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Jake Flora
ASRC Consulting & Environmental Services, LLC
Petroleum Engineer
(720) 988-5375 jflora@asrcenergy.com
1
April 30, 2025
Alaska Oil and Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave, Suite 100
Anchorage, Alaska 99501
RE: DATA TRANSMITTAL 002 WELL: CINGSA CLU S-6
PTD: 224-112
API: 50-133-20728-00-00
Name Type
x >h^ͲϲWƌŽĚƵĐƚŝŽŶ>ŝŶĞƌĞŵĞŶƚŽŶĚ>ŽŐ W&͕d/&&͕>^͕/>^
x >h^Ͳϲ'Zͬ>Žŝů&ůĂŐ;ƐͿ W&͕d/&&͕>^
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x >h^ͲϲWWZK&͕/WZK& W&͕>^
Data Transfer Folder: CINGSA Well Logs Subfolders: 224-112 CLU Storage 6
Please acknowledge receipt by signing and returning one copy of this transmittal.
Received By: Date:
224-112
T40349
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2025.04.30 08:26:26 -08'00'
TRUE Oil SPLUG Other Abandoned Suspended
1b. Well Class:
20AAC 25.105 20AAC 25.110 Development Exploratory
GSTOR 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):
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- 04
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 NA (ft MSL)
22. Logs Obtained:
23.
BOTTOM
20"158'
13-3/8" J-55 2383'
9-5/8" L-80 4939'
7" L-80 5126'
24. Open to production or injection? Yes No 25.
26.
Was hydraulic fracturing used during completion? Yes No
DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED
27.
Date First Production: Method of Operation (Flowing, gas lift, etc.):
Hours Tested: Production for Gas-MCF:
Test Period
Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr):
Press. 24-Hour Rate
Sr Res EngSr Pet GeoSr Pet Eng
97/64th (in)
184' (not installed)
N/A
Oil-Bbl: Water-Bbl:
0
Water-Bbl:
PRODUCTION TEST
NA
Date of Test: Oil-Bbl:
000
3/20/2025
surface
3hrs
Flow Tubing
TUBING RECORD
SIZE
0
0
N/A0
flow well
0
Gas-Oil Ratio:Choke Size:
Per 20 AAC 25.283 (i)(2) attach electronic information
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
DEPTH SET (MD)
7934' / 4904'
PACKER SET (MD/TVD)If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date perf'd or liner run):
384 bbls lead, 51 bbls tail
68#
158'
92 bbls 14# Flexstone8-3/4"
12-1/4"40#
10400'
surface
4904'
surface 8130'
CASING WT. PER
FT.GRADE
December 15, 2024
CEMENTING RECORD
2392786.17
NA
SETTING DEPTH TVD
2391047.43
TOP HOLE SIZE AMOUNT
PULLED
276213.53
274923.83
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.
NA
BOTTOM
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,
Triple Combo (GR, Resistivity, Caliper, Density, Neutron, PE); Mud Log; 9-5/8" CBL(12-18-2024), 4-1/2" CBL (2-8-2025); Directional Surveys; EOW
Report, Perforating GR/CCL Logs, PPROF/IPROF Logs
50-133-20728-00-00
CLU Storage 6
ADL 391627
717' FNL, 1660' FEL, Sec 9, T5N, R11W, SM, AK
2332' FNL, 1901' FWL, Sec 8, T5N, R11W, SM, AK
NA
11/20/2024
10402' / 5126'
10313' / 5119'
PO Box 190989 Anchorage, AK 99519
281995.47 2392833.30
869' FNL, 2118' FEL, Sec 8, T5N, R11W, SM, AK Cannery Loop / Sterling C Gas Storage GL: 33' KB: 54.4'
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
Cook Inlet Natural Gas Storage Alaska, LLC
WAG
Gas
3/7/2025 224-112 / 324-715
26# 7934'
7947'7"
Conductor NA
16"
Driven
surface 333 bbls lead, 78 bbls tail surface
2466'
5370'
2866'surface
surface
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 9:54 am, Apr 29, 2025
Complete
3/7/2025
JSB
RBDMS JSB 050525
2632 JSB
GDSR-6/3/25
/ 324-633
BJM 11/11/25
Conventional Core(s): Yes No Sidewall Cores:
30.
MD TVD
Permafrost - Top N/A N/A If
Permafrost - Base N/A N/A
Top of Productive Interval 8210' 4954'
Sterling A 5877' 3196'
Sterling B 6552' 4360'
Sterling C1 8136' 4941'
Sterling C2 9598' 5072'
Formation Name at TD:
Sterling C2 10402' 5126'
31. List of Attachments:
32. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Contact Name: Jake Flora
Digital Signature with Date:Contact Email:jflora@asrcenergy.com
Contact Phone:720-988-5375
CINGSA Director
General:
Item 1a:
Item 1b:
Item 4b:
Item 9:
Item 15:
Item 19:
Item 20:
Item 22:
Item 23:
Item 24:
Item 27:
Item 28:
Item 30:
Item 31:
INSTRUCTIONS
Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if
needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired.
Yes No
Well tested? Yes No
28. CORE DATA
NAME
29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS
Authorized Title:
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.
Authorized Name and
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.
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.
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).
No
NoSidewall Cores: Yes No
Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov
Matthew
Federle
Digitally signed by
Matthew Federle
Date: 2025.04.29
09:28:28 -08'00'
Casing Detail
Size Type Wt Grade ID Top Btm MD / TVD
20"20" Conductor 106.5# J-55 19.000" 0' 158' / 158'
13-3/8" Surface 68# J-55 12.415" 0' 2866' / 2383'
9-5/8" Intermediate 40# L-80 8.998" 0' 8130' / 4939'
7" Tubing 26# L-80 6.276" 0' 7947' / 4905'
7" Liner 26# L-80 6.276" 7934' 10400' / 5126'
Cement Detail
13-3/8"
9-5/8"
7"
Annular Fluid Detail
7" x 9-5/8" inner annulus 240' diesel freeze protect + corrosion inhibited brine
9-5/8" x 13-3/8" outer annulus 31' diesel freeze protect, drilling mud
13-3/8"
Jewelry Detail
Item ID Depth
A5.963"184'
B Protection Sleeve 4.750" 184'
C Bullet Tieback Seal Assembly, 9.58' 6.180" 7947'
D 7" x 9-5/8" Baker HRD-E ZXP Flex Lock LTP, 11' PBR 6.190" 7934'
E 7" x 9-5/8" Baker HRD-E ZXP Hanger 6.180" 7957'
F RN Nipple, No Go, 13cr 5.838" 7971'
G Baker Landing Collar NA 10313'
Top CINGSA:8138' MD, 4942' TVD (Base of B5 Coal)
9-5/8"
Perforation Detail
Sand Top (MD)Btm (MD)Top (TVD)Btm (TVD)FT Date
C1a Sterling C1a 8210 8410 4954 4974 200 3/6/25 - 3/7/25
Sterling C1b 8600 8700 4990 4998 100 3/5/2025
Sterling C1b 8740 8920 5001 5016 180 3/3/25 - 3/4/25
Sterling C2a 9600 9770 5071 5085 170 2/25/25 - 2/27/25
Sterling C2a 9812 9882 5089 5094 70 2/24/25 - 2/25/25
Sterling C2a 9900 9970 5095 5101 70 2/23/25 - 2/24/25
Sterling C2a 10020 10090 5103 5107 70 2/11/25 - 2/23/25
C1b Sterling C2b 10180 10270 5112 5116 90 2/11/25 - 2/21/25
Sterling C2b 10289 10309 5117 5118 20 2/10/2025
C2a Inclination: Sail Angle 57 deg (2500 - 6500'), Top Perf 80 deg, TD 85 deg
7"
C2b
Last Rev: 4/10/2025
By: Jake Flora
PBTD = 10313' MD / 5118' TVD
TD = 10402' MD / 5126' TVD
Description
333 bbls 12.0# Class G lead, 78 bbls 15.8# tail, cement to surface
CINGSA
CLU Storage 06
Current Schematic
Hydraulic Landing Nipple, Halliburton RRQ
384 bbls 12.0# Class G lead, 51 bbls 14# Flexstone tail, TOC 2760' (12-18-24 CBL)
Displacement pack off occurred 10 bbls from plug bump
92 bbls 14.0 ppg Class G Flexstone, plug bumped, TOC 8000' (2-8-2025 CBL)
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ƌĞůĞĂƐĞǁŝƌĞůŝŶĞ͘
ϭϭͬϮϮͬϮϰ ƌŝůůϭϲ͟ƐƵƌĨĂĐĞŚŽůĞƚŽϮϯϴϬ͛͘
ϭϭͬϮϯͬϮϰ ƌŝůůϭϲ͟ƐƵƌĨĂĐĞŚŽůĞƚŽϮϴϳϵ͛͘ĂĐŬƌĞĂŵƚŽĚƌŝůůĐŽůůĂƌƐĂƚϭϬϵ͛͘Z/,ƚŽd͕ĐŝƌĐƵůĂƚĞŚŽůĞĐůĞĂŶ͘
ϭϭͬϮϰͬϮϰ h͕dKK,͘ZhƚŽƌƵŶϭϯͲϯͬϴ͟ĐĂƐŝŶŐ͘ZƵŶϭϯͲϯͬϴ͟ϲϴηƐƵƌĨĂĐĞĐĂƐŝŶŐƚŽϮϯϴϵ͛͘
ϭϭͬϮϱͬϮϰ ŽŶƟŶƵĞƌƵŶŶŝŶŐϭϯͲϯͬϴ͟ĐĂƐŝŶŐƚŽϮϴϲϲ͛͘Z/,ǁŝƚŚŝŶŶĞƌƐƚƌŝŶŐ͕h͕ĐĞŵĞŶƚϭϯͲϯͬϴ͟ĐĂƐŝŶŐ
ǁŝƚŚϯϯϯďďůƐϭϮ͘ϬƉƉŐĐůĂƐƐ'ůĞĂĚĐĞŵĞŶƚ͕ϳϴďďůƐϭϱ͘ϴƉƉŐĐůĂƐƐ'ƚĂŝůĐĞŵĞŶƚ͘ĞŵĞŶƚĞƌƐ
ƉƵŵƉĞĚϯϴďďůƐǁĂƚĞƌƚŽĚŝƐƉůĂĐĞ͕ƉůƵŐďƵŵƉĞĚ͘ϭϬϬйƌĞƚƵƌŶƐĚƵƌŝŶŐĐĞŵĞŶƚũŽď͕ϭϮϰďďůƐ
ϭϮ͘ϬƉƉŐůĞĂĚĐĞŵĞŶƚƚŽƐƵƌĨĂĐĞ͘ĞŵĞŶƚŝŶƉůĂĐĞĂƚϭϴ͗ϱϳŚƌƐ͘
ϭϭͬϮϲͬϮϰ WKK,ǁŝƚŚŝŶŶĞƌƐƚƌŝŶŐ͘EƌŝƐĞƌ͕&DŵĂĚĞƌŽƵŐŚĐƵƚŽŶϭϯͲϯͬϴ͟ĐĂƐŝŶŐ͕EƐƉůŝƚƌŝƐĞƌ͘DĂŬĞ
ĮŶĂůĐĂƐŝŶŐĐƵƚϭϴ͟'>͘/ŶƐƚĂůů&DϭϯͲϱͬϴƐůŝƉůŽĐŬdžϭϯͲϱͬϴϯŬŇĂŶŐĞ͕ƚĞƐƚƚŽϭϱϬϬƉƐŝ͘DhϭϯͲ
ϱͬϴϯŬdžϭϯͲϱͬϴϱŬhŶŝŚĞĂĚĂƐƐĞŵďůLJ͘ĞŐŝŶEhKW ͘
ϭϭͬϮϳͬϮϰ &ŝŶŝƐŚEhKW ͕ŝŶƐƚĂůůŇŽǁďŽdž͕EhƌŝƐĞƌ͕ƚĞƐƚKWƚŽϮϱϬƉƐŝůŽǁ͕ϯϬϬϬƉƐŝŚŝŐŚ͕ƚĞƐƚŐĂƐĂůĂƌŵƐ͕
ƉĞƌĨŽƌŵĂĐĐƵŵƵůĂƚŽƌĚƌĂǁĚŽǁŶƚĞƐƚ͘K':ŽƐŚ,ƵŶƚŽŶůŽĐĂƟŽŶƚŽǁŝƚŶĞƐƐKWƚĞƐƚ͘
ϭϭͬϮϴͬϮϰ ŽŶƟŶƵĞƚĞƐƟŶŐKW ͘dĞƐƚůŽǁĞƌƌĂŵƐǁŝƚŚϵͲϱͬϴ͟ƚĞƐƚũŽŝŶƚ͘ZƚĞƐƚĞƋƵŝƉŵĞŶƚ͘^ŝŶŐůĞŝŶW
ƌĂĐŬŝŶŐďĂĐŬŝŶĚĞƌƌŝĐŬ͘Dh,͘
ϭϭͬϮϵͬϮϰ DhϭϮͲϭͬϰ͟,͕ƐŝŶŐůĞŝŶŚŽůĞ͕ǁĂƐŚĚŽǁŶƚŽƐƟŶŐŝŶƚŽŇŽĂƚĐŽůůĂƌ͕Zh^>ĐĞŵĞŶƚĞƌƐƚŽD/d
ĐĂƐŝŶŐ͘WƌĞƐƐƵƌĞƚĞƐƚϭϯͲϯͬϴ͟ϲϴηĐĂƐŝŶŐƚŽϮϱϬƉƐŝůŽǁ͕ϮϮϬϬƉƐŝŚŝŐŚ͘'ŽŽĚƚĞƐƚ͘ƌŝůůƐŚŽĞ
