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Alaska Oil and Gas Conservation Commission
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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: _0 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): North Cook Inlet Unit
GL:N/A 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- 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 25.050 101 (ft MSL)
22. Logs Obtained:
23.
BOTTOM
30" H-40 381'
20" H-40 1,990'
13-3/8" N-80 2,639'
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.
1,990'
Surface
N/A
SIZE DEPTH SET (MD)If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date perf'd or liner run):
Surface 2,640' (TOW)
Surface
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
1820 sx18-1/2
24"
Driven
Surface 1142 sx
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
Hilcorp Alaska, LLC
WAG
Gas
10/31/2023 222-098 / 323-176 / 322-511
SETTING DEPTH TVD
2585179
TOP HOLE SIZE
LWD (AGR, PWD, EWR-M5, ALD, CTN, DDS2)
N/A
2,640' MD / 2,639' TVD
N/A
3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503
331994 2586723
50-883-20032-01-00August 22, 2022
N/A
NCIU A-12ASeptember 1, 20221254' FNL, 928' FWL, Sec 6, T11N, R9W, SM, AK
126.6
Tertiary System Gas Pool
ADL 17589
7,352' MD / 6,911' TVD
2,640' MD / 2,639' TVD
N/A
CASING, LINER AND CEMENTING RECORD
Gas-Oil Ratio:
AMOUNT
PULLED
N/A
331029
TOP
SETTING DEPTH MD
suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud
log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing
collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary.
PACKER SET (MD/TVD)
30"
BOTTOMCASINGWT. PER
FT.GRADE CEMENTING RECORD
N/A
2466' FSL, 33' FWL, Sec 6, T11N, R9W, SM, AK
Choke Size:
Surface
Per 20 AAC 25.283 (i)(2) attach electronic information
72# Surface
-
133#
381'
Water-Bbl:
PRODUCTION TEST
N/A
Date of Test: Oil-Bbl:
N/A
Sr Res EngSr Pet GeoSr Pet Eng
Oil-Bbl: Water-Bbl:Flow Tubing
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
G
Revision received 1/30/2024
Abandoned
10/31/2023
JSB
RBDMS JSB 010924
DSR-2/12/24
Conventional Core(s): Yes No Sidewall Cores:
30.
MD TVD
N/A N/A
Top of Productive Interval N/A N/A
3645' 3624'
4673' 4455'
5060' 4808'
5326' 5053'
5906' 5584'
6189' 5844'
6220' 5873'
6562' 6186'
6648' 6265'
6811' 6414'
7,084' 6,666'
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:
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
Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345),
and/or Easement (ADL 123456) number.
The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements
given in other spaces on this form and in any attachments.
The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic
diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from
a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071.
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core
analysis, paleontological report, production or well test results, per 20 AAC 25.070.
Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each
segregated pool is a completion.
TPI (Top of Producing Interval).
Authorized Name and
Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
INSTRUCTIONS
Beluga U
Beluga S
Beluga F
Sterling A
Beluga K
Beluga R
Beluga A
Beluga D
Beluga N
Beluga O
Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and
other tests as required including, but not limited to: core analysis, paleontological report, production or well test results.
Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29.
Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool.
If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the
producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,
showing the data pertinent to such interval).
Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit
detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity,
permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology.
Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain).
Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical
laboratory information required by 20 AAC 25.071.
Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion,
suspension, or abandonment; or 90 days after log acquisition, whichever occurs first.
Beluga T
Wellbore Schematic, P&A reports
Authorized Title: Drilling Manager
Formation Name at TD:
No
NoSidewall Cores: Yes No
Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov
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: _0 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): North Cook Inlet Unit
GL:N/A 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- 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 25.050 101 (ft MSL)
22. Logs Obtained:
23.
BOTTOM
30" H-40 381'
20" H-40 1,990'
13-3/8" N-80 2,639'
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.
1,990'
Surface
N/A
SIZE DEPTH SET (MD)If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date perf'd or liner run):
Surface 2,640' (TOW)
Surface
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
1820 sx18-1/2
24"
Driven
Surface 1142 sx
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
Hilcorp Alaska, LLC
WAG
Gas
10/31/2023 222-098 / 323-176 / 322-511
SETTING DEPTH TVD
2585179
TOP HOLE SIZE
N/A
N/A
2,640' MD / 2,639' TVD
N/A
3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503
331994 2586723
50-883-20032-01-00August 22, 2022
N/A
NCIU A-12ASeptember 1, 20221254' FNL, 928' FWL, Sec 6, T11N, R9W, SM, AK
126.6
Tertiary System Gas Pool
ADL 17589
7,352' MD / 6,911' TVD
2,640' MD / 2,639' TVD
N/A
CASING, LINER AND CEMENTING RECORD
Gas-Oil Ratio:
AMOUNT
PULLED
N/A
331029
TOP
SETTING DEPTH MD
suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud
log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing
collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary.
PACKER SET (MD/TVD)
30"
BOTTOMCASINGWT. PER
FT.GRADE CEMENTING RECORD
N/A
2466' FSL, 33' FWL, Sec 6, T11N, R9W, SM, AK
Choke Size:
Surface
Per 20 AAC 25.283 (i)(2) attach electronic information
72# Surface
-
133#
381'
Water-Bbl:
PRODUCTION TEST
N/A
Date of Test: Oil-Bbl:
N/A
Sr Res EngSr Pet GeoSr Pet Eng
Oil-Bbl: Water-Bbl:Flow Tubing
WINJ
SPLUG Other Abandoned Suspended
Stratigraphic Test
No
No
(attached) No
Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment
By Grace Christianson at 8:22 am, Jan 03, 2024
Conventional Core(s): Yes No Sidewall Cores:
30.
MD TVD
N/A N/A
Top of Productive Interval N/A N/A
7,084' 6,666'
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:
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
Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345),
and/or Easement (ADL 123456) number.
The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements
given in other spaces on this form and in any attachments.
The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic
diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from
a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071.
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core
analysis, paleontological report, production or well test results, per 20 AAC 25.070.
Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each
segregated pool is a completion.
TPI (Top of Producing Interval).
Authorized Name and
Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
INSTRUCTIONS
Beluga U
Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and
other tests as required including, but not limited to: core analysis, paleontological report, production or well test results.
Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29.
Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool.
If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the
producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,
showing the data pertinent to such interval).
Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit
detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity,
permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology.
Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain).
Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical
laboratory information required by 20 AAC 25.071.
Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion,
suspension, or abandonment; or 90 days after log acquisition, whichever occurs first.
