Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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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: Install Cap String
2.Operator Name:4. Current Well Class: 5. Permit to Drill Number:
Exploratory Development
3. Address:Stratigraphic Service
6. API Number:
7. If perforating:8. Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool?
Yes No
9. Property Designation (Lease Number):10. Field: Current Pools:
11.
Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD):
9,940'N/A
Casing Collapse
Conductor
Surface 1,540psi
Intermediate 6,620psi
Intermediate 5,300psi
Intermediate Lnr 4,790psi
Production Lnr 7,500psi
Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft):
12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work:
Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service
14. Estimated Date for 15. Well Status after proposed work:
Commencing Operations:OIL WINJ WDSPL Suspended
16. Verbal Approval:Date: GAS WAG GSTOR SPLUG
AOGCC Representative: GINJ Op Shutdown Abandoned
Contact Name:
Contact Email:
Contact Phone:
Authorized Title:
Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number:
Plug Integrity BOP Test Mechanical Integrity Test Location Clearance
Other Conditions of Approval:
Post Initial Injection MIT Req'd? Yes No
APPROVED BY
Approved by: COMMISSIONER THE AOGCC Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
Suspension Expiration Date:
12.6# / L-80
TVD Burst
6,229'
142'
Kenai C.L.U.Beluga Gas
chelgeson@hilcorp.com
907-777-8405
Noel Nocas, Operations Manager 907-564-5278
Perforation Depth TVD (ft):
Subsequent Form Required:
Will perfs require a spacing exception due to property boundaries?
MPSP (psi):Plugs (MD):
17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval.
Authorized Name and
Digital Signature with Date:
Tubing Size:
PRESENT WELL CONDITION SUMMARY
Chad Helgeson, Operations Engineer
Proposed Pools:
3800 Centerpoint Drive, Suite 1400
Anchorage, Alaska 99503
AOGCC USE ONLY
8,430psi
Tubing Grade:Tubing MD (ft):
252'
Length
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
Fee-Private, Fee-Hilcorp (formerly ADL 060569) ADL 324602
222-092
50-133-20474-02-00
Hilcorp Alaska, LLC
Size
2,970'
9-5/8"5,315'
1,212'
MD
142'
7,930psi
2,571'
5,355'
2,970'
1,212'
6,890psi
1,200'
April 26, 2024
9,938'3,724'
4-1/2"
8,422'
142'20"
6,685'
Perforation Depth MD (ft):
6,527'
Cannery Loop Unit (CLU) 05RD2CO 231A
Same
5,506'7-5/8"
~350 psi 8,710; 9,678'
9,440psi
3,090psi
SLZXP & ZXP Liner Top Pkrs; S-5 TRSSSV 6,214' MD/5,053'TVD; 6,433' MD/5,663' TVD; 141' MD/TVD
8,424'8,710'7,309'
13-3/8"
9-5/8"
See Attached Schematic
4-1/2"
See Attached Schematic
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Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
By Samantha Coldiron at 9:17 am, Apr 15, 2024
324-215
Digitally signed by Noel
Nocas (4361)
DN: cn=Noel Nocas (4361)
Date: 2024.04.12 17:42:14 -
08'00'
Noel Nocas
(4361)
SFD 4/15/2024 DSR-4/23/24BJM 4/15/24
10-404
*&:
Brett W.
Huber, Sr.
Digitally signed by Brett W.
Huber, Sr.
Date: 2024.04.24 10:23:48
-08'00'04/24/24
RBDMS JSB 042624
Cap String
Well: CLU 05RD2
Well Name: CLU 05RD2 API Number: 50-133-20474-02-00
Current Status: Gas Producer Permit to Drill Number: 222-092
First Call Engineer: Chad Helgeson (907) 777-8405 (O)
Second Call Engineer: Jake Flora (907) 777-8442 (O) (720) 988-5375 (C)
Current flowing BHP: 850 psi @ 7336 TVD Based on CLU-5RD2 PLT Data 11/22/22
Maximum Potential Surface Pressure: ~350 psi Max SI buildup in last 2 years
Well Status: Gas producer making 762 mcfd, 16 bwpd @ 68psi
Brief Well Summary
CLU 5RD2 was drilled in 2022. Currently production has slid below unloading rate and has become more erratic
and dropping soap sticks several times a day to unload the well.
The purpose of this work/sundry is to set a 3/8” stainless steel capillary string to inject liquid soap downhole and
keep the well from slugging as the well tapers out below unloading rate.
The TRSSSV will be bypassed when the Capillary string is installed which is allowed per 20AAC25.265(c)(4).
Wellbore Condition
x Well TRSSSV will be hydraulically locked open.
x Minimum ID is 3.813” Profile inside SSSV
x Maximum Angle is 48.54° @ 4,121’ MD
x SSSV at 141’
x Liner/seal assembly @ 6,214’
x CINGSA Pool bottom – 6,304’ MD (5,140’ TVD)
Procedure
1. RU Slickline, PT lubricator to 2500 psi
2. RIH with GR and tag bottom
3. Run PT Survey to determine gas influx and fluid level
4. RDMO SL
5. Block open/bypass the TRSSSV at surface
6. RU Cap String Truck
7. Stab 3/8” capillary line into wellhead pack-off assembly. Make up BHA components. Install pack-off
and pressure test against swab valve to 1500 psi
8. RIH with 3/8” capillary string to ±8400’ MD.
a. Set cap string as deep as practical per SL survey results
9. Install slips and connect tubing to chemical injection pump
10. Set spool of remaining line near well
11. RD cap string Unit, and turn well over to production.
Attachments:
1. Proposed Schematic
Updated by CAH 4-11-24
PROPOSED
Cannery Loop Unit
CLU-05RD2
PTD: 222-092
API: 50-133-20474-02-00
PBTD = 9,851’ / TVD = 8,343’
TD = 9,940’ / TVD = 8,424’
RKB to GL = 18.12’
Cingsa
From 6071’
- 6295’ MD
CASING & TUBING DETAIL
Size Type Wt Grade Conn. ID Top Btm
20” Conductor 129 - Weld - Surf 142’
13-3/8" Surf Csg 61.0 K-55 BTC 12.515” Surf 2,970’
9-5/8” Intermediate Csg 53.5 L-80 BTC 8.535” Surf 1,212’
9-5/8” Intermediate Csg 47 P-110 BTC 8.681” 1,212’ 6,527’
7-5/8” Intermediate Lnr 29.7# L-80 Hyd 521 6.875” 6,433’ 6,685’
4-1/2" Prod Lnr 12.6 L-80 DWC/C 3.958” 6,214’ 9,938’
4-1/2” Tubing 12.6 L-80 DWC/C 3.958” Surf 6,229’
3/8” Capillary String 306 SS NA Surf ±8600’
2
20”
13-3/8”
16”
hole
4-1/2”
JEWELRY DETAIL
No. Depth ID OD Item
1 141 3.813” 6.600” Baker S-5 TRSSSV
2 6,214’ 7.37” 7”x 9-5/8” SLZXP HRDE Liner top packer, w/ 7.37”
PBR
3 6,433’ 3.958” 6.875” 7-5/8” ZXP Liner Top Packer
4 8,710’ 3.958” CIBP set 10/20/22
5 9,678’ - 3.958” CIBP w/ 26’ of cement 10/5/22, tagged 9,667’ CTM
OPEN HOLE / CEMENT DETAIL
13-3/8” Fully cemented with 140bbls back to surface (CLU-05 in 1996)
9-5/8”
12-1/4” hole: Pumped from 9178’ MD. 850sxs lead (375bbls) and 1069 sxs
(222bbls) tail (CLU-05 in 1996) 11/19/96 USIT shows 9-5/8” cemented up to at
least 2800’ MD (stopped logging there)
7-5/8”
8-1/2” hole: Cemented with 102.7bbls 15.3ppg class G. had losses and got no
cement back to surface. 9/24/20 SCMT shows good cement up to at least 6,525
MD (behind tubing above that)
4-1/2” 6-3/4” hole: Lead - 250 sx / 12.5 ppg / 90 bbls Tail - 185 sx / 15.3 ppg / 39 bbls TOC
6,700’ MD – CBL 9/27/22
4
9-5/8”
1
CLU-05RD
(Abandoned)
Window @
6,666’
6-3/4”
hole
7-5/8”
3
Squeezed perfs
7/22/22
PERFORATION DETAIL
Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status
LB 7,880' 7,898' 6,565' 6,581' 18' 11/08/22 Open
LB1 7,921' 7,927' 6,602' 6,607' 6' 11/08/22 Open
LB1C Upper 7,984' 7,993' 6,658' 6,666' 9' 11/08/22 Open
LB1G Upper 8,162' 8,177' 6,816' 6,830' 15' 11/08/22 Open
LB1G Lower 8,186' 8,204' 6,838' 6,854' 18' 11/08/22 Open
LB2 Lower 8,265' 8,282' 6,908' 6,923' 17' 11/08/22 Open
LB2C Upper 8,382' 8,402' 7,013' 7,031' 20' 11/08/22 Open
LB2C Lower 8,414' 8,424' 7,042' 7,051' 20' 11/07/22 Open
LB2D Upper 8,438' 8,452' 7,064' 7,076' 14' 11/01/22 Open
LB2E Lower 8,576' 8,593' 7,188' 7,204' 17' 11/01/22 Open
LB Upper 8,597' 8,606' 7,207' 7,215' 9' 11/01/22 Open
LB3A Upper 8,643' 8,648' 7,249' 7,253' 5' 11/01/22 Open
LB1B Lower 7,952' 7,958' 6,629' 6,635' 6' 10/27/22 Open
LB1B 7,969' 7,974' 6,644' 6,649' 5' 10/28/22 Open
LB1F Upper 8,076' 8,082' 6,740' 6,745' 6' 10/27/22 Open
LB1F Mid 8,094' 8,119' 6,756' 6,778' 26' 10/27/22 Open
LB1F Lower 8,128' 8,140' 6,786' 6,797' 12' 10/27/22 Open
LB2B 8,328' 8,348' 6,964' 6,982' 20' 10/27/22 Open
LB3A Lower 8,668' 8,678’ 7,271' 7,280' 10’ 10/20/22 Open
LB3C Upper 8,718' 8,730' 7,316' 7,327' 12' 10/17/22 Plugged
LB 3C Lower 8,740' 8,747' 7,336' 7,342' 7' 10/17/22 Plugged
LB 4 Upper 8,765' 8,783’ 7,358' 7,374' 28' 10/17/22 Plugged
LB 4 Lower 8,806' 8,814' 7,395' 7,402' 8' 10/17/22 Plugged
LB 4A 8,844' 8,856' 7,429' 7,440' 12' 10/17/22 Plugged
LB4C Upper 8,919’ 8,939’ 7,496' 7,514' 20' 10/14/22 Plugged
LB 4C Lower 8,955' 8,972' 7,528' 7,544' 17' 10/14/22 Plugged
LB4D Mid 9,006’ 9,012' 7,574' 7,580' 6' 10/14/22 Plugged
LB 4D Lower 9,020' 9,030’ 7,587' 7,596' 10' 10/13/22 Plugged
LB 5 Lower 9,078' 9,087’ 7,640' 7,648' 9' 10/13/22 Plugged
LB 5A 9,091' 9,111’ 7,651' 7,670' 20' 10/11/22 Plugged
UT 5A 9,703' 9,710' 8,208’ 8,214’ 7' 09/29/22 Plugged
4
5
3/8” Capillary
String
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.
From:AOGCC Permitting (CED sponsored)
To:Brooks, James S (OGC)
Subject:FW: CLU_05RD2 322-709 - WITHDRAWAL/CANCEL
Date:Friday, December 15, 2023 9:43:11 AM
Attachments:Sundry_322-709_123022.pdf
FYI logged in 2022-403 Excel Log.
Grace
From: Donna Ambruz <dambruz@hilcorp.com>
Sent: Friday, December 15, 2023 9:40 AM
To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov>
Cc: Chad Helgeson <chelgeson@hilcorp.com>
Subject: CLU_05RD2 322-709 - WITHDRAWAL/CANCEL
Please withdraw/cancel the above-referenced sundry.
Thank you.
Donna Ambruz
Operations/Regulatory Tech
KEN Asset Team
Hilcorp Alaska, LLC
3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
907.777.8305 - Direct
dambruz@hilcorp.com
From: Prysunka, Anne E (OGC) <anne.prysunka@alaska.gov>
Sent: Friday, December 30, 2022 2:04 PM
To: Abbie Barker <Abbie.Barker@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>;
Cody Dinger <cdinger@hilcorp.com>; Darci Horner - (C) <dhorner@hilcorp.com>; Donna Ambruz
<dambruz@hilcorp.com>; Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com>; Joseph Lastufka
<Joseph.Lastufka@hilcorp.com>; Josh Allely - (C) <josh.allely@hilcorp.com>; Juanita Lovett
<jlovett@hilcorp.com>; Tom Fouts <tfouts@hilcorp.com>
Subject: [EXTERNAL] MPU_S-205, CLU_05RD2 322-709
Anne Prysunka
Executive Secretary| AOGCC
Alaska Oil and Gas Conservation Commission
Direct: (907) 793-1230
The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis 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.
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):
9,940'N/A
Casing Collapse
Conductor
Surface 1,540psi
Intermediate 6,620psi
Intermediate 5,300psi
Intermediate Lnr 4,790psi
Production Lnr 7,500psi
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
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
Chad Helgeson, Operations Engineer
chelgeson@hilcorp.com
907-777-8405
Noel Nocas, Operations Manager 907-564-5278
Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft):Tubing Size:
12.6# / L-80 6,229'
December 30, 2022
SLZXP & ZXP Liner Top Pkrs; S-5 TRSSSV 6,214' MD/5,053'TVD; 6,433' MD/5,663' TVD; 141' MD/TVD
See Attached Schematic See Attached Schematic 4-1/2"
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
FEE-Hilcorp (formerly ADL 060569), ADL 324602
222-092
50-133-20474-02-00
Cannery Loop
Upper Tyonek GP,
Beluga GP Same
CO 231A
Hilcorp Alaska, LLC
3800 Centerpoint Drive, Suite 1400
Anchorage, Alaska 99503
CLUL 05RD2
Length Size
Proposed Pools:
142'142'
TVD Burst
PRESENT WELL CONDITION SUMMARY
8,424'8,710'7,309'~1,512 psi 8,710; 9,678'
142'20"
MD
9,440psi
3,090psi
7,930psi
2,571'
1,200'
5,355'
2,970'
1,212'
6,527'
Perforation Depth MD (ft):
252'
4-1/2"3,724'
7-5/8"
9-5/8"5,315'
13-3/8"
9-5/8"
2,970'
1,212'
6,890psi5,506'6,685'
8,430psi9,938'8,422'
m
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Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
322-709
By Anne Prysunka at 9:22 am, Dec 19, 2022
Digitally signed by Noel Nocas
(4361)
DN: cn=Noel Nocas (4361),
ou=Users
Date: 2022.12.16 10:52:58 -09'00'
Noel Nocas
(4361)
10-404X
BJM 12/30/22
CLU
DLB 12/19/2022
-bjm
GCW 12/30/22
Jessie L.
Chmielowski
Digitally signed by Jessie L.
Chmielowski
Date: 2022.12.30 13:37:00
-09'00'
RBDMS JSB 010323
Well Work Prognosis
Well Name: CLU 5RD2 API Number: 50-133-20474-02-00
Current Status: Gas Producer Rig: Eline & Fox CTU
Estimated Start Date: 12/30/22
Regulatory Contact: Donna Ambruz (8305) Permit to Drill Number: 222-092
First Call Engineer: Chad Helgeson (907) 777-8405 (O) (907) 229-4824 (M)
Second Call Engineer: Jake Flora (907) 777-8442 (O) (720)-988-5375 (M)
Maximum Expected BHP from perfs 531 psi @ 6,437’ TVD Based on XPT in CLU-14 (8/19/2019)
Maximum Potential Surface Pressure: 1512 psi, based on Max buildup on 11/6/22, proposed perf zone pressure is 531 psi
Brief Well Summary
Cannery Loop 5RD2 is a sidetracked gas producer that was drilled and completed, September 2022. The
wellbore is completed as a 4-1/2” mono-bore with tieback to surface, the well is online currently flowing
at 1.2 mmscfd at 80 psi.
Notes Regarding Wellbore Condition
x SSSV at 141’
x Liner/seal assembly @ 6,214’
x CINGSA Pool bottom – 6,304’ MD (5,140’ TVD)
Procedure:
1. Review all approved COAs
2. RU E-line, PT lubricator to 2000 psi High/250 psi Low
3. Run Perforate Middle Beluga sand with 60 deg phased hollow carrier perf guns
Pool Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT
Beluga MB 7A Lower ±7,737' ±7,749' ±6,437’ ±6,448’ ±12'
Make correlation pass and send log in to Operations Engineer, Reservoir Engineer and the Geologist.
a. Record initial and 5/10/15 minute tubing pressures after firing
b. Above perfs will be shot in the Beluga Gas Pool governed by CO 231A
E-line Procedure (Contingency)
1. If any zone produces sand and/or water or needs isolated:
2. MIRU E-Line and pressure control equipment. PT lubricator to 250 psi Low / 2,500 psi High.
3. RIH and set a Casing Patch or set a CIBP above the zone and dump 25’ of cement on top of
the plug.