ƚƌĂĐŬ͕ĐůĞĂŶŽƵƚƌĂƚĞŚŽůĞƚŽϮϴϳϵ͛͘^ǁĂƉŵƵĚƚŽϵ͘ϬƉƉŐŬůĂͲƐŚŝĞůĚ͕ĚŝƐƉůĂĐĞǁĞůůďŽƌĞ͘
ϭϭͬϯϬͬϮϰ ŽŶƟŶƵĞĚŝƐƉůĂĐŝŶŐǁĞůůďŽƌĞ͘ƌŝůůϮϬ͛ŽĨŶĞǁŚŽůĞĨƌŽŵϮϴϴϵͲϮϴϵϵ͕͛ĐŝƌĐƵůĂƚĞŚŽůĞĐůĞĂŶ͘Zh
ĐĞŵĞŶƚƉƵŵƉ͕ƉĞƌĨŽƌŵ>KdǁŝƚŚϵ͘ϬƉƉŐŵƵĚƚŽϰϯϬƉƐŝ͕ϭϮ͘ϱƉƉŐ DtƌĞĂĐŚĞĚ͘ƌŝůůϭϮͲϭͬϰ͟
ŚŽůĞϮϴϵϵ͛ƚŽϯϰϬϯ͛͘
ϭϮͬϬϭͬϮϰ ƌŝůůϭϮͲϭͬϰ͟ŚŽůĞϯϰϬϯ͛ƚŽϰϵϴϵ͛͘^ŚŽƌƚƚƌŝƉƚŽƐƵƌĨĂĐĞĐĂƐŝŶŐƐŚŽĞ͕ŶŽƟŐŚƚƐƉŽƚƐ͘Dtϵ͘ϯƉƉŐ͘
ϭϮͬϬϮͬϮϰ ŽŶƟŶƵĞƐŚŽƌƚƚƌŝƉƚŽƐŚŽĞ͘ƌŝůůϭϮͲϭͬϰ͟ŚŽůĞϰϵϴϵ͛ƚŽϲϰϬϬ͛͘Dtϵ͘ϯƉƉŐ͘
ϭϮͬϬϯͬϮϰ ƌŝůůϭϮͲϭͬϰ͟ŚŽůĞϲϰϬϬ͛ƚŽϳϬϭϱ͛͘WĞƌĨŽƌŵǁŝƉĞƌƚƌŝƉƚŽϱϬϬϬ͛͘Dtϵ͘ϯƉƉŐ͘
ϭϮͬϬϰͬϮϰ ƌŝůůϭϮͲϭͬϰ͟ŚŽůĞϳϬϭϱ͛ƚŽϳϵϮϳ͛͘Dtϵ͘ϮƉƉŐ͘
ϭϮͬϬϱͬϮϰ ƌŝůůϭϮͲϭͬϰ͟ŚŽůĞϳϵϮϳ͛ƚŽϴϬϵϮ͛͘Dtϵ͘ϮƉƉŐ͘
ϭϮͬϬϲͬϮϰ ƌŝůůϭϮͲϭͬϰ͟ŚŽůĞϴϬϵϮ͛ƚŽϴϭϲϮ͛͘Dtϵ͘ϯƉƉŐ͘WĞƌĨŽƌŵǁŝƉĞƌƚƌŝƉƚŽƐŚŽĞĂƚϮϴϲϲ͛͘
ϭϮͬϬϳͬϮϰ Z/,ƚŽϴϭϲϮ͕͛h͕ďĂĐŬƌĞĂŵƚŽϯϭϰϵ͛͘
ϭϮͬϬϴͬϮϰ ŽŶƟŶƵĞďĂĐŬƌĞĂŵŝŶŐKK,͘dŽƐƵƌĨĂĐĞĐĂƐŝŶŐƐŚŽĞ͘>,͘ZhƚŽƌƵŶĐĂƐŝŶŐ͕ƌƵŶϵͲϱͬϴ͟ϰϬη>Ͳ
ϴϬĐĂƐŝŶŐƚŽϮϴϲϬ͛͘
ϭϮͬϬϵͬϮϰ ZƵŶϵͲϱͬϴ͟ŝŶƚĞƌŵĞĚŝĂƚĞĐĂƐŝŶŐƚŽϴϭϱϬ͕͛ůĂŶĚ͕h͕ŚĂǀĞŝƐƐƵĞƐǁŝƚŚ^>ĐĞŵĞŶƚƚƌƵĐŬ͘
ϭϮͬϭϬͬϮϰ tĂŝƚŽŶĐĞŵĞŶƚƚƌƵĐŬ͘ƌĞĂŬĐŝƌĐƵůĂƟŽŶĞǀĞƌLJϮŚƌƐ͘Zh,ĂůůŝďƵƌƚŽŶƉƵŵƉƚƌƵĐŬ͕ĐŽŶƟŶƵĞΘ
ŵƵĚ͘
ϭϮͬϭϭͬϮϰ WdĐĞŵĞŶƚůŝŶĞƐ͘^ƚĂƌƚĐĞŵĞŶƚũŽď͗ƉƵŵƉϯϴϰďďůƐϭϮ͘ϬƉƉŐůĂƐƐ'>ĞĂĚĐĞŵĞŶƚ͕ĚƌŽƉƌƵƉƚƵƌĞ
ƉůƵŐ͕ƉƵŵƉϱϭďďůƐϭϰ͘ϬƉƉŐdĂŝůůĂƐƐ'&ůĞdžƐƚŽŶĞĐĞŵĞŶƚ͕ĚƌŽƉƉůƵŐ͕ĚŝƐƉůĂĐĞǁŝƚŚϱϵϮďďůƐ͕
ƐĞĞƉĂĐŬŝŶŐŽī͕ƐƚŽƉĚŝƐƉůĂĐŝŶŐ;ϭϬďďůƐĨƌŽŵƉůƵŐďƵŵƉͿ͘&ƌĞĞnjĞƉƌŽƚĞĐƚϵͲϱͬϴ͟džϭϯͲϯͬϴ͟
ĂŶŶƵůƵƐƚŽϯϭ͛ǁŝƚŚĚŝĞƐĞů͘Z/>^͘
ϭϮͬϭϮͬϮϰ dĞƐƚKW͕ǁŝƚŶĞƐƐĞĚďLJK'<Ăŵ^ƚ:ŽŚŶ͘DhϴͲϯͬϰ͟ďŝƚ͕ƉƌŽĚƵĐƟŽŶ,͘Z/,ƚŽϳϲϳϵ͕͛
ƉĞƌĨŽƌŵĐĂƐŝŶŐƚĞƐƚƚŽϮϱϬƉƐŝůŽǁ͕ϯϬϬϬƉƐŝŚŝŐŚĨŽƌϯϬŵŝŶƵƚĞƐ͕W^^͘
ϭϮͬϭϯͬϮϰ ƌŝůůĐĞŵĞŶƚƚŽϳϵϳϱ͛͘WĞƌĨŽƌŵĐĂƐŝŶŐƚĞƐƚƚŽϯϭϲϮƉƐŝĨŽƌϯϬŵŝŶƵƚĞƐ͕W^^͘ƌŝůůƐŚŽĞƚƌĂĐŬƚŽ
ϴϭϯϬ͕͛h͕ĚƌŝůůŶĞǁĨŽƌŵĂƟŽŶƚŽϴϭϴϮ͛͘WĞƌĨŽƌŵ&/dƚŽϭϭ͘ϲ DtĂƚϴϭϯϭ͛D͕ϰϵϰϬ͛ds͘ƌŝůů
ĂŚĞĂĚƚŽϴϰϴϱ͛͘Dtϵ͘ϮƉƉŐ͘
ϭϮͬϭϰͬϮϰ ƌŝůůϴͲϯͬϰ͟ŚŽůĞƚŽϵϯϮϴ͕͛ǁŝƉĞƌƚƌŝƉƚŽƐŚŽĞ͘Dtϵ͘ϰƉƉŐ͘
ϭϮͬϭϱͬϮϰ ƌŝůůϴͲϯͬϰ͟ŚŽůĞƚŽdĂƚϭϬϰϬϮ͛͘Dtϵ͘ϰƉƉŐ͘h͕ďĂĐŬƌĞĂŵKK,ƚŽϵϱϭϯ͛͘
ϭϮͬϭϲͬϮϰ ĂĐŬƌĞĂŵKK,ƚŽϵϮϲϰ͕͛Z/,ƚŽϭϬϯϵϵ͕͛ďĂĐŬƌĞĂŵKK,ƚŽϴϱϬϮ͛͘
ϭϮͬϭϳͬϮϰ ĂĐŬƌĞĂŵKK,ƚŽϴϭϮϮ͛͘h͘dKK,͘Dh,ĂůůŝďƵƌƚŽŶ^dΘ>ƚŽŽů͕Z/,ƚŽϳϱϬϬ͛͘
ϭϮͬϭϴͬϮϰ ŽŶƟŶƵĞůŽŐŐŝŶŐƌƵŶ͗Z/,ƚŽϳϳϬϬ͕͛ĞŶŐĂŐĞƚƌĂĐƚŽƌ͕ƚƌĂĐƚŽƌƚŽϴϭϭϬ͛͘>ŽŐKK,ĂƚϭϰĨƉŵƚŽ
ƐƵƌĨĂĐĞ͕Z,ĂůůŝďƵƌƚŽŶ͘ZhƚŽƌƵŶůŝŶĞƌϳ͟ϮϲηůŝŶĞƌ͘DhƐŚŽĞƚƌĂĐŬ͕ƌƵŶϳ͟ůŝŶĞƌƚŽϮϰϮϲ͕͛ďƌĞĂŬ
ĐŝƌĐƵůĂƟŽŶ͘ŽŶƟŶƵĞd/,ŽŶĚƌŝůůƉŝƉĞƚŽϯϰϲϳ͛
ϭϮͬϭϵͬϮϰ d/,ǁŝƚŚůŝŶĞƌŽŶĚƌŝůůƉŝƉĞƚŽϴϭϭϴ͕͛ǁĂƐŚĂŶĚƌĞĂŵůŝŶĞƌƚŽϭϬϰϬϮ͛͘WůĂĐĞďŽƩŽŵŽĨƐŚŽĞĂƚ
ϭϬϰϬϭ͛͘WƵŵƉϵϮďďůƐϭϰη&ůĞdžƐƚŽŶĞůĂƐƐ'ĞŵĞŶƚǁŝƚŚϭ͘ϯϬϲLJŝĞůĚ͘ƌŽƉǁŝƉĞƌ͕ĚŝƐƉůĂĐĞǁŝƚŚ
ϭϬϬďďůƐƉĞƌĨƉŝůů͘
ϭϮͬϮϬͬϮϰ ^ǁĂƉƚŽϵ͘ϯƉƉŐŵƵĚ͕ƐĞĞǁŝƉĞƌĚĂƌƚůĂŶĚĂƚϭϵϲďďůƐƚŽƚĂůĚŝƐƉůĂĐĞŵĞŶƚ͘WƌĞƐƐƵƌĞƚŽϭϲϬϬƉƐŝ͕
ŇŽĂƚƐŚŽůĚŝŶŐ͘WƌĞƐƐƵƌĞƚŽϮϰϬϬƉƐŝ͕ƐĞƚŚĂŶŐĞƌ͕ƉƌĞƐƐƵƌĞƚŽϯϴϬϬƉƐŝ͕ƌĞůĞĂƐĞŚĂŶŐĞƌƌƵŶŶŝŶŐ
ƚŽŽů͕ƐĞƚǁƚĚŽǁŶƚŽƐĞƚ>dW͘dKK,ǁŝƚŚƌƵŶŶŝŶŐƚŽŽů͘DhƉŽůŝƐŚŵŝůů͕d/,ƚŽϳϵϬϲ͕͛ǁĂƐŚĚŽǁŶ
ƚŽ>dW͕ĐůĞĂŶĚŽǁŶƚŽ>dWϰƟŵĞƐƐĞƫŶŐǁĞŝŐŚƚ͕h͘
ϭϮͬϮϭͬϮϰ tŝƚŚ^>ĐĞŵĞŶƚƉƵŵƉƉĞƌĨŽƌŵĐĂƐŝŶŐƚĞƐƚƚŽϮϱϬƉƐŝůŽǁ͕ϯϬϬϬƉƐŝŚŝŐŚ͕ŐŽŽĚƚĞƐƚ͘ŝƐƉůĂĐĞ
ǁĞůůďŽƌĞƚŽϴ͘ϳƉƉŐďƌŝŶĞ͘WKK,͕>WĨƌŽŵϳϵϰϬ͛͘ZhƚŽƌƵŶϳ͟ϮϲηƚƵďŝŶŐ͘DhƟĞďĂĐŬ
ĂƐƐĞŵďůLJ͕ƌƵŶƚƵďŝŶŐƚŽϮϰϱϴ͛
ϭϮͬϮϮͬϮϰ ZƵŶƚƵďŝŶŐƚŽϳϵϯϳ͕͛ĞŶŐĂŐĞƐĞĂůƐ͕ƉƵůůϰũƚƐ͕Dh^s>EǁŝƚŚƉƌŽƚĞĐƟŽŶƐůĞĞǀĞ͕DhĐŽŶƚƌŽůůŝŶĞ͕
ƚĞƐƚƚŽϱϬϬϬƉƐŝ͕ƐƉĂĐĞŽƵƚ͕ƚĞƌŵŝŶĂƚĞ>ƚŚƌŽƵŐŚƚƵďŝŶŐŚĂŶŐĞƌ͕ƚĞƐƚƚŽϱϬϬϬƉƐŝ͕ƉůĂĐĞĞŶĚŽĨƟĞ
ďĂĐŬƐĞĂůƐĂƚϳϵϰϳ͛;ϴ͘Ϯϲ͛ŽĨƐǁĂůůŽǁŝŶƚŽ^ZͿ͘WŝĐŬŽƵƚŽĨ^Z͕ƌĞǀĞƌƐĞĐŝƌĐƵůĂƚĞϮϲϬďďůƐϴ͘ϳ
ƉƉŐŝŶŚŝďŝƚĞĚďƌŝŶĞĚŽǁŶ/͕ĨŽůůŽǁĞĚďLJϭϳďďůƐĚŝĞƐĞůĨƌĞĞnjĞƉƌŽƚĞĐƚ͕ƵͲƚƵďĞŝŶƚŽƚƵďŝŶŐ͘^ůĂĐŬ
Žī͕ĞŶƚĞƌƐĞĂůďŽƌĞƌĞĐĞƉƚĂĐůĞ͕Z/>^͕D/dƚƵďŝŶŐƚŽϮϱϬƉƐŝůŽǁ͕ϯϭϱϬƉƐŝŚŝŐŚĨŽƌϯϬŵŝŶ͕ŐŽŽĚ
ƚĞƐƚ͘D/dͲ/ĂƚϮϱϬƉƐŝůŽǁ͕ϭϲϱϬƉƐŝŚŝŐŚĨŽƌϯϬŵŝŶƵƚĞƐ͕ŐŽŽĚƚĞƐƚ͘
ϭϮͬϮϯͬϮϰ EKW͕/ŶƐƚĂůůd,͕ŵĂƐƚĞƌǀĂůǀĞ͕ƚĞƐƚŚĂŶŐĞƌŶĞĐŬƐĞĂůƐƚŽϱϬϬϬƉƐŝĨŽƌϭϬŵŝŶ͕ĐůĞĂŶƉŝƚƐďĞŐŝŶ
ƌŝŐŐŝŶŐĚŽǁŶ͘
ϭϮͬϮϰͬϮϰ ůĞĂŶŵƵĚƚĂŶŬƐ͕ƉƌĞƉĂƌĞĨŽƌƌŝŐŵŽǀĞ͕ƌĞůĞĂƐĞƌŝŐĂƚϭϮϬϬŚƌƐ͘
ϭϮͬϮϱͬϮϱ ZŝŐĚŽǁŶ͕ƉƌĞƉĂƌĞƚŽŵŽǀĞ͘
ϭϮͬϮϲͬϮϰ ZŝŐĚŽǁŶ͘
ϭϮͬϮϳͬϮϰ ZŝŐĚŽǁŶ͘DŽǀĞƌŝŐƚŽƌƵnjLJĂƌĚ͘
ϭϮͬϮϴͬϮϰ ZŝŐĚŽǁŶ͘DŽǀĞƌŝŐƚŽƌƵnjLJĂƌĚ͘
ϭϮͬϮϵͬϮϰ ZŝŐĚŽǁŶ͘DŽǀĞƌŝŐƚŽƌƵnjLJĂƌĚ͘
ϭϮͬϯϬͬϮϰ EhƚƌĞĞƐŽŶ>h^Ͳϲ͕>h^Ͳϳ͕ƚĞƐƚƚŽϱϬϬϬƉƐŝĞĂĐŚ͘
ϭϮͬϯϭͬϮϰ WĞƌĨŽƌŵĐĞŵĞŶƚƚŽƉũŽďŽŶϮϬ͟ĐŽŶĚƵĐƚŽƌdžϭϯͲϯͬϴ͟ƐƵƌĨĂĐĞĐĂƐŝŶŐĂŶŶƵůƵƐ͘WƵŵƉϭĐƵďŝĐĨŽŽƚ
ŽĨϭϲ͘ϬWW'ĐĞŵĞŶƚƚŽƚŽƉŽīĂŶŶƵůƵƐ͘
ϭͬϬϭͬϮϰ ,ĂŶĚǁĞůůƚŽ/E'^KƉĞƌĂƚŽƌ͘
tĂŝƚĨŽƌ&ŽdžĐŽŝůĞĚƚƵďŝŶŐƵŶŝƚ͘
ĂŝůLJŽŵƉůĞƟŽŶ^ƵŵŵĂƌLJ
ϮͬϰͬϮϱ ZŝŐƵƉ&ŽdžŽŝůhŶŝƚηϭϬ͘
ϮͬϱͬϮϱ ZĞƐƵŵĞD/Zh͕WĞƌĨŽƌŵK'ǁŝƚŶĞƐƐĞĚKWƚĞƐƚ͘
ϮͬϲͬϮϱ DhĐůĞĂŶŽƵƚ,͘WƵůůƚĞƐƚdƚŽϯϱŬ͕Wd,ƚŽϰϬϬϬƉƐŝ͕ƵŶĂďůĞƚŽŽƉĞŶŵĂƐƚĞƌǀĂůǀĞ͘>ĞĂǀĞ
ŚĞĂƚŽŶƚƌĞĞŽǀĞƌŶŝŐŚƚ͘
ϮͬϳͬϮϱ Z/,ǁŝƚŚĐůĞĂŶŽƵƚ,͗ϮͲϳͬϴ͟d͕Ws͕ďĂůůĚƌŽƉĚŝƐĐŽ͕ƐƟŶŐĞƌ͕ϯ͘ϵϬ͟:^E͘WƵŵƉŚŽƚĨƌĞƐŚ
ǁĂƚĞƌĂƚϳϳϬϬ͕͛ĐůĞĂŶŽƵƚƚŽWdĂƚϭϬϯϰϱ͛ĞůĞĐƚƌŽŶŝĐ;ϭϬϯϴϭ͛ŵĞĐŚĂŶŝĐĂůͿĐŽŝůŵĞĂƐƵƌĞ͘WĂŝŶƚŇĂŐ
ϱϬ͛Žīďƚŵ͕WKK,ƚŽϭϱϮ͕͛ďůŽǁĚƌLJĨƌŽŵϭϱϮ͛ǁŝƚŚEϮƚŽ&WĐŽŝůΘǁĞůů͘
ϮͬϴͬϮϱ Z/,ǁͬ>ͬ'Zͬ>ůŽŐŐŝŶŐƐƚƌŝŶŐ͕,ϮΗĞdžƚĞƌŶĂůĐŽŝůĐŽŶŶĞĐƚŽƌϮͲϯͬϴWƉŝŶ͕ĚƵĂůďĂĐŬ
ƉƌĞƐƐǀĂůǀĞ͕ďĂůůĚƌŽƉĚŝƐĐŽϯͬϰΗďĂůůƉŽƌƚĞĚĚƌĂŝŶƐƵďͬyK͕ϭ͘ϱΗDdƉŝŶ;ĂůůϮ͘ϴϳϱΗKͿ͕yKƚŽϯͬϰΗ
ƐƵĐŬĞƌƌŽĚďŽdž͕DĞŵŽƌLJ>͕ϯͬϰΗƐƵĐŬĞƌƌŽĚƉŝŶůŽŽŬŝŶŐƵƉϮ͘ϭϯΗKͲϮϵ͘ϰϴΖŽǀĞƌĂůůůĞŶŐƚŚ͖Ăƚ
ŇĂŐĚĞƉƚŚĂƚϭϬ͗ϯϭŚƌƐ͕ŵĞĐŚϭϬϯϯϬΖ͕ĞůĞĐϭϬϯϮϰΖǁĂŝƚϮŵŝŶΘůŽŐŽƵƚŽĨŚŽůĞĂƚϯϬĨƉŵƚŽϳϳϬϬΖ͕
WKK,͘
ϮͬϵͬϮϱ Dh'Zͬ>ůŽŐŐŝŶŐƚŽŽůƐ͕Z/,͕ƐƚĂƌƚƉƵŵƉŝŶŐEϮŽŶďĂĐŬƐŝĚĞŽĨĐŽŝůĂƚϮϬϬϬΖ͖ƐƚĂƌƚŐĞƫŶŐƌĞƚƵƌŶƐ
ƚŽďůĞĞĚƚĂŶŬǁͬĐŽŝůĂƚϯϯϯϬΖ͕ϭϰϬϬƉƐŝŐEϮƉƌĞƐƐƵƌĞ͕ĐŽŶƟŶƵĞZ/,͘ƚWdŽĨϭϬϯϴϭŵĞĐŚ͕
ϭϬϯϴϭĞůĞĐ͖WhϭϬΖĂŶĚĐŽŶƟŶƵĞƉƵŵƉŝŶŐEϮƚŽƌĞǀĞƌƐĞĐŝƌĐƵůĂƚĞĂůůůŝƋƵŝĚŽƵƚŽĨǁĞůůďŽƌĞ͖EϮ
ƉƵŵƉƉƌĞƐƐƵƌĞŽĨϮϯϬϬƉƐŝŐ͖WKK,ĂƚϲϬĨƉŵůŽŐŐŝŶŐ'Zͬ>ƟĞͲŝŶůŽŐ͕ƐƚŽƉĂƚϵϴϱϬΖƚŽƉĂŝŶƚ
ǁŚŝƚĞŇĂŐ͖ůŽŐϴϯϬϬΖƚŽϴϬϬϬΖĂƚϯϬĨƉŵĨŽƌďĞƩĞƌ'ZƌĞƐŽůƵƟŽŶĂĐƌŽƐƐƟĞͲŝŶĚĞƉƚŚ͖ĐŽŶƟŶƵĞ
ůŽŐŐŝŶŐƚŽϳϳϬϬΖ;ĂďŽǀĞůŝŶĞƌƚŽƉƉĂĐŬĞƌͿ͖WKK,͕ĐůŽƐĞŵĂƐƚĞƌĂŶĚƐǁĂďǀĂůǀĞƐ͕ďůĞĞĚEϮŽīĐŽŝů
ĂŶĚůƵďƌŝĐĂƚŽƌ͖^/t,WсϭϲϯϬƉƐŝŐ͖ďƌĞĂŬͲŽīƚŽŽůƐ͕ƐƚĂďďĂĐŬŽŶǁĞůů͘WƵŵƉĨŽĂŵƉŝŐƚŚƌŽƵŐŚĐŽŝů
ĚŝƐƉůĂĐĞĚǁŝƚŚŵĞƚŚĂŶŽůƚŽůŝƋƵŝĚƉĂĐŬĐŽŝůĂŚĞĂĚŽĨƉĞƌĨŽƌĂƟŶŐƌƵŶƚŽŵŽƌƌŽǁ͖ϰϳďďůƐŵĞƚŚ
ƉƵŵƉĞĚ͕ĐŽŝůĂŶĚƐƵƌĨůŝŶĞƐƐǁĂƉƉĞĚŽǀĞƌƚŽŵĞƚŚĂŶŽů͖^ĨŽƌŶŝŐŚƚ
ϮͬϭϬͬϮϱ DhWĞƌĨŽƌĂƟŶŐ,ͲĞdžƚĞƌŶĂůĐŽŝůĐŽŶŶĞĐƚŽƌ͕ŚLJĚƌĂƵůŝĐĚŝƐĐŽŶŶĞĐƚϯͬϰďĂůůƚŽƌĞůĞĂƐĞ͕ĚƵĂůĂĐƟŶŐ
ĐŝƌĐƐƵď͕ϱͬϴΗďĂůů͕ϱŬďƵƌƐƚĚŝƐĐ;ĂůůϮ͘ϴϴϬKͿ͕džͬŽϮͲϯͬϴWdžϮͲϯͬϴΗZ 'ϯ͘ϭϯΗK͕džͬŽϮͲϯͬϴW
džϮͲϯͬϴ h ϯ͘ϭϱΗK͕ĮƌŝŶŐŚĞĂĚĂŶĚϮϬΖƉĞƌĨŐƵŶ͘Z/,ƚŽŇĂŐ͕ĐŽƌƌĞĐƚƚŽůŽŐĚĞƉƚŚ͕ƉĞƌĨŽƌĂƚĞŐƵŶ
ηϭϭϬϮϴϵͲϭϬϯϬϵ͛͘WKK,͕ƌĞƉůĂĐĞďƵƌƐƚĚŝƐŬ͕^&E͘
ϮͬϭϭͬϮϱ DhƉĞƌĨŽƌĂƟŶŐ,͕Z/,ƚŽŇĂŐ͕ĐŽƌƌĞĐƚƚŽůŽŐĚĞƉƚŚ͘WĞƌĨŽƌĂƚĞŐƵŶηϮϭϬϮϯϬͲϭϬϮϳϬ͛͘WKK,͘Z/,
ǁŝƚŚŐƵŶηϰ͕ƉĞƌĨŽƌĂƚĞϭϬϬϲϬͲϭϬϬϵϬ͕͛WKK,͘
ϮͬϭϮͬϮϱ &ŽdžĐŽŝůZDKƚŽŐŽƚŽ,ŝůĐŽƌƉ<ĂůŽƚƐĂηϭϬ͕'E/ǁĞůů͘
ϮͬϭϵͬϮϱ D/Zh&ŽdžĐŽŝůĞĚƚƵďŝŶŐƵŶŝƚ͘ĞŐŝŶKWƚĞƐƚ͘
ϮͬϮϬͬϮϱ ŽŵƉůĞƚĞKWƚĞƐƚ͘Z/,ǁŝƚŚZ ůŽŐŐŝŶŐƚŽŽůƐ͗'Zͬ>ƟĞͲŝŶůŽŐ͕ƚĂŐWd͕WKK,͘Dh
ƉĞƌĨŽƌĂƟŶŐ,͕ƐĞĐƵƌĞǁĞůůĨŽƌŶŝŐŚƚ͘
ϮͬϮϭͬϮϱ Z/,ǁŝƚŚŐƵŶηϯ͕ĐŽƌƌĞĐƚĂƚŇĂŐƚŽůŽŐĚĞƉƚŚ͕ƉĞƌĨŽƌĂƚĞϭϬϭϴϬͲϭϬϮϯϬ͕͛KK,͕ĂůůƐŚŽƚƐĮƌĞĚ͘
dƌŽƵďůĞƐŚŽŽƟŶŐƐƚƌŝƉƉĞƌ͘&t,WϭϰϭϬƉƐŝ͘
ϮͬϮϮͬϮϱ Z/,ǁŝƚŚŐƵŶηϱ͕ƚŽŇĂŐ͕ĐŽƌƌĞĐƚƚŽůŽŐĚĞƉƚŚ͘WZ ^^hZ dKϭϮϵϮƉƐŝ͕ďƵƌƐƚĚŝƐŬĨĂŝůĞĚ
ƉƌĞŵĂƚƵƌĞůLJ͘WKK,͕ĚĞĐŝƐŝŽŶŵĂĚĞƚŽƌĞŵŽǀĞďƵƌƐƚĚŝƐŬĨƌŽŵ,͘
ϮͬϮϯͬϮϱ WĞƌĨŽƌĂƚĞŐƵŶηϱϭϬϬϮϬͲϭϬϬϲϬ͕͛ĮƌĞĚĂƚϮϯϱϰƉƐŝ͘
WĞƌĨŽƌĂƚĞŐƵŶηϲϵϵϰϬͲϵϵϳϬ͕͛ĮƌĞĚĂƚϮϲϬϮƉƐŝ͘
&t,WϭϭϲϳƉƐŝ͘
ϮͬϮϰͬϮϱ WĞƌĨŽƌĂƚĞŐƵŶηϳϵϵϬϬͲϵϵϰϬ͕͛ĮƌĞĚĂƚϮϰϬϬƉƐŝ͘
WĞƌĨŽƌĂƚĞŐƵŶηϴϵϴϰϮͲϵϴϴϮ͕͛ĮƌĞĚĂƚϮϮϵϬƉƐŝ͘
&t,WϭϬϲϵƉƐŝ͘
ϮͬϮϱͬϮϱ WĞƌĨŽƌĂƚĞŐƵŶηϵϵϴϭϮͲϵϴϰϮ͕͛ĮƌĞĚĂƚϮϯϯϬƉƐŝ͘
WĞƌĨŽƌĂƚĞŐƵŶηϭϬϵϳϯϬͲϵϳϳϬ͕͛ĮƌĞĚĂƚϮϰϵϬƉƐŝ͘
&t,WϭϭϰϵƉƐŝ͘
ϮͬϮϲͬϮϱ WĞƌĨŽƌĂƚĞŐƵŶηϭϭϵϲϵϬͲϵϳϯϬ͕͛ĮƌĞĚĂƚϮϯϲϬƉƐŝ͘
WĞƌĨŽƌĂƚĞŐƵŶηϭϮϵϲϱϬͲϵϲϵϬ͕͛ĮƌĞĚĂƚϮϰϵϬƉƐŝ͘
&t,WϭϯϴϱƉƐŝ͘
ϮͬϮϳͬϮϱ WĞƌĨŽƌĂƚĞŐƵŶηϭϯϵϲϬϬͲϵϲϱϬ͕͛ĮƌĞĚĂƚϮϯϭϰƉƐŝ͘
DhůŽŐŐŝŶŐƚŽŽůƐ͕Z/,ǁZ 'Zͬ>ůŽŐŐŝŶŐĐĂƌƌŝĞƌ͕ƚĂŐWd͕ůŽŐƵƉ͕ƉĂŝŶƚŇĂŐĂƚϴϳϬϬ͛dD͕
WKK,͘ZĞƉůĂĐĞƐƚƌŝƉƉĞƌĞůĞŵĞŶƚ͘
&t,WϭϰϬϮƉƐŝ͘
ϮͬϮϴͬϮϱ ZĞƉĂŝƌddƌĂĐƚŽƌ͘WĞƌĨŽƌŵƉĂƌƟĂůKWƚĞƐƚ͘ŽŶƟŶƵĞƚŽƌĞƉĂŝƌƐƚƌŝƉƉĞƌ͘
ϯͬϬϭͬϮϱ EŽŽƉĞƌĂƟŽŶƐ͘^ĞŶĚƐƚƌŝƉƉĞƌďƌĂƐƐƚŽŵĂĐŚŝŶĞƐŚŽƉŝŶŶĐŚŽƌĂŐĞ͕ǁĂŝƚŽŶƌĞƉĂŝƌƐ͘
ϯͬϬϮͬϮϱ EŽŽƉĞƌĂƟŽŶƐ͕ǁĂŝƚŽŶƐƚƌŝƉƉĞƌƌĞƉĂŝƌƐ͘
ϯͬϬϯͬϮϱ WĞƌĨŽƌŵK'tŝƚŶĞƐƐĞĚKWƚĞƐƚ͘ZĞƉĂŝƌƐƚƌŝƉƉĞƌďƌĂƐƐĂƚŵĂĐŚŝŶĞƐŚŽƉ͘DhƉĞƌĨŽƌĂƟŶŐ,͕
Wd͘DhdƌŝƉŽŝŶƚdWŐƵŶƐ͘
WĞƌĨŽƌĂƚĞŐƵŶηϭϰϴϴϴϬʹϴϵϮϬ͕͛͛ĮƌĞĚĂƚϮϱϭϭƉƐŝ͘
&t,WϭϮϱϭƉƐŝ͘
ϯͬϬϰͬϮϱ WĞƌĨŽƌĂƚĞŐƵŶηϭϱϴϴϰϬʹϴϴϴϬ͕͛ĮƌĞĚĂƚϮϰϳϯƉƐŝ͘
WĞƌĨŽƌĂƚĞŐƵŶηϭϲϴϳϵϬͲϴϴϰϬ͕͛ĮƌĞĚĂƚϮϰϭϬƉƐŝ͘
WĞƌĨŽƌĂƚĞŐƵŶηϭϳϴϳϰϬͲϴϳϵϬ͕͛ĮƌĞĚĂƚϮϲϬϬƉƐŝ͘
&t,WϭϰϴϳƉƐŝ͘
ϯͬϬϱͬϮϱ WĞƌĨŽƌĂƚĞŐƵŶηϭϴϴϲϱϬͲϴϳϬϬ͕͛ĮƌĞĚĂƚϮϰϰϴƉƐŝ͘
WĞƌĨŽƌĂƚĞŐƵŶηϭϵϴϲϬϬͲϴϲϱϬ͕͛ĮƌĞĚĂƚϮϰϲϭƉƐŝ͘
&t,WϭϮϵϵƉƐŝ͘
ϯͬϬϲͬϮϱ DhůŽŐŐŝŶŐƚŽŽůƐ͕Z/,ǁZ 'Zͬ>ůŽŐŐŝŶŐĐĂƌƌŝĞƌ͕ƐƚŽƉĂƚϴϱϬϬ͛Đƚŵ͕ůŽŐƵƉƚŽϴϮϬϬ͛Đƚŵ͕
ƉĂŝŶƚŇĂŐ͕WKK,͘
WĞƌĨŽƌĂƚĞŐƵŶηϮϬϴϯϲϬͲϴϰϭϬ͕͛ĮƌĞĚĂƚϮϰϱϰƉƐŝ͘
&t,WϭϮϳϴƉƐŝ͘
ϯͬϬϳͬϮϱ WĞƌĨŽƌĂƚĞŐƵŶηϮϭϴϯϭϬʹϴϯϲϬ͕͛ĮƌĞĚĂƚϮϱϱϵƉƐŝ͘
WĞƌĨŽƌĂƚĞŐƵŶηϮϮϴϮϲϬʹϴϯϭϬ͕͛ĮƌĞĚĂƚϮϰϮϯƉƐŝ͘
WĞƌĨŽƌĂƚĞŐƵŶηϮϯϴϮϭϬʹϴϮϲϬ͕͛ĮƌĞĚĂƚϮϲϴϵƉƐŝ͘
&t,WϭϰϮϵƉƐŝ͘
ϯͬϬϴͬϮϱ ZŝŐĚŽǁŶ&ŽdžĐŽŝůĞĚƚƵďŝŶŐƵŶŝƚ͘
,ĂŶĚǁĞůůŽǀĞƌƚŽŽƉĞƌĂƚŽƌ͕ǁĂŝƟŶŐĨŽƌǁŝƚŚĚƌĂǁĂůƉĞƌŝŽĚƚŽŇŽǁƚĞƐƚǁĞůů͘
ϯͬϭϱͬϮϱ >ŽŐW,D^ĂƐŝŶŐ ǀĂůƵĂƟŽŶ>ŽŐ͗Zh< ͲůŝŶĞ͕WdůƵďƌŝĐĂƚŽƌ͘DhZ 'ŽtĞůůĞWdůŽŐŐŝŶŐ
ƚŽŽůƐнĂŬĞƌ,ƵŐŚĞƐƚƌĂĐƚŽƌ͘KƉĞŶƵƉ͕t,WϭϰϴϬƉƐŝ͘Z/,ƚŽϮϬϬϬ͕͛ƚŽŽůƌĞĂĚŝŶŐĞƌƌŽƌƐ͕WKK,͕
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ϯͬϮϰͬϮϱ ZhWŽůůĂƌĚ͘
ZƵŶϭ͗^ƵƌĨĂĐĞWƌĞƐƐƵƌĞZ/,ΛϳϰϬƉƐŝ͕&>ΛϯϱϯϬ͛Z<
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ϰͬϮϲͬϮϱ Zh< ͲůŝŶĞ͕ĂŬĞƌƚƌĂĐƚŽƌ͘