Wellbore Schematic, P&A reports
Authorized Title: Drilling Manager
Formation Name at TD:
No
NoSidewall Cores: Yes No
Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov
Drilling Manager
01/02/24
Monty M
Myers
Updated By: CJD 01/2/24
P&A SCHEMATIC
Tyonek Platform
Well: NCIUA-12A
PTD: 222-098
API: 50-883-20032-01-00
Item Depth MD Depth
TVD ID Description
1 2,640’ 2,639’-13-3/8”Whipstock
2 2,681’ 2,681’Cement Plug – TOC 2,681’ (Rig Milled to 2681’ on 10/30/23)
3 2,859’ 2,859’HRD E ZXP Liner Top Packer (no liner hanger)
4 ~2,918’2,918’<1.0”Collapsed liner – Tagged 9/8/22 Eline drift
OPEN HOLE / CEMENT DETAIL
4-1/2”
8-1/2" hole: Pumped 159bbls 12.0ppg lead followed by 158bbls of 15.3ppg tail cement. Circ’d trace
spacer/cement back to surface off liner top. No losses during job. Annulus volume from openhole caliper =
275bbls.(~40bbls excess pumped)
4
Casing &Tubing Detail
Size Wt Grade Conn ID Top Btm
30”133 H-40 Welded 28.000 Surf 381’
20”133 H-40 19.730 Surf 1,990’
13-3/8”72 N-80 BTC 12.347 Surf 3,028’
4-1/2”12.6 L-80 DWC/ C 3.958 2,859 7,352’
Activity Date Ops Summary
4/14/2023 Mobe crews on boat to Grayling platform due to weather hold with choppers.,Breakdown rig, load derrick, carrier & beam package on boat with crew.,Send load to
Tyonk platform, orientate crew & PJSM.,unload boat & put beam package together, spot base beams on package to well center. install carrier & install walkways.
4/15/2023 Cont. install landings, "A" leg, & Derrick. rest crew on Tyonek send boat to Grayling for 2nd load, guys prep loads & clean decks, Backload boat w/ rig Eq., send
boat to Steelhead p/u rig jacks send boat to Tyonek. Mobe out remaining crew members from beach and move crew from Grayling to Tyonek.,Orientate crews to
Tyonek, PJSM, unload jacke from boat & r/u same, skid rig to A-12A well center, secure same, continue unload boat spotting eq. R/U circulating lines f/pits to
pump. prep derrick & stand, string up drill line. arrange deck, prep loads for backload, send boat to Grayling t/p/u last load of rig Eq.
4/16/2023 Continue stringing up lines in Derrick, l/d same, R/U companion flanges to wellhead & run circulating lines to take returns to production. Boat loading last of rig eq.
from Grayling.,Circulate hole STS volume till clean (450bbls) to production w/drill water, 3.3BPM 200 psi, cont. prep backload for boat.,S/D & monitor well static,
set BPV, N/D tree, prep wellhead, install blanking sub. N/U BOPE tq flanges, check accumulator bottle pre-charge, R/U test pump,Spot Accumulator, run lines,
set electrical distribution panel, R/U prep, stand & raise derrick, secure same.,Install rig floor, stairs & landings, tarp in cellar, m/u 4 1/2" test joint, function test
BOPE
4/17/2023 Cont. Function test BOPE, replace fitting on accumulator line, re-test good.,Fill surface BOPE with water, attempt shell test w/ 4 1/2" TJ on variable pipe rams
having leak on low test, run high test 2500 psi good, Tropubleshoot low test leak, chase down to rams leaking. Shell test w/ annular 250/2500 good.,Source
replacement rams from beach, pull rams & cont. arranging deck & working on rig-up punch list.,Recieve replacement rams, 4 1/2'solid body, dress rams & install,
re-fill surface eq. w/ test water.,Test BOPE as per Hilcorp & AOGCC expectations. Witness waived by Jim Regg 4-17, test w/4 1/2" TJ, 250/2500 good, test gas
alarms & pvt.,Blow down equipment, pull and lay down test joint, break down test joint, rig up bails and elevators, loosen guy lines and remove turn buckles under
carrier, level rig and center elevators over BOPE, install turn buckles under carrier. Remove flow line valve on circulating head. And install circulating head on top
of annular. Remove off driller side stairs, raise rig floor, center BOPE stack with floor hatch, install,off drillers side stairs, Rig up McCoy tongs, offloading
Halliburton equipment. and spotting on deck rigging up same,Lubricate rig, complete Derrick inspection..,Finish rigging up floor, securing ladders and stairs.,Pull
back pressure valve.,Monitor well (well static),Back out lock down pins, make up landing joint into hanger, pull hanger at 40K to rig floor, break and lay down
hanger.,Pooh with 4-1/2 tbg racking backing in derrick t/ 833'
4/18/2023 Cont. POOH standing back 4 1/2" Kill string.,M/U CMT stinger BHA - 4 1/2" pup joint, XO, 2- joints 2 7/8" IBT tubing, mule shoe.= 70.25',TIH w/ 4 1/2" tubing from
derrick t/2893', up /dn wt 47k, cont in hole tag @ 2921', P/U 3' off tag depth.,R/U Halliburton Cmt eq. & pump lines, PJSM,Fill lines w/5 bbls water, PT cmt lines
760/2748 psi, good,,Mix & pump 24bbls 12PPG cmt@ 4bpm, 115psi, displace same rate 40 bbls drill water. full displacement from job.,R/D circ. line POOH
30'min up t/2545',,Rev circulate 1.5 tubing volume clean, R/U beaver slide.,POOH l/d 4 1/2" tubing.,Lay down cement stinger assemply,Make up hanger to landing
joint land hanger run in lock downs, BPV set, clear rig floor of handling equipment and tools, remove beaver slide, stairs & landings, remove rig floor. prep to
scope derrick down.,Scope down derrick & lay over, secure lines.,Nipple Down BOPE, down stack annular, double gate & mud cross.
4/19/2023 Cont. N/D, pull riser & spacer spool,N/U dry hole tree, test void 5k, test tree 300/5k good, Pull TWC, install tree cap.
4/24/2023 R/U Test CMT plug @ 2918' up ~134' Pressure up t/ 1646psi w/2.9bbls, 15 min 1629psi, 30 min 1622psi, bleed back 2.2bbls, good test,R/U e-line RIH tag TOC
@ 2665' POOH R/D same.
5/19/2023 MIT down 13-3/8" casing against cement plug (no tubing). Inspector Kam St. John witnessed. Pressured up to 1624psi. Lost 5psi followed by 3 psi over 30
minutes. PASS.
n (LAT/LONG):
evation (RKB):
50-883-20032-01-00API #:
Well Name:
Field:
County/State:
NCIU A-12A
North Cook Inlet Unit
Hilcorp Energy Company Composite Report
, Alaska
Contractor
AFE #:
AFE $:
232-00373
$325,000
Job Name:232-00373 TY NCI A-12A Decomplete
Spud Date:
Page 1/1
Well Name: NCIU A-12B
Report Printed: 1/2/2024www.peloton.com
Well Operations Summary
Jobs
Actual Start Date:10/28/2023 End Date:
Report Number
1
Report Start Date
10/27/2023
Report End Date
10/28/2023
Operation
Finish L/D 20 more stands of DP. Skid rig 3’. Prep & Extend cantilever out over well 7’. Had to modify platform handrails a nd stairways. N/D A-12B Dry hole tree. Set
Riser in place. Replace ST-80 Torque cylinder that was leaking.