4. If necessary to cleanout or unload well, RU same coil equipment used in initial completion
a. Test BOPs, 4000 psi High/ 250 psi Low
b. Cleanout with N2 or foam
c. Set 4-1/2” plug or patch
Attachments:
1. Current Well Schematic
2. Proposed Well Schematic
Updated by CJD 11-28-2022
SCHEMATIC
Cannery Loop Unit
CLU-05RD2
PTD: 222-092
API: 50-133-20474-02-00
PBTD = 9,851’ / TVD = 8,343’
TD = 9,940’ / TVD = 8,424’
RKB to GL = 18.12’
Cingsa
From 6071’
- 6295’ MD
CASING & TUBING DETAIL
Size Type Wt Grade Conn. ID Top Btm
20” Conductor 129 - Weld - Surf 142’
13-3/8" Surf Csg 61.0 K-55 BTC 12.515” Surf 2,970’
9-5/8” Intermediate Csg 53.5 L-80 BTC 8.535” Surf 1,212’
9-5/8” Intermediate Csg 47 P-110 BTC 8.681” 1,212’ 6,527’
7-5/8” Intermediate Lnr 29.7# L-80 Hyd 521 6.875” 6,433’ 6,685’
4-1/2" Prod Lnr 12.6 L-80 DWC/C 3.958” 6,214’ 9,938’
4-1/2” Tubing 12.6 L-80 DWC/C 3.958” Surf 6,229’
2
20”
13-3/8”
16”
hole
4-1/2”
JEWELRY DETAIL
No. Depth ID OD Item
1 141 3.813” 6.600” Baker S-5 TRSSSV
2 6,214’ 7.37” 7”x 9-5/8” SLZXP HRDE Liner top packer, w/ 7.37”
PBR
3 6,433’ 3.958” 6.875” 7-5/8” ZXP Liner Top Packer
4 8,710’ 3.958” CIBP set 10/20/22
5 9,678’ - 3.958” CIBP w/ 26’ of cement 10/5/22, tagged 9,667’ CTM
OPEN HOLE / CEMENT DETAIL
13-3/8” Fully cemented with 140bbls back to surface (CLU-05 in 1996)
9-5/8”
12-1/4” hole: Pumped from 9178’ MD. 850sxs lead (375bbls) and 1069 sxs
(222bbls) tail (CLU-05 in 1996) 11/19/96 USIT shows 9-5/8” cemented up to at
least 2800’ MD (stopped logging there)
7-5/8”
8-1/2” hole: Cemented with 102.7bbls 15.3ppg class G. had losses and got no
cement back to surface. 9/24/20 SCMT shows good cement up to at least 6,525
MD (behind tubing above that)
4-1/2” 6-3/4” hole: Lead - 250 sx / 12.5 ppg / 90 bbls Tail - 185 sx / 15.3 ppg / 39 bbls TOC
6,700’ MD – CBL 9/27/22
4
9-5/8”
1
CLU-05RD
(Abandoned)
Window @
6,666’
6-3/4”
hole
7-5/8”
3
Squeezed perfs
7/22/22
PERFORATION DETAIL
Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status
LB 7,880' 7,898' 6,565' 6,581' 18' 11/08/22 Open
LB1 7,921' 7,927' 6,602' 6,607' 6' 11/08/22 Open
LB1C Upper 7,984' 7,993' 6,658' 6,666' 9' 11/08/22 Open
LB1G Upper 8,162' 8,177' 6,816' 6,830' 15' 11/08/22 Open
LB1G Lower 8,186' 8,204' 6,838' 6,854' 18' 11/08/22 Open
LB2 Lower 8,265' 8,282' 6,908' 6,923' 17' 11/08/22 Open
LB2C Upper 8,382' 8,402' 7,013' 7,031' 20' 11/08/22 Open
LB2C Lower 8,414' 8,424' 7,042' 7,051' 20' 11/07/22 Open
LB2D Upper 8,438' 8,452' 7,064' 7,076' 14' 11/01/22 Open
LB2E Lower 8,576' 8,593' 7,188' 7,204' 17' 11/01/22 Open
LB Upper 8,597' 8,606' 7,207' 7,215' 9' 11/01/22 Open
LB3A Upper 8,643' 8,648' 7,249' 7,253' 5' 11/01/22 Open
LB1B Lower 7,952' 7,958' 6,629' 6,635' 6' 10/27/22 Open
LB1B 7,969' 7,974' 6,644' 6,649' 5' 10/28/22 Open
LB1F Upper 8,076' 8,082' 6,740' 6,745' 6' 10/27/22 Open
LB1F Mid 8,094' 8,119' 6,756' 6,778' 26' 10/27/22 Open
LB1F Lower 8,128' 8,140' 6,786' 6,797' 12' 10/27/22 Open
LB2B 8,328' 8,348' 6,964' 6,982' 20' 10/27/22 Open
LB3A Lower 8,668' 8,678’ 7,271' 7,280' 10’ 10/20/22 Open
LB3C Upper 8,718' 8,730' 7,316' 7,327' 12' 10/17/22 Plugged
LB 3C Lower 8,740' 8,747' 7,336' 7,342' 7' 10/17/22 Plugged
LB 4 Upper 8,765' 8,783’ 7,358' 7,374' 28' 10/17/22 Plugged
LB 4 Lower 8,806' 8,814' 7,395' 7,402' 8' 10/17/22 Plugged
LB 4A 8,844' 8,856' 7,429' 7,440' 12' 10/17/22 Plugged
LB4C Upper 8,919’ 8,939’ 7,496' 7,514' 20' 10/14/22 Plugged
LB 4C Lower 8,955' 8,972' 7,528' 7,544' 17' 10/14/22 Plugged
LB4D Mid 9,006’ 9,012' 7,574' 7,580' 6' 10/14/22 Plugged
LB 4D Lower 9,020' 9,030’ 7,587' 7,596' 10' 10/13/22 Plugged
LB 5 Lower 9,078' 9,087’ 7,640' 7,648' 9' 10/13/22 Plugged
LB 5A 9,091' 9,111’ 7,651' 7,670' 20' 10/11/22 Plugged
UT 5A 9,703' 9,710' 8,208’ 8,214’ 7' 09/29/22 Plugged
4
5
Updated by CAH 12-16-22
PROPOSED
Cannery Loop Unit
CLU-05RD2
PTD: 222-092
API: 50-133-20474-02-00
PBTD = 9,851’ / TVD = 8,343’
TD = 9,940’ / TVD = 8,424’
RKB to GL = 18.12’
Cingsa
From 6071’
- 6295’ MD
CASING & TUBING DETAIL
Size Type Wt Grade Conn. ID Top Btm
20” Conductor 129 - Weld - Surf 142’
13-3/8" Surf Csg 61.0 K-55 BTC 12.515” Surf 2,970’
9-5/8” Intermediate Csg 53.5 L-80 BTC 8.535” Surf 1,212’
9-5/8” Intermediate Csg 47 P-110 BTC 8.681” 1,212’ 6,527’
7-5/8” Intermediate Lnr 29.7# L-80 Hyd 521 6.875” 6,433’ 6,685’
4-1/2" Prod Lnr 12.6 L-80 DWC/C 3.958” 6,214’ 9,938’
4-1/2” Tubing 12.6 L-80 DWC/C 3.958” Surf 6,229’
2
20”
13-3/8”
16”
hole
4-1/2”
JEWELRY DETAIL
No. Depth ID OD Item
1 141 3.813” 6.600” Baker S-5 TRSSSV
2 6,214’ 7.37” 7”x 9-5/8” SLZXP HRDE Liner top packer, w/ 7.37”
PBR
3 6,433’ 3.958” 6.875” 7-5/8” ZXP Liner Top Packer
4 8,710’ 3.958” CIBP set 10/20/22
5 9,678’ - 3.958” CIBP w/ 26’ of cement 10/5/22, tagged 9,667’ CTM
OPEN HOLE / CEMENT DETAIL
13-3/8” Fully cemented with 140bbls back to surface (CLU-05 in 1996)
9-5/8”
12-1/4” hole: Pumped from 9178’ MD. 850sxs lead (375bbls) and 1069 sxs
(222bbls) tail (CLU-05 in 1996) 11/19/96 USIT shows 9-5/8” cemented up to at
least 2800’ MD (stopped logging there)
7-5/8”
8-1/2” hole: Cemented with 102.7bbls 15.3ppg class G. had losses and got no
cement back to surface. 9/24/20 SCMT shows good cement up to at least 6,525
MD (behind tubing above that)
4-1/2” 6-3/4” hole: Lead - 250 sx / 12.5 ppg / 90 bbls Tail - 185 sx / 15.3 ppg / 39 bbls TOC
6,700’ MD – CBL 9/27/22
4
9-5/8”
1
CLU-05RD
(Abandoned)
Window @
6,666’
6-3/4”
hole
7-5/8”
3
Squeezed perfs
7/22/22
PERFORATION DETAIL
Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status
MB -7A Lower ±7,737’ ±7,749’ ±6,437’ ±6,448’ ±12 Proposed TBD
LB 7,880' 7,898' 6,565' 6,581' 18' 11/08/22 Open
LB1 7,921' 7,927' 6,602' 6,607' 6' 11/08/22 Open
LB1C Upper 7,984' 7,993' 6,658' 6,666' 9' 11/08/22 Open
LB1G Upper 8,162' 8,177' 6,816' 6,830' 15' 11/08/22 Open
LB1G Lower 8,186' 8,204' 6,838' 6,854' 18' 11/08/22 Open
LB2 Lower 8,265' 8,282' 6,908' 6,923' 17' 11/08/22 Open
LB2C Upper 8,382' 8,402' 7,013' 7,031' 20' 11/08/22 Open
LB2C Lower 8,414' 8,424' 7,042' 7,051' 20' 11/07/22 Open
LB2D Upper 8,438' 8,452' 7,064' 7,076' 14' 11/01/22 Open
LB2E Lower 8,576' 8,593' 7,188' 7,204' 17' 11/01/22 Open
LB Upper 8,597' 8,606' 7,207' 7,215' 9' 11/01/22 Open
LB3A Upper 8,643' 8,648' 7,249' 7,253' 5' 11/01/22 Open
LB1B Lower 7,952' 7,958' 6,629' 6,635' 6' 10/27/22 Open
LB1B 7,969' 7,974' 6,644' 6,649' 5' 10/28/22 Open
LB1F Upper 8,076' 8,082' 6,740' 6,745' 6' 10/27/22 Open
LB1F Mid 8,094' 8,119' 6,756' 6,778' 26' 10/27/22 Open
LB1F Lower 8,128' 8,140' 6,786' 6,797' 12' 10/27/22 Open
LB2B 8,328' 8,348' 6,964' 6,982' 20' 10/27/22 Open
LB3A Lower 8,668' 8,678’ 7,271' 7,280' 10’ 10/20/22 Open
LB3C Upper 8,718' 8,730' 7,316' 7,327' 12' 10/17/22 Plugged
LB 3C Lower 8,740' 8,747' 7,336' 7,342' 7' 10/17/22 Plugged
LB 4 Upper 8,765' 8,783’ 7,358' 7,374' 28' 10/17/22 Plugged
LB 4 Lower 8,806' 8,814' 7,395' 7,402' 8' 10/17/22 Plugged
LB 4A 8,844' 8,856' 7,429' 7,440' 12' 10/17/22 Plugged
LB4C Upper 8,919’ 8,939’ 7,496' 7,514' 20' 10/14/22 Plugged
LB 4C Lower 8,955' 8,972' 7,528' 7,544' 17' 10/14/22 Plugged
LB4D Mid 9,006’ 9,012' 7,574' 7,580' 6' 10/14/22 Plugged
LB 4D Lower 9,020' 9,030’ 7,587' 7,596' 10' 10/13/22 Plugged
LB 5 Lower 9,078' 9,087’ 7,640' 7,648' 9' 10/13/22 Plugged
LB 5A 9,091' 9,111’ 7,651' 7,670' 20' 10/11/22 Plugged
UT 5A 9,703' 9,710' 8,208’ 8,214’ 7' 09/29/22 Plugged
4
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
CLU 05RD2 50133204740200 222092 11/17/2022 AK E-Line Perf
Meredith Guhl Digitally signed by Meredith Guhl
Date: 2022.12.02 12:24:17 -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): Cannery Loop Unit
GL: 20.5' BF:N/A
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 7,307'
24. Open to production or injection? Yes No 25.
26.
Was hydraulic fracturing used during completion? Yes No
DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED
27.
Date First Production: Method of Operation (Flowing, gas lift, etc.):
Hours Tested: Production for Gas-MCF:
Test Period
Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr):
Press. 24-Hour Rate
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
CASING, LINER AND CEMENTING RECORD
List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion,
TUBING RECORD
6,229'4-1/2"
SIZE DEPTH SET (MD)
LTP @ 6,214' / 5,053'
PACKER SET (MD/TVD)
6-3/4" L-250 sx / T-185 sx6,214'
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date perf'd or liner run):
3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503
272695 2388620
50-133-20474-02-00September 9, 2022
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
Hilcorp Alaska, LLC
WAG
Gas
9/29/2022 222-092 / 322-562
AMOUNT
PULLED
275882
276592
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.
CLU-05RD2September 15, 2022171' FSL, 275' FEL, Sec 7, T5N, R10W, SM, AK
38.5'
BOTTOMCASINGWT. PER
FT.GRADE CEMENTING RECORD
2390810
SETTING DEPTH TVD
2391348
TOP HOLE SIZE
LWD (GR, Res, Density Neutron), Mudlog, OH Wireline (SP/GR), CBL 9-27-22, Perf/Tie In logs
Water-Bbl:
PRODUCTION TEST
10/13/2022
Date of Test: Oil-Bbl:
Flowing
*** Please see attached schematic for perforation detail ***
Gas-Oil Ratio:
5,053'
Per 20 AAC 25.283 (i)(2) attach electronic information
12.6# 9,938'
Upper Ty GP, Ty D GP, Beluga GP
ADL 060569 / ADL 324602
LOCI 78-156
N/A
6,666' MD / 5,488' TVD
141' MD / 141' TVD
9,940' MD / 8,424' TVD
8,710' MD / 7,308' TVD
2429' FSL, 2416' FEL, Sec 8, T5N, R11W, SM, AK
2300' FNL, 1716' FEL, Sec 8, T5N, R11W, SM, AK
Choke Size:
Sr Res EngSr Pet GeoSr Pet Eng
N/A
N/A
Oil-Bbl: Water-Bbl:
01787 75
11/23/2022 24
Flow Tubing
17
1258
N/A12580
WINJ
SPLUGOther Abandoned Suspended
Stratigraphic Test
No
No
(attached) No
Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment
By James Brooks at 12:30 pm, Nov 29, 2022
Completed
9/29/2022
JSB
RBDMS JSB 113022
GDSR-12/8/22
Conventional Core(s): Yes No Sidewall Cores:
30.
MD TVD
Top of Productive Interval L Beluga 7,880' 6,565'
6,738' 5,555'
7,038' 5,822'
7,762' 6,460'
7,858' 6,545'
7,917' 6,598'
8,594' 7,205'
8,749' 7,344'
9,035' 7,600'
9,195' 7,746'
9,351' 7,887'
9,634' 8,145'
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:
MB 8
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
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.
Tyonek
Lower Beluga
UB 7
LB1
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.
LB 5
Mid Beluga
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.
TPI (Top of Producing Interval).
Authorized Name and
INSTRUCTIONS
T7
LB 3
LB 4
T1
T5
Wellbore Schematic, Drilling and Completion Reports, Definitive Directional Surveys, Csg and Cmt Report.
Authorized Title: Drilling Manager
No
NoSidewall Cores: Yes No
Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov
11.29.2022
Digitally signed by Monty M Myers
DN: cn=Monty M Myers, c=US,
o=Hilcorp Alaska, LLC, ou=Technical
Services - AK Drilling,
email=mmyers@hilcorp.com
Reason: I am approving this document
Date: 2022.11.29 06:58:57 -09'00'
Monty M
Myers
Updated by CJD 11-28-2022
SCHEMATIC
Cannery Loop Unit
CLU-05RD2
PTD: 222-092
API: 50-133-20474-02-00
PBTD = 9,851’ / TVD = 8,343’
TD = 9,940’ / TVD = 8,424’
RKB to GL = 18.12’
Cingsa
From 6071’
- 6295’ MD
CASING & TUBING DETAIL
Size Type Wt Grade Conn. ID Top Btm
20” Conductor 129 - Weld - Surf 142’
13-3/8" Surf Csg 61.0 K-55 BTC 12.515” Surf 2,970’
9-5/8” Intermediate Csg 53.5 L-80 BTC 8.535” Surf 1,212’
9-5/8” Intermediate Csg 47 P-110 BTC 8.681” 1,212’ 6,527’
7-5/8” Intermediate Lnr 29.7# L-80 Hyd 521 6.875” 6,433’ 6,685’
4-1/2" Prod Lnr 12.6 L-80 DWC/C 3.958” 6,214’ 9,938’
4-1/2” Tubing 12.6 L-80 DWC/C 3.958” Surf 6,229’
2
20”
13-3/8”
16”
hole
4-1/2”
JEWELRY DETAIL
No. Depth ID OD Item
1 141 3.813” 6.600” Baker S-5 TRSSSV
2 6,214’ 7.37” 7”x 9-5/8” SLZXP HRDE Liner top packer, w/ 7.37”
PBR
3 6,433’ 3.958” 6.875” 7-5/8” ZXP Liner Top Packer
4 8,710’ 3.958” CIBP set 10/20/22
5 9,678’ - 3.958” CIBP w/ 26’ of cement 10/5/22, tagged 9,667’ CTM
OPEN HOLE / CEMENT DETAIL
13-3/8” Fully cemented with 140bbls back to surface (CLU-05 in 1996)
9-5/8”
12-1/4” hole: Pumped from 9178’ MD. 850sxs lead (375bbls) and 1069 sxs
(222bbls) tail (CLU-05 in 1996) 11/19/96 USIT shows 9-5/8” cemented up to at
least 2800’ MD (stopped logging there)
7-5/8”
8-1/2” hole: Cemented with 102.7bbls 15.3ppg class G. had losses and got no
cement back to surface. 9/24/20 SCMT shows good cement up to at least 6,525
MD (behind tubing above that)
4-1/2” 6-3/4” hole: Lead - 250 sx / 12.5 ppg / 90 bbls Tail - 185 sx / 15.3 ppg / 39 bbls TOC
6,700’ MD
4
9-5/8”
1
CLU-05RD
(Abandoned)
Window @
6,666’
6-3/4”
hole
7-5/8”
3
Squeezed perfs
7/22/22
PERFORATION DETAIL
Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status
LB 7,880' 7,898' 6,565' 6,581' 18' 11/08/22 Open
LB1 7,921' 7,927' 6,602' 6,607' 6' 11/08/22 Open
LB1C Upper 7,984' 7,993' 6,658' 6,666' 9' 11/08/22 Open
LB1G Upper 8,162' 8,177' 6,816' 6,830' 15' 11/08/22 Open
LB1G Lower 8,186' 8,204' 6,838' 6,854' 18' 11/08/22 Open
LB2 Lower 8,265' 8,282' 6,908' 6,923' 17' 11/08/22 Open
LB2C Upper 8,382' 8,402' 7,013' 7,031' 20' 11/08/22 Open
LB2C Lower 8,414' 8,424' 7,042' 7,051' 20' 11/07/22 Open
LB2D Upper 8,438' 8,452' 7,064' 7,076' 14' 11/01/22 Open
LB2E Lower 8,576' 8,593' 7,188' 7,204' 17' 11/01/22 Open
LB Upper 8,597' 8,606' 7,207' 7,215' 9' 11/01/22 Open
LB3A Upper 8,643' 8,648' 7,249' 7,253' 5' 11/01/22 Open
LB1B Lower 7,952' 7,958' 6,629' 6,635' 6' 10/27/22 Open
LB1B 7,969' 7,974' 6,644' 6,649' 5' 10/28/22 Open
LB1F Upper 8,076' 8,082' 6,740' 6,745' 6' 10/27/22 Open
LB1F Mid 8,094' 8,119' 6,756' 6,778' 26' 10/27/22 Open
LB1F Lower 8,128' 8,140' 6,786' 6,797' 12' 10/27/22 Open
LB2B 8,328' 8,348' 6,964' 6,982' 20' 10/27/22 Open
LB3A Lower 8,668' 8,678’ 7,271' 7,280' 10’ 10/20/22 Open
LB3C Upper 8,718' 8,730' 7,316' 7,327' 12' 10/17/22 Plugged
LB 3C Lower 8,740' 8,747' 7,336' 7,342' 7' 10/17/22 Plugged
LB 4 Upper 8,765' 8,783’ 7,358' 7,374' 28' 10/17/22 Plugged
LB 4 Lower 8,806' 8,814' 7,395' 7,402' 8' 10/17/22 Plugged
LB 4A 8,844' 8,856' 7,429' 7,440' 12' 10/17/22 Plugged
LB4C Upper 8,919’ 8,939’ 7,496' 7,514' 20' 10/14/22 Plugged
LB 4C Lower 8,955' 8,972' 7,528' 7,544' 17' 10/14/22 Plugged
LB4D Mid 9,006’ 9,012' 7,574' 7,580' 6' 10/14/22 Plugged
LB 4D Lower 9,020' 9,030’ 7,587' 7,596' 10' 10/13/22 Plugged
LB 5 Lower 9,078' 9,087’ 7,640' 7,648' 9' 10/13/22 Plugged
LB 5A 9,091' 9,111’ 7,651' 7,670' 20' 10/11/22 Plugged
UT 5A 9,703' 9,710' 8,208’ 8,214’ 7' 09/29/22 Plugged
4
5
Activity Date Ops Summary
9/6/2022 Scope in derrick, Secure derrick for laying over, Lay over derrick, Secure derrick for shipping. Lay over Mud Gas Separator, Scope in doghouse, Lower
doghouse into water tank, Complete rigging down all electrical, Pason, Hydraulics, Utility lines. Blow down water lines and remove. Crane/ Tail roll;Iron
Roughneck, Choke house, Mud pits 1, 2 and 3. Accumulator/ Water tank/ Doghouse skid, Generator/ Air compressor skid, Mud pumps 1 and 2 skids, Mud pump
jig, catwalk and BOPE stack.;Remove derrick from draworks skid and secure on trailer, move drilling line spool and secure on same trailer. Remove draworks
skid and secure on trailer. Crane sub base onto trailer and secure. At 1300 hours mob equipment to Cannery Loop Pad #1. Load pony subs and HPU skid on
trailer and secure same;At Cannery Loop Pad #1 Set pony subs. Set in sub base. Center sub base over hole. Set the drawworks and pin to sub. Crane in drill
line spool. Crane in the derrick and pin to sub. Hook up hydraulics. Raise the windwalls on the board. R/U the IR HPU.;Set the water tank/ koomey house.