WdůƵďƌŝĐĂƚŽƌƚŽϮϯϱϬƉƐŝ͘/ŶŝƟĂůt,WϭϱϯϲƉƐŝ͘
DhĂŬĞƌϮ͘ϱ͟ƚƌĂĐƚŽƌ͕< ͲůŝŶĞƐŽŶĚĞdžƉƌŽĚƵĐƟŽŶůŽŐŐŝŶŐd^͕K>ϰϮ͛͘
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dƌĂĐƚŽƌƚŽϴϱϳϱ͕͛ďĞŐŝŶďůĞĞĚŝŶŐǁĞůůĚŽǁŶƚŽůŽŐǁĂƚĞƌŝŶŇŽǁ͘
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dƌĂĐƚŽƌƚŽϴϵϱϬ͕͛t,WϲϬϬƉƐŝ͕ůŽŐĚLJŶĂŵŝĐƉĂƐƐƵƉƚŽϴϬϬϬ͛͘
WKK,͕ŇƵŝĚůĞǀĞůĂƚϱϲϬϬ͛;ϭϭϱďďůƐŝŶŇŽǁĚƵƌŝŶŐWWZK&ůŽŐŐŝŶŐͿ
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ϰͬϮϳͬϮϱ tĞůůďůĞĚƚŽnjĞƌŽƉƐŝŽǀĞƌŶŝŐŚƚƚŽƚĂŶŬ͘t,WϬƉƐŝ͘
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&ůƵŝĚůĞǀĞůĂƚϭϯϯϬ͛͘
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KƉĞŶ>h^ϰƚŽďĂĐŬŇŽǁŽŶ>h^ϲĂƚϭϯϴϱƉƐŝ͘
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>ŽŐĚLJŶĂŵŝĐƉĂƐƐƚŽϴϭϬϬ͕͛WKK,͘
&ŝŶĂůŇƵŝĚůĞǀĞůϲϯϴϴ͛͘;ϭϵϬďďůƐŽĨŇƵŝĚŵŽǀĞĚĚŽǁŶŚŽůĞĚƵƌŝŶŐ/WZK&ůŽŐŐŝŶŐͿ
ZDK< ͲůŝŶĞ͘
CLU S-6 Final Surveys Survey Geodetic Report
(Def Survey)
2.10.836.0
Comments MD
(ft)
Incl
(°)
Azim True
(°)
TVD
(ft)
VSEC
(ft)
NS
(ft)
EW
(ft)
DLS
(°/100ft)
Northing
(ftUS)
Easting
(ftUS)
Latitude
(N/S ° ' ")
Longitude
(E/W ° ' ")
RTE 0.00 0.00 0.00 0.00 0.00 0.00 0.00 N/A 2392833.24 281945.47 N 60 32 39.03 W 151 12 40.18
21.92 0.00 0.00 21.92 0.00 0.00 0.00 0.00 2392833.24 281945.47 N 60 32 39.03 W 151 12 40.18
158.78 0.22 145.52 158.78 -0.09 -0.22 0.15 0.16 2392833.02 281945.61 N 60 32 39.03 W 151 12 40.17
202.00 0.09 211.38 202.00 -0.09 -0.31 0.18 0.46 2392832.92 281945.64 N 60 32 39.03 W 151 12 40.17
260.00 0.06 153.75 260.00 -0.06 -0.38 0.17 0.13 2392832.86 281945.63 N 60 32 39.03 W 151 12 40.17
321.50 0.27 249.43 321.50 0.07 -0.46 0.05 0.46 2392832.78 281945.51 N 60 32 39.03 W 151 12 40.17
383.00 0.52 313.34 383.00 0.37 -0.32 -0.29 0.76 2392832.93 281945.17 N 60 32 39.03 W 151 12 40.18
443.00 0.73 295.97 442.99 0.80 0.03 -0.83 0.47 2392833.29 281944.64 N 60 32 39.03 W 151 12 40.19
510.00 1.71 296.06 509.98 1.87 0.66 -2.12 1.46 2392833.94 281943.37 N 60 32 39.04 W 151 12 40.22
592.50 4.21 287.16 592.36 5.36 2.10 -6.12 3.07 2392835.45 281939.39 N 60 32 39.05 W 151 12 40.30
630.00 5.31 289.39 629.73 7.96 3.08 -9.07 2.97 2392836.48 281936.46 N 60 32 39.06 W 151 12 40.36
664.73 6.08 290.17 664.29 10.78 4.25 -12.31 2.23 2392837.71 281933.24 N 60 32 39.07 W 151 12 40.42
724.60 7.53 294.21 723.74 16.41 6.95 -18.86 2.55 2392840.53 281926.74 N 60 32 39.10 W 151 12 40.55
789.17 8.02 289.70 787.71 23.38 10.20 -26.96 1.21 2392843.94 281918.70 N 60 32 39.13 W 151 12 40.71
852.85 10.26 289.23 850.58 31.72 13.57 -36.50 3.52 2392847.48 281909.23 N 60 32 39.16 W 151 12 40.90
915.25 13.02 288.71 911.69 42.16 17.65 -48.41 4.43 2392851.78 281897.40 N 60 32 39.20 W 151 12 41.14
979.87 15.36 286.92 974.34 55.47 22.48 -63.49 3.68 2392856.88 281882.40 N 60 32 39.25 W 151 12 41.44
1044.25 17.19 284.36 1036.14 70.99 27.32 -80.87 3.05 2392862.04 281865.12 N 60 32 39.30 W 151 12 41.79
1107.89 17.29 282.55 1096.92 87.56 31.71 -99.21 0.86 2392866.77 281846.86 N 60 32 39.34 W 151 12 42.16
1168.69 18.22 279.56 1154.82 104.20 35.25 -117.40 2.14 2392870.64 281828.74 N 60 32 39.38 W 151 12 42.52
1233.26 19.82 277.11 1215.86 123.52 38.28 -138.22 2.77 2392874.06 281807.98 N 60 32 39.41 W 151 12 42.94
1295.10 21.15 273.81 1273.80 143.78 40.32 -159.76 2.85 2392876.49 281786.49 N 60 32 39.43 W 151 12 43.37
1358.94 24.11 270.66 1332.72 167.24 41.24 -184.30 5.01 2392877.86 281761.97 N 60 32 39.44 W 151 12 43.86
1421.91 27.37 268.30 1389.43 193.71 40.96 -211.63 5.43 2392878.08 281734.64 N 60 32 39.43 W 151 12 44.41
1484.52 29.48 270.68 1444.49 222.54 40.71 -241.43 3.82 2392878.39 281704.84 N 60 32 39.43 W 151 12 45.00
1548.33 30.97 271.62 1499.63 253.38 41.36 -273.54 2.45 2392879.63 281672.75 N 60 32 39.44 W 151 12 45.64
1611.61 32.22 272.94 1553.53 285.02 42.69 -306.66 2.26 2392881.56 281639.66 N 60 32 39.45 W 151 12 46.31
1674.78 34.22 273.35 1606.37 317.89 44.59 -341.22 3.19 2392884.10 281605.15 N 60 32 39.47 W 151 12 47.00
1738.19 36.80 274.14 1657.98 352.75 47.00 -377.97 4.13 2392887.19 281568.45 N 60 32 39.49 W 151 12 47.73
1802.66 38.89 274.62 1708.89 390.04 50.03 -417.40 3.27 2392890.94 281529.08 N 60 32 39.52 W 151 12 48.52
1866.99 39.60 276.17 1758.71 428.17 53.86 -457.92 1.88 2392895.51 281488.64 N 60 32 39.56 W 151 12 49.33
1928.47 40.06 276.48 1805.92 464.84 58.20 -497.06 0.81 2392900.57 281449.59 N 60 32 39.60 W 151 12 50.11
1992.27 40.77 275.88 1854.50 503.39 62.65 -538.18 1.27 2392905.78 281408.56 N 60 32 39.65 W 151 12 50.93
2055.62 42.26 275.33 1901.93 542.67 66.75 -579.96 2.42 2392910.64 281366.86 N 60 32 39.69 W 151 12 51.77
2119.75 44.04 275.46 1948.72 583.76 70.87 -623.63 2.78 2392915.57 281323.28 N 60 32 39.73 W 151 12 52.64
2183.38 45.66 275.36 1993.83 625.80 75.10 -668.30 2.55 2392920.62 281278.70 N 60 32 39.77 W 151 12 53.54
2246.94 47.93 274.17 2037.34 669.38 78.94 -714.47 3.82 2392925.31 281232.61 N 60 32 39.81 W 151 12 54.46
2309.26 50.48 273.51 2078.05 714.01 82.09 -761.54 4.17 2392929.33 281185.61 N 60 32 39.84 W 151 12 55.40
2372.82 53.15 273.58 2117.34 761.35 85.18 -811.40 4.20 2392933.34 281135.82 N 60 32 39.87 W 151 12 56.40
2436.39 54.80 273.34 2154.73 810.10 88.28 -862.71 2.61 2392937.38 281084.57 N 60 32 39.90 W 151 12 57.42
2500.79 56.08 273.52 2191.26 860.39 91.46 -915.65 2.00 2392941.53 281031.70 N 60 32 39.93 W 151 12 58.48
2564.10 56.66 273.43 2226.32 910.37 94.65 -968.27 0.92 2392945.69 280979.15 N 60 32 39.96 W 151 12 59.53
2625.87 56.88 273.51 2260.17 959.36 97.78 -1019.84 0.37 2392949.77 280927.65 N 60 32 39.99 W 151 13 0.56
2688.60 58.92 273.30 2293.51 1009.76 100.94 -1072.89 3.26 2392953.90 280874.67 N 60 32 40.02 W 151 13 1.63
2753.04 59.48 273.71 2326.50 1062.22 104.32 -1128.13 1.03 2392958.30 280819.50 N 60 32 40.06 W 151 13 2.73
2801.26 59.93 273.63 2350.83 1101.65 106.98 -1169.68 0.94 2392961.73 280778.01 N 60 32 40.08 W 151 13 3.56
2903.81 60.12 274.94 2402.07 1185.46 113.62 -1258.27 1.12 2392970.00 280689.57 N 60 32 40.15 W 151 13 5.33
2968.08 58.20 274.77 2435.01 1237.34 118.29 -1313.25 3.00 2392975.68 280634.68 N 60 32 40.19 W 151 13 6.43
3032.20 57.59 274.23 2469.09 1288.52 122.56 -1367.39 1.19 2392980.94 280580.63 N 60 32 40.24 W 151 13 7.51
3096.55 57.51 272.90 2503.62 1339.97 125.93 -1421.59 1.75 2392985.31 280526.51 N 60 32 40.27 W 151 13 8.60
3159.49 57.31 272.57 2537.52 1390.46 128.46 -1474.56 0.54 2392988.81 280473.60 N 60 32 40.29 W 151 13 9.66
3222.46 57.46 271.93 2571.46 1441.10 130.55 -1527.56 0.89 2392991.87 280420.65 N 60 32 40.31 W 151 13 10.72
3286.94 57.17 271.47 2606.28 1493.06 132.16 -1581.80 0.75 2392994.48 280366.44 N 60 32 40.33 W 151 13 11.80
3349.37 57.18 272.13 2640.12 1543.26 133.80 -1634.24 0.89 2392997.09 280314.05 N 60 32 40.35 W 151 13 12.85
3411.58 57.31 273.99 2673.78 1592.98 136.60 -1686.48 2.52 2393000.85 280261.87 N 60 32 40.37 W 151 13 13.89
3476.29 57.67 275.26 2708.56 1644.35 141.00 -1740.87 1.75 2393006.25 280207.57 N 60 32 40.42 W 151 13 14.98
3538.23 58.09 275.78 2741.50 1693.46 146.04 -1793.08 0.98 2393012.25 280155.46 N 60 32 40.47 W 151 13 16.02
3602.26 58.12 274.19 2775.33 1744.53 150.77 -1847.24 2.11 2393017.97 280101.41 N 60 32 40.51 W 151 13 17.11
3666.70 57.80 274.25 2809.51 1796.09 154.79 -1901.71 0.50 2393023.00 280047.02 N 60 32 40.55 W 151 13 18.20
3729.83 57.30 275.71 2843.39 1846.13 159.41 -1954.78 2.11 2393028.59 279994.04 N 60 32 40.60 W 151 13 19.26
3794.24 57.54 276.99 2878.07 1896.65 165.41 -2008.72 1.72 2393035.59 279940.23 N 60 32 40.66 W 151 13 20.34
3856.71 58.12 276.65 2911.33 1945.72 171.69 -2061.23 1.04 2393042.83 279887.85 N 60 32 40.72 W 151 13 21.39
3919.31 57.75 276.29 2944.57 1995.07 177.67 -2113.94 0.77 2393049.78 279835.26 N 60 32 40.78 W 151 13 22.44
3982.89 57.01 275.75 2978.84 2045.03 183.29 -2167.20 1.37 2393056.38 279782.12 N 60 32 40.83 W 151 13 23.50
4047.20 57.30 274.71 3013.72 2095.70 188.21 -2221.00 1.43 2393062.29 279728.42 N 60 32 40.88 W 151 13 24.58