Lift & Set bops on riser. Start to torque bolts on BOPs and riser. Merica scafold hand install and inspect scafold heat structur after move.
Torque 2 connections on riser. Change out Lower pipe rams to 9 5/8", Install bell nipple and dresser sleave. Install and tighte n down bell inpple to flow box. Assist welder
with return ditch modifications.
Report Number
2
Report Start Date
10/28/2023
Report End Date
10/29/2023
Operation
Work on rig acceptance check list. Clean and organize well bay, Deck and rig floor from N/U. Install elbow 90 to drop returns into shaker ditch. Install flow ditch hole
plates. Inspect top drive saver sub
Install pup jt in rotary and change out saver sub. redress die blocks with new bolts. Trouble shoot and re-time grabber box seq uence.
Report Number
3
Report Start Date
10/29/2023
Report End Date
10/30/2023
Operation
Cont. trouble shooting and going through hydraulic timing sequence on pipe handler.
Rig up to test BOP's. Attemted a shell test finding 2 leaks on riser connection. Bled down pressure and re-torqued.
Test 13 5/8' BOP's as per sundry 250/3000 for 5 min each with 4.5" test jt. Pulled test jt and test blinds. Tested all gas and PVT alarms.
Swap out test jts to 9 5/8" and pressure test LPR 250/3000 for 5 min each.
Backed out L/D screw and pulled hanger to floor with test jt. and L/D same.
Make up jts of 4.5" and latch tool. RIH and latch onto isolation sleave.
Perform Draw down on koomey. Back out LDS and pull isolation sleave lay down same. Install wear ring and run in 4 LDS. POOH and L/D assebly.
Smelled diesel in stack and performed sheen test-failed. Pull bell nipple and replace rubber gasket and fixed leak. R/U on casi ng valve sucking out stack to production
flushing to remove top diesel.
Cont. to flush stack while bringing short pieces of BHA to rig floor. Discussing options with production for fluid disposal.
Hold PJSM, M/U 12 1/4" Bit, bit sub, watermelon mill and crossover. RIH with 3 stds of spiral 6 1/4" spiral drill collars to 28 8'.
Report Number
4
Report Start Date
10/30/2023
Report End Date
10/31/2023
Operation
P/U 21 Joints of 4.5 HWDP to 940'. P/U 10 Stands of 4.5 DP & Stand back 5 stands to make room. P/U another 10 Stands of DP to 2300'. Check torque with rig
tongs.
Rig up circ lines to production black water line from the trip tank. Rig up lines to ISO tanks . PJSM with production.
RIH & Wash down F/ 2609' T/ 2676'. Tag 40 k dn. Pump soap pill and chase with 9.1 PPG KCL mud sending returns to trip tank then to production. Displace until
interface at trip tank ( 340 BBL ). Shut down and pump down Trip tanks to production. Line up to ISO tanks & displace 100 BBL of soap/Mud interface. Shut down.
Pressure wash inside flow box. Sim-ops rig up to test CSG.
Line up and flood choke and kill lines and remove air from system. Pressure test CSG to 2301 PSI- good test. Bled down pressure and R/D testing equipment.
Flood flow ditches observing a leak on new 90 on starboard side and port side hole cover. Fixed 90 and starboard side leak and filled all sand traps at 400 GPM while
fixing port side cover.
Cont. working on leaks in flow ditches. Port side was fixed again but wasn't able to get good flow due to cuttings and old mud in ditch. Drilled 5' of CMT from 2676' T/2681'
400 GPM, 500 PSI, 70 RPM, 1-3K TQ, 2-5K WOB. Pickked up shut down rotary and pumps and set 50K Down.
Circulate 1.5X BU at 400 GPM, 500 PSI, while cleaning the port side ditch. Observed CMT cuttings at surface at BU and circulate d clean. Blow down all surface lines.
POOH F/2678' T/288' racking stds of DP and HWDP in derrick. Sim-ops cont. cleaning port side flow ditch.
Change out elevators, Rack back 3 stds of 6 1/4" spiral collars. Change out bails to short set.
Report Number
5
Report Start Date
10/31/2023
Report End Date
11/1/2023
Operation
Finish chg bails, and rig service
PJSM, P/up Well bore integrity 13-3/8" trackmaster whipstock assy.
RIH slow F/ 180' to 2626'
R/up ak e-eline and run chk shot w/ gryo X2 @ 116.24 AZ pooh. P/up single and oriente rih t/ 2656' and rerun gryo @ gyro TF = 3 37.02 or 164.51 ROHS. Pooh w/ wire
line
P/up stand rih t/ 2682' and set anchor w/good indacation of set @ 25k. and pull up hole to up weight + 5' and sheer bolt w/ 42k w/ top of whipstock @ 2640'
Obtain SPR and establish parameters. Mrill 13 3/8" window F/2640' -T/2645' , GPM- 720, PSI 1445, 70 RPM= 5-8K TQ, WOB= 5-9K. MW 9.1 – Vis 43,, P/U 120K, S/O
120K, ROT 120K.
Cont. Milling 13 3/8" window F/2645' -T/2656' , GPM- 825, PSI 1850, 70 RPM= 3-10K TQ, WOB= 8-10K. MW 9.1+ – Vis 47.
API: 5088320032 Field: North Cook Inlet Unit
Sundry #:
State: Alaska
Rig/Service: Spartan 151Permit to Drill (PTD) #:222098
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#% A #% A
A
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Tuesday, July 25, 2023
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Kam StJohn
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
Hilcorp Alaska, LLC
A-12A
N COOK INLET UNIT A-12A
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 07/25/2023
A-12A
50-883-20032-01-00
222-098-0
N
SPT
2859
2220980 1500
0 1620 1615 1612
0 0 0 0
OTHER P
Kam StJohn
5/19/2023
This well is a gas producer. It has been cemented to TOC 2665' and per sundry 323-176 and program needed a MIT-T to 1500psi. Lots of
communication in the tubing string which is why the Tbg and I/A tracked.
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:N COOK INLET UNIT A-12A
Inspection Date:
Tubing
OA
Packer Depth
23 1624 1619 1616IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitKPS230519175529
BBL Pumped:2 BBL Returned:2
Tuesday, July 25, 2023 Page 1 of 1
9
9
9
9 9
9 9
9 9 9
*DVSURGXFHU
9
9
cemented to TOC 2665' sundry 323-176 Lots of
communication in the tubing string which is why the Tbg and I/A tracked.
