITP = 377 psi. Come online
w/ N2 @ 1300 scf/min. Reduce rate to 1000 scf/min @ 65,000 scf./2650 psi. Reduce rate to 500 scf/min @ 70,000 scf / 2890 psi. SI @ 73,500 scf / 2950 psi. PT
to 250/3300 psi, pass. Online @ 500 scf/min, ssv closed @ 82,000 scf/3290 psi. SI at wing. PT to 250/3500 psi, pass. Ops opens SSV. Online @ 600 scf/min.
Build WHP to 3460 @ 93,276 scf. SI well on the flowline. 772 gallons of N2 pumped.,Rig down N2 unit and secure well SI at the flowline valve. N2 left on
location, 4935 gallons on SLB pump and pods, 6000 gallons on Airgas transport.
11/9/2022 PTW and PJSM. Monitor pressure fall off from yesterday. SITP is 3042 psi this morning (fell off from 3450 psi yesterday). Waiting on Operations to swap a 1502
connection to the tree so that additional pressure can be applied with N2.,MU hardline to tree and pressure test lines to 4750 psi. Good test. Come online with
nitrogen pump at 1000 scfm. Pressure climbed to 3500 and then broke over. Increased rate to 1400 scfm, Pressure built to 4100 psi and then broke over again.
Shut down nitrogen pump with WHP at 4020 psi. Pumped a total of 820 gallons of N2, 75,000 scf. Secured tree and equipment for the night. SDFN.
11/10/2022 Morning meeting. PTW and PJSM. Snow removal. Move in rig up on 233-23.,Pickup lubricator and GPT logging tools. Pressure test to 250 psi and 3500 psi.
Good test. Open well - WHP at 1284 psi. RIH and find fluid level at 5960' (10' above top perf). POOH.,MU 3.5" special clearance CIBP. Arm and RIH. Set plug
5950'. Tag plug, on depth. POOH.,MU 11' 2-7/8" HSC gun. Arm and RIH. Pull correlation log, send to town, on depth. Perforate the H3 from 5741'-5751'. POOH.
Pressure stable at 1184 psi for 15 min after shooting. All shots fired, gun was dry. Lay down lubricator. Secure tree. Re-head. SDFN.
11/11/2022 Morning meeting. PJSM and PTW. Warmup equipment and pickup lubricator. SITP 1580 psi. MU GPT tools and RIH. Find fluid level at ~5900'. POOH.,MU 20' 2-
7/8" HSC gun. Arm and RIH. Pull correlation log. Perforate the H2 from 5685'-5705'. POOH. Initial pressure - 1578 psi, 5 min - 1567 psi, 10 min - 1546 psi, 15 min
- 1521 psi. All shots fired, gun was dry.,MU 6' 2-7/8" HSC gun. Arm and RIH. Pull correlation log. Perforate the H Lower from 5604'-5610'. POOH. Initial pressure -
1222 psi, 5 min - 1218 psi, 10 min - 1214 psi, 15 min - 1210 psi. All shots fired, gun was dry.,MU 4' 2-7/8" HSC gun. Arm and RIH. Pull correlation log. Perforate
the H Upper from 5578'-5582'. POOH. Initial pressure -1174 psi, no change after 15 min. All shots fired, gun was dry.,MU 6' 2-7/8" HSC gun. Arm and RIH. Pull
correlation log. Perforate the G9 from 5433'-5439. POOH. Initial pressure -1167 psi,, 5 min - 1172 psi, 10 min - 1176 psi, 15 min - 1179 psi. All shots fired, gun
was dry. Lay down lubricator. Secure tree. SDFN.
ppp p
Perforate the H2 from 5685'-5705'. POOH
SLB N2 on location
p
Perforate the G9 from 5433'-5439. POOH
pp p
Perforate the H Lower from 5604'-5610'. p
Perforate pp
the H Upper from 5578'-5582'.
pg
Perforate the H3 from 5741'-5751'. POOH.
11/12/2022 Morning meeting. PTW and PJSM. Warmup equipment and pickup lubricator. MU GPT. Well flowing at 1.145 mm at 334 psi. RIH and find fluid level at 5620' and
tagged at 5950'. POOH.,MU 5' 2-7/8" HSC gun. Arm and RIH. Correlate, send to town, on depth. Shut in well prior to shooting. Perforate the G3 Lower from 5291'-
5296'. POOH. All shots fired, gun was dry. Pressure data: initial - 685 psi, 5 min - 716 psi, 10 min - 783 psi, 15 min - 835 psi.,MU 9' 2-7/8" HSC gun. Arm and RIH.
Correlate, on depth. Perforate the G3 Upper from 5268'-5277'. POOH. All shots fired, gun was dry. Pressure data: initial - 1057 psi, 5 min - 1037 psi, 10 min -
1016 psi, 15 min - 1012 psi.,MU 8' 2-7/8" HSC gun. Arm and RIH. Correlate, on depth. Perforate the G2 Lower from 5243'-5251'. POOH. All shots fired, gun was
dry. Pressure data: initial - 967 psi, 5 min - 961 psi, 10 min - 944 psi, 15 min - 936 psi.,MU 15' 2-7/8" HSC gun. Arm and RIH. Correlate, on depth. Perforate the
G2 Upper from 5211'-5226'. POOH. All shots fired, gun was dry. Pressure data: initial - 902 psi, 5 min - 903 psi, 10 min - 899 psi, 15 min - 895 psi.,MU 6' 2-7/8"
HSC gun. Arm and RIH. Correlate, on depth. Perforate the G1 from 5188'-5194'. POOH. All shots fired, gun was dry. Pressure data: initial - 885 psi, 5 min - 890
psi, 10 min - 890 psi, 15 min - 890 psi.
Lay down lubricator. Secure tree. SDFN.
g
Perforate the yp
G2 Upper from 5211'-5226'. POOH.
gy p
Perforate the G3 Upper from 5268'-5277'. POOH. All shots fired y pp
Perforate the G2 Lower from 5243'-5251'. POOH. All shots fired,
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AE A
A
Chelsea Wright Digitally signed by Chelsea Wright
Date: 2022.09.23 08:19:06 -08'00'Benjamin Hand Digitally signed by Benjamin Hand
Date: 2022.09.23 09:34:48 -08'00'
TD Shoe Depth: PBTD:
Jts.
1
2
147
Yes X No X Yes No 15
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?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
Shoe 5
Rotate Csg Recip Csg Ft. Min. PPG9.6
Shoe @ 7446 FC @ Top of Liner 27147,402.20
Floats Held950
6% KCL Mud
CASING RECORD
County State Alaska Supv.R Pederson / J Gruenberg
Hilcorp Energy Company
CASING & CEMENTING REPORT
Lease & Well No.BRU 233-23 Date Run 22-Sep-22
Setting Depths
Component Size Wt. Grade THD Make Length Bottom Top
BTC Innovex 1.36 7,446.00 7,444.64
Csg Wt. On Hook: Type Float Collar:Innovex No. Hrs to Run:
9.6 5
100
1513
FI
R
S
T
S
T
A
G
E
10.5Tuned Prime 30
100/106
1975
30
Halliburton
15.3 14.3
Bump press
CBL
Bump Plug?