4111.58 57.24 273.65 3048.53 2146.83 192.16 -2275.01 1.39 2393067.23 279674.49 N 60 32 40.92 W 151 13 25.66
4174.43 56.89 273.10 3082.70 2196.87 195.27 -2327.67 0.92 2393071.30 279621.90 N 60 32 40.95 W 151 13 26.71
4237.97 57.00 273.23 3117.36 2247.45 198.21 -2380.84 0.24 2393075.22 279568.79 N 60 32 40.98 W 151 13 27.78
4301.39 56.79 274.61 3152.00 2297.69 201.84 -2433.84 1.85 2393079.83 279515.87 N 60 32 41.02 W 151 13 28.84
4365.70 56.77 275.46 3187.23 2348.21 206.56 -2487.43 1.11 2393085.53 279462.38 N 60 32 41.06 W 151 13 29.91
4428.12 57.01 275.78 3221.33 2397.12 211.68 -2539.47 0.58 2393091.61 279410.45 N 60 32 41.11 W 151 13 30.95
4491.82 57.34 275.54 3255.86 2447.18 216.96 -2592.74 0.61 2393097.87 279357.29 N 60 32 41.16 W 151 13 32.01
4555.96 57.42 275.35 3290.43 2497.78 222.08 -2646.51 0.28 2393103.98 279303.62 N 60 32 41.21 W 151 13 33.09
4619.39 57.37 275.16 3324.61 2547.89 226.98 -2699.72 0.26 2393109.86 279250.51 N 60 32 41.26 W 151 13 34.15
4682.55 57.27 275.21 3358.72 2597.76 231.78 -2752.67 0.17 2393115.63 279197.67 N 60 32 41.31 W 151 13 35.21
4746.17 57.40 275.12 3393.05 2648.02 236.60 -2806.01 0.24 2393121.44 279144.43 N 60 32 41.36 W 151 13 36.28
4809.03 57.30 275.27 3426.97 2697.67 241.40 -2858.72 0.26 2393127.20 279091.82 N 60 32 41.40 W 151 13 37.33
4871.52 57.22 275.29 3460.76 2746.95 246.23 -2911.06 0.13 2393133.00 279039.58 N 60 32 41.45 W 151 13 38.38
4935.21 57.26 275.09 3495.23 2797.20 251.08 -2964.40 0.27 2393138.82 278986.34 N 60 32 41.50 W 151 13 39.44
Total Gravity Field Strength:1001.1859mgn (9.80665 Based)
Total Corr Mag North->True
North:
Gravity Model:
55053.227 nT
GARM
Total Magnetic Field Strength:
Magnetic Dip Angle:
North Reference:
73.423 °
November 15, 2024
BGGM 2024
True North
0.0000 °
13.9231 °
Grid Convergence Used:
54.920 ft above Mean Sea LevelTVD Reference Elevation:
Seabed / Ground Elevation:33.000 ft above Mean Sea Level
Field:
Report Date:
Alaska - Kenai Unit
Client:CINGSA
December 27, 2024 - 12:13 PM Minimum Curvature / Lubinski
254.932 ° (True North)
0.000 ft, 0.000 ft
RKB
Survey / DLS Computation:
TVD Reference Datum:
Vertical Section Azimuth:
Vertical Section Origin:
UWI / API#:
CLU S-6
Structure / Slot:
Well:
Borehole:
Unknown / Unknown
CLU S-6
Cannery Loop Unit / CLU S-6
Location Grid N/E Y/X:
NAD27 Alaska State Plane, Zone 04, US Feet
189.036 ° / 8064.071 ft / 6.490 / 1.573
Coordinate Reference System:
Survey Name:CLU S-6 Final Surveys
Survey Date:
Grid Scale Factor:
Version / Patch:
Well HeadLocal Coord Referenced To:
13.923 °Magnetic Declination:
Declination Date:
0.99995411
Magnetic Declination Model:
N 60° 32' 39.02983", W 151° 12' 40.17510"
Tort / AHD / DDI / ERD Ratio:
CRS Grid Convergence Angle:
November 18, 2024
Location Lat / Long:
-1.0546 °
N 2392833.240 ftUS, E 281945.470 ftUS
Drilling Office 2.10.836.0
Alaska - Kenai Unit\Cannery Loop Unit\CLU S-6\CLU S-6\CLU S-6 Final Surveys
# SLB-Private 12/27/2024 12:22 PM Page 1 of 3
Comments MD
(ft)
Incl
(°)
Azim True
(°)
TVD
(ft)
VSEC
(ft)
NS
(ft)
EW
(ft)
DLS
(°/100ft)
Northing
(ftUS)
Easting
(ftUS)
Latitude
(N/S ° ' ")
Longitude
(E/W ° ' ")
4997.30 57.62 275.41 3528.64 2846.27 255.87 -3016.51 0.72 2393144.57 278934.33 N 60 32 41.55 W 151 13 40.49
5060.99 57.70 275.54 3562.71 2896.66 261.00 -3070.07 0.21 2393150.69 278880.87 N 60 32 41.60 W 151 13 41.56
5126.06 57.86 275.46 3597.41 2948.20 266.28 -3124.87 0.27 2393156.97 278826.18 N 60 32 41.65 W 151 13 42.65
5186.41 57.83 275.31 3629.53 2996.07 271.07 -3175.74 0.22 2393162.70 278775.41 N 60 32 41.70 W 151 13 43.67
5250.38 57.83 275.21 3663.59 3046.85 276.04 -3229.66 0.13 2393168.66 278721.59 N 60 32 41.74 W 151 13 44.75
5314.19 57.90 275.06 3697.53 3097.56 280.87 -3283.48 0.23 2393174.48 278667.88 N 60 32 41.79 W 151 13 45.82
5375.97 57.76 275.22 3730.42 3146.63 285.56 -3335.56 0.32 2393180.13 278615.89 N 60 32 41.84 W 151 13 46.86
5439.52 57.71 275.49 3764.35 3196.99 290.57 -3389.06 0.37 2393186.12 278562.49 N 60 32 41.89 W 151 13 47.93
5503.03 57.97 275.41 3798.15 3247.35 295.68 -3442.59 0.42 2393192.22 278509.07 N 60 32 41.94 W 151 13 49.00
5567.02 57.70 275.40 3832.22 3298.09 300.78 -3496.51 0.42 2393198.31 278455.25 N 60 32 41.99 W 151 13 50.08
5630.31 57.72 275.66 3866.03 3348.18 305.94 -3549.77 0.35 2393204.44 278402.11 N 60 32 42.04 W 151 13 51.15
5694.13 57.83 275.65 3900.06 3398.67 311.26 -3603.49 0.17 2393210.75 278348.49 N 60 32 42.09 W 151 13 52.22
5757.83 57.68 275.24 3934.05 3449.13 316.37 -3657.13 0.59 2393216.85 278294.96 N 60 32 42.14 W 151 13 53.29
5820.89 58.28 274.35 3967.48 3499.42 320.84 -3710.40 1.53 2393222.30 278241.78 N 60 32 42.18 W 151 13 54.36
5883.95 57.48 273.56 4001.01 3549.91 324.52 -3763.68 1.65 2393226.96 278188.58 N 60 32 42.22 W 151 13 55.42
5947.13 57.27 273.11 4035.07 3600.39 327.62 -3816.80 0.69 2393231.04 278135.53 N 60 32 42.25 W 151 13 56.49
6010.73 57.23 273.05 4069.48 3651.22 330.49 -3870.22 0.10 2393234.89 278082.18 N 60 32 42.28 W 151 13 57.55
6074.21 57.16 273.16 4103.87 3701.92 333.38 -3923.49 0.18 2393238.76 278028.96 N 60 32 42.31 W 151 13 58.62
6137.08 57.27 273.33 4137.91 3752.10 336.37 -3976.26 0.29 2393242.72 277976.26 N 60 32 42.34 W 151 13 59.67
6201.24 57.22 275.64 4172.63 3802.94 340.59 -4030.05 3.03 2393247.93 277922.56 N 60 32 42.38 W 151 14 0.75
6264.53 57.23 275.93 4206.89 3852.67 345.96 -4083.00 0.39 2393254.27 277869.73 N 60 32 42.43 W 151 14 1.81
6327.77 57.07 275.63 4241.20 3902.31 351.31 -4135.85 0.47 2393260.59 277816.98 N 60 32 42.48 W 151 14 2.87
6390.32 57.40 275.19 4275.05 3951.59 356.27 -4188.22 0.79 2393266.51 277764.72 N 60 32 42.53 W 151 14 3.91
6455.93 57.33 275.35 4310.43 4003.40 361.34 -4243.23 0.23 2393272.60 277709.81 N 60 32 42.58 W 151 14 5.01
6518.69 57.91 275.00 4344.04 4053.12 366.12 -4296.02 1.04 2393278.35 277657.12 N 60 32 42.63 W 151 14 6.07
6581.41 59.03 273.10 4376.84 4103.63 369.89 -4349.34 3.14 2393283.10 277603.88 N 60 32 42.66 W 151 14 7.13
6644.73 60.52 271.19 4408.72 4155.89 371.93 -4404.01 3.51 2393286.15 277549.26 N 60 32 42.68 W 151 14 8.23
6708.32 61.13 269.09 4439.72 4209.47 372.06 -4459.53 3.04 2393287.30 277493.76 N 60 32 42.69 W 151 14 9.34
6770.10 62.17 267.16 4469.06 4262.40 370.28 -4513.87 3.22 2393286.52 277439.40 N 60 32 42.67 W 151 14 10.42
6834.38 62.40 265.24 4498.96 4318.20 366.51 -4570.64 2.67 2393283.79 277382.57 N 60 32 42.63 W 151 14 11.56
6896.90 63.04 263.06 4527.61 4373.05 360.84 -4625.91 3.26 2393279.14 277327.20 N 60 32 42.57 W 151 14 12.66
6960.68 62.67 261.37 4556.71 4429.34 353.16 -4682.14 2.43 2393272.49 277270.85 N 60 32 42.50 W 151 14 13.79
7023.14 62.26 259.44 4585.59 4484.47 343.93 -4736.75 2.82 2393264.27 277216.08 N 60 32 42.41 W 151 14 14.88
7086.48 62.82 257.19 4614.80 4540.57 332.54 -4791.78 3.27 2393253.90 277160.85 N 60 32 42.30 W 151 14 15.98
7149.53 63.37 254.96 4643.34 4596.78 319.01 -4846.35 3.27 2393241.38 277106.05 N 60 32 42.16 W 151 14 17.07
7213.13 63.97 252.72 4671.55 4653.76 303.14 -4901.09 3.29 2393226.52 277051.02 N 60 32 42.01 W 151 14 18.16
7277.18 64.27 250.68 4699.51 4711.29 285.05 -4955.80 2.90 2393209.44 276995.99 N 60 32 41.83 W 151 14 19.26
7341.23 65.05 248.40 4726.92 4768.92 264.81 -5010.03 3.44 2393190.21 276941.40 N 60 32 41.63 W 151 14 20.34
7404.36 66.15 246.60 4753.00 4825.92 242.81 -5063.14 3.13 2393169.19 276887.90 N 60 32 41.41 W 151 14 21.40
7467.84 67.56 245.78 4777.95 4883.61 219.25 -5116.54 2.52 2393146.61 276834.08 N 60 32 41.18 W 151 14 22.47
7531.89 68.99 244.58 4801.66 4942.25 194.27 -5170.54 2.83 2393122.63 276779.63 N 60 32 40.93 W 151 14 23.55
7594.31 71.38 243.55 4822.82 4999.92 168.58 -5223.34 4.13 2393097.92 276726.36 N 60 32 40.68 W 151 14 24.61
7657.81 73.14 241.85 4842.17 5059.02 140.84 -5277.08 3.77 2393071.18 276672.13 N 60 32 40.41 W 151 14 25.68
7720.73 75.34 240.66 4859.26 5117.85 111.72 -5330.17 3.94 2393043.04 276618.52 N 60 32 40.12 W 151 14 26.74