James B. Regg Digitally signed by James B. Regg
Date: 2023.07.25 12:20:57 -08'00'
CAUTION: This email originated from outside the State of Alaska mail system.
Do not click links or open attachments unless you recognize the sender and know
the content is safe.
From:McLellan, Bryan J (OGC)
To:Ryan Rupert
Cc:Regg, James B (OGC); Harold Soule - (C); Dan Marlowe; Juanita Lovett
Subject:RE: NCIU A-12A (PTD#222-098)
Date:Tuesday, April 18, 2023 12:25:00 PM
Ryan,
This change in sequence is approved.
Bryan McLellan
Senior Petroleum Engineer
Alaska Oil & Gas Conservation Commission
333 W 7th Ave
Anchorage, AK 99501
Bryan.mclellan@alaska.gov
+1 (907) 250-9193
From: Ryan Rupert <Ryan.Rupert@hilcorp.com>
Sent: Tuesday, April 18, 2023 11:06 AM
To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Harold Soule - (C) <hsoule@hilcorp.com>; Dan
Marlowe <dmarlowe@hilcorp.com>; Juanita Lovett <jlovett@hilcorp.com>; Ryan Rupert
<Ryan.Rupert@hilcorp.com>
Subject: NCIU A-12A (PTD#222-098)
Bryan-
Just wanted to update the agency with a reordering of steps for our in-progress RWO on NCIU A-12A
(Sundry #323-176). If the AOGCC would like to discuss further, please let me know. We will note it
in the change log for this sundry, and still submit for 48hr witness notification before the MIT and
tag. Thanks,
Sundried plan:
1. RU cementers, and lay in 24bbls cement from 2918’ to 2725’
2. POOH and lay down kill string
3. WoC
4. MIT down 13-3/8” casing to 1500psi (charted)
5. RU SL and confirm ToC is at or above 2,759’ MD
6. RD SL
7. ND BOP’s, Install dryhole tree and test
8. RDMO HAK rig 404
Re-ordered plan:
1. RU cementers, and lay in 24bbls cement from 2918’ to 2725’
2. POOH and lay down kill string
3. Install tubing hanger and BPV/TWC
4. ND BOP’s, Install dryhole tree and test
5. RDMO HAK rig 404
6. Pull BPV/TWC
7. WoC
8. MIT down 13-3/8” casing to 1500psi (charted)
9. RU SL and confirm ToC is at or above 2,759’ MD
10. RD SL
Ryan Rupert
CIO Ops Engineer (#13088)
907-301-1736 (Cell)
907-777-8503 (Office)
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, 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 theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate.
CAUTION: This email originated from outside the State of Alaska mail system.
Do not click links or open attachments unless you recognize the sender and know
the content is safe.
From:McLellan, Bryan J (OGC)
To:Ryan Rupert
Cc:Juanita Lovett; Sean McLaughlin; Dan Marlowe
Subject:RE: NCIU A-12A Decomplete RWO (PTD#222-098)
Date:Thursday, March 30, 2023 2:33:00 PM
Ryan,
Hilcorp has approval to make the change to TOC requested in your email below. The proposal
provides more than minimum required 100’ of cement above the liner top.
Bryan McLellan
Senior Petroleum Engineer
Alaska Oil & Gas Conservation Commission
333 W 7th Ave
Anchorage, AK 99501
Bryan.mclellan@alaska.gov
+1 (907) 250-9193
From: Ryan Rupert <Ryan.Rupert@hilcorp.com>
Sent: Thursday, March 30, 2023 1:17 PM
To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Cc: Juanita Lovett <jlovett@hilcorp.com>; Sean McLaughlin <Sean.Mclaughlin@hilcorp.com>; Dan
Marlowe <dmarlowe@hilcorp.com>; Ryan Rupert <Ryan.Rupert@hilcorp.com>
Subject: NCIU A-12A Decomplete RWO (PTD#222-098)
Bryan-
In order to give maximum depth for kickoff, I’d like to amend the ToC down to 2725’ MD for the
NCIU A-12A decomplete RWO (approved sundry #323-176). This would be 134’ of cement above
liner top at 2859’ MD. Let me know if that change is acceptable. Thanks,
Ryan Rupert
CIO Ops Engineer (#13088)
907-301-1736 (Cell)
907-777-8503 (Office)
The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the
JLC 3/28/2023
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Date: 2022.09.06 14:52:45 -08'00'Chelsea Wright Digitally signed by Chelsea Wright
Date: 2022.09.06 15:14:45 -08'00'
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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: 10/14/2022
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
DATA TRANSMITTAL
WELL: NCIA-12A
PTD: 222-098
API: 50-883-20032-01-00
FINAL LWD FORMATION EVALUATION LOGS (08/22/2022 to 09/02/2022)
x EWR-M5, AGR, 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:222-098
T37162
Kayla
Junke
Digitally signed by
Kayla Junke
Date: 2022.10.17
15:57:54 -08'00'
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Date: 2022.09.19
14:48:09 -08'00'
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CAUTION: This email originated from outside the State of Alaska mail
system. Do not click links or open attachments unless you recognize the
sender and know the content is safe.
From:McLellan, Bryan J (OGC)
To:Sean McLaughlin
Cc:Cody Dinger
Subject:Re: NCIU A-12A Temporary Shut Down of Operations ( PTD 222-098)
Date:Thursday, September 8, 2022 7:43:38 PM
Sean,
Hilcorp has approval to proceed with temporary shutdown per your plan below. Follow up
with written sundry application.
Regards
Bryan McLellan
Sent from my iPhone
On Sep 8, 2022, at 5:43 PM, Sean McLaughlin <Sean.Mclaughlin@hilcorp.com>
wrote:
Bryan,
During a casing pressure test on well NCIU A-12A a failure of the liner occurred. After
the PT failure a test packer was run and the 13-3/8” casing was tested to the top of the
liner to 3000 psi. Attempts to gain access through the 4-1/2” liner have failed. A 2-
7/8” drift was run on drill pipe and a series of gauge rings were run on eline. There is
an obstruction near the top of the 4-1/2” liner. Verbal approval for temporary
shutdown of operations is requested. The form will be submitted 9/9/22.
Plan forward:
Run a 4-1/2” kill string
ND BOPE / NU tree
Circulate out the 10.1 ppg mud with inhibited seawater
RDMO
Regards,
sean
Sean McLaughlin
Hilcorp Alaska, LLC
Drilling Engineer
Sean.McLaughlin@hilcorp.com
Cell: 907-223-6784
The information contained in this email message is confidential and may be legally privileged and is intended only forthe 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 suchvirus and other checks as it considers appropriate.