20:15 9/22/2022 2,900
7,446.007,446.00 7,360.41
CEMENTING REPORT
Csg Wt. On Slips:
6% KCL Mud
12 103.5
Type of Shoe:Bullnose Casing Crew:Parker
Baker
www.wellez.net WellEz Information Management LLC ver_04818br
2.5
1 per joint for first 143 joints
Liner 4 1/2 12.6 L-80 BTC 41.19 7,444.64 7,403.45
Float Collar 5 BTC Innovex 1.25 7,403.45 7,402.20
Liner 4 1/2 12.6 L-80 BTC 40.78 7,402.20 7,361.42
Landing Collar 5 BTC JHobbs 1.01 7,361.42 7,360.41
Liner 4 1/2 12.6 L-80 JFELion JFE 4,619.35 7,360.41 2,741.06
Crossover 5 L-80 BTC 4.88 2,741.06 2,736.18
Liner Hanger 6 BTC Baker 25.27 2,736.18 2,714.00
I II 250 2.39
I II 70 1.24
3.5
Kyle Wiseman Hilcorp Alaska, LLC
Geotechnician 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: (907) 777-8337
E-mail: Kyle.Wiseman@hilcorp.com
Please acknowledge receipt by signing and returning one copy of this transmittal.
Received By: Date:
Date: 12/02/2022
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
SFTP DATA TRANSMITTAL T#20221202
Well API #PTD #Log Date Log
Company Log Type AOGCC
Eset#
BRU 222-34 50283201860000 222039 11/22/2022 AK E-Line Perf
BRU 233-23 50283201360100 222050 11/3/2022 AK E-Line GPT
BRU 244-27 50283201850000 222038 11/23/2022 AK E-Line Perf GPT
CLU 05RD2 50133204740200 222092 11/17/2022 AK E-Line Perf
MPU K-34 50029227120000 196169 11/10/2022 AK E-Line Punch
CLU 13 50133206460000 214171 11/12/2022 Halliburton SBHP
END 3-25B 50029221250200 203021 11/24/2022 Halliburton PPROF
PBU S-15 50029211130000 184071 11/24/2022 Halliburton RBT
PBU Z-221 50029237040000 221095 11/17/2022 Halliburton IPROF
PBU Z-221 50029237040000 221095 11/19/2022 Halliburton IPROF
Please include current contact information if different from above.
T37345
T37346
T37347
T37348
T37349
T37350
T37351
T37352
T37353
T37353
By Meredith Guhl at 12:25 pm, Dec 02, 2022
BRU 233-23 50283201360100 222050 11/3/2022 AK E-Line GPT
Meredith Guhl Digitally signed by Meredith Guhl
Date: 2022.12.02 12:24:17 -09'00'
David Douglas Hilcorp Alaska, LLC '? Z Z _ d SD
Sr. GeoTechnician 3800 CenterPoint Drive, Suite 1400
Anchorage, AK 99503 1 (� 2Z
Tele: (907) 777-8337 U I
1111"„ri, kla-k". LN E-mail: david.douglas@hilcorp.com
Date: 12/01/2022
To: Alaska Oil & Gas Conservation Commission
Petroleum Geology Assistant
333 W 7th Ave Ste 100 RECEIVED
Anchorage, AK 99501
DATA TRANSMITTAL DEC 0 1 ZUZZ
BRU 233-23 A®GCC
- PTD 222-050
- API 50-283-20136-01-00
Washed and Dried Well Samples (09/12/2022 to 09/18/2022)
B Set (3 Boxes):
WELL
BOX
SAMPLE INTERVAL (FEET / MD)
BRU 233-23
BOX 1 OF 3
2910' - 4500' MD
BRU 233-23
BOX 2 OF 3
4500' - 6000' MD
BRU 233-23
BOX 3 OF 3
6000' — 7446' MD (TD)
Please include current contact information if different from above.
Please acknowledge receipt by signing and returning one copy of this transmittal.
Received Date:
Kyle Wiseman Hilcorp Alaska, LLC
Geotechnician 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: (907) 777-8337
E-mail: Kyle.Wiseman@hilcorp.com
Please acknowledge receipt by signing and returning one copy of this transmittal.
Received By: Date:
Date: 11/21/2022
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
SFTP DATA TRANSMITTAL T#20221121
Well API #PTD #Log Date Log
Company Log Type AOGCC
Eset#
CLU 05RD2 50133204740200 222092 10/18/2022 AK E-Line Perf_GPT
MGS S MGS
Unit 11 50733201040000 168032 10/11/2022 AK E-Line LDL
SRU 241-33 50133206630000 217047 8/29/2022 AK E-Line TTBP_Perf
SRU 32A-33 50133101640100 191014 9/23/2022 AK E-Line GPT
SCU 344-33 50133202930100 218054 9/11/2022 AK E-Line Punch
BCU 18RD 50133205840100 222033 9/10/2022 AK E-Line GPT
BCU 18RD 50133205840100 222033 9/18/2022 AK E-Line Stim
BRU 233-23 50283201360100 222050 11/1/2022 AK E-Line Perf
BRU 233-23 50283201360100 222050 9/12/2022 AK E-Line CIBP
Please include current contact information if different from above.
T37280
T37281
T37282
T37283
T37284
T37285
T37285
T37286
T37286
By Meredith Guhl at 2:54 pm, Nov 21, 2022
BRU 233-23 50283201360100 222050 11/1/2022 AK E-Line Perf
BRU 233-23 50283201360100 222050 9/12/2022 AK E-Line CIBP
Meredith Guhl Digitally signed by Meredith Guhl
Date: 2022.11.21 14:55:38 -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: 11/15/2022
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
T37260
BRU 233-23 50283201360100 222050 10/8/2022 Halliburton RCBL
Kayla
Junke
Digitally signed by Kayla Junke
Date: 2022.11.15 15:32:43 -09'00'
CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders.
From:McLellan, Bryan J (OGC)
To:Jacob Flora
Cc:Benjamin Siks
Subject:RE: [EXTERNAL] RE: Perf Add Request: BRU 233-23 Mem (PTD 222-050) (Sundry 322-560)
Date:Wednesday, November 2, 2022 4:05:00 PM
Attachments:image001.png
image002.png
Hilcorp has approval to add the perfs listed in the below table. Report them on the 10-407 with sundry 322-560.
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: Wednesday, November 2, 2022 3:43 PM
To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Cc: Benjamin Siks <bsiks@hilcorp.com>
Subject: Re: [EXTERNAL] RE: Perf Add Request: BRU 233-23 Mem (PTD 222-050) (Sundry 322-560)
Correct, all the perfs in the table.
Thanks,
Jake
On Nov 2, 2022, at 3:39 PM, McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> wrote:
Jake,
I don’t see any red brackets. Do you want to add all the perfs listed in the table in your email below?
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: Wednesday, November 2, 2022 10:06 AM
To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Cc: Benjamin Siks <bsiks@hilcorp.com>
Subject: Perf Add Request: BRU 233-23 Mem (PTD 222-050) (Sundry 322-560)
Hello Bryan,
We have currently tested up to the H-9 sand and have not made a well yet. Hilcorp requests to add the below perfs notated with
the red bracket to the approved sundry. They are all well below the highest allowable perforation depth of 3311’ TVD.
Greatly appreciated,
Jake
CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders.