7785.02 77.29 239.00 4874.47 5178.15 80.33 -5384.16 3.94 2393012.64 276563.95 N 60 32 39.81 W 151 14 27.82
7848.35 78.79 237.83 4887.59 5237.55 47.88 -5436.94 2.98 2392981.17 276510.59 N 60 32 39.49 W 151 14 28.88
7914.69 79.03 236.04 4900.35 5299.46 12.36 -5491.49 2.67 2392946.67 276455.40 N 60 32 39.14 W 151 14 29.97
7940.38 79.17 235.59 4905.21 5323.30 -1.81 -5512.36 1.80 2392932.88 276434.27 N 60 32 39.00 W 151 14 30.38
7959.66 79.41 235.34 4908.80 5341.16 -12.55 -5527.97 1.78 2392922.43 276418.47 N 60 32 38.89 W 151 14 30.70
7974.98 79.62 235.54 4911.58 5355.36 -21.10 -5540.37 1.88 2392914.12 276405.91 N 60 32 38.81 W 151 14 30.94
8040.36 79.58 235.23 4923.39 5415.96 -57.63 -5593.30 0.47 2392878.57 276352.33 N 60 32 38.45 W 151 14 32.00
8069.24 79.61 235.56 4928.60 5442.73 -73.76 -5616.68 1.13 2392862.87 276328.66 N 60 32 38.29 W 151 14 32.47
8100.22 79.15 235.27 4934.31 5471.43 -91.04 -5641.74 1.75 2392846.05 276303.28 N 60 32 38.12 W 151 14 32.97
8110.12 78.89 235.48 4936.20 5480.59 -96.57 -5649.74 3.35 2392840.68 276295.18 N 60 32 38.07 W 151 14 33.13
8190.34 79.55 235.09 4951.20 5554.80 -141.45 -5714.52 0.95 2392797.00 276229.59 N 60 32 37.62 W 151 14 34.42
8255.79 83.18 234.16 4961.03 5615.48 -178.90 -5767.27 5.72 2392760.52 276176.16 N 60 32 37.25 W 151 14 35.48
8318.57 85.21 231.99 4967.38 5673.44 -216.42 -5817.19 4.72 2392723.93 276125.56 N 60 32 36.88 W 151 14 36.48
8381.64 85.32 231.50 4972.58 5731.22 -255.34 -5866.55 0.79 2392685.93 276075.50 N 60 32 36.50 W 151 14 37.46
8445.04 85.52 230.91 4977.64 5789.07 -294.93 -5915.81 0.98 2392647.25 276025.52 N 60 32 36.11 W 151 14 38.45
8510.17 85.26 227.99 4982.88 5847.67 -337.13 -5965.13 4.49 2392605.97 275975.43 N 60 32 35.70 W 151 14 39.43
8572.84 85.23 225.86 4988.08 5902.81 -379.79 -6010.75 3.39 2392564.16 275929.04 N 60 32 35.27 W 151 14 40.34
8635.17 85.23 223.87 4993.26 5956.56 -423.81 -6054.56 3.18 2392520.96 275884.42 N 60 32 34.84 W 151 14 41.22
8699.51 85.26 221.41 4998.59 6010.76 -470.97 -6097.99 3.81 2392474.60 275840.14 N 60 32 34.38 W 151 14 42.09
8763.08 85.29 218.75 5003.83 6062.74 -519.44 -6138.78 4.17 2392426.89 275798.47 N 60 32 33.90 W 151 14 42.90
8826.58 85.34 216.68 5009.02 6113.14 -569.50 -6177.49 3.25 2392377.56 275758.84 N 60 32 33.41 W 151 14 43.68
8889.26 85.24 214.01 5014.17 6161.28 -620.45 -6213.63 4.25 2392327.28 275721.77 N 60 32 32.90 W 151 14 44.40
8953.40 85.29 211.90 5019.46 6208.79 -674.09 -6248.40 3.28 2392274.30 275686.03 N 60 32 32.38 W 151 14 45.09
9016.99 85.40 210.66 5024.62 6254.65 -728.25 -6281.30 1.95 2392220.75 275652.13 N 60 32 31.84 W 151 14 45.75
9081.07 85.35 209.69 5029.79 6300.01 -783.47 -6313.41 1.51 2392166.14 275619.01 N 60 32 31.30 W 151 14 46.39
9144.19 85.44 209.26 5034.86 6344.14 -838.24 -6344.37 0.69 2392111.95 275587.06 N 60 32 30.76 W 151 14 47.01
9208.06 85.26 211.06 5040.04 6389.33 -893.28 -6376.35 2.82 2392057.51 275554.07 N 60 32 30.22 W 151 14 47.65
9270.48 85.35 211.89 5045.14 6434.49 -946.34 -6408.83 1.33 2392005.06 275520.62 N 60 32 29.69 W 151 14 48.30
9332.53 85.32 211.14 5050.19 6479.41 -999.06 -6441.16 1.21 2391952.95 275487.33 N 60 32 29.17 W 151 14 48.94
9396.26 85.29 211.70 5055.41 6525.48 -1053.26 -6474.27 0.88 2391899.36 275453.22 N 60 32 28.64 W 151 14 49.60
9459.57 85.35 210.26 5060.57 6570.90 -1107.36 -6506.75 2.27 2391845.88 275419.76 N 60 32 28.11 W 151 14 50.25
9523.02 85.41 211.55 5065.68 6616.37 -1161.62 -6539.23 2.03 2391792.22 275386.28 N 60 32 27.57 W 151 14 50.90
9585.64 85.34 211.73 5070.73 6661.80 -1214.76 -6571.97 0.31 2391739.70 275352.57 N 60 32 27.05 W 151 14 51.55
9650.32 85.41 211.54 5075.95 6708.73 -1269.65 -6605.79 0.31 2391685.44 275317.75 N 60 32 26.51 W 151 14 52.23
9713.98 85.34 211.47 5081.08 6754.81 -1323.75 -6638.94 0.16 2391631.97 275283.61 N 60 32 25.98 W 151 14 52.89
9777.18 85.37 211.88 5086.20 6800.69 -1377.36 -6672.02 0.65 2391578.98 275249.55 N 60 32 25.45 W 151 14 53.55
9840.51 85.26 211.58 5091.37 6846.70 -1431.04 -6705.22 0.50 2391525.92 275215.37 N 60 32 24.92 W 151 14 54.22
9904.03 85.26 210.03 5096.62 6892.13 -1485.41 -6737.63 2.43 2391472.16 275181.96 N 60 32 24.38 W 151 14 54.86
9966.07 86.47 210.88 5101.10 6936.29 -1538.75 -6769.00 2.38 2391419.40 275149.62 N 60 32 23.86 W 151 14 55.49
10029.49 86.81 210.61 5104.81 6981.68 -1593.17 -6801.36 0.68 2391365.60 275116.26 N 60 32 23.32 W 151 14 56.14
10093.30 86.81 210.71 5108.36 7027.30 -1647.97 -6833.85 0.16 2391311.40 275082.77 N 60 32 22.78 W 151 14 56.79
10156.54 87.29 210.58 5111.62 7072.51 -1702.31 -6866.04 0.79 2391257.67 275049.59 N 60 32 22.25 W 151 14 57.43
10219.79 87.35 210.88 5114.58 7117.81 -1756.62 -6898.33 0.48 2391203.97 275016.31 N 60 32 21.71 W 151 14 58.07
10283.63 86.78 209.31 5117.84 7163.02 -1811.77 -6930.30 2.61 2391149.41 274983.33 N 60 32 21.17 W 151 14 58.71
10346.32 85.69 209.17 5121.96 7206.71 -1866.36 -6960.85 1.75 2391095.40 274951.78 N 60 32 20.63 W 151 14 59.32
Proj to Well TD 10402.00 85.69 209.17 5126.15 7245.45 -1914.84 -6987.91 0.00 2391047.43 274923.83 N 60 32 20.15 W 151 14 59.86
Part MD From
(ft)
MD To
(ft)
EOU Freq
(ft)
Hole Size
(in)
Casing Diameter
(in)
1 0.000 21.920 1/98.425 16.000 13.375
1 21.920 202.000 Act Stns 16.000 13.375
1 202.000 630.000 Act Stns 16.000 13.375 SLB_NSG+SSHOT CLU S-6 / CLU S-6 Final Surveys
SLB_MWD-INC_ONLY CLU S-6 / CLU S-6 Final Surveys
Description Survey Tool Type Borehole / Survey
SLB_MWD-INC_ONLY-Depth
Only CLU S-6 / CLU S-6 Final Surveys
Survey Type:Def Survey
Survey Error Model:ISCWSA Rev 0 *** 3-D 95.000% Confidence 2.7955 sigma
Survey Program:
Drilling Office 2.10.836.0
Alaska - Kenai Unit\Cannery Loop Unit\CLU S-6\CLU S-6\CLU S-6 Final Surveys
# SLB-Private 12/27/2024 12:22 PM Page 2 of 3
Comments MD
(ft)
Incl
(°)
Azim True
(°)
TVD
(ft)
VSEC
(ft)
NS
(ft)
EW
(ft)
DLS
(°/100ft)
Northing
(ftUS)
Easting
(ftUS)
Latitude
(N/S ° ' ")
Longitude
(E/W ° ' ")
1 630.000 2801.260 Act Stns 16.000 13.375
1 2801.260 8110.120 Act Stns 12.250 9.625
1 8110.120 10402.000 Act Stns 8.750 7.000
SLB_MWD+DM+SAG CLU S-6 / CLU S-6 Final Surveys
SLB_MWD+DM+SAG CLU S-6 / CLU S-6 Final Surveys
SLB_MWD+DM+SAG CLU S-6 / CLU S-6 Final Surveys
Drilling Office 2.10.836.0
Alaska - Kenai Unit\Cannery Loop Unit\CLU S-6\CLU S-6\CLU S-6 Final Surveys
# SLB-Private 12/27/2024 12:22 PM Page 3 of 3
SURVEY MANAGEMENT
Client: Job No.: Report Date:
Field: Well Name: Borehole:
Stru/Slot: Survey:
Azimuth Reference:
Mag. Model / Mag. Decl. Date:BGGM 2024 15-Nov-24
Magnetic Declination:
Grid Convergence:
Total Correction:
Vertical Section Origin:
Vertical Section Plane:
DEFINITIVE SURVEY CONSTRUCTION - ORIGINAL WELL
Type:
WELL REFERENCE POINT LOCATION
MD INC AZ TVD VS NS EW Northing Easting Latitude Longitude
21.92 0.00 0.00 21.92 0.00 0.00 0.00 2392833.24 281945.47 N 60° 32' 39.02983" W 151° 12' 40.17510"
BOTTOM HOLE LOCATION
MD INC AZ TVD VS NS EW Northing Easting Latitude Longitude
10402.00 85.69 209.17 5126.15 7245.45 -1914.84 -6987.91 2391047.43 274923.83 N 60° 32' 20.15264" W 151° 14' 59.86160"
BOTTOM HOLE LOCATION COMPARISON SOURCE :
MD INC AZ TVD VS NS EW Northing Easting Latitude Longitude
10402.00 85.69 209.17 5126.15 7245.45 -1914.84 -6987.91 2391047.43 274923.83 N 60° 32' 20.15264" W 151° 14' 59.86160"
COMMENTS
Well Position Declaration Drilling Targets requirement met ?Yes
DEFINITIVE SURVEY SIGNED OFF
For Schlumberger:
Checked By: (Sign)
WELL SURVEY FILE UPDATED AND BACKED UP ON SERVER
Checked By: (Sign)
Name:
Date:
10402.00
16.00
Name:
Survey From
SLB_MWD-INC_ONLY
True North
21.92
W 151° 13' 5.50761"
CINGSA
7.00
202.00
N 60° 33' 10.69330"
Hole Size
2801.26
TVD Reference Elevation:
8110.12
SLB_NSG+SSHOT
Name:
0.00000000 °
16.00
SLB_MWD+DM+SAG
NAD27 Alaska State Plane, Zone 04, US Feet
0.00 ft(1.00 sigma)
0.000 ft, 0.000 ft
SLB_MWD+DM+SAG
SLB DEC Manager
Position:
Casing Size
N 60° 32' 39.02983"
8110.12
2396071.21