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
BOPE Test Report for:
Reviewed By:
P.I. Suprv
Comm ________N COOK INLET UNIT A-12A
JBR 09/21/2022
MISC. INSPECTIONS:
FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK:
ACCUMULATOR SYSTEM:MUD SYSTEM:
P/F P/F
P/FP/FP/F
Visual Alarm
QuantityQuantity
Time/Pressure
SizeQuantity
Number of Failures:0
4" & 4-1/2" joints.
Test Results
TEST DATA
Rig Rep:Bryan LafleurOperator:Hilcorp Alaska, LLC Operator Rep:Sloan Sunderland
Rig Owner/Rig No.:Enterprise 151 PTD#:2220980 DATE:9/3/2022
Type Operation:DRILL Annular:
250/3000Type Test:BIWKLY
Valves:
250/3000
Rams:
250/3000
Test Pressures:Inspection No:bopSAM220906163025
Inspector Austin McLeod Insp Source
Related Insp No:
INSIDE REEL VALVES:
Quantity P/F
(Valid for Coil Rigs Only)
Remarks:
Test Time 5
MASP:
2837
Sundry No:
Control System Response Time (sec)
Time P/F
Housekeeping:P
PTD On Location P
Standing Order Posted P
Well Sign P
Hazard Sec.P
Test Fluid W
Misc NA
Upper Kelly 1 P
Lower Kelly 1 P
Ball Type 2 P
Inside BOP 1 P
FSV Misc 0 NA
13 PNo. Valves
1 PManual Chokes
2 PHydraulic Chokes
0 NACH Misc
Stripper 0 NA
Annular Preventer 1 13-5/8 P
#1 Rams 1 2-7/8x5 P
#2 Rams 1 Blind P
#3 Rams 1 2-7/8x5 P
#4 Rams 0 NA
#5 Rams 0 NA
#6 Rams 0 NA
Choke Ln. Valves 1 3-1/8 P
HCR Valves 2 3-1/8 P
Kill Line Valves 3 3-1/16&3-1/8 P
Check Valve 0 NA
BOP Misc 0 NA
System Pressure P3150
Pressure After Closure P1750
200 PSI Attained P25
Full Pressure Attained P127
Blind Switch Covers:PAll stations
Bottle precharge P
Nitgn Btls# &psi (avg)P16@2300
ACC Misc NA0
P PTrip Tank
P PPit Level Indicators
P PFlow Indicator
P PMeth Gas Detector
P PH2S Gas Detector
0 NAMS Misc
Inside Reel Valves 0 NA
Annular Preventer P15
#1 Rams P10
#2 Rams P10
#3 Rams P10
#4 Rams NA0
#5 Rams NA0
#6 Rams NA0
HCR Choke P2
HCR Kill P2
9
9
9
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By Samantha Carlisle at 10:57 am, Aug 29, 2022
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CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or
open attachments unless you recognize the sender and know the content is safe.
From:McLellan, Bryan J (OGC)
To:Sean McLaughlin
Cc:Davies, Stephen F (OGC); Roby, David S (OGC)
Subject:RE: NCI A-12A (222-098) Omit 7" drilling liner
Date:Monday, August 29, 2022 9:51:00 AM
Attachments:image001.png
Sean,
Hilcorp is granted approval to proceed with the plan as indicated below. I agree that you will have >25 bbls kick tolerance,
assuming 15.2 ppg EMW LOT, 10.1 ppg mud and 8.5” hole size to TD.
Please follow up with a “Change of Approved permit” Sundry submitted within 3 days.
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
From: Sean McLaughlin <Sean.Mclaughlin@hilcorp.com>
Sent: Monday, August 29, 2022 9:10 AM
To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Subject: NCI A-12A (222-098) Omit 7" drilling liner
Bryan,
Hilcorp requests permission to omit the 7” drilling liner on A-12A. The two criteria for omitting the drilling liner in the PTD
were sufficient FIT and no losses. A 15.2# fit was obtained after milling the window (planned 14.8# with 6.125” hole gave a 25
bbl KTV). Rig 151 has drilled through both loss circulation risk areas without issue.
Sections 14 and 15 of the program will be omitted. Hilcorp will drill the lower Beluga per section 16 and run 4-1/2” liner per
section 17. The Beluga H is prognosed to be at 5400’ – 5800’ MD. In this interval the MW will be increased to 10.1 ppg and
loss circulation status reverified prior to drilling into the Beluga I (top ~5800’ MD).
A change to section 16 will be to continue drilling an 8.5” openhole to TD. The ECD’s will be more favorable, hole cleaning is
better with the 6-3/4” BHA, and KTV will increase. The mechanical setup for the liner will not change. The revised cement
calculations are below.
Verified cement calcs -bjm
Regards,
sean
Sean McLaughlin
Hilcorp Alaska, LLC
Drilling Engineer
Sean.McLaughlin@hilcorp.com
Cell: 907-223-6784
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CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas
Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential
and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you
are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the
mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov.
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STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
*All BOPE reports are due to the agency within 5 days of testing*
SSu bm itt t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov
Rig Owner: Rig No.:151 DATE: 8/20/22
Rig Rep.: Rig Email:
Operator:
Operator Rep.: Op. Rep Email:
Well Name:PTD #2220980 Sundry #
Operation: Drilling: X Workover: Explor.:
Test: Initial: X Weekly: Bi-Weekly: Other:
Rams:250-3000 Annular:250-3000 Valves:250-3000 MASP:2837
MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES:
Test Result/Type Test Result Quantity Test Result
Housekeeping P Well Sign P Upper Kelly 1P
Permit On Location P Hazard Sec.P Lower Kelly 1FP
Standing Order Posted P Misc.NA Ball Type 2P
Test Fluid Water Inside BOP 1P
FSV Misc 0NA
BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm
Stripper 0NATrip Tank PP
Annular Preventer 1 13-5/8" 5K P Pit Level Indicators PP
#1 Rams 1 2-7/8" x 5" 5K P Flow Indicator PP
#2 Rams 1 Blind 5K P Meth Gas Detector PP
#3 Rams 1 2-7/8" x 5" 5K P H2S Gas Detector PP
#4 Rams 0NAMS Misc 0NA
#5 Rams 0NA
#6 Rams 0NAACCUMULATOR SYSTEM:
Choke Ln. Valves 1 3-1/8" 5M P Time/Pressure Test Result
HCR Valves 2 3-1/8" 5M P System Pressure (psi)3150 P
Kill Line Valves 3 1/16"10M & (1)3-1/P Pressure After Closure (psi)1725 P
Check Valve 0NA200 psi Attained (sec)17 P
BOP Misc 0NAFull Pressure Attained (sec)120 P
Blind Switch Covers: All stations Yes
CHOKE MANIFOLD:Bottle Precharge:P
Quantity Test Result Nitgn. Bottles # & psi (Avg.): 16@2500 P
No. Valves 13 P ACC Misc 0NA
Manual Chokes 1P
Hydraulic Chokes 2P Control System Response Time:Time (sec) Test Result
CH Misc 0NA Annular Preventer 22 P
#1 Rams 11 P
Coiled Tubing Only:#2 Rams 11 P
Inside Reel valves 0NA #3 Rams 11 P
#4 Rams 0 NA
Test Results #5 Rams 0 NA
#6 Rams 0 NA
Number of Failures:1 Test Time:10.0 HCR Choke 2 P
Repair or replacement of equipment will be made within days. HCR Kill 2 P
Remarks:
AOGCC Inspection
24 hr Notice Yes Date/Time 8-16-2022/04:42
Waived By
Test Start Date/Time:8/19/2022 17:30
(date) (time)Witness
Test Finish Date/Time:8/20/2022 3:30
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Jim Regg
Enterprise
All tests performed with 4" & 4.5" test joint against the test plug. Test #2 F/P Fuctioned lower IBOP and re-tested good. Tested all
gas alarms good
Bruce Hebert
Hilcorp
Shane Hauck / S. Dambacher
NCIU A-12A
Test Pressure (psi):
ig151oim@enterpriseoffshore.com
shauck@hilcorp.com
Form 10-424 (Revised 08/2022) 2022-0820_BOP_Enterprise151_NICU_A-12A
9 9
9
9
999 9
9
9
9
MEU
-5HJJ
FP
Test #2 F/P Fuctioned lower IBOP and re-tested good.