From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Sent: Monday, October 24, 2022 9:24 AM
To: Jacob Flora <Jake.Flora@hilcorp.com>
Cc: Benjamin Siks <bsiks@hilcorp.com>; Karson Kozub - (C) <kkozub@hilcorp.com>
Subject: RE: [EXTERNAL] RE: BRU 233-23 Mem CBL (PTD 222-050) (Sundry 322-560)
Jake,
Hilcorp has approval to perf the additional sands listed in the below email under sundry 322-560. Include the report of these perfs
in the 10-404.
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: Friday, October 21, 2022 4:04 PM
To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Cc: Benjamin Siks <bsiks@hilcorp.com>; Karson Kozub - (C) <kkozub@hilcorp.com>
Subject: RE: [EXTERNAL] RE: BRU 233-23 Mem CBL (PTD 222-050) (Sundry 322-560)
Hi Bryan,
Our geologist would like to add the below sand (in red font) to the currently approved perforation table. This sand is about 500’
deeper than the previously approved table. To accommodate this I redid the calcs for MPSP and shallowest allowable perf depth,
which still exceeds the perf table TVDs.
Let me know if you need anything else to review this request.
Thanks,
Jake
New Max BHP 2777 psi @ 6313’ TVD (based on 0.44 psi gradient)
New MPSP 2146 psi (Based on 0.1 psi/ft gas gradient to surface)
New Shallowest Allowable Perf TVD = 3311’ TVD
REQUESTING TO ADD:
CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders.
BELUGA I12 7149 to 7161’ MD 6313 to 6324’ TVD
CURRENTLY APPROVED IN SUNDRY 322-560:
From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Sent: Friday, October 21, 2022 2:00 PM
To: Jacob Flora <Jake.Flora@hilcorp.com>
Subject: [EXTERNAL] RE: BRU 233-23 Mem CBL (PTD 222-050) (Sundry 322-560)
Jake,
Cement looks good. Hilcorp has approval to perforate per sundry 322-560
.
Bryan McLellan
Senior Petroleum Engineer
Alaska Oil & Gas Conservation Commission
CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders.
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.
333 W 7th Ave
Anchorage, AK 99501
Bryan.mclellan@alaska.gov
+1 (907) 250-9193
From: Jacob Flora <Jake.Flora@hilcorp.com>
Sent: Friday, October 21, 2022 9:17 AM
To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Subject: FW: BRU 233-23 Mem CBL (PTD 222-050) (Sundry 322-560)
Hi Bryan,
Would you be able to look at this CBL and give approval to perforate? Hoping to be on it Monday.
Thanks,
Jake
From: Jacob Flora
Sent: Friday, October 14, 2022 1:37 PM
To: bryan.mclellan@alaska.gov; Karson Kozub - (C) <kkozub@hilcorp.com>
Subject: BRU 233-23 Mem CBL (PTD 222-050) (Sundry 322-560)
Hi Bryan,
Please see attached CBL for this well.
Thanks,
Jake
From: Brad Gathman - (C) <Brad.Gathman@hilcorp.com>
Sent: Sunday, October 9, 2022 5:30 AM
To: Jacob Flora <Jake.Flora@hilcorp.com>
Subject: FW: [EXTERNAL] BRU 233-23 Mem RBT 100822
From: John Soules III <John.SoulesIII@halliburton.com>
Sent: Saturday, October 8, 2022 6:48 PM
To: Katherine O'Connor <Katherine.Oconnor@hilcorp.com>; Brad Gathman - (C) <Brad.Gathman@hilcorp.com>
Cc: Chris Gullett <Christopher.Gullett@halliburton.com>
Subject: [EXTERNAL] BRU 233-23 Mem RBT 100822
All,
Attached is the RBT log. Est. Cement looks to be @ 2900’
Thanks,
John Soules
This e-mail, including any attached files, may contain confidential and privileged information for the sole use of the intended
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The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are notan intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have
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and other checks as it considers appropriate.
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
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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.
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.
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.
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: 10/19/2022
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
DATA TRANSMITTAL
BRU 233-23
- PTD 222-050
- API 50-283-20136-01-00
MUDLOGS - EOW DRILLING REPORTS (09/12/2022 to 09/18/2022)
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:222-050
T37171
Kayla
Junke
Digitally signed by Kayla Junke
Date: 2022.10.20 11:43:14 -08'00'
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: 10/19/2022
To: Alaska Oil & Gas Conservation Commission
Natural Resources Technician
333 W. 7th Ave. Ste#100
Anchorage, AK 99501
DATA TRANSMITTAL
BRU 233-23
- PTD 222-050
- API 50-283-20136-01-00
FINAL LWD FORMATION EVALUATION LOGS (09/02/2022 to 09/19/2022)
ROP, DGR, SLIM 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:222-050
T37171
Kayla Junke
Digitally signed by
Kayla Junke
Date: 2022.10.20
11:41:41 -08'00'
1
Regg, James B (OGC)
From:Brad Gathman - (C) <Brad.Gathman@hilcorp.com>
Sent:Sunday, October 9, 2022 12:36 PM
To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC)
Cc:Juanita Lovett; Donna Ambruz
Subject:SLB 13 CTU BOPE Test Form 10-06-22
Attachments:SLB 13 CTU BOPE Test Form 10-06-22.xlsx; [EXTERNAL] AOGCC Inspection Form Confirmation Email;
[EXTERNAL] RE: AOGCC Test Witness Notification Request: BOPE, SLB Coiled Tubing Unit 13, BRU
233-23
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 233-23
PTD 2220500
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:10/6/22
Rig Rep.:Rig Email:
Operator:
Operator Rep.:Op. Rep Email:
Well Name:PTD #2220500 Sundry #322-560
Operation:Drilling:Workover:x Explor.:
Test:Initial:x Weekly:Bi-Weekly:Other:
Rams:250/3000 Annular:N/A Valves:250/3000 MASP:1980
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 1 B/S P Pit Level Indicators NA NA
#1 Rams 1 B/S P Flow Indicator NA NA
#2 Rams 1 Slip P Meth Gas Detector NA NA
#3 Rams 1 Pipe P H2S Gas Detector NA NA
#4 Rams 0 NA NA MS Misc 0 NA
#5 Rams 0 NA NA
#6 Rams 0 NA NA ACCUMULATOR SYSTEM:
Choke Ln. Valves 2 2"P Time/Pressure Test Result
HCR Valves 0 NA NA System Pressure (psi)2950 P
Kill Line Valves 2 2"P Pressure After Closure (psi)1625 P
Check Valve 1 2" 1502 P 200 psi Attained (sec)14 P
BOP Misc 3 EQ Ports P Full Pressure Attained (sec)53 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 17 P
Coiled Tubing Only:#2 Rams 18 P
Inside Reel valves 1 P #3 Rams 7 P
#4 Rams 9 P
Test Results #5 Rams 0 NA
#6 Rams 0 NA
Number of Failures:0 Test Time:2.0 HCR Choke 0 NA
Repair or replacement of equipment will be made within NA days. HCR Kill 0 NA
Remarks:
AOGCC Inspection
24 hr Notice YES Date/Time 10/4/22 14:46
Waived By
Test Start Date/Time:10/6/2022 17:00
(date)(time)Witness
Test Finish Date/Time:10/6/2022 19:00
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Jim Regg
Schlumberger
A push/pull test was performed on Slip rams
William Tietje
Hilcorp Alaska
Brad Gathman
BRU 233-23
Test Pressure (psi):
atietje@slb.com
brad.gathman@hilcorp.com
Form 10-424 (Revised 08/2022)2022-1006_BOP_SLB13_BRU_233-23
jbr
J. Regg; 11/15/2022
1
Regg, James B (OGC)
From:Rance Pederson - (C) <rpederson@hilcorp.com>
Sent:Saturday, September 24, 2022 9:07 PM
To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC); Wallace, Chris D (OGC)
Subject:BOPE Test Report
Attachments:MIT Hilcorp 147 09-24-22.xlsx; BRU 233-23 MIT-T and IA Chart_9-24-22.pdf
Please see the attached MIT form and chart for BRU 233 23.