Raise V-door. Raise and scope into position. Set pit/pump house jig. Set pit module#1. Craned in the iron roughneck. Raised the dog house. Craned in the
choke house. Set pit module#2.;Raised derrick to half mast. Set pit module #2. Set pit module #3. Raised the roofs on the pit modules. Crane in the
centrifuge, Set generator house, Set gas buster. Set TD HPU module.;Raised the vacuum degasser and connected lines. Set in pump#1 module. Set BOP
stack off of trailer and hang on the sub bridge cranes. Set pump#2 module. Set the boiler house.;R/U jumper lines between pits and pumps. Connected
electrical. Turn on lights around the rig. Connect hydraulic, fuel and water lines. R/U brake linkage and air to drillers console. Set the kelly hose/service loop
and drill line on the rig floor.;Installed the dog knot on the drill line and anchored to drum. R/U lines in pit modules.;Laid felt, liner and matts for the catwalk.
Spooled up the drilling line. R/U the Pason system. R/U electrical lines. R/U instrument lines to the Driller's console. Charged air lines. R/U choke house lines
to the shakers. Spot in the third party shacks. Spot auxiliary fuel tank.;R/U utility lines. R/U high pressure mud lines. R/U hydraulic lines to the choke house.
R/U boiler. R/U CCI shack. R/U TD HPU. Installed torque tube turnbuckles. RKB 17.88' GL 18.12' LD;Installed equalizers between mud tanks.
9/7/2022 Rig up transfer lines and dresser sleeves between pits, Dump lines to cuttings box, shipping blocks on shakers, Degasser in pits, Suction from pit 7 to mud
pumps, Suction between MP1 and MP2, Accumulator lines. Rig up controls and function test iron roughneck. Rig up catwalk, Torque tube,;Remove centrifugal
pumps from hopper #1, Clean and organize roughneck shack, Clean and organize choke house, Spot Gen 3 with crane and rig up. Scope up derrick and dog in
pins, Rig up derrick board, Rig up MGS vent line and continue rigging up electrical lines. Tear down office trailers and crew;quarters at Pearl pad and move to
Cannery Loop pad #1.;Tie off bridal lines in derrick. Adjust the torque tube . Inspect derrick. Rig up to pick up top drive. Pick up and rig up top drive to blocks.
Lay down top drive cradle. Pick up and rig up torque bushing to top drive. Rig up kelly hose and service loop. Office trailers and crew quarter trailers;arrive from
Pearl pad. Spot all equipment, rig up and connect communication lines. Crane new centrifuge, feed pump and control panel. Welder work on tabs for centrifuge
and remove needed grating. Crane windwalls and install on pit modules. Continue rigging up in pits, installing water, air and;steam around rig. Continue
installing new centrifuge, Remove dry hole tree from well and begin nippling up BOPE stack.;Open ram doors and inspect rams and cavities. washed out stack.
Variable rams in the top and fixed rams in the bottom. Installed choke HCR. choke line and kill line. Chain stack. Installed the trip nipple. and the flow box.
Installed the flow nipple.;Installed the fill-up line, flow line and bleeder Continued working on the centrifuge stand. Continued rigging up the pits. Continued
hooking up service lines around the rig. Installed hopper and gun pumps#1 in pit module#1. Checked accumulator bottles and filled as required.;Worked on rig
acceptance check list.;Dressed out rig floor bales/elevators, tongs, subs and mouse hole. Filled the mud tanks. Functioned all pumps, agitators, mud pumps,
top drive, pressurized the accumulator and function tested. Filled the hole. Tested the rig service lines to 2500psi. R/U BOPE testing equipment.;Rig accepted
at 06:00hrs 9/8/2022.;Hauled: 0 bbl Solids to KGF G&I
Cumulative: 0 bbl
Hauled: 0 bbl Fluid to KGF G&I
Cumulative: 0 bbl
Hauled: 0 bbl Cement to KGF G&I
Cumulative: 0 bbl
Lost: 0 bbl Fluid Down Hole
Cumulative: 0 bbl
Daily Metal: 0 lbs
Cumulative: 0 lbs
18
n (LAT/LONG):
evation (RKB):
API #:
Well Name:
Field:
County/State:
CLU 005RD2
Cannery Loop
Hilcorp Energy Company Composite Report
, Alaska
Contractor
AFE #:
AFE $:
Job Name:221-00096 CLU-05RD2 Drilling
Spud Date:
9/8/2022 P/U 4-1/2" test joint and install test plug and set in wellhead. R/U equipment for testing BOPE. Flood and purge all lines and equipment for Initial BOPE test.
AOGCC Jim Regg waived witness of BOPE test yesterday at 14:07pm.;Attempted to get shell test with no success, Leak was detected through IA valve at 2
drops per second. Pulled test plug and replaced seal ring with new one and attempted shell test again with same results. The current wellhead has two guide
pins 90° from IA casing ports. We removed the 4-1/2" test;joint, closed the blind rams and pressured up to 4000psi. to seal the test plug. It worked and leak was
stopped that was previously observed at the IA valve. We bled off and placed the 4-1/2" test joint back into the test plug and was unable to get a shell test
against the Annular Preventer. IA was;leaking as previously observed. We bled off and pulled the test plug and changed the seal ring again, rotated the
configuration 180° and set in wellhead. Unscrewed the test joint, closed the blind rams and seated and tested to 4000psi. successfully with no leaks at the IA.
We then made up the test;joint, closed the lower pipe rams and tested to 250/ 4000psi successfully with no more leaks at the IA. We then began the shell test
process by flooding and purging all lines, closing the Annular Preventer and performed a successful 250/ 4000psi shell test. During all this time this
morning;contacted wellhead supervisor and discussed the happenings in which they sent a transitional spool to location to place between the BOPE stack and
the existing wellhead to use for testing with a conventional test plug if we were not successful.;Complete Initial BOPE test 250/ 4000psi for 5/ 5 minutes each.
One FP on Annular Preventer high test due to air in system.;Rig down test equipment, blow down all lines. Make up and install 9" ID wear ring. Strap and Tally
drill pipe on racks. Fix service loop cover on top drive.;M/U 6-3/4" Bit, Bit sub and crossover and RIH picking up 4-1/2" 16.60# S-135 CDS40 drill pipe F/ surface
T/4954'.;Continued to P/U 4.5" DP and break-in recuts F/4954' to 6687' and tag TOC. Total 217joints P/U and L/D 1 joint.;POOH and rack back 4.5" DP. @
2400';Hauled: 0 bbl Solids to KGF G&I
Cumulative: 0 bbl
Hauled: 0 bbl Fluid to KGF G&I
Cumulative: 0 bbl
Hauled: 0 bbl Cement to KGF G&I
Cumulative: 0 bbl
Lost: 0 bbl Fluid Down Hole
Cumulative: 0 bbl
Daily Metal: 0 lbs
Cumulative: 0 lbs
9/9/2022 Continue POOH with 6-3/4" bit standing back drill pipe F/ 2400' T/ 65'. P/U and M/U 18 joints of 4-1/2" HWDP and RIH T/ 1015', POOH and stand back 9 stands
of HWDP. P/U last stand of drill pipe high and break off, crossover, bit sub and bit.;PJSM, P/U and make up mill assembly with MWD tools obtain high side of
whipstock tray at 310.6°. M/U Top Drive and shallow test MWD tools, Good. Break off TD from MWD tools and P/U whipstock and remove anchor shipping
assembly, Set whipstock in hole on false rotary table and connect shear bolt as;per whipstock representative. P/U and confirm good connection and remove
whipstock lifting assembly.;RIH with whipstock/ Mill assembly F/ Surface T/ 696' PUW 37K SOW 35K.;Service rig. Changed O-rings on top drive service loop
line and IBOP actuator line.;Continue RIH with 7-5/8" Whipstock/ Mill assembly F/ 696' T/6205'.;Built mud for displacement. Circulated and tested MWD tools.
Troubleshot and solved a detection issue with the MWD tools. P/U 120K S/O 95K.;Cont. RIH F/6205' T/6598'. Had 5K set down X2 at 6598'. Screwed in and
oriented whipstock 30R and worked through tight spot with pumps on. Continued to wash to TOC F/6598' T/6688'. Set the whipstock with 8K down, bottom @
6686'. Sheared the mills off with 35K down. P/U 126 K S/O 96K.;Empty pit 7 and prep for displacement.;Displaced well to 9.5ppg 6% KCL PHPA mud.
290GPM 790psi.;Milled window 60-100RPM 10,000-15000 TQ 275-300GPM 1050-1250psi. P/U 126 S/O 96K MWin 9.5ppg MW out 9.56ppg. Began building
batch of 300bbls 9.5ppg 6% KCL PHPA mud. Cleaned and organized around the rig. TOW 6666' BOW 6677.5'.;Drill rathole below window 6678' to 6695'
300GPM 1200psi 80RPM 10-11K TQ.
9/10/2022 Complete rathole below window F/ 6695' T/ 6698' 300GPM 1200psi 80RPM 10-11K TQ, CBU while dressing window as per whipstock representative. Sweep
came back 29 BBLs early. Dry drift window with no problems observed. 15 Lbs of metal recovered so far.;R/U testing equipment and purge all lines for Fit T/ 14#
EMW. Pumped 82.8 gallons and observed leak off at 945 psi. Bled back 58.8 gallons. Send results to Engineer for AOGCC approval. 12.8ppg EMW
approval.;While prepping to shim sub base string was pulled into VBRs with a tool joint in upper ram cavity with 43K overpull observed. Notifications were made
and lower pipe rams were shut with a hose rigged up to IA for trip tank. Well is static. Open upper rams to ensure there is no debris and inspect.;Observed Turbo
out on rig floor motor, Replace turbocharger on rig floor motor. Contact AOGCC for notification of events and plan forward to change rams and test UPRs 250/
4000 psi when out of the hole.;PJSM, Monitor Well, Static POOH with milling assembly F/ 6645' to surface. L/D milling assy . Gauge the mills. Window mill
3/16" under gauge. Follow mill 1/16" under gauge, Gauge mill 1/16" under gauge.;Cleaned and cleared the rig floor.;Pulled the wear bushing. Set the test plug.
Backed out the test joint. Closed the blind rams. Installed 4 1/2" fixed rams in the upper ram cavity. Shell tested the stack to 4000psi OK. Tested the upper
rams and the low test failed.;Opened the ram doors and removed the 4 1/2" fixed rams and attempted to install a rental set of 2 7/8" X 4 1/2" VBR's. The doors
would not close with the VBR's. We then reinstalled the 4 1/2" fixed rams but switched the ODS ram to DS and visa versa.;Tested the upper rams 250/4000psi
5min OK. Pulled the test plug and set the wear bushing. R/D test equipment. Cleaned and cleared the rig floor.;PJSM. P/U 6 3/4" bit, mud motor and MWD
BHA#3 to 120'. Shallow test the MWD OK.;Continue to RIH w/BHA#3 120' to 5059' P/U 105K S/O 70K.;Hauled: 0 bbl Solids to KGF G&I
Cumulative: 0 bbl
Hauled: 520 bbl Fluid to KGF G&I
Cumulative: 520 bbl
Hauled: 0 bbl Cement to KGF G&I
Cumulative: 0 bbl
Lost: 0 bbl Fluid Down Hole
Cumulative: 0 bbl
Daily Metal: 15 lbs
Cumulative: 15 lb
9/11/2022 Continue to RIH with BHA#3 Directional/ Motor with 6-3/4" PDC bit F/ 5059' T/ 6698' orient motor before passing through window and no problem easing through
window P/U 145K S/O 95K.;Drill F/ 6698' md T/ 7095' md Sliding as needed to get away from parent wellbore. GPM 275, SPP 1660psi, Diff 250psi, RPM 60, TQ
10.5K, WOB 7K, Max Gas 100 units, P/U 155K, S/O 93K, ROT 118K, Obtain SPRs at 7095' md, 5869' tvd, MW=9.5ppg. MP1 46spm/ 426psi, MP2 47spm/
426psi. Survey on Bottom.;Flow check well= Slight seepage. POOH F/ 7095' T/ 113'. P/U 159K, S/O 94K.;Stood back flex collars. Drained the motor and graded
bit 1,1,WT, X,I,NO,BHA.;Cleaned and cleared the rig floor.;M/U BHA#4. Uploaded to the tools. Shallow pulse tested the tools. Loaded radioactive sources.
M/U flex collars, HWDP and jars.;P/U 4.5" DP while RIH at 3400'.;At 7096' distance to well plan 24.8' , 14.87' high 19.83' right. rotating hrs 3.09 sliding hrs
.63;Hauled: 8.5 bbl Solids to KGF G&I
Cumulative: 8.5 bbl
Hauled: 76.5 bbl Fluid to KGF G&I
Cumulative: 596.5 bbl
Hauled: 0 bbl Cement to KGF G&I
Cumulative: 0 bbl
Lost: 0 bbl Fluid Down Hole
Cumulative: 0 bbl
Daily Metal: 3 lbs
Cumulative: 18 lbs
9/12/2022 Continue RIH with 6-3/4" triple combo BHA #4 picking up 4-1/2" 16.60# S-135 drill pipe F/ 3400' T/ 3644', Turn elevators to facing v door and continue RIH with
drill pipe from derrick F/ 3644' T/ 6616' P/U 144K S/O 94K.;Establish circulation, Obtain new SPRs @ 6616' MD 5441' TVD, MP #1 46 SPM 511 PSI, MP #2 47
SPM 517 PSI shut down pump and pass through window without orientation with no set downs or problems and continue RIH F/ 6616' MD T/ 6803' MD with TM
collar 5' below BOW MADD PASS T/ 7095' MD.;GPM 280, SPP 1530 PSI, RPM 50, FPH 180.;Tag bottom at 7095' MD, Pump Hi-Vis sweep and start drilling F/
7095' MD T/ 7139' MD. GPM 274, SPP 1850psi, Diff 267psi, RPM 60, TQ 10.2K, WOB 5K, Max Gas 15 units, ECD 10.2 PPG, P/U 144K, S/O 96K, ROT
118K.;Continue drilling 6-3/4" Production hole F/ 7139' MD T/ 7477' MD. MW in 10.4 ppg Vis 51, MW out 10.25 ppg Vis 50, GPM 275, SPP 1870psi, Diff 160psi,
RPM 70, TQ 10.8K, WOB 4K, Max Gas 186 units, ECD 10.8 PPG, P/U 154K, S/O 98K, ROT 123K.;Continued drilling 6-3/4" Production hole F/ 7477' MD to
7865' MW in 10.5 ppg Vis 57, MW out 10.5 ppg Vis 53, GPM 275, SPP 2070psi, Diff 260psi, RPM 60, TQ 10.9K, WOB 5K, Max Gas 144 units, ECD 11.2 PPG,
P/U167 K, S/O 97K, ROT 124K.;Continued drilling 6-3/4" Production hole F/ 7865' MD to 8096' MW in 10.45 ppg Vis 55, MW out 10.5 ppg Vis 54, GPM 275,
SPP 2050psi, Diff 250psi, RPM 60, TQ 11K, WOB 5K, Max Gas 150 units , ECD 11.2 PPG, P/U 167K, S/O 97K, ROT 124K.;CBU 275GPM, 1900psi, 60RPM,
TQ 11K, ECD 11.23ppg B/U gas 225 units.;Flow check, slight seepage. POOH F/8096' to 7720'. Tight spots 20-25K over @ 7923', 7847', 7783', 7773'7759'.