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:Sean McLaughlin
To:McLellan, Bryan J (OGC)
Subject:NCIU A-12A (222-098) permit questions
Date:Tuesday, August 9, 2022 2:18:26 PM
Bryan,
The A-12A CoA’s stipulate a 3500 psi BOP test. The A-12 wellhead is rated to 3000 psi. The MASP is
2837 psi. A 3000 psi BOPE test was requested. Is a 3000 psi BOPE test approved?
Regards,
sean
Sean McLaughlin
Hilcorp Alaska, LLC
Drilling Engineer
Sean.McLaughlin@hilcorp.com
Cell: 907-223-6784
The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the
individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby
notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please
immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete
this message.
While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the
onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate.
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
Monty M. Myers
Drilling Manager
Hilcorp Alaska, LLC
3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Re: North Cook Inlet Field, Tertiary System Gas Pool, NCIU A-12A
Hilcorp Alaska, LLC
Permit to Drill Number: 222-098
Surface Location: 1254' FNL, 928' FWL, Sec 6, T11N, R9W, SM, AK
Bottomhole Location: 2536' FSL, 51' FWL, Sec 6, T11N, R9W, SM, AK
Dear Mr. Myers:
Enclosed is the approved application for the permit to drill the above referenced well.
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well
logs run must be submitted to the AOGCC within 90 days after completion, suspension, or
abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first.
This permit to drill does not exempt you from obtaining additional permits or an approval required
by law from other governmental agencies and does not authorize conducting drilling operations
until all other required permits and approvals have been issued. In addition, the AOGCC reserves
the right to withdraw the permit in the event it was erroneously issued.
Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska
Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply
with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code,
or an AOGCC order, or the terms and conditions of this permit may result in the revocation or
suspension of the permit.
Sincerely,
Jessie L. Chmielowski
Commissioner
DATED this ___ day of August, 2022. 4
Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski
Date: 2022.08.04 16:47:55 -08'00'
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6750True Vertical Depth (500 usft/in)-500 -250 0 250 500 750 1000 1250 1500 1750 2000 2250 2500 2750 3000 3250
Vertical Section at 211.87° (500 usft/in)
NCIU A-12A tgt1
3000
3500
4000
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6000
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A-12
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NCI A-12A wp02
KOP : Start Dir 8.73º/100' : 3010' MD, 3009.85'TVD : 17.68° LT TF
End Dir : 3034' MD, 3033.84' TVD
Start Dir 4.5º/100' : 3054' MD, 3053.82'TVD
End Dir : 3852.05' MD, 3790.68' TVD
Start Dir 4º/100' : 4369.7' MD, 4197.89'TVD
End Dir : 4747.94' MD, 4522.63' TVD
Total Depth : 7173' MD, 6754.91' TVD
Top Beluga B
Hilcorp Alaska, LLC
Calculation Method:Minimum Curvature
Error System:ISCWSA
Scan Method: Closest Approach 3D
Error Surface: Ellipsoid Separation
Warning Method: Error Ratio
WELL DETAILS: Plan: NCIU A-12
Water Depth: 101.00
+N/-S +E/-W
Northing Easting Latitude Longitude
0.00 0.00 2586723.59 331994.15 61° 4' 36.315 N 150° 56' 55.638 W
SURVEY PROGRAM
Date: 2022-07-18T00:00:00 Validated: Yes Version:
Depth From Depth To Survey/Plan Tool
410.63 3010.00 N COOK INLET UNIT A-12 Sperry (NCI A-12) 3_CB-Film-GMS
3010.00 3410.00 NCI A-12A wp02 (Plan: NCI A-12A) 3_MWD_Interp Azi+Sag
3410.00 7173.00 NCI A-12A wp02 (Plan: NCI A-12A) 3_MWD+AX+Sag
FORMATION TOP DETAILS
TVDPath TVDssPath MDPath Formation
4522.63 4396.00 4747.94 Top Beluga B
REFERENCE INFORMATION
Co-ordinate (N/E) Reference:Well Plan: NCIU A-12, True North
Vertical (TVD) Reference:NCIU A-12A planned RKB @ 126.63usft
Measured Depth Reference:NCIU A-12A planned RKB @ 126.63usft
Calculation Method:Minimum Curvature
Project:North Cook Inlet
Site:North Cook Inlet Unit
Well:Plan: NCIU A-12
Wellbore:Plan: NCI A-12A
Design:NCI A-12A wp02
CASING DETAILS
TVD TVDSS MD Size Name
3009.85 2883.22 3010.00 13-3/8 13 3/8" TOW
6754.91 6628.28 7173.00 4-1/2 4 1/2" x 6 1/8"
SECTION DETAILS
Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation
1 3010.00 0.33 205.25 3009.85 -19.33 -7.15 0.00 0.00 20.19 KOP : Start Dir 8.73º/100' : 3010' MD, 3009.85'TVD : 17.68° LT TF
2 3034.00 2.41 189.94 3033.84 -19.89 -7.27 8.73 -17.68 20.73 End Dir : 3034' MD, 3033.84' TVD
3 3054.00 2.41 189.94 3053.82 -20.72 -7.41 0.00 0.00 21.51 Start Dir 4.5º/100' : 3054' MD, 3053.82'TVD
4 3852.05 38.13 212.64 3790.68 -252.33 -147.82 4.50 23.97 292.33 End Dir : 3852.05' MD, 3790.68' TVD
5 4369.70 38.13 212.64 4197.89 -521.44 -320.20 0.00 0.00 611.90 Start Dir 4º/100' : 4369.7' MD, 4197.89'TVD
6 4747.94 23.00 211.97 4522.63 -683.39 -422.90 4.00 -178.99 803.65 NCIU A-12A tgt1 End Dir : 4747.94' MD, 4522.63' TVD