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
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.
Submit to:
OPERATOR:
FIELD / UNIT / PAD:
DATE:
OPERATOR REP:
AOGCC REP:
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD 2220500 Type Inj N Tubing 0 3120 3120 3115 Type Test P
Packer TVD 2731 BBL Pump 1.2 IA 0 75 75 75 Interval I
Test psi 3000 BBL Return 1.2 OA 0 0 0 0 Result P
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD 2220500 Type Inj N Tubing 0 145 143 130 Type Test P
Packer TVD 2731 BBL Pump 0.7 IA 0 2580 2570 2550 Interval I
Test psi 2500 BBL Return 0.6 OA 0 0 0 0 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:
Hilcorp Alaska, LLC
Beluga River Field / Beluga River Unit / K Pad
Rance Pederson
09/24/22
Notes:4 1/2" tieback string and liner. ZXP liner top packer at 2731' tvd.
Notes:
Notes:
Notes:
BRU 233-23
BRU 233-23
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" x 4 1/2" inner annulus. ZXP liner top packer at 2731' tvd.
Notes:
Notes:
Form 10-426 (Revised 01/2017)2022-0924_MITP_BRU_233-23_2tests
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WŚŽŶĞ͗ϵϬϳͲϳϵϯͲϭϮϰϮ
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas
Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential
and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you
are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the
mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov.
&ƌŽŵ͗:ŽƐŚƵĂZŝůĞLJͲ;ͿфũƌŝůĞLJΛŚŝůĐŽƌƉ͘ĐŽŵх
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Hilcorp DSM: 907-283-1369
Cell: 907-252-1211
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CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas
Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential
and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you
are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the
mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov.
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Cell: 907-252-1211
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STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
*All BOPE reports are due to the agency within 5 days of testing*
SSu bm itt t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov
Rig Owner: Rig No.:147 DATE: 9/11/22
Rig Rep.: Rig Email:
Operator:
Operator Rep.: Op. Rep Email:
Well Name:PTD #2220500 Sundry #
Operation: Drilling: X Workover: Explor.:
Test: Initial: X Weekly: Bi-Weekly: Other:
Rams:250/3500 Annular:250/2500 Valves:250/3500 MASP:2231
MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES:
Test Result/Type Test Result Quantity Test Result
Housekeeping P Well Sign P Upper Kelly 1P
Permit On Location P Hazard Sec.P Lower Kelly 1P
Standing Order Posted P Misc.NA Ball Type 1P