B/R 7782' -7720'.;At 8096' 24.90' from the plan 20.90' high 13.5' right Slide 1.45hrs Rotate 9.19hrs.;Hauled: 20 bbl Solids to KGF G&I
Cumulative: 29 bbl
Hauled: 60 bbl Fluid to KGF G&I
Cumulative: 657 bbl
Hauled: 0 bbl Cement to KGF G&I
Cumulative: 0 bbl
Lost: 10.3bbl Fluid Down Hole
Cumulative: 30.9 bbl
Daily Metal: 3 lbs
Cumulative: 21 lbs
9/13/2022 Continue POOH F/ 7720' MD T/ 7047' with several 25K overpulls and wiping. Backream F/ 7344' MD T/ 7047' GPM 270, SPP 1990 psi, RPM 80, P/U 185K, S/O
97K.;Service crown, Blocks, Top Drive, Iron Roughneck, Pac Rim, Gear Box, Drive Line, Floor Motor, Brake Linkage and Draworks. Clean Rig Floor, Monitor
Trip tank with no loss or gains.;RIH on elevators F/ 7047' and wash last stand down T/ 8096'.;Make connection and send 20 BBL Hi-Vis sweep and drill ahead F/
8096' MD T/ 8220' MD, MW in 10.5 ppg Vis 56, MW in 10.5 ppg Vis 56, GPM 275, SPP 2275psi, Diff 330psi, RPM 60, TQ 11.7K, WOB 5K, Max Gas 154 units,
ECD 11.1 PPG, P/U 185K, S/O 97K, ROT 126K.;Continue Drilling 6-3/4" Production Hole F/ 8220' MD T/ 8494' MD, MW in 10.55 ppg Vis 56, MW in 10.55 ppg
Vis 59, GPM 275, SPP 2300psi, Diff 350psi, RPM 60, TQ 12.1K, WOB 5K, Max Gas 205 units, ECD 11.4 PPG, P/U 190K, S/O 101K, ROT 132K.;Continue
Drilling 6-3/4" Production Hole F/ 8494' MD T/ 8785' MD, Pumped hi-vis sweep @ 8590' -Returned on time W20% increase MW in 10.6 ppg Vis 56, MW in 106
ppg Vis 59, GPM 275, SPP 2380psi, Diff 350psi, RPM 60, TQ 12.6K, WOB 5K, Max Gas 268 units, ECD 11.5 PPG, P/U 197K, S/O 102K, ROT 134K.;Continue
Drilling 6-3/4" Production Hole F/ 8785' MD T/ 8860' MD, MW in 10.75ppg Vis 56, MW in 107 ppg Vis 59, GPM 275, SPP 2490psi, Diff 350psi, RPM 60, TQ
12.3K, WOB 5K, Max Gas 268 units, ECD 11.65 PPG, P/U 200K, S/O 103K, ROT 134K.
9/14/2022 Continue Drilling 6-3/4" Production Hole F/ 8860' MD T/ 9086' MD, MW in 10.85ppg Vis 66, MW 0ut 10.9ppg Vis 66, GPM 285, SPP 2775psi, Diff 350psi, RPM
80, TQ 11.8K, WOB 7K, Max Gas 27 units, ECD 11.8 PPG, P/U 199K, S/O 106K, ROT 138K;Continue Drilling 6-3/4" Production Hole F/ 9086' MD T/ 9209' MD,
MW in 11.3ppg Vis 66, MW 0ut 11.1ppg Vis 65, GPM 285, SPP 2750psi, Diff 300psi, RPM 80, TQ 12.2K, WOB 6K, Max Gas 163 units, ECD 12.07 PPG, P/U
198K, S/O 108K, ROT 139K;SPRs @ 9209'MD, 7758'TVD, MP #! 46spm 704psi, MP #2 717psi, MW 11.3ppg Obtain Survey, Flowcheck= Static.;POOH on
elevators F/ 9209' MD T/ 8090' MD, P/U 187K, S/O 102K @ 8100' MD.;Service Crown, Blocks, Top Drive, Iron Roughneck, Draworks, Brake Linkage and
Driveshaft.;RIH with elevators F/ 8090' MD T/ 9209' MD, Washing last stand to bottom. P/U 205K, S/O 110K;Pump sweep and circulate and condition until MW
In and Out are at 11.3ppg. GPM 260, SPP 2400, RPM 80, TQ 12.3K.
Sweep returned on time with 10/15% increase in cuttings;Continue Drilling 6-3/4" Production Hole F/ 9209' MD T/ 9457' MD, MW in 11.3ppg Vis 66, MW 0ut
11.3ppg Vis 65, GPM 270, SPP 2600psi, Diff 230psi, RPM 80, TQ 12.3K, WOB 5K, Max Gas 163 units, ECD 12.24 PPG, P/U 200K, S/O 110K, ROT
140K;Continue Drilling 6-3/4" Production Hole F/ 9209' MD T/ 9703' MD, MW in 11.3ppg Vis 66, MW 0ut 11.3ppg Vis 65, GPM 270, SPP 2600psi, Diff 230psi,
RPM 80, TQ 12.3K, WOB 5K, Max Gas 62 units, ECD 12.24 PPG, P/U 198K, S/O 110K, ROT 143K
9/15/2022 Drill 6-3/4" Production Hole F/ 9703' MD T/ 9940' MD, MW in 11.3ppg Vis 64, MW 0ut 11.35ppg Vis 65, GPM 270, SPP 2875psi, Diff 450psi, RPM 70, TQ
11.8K, WOB 12K, Max Gas 170 units, ECD 12.5 PPG, P/U 205K, S/O 110K, ROT 143K. Obtain SPRs MP #1 46spm 825psi, MP #2 47spm 833psi;Circulate Hi-
Vis sweep, sweep back on time with 25% increase in cuttings. GPM 270, SPP 2650psi, RPM 70, TQ 12.1K;Flowcheck well Static, POOH F/ 9940' MD T/7065',
P/U 150K, S/O 58K.;Ream F/ 7065' to 6797' 266gpm @ 2150 psi, 30-80 rpm @ 7.7K tq. Wash F/6797' to 6690' 266 gpm @ 1950psi. Shut down pumps and
pulled bit thru window to 6610';Service rig and slip and cut 105' of drill line, perform weekly BOPE function test;POOH F/6610' to 737'. stand back HWDP and
Non-mag. Remove sources and download MWD. L/D BHA. Bit grade 1-1
9/16/2022 Clean and Clear Rig Floor;PJSM, Lay out logging tools on catwalk, R/U sheaves, cable head, P/U Jar enhancer, E-Line jars, Gamma tool and RIH and work
through tight spots and reach 7542' WLM and unable to get any deeper. POOH and R/D logging tools and equipment. Leave unit and equipment on
location.;Monitor Well on trip tank during logging operations with no gains or losses.;PJSM, M/U 6-3/4" cleanout BHA #5, RIH with flex collars and HWDP/
Jars.;RIH with BHA #5 F/ 623' MD T/ 7464' MD. P/U 140K, S/O 95K, Fill pipe every 2000'. Attempt to work through tight spots without pumps.;Ream down from
7464' MD to 7555' and circulate bottoms up. 320 GPM, Spp1540, RPM 80, tq 8.7,;RIH F 7555' T 9866' MD working thru multiple tight spots with 10-20K drag. Fill
pipe and Circ drill pipe volume @ 8950. Attempt to work thru tight spot at 9866' Kelly up and ream down to 9940' md. with 10' of fill on bottom. P/U 210K, S/O
105K, ROT 145K, 320 GPM @ 2000 ssp. rpm 75 , tq 12.3;Pump hi-vis/Nut plug sweep. P/U 210K, S/O 105K, ROT 145K, 320 GPM @ 2000 ssp. rpm 75 , tq
12.3. sweep returned on time with 25% increase in cuttings
SPR MP1 46 SPM/564psi , MP2 47 SPM/ 560PSI
Flow check well;POOH F/ 9940' to 6618' with no issues. Drop drift and cont to POOH to 5342'
9/17/2022 Continue POOH with 6-3/4" cleanout BHA #5 F/ 5342' T/ 623'.;L/D HWDP, Jars, Flex collars, 6-1/2" Stabilizer, Bit sub and 6-3/4" Bit.;Clean and Clear rig
floor.;PJSM with all involved with wireline operations, Hang sheave in elevators, M/U SP logging tool string.;RIH with SP logging assembly F/ surface T/ 9240'.
Confirm with Geologist depth is good and begin logging open hole. Log well F/ 9240' T/ 6678' Monitoring well on trip tank.;R/D and L/D E-Line logging tools and
equipment. Bring 9-5/8" scraper and crossovers to rig floor.;P/U 9 5/8" scraper assembly and RIH to 6255' P/U 110K, S/O 65K;Work Scraper F/ 6200' to 6250'
(packer setting depth) 5 times. Flow check well and drop drift;POOH F/ 6250' to surface and L/D BHA P/U 100K, S/O 60K;Clear rig floor, service rig.;R/U casing
equipment. and lay out pipe on catwalk
9/18/2022 R/U Casing tongs, Elevators and slips for running 4-1/2" 12.6# L-80 DWC/ C-HT Liner. M/U correct crossover to floor valve.;Waiting on confirmation of LTP
crossovers arriving in Anchorage before starting to RIH with 4-1/2" Liner, Otherwise we will RIH with 6-3/4" cleanout assembly BHA #5 again. Replace Roller/
Sprocket bearings on Iron Roughneck, Replace fan belts on floor motor, Inspect crown, Clean/ Organize throughout;Rig, Monitor well on trip tank with no gains
or losses.;Continue waiting for confirmation of LTP crossovers arriving in Anchorage from Hotshot driver. General housekeeping and pressure washing around
rig, Mobilize crossover subs and drill pipe pups to pipe skate for upcoming liner run. Monitor well on trip tank with no gains or losses.;Receive confirmation from
Hotshot driver that they have loaded the crossover pups needed for the LTP and the Bullet seal assembly at 14:35pm.;PJSM, P/U and M/U shoe track with
Baker-Lok and confirm floats are good. RIH with 4-1/2" 12.6# L-80 Range III DWC/ C-HT liner F/ 128' T/ 1689' Torque connections to 6150 ft/ lbs. Received call
from Baker representative that was at Yellowjacket and the crossover is box x box. Will not work.;POOH L/D 4 1/2" liner F/1698' to 290'. Received call from
Baker representative that needed X/O's were found;RIH with 4 1/2" liner F/ 290' T/ 3735' TQ connections to 6150ft/lbs, Change out handling equipment and
M/U liner hanger assembly , Circ. liner volume and get parameters. Pumps on. P/U 50K, S/O 43K, pumps off P/U 55K, S/O 47K. 15 rpm @ 3.1K tq.;R/D casing
equipment, Change out slips/elevators. RIH F/3735' T/4914'
9/19/2022 Continue RIH with 4-1/2" 12.6# L-80 DWC/ C-HT Liner with drill pipe F/ 4914' MD T/ 6645' MD filling pipe every 1500'. P/U 104K S/O 75K;CBU before passing
through window. GPM 225, SPP 485psi, P/U 97K S/O 73K.;Continue RIH with 4-1/2" 12.6# L-80 DWC/ C-HT Liner with drill pipe F/ 6645' MD T/ 9940' MD filling
pipe every 1500' and circulating open hole volume. Wash last stand to bottom. P/U 175K S/O 95K;P/U cement head, circulate and condition mud for cement job,
R/U cementers, P/U cementing equipment. GPM 215, SPP 850 psi. P/U 175K S/O 95K.;PJSM, Cementing 4-1/2" Production Liner with all involved personnel,
Pressure test lines T/ 650 psi Low, 4800 psi high. Good test. Mix and pump 30 BBLs 12ppg spacer @ 5 BPM, 600 psi. Pump 90 BBLs (250 SKS) 12.5ppg lead
cement @ 4 BPM, 360 psi. Pump 39 BBLS (185 SKS) 15.3ppg tail cement @ 4BPM, 80psi;Clean surface lines with 12 BBLs water, Drop drill pipe wiper dart
with 10 BBLs water, 125.1 BBLs of 11.3ppg mud @ 4 BPM, 420 psi, slow down to 3 BPM for the last 20 BBLs. Pressure before plug bump at 1040psi. Bump
plug at 135.1 total ( 5 BBLs early) pressure up and set Hanger at 2600psi,;and bring pressure up to 4100 psi to release HRDE tool, Bleed off 1.5 BBL and floats
held. CIP @ 18:05pm. Set down and set Packer and P/U string 3' and L/D Cement head. M/U Top Drive to 15' pup and pressure up to 500psi and pull running
tool from Liner Top Packer;Circulate 2 CBU's, 275GPM, 520psi. Approx 30 bbls spacer and trace cement returned. Cement strung out thru circulation. Drop
clean out balls and circ DP volume. Flow check well P/U 110K, S/O 85K;POOH F/ 6178' to surface and L/D running tool;Clean and clear floor, break down
cement head, Flush and wash BOP's with black water.;P/U Polish mill BHA and TIH from surface T/ 3954'
9/20/2022 Continue RIH with Polish mill BHA and TIH f/ 3954' MD t/ 6219' -6229' MD Polish Liner top 150 gpm;Displace well t/ 8.4 ppg inhibited fluid, R/U and reverse
circulate 5 bpm 415 bbls;POOH L/D DP sucking wiper balls through pipe and redoping and installing thread protectors;R/U and test casing to 2500 psi f/ 10 min
on chart 4.3 bbls pumped 4.3 bbls returned;RIH w/ w/ remaining DP in derrick T/3400' P/U 70K, S/O 57K;POOH L/D DP f/3400' to surface.;Clear rig floor,
service rig . Pull wear bushing. R/U casing tongs and handling equipment. Prep Tie-back completion;M/U seal assembly and TIH with 4 1/2" tie-back completion
from surface T/ 4382'
9/21/2022 Continue RIH w/ 4.5'' Tie Back as per Detail f/ 4382' t/ 6118' RIH and space out, L/D 2 jts P/U Space 29.11' of out pups, M/U hanger and landing jt, Land on
hanger RILDS, R/D TRS equipment Clear floor.;R/U and test Tubing t/ 4000 psi f/ 10 min Test IA t/ 2500 psi f/ 10 min good tests.;Flush Lines install TWC, Flush
stack and drain, Open Ram doors and clean ram cavities, change uppers t/ 2 7/8x5 VBR's< Remove flow box and choke and kill lines, N/D BOP Stack.;Clean
Wellhead and API groove, N/U tree and terminate control line through tree adaptor flange. N/U dry hole tree and test voids to 5000psi for 15min each. R/D top
drive bails and saver sub.;Pressure test tree to 5000psi. Leaked around seal ring. tighten bolts and re-test- good test.;Pressure test tubing to 4000 psi for 30
min. 94.3 gal pumped, 105 gal returned.;Pressure test Annulus to 2500psi for 30 min. 145 gal pumped, 155 gal returned. R/D test equipment and Close/bleed
off SSV.;R/D top drive and rig equipment. Prep Derick to scope down. Release rig @06:00 hrs.
Activity Date Ops Summary
9/26/2022 Fox coil arrive at office, hold TBT and approve PTW.
MIRU coil equipment. Spot supply and return rain for rent tanks.,Test BOPE to 250 psi low / 4000 psi high. Did not get a response from AOGCC about witness
of BOPE test.,Mobilize manlift and Yellow jacket pump to location.
Fill supply tank with 400 bbls of freshwater.
SDFN
9/27/2022 Fox arrive on location and hold TBT, approve PTW.
MU CTC and pull test to 30k. MU DFCV's, Disco, jars, motor and PT 3500 psi. MU 3.75" mill.,PT lubricator to 250/4000 psi. Open swab and RIH.
Tag SSSV at 143'. Unable to get through with 3.75" mill. POOH.
MU 3.65" flat bottom junk mill.,RIH with 3.65" junk mill. Run through SSSV without seeing any weight bobbles.
Tag at 9802' ctmd. Online with pump at 1.3 bpm and 2800 psi. Mill through restriction easily.
continue to RIH pumping and tag PBTD at 9854' ctmd.,Pump water at PBTD and circulate out drilling mud from liner. Chase mud to surface while POOH.
Stop pumping at 500' and pull through SSSV without issues. Coil at surface, close swab.,Laydown milling BHA and lubricator. Set injector on back deck.
Leave BOPs on well for E-line.,Yellow Jacket E-line MU lubricator and CBL toolstring. RIH and calibrate tool in free pipe. Tie into Liner hanger. Tag PBTD at
9795' (uncorrected), sticky while picking up off bottom.
Log up to above liner hanger. GR stopped working, but CBL data is good. Estimated TOC = 6700'
RIH to PBTD and able to get GR working, log up to above liner hanger with GR.,POOH with CBL toolstring.
RDMO E-line. Secure well for the night.
9/28/2022 Fox coil arrive on location, hold TBT and approve PTW.
Pick up injector and lubricator, MU roll on connector, DFCV's, stinger and 2.125" nozzle.
Go to the well and PT lubricator to 250/4000 psi.
Haul off Yellow Jacket pump and move in N2 pump and transport.,Open swab and RIH. Start pumping N2 at 1000 scfm at 7000'. RIH pumping N2 and tag at
9865' ctmd.
Continue pumping chasing all fluid is out of well and recover 180 bbls of water.
Pressure up tubing to 2500 psi with Nitrogen.,Shut in swab. Laydown nozzle BHA, lubricator and set down injector. ND coil BOPs, flowcross and install tree
cap.
Coil RDMO.
9/29/2022 Yellow Jacket E-line arrive and hold TBT and approve PTW.
MU perforating toolstring and lubricator.
Stab onto well and test 250 psi low / 4000 psi high.,RIH with 2-7/8" x 7' , 6 spf, HSC perf gun.
Send correlation data to RE/GEO and confirm on depth.
Perforate UT 5A from 9703 - 9710'.
Initial pressure = 2542 psi. 5, 10,15 min = 2540 psi.
All shots fired. Gun is wet with mud in bull plug.,E-line RDMO
10/2/2022 Fox N2 arrive and hold TBT and approve PTW.
MIRU equipment and cool down N2 unit. Pressure Test treating lines to 4500 psi,Start pumping N2 at 1000 scfm. Pressure tubing to 4000 psi and shut
down.,Fox N2 RDMO.
10/5/2022 AK Eline on location. PJSM & open PTW. Rig up Eline. Pick up BHA #1. PT Lubricator to 250/4000 psi, pass. 3500 SITP.,RIH w/ 17' x 1.69" weight bar. 5'x2"
weight bar, 1.69" GPT, 2.75" Junk basket w/ 3.75" gauge ring. Sit down @ tubing hanger. POOH.,RIH w/ 17' x 1.69" weight bar. 5'x2" weight bar, 1.69" GPT,
2.75" Junk basket. Make it through the tubing hanger. POOH.,RIH w/ 17' x 1.69" weight bar. 5'x2" weight bar, 1.69" GPT, 2.75" Junk basket w/ 3.75" gauge
ring. Sit down at TRSSSV. POOH.,RIH w/ 17' x 1.69" weight bar. 5'x2" weight bar, & 1.69" GPT tool. Tag TD @ 9803'. Find fluid level @ 8490'. POOH, hang
up in the TRSSSV, bleed off tubing pressure to 2700 psi (5000 psi on the control line), POOH clean.,RIH w/ GR/CCL & 3.5" CIBP. (13.7' CCL to mid element).