33.000 ft above Mean Sea Level
Gustavo Ramos
Instrument Type
Name:
Projection to TD:
13.9231 °
Date:
54.920 ft above Mean Sea Level
18-Nov-24
13.38
Position:
13.38
Date:
254.932 ° (True North)
27-Dec-24
280738.20
16.00
SLB_MWD+DM+SAG
281945.47
630.00
13.923 °
SLB_MWD-INC_ONLY-Depth Only
Seabed/GroundLevel:
9.632801.26
Alaska - Kenai Unit
Grid Coordinate System:
CLU S-6
202.00
CLU S-6
Survey Date:
Updated and Backed up By: (Sign)
Borehole: RKB
DEFINITIVE SURVEY SIGN-OFF
Position:
Survey To
13.38
Depth Units:
Prepared By: (Sign)
(ft)
Structure/Slot Uncertainty:
21.92
630.00
Date:
8.75
Opeyemi Oyelami
Date:
W 151° 12' 40.17510"
12.25
TVD Reference Datum:
Structure Reference:
CLU S-6 Final Surveys
0.00 ft(1.00 sigma)
Slot Coordinates:2392833.24
0.00
Cannery Loop Unit/CLU S-6
For Schlumberger:
Name:
Approved By: (Sign)
DE Great Bear Pantheon
SLB DE
For Client:
# SLB-Private
TRACT E
KN 2005-122
CITY OF KENAI
TRACT F1
KN 2014-20
STATE OF ALASKA
B
R
I
D
G
E
A
C
C
E
S
S
R
O
A
D
S4 S3
S9 S10
SECTION 4 T5N R11W
SECTION 9 T5N R11W
SE
C
T
I
O
N
9
T
5
N
R
1
1
W
SE
C
T
I
O
N
1
0
T
5
N
R
1
1
W
SECTION LINE
NOT TO SCALE
B
E
A
V
E
R
L
O
O
P
R
O
A
D
CLU S-1
CLU S-2
CLU S-3
CLU S-4
CLU S-5
SECTION CORNER
NAD83
N:2393280.90'
E:1423637.27'
NAD27
N:2393518.79'
E:283617.10'
CINGSA
DRILL PAD
CLU S-6 CLU S-7
SE
C
T
I
O
N
L
I
N
E
NO
T
T
O
S
C
A
L
E
REVISION:
DATE:
DRAWN BY:
SCALE:
PROJECT NO.
BOOK NO.
SHEET
OF
ENGINEERING / MAPPING / SURVEYING / TESTING
P.O. BOX 468 SOLDOTNA, AK. 99669
VOICE: (907) 283-4218 FAX: (907) 283-3265
PROJECT
LOCATION SECTION 9, T5N, R11W,
SEWARD MERIDIAN, ALASKA
1
7/3/2024
BGB
1"=150'
243002
24-04
1 2
CINGSA
CLU S-6 & CLU S-7 WELLS AS-BUILT
SURFACE LOCATION DIAGRAM
717'
FNL
1660'
FEL
1610'
FEL
716'
FNL
REVISION:
DATE:
DRAWN BY:
SCALE:
PROJECT NO.
BOOK NO.
SHEET
OF
ENGINEERING / MAPPING / SURVEYING / TESTING
P.O. BOX 468 SOLDOTNA, AK. 99669
VOICE: (907) 283-4218 FAX: (907) 283-3265
1
7/3/2024
BGB
N/A
243002
24-04
2 2
CONTROL NOTE
PROJECT
LOCATION SECTION 9, T5N, R11W,
SEWARD MERIDIAN, ALASKA
CINGSA
CLU S-6 & CLU S-7 WELLS AS-BUILT
SURFACE LOCATION DIAGRAM
1) BASIS OF HORIZONTAL CONTROL; NAD83 US SURVEY FEET POSITION (EPOCH 2010) IS AN OPUS
SOLUTION FROM NGS STATIONS AC23 SOLDOTNA__AK2007 CORS ARP, AC47 SLOPEMTN__AK2007 CORS
ARP & DRIFTRIVERAK2006 CORS ARP for ADOT&PF BM 601
THE ALASKA STATE PLANE NAD83 ZONE 4 COORDINATES ARE:
N: 2393464.701
E: 1422055.725
LAT: 60°32'45.5509"N
LONG: -151°12'46.71771"W
2)BASIS OF VERTICAL CONTROL IS ADOT&PF BM 601 LOCATED AT BRIDE ACCESS RD. & BEAVER LOOP
RD INTERSECTION PER AKSAS PROJECT NO. 58703.
ELEV: 42.20' (NORTH AMERICAN VERTICAL DATUM OF 1988 (GEOID12A)
3)DATUM TRANSFORMATIONS FROM NAD83 TO NAD27 WERE DONE USING CORPSCON SOFTWARE
VERSION 6.0.1.
4)SURVEY PERFORMED BY MCLANE CONSULTING INC. ON JULY 3, 2024.
1
Page 1/1
Well Name: CLUS-6
Report Printed: 2/26/2025
www.peloton.com
Cement
API/UWI
50-133-20728-00-00
Surface Legal Location
Sec 9, T5N, R11W
Field Name
Cannery Loop
License # State/Province
Alaska
Well Configuration Type
Horizontal
Ground Elevation (ft)
33.00
Casing Flange Elevation (ft) KB-Ground Distance (ft)
21.92
KB-Casing Flange Distance (ft) Spud Date
11/20/2024 13:30
Rig Release Date
Intermediate Casing Cement
Intermediate Casing Cement, Casing, 12/11/2024 04:00
Type
Casing
Cementing Start Date
12/11/2024
Cementing End Date
12/11/2024
Wellbore
Original Hole
String
Intermediate, 8,130.4ftKB
Cementing Company
Dowell Schlumberger
Evaluation Method Cement Evaluation Results
Comment
1, 2,000.0-8,150.2ftKB
Top Depth (ftKB)
2,000.0
Bottom Depth (ftKB)
8,150.2
Full Return?
No
Vol Cement Ret (bbl)
0.0
Top Plug?
Yes
Bottom Plug?
Yes
Initial Pump Rate (bbl/min)
6
Final Pump Rate (bbl/min)
2
Avg Pump Rate (bbl/min)
6
Final Pump Pressure (psi)
1,950.0
Plug Bump Pressure (psi)
Pipe Reciprocated?
No
Reciprocation Stroke Length (ft) Reciprocation Rate (spm) Pipe Rotated?
No
Pipe RPM (rpm)
Tagged Depth (ftKB) Tag Method
Drill Bit
Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Drill Out Date
Lead
Fluid Type
Lead
Fluid Description
11.8 ppg Extended Class G
Cement
Amount (sacks)
831
Class
G
Volume Pumped (bbl)
284.0
Estimated Top (ftKB)
2,000.0
Estimated Bottom Depth (ftKB)
7,450.0
Percent Excess Pumped (%)
30.0
Yield (ft³/sack)
2.60
Mix H20 Ratio (gal/sack)
15.44
Free Water (%)
0.60
Density (lb/gal)
11.80
Plastic Viscosity (cP)
6.0
Thickening Time (hr)
7.05
1st Compressive Strength (psi)
50.0
Cement Stage Fluid Additives
Add Type Conc
Chemical Extender D020 3.0
Liquid Antifoam Agent D047 0.05
Cement Dispersant D065 0.2
Chemical Extender D079 1.1
Low Temp Liq Retarder D110A 0.3
Tail
Fluid Type
Tail
Fluid Description
14 PPG FLEXSTONE TAIL
Amount (sacks)
219
Class
G
Volume Pumped (bbl)
51.0
Estimated Top (ftKB)
7,450.0
Estimated Bottom Depth (ftKB)
8,150.2
Percent Excess Pumped (%)
15.0
Yield (ft³/sack)
1.30
Mix H20 Ratio (gal/sack)
4.13
Free Water (%)
0.00
Density (lb/gal)
14.00
Plastic Viscosity (cP)
232.0
Thickening Time (hr)
4.21
1st Compressive Strength (psi)
50.0
Cement Stage Fluid Additives
Add Type Conc
Liquid Antifoam Agent D047 0.1
Low Temp Liq Retarder D177 0.03
Cement Dispersant D202 0.6
GAS CONTROL AGENT D400 0.5
Page 1/1
Well Name: CLUS-6
Report Printed: 2/26/2025
www.peloton.com
Cement
API/UWI
50-133-20728-00-00
Surface Legal Location
Sec 9, T5N, R11W
Field Name
Cannery Loop
License # State/Province
Alaska
Well Configuration Type
Horizontal
Ground Elevation (ft)
33.00
Casing Flange Elevation (ft) KB-Ground Distance (ft)
21.92
KB-Casing Flange Distance (ft) Spud Date
11/20/2024 13:30
Rig Release Date
Production Liner Cement
Production Liner Cement, Casing, 12/19/2024 22:50
Type
Casing
Cementing Start Date
12/19/2024
Cementing End Date
12/20/2024
Wellbore
Original Hole
String
Liner, 10,401.0ftKB
Cementing Company
Dowell Schlumberger
Evaluation Method Cement Evaluation Results
Comment
1, 7,934.0-10,401.0ftKB
Top Depth (ftKB)
7,934.0
Bottom Depth (ftKB)
10,401.0
Full Return?
Yes
Vol Cement Ret (bbl) Top Plug?
Yes
Bottom Plug?
No
Initial Pump Rate (bbl/min)
3
Final Pump Rate (bbl/min)
3
Avg Pump Rate (bbl/min)
3
Final Pump Pressure (psi)
1,587.0
Plug Bump Pressure (psi)
1,587.0
Pipe Reciprocated?
No
Reciprocation Stroke Length (ft) Reciprocation Rate (spm) Pipe Rotated?
No
Pipe RPM (rpm)
Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Drill Out Date
Tail
Fluid Type
Tail
Fluid Description Amount (sacks)
384
Class
G
Volume Pumped (bbl)
92.0
Estimated Top (ftKB)
7,935.0
Estimated Bottom Depth (ftKB)
10,401.0
Percent Excess Pumped (%)
14.0
Yield (ft³/sack)
1.31
Mix H20 Ratio (gal/sack)
4.28
Free Water (%) Density (lb/gal)
14.00
Plastic Viscosity (cP) Thickening Time (hr) 1st Compressive Strength (psi)
Cement Stage Fluid Additives
Add Type Conc
Page 1/1
Well Name: CLUS-6
Report Printed: 2/26/2025
www.peloton.com
Cement
API/UWI
50-133-20728-00-00
Surface Legal Location
Sec 9, T5N, R11W
Field Name
Cannery Loop
License # State/Province
Alaska
Well Configuration Type
Horizontal
Ground Elevation (ft)
33.00
Casing Flange Elevation (ft) KB-Ground Distance (ft)
21.92
KB-Casing Flange Distance (ft) Spud Date
11/20/2024 13:30
Rig Release Date
Surface Casing Cement
Surface Casing Cement, Casing, 11/25/2024 16:00
Type
Casing
Cementing Start Date
11/25/2024
Cementing End Date
11/25/2024
Wellbore
Original Hole
String
Surface, 2,866.6ftKB
Cementing Company
Dowell Schlumberger
Evaluation Method
Returns to Surface
Cement Evaluation Results
124 BBLS CEMENT BACK TO SURFACE.
Comment
1, 24.9-2,866.6ftKB
Top Depth (ftKB)
24.9
Bottom Depth (ftKB)
2,866.6
Full Return?
Yes
Vol Cement Ret (bbl)
124.0
Top Plug?
Yes
Bottom Plug?
No
Initial Pump Rate (bbl/min)
5
Final Pump Rate (bbl/min)
3
Avg Pump Rate (bbl/min)
5
Final Pump Pressure (psi)
850.0
Plug Bump Pressure (psi)
1,550.0
Pipe Reciprocated?
No
Reciprocation Stroke Length (ft) Reciprocation Rate (spm) Pipe Rotated?