Test Fluid Water Inside BOP 1P
FSV Misc 0NA
BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm
Stripper 0NATrip Tank PP
Annular Preventer 1 11''FP Pit Level Indicators PP
#1 Rams 1 2 7/8''P Flow Indicator PP
#2 Rams 1 Blind FP Meth Gas Detector PP
#3 Rams 1 4.5'' Solid Body FP H2S Gas Detector PP
#4 Rams 0NAMS Misc 0NA
#5 Rams 0NA
#6 Rams 0NAACCUMULATOR SYSTEM:
Choke Ln. Valves 1 3 1/8''P Time/Pressure Test Result
HCR Valves 2 2 1/16'' & 3 1/8''P System Pressure (psi)3200 P
Kill Line Valves 1 2 1/16''P Pressure After Closure (psi)1750 P
Check Valve 0NA200 psi Attained (sec)28 P
BOP Misc 0NAFull Pressure Attained (sec)93 P
Blind Switch Covers: All stations Yes
CHOKE MANIFOLD:Bottle Precharge:P
Quantity Test Result Nitgn. Bottles # & psi (Avg.): 4@2425 P
No. Valves 13 P ACC Misc 0NA
Manual Chokes 1P
Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result
CH Misc 0NA Annular Preventer 13 P
#1 Rams 4 P
Coiled Tubing Only:#2 Rams 4 P
Inside Reel valves 0NA #3 Rams 4 P
#4 Rams 0 NA
Test Results #5 Rams 0 NA
#6 Rams 0 NA
Number of Failures:3 Test Time:10.0 HCR Choke 2 P
Repair or replacement of equipment will be made within days. HCR Kill 2 P
Remarks:
AOGCC Inspection
24 hr Notice Yes Date/Time 9-8-2022 15:39
Waived By
Test Start Date/Time:9/11/2022 2:00
(date) (time)Witness
Test Finish Date/Time:9/11/2022 12:00
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Jim Regg
Hilcorp
Tested w/ 4.5'' Test jts / Quadco Testsed Gas Alarms, 3 FP Annular - Function Retest - Low Test, LPR Function Retest Low,
Blind Rams - Change Elements Retest
Kenneth Porterfield
Hilcorp
Josh Riley
BRU 233-23
Test Pressure (psi):
jriley@hilcorp.com
Form 10-424 (Revised 08/2022) 2022-0911_BOP_Hilcorp147_BRU_233-23
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Ě͘^ŚĂůůŽǁĞƐƚůůŽǁĂďůĞWĞƌĨdsсDW^Wͬ;Ϭ͘ϳϰϴͲϬ͘ϭͿсϭϵϴϬƉƐŝͬϬ ͘ϲϰϴсϯϬϱϱ͚ds
ϭϬ͘ZDK
ϭϭ͘dƵƌŶǁĞůůŽǀĞƌƚŽƉƌŽĚƵĐƚŝŽŶΘĨůŽǁƚĞƐƚǁĞůů
ƚƚĂĐŚŵĞŶƚƐ͗
ϭ͘ƐͲďƵŝůƚtĞůů^ĐŚĞŵĂƚŝĐ
Ϯ͘WƌŽƉŽƐĞĚtĞůů^ĐŚĞŵĂƚŝĐ
ϯ͘ŽŝůdƵďŝŶŐKWŝĂŐƌĂŵ
ϰ͘^ƚĂŶĚĂƌĚEŝƚƌŽŐĞŶKƉĞƌĂƚŝŽŶƐ
ϱ͘K'ZtKŚĂŶŐĞ&Žƌŵ
hƉĚĂƚĞĚďLJ&sZϬϵͲϬϳͲϮϬϮϮ
WZKWK^ ^, Dd/
ĞůƵŐĂZŝǀĞƌhŶŝƚ
ZhϮϯϯͲϮϯ;ϮϭϮͲϮϰd^dͿ
Wd͗ϮϮϮͲϬϱϬ
W/͗ ϱϬͲϮϴϯͲϮϬϭϯϲͲϬϭͲϬϬ
Wdсϳ͕ϯϵϯ͛ͬdsсϲ͕ϰϵϭ͛
dсϳ͕ϰϮϯ͛ͬdsсϲ͕ϱϲϱ͛
Z<ƚŽ'>сϭϴ͘ϱ͛
^/E' d/>
^ŝnjĞ dLJƉĞ tƚ 'ƌĂĚĞ ŽŶŶ͘ / dŽƉ ƚŵ
ϮϬ͟ ŽŶĚƵĐƚŽƌ ϭϱϰ͘ϭϵ yͲϲϱ tĞůĚ ϭϵ͘ϭϯ͟ ^ƵƌĨ ϭϬϴ͛
ϵͲϱͬϴΗ ^ƵƌĨƐŐ ϰϬ͘Ϭ >ͲϴϬ dD ϴ͘ϴϯϱ͟ ^ƵƌĨ Ϯ͕ϴϱϭ͛
ϳ͟ WƌŽĚƐŐ Ϯϲ͘Ϭ >ͲϴϬ dD ϲ͘Ϯϳϲ͟ ^ƵƌĨ ΕϮ͕ϴϴϬ͛
ϰͲϭͬϮΗ WƌŽĚ>Ŷƌ ϭϮ͘ϲ >ͲϴϬ :& >/KE ϯ͘ϵϱϴ͟ ΕϮ͕ϳϬϬ͛ ϳ͕ϰϮϯ
ϰͲϭͬϮΗ WƌŽĚdŝĞďĂĐŬ ϭϮ͘ϲ >ͲϴϬ :& >/KE ϯ͘ϵϱϴ͟ ^ƵƌĨ Ϯ͕ϳϬϬ͛
Ϯ
ϮϬ͟
ϵͲϱͬϴ͟
ϭϮͲϭͬϰ͟
ŚŽůĞ
ϰͲϭͬϮ͟
: t >Zz d/>
EŽ͘ ĞƉƚŚ / K /ƚĞŵ
ϭ Ϯ͕ϵϬϬ͛ Eͬ ϲ͘Ϯϳϲ͟ tŚŝƉƐƚŽĐŬ
Ϯ Ϯ͕ϳϬϬ͛ ϰ͘ϴϳϱ͟ ϱ͘ϵϲϬ͟ >ŝŶĞƌŚĂŶŐĞƌͬ>dWƐƐĞŵďůLJ
ϯ Ϯ͕ϳϬϬ͛ ϰ͘ϳϵϬ͟ ϱ͘ϳϭϬ͟ ^ĞĂů^ƚĞŵ
KW E,K> ͬ D Ed d/>
ϵͲϱͬϴ͟ dKΛ^ƵƌĨĂĐĞ;KƌŝŐŝŶĂůZhϮϭϮͲϮϰdͿ