RIH and tie into CBL 9/27/22. Set 3.5" CIBP @ 9678' (9664.3' CCL stop depth). Tag plug to confirm set. POOH.,Mix & load 17 gallons cement. RIH w/ 1.69"
CCL & 40' x 3.5" dump bailer. Tag plug @ 9678' and pick up 50', dump 17 gallons of cement (26') on CIBP. TOC @ 9652'. RDMO Eline.
10/9/2022 Fox coil on location. Open PTW & PJSM. Spot and rig up coil equipment & crane. Spot return tank and tie in.,Perform BOPE test to 250/4000 per sundry
(AOGCC witness waived by Jim Regg). BOP test passed. Secure well and location. LDFN.
10/10/2022 Fox coil w/ N2 pump on location. Open PTW & PJSM. Rig up on well and PT lubricator to 250/4000 psi, pass. PT Nitrogen lines to 250/4000 psi, pass.,115 psi
on the well. RIH w/ yellowjacket MHA & 2.88" nozzle. Tag CIBP w/ cement @ 9667' CTM. POOH 15' and come online w/ N2 @ 1000 scf/min. Start seeing fluid
@ 65,000 scf. POOH @ 130 fpm. Bump up taking 27 bbls of returns. Trap 600 psi on the well. RDMO Coil unit and N2 pump.
10/11/2022 Arrive location w/ AK Eline. Open PTW & PJSM. Rig up on well & pick up BHA #1. PT lubricator to 250/4000 psi per sundry. Pass.,Wellhead pressure = 605
psi. RIH w/ 12' x 1.69" weight bar, 1.69" GPT w/ CCL. Tag cement @ 9637'. Fluid level @ 9430'. POOH.,Wellhead pressure = 615 psi. RIH w/ 3.125" GR/CCL,
2.75" shock sub, 20' x 2 7/8" Geo Razors, 6spf, 15gm. (CCL to top shot 9')
Send log to Geo, on depth.,Pull on depth and perforate LB 5A Upper 9091' - 9111' MD. POOH. All shots fired - gun dry
0min - 617psi
5 min = 619psi
10 min = 619 psi
15 min = 619psi
OOH pressure = 618 psi.,M/U and RIH w/ 12' x 1.69" weight bar, 1.69" GPT w/ CCL. Fluid level @ 9365'. Gamma worked intermittently when we got to
bottom. Pulled GPT log from 9150-8700'
POOH.,Lay down the lubricator.
Secure well and SDFN
n (LAT/LONG):
evation (RKB):
API #:
Well Name:
Field:
County/State:
CLU 005RD2
Cannery Loop
Hilcorp Energy Company Composite Report
, Alaska
Contractor
AFE #:
AFE $:
Job Name:221-00096 CLU-05RD2 Completion
Spud Date:
10/12/2022 PJSM and PTW
SITP 1025psi,P/U Lubricator. RIH w/ 17' x 1.69" weight bar, 1.69" GPT w/ CCL. Fluid level @ 9224ft'. Log from 9,620'-8600'. Send log to town, cooling
observed over the perforated interval. POOH,M/U and RIH with Guns #2&3. w/ 3.125" GR/CCL, 2.75" shock sub, 9'&10' switch guns. 2 7/8" Geo Razors,
6spf, 15gm.
Pull correlation log and send to town. On depth,Pull on depth and the shooting panel cannot connect to the gun switches. Troubleshoot with no luck POOH.
Moisture in the teardrop connection preventing gun communication.,Lay down the lubricator. Secure well and SDFN.
10/13/2022 PJSM and PTW
SITP - 1964 psi,PU lubricator and MU GPT tools - 7' weight bar, roller bogie, 10' weight bar, roller bogie, 1-11/16" GPT tool - OAL - 29'. RIH. Fluid level at
9120'. GPT tools appear to be erratic when in fluid. POOH. Send to town. Make 2' correction per Geo. Make 9086' equal 9088'. Resend log.,Arm and RIH with
9' and 10' 2-7/8" 6 spf HSC guns. Verified switches on surface and at 200'. Switches failed to communicate when toolstring was at 8000'. Tested and failed to
communicate at 7000' and 6000'. Started to communicate normally at 5000'. Run back in hole. Tool communicating normally. Pull correlation pass from 9100'-
8550', send to town, make 1' shift per Geo.,Perforate the LB 5 Lower from 9078'-9087'. Pressure - 2175 psi, 2177 psi, 2179 psi, 2181 psi.
Perforate the LB 4D Lower from 9020'-9030'. Pressure - 2188 psi, 2190 psi, 2192 psi, 2194 psi.
POOH. All shots fired. Gun was dry.,MU GPT logging tools. Bleed down WHP from 2197 psi to 800 psi. Well is flowing at 300 mcf at 830 psi. Found fluid level
at 9070', this is 60 below the top open perf. POOH. Install night cap. Lay down lubricator. SDFN.
10/14/2022 PJSM and PTW
Start equipment. MU tool-string. SITP 745 psi.,Arm and RIH with 6' and 17' 2-7/8" HSC guns on a switch. Pull correlation log, send to town, on depth. Attempt
to perforate the LB 4D Mid. Switch communicated like normal but would not transmit any current and would not fire. After discussing with town, decided to
shoot upper gun. Perforate the LB 4C Lower from 8955'-8972'. POOH. Pressure data: 860 psi - no change after 15 min. All shots of upper gun fired, gun was
damp.,Lower 6' gun did not fire. MU same 6' gun. Arm and RIH. Pull correlation log, send to town, on depth. Attempt to perforate the LB 4D Mid from 9006'-
9012'. No indication of fire. POOH. Gun did not fire. Tool was broken down at surface and wires had pulled out of the detonator. Brought well online at 1130.
Flowing at 175 mcf and 900 psi.,Gun was re-wired. Arm and RIH 6' gun. Pull correlation log, send to town, on depth. Perforate the LB 4D Mid from 9006'-9012'.
POOH. All shots fired. Gun was dry. Well was flowing at 308 mcf and 857 psi, no change after shooting.,Arm and RIH with 20' 2-7/8" HSC gun. Pull correlation
log, send to town, on depth. Perforate the LB 4C Upper from 8919'-8939'. POOH. Well is flowing at 175 mcf and 812 psi, no change after shooting. All shots
fired, gun was dry.,MU and RIH with GPT tools. Log with well flowing at 265 mcf and 720 psi FTP. Fluid level at 8652'. Cooling across perf intervals. Send log
to town. POOH. Lay down toolstring and lubricator. Install night cap. SDFN.
10/17/2022 AK EL arrive on location. PTW and PJSM. Pick up lubricator. MU and run GPT tools. Fluid level detected at 7650', well is flowing at 215 mcf and 575 psi, top
open perf is 8919'-8939'. POOH. GPT log sent to Geo/Engineer.,MU 12' and 8' 2-3/4" HSC guns. Arm and RIH. Pull correlation log, send to town, on depth.
Perforate the LB 4A from 8844'-8856'. Wait 15 min. Pressure data: initial - 182 psi, 5 min - 178 psi, 10 min - 174 psi, 15 min - 170 psi.
Perforate the LB 4 Lower from 8806'-8814'. Pressure data: initial - 168 psi, 5 min - 165 psi, 10 min - 163 psi, 15 min - 159 psi.
POOH. All shots fired.,MU 18' 2-3/4" HSC gun. Arm and RIH. Pull correlation log, send to town, on depth. Perforate the LB 4 Upper from 8765'-8783'. POOH.
All shots fired.
Pressure data - 75 psi and 115 mcf - no change after 15 min.,MU 7' and 12' 2-3/4" HSC gun with a switch. Arm and RIH. Pull correlation log, send to town, on
depth. Perforate the LB 3C Lower from 8740'-8747'. Pressure data - 115 mcf and 73 psi - no change after 15 min.
Perforate the LB 3C Upper from 8718'-8730'. Pressure data - 115 mcf and 73 psi - no change after 15 min.
POOH. All shots fired. Pop off well and drop soap sticks, install night cap, and cycle swab. SDFN.
10/18/2022 PTW and PJSM
PU lubricator and make up GPT tools.
RIH and log across production zones. Find fluid level at 6980'. Sent log to Eng/Geo.
Install night cap and SDFN. EL unit off location, but left crane and other equipment on location.,Fox Energy nitrogen on location. PTW and PJSM. Rig up to
tree wing test lines to 4500 psi, (good), open well Begin pressuring up on well to 4500 psi with nitrogen, at 1000 to 1200 scfm pumped total of 237.800 SCF
PRESSURE 4472 at flow line gauge, out of nitrogen, shut well in pressure bleed from 4472 psi to 4200 psi in 30 minutes secure well and equipment for night
monitor pressure
10/19/2022 Waiting on Nitrogen transport,Cooling down Nitrogen unit.,Pressure test lines to 4,500 psi, open well, SITP at 3,011 psi, Pressure up from 3,011 psi to 4,500
psi with 81,850 SCF, pumping at 1,200 SCFM,,Monitor well pressure for 1 hour pressure bleed from 4,500 psi to 3,975 psi,Pressure up with nitrogen f/ 3,975 to
4,500 psi with 34,519 SCF at 1,200 scfm,Pressure bleed f/ 4,500 psi to 4,030 psi,Pressure up with nitrogen f/ 4,030 psi to 4,500 with 29,087 SCF at 1,200
SCFM,Monitor pressure, pressure bleed 4,500 psi to 4,350 psi, pressure up with nitrogen f/ 4,350 to 4,500 with 11,500 SCF shut well in for night.
10/20/2022 IFO held PISM Fox Nitrogen pressured up on well to 4500 psi with 80,117 SCF pumping at 1200 scfm,AK Eline Pick up GPT, stab on, pressure test lubricator
to 4132 RIH with GPT to 9166 ft. log up to 8100 ft, send log into town for verification found fluid level at 9064 ft. POOH lay down tool,Make up 3.71 Legacy Big
Boy bridge plug, rated for 10,000 psi at 325* lot # 959C2, to 8722 ELM log correlation pass f/ 8722 ft ELM to 8400 ft ELM, send log for verification (on depth)
set CIBP at 8710 ELM, pick up 20 ft. RIH tagging CIBP at 8710 ft. pooh bleeding nit pressure on well from 3640 psi to 1000 psi,OOH continue bleeding
Nitrogen pressure off to 1000 psi, while making up perf gun, RIH with 2-7/8 HC perf gun loaded with 10 ft of shots 6 shots per ft. 60* phasing, RIH run
correlation pass, send in for verification, spot gun on depth perforate the LB 3A lower sand from 8668 ft to 8678 ft, tbg pressure at 1056 psi, 5 minutes 1070
psi, 15 minutes 1078 psi, 15 minutes 1085 psi pooh lay down guns,,all shots fired, Gun dry, gun debris in bull plug, turn well over to production
10/21/2022 Get permits, and warm up equipment,Make up 5' x 2" wt. bar, 18" roller bogie (3.60 od), 7' x 1-11/16 wt. bar, 18" roller Boggie (3.60 od), 7' GPT , ccl, rope
socket, Rih tagged CIBP AT 8710' elm, RUN PASS with GPT to 8200' ELM, send log in for verification, no fluid, across perforations at 8668 to 8678. bleed tbg
pressure from 500 psi to 200 psi, monitor well flowing at 200 psi at 125k rate, run second pass from 8710 ft. to 8200 ft, no fluid,across prefs at 8668' to 8678 '
monitor well 1 hour, run third pass with GPT, from 8710 to 8200 ', sent log in for verification, no fluid across perforations at 8668 to 8678', received orders to
pooh and rig down for the weekend.,Pooh with GPT lay out same, rig down E-line. turn well over to production
10/24/2022 AK Eline arrive on location. Open PTW & PJSM. Pick up BHA #1 and stab on the well. Open up to wellhead pressure 1937 psi.,SITP = 1937. RIH w/ 5' x 1.69"
WB, 1.9'x 3.60" Roller Bogie, 7' x 1.69" WB, 1.9' x 3.60" Roller Bogie, 7.5" x 1.69" GPT w/ CCL (CCL to GPT = 7').
Tag plug @ 8710'. Find FL @ 7575'.
Sit w/ GPT tool mid perf (8673') and record pressure/temperature for 15 minutes. Starting, SITP = 1951, BHP = 2766, Temp = 130.85. Ending, SITP = 1950,
BHP = 2761, Temp = 130.68.
POOH.,Rig down AK Eline and secure well.
10/25/2022 Rig up Fox N2 unit to the companion valve. PT lines to 250/4500 psi. Pass,SITP = 2265 psi. Come online w/ N2 @ 1200 scf/min. Build wellhead pressure to
4423 psi w/ 163,777 scf of N2. Did not see breakover. Last 50 psi pressure build up slowed.
SI N2. Master valve left open to monitor flowline pressure. Swab valve shut.
RDMO N2 unit.
10/27/2022 AK EL arrive on location. PTW and PJSM. Warm up equipment and snow removal. WHP is 4086 psi. PU GPT toolstring. RIH. No fluid above 8550'. POOH.
Lay down GPT.,MU 20' 2-7/8" HSC gun. Arm and RIH. Pull correlation log, send to town, on depth. Bleed off WHP from 2700 psi down to 500 psi. Well would
not maintain a flow rate above 500 psi, shut in choke. Perforate the LB 2B from 8328'-8348'. Crack choke, well is flowing at 175 mcf and 487 psi FTP. POOH.
All shots fired. Gun was dry,,MU 12' 2-7/8" HSC gun, Arm and RIH. Pull correlation log, send to town, on depth. Perforate the LB 1F Lower from 8128'-8140'.
POOH. WHP 350 psi and 160 mcf. Rate stayed steady at 160 mcf and FTP dropped to 342 psi after 15 min. Lay down guns, all shots fired. Gun was dry.,MU
25' 2-3/4" HSC gun, Arm and RIH. Pull correlation log, send to town, on depth. Perforate the LB 1F Mid from 8094'-8119'. POOH. Pressure data - initial 395 psi,
5 min - 402 psi, 10 min - 407 psi, 15 min - 412 psi. Flow rate stayed steady at 182 mcf. Lay down guns, all shots fired. Gun was dry.,MU 6' 2-7/8" HSC gun,
Arm and RIH. Pull correlation log, send to town, on depth. Perforate the LB 1F Upper from 8076'-8082'. POOH. Pressure data - initial 175 psi, 5 min - 178 psi,
10 min - 181 psi, 15 min - 185 psi. Flow rate increased from 281 to 290 mcf over 15 min. Lay down guns, all shots fired. Gun was dry.
Secure tree. Lay down lubricator. SDFN.
10/28/2022 AK E line crew arrive on location. PTW, JSA. FIre equipment. PIck up lubricator. Make up GPT tool. Well currently fowing 225 psi @ 518 MCFD.
Stab on well. PT lubricator 250/4000 psi. RIH with GPT tool looking for fluid level. No defined level seen. Looks like comingled gas and fluid below 8128'.
POOH to surface.,Make up 5'x 2 7/8" perf gun. RIH. Pull correlation log. Send log to town. On Depth. Perforate LB 1B sands from 7969"-7974' with Geo
Dynamics 5'x 2 7/8" gun loaded 6 spf 0* phasing 15g RZR charges. Slight increase in pressure and rate. POOH to surface. Gun damp. All shots fired.
Well flowing 219 psi @ 527 MCFD>,Make up 6' gun . RIH Log correlation. Sent to town. On depth. Perforate the LB 1B lower from 7952'-7958' with 6' x 2
7/8" gun loaded with 6 spf, 0* Phasing with 15g RZR charges. POOH to surface. Confirmed all shots fired. Gun damp,Make up GPT . RIH . Log OOH from
8430. No sign if definite fluid level. POOH to surface. Send GPT log to town. Rig down AK E-line. Continue flowing well.
11/1/2022 Travel from AK-E-Line shop to KGF office.,PJSM and permit.,Travel to Cannery Loop.,Spot equipment and rig up e-line. Prep Gun 19. Stab on well.,Pressure
test surface equipment to 4000 PSI. Test good.,Run in hole w/ Gun 19 2-7/8" OD x 5' carrier gun to shoot LB 3A Upper sands at 8643' to 8648'.,Tie in LB 3A
Upper sands at 8643' to 8648' - Tagged fill at 8677.6. Plug is set at 8710'.,Sent tie in log to town for approval.,Advised to make 2' correction. Correction made.
Spot Gun 19 (2-7/8" x 5') for LB 3A Upper sands at 8643' to 8648' (CCL to to top shot 11.2' - CCL on depth at 8631.8). Fired gun. Good weight drop. Start
pressure and 5 minute readings for 15 minutes unchanged at 82 PSI. POOH.,OOH. Lay down Gun 19. Pick up Gun 20.,Run in hole w/ Gun 20 2-7/8" OD x 9'
carrier gun to shoot LB 3 Upper sands at 8597' to 8606'.,Tie in LB 3 Upper sands at 8597' to 8606',Sent tie in log to town for approval.,Spot Gun 20 (2-7/8" x 9')
for LB 3 Upper sands at 8597' to 8606' (CCL to to top shot 10.4' - CCL on depth at 8586.6). Fired gun. Good weight drop. POOH. 5 Minute readings: Start 85/5
min 83/10 min 82/15 min78.,OOH. Lay down Gun 20. Pick up Gun 21.,Run in hole w/ Gun 21 2-7/8" OD x 17' carrier gun to shoot LB 2E Lower sands at 8576'
to 8593'.,Tie in LB 2E Lower sands at 8576' to 8593',Sent tie in log to town for approval.,Spot Gun 21 (2-7/8" x 17') for LB 2E Lower sands at 8576' to 8593'
(CCL to to top shot 11.3' - CCL on depth at 8564.7). Fired gun. Good weight drop. POOH. 5 Minute readings: Start 80/5 min 82/10 min 82/15 min 82,OOH. Lay
down Gun 21. Pick up Gun 22.,Run in hole w/ Gun 22 2-7/8" OD x 14' carrier gun to shoot LB 2D Upper sands at 8438' to 8452'.,Tie in LB 2D Upper sands at
8438' to 8452',Advised to make 2' correction. Correction made. Spot Gun 22 (2-7/8" x 14') for LB 2D Upper sands at 8438' to 8452' (CCL to to top shot 11.3' -
CCL on depth at 8426.7). Fired gun. Good weight drop. POOH. 5 Minute readings: Start 80/5 min 82/10 min 79/15 min 82,OOH. Lay down Gun 22. Lay down
lubricator & secure well. SDFN. Will return tomorrow for more perforating runs.,Travel back to AK E-line shop.
11/7/2022 AK E-line arrive on location. Hold TBT and approve PTW.