No
Pipe RPM (rpm)
Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Drill Out Date
Lead
Fluid Type
Lead
Fluid Description
12.0 PPG
Amount (sacks)
757
Class
G
Volume Pumped (bbl)
333.0
Estimated Top (ftKB)
25.0
Estimated Bottom Depth (ftKB)
2,366.0
Percent Excess Pumped (%)
87.0
Yield (ft³/sack)
2.47
Mix H20 Ratio (gal/sack)
14.48
Free Water (%)
1.24
Density (lb/gal)
12.00
Plastic Viscosity (cP)
8.0
Thickening Time (hr)
7.35
1st Compressive Strength (psi)
50.0
Cement Stage Fluid Additives
Add Type Conc
Chemical Extender D020 3.0
Liquid Antifoam Agent D047 0.05
Cement Dispersant D065 0.2
Chemical Extender D079 1.5
Liquid Accelerator D186 0.2
Tail
Fluid Type
Tail
Fluid Description
15.8 PPG
Amount (sacks)
378
Class
G
Volume Pumped (bbl)
78.0
Estimated Top (ftKB)
2,366.0
Estimated Bottom Depth (ftKB)
2,866.6
Percent Excess Pumped (%)
75.0
Yield (ft³/sack)
1.16
Mix H20 Ratio (gal/sack)
5.07
Free Water (%)
0.00
Density (lb/gal)
15.80
Plastic Viscosity (cP)
98.0
Thickening Time (hr)
3.10
1st Compressive Strength (psi)
50.0
Cement Stage Fluid Additives
Add Type Conc
Liquid Antifoam Agent D047 0.02
Cement Dispersant D065 0.5
Fluid Loss Control D167 0.35
CASING SUMMARY
RIG Nordic 37 Date 12/6/2024
WELL # CLUS-6
CASING 9 5/8" L-80 VamTop
CASING WT. 40
210 JTS ON RACK 198 JTS RAN 21.92 RT-GL
8567.08 FT ON RACK 7965.36 FT RAN
ITEM Description includes: SIZE, TYPE, CONNECTION (JTS #-#) 12.25" TD 8,162.00
ITEM ID OD LENGTH TOP BOTTOM
Halliburton 9 5/8" Float Shoe N/A 10.670 1.67 8128.73 8130.40
1 Jt 9 5/8" 40# L-80 BTC Casing (#1) 8.835 9.625 38.40 8090.33 8128.73
1 Jt 9 5/8" 40# L-80 BTC Casing (#2) 8.835 9.625 38.44 8051.89 8090.33
Halliburton 9 5/8" Float Collar N/A 10.670 1.29 8050.60 8051.89
1 JT 9 5/8" 40# L-80 BTC, baker lock FC on pin (#3 8.835 9.625 37.88 8012.72 8050.60
1 XO JT 9 5/8" 40# L-80 VamTop Box x BTC pin (#4) 8.835 9.625 40.44 7972.28 8012.72
9 5/8" 40# L-80 Vam Top Pup Jt. 8.835 9.625 4.76 7967.52 7972.28
9 5/8" 40# L-80 Vam Top Pup Jt. 8.835 9.625 9.75 7957.77 7967.52
194 Jts 9 5/8" 40# L-80 VamTop Casing ( #5-#198) 8.835 9.625 7933.14 24.63 7957.77
Csg Hanger w/ L-80 Pup BTC Pin top x Vam Top pin 8.835 13.505 2.85 21.78 24.63
9 5/8" Casing hang off to Rotary table 8.835 9.625 21.78 .21.78
PU Wt - 250k, SO Wt - 125k,
Casing hanger 9-5/8" Buttress thread
Baker-Lok Shoe-track Jts #1-3,
9-5/8" x 12" Mech-Form Steel Spiral Blade Centralizers:
1 on stop ring 10' above shoe on jt #1
1 on stop ring middle of joints #2
1 on stop rings from joints #3- #25 (23ea)
1 ea free floating on every other jts #26-118 (46 ea) Odd # Jnts
1 on stop rings from joints #118- #150 (33ea)
1 centralizer locked down on stop rings 5' up on joint 198.
105 total centralizers
118 stop rings
Casing drifted to 8.75"
CASING SUMMARY
RIG Nordic 37 Date 12/14/2024
WELL # CLUS-6
CASING 7" L-80 Vam Top HC
CASING WT. 26 Vam Top HC
195.47 Liner Lap
60 JTS ON RACK 59 Vam Top JTS RUN 7934.93 Liner Top
2457.79 FT ON RACK 2416.60 Total Ft. Ran 8130.40 9-5/8"Shoe
ITEM Description includes: SIZE, TYPE, CONNECTION (JTS 1-60 TD =
ITEM ID OD LENGTH TOP BOTTOM
7" Halliburton Float Shoe, BTC Box 7.875 2.30 10397.70 10400.00
1 Jt 7", 26# Vam Top HC box x BTC pin (Jt #1) 6.276 7.000 41.11 10356.59 10397.70
1 XOS Pup Jt 7", 26# BTC box x Vam Top HC pin 6.276 7.000 5.63 10350.96 10356.59
7" Halliburton Float Collar BTC BxP 6.26 7.590 1.02 10349.94 10350.96
1 XOS Jt 7", 26# L-80 Vam Top HC x BTC (Jt #2) 6.276 7.000 35.25 10314.69 10349.94
7" Baker Landing Collar (Pin end of Jt. #3) 4 7.62 .80 10313.89 10314.69
57 Jts 7", 26# L-80 VAM TOP HC (#3-59) 6.276 7.000 2340.24 7973.65 10313.89
7" 26# 13 cr RN nipple Vam Top (Above/Below NG 5.953) 5.838 7.67 1.74 7971.91 7973.65
7" 29#, L-80 VamTop Liner Pup Jnt 6.22 7.6 3.89 7968.02 7971.91
XO 7" 26# L-80 H563 B x Vam Top Pin 6.21 7.66 1.10 7966.92 7968.02
7" x 9-5/8" Baker HRD-E ZXP Hanger 6.18 8.3 9.31 7957.61 7966.92
Coupling 7" Hydril 563 BxB 6.35 8.43 1.33 7956.28 7957.61
7" x 9-5/8" Baker HRD-E ZXP Flex Lock LTP (TBR 7.37" x 11.36') 6.19 8.43 21.35 7934.93 7956.28
Drifted to 6.151"
Jet Lube Seal Guard Pipe Dope on Vam Top HC Threads
CASING SUMMARY
RIG Nordic 37 Date 11/25/2024
WELL # CLUS-6
CASING 13 3/8" J-55 BTC
CASING WT. 68
70 JTS ON RACK 68 JTS RAN 23.42 RT-Cut Point
2948.06 FT ON RACK 2863.84 FT RAN 12.43 Rat Hole
ITEM Description includes: SIZE, TYPE, CONNECTION (JTS #-#)16" TD 2,879.00
ITEM ID OD LENGTH TOP BOTTOM
HES Float Shoe N/A 14.825 1.80 2864.77 2866.57
2 Jts 13 3/8" 68# J-55 BTC Casing (#1- #2) 12.415 14.375 84.28 2780.49 2864.77
Halliburton 13 3/8" Sting in Float Collar N/A 14.375 2.20 2778.29 2780.49
63 Jts 13 3/8" 68# J-55 BTC Casing ( #3 - #67) 12.415 14.375 2737.49 40.80 2778.29
13 3/8" 68# J-55 BTC Cut Joint Left in Well (#68) 12.415 13.375 17.38 23.42 40.80
13 3/8" 68# J-55 BTC Cut Joint Removed (#68) 24.69 -1.27 23.42
42.07
PU 220Wt k, SO 90Wt k
Baker-Lok Shoe-track Jts #1-3
Summit Solid Straight Blade Centralizers
1 Centralizer w/2 stop rings 5' above shoe on jt #1
1 Centralizer on jts #2 & #3 locked down mid jt with 4 stop rings
1 free-floating on jt #4 - #12
1 Free floating ever other jt f/ #14 - #66 (Even # Jnts) 27 total
Total 39 Centralizers run and 6 stop Rings
Drifted to 12.259
Data check of Joint #68 Length
TUBING SUMMARY
RIG Nordic 37 Date 12/22/2024
WELL # CLUS-6
CASING 7" L-80 VamTopHC
CASING WT. 26
200 JTS ON RACK 190 JTS 20.60 ULDS
8269.74 FT ON RACK 7851.73 FT RAN
7938.00
ITEM Description includes: SIZE, TYPE, CONNECTION (JTS #-#)7949.00
ITEM ID OD LENGTH TOP BOTTOM
7 3/8" Tieback Assembly, VamTop box (9.58' Bullet tie back seal assy)6.18 7.870 21.58 7925.76 7947.34
7" 26# L-80 Vam Top HC (#1-187) 6.276 7.656 7732.64 193.12 7925.76
7" 26# L-80 Vam Top Pup Jt 6.276 7.656 4.79 188.33 193.12
HES, RRQ HYD Landing Nipple w/ Isolation Sleeve Vam Top 4.75 7.620 3.42 184.91 188.33
7" 26# L-80 Vam Top Pup jt 6.276 7.656 4.78 180.13 184.91
7" 26# L-80 Vam Top HC (#188-189) 6.276 7.656 82.26 97.87 180.13
7" 26# L-80 Vam Top HC Pup Joints 6.276 7.656 7.79 90.08 97.87
7" 26# L-80 Vam Top HC Pup Joints 6.276 7.656 9.81 80.27 90.08
7" 26# L-80 Vam Top HC Pup Joints 6.276 7.656 19.83 60.44 80.27
7" 26# L-80 Vam Top HC (#190) 6.276 7.656 36.83 23.61 60.44
7" 26# L-80 VamTop x VamTop Hanger P x P Pup Jt 6.276 7.533 2.19 21.42 23.61
13.5" x 7" FMC Hanger 6.125 13.500 .82 20.60 21.42
Nordic 37 RT to LDS 20.60 . 20.60
14 Stainless Steel Bands installed around 1/4" Control Line
PUW 175K, SOW105 K w/ Traveling Block
Drifted to 6.151"
Landed with 105k with blocks, 75k with out traveing block wt.
Seal assembly has 8.25' of swallow inside of the tie back seal bore
There is a 2.78 ft of diffence between liner tally and tbg tally for Top of Liner.
Top of Linerfor liner run is 7935'
Top of liner for tbg run is 7937.78.
Top of Tieback Receptacle =
Bottom of Tieback Receptacle =
1
Gluyas, Gavin R (OGC)
From:McLellan, Bryan J (OGC)
Sent:Wednesday, March 19, 2025 8:43 AM
To:Flora, Jacob
Cc:Matthew Federle
Subject:RE: CLUS-06 AOGCC 10-403 PTD 224-112 - Diagnostics, Request for Additional Sundry
Steps
Jake,
Approval is granted to proceed with the plan below under the existing sundry. Conditions of approval on the
original sundry still apply. E-line lubricator to be pressure tested to at least 2000 psi.
Bryan McLellan
Senior Petroleum Engineer
Alaska Oil & Gas Conservation Commission
Bryan.mclellan@alaska.gov
+1 (907) 250-9193
From: Flora, Jacob <JFlora@asrcenergy.com>
Sent: Wednesday, March 19, 2025 7:46 AM
To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Cc: Matthew Federle <Matthew.Federle@enstarnaturalgas.com>
Subject: RE: CLUS-06 AOGCC 10-403 PTD 224-112 - Diagnostics, Request for Additional Sundry Steps
Bryan,
In step 6 we would use the tractor to reperforate.
From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Sent: Tuesday, March 18, 2025 5:22 PM
To: Flora, Jacob <JFlora@asrcenergy.com>
Cc: Matthew Federle <Matthew.Federle@enstarnaturalgas.com>
Subject: RE: CLUS-06 AOGCC 10-403 PTD 224-112 - Diagnostics, Request for Additional Sundry Steps
Jake,
In step #6, Are you planning to re-perf with CT or with E-line tractor?
Bryan McLellan
Senior Petroleum Engineer
❚❛❜CAUTION: EXTERNAL SENDER This email originated from outside of the organization. Do not click
links or open attachments unless you recognize the sender and know the content is safe.
2
Alaska Oil & Gas Conservation Commission
Bryan.mclellan@alaska.gov
+1 (907) 250-9193
From: Flora, Jacob <JFlora@asrcenergy.com>
Sent: Tuesday, March 18, 2025 3:06 PM
To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Cc: Matthew Federle <Matthew.Federle@enstarnaturalgas.com>
Subject: CLUS-06 AOGCC 10-403 PTD 224-112 - Diagnostics, Request for Additional Sundry Steps
Hello Bryan,
We completed the baseline casing evaluation log and shortly after attempted the flow test. The well was given a
400 psi drawdown and did not sustain flow as expected.
CINGSA requests to perform the below steps under open sundry 324-715:
1. Use slickline to run a PT survey to identify fluid if present (non sundry)
2. If fluid present attempt to unload to tank (non sundry)
3. If unable to unload, RU coiled tubing, blow well dry with nitrogen (Sundry 324-715)
4. Re-perf select intervals as needed within the existing approved depths (Sundry 324-715)
5. If minimal fluid, RU E-line and tractor, log GR/CCL to confirm perforations are on depth
6. Re-perf select intervals as needed within the existing approved depths (Sundry 324-715)
All work will be performed within the sundry requirement of the 3000 psi BOP test, including 24hr notification if
coiled tubing is placed back on the wellbore.
The casing logs are being processed now and I will submit them upon completion.
Please let me know if you need any additional data to evaluate this request.
Thanks,
Jake
Jake Flora
Drilling & Completion Engineer
ASRC Energy Services
Cell: 720-988-5375
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.
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
BOPE Test Report for:
Reviewed By:
P.I. Suprv
Comm ________CANNERY LOOP UNIT S-6
JBR 04/01/2025
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
Test Fluid Was Neat Methanol
Test Results
TEST DATA
Rig Rep:Buddy MarshallOperator:Cook Inlet Natural Gas Storage Alaska, LL Operator Rep:Josh Murphy
Rig Owner/Rig No.:Fox 10 PTD#:2241120 DATE:3/3/2025
Type Operation:WRKOV Annular:
Type Test:WKLY
Valves:
250/3000
Rams:
250/3000
Test Pressures:Inspection No:bopBDB250304064235
Inspector Brian Bixby
Inspector
Insp Source
Related Insp No:
INSIDE REEL VALVES:
Quantity P/F
(Valid for Coil Rigs Only)
Remarks:
Test Time 6.5
MASP:
1460
Sundry No:
324-715
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 O
Misc NA
Upper Kelly 0 NA
Lower Kelly 0 NA
Ball Type 0 NA
Inside BOP 0 NA
FSV Misc 0 NA
5 PNo. Valves
2 PManual Chokes
0 NAHydraulic Chokes
0 NACH Misc
Stripper 1 2"P
Annular Preventer 0 NA
#1 Rams 1 Blind Shear P
#2 Rams 1 2" Pipe Slips P
#3 Rams 0 NA
#4 Rams 0 NA
#5 Rams 0 NA
#6 Rams 0 NA
Choke Ln. Valves 2 2"P
HCR Valves 0 NA
Kill Line Valves 2 2"P
Check Valve 0 NA
BOP Misc 0 NA
System Pressure P2950
Pressure After Closure P2300
200 PSI Attained P3
Full Pressure Attained P8
Blind Switch Covers:PYES
Bottle precharge P
Nitgn Btls# &psi (avg)NA
ACC Misc NA0
NA NATrip Tank
NA NAPit Level Indicators
NA NAFlow Indicator
NA NAMeth Gas Detector
NA NAH2S Gas Detector
0 NAMS Misc
Inside Reel Valves 1 P
Annular Preventer NA0
#1 Rams P21
#2 Rams P23
#3 Rams NA0
#4 Rams NA0
#5 Rams NA0
#6 Rams NA0
HCR Choke NA0
HCR Kill NA0
9
9
9 9 9 9
9
9
9
9
9
⚠️CAUTION: EXTERNAL SENDER This email originated from outside of the
organization. Do not click links or open attachments unless you recognize the sender
and know the content is safe.
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.
You don't often get email from lseymour@asrcenergy.com. Learn why this is important
From:McLellan, Bryan J (OGC)
To:Seymour, Len
Cc:Flora, Jacob
Subject:RE: CLU S-06 RBT Field Print
Date:Monday, February 10, 2025 9:22:00 AM
Attachments:image002.png
Thanks Len. Cement looks good. CINGSA has approval to proceed with perfs per the sundry
324-715.
Bryan McLellan
Senior Petroleum Engineer
Alaska Oil & Gas Conservation Commission
Bryan.mclellan@alaska.gov
+1 (907) 250-9193
From: Seymour, Len <lseymour@asrcenergy.com>
Sent: Sunday, February 9, 2025 8:54 AM
To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Cc: Flora, Jacob <JFlora@asrcenergy.com>
Subject: FW: CLU S-06 RBT Field Print
Bryan, here is the CBL field print for CLUS-6 well. Len Seymour
From: Corey Goerdt <Corey.Goerdt@readcasedhole.com>
Sent: Saturday, February 8, 2025 4:52 PM
To: Cerveny, Philip <pcerveny@asrcenergy.com>; Seymour, Len <lseymour@asrcenergy.com>
Cc: Olsen, Clark <colsen@asrcenergy.com>; Flora, Jacob <JFlora@asrcenergy.com>; Joshua Murphy
<josh@mpactes.com>
Subject: CLU S-06 RBT Field Print
Here is the field print for the RBT ran on CLU S-6 today. If another depth shift is required I can
make changes.
Corey Goerdt
Field Engineer
Cell: +1 907 354 0805 / Direct: +1 907 659 2307
The information contained in this message is sent in the strictest confidence for the addressee only. It is confidential and intended only
for the use of the addressee in relation to the ends originally intended to. It may contain privileged information. If you have received this
email in error you are requested to preserve its confidentiality and advise the sender of the error in transmission. READ has made
reasonable efforts to guarantee this message is free from computer viruses and other defects but it is the responsibility of the addressee
to scan this email and any attachments. READ does not accept liability for any loss or damage of any nature, however caused, which may
result directly or indirectly from this email or any file attached.