ϳΗ dKΛϮ͕ϴϲϬ͛;KƌŝŐŝŶĂůZhϮϭϮͲϮϰdͿ
ϯͲϭͬϮ͟ Ɛƚ͘dKΛdK>;ϰϬйĞdžĐĞƐƐͿ
ϲͲϭͬϴ͟
ŚŽůĞ
ϯ
ϰ
ϴͲϭͬϮ͟
ŚŽůĞ
ϳ͟
ϭ
ZhϮϭϮͲϮϰd
;ďĂŶĚŽŶĞĚͿ
hƉĚĂƚĞĚďLJ͗:>>ϬϵͬϮϬͬϮϮ
WZKWK^
ĞůƵŐĂZŝǀĞƌhŶŝƚ
ZhϮϯϯͲϮϯ;ϮϭϮͲϮϰd^dͿ
Wd͗ϮϮϮͲϬϱϬ
W/͗ ϱϬͲϮϴϯͲϮϬϭϯϲͲϬϭͲϬϬ
Wdс ϳ͕ϰϬϭ͛ ͬ dsс ϲ͕ϰϴϮ͛
dсϳ͕ϰϰϲ͛ͬdsсϲ͕ϱϭϲ͛
Z<ƚŽ'>сϭϴ͘ϱ͛
W Z&KZd/KE d/>
ŽŶĞ dŽƉ
;DͿ
ƚŵ
;DͿ
dŽƉ
;dsͿ
ƚŵ
;dsͿ &d ĂƚĞ ^ƚĂƚƵƐ
, цϱ͕ϱϳϵ͛цϱ͕ϱϴϮ͛цϱ͕ϭϬϯ͛цϱ͕ϭϬϲ͛цϯ͛&ƵƚƵƌĞ WƌŽƉŽƐĞĚ
, цϱ͕ϲϬϯ͛цϱ͕ϲϭϬ͛цϱ͕ϭϮϯ͛цϱ͕ϭϯϬ͛цϳ͛&ƵƚƵƌĞ WƌŽƉŽƐĞĚ
,ϭ цϱ͕ϲϰϲ͛цϱ͕ϲϱϳ͛цϱ͕ϭϱϲ͛цϱ͕ϭϲϳ͛цϭϭ͛&ƵƚƵƌĞ WƌŽƉŽƐĞĚ
,Ϯ цϱ͕ϲϲϮ͛цϱ͕ϲϲϵ͛цϱ͕ϭϲϴ͛цϱ͕ϭϳϱ͛цϳ͛&ƵƚƵƌĞ WƌŽƉŽƐĞĚ
,Ϯ цϱ͕ϲϴϮ͛цϱ͕ϳϬϳ͛цϱ͕ϭϴϮ͛цϱ͕ϮϬϳ͛цϮϱ͛&ƵƚƵƌĞ WƌŽƉŽƐĞĚ
,ϯ цϱ͕ϳϰϬ͛цϱ͕ϳϱϯ͛цϱ͕ϮϮϳ͛цϱ͕ϮϰϬ͛цϭϯ͛&ƵƚƵƌĞ WƌŽƉŽƐĞĚ
,ϰ цϱ͕ϳϲϯ͛цϱ͕ϳϲϴ͛цϱ͕Ϯϰϰ͛цϱ͕Ϯϰϵ͛цϱ͛&ƵƚƵƌĞ WƌŽƉŽƐĞĚ
,ϰ цϱ͕ϳϵϭ͛цϱ͕ϳϵϳ͛цϱ͕Ϯϲϲ͛цϱ͕ϮϳϮ͛цϲ͛&ƵƚƵƌĞ WƌŽƉŽƐĞĚ
,ϴ цϱ͕ϵϮϮ͛цϱ͕ϵϯϯ͛цϱ͕ϯϲϲ͛цϱ͕ϯϳϳ͛цϭϭ͛&ƵƚƵƌĞ WƌŽƉŽƐĞĚ
,ϴ цϱ͕ϵϰϳ͛цϱ͕ϵϱϰ͛цϱ͕ϯϴϲ͛цϱ͕ϯϵϯ͛цϳ͛&ƵƚƵƌĞ WƌŽƉŽƐĞĚ
,ϵ цϱ͕ϵϳϬ͛цϱ͕ϵϴϱ͛цϱ͕ϰϬϯ͛цϱ͕ϰϭϴ͛цϭϱ͛&ƵƚƵƌĞ WƌŽƉŽƐĞĚ
,ϭϬ цϲ͕Ϭϭϰ͛цϲ͕Ϭϱϱ͛цϱ͕ϰϯϴ͛цϱ͕ϰϳϵ͛цϰϭ͛&ƵƚƵƌĞ WƌŽƉŽƐĞĚ
,ϭϯ цϲ͕ϭϴϱ͛цϲ͕ϮϰϬ͛цϱ͕ϱϲϲ͛цϱ͕ϲϮϭ͛цϱϱ͛&ƵƚƵƌĞ WƌŽƉŽƐĞĚ
,ϭϱ цϲ͕ϯϲϵ͛цϲ͕ϯϵϮ͛цϱ͕ϳϬϰ͛цϱ͕ϳϮϳ͛цϮϯ͛&ƵƚƵƌĞ WƌŽƉŽƐĞĚ
/ цϲ͕ϰϴϯ͛цϲ͕ϰϵϳ͛цϱ͕ϳϵϭ͛цϱ͕ϴϬϱ͛цϭϰ͛&ƵƚƵƌĞ WƌŽƉŽƐĞĚ
/ϭ цϲ͕ϱϮϰ͛цϲ͕ϱϰϲ͛цϱ͕ϴϮϯ͛цϱ͕ϴϰϱ͛цϮϮ͛&ƵƚƵƌĞ WƌŽƉŽƐĞĚ
KW E,K> ͬ D Ed d/>
ϵͲϱͬϴ͟ dKΛ^ƵƌĨĂĐĞ;KƌŝŐŝŶĂůZhϮϭϮͲϮϰdͿ
ϳΗ dKΛϮ͕ϴϲϬ͛;KƌŝŐŝŶĂůZhϮϭϮͲϮϰdͿ
ϯͲϭͬϮ͟ Ɛƚ͘dKΛdK>;ϰϬйĞdžĐĞƐƐͿ
^/E' d/>
^ŝnjĞ dLJƉĞ tƚ 'ƌĂĚĞ ŽŶŶ͘ / dŽƉ ƚŵ
ϮϬ͟ ŽŶĚƵĐƚŽƌ ϭϱϰ͘ϭϵ yͲϲϱ tĞůĚ ϭϵ͘ϭϯ͟ ^ƵƌĨ ϭϬϴ͛
ϵͲϱͬϴΗ ^ƵƌĨƐŐ ϰϬ͘Ϭ >ͲϴϬ dD ϴ͘ϴϯϱ͟ ^ƵƌĨ Ϯ͕ϴϱϭ͛
ϳ͟ WƌŽĚƐŐ Ϯϲ͘Ϭ >ͲϴϬ dD ϲ͘Ϯϳϲ͟ ^ƵƌĨ
Ϯ͕ϵϬϳ
;dKtͿ
ϰͲϭͬϮΗ WƌŽĚ>Ŷƌ ϭϮ͘ϲ >ͲϴϬ :& >/KE ϯ͘ϵϱϴ͟цϮ͕ϳϭϬ͛ цϳ͕ϰϰϲ
ϰͲϭͬϮΗ WƌŽĚdŝĞďĂĐŬ ϭϮ͘ϲ >ͲϴϬ :& >/KE ϯ͘ϵϱϴ͟ ^ƵƌĨ цϮ͕ϳϭϬ͛
ϮϬ͟
ϵͲϱͬϴ͟
ϭϮͲϭͬϰ͟
ŚŽůĞ
ϰͲϭͬϮ͟
: t >Zz d/>
EŽ͘ ĞƉƚŚ / K /ƚĞŵ
ϭ цϮ͕ϳϭϬ ϰ͘ϴϳϱ͟ ϱ͘ϵϲϬ͟
&ůĞdžͲ>ŽĐŬs>ŝŶĞƌ,ĂŶŐĞƌ͕,ZͲ ,yW͕ϱΗdžϳΗ>ŝŶĞƌ
dŽƉWĂĐŬĞƌǁͬϱ͘ϮϱΗWZ
ϲͲϭͬϴ͟
ŚŽůĞ
ϭ
ϰ
ϴͲϭͬϮ͟
ŚŽůĞ
ϳ͟
ZhϮϭϮͲϮϰd
;ďĂŶĚŽŶĞĚͿ
Ğů,ʹ/ϭ
^dEZt >>WZK hZ
E/dZK' EKW Zd/KE^
ϭϮͬϬϴͬϮϬϭϱ &/E>ǀϭ WĂŐĞϭŽĨϭ
ϭ͘Ϳ D/ZhEŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚĂŶĚ>ŝƋƵŝĚEŝƚƌŽŐĞŶdƌĂŶƐƉŽƌƚ͘
Ϯ͘Ϳ EŽƚŝĨLJWĂĚKƉĞƌĂƚŽƌŽĨƵƉĐŽŵŝŶŐEŝƚƌŽŐĞŶŽƉĞƌĂƚŝŽŶƐ͘
ϯ͘Ϳ WĞƌĨŽƌŵWƌĞͲ:Žď^ĂĨĞƚLJDĞĞƚŝŶŐ͘ZĞǀŝĞǁEŝƚƌŽŐĞŶǀĞŶĚŽƌƐƚĂŶĚĂƌĚŽƉĞƌĂƚŝŶŐƉƌŽĐĞĚƵƌĞƐĂŶĚ
ĂƉƉƌŽƉƌŝĂƚĞ^ĂĨĞƚLJĂƚĂ^ŚĞĞƚƐ;ĨŽƌŵĞƌůLJD^^Ϳ͘
ϰ͘Ϳ ŽĐƵŵĞŶƚ ŚĂnjĂƌĚƐ ĂŶĚ ŵŝƚŝŐĂƚŝŽŶ ŵĞĂƐƵƌĞƐ ĂŶĚ ĐŽŶĨŝƌŵ ĨůŽǁ ƉĂƚŚƐ͘ /ŶĐůƵĚĞ ƌĞǀŝĞǁ ŽŶ
ĂƐƉŚLJdžŝĂƚŝŽŶĐĂƵƐĞĚ ďLJ ŶŝƚƌŽŐĞŶĚŝƐƉůĂĐŝŶŐŽdžLJŐĞŶ͘DŝƚŝŐĂƚŝŽŶŵĞĂƐƵƌĞƐŝŶĐůƵĚĞĂƉƉƌŽƉƌŝĂƚĞ
ƌŽƵƚŝŶŐŽĨĨůŽǁůŝŶĞƐ͕ĂĚĞƋƵĂƚĞǀĞŶƚŝŶŐĂŶĚĂƚŵŽƐƉŚĞƌŝĐŵŽŶŝƚŽƌŝŶŐ͘
ϱ͘Ϳ ^ƉŽƚWƵŵƉŝŶŐhŶŝƚĂŶĚdƌĂŶƐƉŽƌƚ͘ŽŶĨŝƌŵůŝƋƵŝĚEϮǀŽůƵŵĞƐŝŶƚƌĂŶƐƉŽƌƚ͘
ϲ͘Ϳ ZŝŐƵƉůŝŶĞƐĨƌŽŵƚŚĞEŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚƚŽƚŚĞǁĞůůĂŶĚƌĞƚƵƌŶƐƚĂŶŬ͘^ĞĐƵƌĞůŝŶĞƐǁŝƚŚǁŚŝƉ
ĐŚĞĐŬƐ͘
ϳ͘Ϳ WůĂĐĞ ƐŝŐŶƐ ĂŶĚ ƉůĂĐĂƌĚƐ ǁĂƌŶŝŶŐ ŽĨ ŚŝŐŚ ƉƌĞƐƐƵƌĞ ĂŶĚ ŶŝƚƌŽŐĞŶ ŽƉĞƌĂƚŝŽŶƐ Ăƚ ĂƌĞĂƐ ǁŚĞƌĞ
EŝƚƌŽŐĞŶŵĂLJĂĐĐƵŵƵůĂƚĞŽƌďĞƌĞůĞĂƐĞĚ͘
ϴ͘Ϳ WůĂĐĞƉƌĞƐƐƵƌĞŐĂƵŐĞƐĚŽǁŶƐƚƌĞĂŵŽĨůŝƋƵŝĚĂŶĚŶŝƚƌŽŐĞŶƉƵŵƉƐƚŽĂĚĞƋƵĂƚĞůLJŵĞĂƐƵƌĞƚƵďŝŶŐ