Start and warm up crane. Spot in E-line unit.
MU wireline valves to tree. MU lubricator and pick up perf gun.
Stab onto well and PT lubricator 250 psi low / 4000 psi high.,RIH with perf gun (2-7/8" x 10'). GR to top shot = 11.5. Well is flowing with pressure = 80 psi.
Send correlation data to RE/GEO and add 1' to get on depth.
Perf LB 2C Lower: 8414-8424'.
All shots fired and bull plug on had a little water inside.,Laydown lubricator and secure well with night cap on wireline valves.
SDFN.
11/8/2022 PJSM and PTW
Well flowing ~932MCFD @ 79psi
Warm up equipment,M/U gun gamma and 20ft gun, stab on well.,M/U and RIH w/ 20ft Geodynamic 2-7/8"OD gun, 15g, 6spf. (CCL to top shot 11.5ft)
Pull correlation log and send to town. On depth,Pull on depth and shoot LB2C upper from 8,382-8,402ft. POOH, bull plug has a little water
0min - 82psi
5min - 81psi
10min - 77psi
15min - 72psi
No change in flow rate,M/U and RIH w/ 17ft Geodynamic 2-7/8"OD gun, 15g, 6spf. (CCL to top shot 14.3ft)
Pull correlation log and send to town. On depth,Pull on depth and shoot LB2 lower from 8,265-8,282ft. POOH, all shots fired, bull plug has a little water
0min - 81psi
5min - 81psi
10min - 81psi
15min - 79psi
No change in flow rate,M/U and RIH w/ 18ft Geodynamic 2-7/8"OD gun, 15g, 6spf. (CCL to top shot 13.3ft)
Pull correlation log and send to town. On depth,Pull on depth and shoot LB1G lower from 8,186-8,204ft. POOH, all shots fired, bull plug has a little water
0min - 85psi
5min - 85psi
10min - 82psi
15min - 82psi
No change in flow rate,Gun Run #27
Gun Misfired, re-logged perf interval to see if perforations were visible on CCL. No perforations were seen, held a safety meeting to discuss the risks of
bringing a misfired gun to the surface. Pulled the shooting panel key and completely powered down the E-line computers at 200ft from surface. Disarmed gun
per procedure.
Detonator resistors blew but did not set off the detonator. Replaced detonator,Re-run 15ft Geodynamic 2-3/4"OD gun, 15g, 6spf. (CCL to top shot 13.3ft)
Pull correlation log . On depth,Pull on depth and shoot LB1G upper from 8,162-8,177ft. POOH, all shots fired, bull plug has a little water
0min - 83psi
5min - 80psi
10min -85 psi
15min - 81psi
No noticeable change in flow rate,M/U and RIH w/ 9ft Geodynamic 2-7/8"OD gun, 15g, 6spf. (CCL to top shot 12.4ft)
Pull correlation log and send to town. On depth,Pull on depth and shoot LB1C upper from 7,984-7,993ft. POOH, all shots fired, bull plug has a little water
11/17/2022 PJSM and PTW
Well flowing ~961MCFD @ 77psi,Spot equipment. R/U AK E-line. M/U 18ft & 6ft switch guns. Stab lubricator on the well.
Pressure test lubricator with MeOH/water blend to 250psi/4000psi - Test good,Open well and RIH w/ 6FT Geodynamics 2-3/4"OD 15g, 6spf (CCL to top shot
28.3ft) & 18FT Geodynamics 2-3/4"OD 15g, 6spf (CCL to top shot 9.2ft). Switch guns
Pull the correlation log and send it to town. On depth.,Pull on depth and shoot LB1 from 7,921-7,927ft.
FTP
0min - 79psi no change in 15min,Pull on depth and shoot LB from 7,880-7,898ft. POOH, all shots fired, bull plug has a little water
FTP
0min - 79psi, no change in 15min,Secure well and hand over to production
RDMO AK E-line
Rate slowly increasing
Final well conditions 1.3MMCFD @ 88psi
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Benjamin Hand Digitally signed by Benjamin Hand
Date: 2022.09.16 11:47:07 -08'00'Chelsea Wright Digitally signed by Chelsea
Wright
Date: 2022.09.16 13:18:36 -08'00'
TD Shoe Depth: PBTD:
Jts.
1
2
3
87
Yes X No Yes X No
Fluid Description:
Liner hanger Info (Make/Model):Liner top Packer?:X Yes No
Liner hanger test pressure:X Yes No
Centralizer Placement:
Preflush (Spacer)
Type: Density (ppg) Volume pumped (BBLs)
Lead Slurry
Type:Sacks: Yield:
Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm):
Tail Slurry
Type:Sacks: Yield:
Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm):
Post Flush (Spacer)
Type: Density (ppg) Rate (bpm): Volume:
Displacement:
Type: Density (ppg) Rate (bpm): Volume (actual / calculated):
FCP (psi): Pump used for disp: X Yes No
Casing Rotated? Yes X No Reciprocated?X Yes No % Returns during job
Cement returns to surface? Yes X 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. PPG11.3
Shoe @ 9938 FC @ Top of Liner 6,2149,893.00
Floats Held
6% KCL Polymer Mud
CASING RECORD
County State Alaska Supv.Jay Murphy
Hilcorp Energy Company
CASING & CEMENTING REPORT
Lease & Well No.CLU 005RD2 Date Run 19-Sep-22
Setting Depths
Component Size Wt. Grade THD Make Length Bottom Top
BTC Baker 1.42 9,938.00 9,936.58
Csg Wt. On Hook:55,000 Type Float Collar:Baker round nose No. Hrs to Run:
11.3 4
100
1040
FI
R
S
T
S
T
A
G
E
12Tune Primed 30
135.1/140.1
1600
0
Halliburton
15.3 39
Bump press
CBL
Bump Plug?
18:05 9/19/2022 6,700
9,938.009,940.00
CEMENTING REPORT
Csg Wt. On Slips:
6%KCl/Polymer
12.5 90
Type of Shoe: Casing Crew:
7" x 9 5/8" SLZPX, HRDE w/7.37" PBR
www.wellez.net WellEz Information Management LLC ver_04818br
4
Baker-Loc jt 4 1/2 12.6 L-80 BTC 41.41 9,936.58
Float Coller 5 BTC Baker 1.38 9,895.17 9,893.79
Baker-Loc jt 4 1/2 12.6 L-80 BTC 41.39 9,893.79 9,852.40
Landing Collar 5 BTC Baker 1.08 9,852.40 9,851.32
Baker-Loc jt 4 1/2 12.6 L-80 DWC 41.41 9,851.32 9,809.91
4 1/2" DWC casing 4 1/2 12.6 L-80 DWC 3,563.98 9,809.91 6,245.93
X/O's 7" 563 x 4 1/2" DWC 7 7.23 6,245.93 6,238.70
7" x 9 5/8" SLZXP/HRDE 8 5/8 Baker 24.48 6,238.70 6,214.22
l ll 250 2.02
l ll 185 1.18
4
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: 11/28/2022
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
SFTP DATA TRANSMITTAL T#20221128-1
Well API #PTD #Log Date Log
Company Log Type AOGCC
Eset#
CLU 13 50133206460000 214171 11/12/2022 Halliburton PERF
CLU 05RD2 50133204740200 222092 11/11/2022 Halliburton PPROF
KBU 22-06 50133205500000 205054 2/26/2022 Halliburton RMX
KBU 22-06 50133205500000 205054 2/26/2022 Halliburton TMD3D
KBU 33-06X 50133205290000 203183 2/28/2022 Halliburton RMX
KBU 33-06X 50133205290000 203183 2/28/2022 Halliburton TMD3D
KDU 4 50133201760000 169012 11/7/2022 Halliburton EPX
KDU 4 50133201760000 169012 11/7/2022 Halliburton MFC24
KU 43-6RD 50133100910100 201231 11/8/2022 Halliburton EPX
KU 43-6RD 50133100910100 201231 11/8/2022 Halliburton MFC24
Please include current contact information if different from above.
By Meredith Guhl at 10:05 am, Nov 29, 2022
T37319
T37313
T37320
T37320
T37321
T37321
T37322
T37322
T37323
T37323
CLU 05RD2 50133204740200 222092 11/11/2022 Halliburton PPROF
Meredith Guhl Digitally signed by Meredith Guhl
Date: 2022.11.29 11:15:51 -09'00'
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: 11/28/2022
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
SFTP DATA TRANSMITTAL T#20221128
Well API #PTD #Log Date Log
Company Log Type AOGCC
Eset#
SD-06 50133205820000 208160 9/12/2022 Yellowjacket PERF
SRU 32A-33 50133101640100 191014 9/21/2022 Yellowjacket PERF
KBU 42-06Y 50133206340000 214089 9/26/2022 Yellowjacket GPT-PERF
CLU 05RD2 50133204740200 222092 9/29/2022 Yellowjacket PERF
SCU 344-33 50133202930100 218054 10/8/2022 Yellowjacket PERF-GPT
Please include current contact information if different from above.
By Meredith Guhl at 9:48 am, Nov 29, 2022
T37313
T37314
T37315
T37316
T37317
CLU 05RD2 50133204740200 222092 9/29/2022 Yellowjacket PERF
Meredith Guhl Digitally signed by Meredith Guhl
Date: 2022.11.29 09:55:33 -09'00'
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
CLU 05RD2 50133204740200 222092 10/18/2022 AK E-Line Perf_GPT
Meredith Guhl Digitally signed by Meredith Guhl
Date: 2022.11.21 14:55:38 -09'00'
1
Regg, James B (OGC)
From:Ryan Thompson <Ryan.Thompson@hilcorp.com>
Sent:Monday, October 10, 2022 7:22 PM
To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC)
Subject:BOPE Test Report CLU 05RD2
Attachments:[EXTERNAL] Re: AOGCC Test Witness Notification Request: BOPE, CTU Fox Energy 8, CLU 05RD2;
BOPE Test Report CLU 05RD2 10-9-2022.xlsx
Please find the BOPE test report for CLU 05RD2.
Thank you,
Ryan Thompson
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.
Cannery Loop Unit 5RD2
PTD 2220920
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.:8 DATE:10/9/22
Rig Rep.:Rig Email:
Operator:
Operator Rep.:Op. Rep Email:
Well Name:PTD #2220920 Sundry #322-562
Operation:Drilling:Workover:X Explor.:
Test:Initial:X Weekly:Bi-Weekly:Other:
Rams:250/4000 Annular:NA Valves:250/4000 MASP:3939
MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES:
Test Result/Type Test Result Quantity Test Result
Housekeeping P Well Sign P Upper Kelly 0 NA
Permit On Location P Hazard Sec.P Lower Kelly 0 NA
Standing Order Posted P Misc.NA Ball Type 0 NA
Test Fluid Other Inside BOP 0 NA
FSV Misc 0 NA
BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm
Stripper 1 1.75"P Trip Tank NA NA
Annular Preventer 0 NA NA Pit Level Indicators NA NA
#1 Rams 1 1.75" B/S P Flow Indicator NA NA
#2 Rams 1 1.75" P/S P Meth Gas Detector NA NA
#3 Rams 0 NA NA 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)2980 P
Kill Line Valves 2 2"P Pressure After Closure (psi)2600 P
Check Valve 0 NA NA 200 psi Attained (sec)3 P
BOP Misc 0 NA NA Full Pressure Attained (sec)8 P
Blind Switch Covers:All stations Yes
CHOKE MANIFOLD:Bottle Precharge:P
Quantity Test Result Nitgn. Bottles # & psi (Avg.):0 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 19 P
Coiled Tubing Only:#2 Rams 16 P
Inside Reel valves 1 P #3 Rams 0 NA
#4 Rams 0 NA
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 days. HCR Kill 0 NA
Remarks:
AOGCC Inspection
24 hr Notice Yes Date/Time 10/8/22 10:47
Waived By
Test Start Date/Time:10/9/2022 10:00
(date)(time)Witness
Test Finish Date/Time:10/9/2022 12:00
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Jim Regg
Fox
Test Fluid: Methanol. Bottle Precharge: 1400 psi.
Landry Lynn
Hilcorp
Ryan Thompson
CLU 05RD2
Test Pressure (psi):
trais@foxenergyak.com
ryan.thompson@hilcorp.com
Form 10-424 (Revised 08/2022)2022-1009_BOP_Fox8_CLU-5RD2
Alaska LLC
jbr
J. Regg; 11/18/2022
From:Regg, James B (OGC)
To:AOGCC Records (CED sponsored)
Subject:BOP - Fox 8 Service Coil
Date:Friday, November 18, 2022 2:32:15 PM
Attachments:2022-1009_BOP_Fox8_CLU-5RD2.pdf
Cannery Loop Unit 5RD2 (PTD 2220920)
Jim Regg
Supervisor, Inspections
AOGCC
333 W. 7th Ave, Suite 100
Anchorage, AK 99501
907-793-1236
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: 11/17/2022
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
SFTP DATA TRANSMITTALT#20221117-1
Log Print Files and Log Data Files:
Well API #PTD #Log Date Log Company Log Type AOGCC
Eset#
CLU 05RD2 50133204740200 222092 9/27/2022 Yellowjacket CBL
CLU 10 50133205530000 205106 8/7/2022 Yellowjacket CBL-PLUG
CLU 10RD 50133205530100 222113 9/30/2022 Yellowjacket CBL
CLU 10RD 50133205530100 222113 10/16/2022 Halliburton RCBL
CLU 13 50133206460000 214171 10/2/2022 Yellowjacket CBL
Please include current contact information if different from above.
T37265
T37266
T37267
T37267
T37268
By Meredith Guhl at 1:32 pm, Nov 17, 2022
CLU 05RD2 501 33204740200 222092 9 /27/2022 Ye llowjac ke t CBL
Meredith Guhl Digitally signed by Meredith Guhl
Date: 2022.11.17 13:32:28 -09'00'
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: 11/8/2022
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
SFTP DATA TRANSMITTAL T#20221108-1
Well API #PTD #Log Date Log
Company Log Type AOGCC
Eset#
HVB-16A 502312004001 222070 8/13/2022 AK E-Line Perf
HVB-16A 502312004001 222070 8/17/2022 AK E-Line GPT/Perf
CLU 05RD2 501332047402 222092 10/5/2022 AK E-Line GPT/CIBP/Cement
NCI B-03A 508832009501 222048 9/27/2022 AK E-Line Perf
Please include current contact information if different from above.
T37249
T37249
T37250
T37251
CLU 05RD2 501332047402 222092 10/5/2022 AK E-Line GPT/CIBP/Cement
Kayla
Junke
Digitally signed by
Kayla Junke
Date: 2022.11.09
11:41:18 -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: 11/01/2022
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
DATA TRANSMITTAL
WELL: CLU-05RD2
PTD: 222-092
API: 50-133-20474-02-00
FINAL OPENHOLE WIRELINE LOGS (09/17/202)
x GR, SP (5”/100’ MD Color Log)
x Data File (LAS)
SFTP Transfer - Data Folders:
Please include current contact information if different from above.
PTD: 222-092
T37217
Kayla Junke
Digitally signed by Kayla
Junke
Date: 2022.11.02 09:37:31
-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
Date: 10/05/2022
To: Alaska Oil & Gas Conservation Commission
Petroleum Geology Assistant
333 W 7th Ave Ste 100
Anchorage, AK 99501
DATA TRANSMITTAL
RECEIVED
OCT 0 5 2022
WELL: CLu-05RD2 AOOCC
PTD: 222-092
API: 50-133-20474-02-00
Washed and Dried Well Samples (TD: 09/15/2022)
B Set (2 Boxes):
WELL
BOX
SAMPLE INTERVAL (FEET i MD)
CLU 05RD2
BOX 1 OF 2
6660' - 8430' MD
CLU 05RD2
BOX 2 OF 2
8430' - 9940' MD (TD)
Please include current contact information if different from above.
Please acknowledge receipt by signing and returning one copy of this transmittal.
Received 8 Date:
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: 10/04/2022
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
DATA TRANSMITTAL
WELL: CLU-05RD2
PTD: 222-092
API: 50-133-20474-02-00
FINAL LWD FORMATION EVALUATION LOGS (09/10/2022 to 09/16/2022)
x ROP, PCG, ADR, ALD, CTN (2” & 5” MD/TVD Color Logs)
x Final Definitive Directional Survey
SFTP Transfer - Data Folders:
Please include current contact information if different from above.
PTD:222-092
T37101
Kayla
Junke
Digitally signed by
Kayla Junke
Date: 2022.10.05
10:09:13 -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: 10/04/2022
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
DATA TRANSMITTAL
CLU-05RD2
PTD: 222-092
API: 50-133-20474-02-00
MUDLOGS - EOW DRILLING REPORTS (09/10/2022 to 09/15/2022)
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:222-092
T37101
Kayla Junke
Digitally signed by Kayla
Junke
Date: 2022.10.05 10:08:08
-08'00'
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37'
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
*All BOPE reports are due to the agency within 5 days of testing*
SSu bm it t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov
Rig Owner: Rig No.:8 DATE: 9/26/22
Rig Rep.: Rig Email:
Operator:
Operator Rep.: Op. Rep Email:
Well Name:PTD #2220920 Sundry #322-562
Operation: Drilling: Workover: x Explor.:
Test: Initial: x Weekly: Bi-Weekly: Other:
Rams:250/4000 Annular:N/A Valves:250/4000 MASP:3939
MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES:
Test Result/Type Test Result Quantity Test Result
Housekeeping P Well Sign P Upper Kelly 0NA
Permit On Location P Hazard Sec.NA Lower Kelly 0NA
Standing Order Posted P Misc.NA Ball Type 0NA
Test Fluid Water Inside BOP 0NA
FSV Misc 0NA
BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm
Stripper 1 1.75"P Trip Tank NA NA
Annular Preventer 0NAPit Level Indicators NA NA
#1 Rams 1 1.75" BS P Flow Indicator NA NA
#2 Rams 1 1.75" PS P Meth Gas Detector NA NA
#3 Rams 0NAH2S Gas Detector NA NA
#4 Rams 0NAMS Misc 0NA
#5 Rams 0NA
#6 Rams 0NAACCUMULATOR SYSTEM:
Choke Ln. Valves 2 2"P Time/Pressure Test Result
HCR Valves 0NASystem Pressure (psi)3000 P
Kill Line Valves 2 2"P Pressure After Closure (psi)2375 P
Check Valve 0NA200 psi Attained (sec)6 P
BOP Misc 0NAFull Pressure Attained (sec)15 P
Blind Switch Covers: All stations YES
CHOKE MANIFOLD:Bottle Precharge: 1400 P
Quantity Test Result Nitgn. Bottles # & psi (Avg.): NA NA
No. Valves 5P ACC Misc 0NA
Manual Chokes 2P
Hydraulic Chokes 0NA Control System Response Time:Time (sec) Test Result
CH Misc 0NA Annular Preventer 0 NA
#1 Rams 15 P
Coiled Tubing Only:#2 Rams 14 P
Inside Reel valves 1P #3 Rams 0 NA
#4 Rams 0 NA
Test Results #5 Rams 0 NA
#6 Rams 0 NA
Number of Failures:0 Test Time:2.5 HCR Choke 0 NA
Repair or replacement of equipment will be made within days. HCR Kill 0 NA
Remarks:
AOGCC Inspection
24 hr Notice YES Date/Time 9/25/22 09:50
Waived By
Test Start Date/Time:9/26/2022 11:00
(date) (time)Witness
Test Finish Date/Time:9/26/2022 13:30
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Fox
Accumulator system 4 bottles at 1400psi.