7 7173.00 23.00 211.97 6754.91 -1487.22 -924.60 0.00 0.00 1751.20 Total Depth : 7173' MD, 6754.91' TVD
-1800
-1700
-1600
-1500
-1400
-1300
-1200
-1100
-1000
-900
-800
-700
-600
-500
-400
-300
-200
-100
0
100
South(-)/North(+) (200 usft/in)-1300 -1200 -1100 -1000 -900 -800 -700 -600 -500 -400 -300 -200 -100 0 100
West(-)/East(+) (200 usft/in)
NCIU A-12A tgt1
3
5
0
07
250750077508000A-12
13 3/8" TOW
4 1/2" x 6 1/8"
3500
3750
4000
4250
4500
4750
5000
5250
5500
5750
6000
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6500
6755N
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A wp02
KOP : Start Dir 8.73º/100' : 3010' MD, 3009.85'TVD : 17.68° LT TF
End Dir : 3034' MD, 3033.84' TVD
Start Dir 4.5º/100' : 3054' MD, 3053.82'TVD
End Dir : 3852.05' MD, 3790.68' TVD
Start Dir 4º/100' : 4369.7' MD, 4197.89'TVD
End Dir : 4747.94' MD, 4522.63' TVD
Total Depth : 7173' MD, 6754.91' TVD
CASING DETAILS
TVD TVDSS MD Size Name
3009.85 2883.22 3010.00 13-3/8 13 3/8" TOW
6754.91 6628.28 7173.00 4-1/2 4 1/2" x 6 1/8"
Project: North Cook Inlet
Site: North Cook Inlet Unit
Well: Plan: NCIU A-12
Wellbore: Plan: NCI A-12A
Plan: NCI A-12A wp02
WELL DETAILS: Plan: NCIU A-12
Water Depth: 101.00
+N/-S +E/-W Northing Easting Latitude Longitude
0.00 0.00 2586723.59 331994.15 61° 4' 36.315 N 150° 56' 55.638 W
REFERENCE INFORMATION
Co-ordinate (N/E) Reference:Well Plan: NCIU A-12, True North
Vertical (TVD) Reference:NCIU A-12A planned RKB @ 126.63usft
Measured Depth Reference:NCIU A-12A planned RKB @ 126.63usft
Calculation Method:Minimum Curvature
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0.001.002.003.004.00Separation Factor3150 3375 3600 3825 4050 4275 4500 4725 4950 5175 5400 5625 5850 6075 6300 6525 6750 6975 7200Measured Depth (450 usft/in)A-12NCIU B-05 wp01No-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.WELL DETAILS:Plan: NCIU A-12 NAD 1927 (NADCON CONUS)Alaska Zone 04Water Depth: 101.00+N/-S +E/-W Northing EastingLatitudeLongitude0.000.002586723.59331994.1561° 4' 36.315 N150° 56' 55.638 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: NCIU A-12, True NorthVertical (TVD) Reference: NCIU A-12A planned RKB @ 126.63usftMeasured Depth Reference:NCIU A-12A planned RKB @ 126.63usftCalculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2022-07-18T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool410.63 3010.00 N COOK INLET UNIT A-12 Sperry (NCI A-12) 3_CB-Film-GMS3010.00 3410.00 NCI A-12A wp02 (Plan: NCI A-12A) 3_MWD_Interp Azi+Sag3410.00 7173.00 NCI A-12A wp02 (Plan: NCI A-12A) 3_MWD+AX+Sag0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)3150 3375 3600 3825 4050 4275 4500 4725 4950 5175 5400 5625 5850 6075 6300 6525 6750 6975 7200Measured Depth (450 usft/in)GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference3010.00 To 7173.00Project: North Cook InletSite: North Cook Inlet UnitWell: Plan: NCIU A-12Wellbore: Plan: NCI A-12APlan: NCI A-12A wp02CASING DETAILSTVD TVDSS MD Size Name3009.85 2883.22 3010.00 13-3/8 13 3/8" TOW6754.91 6628.28 7173.00 4-1/2 4 1/2" x 6 1/8"
Updated By: CJD 08/2/22
Proposed Schematic (B)
North Cook Inlet Unit
Tyonek Platform
Well: NCI A-12A
PTD: TBD
API: TBD
Completed: Future
Jewelry Detail
Item Depth
MD ID OD Description
1 ±2,800’ 4-1/2” Baker LTP
2 ±2,800’ 4-1/2” Tieback Seal Assy
Casing &Tubing Detail
Size Wt Grade Conn ID Top Btm
30” 133 H-40 Welded 28.000 Surf 381’
20” 133 H-40 19.730 Surf 1,990’
13-3/8” 72 N-80 BTC 12.347 Surf ±3,010’
4-1/2” 12.6 L-80 DWC/ C 3.958 ±2,800 7,173’
4-1/2” 12.6 L-80 DWC/ C 3.958 Surface 5,640’
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:Sean McLaughlin
To:McLellan, Bryan J (OGC)
Subject:RE: [EXTERNAL] NCIU A-12A PTD questions
Date:Tuesday, August 2, 2022 9:27:46 AM
Attachments:image001.png
image002.png
NCI A-12A Proposed (B) Schematic 8-2-22.doc
Bryan,
I’ve attached the KT calcs for the single string case. Please note that I’m using the maximum expected reservoir pressure in the calculation not the most
likely pressure that BP has used in the past. As such, the intensity kick is already accounted for. Adding a half pound EMW to the max anticipated
pressure would unfairly burden the KTV. Alternatively, I could use the most likely case of 9.4 ppg reservoir pressure for the calculation. Let me know how
you wish to proceed.
The program is written for the expected case. The last 6 drilled wells have had FITs over 14.7 ppg. Lost circulation with the higher MW/ECD’s is the larger
concern. You may or may not recall there was serious LC issues in 2 of the 3 drilled wells last year with elevated ECDs. I’ve attached a diagram for the
single string case.
Regards,
sean
From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Sent: Monday, August 1, 2022 5:22 PM
To: Sean McLaughlin <Sean.Mclaughlin@hilcorp.com>
Subject: [EXTERNAL] NCIU A-12A PTD questions
Sean,
A few questions about the PTD application:
1. Could you send your kick tolerance calcs for the long 6.125” hole section (where you don’t run 7” liner)? I can get 25 bbls for this hole section if I
assume a 6.75 hole, but not for a 6.125” hole. If you drill 6.75” hole, you will have more buffer in case you don’t achieve a 14.8 ppg leakoff. Even
more if you drill 8.5” hole.