ĂŶĚĐĂƐŝŶŐƉƌĞƐƐƵƌĞƐ͘
ϵ͘Ϳ WůĂĐĞƉƌĞƐƐƵƌĞŐĂƵŐĞƐƵƉƐƚƌĞĂŵĂŶĚĚŽǁŶƐƚƌĞĂŵŽĨĂŶLJĐŚĞĐŬǀĂůǀĞƐ͘
ϭϬ͘Ϳ tĞůůƐŝƚĞDĂŶĂŐĞƌƐŚĂůůǁĂůŬĚŽǁŶǀĂůǀĞĂůŝŐŶŵĞŶƚƐĂŶĚĞŶƐƵƌĞǀĂůǀĞƉŽƐŝƚŝŽŶŝƐĐŽƌƌĞĐƚ͘
ϭϭ͘Ϳ ŶƐƵƌĞƉŽƌƚĂďůĞϰͲŐĂƐĚĞƚĞĐƚŝŽŶĞƋƵŝƉŵĞŶƚŝƐŽŶƐŝƚĞ͕ĐĂůŝďƌĂƚĞĚ͕ĂŶĚďƵŵƉƚĞƐƚĞĚƉƌŽƉĞƌůLJƚŽ
ĚĞƚĞĐƚ> >ͬ,Ϯ^ͬKϮͬKϮůĞǀĞůƐ͘ ŶƐƵƌĞEŝƚƌŽŐĞŶǀĞŶĚŽƌŚĂƐĂǁŽƌŬŝŶŐĂŶĚĐĂůŝďƌĂƚĞĚĚĞƚĞĐƚŽƌĂƐ
ǁĞůůƚŚĂƚŵĞĂƐƵƌĞƐKϮůĞǀĞůƐ͘
ϭϮ͘Ϳ WƌĞƐƐƵƌĞƚĞƐƚůŝŶĞƐƵƉƐƚƌĞĂŵŽĨǁĞůůƚŽĂƉƉƌŽǀĞĚƐƵŶĚƌLJƉƌĞƐƐƵƌĞŽƌDW^W;DĂdžŝŵƵŵWŽƚĞŶƚŝĂů
^ƵƌĨĂĐĞWƌĞƐƐƵƌĞͿ͕ǁŚŝĐŚĞǀĞƌŝƐŚŝŐŚĞƌ͘dĞƐƚůŝŶĞƐĚŽǁŶƐƚƌĞĂŵŽĨǁĞůů;ĨƌŽŵǁĞůůƚŽƌĞƚƵƌŶƐƚĂŶŬͿ
ƚŽϭ͕ϱϬϬƉƐŝ͘WĞƌĨŽƌŵǀŝƐƵĂůŝŶƐƉĞĐƚŝŽŶĨŽƌĂŶLJůĞĂŬƐ͘
ϭϯ͘Ϳ ůĞĞĚŽĨĨƚĞƐƚƉƌĞƐƐƵƌĞĂŶĚƉƌĞƉĂƌĞĨŽƌƉƵŵƉŝŶŐŶŝƚƌŽŐĞŶ͘
ϭϰ͘Ϳ WƵŵƉŶŝƚƌŽŐĞŶĂƚĚĞƐŝƌĞĚƌĂƚĞ͕ŵŽŶŝƚŽƌŝŶŐƌĂƚĞ;^&DͿĂŶĚƉƌĞƐƐƵƌĞ;W^/Ϳ͘ůůŶŝƚƌŽŐĞŶƌĞƚƵƌŶƐ
ĂƌĞƚŽďĞƌŽƵƚĞĚƚŽƚŚĞƌĞƚƵƌŶƐƚĂŶŬ͘
ϭϱ͘Ϳ tŚĞŶĨŝŶĂůŶŝƚƌŽŐĞŶǀŽůƵŵĞŚĂƐďĞĞŶĂĐŚŝĞǀĞĚ͕ŝƐŽůĂƚĞǁĞůůĨƌŽŵEŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚĂŶĚ
ďůĞĞĚĚŽǁŶůŝŶĞƐďĞƚǁĞĞŶǁĞůůĂŶĚEŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚ͘
ϭϲ͘Ϳ KŶĐĞLJŽƵŚĂǀĞĐŽŶĨŝƌŵĞĚůŝŶĞƐĂƌĞďůĞĚĚŽǁŶ͕ŶŽƚƌĂƉƉĞĚƉƌĞƐƐƵƌĞĞdžŝƐƚƐ͕ĂŶĚŶŽŶŝƚƌŽŐĞŶŚĂƐ
ĂĐĐƵŵƵůĂƚĞĚďĞŐŝŶƌŝŐĚŽǁŶŽĨůŝŶĞƐĨƌŽŵƚŚĞEŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚ͘
ϭϳ͘Ϳ &ŝŶĂůŝnjĞũŽďůŽŐĂŶĚĚŝƐĐƵƐƐŽƉĞƌĂƚŝŽŶƐǁŝƚŚtĞůůƐŝƚĞDĂŶĂŐĞƌ͘ŽĐƵŵĞŶƚĂŶLJůĞƐƐŽŶƐůĞĂƌŶĞĚ
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333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
Monty M. Myers
Drilling Manager
Hilcorp Alaska, LLC
3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Re: Beluga River Field, Beluga River, Sterling-Beluga Gas Pool, BRU 233-23
Hilcorp Alaska, LLC
Permit to Drill Number: 222-050
Surface Location: 2054' FNL, 144' FWL, Sec 24, T13N, R10W, SM, AK
Bottomhole Location: 1650' FSL, 1538' FEL, Sec 23, T13N, R10W, SM, AK
Dear Mr. Myers:
Enclosed is the approved application for the permit to drill the above referenced well.
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071,composite curves for well logs
run must be submitted to the AOGCCwithin 90 days after completion, suspension or abandonment
of this well.
This permit to drill does not exempt you from obtaining additional permits or an approval required
by law from other governmental agencies and does not authorize conducting drilling operations
until all other required permits and approvals have been issued. In addition, the AOGCC reserves
the right to withdraw the permit in the event it was erroneously issued.
Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska
Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply
with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code,
or an AOGCC order, or the terms and conditions of this permit may result in the revocation or
suspension of the permit.
Sincerely,
Jeremy M. Price
Chair
DATED this ___ day of May, 2022.