Did not receive a response from AOGCC to witness/waive BOPE test
Terence Rais
Hilcorp Alaska
Brad Gathman
CLU 05RD2
Test Pressure (psi):
Trais@FoxEnergyAK.com
brad.gathman@hilcorp.com
Form 10-424 (Revised 08/2022)2022-0926_BOP_Fox8_CLU-05RD2
9
9
9
9 9
9
9 9
9 9
9
9
-5HJJ
From:McLellan, Bryan J (OGC)
To:Chad Helgeson
Subject:CLU-05RD2 (PTD 222-092) perf sundry
Date:Friday, September 23, 2022 3:24:00 PM
Chad,
Hilcorp has approval to perform steps 1-10 in the procedure while the sundry application is being
processed. FYI, the sundry number is 322-562.
Conditions of approval:
1. CT BOP test to 4000 psi
2. Submit CBL to AOGCC for approval to proceed with perfs.
Regards
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
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Tuesday, October 25, 2022
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Sully Sullivan
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
Hilcorp Alaska, LLC
05RD2
CANNERY LOOP UNIT 05RD2
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 10/25/2022
05RD2
50-133-20474-02-00
222-092-0
N
SPT
5042
2220920 2500
0 340 340 345
0 220 220 220
INITAL P
Sully Sullivan
9/22/2022
Initial MIT of IA to 2500 psi per PTD after new perfs
30 MinPretestInitial15 Min
Well Name
Type Test
Notes:
Interval P/F
Well
Permit Number:
Type Inj TVD
PTD Test psi
API Well Number Inspector Name:CANNERY LOOP UNIT 05RD2
Inspection Date:
Tubing
OA
Packer Depth
0 2700 2700 2700IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitSTS220930102444
BBL Pumped:3.5 BBL Returned:3.7
Tuesday, October 25, 2022 Page 1 of 1
9
9
9
9
9
*DV3URGXFHU
MIT of IA
James B. Regg Digitally signed by James B. Regg
Date: 2022.10.26 10:56:58 -08'00'
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Tuesday, October 25, 2022
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Sully Sullivan
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
Hilcorp Alaska, LLC
05RD2
CANNERY LOOP UNIT 05RD2
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 10/25/2022
05RD2
50-133-20474-02-00
222-092-0
N
SPT
5042
2220920 4000
0 4100 4100 4100
0 0 0 0
INITAL P
Sully Sullivan
9/22/2022
Initial MIT of Tubing after new perfs
30 MinPretestInitial15 Min
Well Name
Type Test
Notes:
Interval P/F
Well
Permit Number:
Type Inj TVD
PTD Test psi
API Well Number Inspector Name:CANNERY LOOP UNIT 05RD2
Inspection Date:
Tubing
OA
Packer Depth
0 370 365 360IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitSTS220930100422
BBL Pumped:2.3 BBL Returned:2.5
Tuesday, October 25, 2022 Page 1 of 1
9
9
9
9 9
9
9
*DV3URGXFHU
MIT of Tubing
James B. Regg Digitally signed by James B. Regg
Date: 2022.10.26 10:54:41 -08'00'
From:Regg, James B (OGC)
To:AOGCC Records (CED sponsored)
Subject:FW: [EXTERNAL] RE: Incident on Rig 169
Date:Monday, September 12, 2022 2:01:44 PM
Cannery Loop Unit 5RD2 (PTD 2220920)
Jim Regg
Supervisor, Inspections
AOGCC
333 W. 7th Ave, Suite 100
Anchorage, AK 99501
907-793-1236
From: Jay Murphy - (C) <Jay.Murphy@hilcorp.com>
Sent: Monday, September 12, 2022 10:54 AM
To: Regg, James B (OGC) <jim.regg@alaska.gov>
Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Subject: RE: [EXTERNAL] RE: Incident on Rig 169
Jim,
Saturday September 10, 2022 at 08:30 am we completed the 20’ of new formation below the
window we milled and the whipstock representative completed dressing and dry drifting the window
after we circulated a bottoms up we parked the string at 6645’ and rigged up our testing equipment
and performed the LOT. I went to the office to pass on the results of the LOT to Mr. Mclaughlin. At
about 10:15 am I was notified that the pipe had been pulled into the VBRs which were in the Upper
pipe rams. Looking back on the Pason system the event took place at 10:00 am. We were concerned
about any debris that may cause more damage in the Upper ram cavity. We connected the trip tank
to the IA with a tee and closed the lower 4-1/2” fixed rams and opened up the upper pipe rams to
inspect. The rams were damaged but there was no broken parts laying in the ram cavities. We
buttoned up the upper ram doors and we observed that the turbocharger on the rig floor motor was
burnt up so we replaced that too. It was 14:00 hours when we verified no pressure under the lower
pipe rams and opened the well and POOH with the milling assembly.
Thank You and Best Regards,
Jay Murphy/ DSM
Hilcorp Alaska, LLC
HAK Rig 169
Office: 907-283-1369
Cell: 907-715-9211
Jay.Murphy@Hilcorp.com
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ϰ͘WhŵŽƚŽƌΘŵŝůů͕Z/,ĂŶĚŵŝůůĨƌŽŵƚĂŐĚĞƉƚŚ;ĞdžƉĞĐƚƐŽŵĞĐĞŵĞŶƚƐƚƌŝŶŐĞƌƐĨƌŽŵďƵŵƉŝŶŐƉůƵŐ
ϱďďůƐĞĂƌůLJͿƚŽWdŽĨϵ͕ϴϱϭ͛ŽƌƚŝůůƐƚŽƉƉĞĚƉƌŽŐƌĞƐƐĂƚůĞĂƐƚďĞůŽǁϵ͕ϳϱϬ͛
ϱ͘ŝƌĐŽƵƚϭϭ͘ϯƉƉŐŵƵĚƚŽϴ͘ϰƉƉŐǁĂƚĞƌ͘
ϲ͘D/Zh ͲůŝŶĞ͕WdůƵďƌŝĐĂƚŽƌƚŽϮϱϬϬƉƐŝ,ŝŐŚͬϮϱϬƉƐŝ>Žǁ;ŶŽŽƉĞ ŶƉĞƌĨƐͿ
ϳ͘Z/,ĂŶĚůŽŐ>
ϴ͘Z ůŝŶĞ
ϵ͘dZ/,ǁŝƚŚũĞƚŶŽnjnjůĞ͕ƵŶůŽĂĚĨůƵŝĚĨƌŽŵƚŚĞǁĞůůďŽƌĞǁŝƚŚŶŝƚ ƌŽŐĞŶ͕ůĞĂǀĞEϮƉƌĞƐƐƵƌĞŽŶǁĞůů
ƚŽĚĞƐŝƌĞĚƵŶĚĞƌďĂůĂŶĐĞĨƌŽŵƚŚĞZĞƐĞƌǀŽŝƌ ŶŐŝŶĞĞƌ;ĞdžƉĞĐƚϮϱϬϬͲϯϬϬϬƉƐŝͿ
ϭϬ͘ZDKĐŽŝůƚƵďŝŶŐ
ϭϭ͘Zh ͲůŝŶĞ͕WdůƵďƌŝĐĂƚŽƌƚŽϰϬϬϬƉƐŝ,ŝŐŚͬϮϱϬƉƐŝ>Žǁ
ϭϮ͘WĞƌĨŽƌĂƚĞhƉƉĞƌdLJŽŶĞŬƐĂŶĚǁŝƚŚϲϬĚĞŐƉŚĂƐĞĚŚŽůůŽǁĐĂƌƌŝĞƌƉĞƌĨŐƵŶƐ
WŽŽů^ĂŶĚƐdŽƉ;DͿƚŵ;DͿdŽƉ;dsͿƚŵ;dsͿ&d
hƉƉĞƌdLJŽŶĞŬhdϱцϵ͕ϳϬϯΖцϵ͕ϳϭϬΖцϴ͕ϮϬϴ͛цϴ͕Ϯϭϰ͛цϳΖ
DĂŬĞĐŽƌƌĞůĂƚŝŽŶƉĂƐƐĂŶĚƐĞŶĚůŽŐŝŶƚŽKƉĞƌĂƚŝŽŶƐ ŶŐŝŶĞĞƌ͕ZĞƐĞƌǀŽŝƌ ŶŐŝŶĞĞƌĂŶĚƚŚĞ'ĞŽůŽŐŝƐƚ͘
D 5HFRUGLQLWLDODQGPLQXWHWXELQJSUHVVXUHVDIWHUILULQJ
0,77 DQG 0,7,$ GRQH ZLWK WKH ULJ EMP
ƚŚĞƚƵďŝŶŐǁŝůůďĞ
ƚĞƐƚĞĚƚŽϰϬϬϬƉƐŝĂŶĚĐĂƐŝŶŐƚŽϮϱϬϬƉƐŝ͘
6XEPLW &%/ WR $2*&& IRU DSSURYDO WR SURFHHG ZLWK SHUIV EMP
tĞůůtŽƌŬWƌŽŐŶŽƐŝƐ
ď͘ďŽǀĞƉĞƌĨƐǁŝůůďĞƐŚŽƚŝŶƚŚĞhƉƉĞƌdLJŽŶĞŬ'ĂƐWŽŽůŐŽǀĞƌŶĞĚďLJKϮϯϭ͘
ϭϯ͘Z Ͳ>ŝŶĞhŶŝƚĂŶĚƚƵƌŶǁĞůůŽǀĞƌƚŽƉƌŽĚƵĐƚŝŽŶ
ϭϰ͘KƉĞƌĂƚŝŽŶƐƚŽĨůŽǁǁĞůůĂŶĚƚĞƐƚ͕
/ĨĐŽŵŵĞƌĐŝĂůƌĂƚĞƐĂƌĞĂĐŚŝĞǀĞĚĂŶĂƉƉůŝĐĂƚŝŽŶĨŽƌĐŽŵŵŝŶŐůŝŶŐǁŝůůďĞƐƵďŵŝƚƚĞĚƚŽK'ĨŽƌ
ƌĞǀŝĞǁ͘
ϭϱ͘dĞƐƚ^s^ĂƐƉĞƌϮϬϮϱ͘Ϯϲϱ͘
ĂͿEŽƚŝĨLJK'ϮϰŚƌƐŝŶĂĚǀĂŶĐĞŽĨƚĞƐƚŝŶŐ^s^
/ĨŽŵŵĞƌĐŝĂůƌĂƚĞƐĂƌĞŶŽƚĂĐŚŝĞǀĞĚďLJƚŚĞhƉƉĞƌdLJŽŶĞŬƐĂŶĚ
ϭϲ͘D/Zh ůŝŶĞĂŶĚEϮƉƵŵƉƚƌƵĐŬ
ϭϳ͘WƌĞƐƐƵƌĞƚĞƐƚĞƋƵŝƉŵĞŶƚƚŽϰ͕ϬϬϬƉƐŝ,ŝŐŚͬϮϱϬƉƐŝ>Žǁ
ϭϴ͘ ůŝŶĞƌƵŶWdƚŽĨŝŶĚĨůƵŝĚůĞǀĞů
ϭϵ͘ZhEϮĂŶĚƉƵƐŚĨůƵŝĚďĞůŽǁϵ͕ϭϱϬ͛;ǀĞƌŝĨLJĨůƵŝĚĚĞƉƚŚǁŝƚŚWdͿ
ϮϬ͘WhϰͲϭͬϮ͟/W͕Z/,ĂŶĚƐĞƚĂƚΕϵ͕ϲϳϴ͛;ǁŝƚŚŝŶϱϬĨƚŽĨƚŚĞƚŽƉƉĞƌĨŝŶdLJŽŶĞŬƐĂŶĚƐͿ
Ϯϭ͘ƵŵƉďĂŝůϮϱĨƚŽĨĐĞŵĞŶƚŽŶƚŽƉŽĨƉůƵŐ;ĞƐƚdŽΕϵ͕ϲϱϯ͛DͿ
ϮϮ͘WĞƌĨŽƌĂƚĞĞůƵŐĂ'ĂƐƐĂŶĚƐǁŝƚŚϲϬĚĞŐƉŚĂƐĞĚŚŽůůŽǁĐĂƌƌŝĞƌƉĞƌĨŐƵŶƐ
WŽŽů^ĂŶĚƐdŽƉ;DͿƚŵ;DͿdŽƉ;dsͿƚŵ;dsͿ&d
ĞůƵŐĂ>ϱͲ>цϳ͕ϴϴϬΖцϵ͕ϭϭϭΖцϲ͕ϱϲϱ͛цϳ͕ϲϳϬ͛цϭ͕ϮϯϭΖ
DĂŬĞĐŽƌƌĞůĂƚŝŽŶƉĂƐƐĂŶĚƐĞŶĚůŽŐŝŶƚŽKƉĞƌĂƚŝŽŶƐ ŶŐŝŶĞĞƌ͕ZĞƐĞƌǀŽŝƌ ŶŐŝŶĞĞƌĂŶĚƚŚĞ'ĞŽůŽŐŝƐƚ͘
D 5HFRUGLQLWLDODQGPLQXWHWXELQJSUHVVXUHVDIWHUILULQJ
ď͘ďŽǀĞƉĞƌĨƐǁŝůůďĞƐŚŽƚŝŶƚŚĞĞůƵŐĂ'ĂƐWŽŽůŐŽǀĞƌŶĞĚďLJKϮϯϭ
Đ͘ ƐƚŝŵĂƚĞĚϰϴϯĨƚŽĨĂĐƚƵĂůƉĞƌĨƐǁŝůůďĞƐŚŽƚŽǀĞƌƚŚŝƐϭ͕ϮϯϭĨƚŝŶƚĞƌǀĂůŝŶƚŚĞ>ŽǁĞƌ
ĞůƵŐĂ^ĂŶĚƐ
Ϯϯ͘/Ĩ^s^ǁĂƐŶŽƚƚĞƐƚĞĚĚƵƌŝŶŐhƉƉĞƌdLJŽŶĞŬ'ĂƐƚĞƐƚ͕dĞƐƚ^s^ĂƐƉĞƌϮϬϮϱ͘Ϯϲϱ͘
Ă͘EŽƚŝĨLJK'ϮϰŚƌƐŝŶĂĚǀĂŶĐĞŽĨƚĞƐƚŝŶŐ^s^
ͲůŝŶĞWƌŽĐĞĚƵƌĞ;ŽŶƚŝŶŐĞŶĐLJͿ
ϭ͘/ĨĂŶLJnjŽŶĞƉƌŽĚƵĐĞƐƐĂŶĚĂŶĚͬŽƌǁĂƚĞƌŽƌŶĞĞĚƐŝƐŽůĂƚĞĚ͗
Ϯ͘D/Zh Ͳ>ŝŶĞĂŶĚƉƌĞƐƐƵƌĞĐŽŶƚƌŽůĞƋƵŝƉŵĞŶƚ͘WdůƵďƌŝĐĂƚŽƌƚŽϮϱϬƉƐŝ>ŽǁͬϮ͕ϱϬϬƉƐŝ,ŝŐŚ͘
ϯ͘Z/,ĂŶĚƐĞƚĂĂƐŝŶŐWĂƚĐŚŽƌƐĞƚĂ/WĂďŽǀĞƚŚĞnjŽŶĞĂŶĚĚƵŵ ƉϮϱ͛ŽĨĐĞŵĞŶƚŽŶƚŽƉŽĨ
ƚŚĞƉůƵŐ͘
ϰ͘/ĨŶĞĐĞƐƐĂƌLJƚŽĐůĞĂŶŽƵƚŽƌƵŶůŽĂĚǁĞůů͕ZhƐĂŵĞĐŽŝůĞƋƵŝƉŵĞŶƚƵƐĞĚŝŶŝŶŝƚŝĂůĐŽŵƉůĞƚŝŽŶ
Ă͘dĞƐƚKWƐ͕ϰϬϬϬƉƐŝ,ŝŐŚͬϮϱϬƉƐŝ>Žǁ
ď͘ůĞĂŶŽƵƚǁŝƚŚEϮŽƌĨŽĂŵ
Đ͘^ĞƚϰͲϭͬϮ͟ƉůƵŐŽƌƉĂƚĐŚ
ƚƚĂĐŚŵĞŶƚƐ͗
ϭ͘WƌŽƉŽƐĞĚtĞůů^ĐŚĞŵĂƚŝĐ
Ϯ͘ŽŝůdƵďŝŶŐKWŝĂŐƌĂŵ
ϯ͘^ƚĂŶĚĂƌĚEŝƚƌŽŐĞŶKƉĞƌĂƚŝŽŶƐ
hƉĚĂƚĞĚďLJ,ϬϵͲϮϭͲϮϬϮϮ
WƌŽƉŽƐĞĚ
ĂŶŶĞƌLJ>ŽŽƉhŶŝƚ
>hͲϬϱZϮ
Wd͗ϮϮϮͲϬϵϮ
W/͗ϱϬͲϭϯϯͲϮϬϰϳϰͲϬϮͲϬϬ
Wdсϵ͕ϴϱϭ͛ͬdsсϴ͕ϯϰϯ͛
dсϵ͕ϵϰϬ͛ͬdsсϴ͕ϰϮϰ͛
Z<ƚŽ'>сϭϴ͘ϭϮ͛
&LQJVD
)URP¶
¶0'
W Z&KZd/KE d/>
^ĂŶĚƐdŽƉ;DͿƚŵ;DͿdŽƉ;dsͿƚŵ;dsͿ&dĂƚĞ^ƚĂƚƵƐ
>ϱͲ>цϳ͕ϴϴϬΖцϵ͕ϭϭϭΖцϲ͕ϱϲϱ͛цϳ͕ϲϳϬ͛цϭ͕ϮϯϭΖdWƌŽƉŽƐĞĚ
hdϱцϵ͕ϳϬϯΖцϵ͕ϳϭϬΖцϴ͕ϮϬϴ͛цϴ͕Ϯϭϰ͛цϳΖdWƌŽƉŽƐĞĚ
^/E'Θdh/E' d/>
^ŝnjĞdLJƉĞtƚ'ƌĂĚĞŽŶŶ͘/dŽƉƚŵ
ϮϬ͟ŽŶĚƵĐƚŽƌϭϮϵͲtĞůĚͲ^ƵƌĨϭϰϮ͛
ϭϯͲϯͬϴΗ^ƵƌĨƐŐϲϭ͘Ϭ<ͲϱϱdϭϮ͘ϱϭϱ͟^ƵƌĨϮ͕ϵϳϬ͛
ϵͲϱͬϴ͟/ŶƚĞƌŵĞĚŝĂƚĞƐŐϱϯ͘ϱ>ͲϴϬdϴ͘ϱϯϱ͟^ƵƌĨϭ͕ϮϭϮ͛
ϵͲϱͬϴ͟/ŶƚĞƌŵĞĚŝĂƚĞƐŐϰϳWͲϭϭϬdϴ͘ϲϴϭ͟ϭ͕ϮϭϮ͛ϲ͕ϱϮϳ͛
ϳͲϱͬϴ͟/ŶƚĞƌŵĞĚŝĂƚĞ>ŶƌϮϵ͘ϳη>ͲϴϬ,LJĚϱϮϭϲ͘ϴϳϱ͟ϲ͕ϰϯϯ͛ϲ͕ϲϴϱ͛
ϰͲϭͬϮΗWƌŽĚ>ŶƌϭϮ͘ϲ>ͲϴϬtͬϯ͘ϵϱϴ͟ϲ͕Ϯϭϰ͛ϵ͕ϵϯϴ͛
ϰͲϭͬϮ͟dƵďŝŶŐϭϮ͘ϲ>ͲϴϬtͬϯ͘ϵϱϴ͟^ƵƌĨϲ͕Ϯϭϰ͛
Ϯ
ϮϬ͟
ϭϯͲϯͬϴ͟
ϭϲ͟
ŚŽůĞ
ϰͲϭͬϮ͟
: t >Zz d/>
EŽ͘ĞƉƚŚ/K/ƚĞŵ
ϭϭϰϭϯ͘ϴϭϯ͟´ĂŬĞƌ^ͲϱdZ^^^s
Ϯϲ͕Ϯϭϰ͛ϳ͘ϯϳ͟ϳ͟džϵͲϱͬϴ͟^>yW,Z >ŝŶĞƌƚŽƉƉĂĐŬĞƌ͕ǁͬϳ͘ϯϳ͟
WZ
ϯϲ͕ϰϯϯ͛ϯ͘ϵϱϴ͟ϲ͘ϴϳϱ͟ϳͲϱͬϴ͟yW>ŝŶĞƌdŽƉWĂĐŬĞƌ
KW E,K> ͬ D Ed d/>
ϭϯͲϯͬϴ͟&ƵůůLJĐĞŵĞŶƚĞĚǁŝƚŚϭϰϬďďůƐďĂĐŬƚŽƐƵƌĨĂĐĞ;>hͲϬϱŝŶϭϵϵϲͿ
ϵͲϱͬϴ͟
ϭϮͲϭͬϰ͟ŚŽůĞ͗WƵŵƉĞĚĨƌŽŵϵϭϳϴ͛D͘ϴϱϬƐdžƐůĞĂĚ;ϯϳϱďďůƐͿĂŶĚϭϬϲϵƐdžƐ
;ϮϮϮďďůƐͿƚĂŝů;>hͲϬϱŝŶϭϵϵϲͿϭϭͬϭϵͬϵϲh^/dƐŚŽǁƐϵͲϱͬϴ͟ĐĞŵĞŶƚĞĚƵƉƚŽĂƚ
ůĞĂƐƚϮϴϬϬ͛D;ƐƚŽƉƉĞĚůŽŐŐŝŶŐƚŚĞƌĞͿ
ϳͲϱͬϴ͟
ϴͲϭͬϮ͟ŚŽůĞ͗ĞŵĞŶƚĞĚǁŝƚŚϭϬϮ͘ϳďďůƐϭϱ͘ϯƉƉŐĐůĂƐƐ'͘ŚĂĚůŽƐƐĞƐĂŶĚŐŽƚŶŽ
ĐĞŵĞŶƚďĂĐŬƚŽƐƵƌĨĂĐĞ͘ϵͬϮϰͬϮϬ^DdƐŚŽǁƐŐŽŽĚĐĞŵĞŶƚƵƉƚŽĂƚůĞĂƐƚϲ͕ϱϮϱ
D;ďĞŚŝŶĚƚƵďŝŶŐĂďŽǀĞƚŚĂƚͿ
ϰͲϭͬϮ͟WůĂŶŶĞĚ͘dKΛϲ͕ϰϲϱ͛;ϱϬйĞdžĐĞƐƐͿʹdǁŝƚŚ>
ϰ
ϵͲϱͬϴ͟
ϭ
>hͲϬϱZ
;ďĂŶĚŽŶĞĚͿ
tŝŶĚŽǁΛ
ϲ͕ϲϲϲ͛
ϲͲϯͬϰ͟
ŚŽůĞ
ϳͲϱͬϴ͟
ϯ
^ƋƵĞĞnjĞĚƉĞƌĨƐ
ϳͬϮϮͬϮϮ
^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
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ϭϴ͘Ϳ ZDKEŝƚƌŽŐĞŶWƵŵƉŝŶŐhŶŝƚĂŶĚ>ŝƋƵŝĚEŝƚƌŽŐĞŶdƌĂŶƐƉŽƌƚ͘
CAUTION: This email originated from outside the State of Alaska mail system.