2. The well program is written as though the contingency for not getting enough kick tolerance (running a 7” drilling liner) is actually the base plan.
I’m pretty sure the base plan is to omit the 7” liner. If both possibilities are to be permitted, then you’ll need to include proposed diagrams and
cement calcs for both options. Also need to state the minimum criteria for proceeding with plan A or plan B, which is a minimum of 15 bbls kick
tolerance assuming a pore pressure of 0.5 ppg over prognosed.
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
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return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message.
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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.
From:Sean McLaughlin
To:Davies, Stephen F (OGC)
Cc:McLellan, Bryan J (OGC);Boyer, David L (OGC)
Subject:RE: [EXTERNAL] NCIU A-12A (PTD 222-098)
Date:Tuesday, August 2, 2022 4:05:10 PM
Attachments:image001.png
Steve,
I believe you are inquiring about both kick prevention and kick detection. The best kick prevention we have
is to stop drilling in the Beluga H. The geologist monitoring the well is able to pick tops from the LWD (triple
combo) logs while drilling through the section. This has been working great on this Tyonek campaign. We
have stopped drilling in the Beluga H on the last 6 wells and will use that same method to stop drilling in the
Beluga H on A-12A. Furthermore, A-12A is located in the center of the field and the geology in the area has
been very predictable and there is good offset data.
In the event out kick prevention fails all the normal kick detection elements are in place. There is a gas
monitoring system, connection gas is tracked, flow checks are preformed prior to tripping, there is a PVT
system, flow alarms, and pit watchers. Elements of the kick detection system are regularly checked by the
AOGCC inspectors.
Regards,
sean
From: Davies, Stephen F (OGC) <steve.davies@alaska.gov>
Sent: Tuesday, August 2, 2022 3:12 PM
To: Sean McLaughlin <Sean.Mclaughlin@hilcorp.com>
Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Boyer, David L (OGC)
<david.boyer2@alaska.gov>
Subject: RE: [EXTERNAL] NCIU A-12A (PTD 222-098)
Sean,
The more markers and pressures listed in the table, the better for me: That way I don’t have to spend so
much time correlating well logs since we two geologists here are responsible for permitting throughout the
state. I’m not quite as confident that Hilcorp will not encounter over-pressured strata near the base of the
8-1/2” hole section. Stranger things have happened. How will Hilcorp monitor progress while drilling the
lower portion of the 8-1/2” hole to ensure that the abnormally pressured strata are not penetrated prior to
running casing? Realtime LWD monitoring? Mud system monitoring? Pit watchers?
Thanks and stay safe,
Steve Davies
Alaska Oil and Gas Conservation Commission (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: Sean McLaughlin <Sean.Mclaughlin@hilcorp.com>
Sent: Tuesday, August 2, 2022 1:39 PM
To: Davies, Stephen F (OGC) <steve.davies@alaska.gov>
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.
Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Boyer, David L (OGC)
<david.boyer2@alaska.gov>
Subject: RE: [EXTERNAL] RE: NCIU A-12A (PTD 222-098)
Hi Steve,
The G&G team I work with doesn’t fill out the sheet below and I don’t use any of the information on that
form in well planning. I don’t believe it is done on the north slope wells either. I will continue to make the
pressure table as informational as possible to help with the AOGCC review.
Regards,
sean
From: Davies, Stephen F (OGC) <steve.davies@alaska.gov>
Sent: Tuesday, August 2, 2022 12:17 PM
To: Sean McLaughlin <Sean.Mclaughlin@hilcorp.com>
Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Boyer, David L (OGC)
<david.boyer2@alaska.gov>
Subject: [EXTERNAL] RE: NCIU A-12A (PTD 222-098)
Sean,
In follow-up to the questions in my email, below, could Hilcorp also please provide a geologic prognosis for
this well in the same format as used for other Hilcorp wells as shown below? The additional information
contained in the prognosis is a real help to speed AOGCC’s review process.
Thanks and stay safe,
Steve Davies
Alaska Oil and Gas Conservation Commission (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: Sean McLaughlin <Sean.Mclaughlin@hilcorp.com>
Sent: Tuesday, August 2, 2022 1:22 PM
To: Davies, Stephen F (OGC) <steve.davies@alaska.gov>
Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Boyer, David L (OGC)
<david.boyer2@alaska.gov>
Subject: RE: [EXTERNAL] NCIU A-12A (PTD 222-098)
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.
Hi Steve,
On page 35, I’ve attempted to show that the 0.52 psi/ft gradient extends to the base of the Beluga U. Also
that planned TD is significantly above the base of the U. So it was intentional to provide a pressure deeper
than what we plan to drill.
Out of an abundance of caution (and ease) we are assuming the pressure transition starts in the Beluga I.
As shown on page 35 we are assuming the Beluga I-U is at a 0.52 psi/ft gradient (maximum anticipated
pressure). This is conservative as A-14, A-15, and A-16 offset wells weighted up slowly through the lower
Beluga to TD in the U with 9.9 ppg, 10.1, ppg, and 9.4 ppg mud weights respectively. The plan is to drill into
the Beluga H with a 9.0 ppg mud like we have on the last 6 wells. We will weight up to a 9.8 ppg minimum
mud weight, and verify if there is lost circulation prior to drilling into the Beluga I. The casing point of the 8-
1/2” hole section is the same TD horizon of the last 6 wells. I am confident we will not encounter over-
pressured strata at the base of the 8-1/2” hole.
Regards,
sean
From: Davies, Stephen F (OGC) <steve.davies@alaska.gov>
Sent: Tuesday, August 2, 2022 9:52 AM
To: Sean McLaughlin <Sean.Mclaughlin@hilcorp.com>
Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Boyer, David L (OGC)
<david.boyer2@alaska.gov>
Subject: [EXTERNAL] NCIU A-12A (PTD 222-098)
Hi Sean,
I’m reviewing Hilcorp’s Permit to Drill application for NCIU A-12A, and Bryan and I need some additional
information.
On page 35, in the MASP section for the 6-1/8” hole section, the TD and TVD given for the “Beluga I-
U” is listed as 8254’ MD and 6867’ TVD, but these depths exceed the planned TD for this well. Please
provide clarification.
Bryan also has noted a question on this page: “Where is the transition from 8.3 to 10.0 ppg res
pressure?” I presume that this pressure change occurs near Hilcorp’s planned casing point at 5839’
MD / 5527’ TVD, but additional detail is needed. Please provide depths for the top and base of this
pressure-transition zone (MDs and TVDs) and provide information as to how Hilcorp will avoid
encountering over-pressured strata while drilling to casing point in the 8-1/2” hole section.
Thanks and stay safe,
Steve Davies
Alaska Oil and Gas Conservation Commission (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 any attachments will not adversely affect its systems or data. No responsibility is accepted by
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