Jeremy
Price
Digitally signed by
Jeremy Price
Date: 2022.05.25
10:47:09 -08'00'
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Date: 2022.05.25 10:46:21
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Vertical Section at 227.00° (550 usft/in)
Beluga J4 TD_wp06
3000
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4000
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6565
BRU 212-24T
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3 1/2" Liner
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BRU 233-23 wp06
KOP: 12.7º/100' : 2900' MD, 2880.43'TVD : 30° LT TF
End Dir : 2917' MD, 2897.38' TVD
Start Dir 4º/100' : 2937' MD, 2917.29'TVD
End Dir : 3997.96' MD, 3896.95' TVD
Start Dir 3º/100' : 6880.96' MD, 6105.46'TVD
Total Depth : 7423.97' MD, 6565.14' TV
BRU_ST_A1_COAL
STERLING_B
STERLING_C
BELUGA_D
BELUGA_E
BELUGA_F
BELUGA_G
BELUGA_H
BELUGA_I
BRU_BELUGA_J
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: BRU 212-24T
Ground Level: 74.00
+N/-S +E/-W Northing Easting Latitude Longitude
0.00 0.00 2633581.20 323477.95 61° 12' 16.448 N 151° 0' 3.320 W
SURVEY PROGRAM
Date: 2022-04-20T00:00:00 Validated: Yes Version:
Depth From Depth To Survey/Plan Tool
142.40 2807.82 BRU 212-24T (R100) (BRU 212-24T) 3_MWD+AX+Sag
2905.48 2900.00 BRU 212-24T (R200) (BRU 212-24T) 3_MWD+AX+Sag
2900.00 7423.97 BRU 233-23 wp06 (BRU 233-23) 3_MWD+AX+Sag
FORMATION TOP DETAILS
TVDPath TVDssPath MDPath Formation
3260.50 3168.00 3283.18 BRU_ST_A1_COAL
3439.50 3347.00 3469.17 STERLING_B
3585.50 3493.00 3627.00 STERLING_C
3804.50 3712.00 3881.10 BELUGA_D
4005.50 3913.00 4139.65 BELUGA_E
4323.50 4231.00 4554.77 BELUGA_F
4754.50 4662.00 5117.40 BELUGA_G
5072.50 4980.00 5532.52 BELUGA_H
5747.50 5655.00 6413.67 BELUGA_I
6340.50 6248.00 7170.51 BRU_BELUGA_J
REFERENCE INFORMATION
Co-ordinate (N/E) Reference:Well BRU 212-24T, True North
Vertical (TVD) Reference:BRU 233-23 @ 92.50usft
Measured Depth Reference:BRU 233-23 @ 92.50usft
Calculation Method: Minimum Curvature
Project:Beluga River
Site:BRU K-Pad
Well:BRU 212-24T
Wellbore:BRU 233-23
Design:BRU 233-23 wp06
CASING DETAILS
TVD TVDSS MD Size Name
6565.14 6472.64 7423.97 3-1/2 3 1/2" Liner
SECTION DETAILS
Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation
1 2900.00 3.56 348.44 2880.43 255.92 -21.97 0.00 0.00 -158.47 KOP: 12.7º/100' : 2900' MD, 2880.43'TVD : 30° LT TF
2 2917.00 5.44 334.65 2897.38 257.17 -22.41 12.70 -30.00 -159.00 End Dir : 2917' MD, 2897.38' TVD
3 2937.00 5.44 334.65 2917.29 258.89 -23.22 0.00 0.00 -159.58 Start Dir 4º/100' : 2937' MD, 2917.29'TVD
4 3997.96 40.00 220.84 3896.95 36.07 -279.56 4.00 -119.37 179.86 End Dir : 3997.96' MD, 3896.95' TVD
5 6880.96 40.00 220.84 6105.46 -1365.92 -1491.43 0.00 0.00 2022.32 Start Dir 3º/100' : 6880.96' MD, 6105.46'TVD
6 7423.97 23.71 220.84 6565.14 -1582.00 -1678.21 3.00 180.00 2306.29 Beluga J4 TD_wp06 Total Depth : 7423.97' MD, 6565.14' TVD
-1800-1600-1400-1200-1000-800-600-400-2000200South(-)/North(+) (300 usft/in)-2200 -2000 -1800 -1600 -1400 -1200 -1000 -800 -600 -400 -200 0 200 400West(-)/East(+) (300 usft/in)Beluga J4 TD_wp06BRU 212-24T9 5/8"3 1/2" Liner2505007501000125015001750200022502500275030003 2 5 0
35003750400042504500475050005250550057506000625065006565BRU 233-23 wp06KOP: 12.7º/100' : 2900' MD, 2880.43'TVD : 30° LT TFEnd Dir : 2917' MD, 2897.38' TVDStart Dir 4º/100' : 2937' MD, 2917.29'TVDEnd Dir : 3997.96' MD, 3896.95' TVDStart Dir 3º/100' : 6880.96' MD, 6105.46'TVDTotal Depth : 7423.97' MD, 6565.14' TVDProject: Beluga RiverSite: BRU K-PadWell: BRU 212-24TWellbore: BRU 233-23Plan: BRU 233-23 wp06WELL DETAILS: BRU 212-24TGround Level: 74.00+N/-S+E/-WNorthingEasting LatitudeLongitude0.00 0.002633581.20 323477.95 61° 12' 16.448 N 151° 0' 3.320 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well BRU 212-24T, True NorthVertical (TVD) Reference:BRU 233-23 @ 92.50usftMeasured Depth Reference:BRU 233-23 @ 92.50usftCalculation Method:Minimum CurvatureCASING DETAILSTVD TVDSS MD Size Name6565.14 6472.64 7423.97 3-1/2 3 1/2" Liner
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0.001.002.003.004.00Separation Factor3025 3300 3575 3850 4125 4400 4675 4950 5225 5500 5775 6050 6325 6600 6875 7150 7425 7700 7975 8250Measured Depth (550 usft/in)BRU 212-24BRU 212-24TNo-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.NOERRORSWELL DETAILS:BRU 212-24T NAD 1927 (NADCON CONUS)Alaska Zone 04Ground Level: 74.00+N/-S +E/-W Northing EastingLatitudeLongitude0.000.002633581.20323477.9561° 12' 16.448 N 151° 0' 3.320 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well BRU 212-24T, True NorthVertical (TVD) Reference: BRU 233-23 @ 92.50usftMeasured Depth Reference:BRU 233-23 @ 92.50usftCalculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2022-04-20T00:00:00 Validated: Yes Version: Depth From Depth ToSurvey/PlanTool142.40 2807.82 BRU 212-24T (R100) (BRU 212-24T) 3_MWD+AX+Sag2905.48 2900.00 BRU 212-24T (R200) (BRU 212-24T) 3_MWD+AX+Sag2900.00 3300.00 BRU 233-23 wp06 (BRU 233-23) 3_MWD_Interp Azi+Sag3300.00 7423.97 BRU 233-23 wp06 (BRU 233-23) 3_MWD+AX+Sag0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)3025 3300 3575 3850 4125 4400 4675 4950 5225 5500 5775 6050 6325 6600 6875 7150 7425 7700 7975 8250Measured Depth (550 usft/in)BRU 212-24BRU 212-24TNO GLOBAL FILTER: Using user defined selection & filtering criteria2900.00 To 7424.31Project: Beluga RiverSite: BRU K-PadWell: BRU 212-24TWellbore: BRU 233-23Plan: BRU 233-23 wp06CASING DETAILSTVD TVDSS MD Size Name6565.14 6472.64 7423.97 3-1/2 3 1/2" Liner
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