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From: Regg, James B (OGC) <jim.regg@alaska.gov>
Sent: Monday, September 12, 2022 10:32 AM
To: Jay Murphy - (C) <Jay.Murphy@hilcorp.com>
Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Subject: [EXTERNAL] RE: Incident on Rig 169
When I read the initial note (9/10) is sounds like the incident happened, the rig proceeded with
milling ops then pulled to replace rams. Doesn’t make sense. I am confused about the sequence of
events and would appreciate a summary timeline. Thank you.
Jim Regg
Supervisor, Inspections
AOGCC
333 W. 7th Ave, Suite 100
Anchorage, AK 99501
907-793-1236
From: Jay Murphy - (C) <Jay.Murphy@hilcorp.com>
Sent: Sunday, September 11, 2022 5:48 AM
To: Regg, James B (OGC) <jim.regg@alaska.gov>
Subject: FW: Incident on Rig 169
Jim,
After going through all of the statements and discussing with the crew the plan was to level the sub
base. The driller was the only one on the floor and he removed the sign from the brake handle of the
BOPE being closed and screwed into the testing assembly with the top drive. He pulled to release the
slips and kept pulling until the incident happened. When we got out of the hole we installed the 4-
1/2” Fixed rams, which did not test to begin with, Then we tried the VBRs that we had gotten from
Yellowjacket and they would not test. We then re-inserted the 4-1/2” fixed rams again as they had
new elements and did perform a successful 300/ 4000 psi. pressure test and would be happy to send
you the chart if needed..
Thank You and Best Regards,
Jay Murphy/ DSM
Hilcorp Alaska, LLC
HAK Rig 169
Office: 907-283-1369
Cell: 907-715-9211
Jay.Murphy@Hilcorp.com
From: Jay Murphy - (C)
Sent: Saturday, September 10, 2022 11:14 AM
To: jim.regg@alaska.gov
Subject: Incident on Rig 169
Jim,
At 10:00am our driller pulled into the upper pipe rams and pulled 40K over into the VBRs. I have
made notifications and wanted to keep you in the loop. We had just finished our LOT and I was in
the office informing the Engineer of the results when I was notified. The crew shimmed the sub.
Then the driller pulled into the UPRs. We completed milling the window and 20’ of new formation.
Right now we have the lower 4-1/2” fixed rams closed and are opening the upper ram doors to
ensure that there is no debris in the configuration. We will be POOH F/ 6645’ with our milling
assembly and laying it down and we will replace the rams and retest the upper pipe rams 250/
4000psi.
Thank You and Best Regards,
Jay Murphy/ DSM
Hilcorp Alaska, LLC
HAK Rig 169
Office: 907-283-1369
Cell: 907-715-9211
Jay.Murphy@Hilcorp.com
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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
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Alaska Oil and Gas
Conservation Commission
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
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Jessie L.
Chmielowski
Digitally signed by Jessie L.
Chmielowski
Date: 2022.08.04 09:04:00
-08'00'
11 SFD 8/582022
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From:Davies, Stephen F (OGC)
To:Carlisle, Samantha J (OGC); Guhl, Meredith D (OGC)
Subject:FW: [EXTERNAL] RE: CLU 05 RD2 (PTD 222-092) - Landownership Question
Date:Tuesday, August 2, 2022 6:34:02 PM
Sam, Meredith:
Please file the email below with the CLU 5RD2 Permit to Drill application.
Thanks and be well,
Steve
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use
of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended
recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or
steve.davies@alaska.gov.
From: Cody Terrell <cterrell@hilcorp.com>
Sent: Thursday, July 21, 2022 8:53 PM
To: Davies, Stephen F (OGC) <steve.davies@alaska.gov>
Cc: Boyer, David L (OGC) <david.boyer2@alaska.gov>
Subject: Re: [EXTERNAL] RE: CLU 05 RD2 (PTD 222-092) - Landownership Question
Steve,
This is correct. Hilcorp has 100% of the subsurface leased and 100% working interest owned by Hilcorp.
Regards,
Cody T. Terrell
Landman
Hilcorp Alaska,LLC
Cell: 713-870-4532
Office: 907-777-8432
From: Davies, Stephen F (OGC) <steve.davies@alaska.gov>
Sent: Wednesday, July 20, 2022 7:35:40 AM
To: Cody Terrell <cterrell@hilcorp.com>
Cc: Boyer, David L (OGC) <david.boyer2@alaska.gov>
Subject: [EXTERNAL] RE: CLU 05 RD2 (PTD 222-092) - Landownership Question
Cody,
From the records I have access to, here is what I’ve found regarding CLU 5 RD2:
Surface location in Hilcorp fee lease (formerly ADL 060569); wellbore passes thru private fee lease in which Hilcorp owns 100% working interest; top
productive interval and TD lie in ADL 324602.
Is this an accurate statement?
Thanks for your help and stay safe,
Steve Davies
AOGCC
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use
of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended
recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or
steve.davies@alaska.gov.
From: Davies, Stephen F (OGC)
Sent: Tuesday, July 19, 2022 8:33 AM
To: Cody Terrell (cterrell@hilcorp.com) <cterrell@hilcorp.com>
Cc: Boyer, David L (OGC) <david.boyer2@alaska.gov>
Subject: CLU 05 RD2 (PTD 222-092) - Landownership Question
Hi Cody,
Landownership in the CLU area is quite complex, so could you please clarify landownership along the CLU 5RD2 well path for me? As I understand it, the
surface location lies in the southeast portion of Section 7 , which is a former state lease (ADL 60659) now owned 100% by Hilcorp, and the portion of the
well that will lie beneath the Kenai River lies within current state lease ADL 324602 that is also owned by Hilcorp. Who is the landowner for the onshore
portion of the SW1/4SW1/4 of Section 8 that is crossed by CLU 05RD2 (the portion labeled as CWC Fisheries Inc)? If this is private land, is this leased by
Hilcorp?
Thanks for your help and stay safe,
Steve Davies
AOGCC
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use
of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended
recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or
steve.davies@alaska.gov.
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 anyattachments 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.
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Hilcorp Alaska, LLC
FEE ADL 60568
James Kenneth Foute
Hilcorp Alaska, LLC
FEE ADL 60568
Hilcorp Alaska, LLC
FEE AA-092401
Hilcorp Alaska, LLC
FEE ADL 60569
C W C FISHERIES INC
JOSEPH A COCHRAN
Hilcorp Alaska, LLC
FEE C-605069
Hilcorp Alaska, LLC
FEE C-605069
Hilcorp Alaska, LLC
FEE C-605069
ALASKA PACKERS ASSOCIATIONCHARLES R WEBBER
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Vertical Section at 53.00° (1000 usft/in)
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CLU-05RD2 wp03
Start Dir 12.5º/100' : 6665' MD, 5487.17'TVD : 30° RT TF
End Dir : 6682' MD, 5503.09' TVD
Start Dir 2º/100' : 6702' MD, 5521.7'TVD
End Dir : 6978.65' MD, 5773.82' TVD
Start Dir 2º/100' : 8587.12' MD, 7206.68'TVD
End Dir : 8706.51' MD, 7313.11' TVD
Total Depth : 11874.71' MD, 10138.5' TVD
Tyonek D6
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: Cannery Loop Unit 05
Ground Level: 20.50
+N/-S +E/-W Northing Easting Latitude Longitude
0.00 0.00 2388620.75 272695.38 60° 31' 55.840 N 151° 15' 43.471 W
SURVEY PROGRAM
Date: 2022-07-14T00:00:00 Validated: Yes Version:
Depth From Depth To Survey/Plan Tool
198.40 6440.40 Baker Hughes INTEQ MWD (Cannery Loop Unit 05) 3_MWD
6527.00 6665.00 Survey #1 (Cannery Loop Unit 05RD) 3_MWD_Interp Azi
6665.00 7000.00 CLU-05RD2 wp03 (Cannery Loop Unit 05RD2) 3_MWD_Interp Azi
7000.00 11874.71 CLU-05RD2 wp03 (Cannery Loop Unit 05RD2) 3_MWD+IFR1+MS+
FORMATION TOP DETAILS
TVDPath TVDssPath MDPath Formation
4923.50 4885.00 6077.40 Top CINGSA
5128.50 5090.00 6293.21 Base CINGSA
9988.50 9950.00 11706.51 Tyonek D6
REFERENCE INFORMATION
Co-ordinate (N/E) Reference:Well Cannery Loop Unit 05, True North
Vertical (TVD) Reference:Actual @ 38.50usft
Measured Depth Reference:Actual @ 38.50usft
Calculation Method:Minimum Curvature
Project:Kenai C.I.U.
Site:Cannery Loop Unit #1 Pad
Well:Cannery Loop Unit 05
Wellbore:Cannery Loop Unit 05RD2
Design:CLU-05RD2 wp03
CASING DETAILS
TVD TVDSS MD Size Name
5487.17 5448.67 6665.00 7 7" TOW
10138.50 10100.00 11874.71 4-1/2 4 1/2" x 6 3/4"
SECTION DETAILS
Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation
1 6665.00 19.63 52.13 5487.17 1944.87 2685.60 0.00 0.00 3315.27 Start Dir 12.5º/100' : 6665' MD, 5487.17'TVD : 30° RT TF
2 6682.00 21.50 55.03 5503.09 1948.41 2690.41 12.50 30.00 3321.24 End Dir : 6682' MD, 5503.09' TVD
3 6702.00 21.50 55.03 5521.70 1952.61 2696.41 0.00 0.00 3328.56 Start Dir 2º/100' : 6702' MD, 5521.7'TVD
4 6978.65 27.02 54.26 5773.82 2018.43 2789.04 2.00 -3.62 3442.15 End Dir : 6978.65' MD, 5773.82' TVD
5 8587.12 27.02 54.26 7206.68 2445.29 3382.23 0.00 0.00 4172.79 Start Dir 2º/100' : 8587.12' MD, 7206.68'TVD
6 8706.51 26.90 49.00 7313.11 2478.86 3424.64 2.00 -95.30 4226.85 End Dir : 8706.51' MD, 7313.11' TVD
7 11706.51 26.90 49.00 9988.50 3369.33 4449.01 0.00 0.00 5580.85 CLU-05RD2 wp01 Tgt
8 11874.71 26.90 49.00 10138.50 3419.26 4506.44 0.00 0.00 5656.77 Total Depth : 11874.71' MD, 10138.5' TVD
140015751750192521002275245026252800297531503325350036753850South(-)/North(+) (350 usft/in)1750 1925 2100 2275 2450 2625 2800 2975 3150 3325 3500 3675 3850 4025 4200 4375 4550 4725 4900 5075West(-)/East(+) (350 usft/in)CLU-05RD2 wp01 TgtC L U0 5 R D
CLU059 5/8" 7" TOW4 1/2" x 6 3/4"37504000425 04 500475 050005 2 5 0
5 5 0 0
5 7 5 0
6 0 0 0
6 2 5 0
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6 7 5 0
7 0 0 0725075007750800082508500875090009250950097501000010139CLU-05R D 2 w p03Start Dir 12.5º/100' : 6665' MD, 5487.17'TVD : 30° RT TFEnd Dir : 6682' MD, 5503.09' TVDStart Dir 2º/100' : 6702' MD, 5521.7'TVDEnd Dir : 6978.65' MD, 5773.82' TVDStart Dir 2º/100' : 8587.12' MD, 7206.68'TVDEnd Dir : 8706.51' MD, 7313.11' TVDTotal Depth : 11874.71' MD, 10138.5' TVDCASING DETAILSTVDTVDSS MDSize Name5487.17 5448.67 6665.00 7 7" TOW10138.50 10100.00 11874.71 4-1/2 4 1/2" x 6 3/4"Project: Kenai C.I.U.Site: Cannery Loop Unit #1 PadWell: Cannery Loop Unit 05Wellbore: Cannery Loop Unit 05RD2Plan: CLU-05RD2 wp03WELL DETAILS: Cannery Loop Unit 05Ground Level: 20.50+N/-S +E/-WNorthingEastingLatitudeLongitude0.00 0.002388620.75 272695.38 60° 31' 55.840 N 151° 15' 43.471 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Cannery Loop Unit 05, True NorthVertical (TVD) Reference:Actual @ 38.50usftMeasured Depth Reference:Actual @ 38.50usftCalculation Method:Minimum Curvature
140015751750192521002275245026252800297531503325350036753850South(-)/North(+) (350 usft/in)1750 1925 2100 2275 2450 2625 2800 2975 3150 3325 3500 3675 3850 4025 4200 4375 4550 4725 4900 5075West(-)/East(+) (350 usft/in)500055006000650070007500CLU 153000350040004500Cannery Loop Unit 076 0 0 0
6 5 0 07000750080008500CLU #134 5 0 0
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5 5 0 0Cannery Loop Unit 08550060006 5 0075008 0 0 08500 CANNERY LOOP UNIT 01RDCANNERY LOOP UNIT 01RDPB155006000650070007 5 0 0
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1 0 2 1 2Cannery Loop Unit 0140004 5 005000550060006500700075008000100001 1 25 3
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7 0 0 07500900095001000010139CLU-05RD2 wp03Project: Kenai C.I.U.Site: Cannery Loop Unit #1 PadWell: Cannery Loop Unit 05Wellbore: Cannery Loop Unit 05RD2Plan: CLU-05RD2 wp03
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