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
BOPE Test Report for:
Reviewed By:
P.I. Suprv
Comm ________CANNERY LOOP UNIT S-6
JBR 03/21/2025
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 Test Results
TEST DATA
Rig Rep:Buddy MarshallOperator:Cook Inlet Natural Gas Storage Alaska, LL Operator Rep:Len Seymour
Rig Owner/Rig No.:Fox 10 PTD#:2241120 DATE:2/5/2025
Type Operation:WRKOV Annular:
Type Test:INIT
Valves:
250/3500
Rams:
250/3500
Test Pressures:Inspection No:bopAGE250207095115
Inspector Adam Earl
Inspector
Insp Source
Related Insp No:
INSIDE REEL VALVES:
Quantity P/F
(Valid for Coil Rigs Only)
Remarks:
Test Time 2.5
MASP:
1729
Sundry No:
324-715
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 O
Misc NA
Upper Kelly 0 NA
Lower Kelly 0 NA
Ball Type 0 NA
Inside BOP 0 NA
FSV Misc 0 NA
5 PNo. Valves
2 PManual Chokes
0 NAHydraulic Chokes
0 NACH Misc
Stripper 1 2"P
Annular Preventer 0 NA
#1 Rams 1 Blind/shear P
#2 Rams 1 2" Pipe Slip P
#3 Rams 0 NA
#4 Rams 0 NA
#5 Rams 0 NA
#6 Rams 0 NA
Choke Ln. Valves 2 2"P
HCR Valves 0 NA
Kill Line Valves 2 2"P
Check Valve 0 NA
BOP Misc 0 NA
System Pressure P3000
Pressure After Closure P2350
200 PSI Attained P3
Full Pressure Attained P18
Blind Switch Covers:PAll Stations
Bottle precharge P
Nitgn Btls# &psi (avg)NA
ACC Misc NA0
NA NATrip Tank
NA NAPit Level Indicators
NA NAFlow Indicator
NA NAMeth Gas Detector
NA NAH2S Gas Detector
0 NAMS Misc
Inside Reel Valves 1 P
Annular Preventer NA0
#1 Rams P21
#2 Rams P22
#3 Rams NA0
#4 Rams NA0
#5 Rams NA0
#6 Rams NA0
HCR Choke NA0
HCR Kill NA0
9
9
9
9 9 999
9
C a Ci f u.Aia- S -o(�
Pb 2-z4 it u
Regg, James B (OGQ
From:
ackermdwa@gmail.com
Sent:
Monday, January 27, 2025 5:36 PM
To:
Brooks, Phoebe L (OGQ
Cc:
Regg, James B (OGC); 'Isaacson, William'; 'ACES Company Man'; 'Mike.Hatten'
Subject:
RE: CLUS6 MIT 12-22-2024 question
Attachments:
MIT CLUS 6 12-22-24 Revised DA.xlsx
S
You don't often get email
from ackermdwa@gmail.com. Learn why this is important
Phoebe:
Here is the amended MITform.
Please let me know if you need anything else.
Thanks
Dennis
From: ACES Company Man <ACESCompanyMan@asrcenergy.com>
Sent: Monday, January 27, 2025 1:47 PM
To: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; Dennis Ackerman <ackermdwa@gmail.com>
Cc: Regg, James B (OGC) <jim.regg@alaska.gov>
Subject: Re: CLUS6 MIT 12-22-2024 question
Dennis,
Looks like they need more info.
Thanks,
Joey
Get Outlook for iOS
From: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>
Sent: Monday, January 27, 2025 12:29 PM
To: ACES Company Man <ACESCompanvMan asrcenergv.com>
Cc: Regg, James B (OGC) <iim.regg@alaska.gov>
Subject: RE: CLUS6 MIT 12-22-2024 question
I CAUTION: EXTERNAL SENDER This email originated from outside of the organization. Do not click
links or open attachments unless you recognize the sender and know the content is safe.
Dennis,
I've attached a revised report correcting the PTD # field and moving the Notes, but the MIT is still incomplete (the tubing
and OA should not be left blank). Please resubmit the completed report.
Thank you,
Phoebe
Phoebe Brooks
Research Analyst
Alaska Oil and Gas Conservation Commission
Phone:907-793-1242
CONFIDENTIALITYNO77CE: 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 phoe.be.brooks@alaska.gov.
From: ACES Company Man <ACESCompanyMan@asrcenergy.com>
Sent: Monday, December 23, 2024 5:34 PM
To: Regg, James B (OGC) <iim.regg@alaska.gov>; ACES Company Man <ACESCompanvMan@asrcener vg com>
Cc: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; Isaacson, William <wisaacson@asrcenergy.com>;
Mike.Hatten <Mike,Hatten@enstarnaturalgas.com>
Subject: RE: CLUS6 MIT 12-22-2024
Please review and let me know if you have any other errors.
Thanks,
Dennis
Dennis Ackerman and Steve Lawrence
ASPIC Well Site Leader
Nordic 37 Company Man
(907) 885-4867
aicesQo.mpanyman..@asrcene.rgy.com
From: Regg, James B (OGC) <iim.regg alaska.gov>
Sent: Monday, December 23, 2024 4:22 PM
To: ACES Company Man <ACESCompanvMan@asrcenergy.com>
Cc: Brooks, Phoebe L (OGC) <phoebe.brooks @alaska.gov>
Subject: RE: CLUS6 MIT 12-22-2024
tL CAUTION: EXTERNAL SENDER This email originated from outside of the organization. Do not click
links or open attachments unless you recognize the sender and know the content is safe.
Also, the Interval should be "O" (other); we reserve "I" (initial) forthe first test after commencing injection.
Jim Regg
Supervisor, Inspections
AOGCC
333 W. 71h Ave, Suite 100
Anchorage, AK 99501
907-793-1236
From: Regg, James B (OGC)
Sent: Monday, December 23, 2024 4:19 PM
To: ACES Company Man <ACESCompanyMan@asrcenergy.com>
Subject: RE: CLUS6 MIT 12-22-2024
Pretest is the static pressure before you start pressuring up for the test.
Jim Regg
Supervisor, Inspections
AOGCC
333 W. 7" Ave, Suite 100
Anchorage, AK 99501
907-793-1236
From: ACES Company Man <ACESCompanyMan@asrcenergy.com>
Sent: Monday, December 23, 2024 4:04 PM
To: Regg, James B (OGC) <iim.regg@alaska.gov>; ACES Company Man <ACESCompanvMan@asrcenergy.com>
Cc: Mike.Hatten <Mike.Hatten@en starnaturalgas.com>; Isaacson, William <wisaacson@asrcenergy.com>; Brooks,
Phoebe L (OGC) <phoebe.brooks@alaska.gov>
Subject: RE: CLUS6 MIT 12-22-2024
Mr. Regg:
Changed as per your instructions.
I misunderstood what the pretest was as we had tested the 9 5/8 casing previously to 3000 psi. For this
MIT we did not preform a pretest so I left it blank.
Please inform me if this is incorrect.
Dennis Ackerman and Steve Lawrence
ASRC Well Site Leader
Nordic 37 Company Man
(907) 885-4867
aGescPm.panyma n@asrcenergy.com
From: Regg, James B (OGC) <iim.regg@alaska.gov>
Sent: Monday, December 23, 2024 2:52 PM
To: ACES Company Man <ACESCompanvMan@asrcenergV com>
Cc: Mike.Hatten <Mike.Hatten@enstarnaturalgas.com>; Isaacson, William <wisaacson@asrcenergy.com>; Brooks,
Phoebe L (0GC) <phoebe.brooks@alaska.gov>
Subject: RE: CLUS6 MIT 12-22-2024
I CAUTION: EXTERNAL SENDER This email originated from outside of the organization. Do not click
links or open attachments unless you recognize the sender and know the content is safe.
"Type Inj" block should be "N" unless you were injecting at the time of this MIT.
Explain 3000 psi Pretest IA pressure (took 2.4 bbts to decrease from 3000 psi to initial test pressure 1649 psi?)
Move "No Witness" from "AOGCC Rep" to Notes section
Jim Regg
Supervisor, Inspections
AOGCC
333 W. 71h Ave, Suite 100
Anchorage, AK 99501
907-793-1236
From: ACES Company Man <ACESCompanvMan@asrcenergy.com>
Sent: Monday, December 23, 2024 7:16 AM
To: Regg, James B (OGC) <iim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bav@alaska.gov>;
Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; Wallace, Chris D (OGC) <chris.waIlace@alaska.gov>
Cc: Mike.Hatten <Mike.flatten@erlstarnaturalgas.com>; Isaacson, William <wisaacson@asrcenergy.com>; ACES
Company Man <ACESCompanvMan@asrcenergy.com>
Subject: CLUS6 MIT 12-22-2024
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.
Please contact me if you have any questions.
Thanks,
Dennis
Dennis Ackerman and Steve Lawrence
ASRC Well Site Leader
Nordic 37 Company Man
(907) 885-4867
acescorn.Panyrrzan@.asrc..energy .co_m
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
Mechanical Inter yTest
Submit to: 'wirreagglulaska.gov: AOGCC. Insoectorsftalaska.Coy. phoebe brook.0.1iska. GOV
OPERATOR:
FIELD / UNIT / PAD:
DATE:
OPERATOR REP:
AOGCC REP:
Cook Inlet Natural Gas Storage Alaska LLC
CANNERY LOOP/ Stettirlg C Pool / CLUS
1V22/24
Steve Lavrtencel Dennis Ackerman
chris."llace0alaska.aov
�L
Well
CLUBS
Pressures'. Pretest Initial 15 Min. 30 Min, 45 Min. 60 Min.
PTO
2211120
Type Inj
N
Tubing
0 -
0
0
0 -
Type Test
P
Packer TVD
4905
BBL Pump
2.4
IA
0
1849
1638,
11335-
Interval
0
Test psi
15M
BBL Return2.4
OA
0 /
0
1 0
0
Result
P
'
No Withi
Interval Other: The teal for the IA, after initial completion was mn into the liner ere back seal assembly. ✓
Well
Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD
Type Inj
Tubing
Type Test
Packer TVD
BBL Pump
IA
Interval
Test psi
BBL Return
OA
Result
Notes:
Well
Pressures: Pretest Initial 15 Min, 30 Min. 45 Min. 60 Min.
PTD
Type lnj
Tubing
Type Test
Packer TVD
BBL Pump
IA
Interval
Test psi
BBL Return
OA
Result
Nobs:
Well
Pressures: Pretest Initial 15 Min, 30 Min, 45 Min. 60 Min.
PTO
Typa Inj
Tubing
Type Test
Packer TVD
BBL Pump
IA
Interval
Test psi
BBL Return
OA
Result
Notes:
Well
Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min,
PTD
Type Inj
Tubing
Type Test
Packer TVO
BBL Pump
IA
interval
Test psi
BBL Return
OA
Result
Notes:
Well
Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD
Type Inl
Tubing
Type Test
Packer TVD
BBL Pump
IA
Interval
Test psi
BBL Return
OA
Result
Nolen:
Well
Pressures: Pretest Initial 15 All 30 Min. 45 Min. 60 Min.
PTD
Type Inj
Tubing
Type Test
Packer TVD
BBL Pump
IA
Interval
Test psi
BBL Return
OA
Result
Notes:
well
Pressures'. Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD
Typa lnj
Tubing
Type Tesl
Packer TVD
BBL Pump
IA
Interval
Test psi
BBL Return
OA
Result
Notes:
TYPE INJ Cali
W = Wale!
G = Gas
a=slurry
1=lnc steal WastewMer
N = No InloUnp
TYPE TEST Cotles INTERVAL Cures
P=Preaure Test I=Initial Teat
O= Other(EeacnOe In Notes) 4=Four Year Cycle
V = ReTuired by Variance
0 = Other lesson. in ndea)
Result Codes
P=Pass
F=Fall
1= loconclusve
Form 10�126 (Revised 01/2017) MIT ttLS 612-22-24 Revised CA
224-112
T39955
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 Initial Completion
2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number:
Exploratory Development
3.Address:Stratigraphic Service
6.API Number:
7. If perforating:N/A 8. Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool?SIO-09
Yes No
9.Property Designation (Lease Number):10. Field:
Cannery Sterling C Gas Storage Pool N/A
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD):
10402' 5126' 10313' 5118' 1460 psi None None
Casing Collapse
Structural
Conductor n/a
Surface 1950 psi
Intermediate 3090 psi
Production
Liner 5410 psi
Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft):
12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work:
Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service
14.Estimated Date for 15.Well Status after proposed work:
Commencing Operations: OIL WINJ WDSPL Suspended
16.Verbal Approval: Date: GAS WAG GSTOR SPLUG
AOGCC Representative: GINJ Op Shutdown Abandoned
Contact Name:Jake Flora
Contact Email:
Contact Phone: 720-988-5375
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
Subsequent Form Required:
Suspension Expiration Date:
Will perfs require a spacing exception due to property boundaries?
Current Pools:
MPSP (psi): Plugs (MD):
17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval.
Authorized Name and
Digital Signature with Date:
± 7934' MD/4903' TVD, ± 173' MD/173' TVD
Perforation Depth TVD (ft):
AOGCC USE ONLY
7240 psi
Tubing Grade: Tubing MD (ft):
JFLORA@ASRCENERGY.COM
CINGSA Director
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL 391627
224-112
PO Box 190989 Anchorage, AK 99519 50-133-20728
Cook Inlet Natural Gas Storage Alaska, LLC
Length Size
Proposed Pools:
CLUS-6
PRESENT WELL CONDITION SUMMARY
TVD Burst
± 7937'
MD
5750 psi
n/a
3450 psi
158'
2383'
4939'
158'
2866
20"
13-3/8"
137'
9-5/8"8109'
2845'
8130'
planned
7"
planned
Tubing Size:
1/1/2025
± 10400'± 2466'
7"
± 5126'
7" ZXP LTP, WRSSSV
Perforation Depth MD (ft):
26#
m
n
P
2
6
5
6
t
N
Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
Matthew
Federle
Digitally signed by
Matthew Federle
Date: 2024.12.20 14:29:12
-09'00'
By Grace Christianson at 3:33 pm, Dec 20, 2024
324-715
324-715
DSR-12/20/24
Submit 7" CBL to AOGCC and obtain approval before perforating.
X
Statewide Regulations; spacing exception granted by CO No. 818 SFD
CT BOP test to 3000 psi
10-407
-00-00 SFD
SFD 12/26/2024BJM 12/26/24
MEUIRUMOF
Gregory C. Wilson Digitally signed by Gregory C. Wilson
Date: 2024.12.26 14:50:07 -09'00'12/26/24
RBDMS JSB 030425
Cook Inlet Natural Gas Storage Alaska, LLC
3000 Spenard Road
PO Box 190989
Anchorage, AK 99519-0989
Main: 907-334-7980
Fax: 907-334-7671
www.cingsa.com
December 18, 2024
Mrs. Jessie Chmielowski, Commissioner
Mr. Greg Wilson, Commissioner
Alaska Oil and Gas Conservation Commission
333 W 7th Ave., Suite 100
Anchorage, Alaska 99501
RE: Application for Sundry Approval
Cook Inlet Natural Gas Storage Alaska, LLC (CINGSA): CLU Storage 6
PTD: 224-112
Dear Commissioners,
Cook Inlet Natural Gas Alaska, LLC (CINGSA), hereby applies for Sundry Approval to complete the CLU
Storage 6 gas storage injection well, located in Kenai, Alaska.
Please find attached for review of the Commission the 10-403 Form, Completion Procedure, Proposed Well
Schematic, BOPE Diagram, and Nitrogen Operating Procedure.
Fox Coiled Tubing will be used to complete this work, commencing approximately January 1, 2025.
If you have any questions regarding the enclosed application, please contact Jake Flora at (720) 988-5375.
Sincerely,
Mathew Federle
CINGSA Director
y
To: Matt Federle
Director of CINGSA
From: Jake Flora / Doug Cismoski P.E.
ASRC Consulting & Environmental
Well Name:CLU Storage 6 API:50-133-20728-00-00
PTD: 224-112
Status:Drilled & cased wellbore w/ no perforations
Engineer:Jake Flora, (720) 988-5375
Well Summary:
CLU Storage 6 is the second of two new wells drilled in the fall of 2024 to provide additional deliverability from
the CINGSA gas storage facility. The wellbore has a 57 degree sail angle rising to 85 degrees through the Sterling
C Sand target interval(s) and will be perforated with coiled tubing deployed TCP.
Scope:
Use coiledtubing to clean out drilling mud from 7” liner, reverse wellbore dry with nitrogen, and perforateselected
target intervals within the Sterling C Gas Storage Pool. Following perforating the well will be flow tested. If sand
or water are suspected during the flow test, coiled tubing will return to the well to tag and evaluate for water entry.
Well Information:
Max Expected BHP 2224 psi (Based on 0.449 psi/ft gradient @ 4954’TVD)
MPSP: 1729 psi (Based on BHP minus 0.1 psi/ft gas gradient)
Total Depth: 10402’ MD / 5126’ TVD
Plug back depth: ~10313’ MD / 5118’ TVD (Landing Collar)
Minimum ID 4.750” / 173’ SVLN Protection Sleeve / Tubing
Procedure:
1. Provide AOGCC 24hrs notice for BOP test
2. Review all approved COAs
3. MIRU 2” Coiled Tubing
4. RU BOPE, perform BOP test to 3000 psi
5. MU cleanout BHA
6. Using freshwater clean out wellbore to landing collar at ~10313’, flag pipe 50’ off TD
x If PBTD is found high due to cement stringers, RU slickline, pull SVLN Sleeve, PU motor/bit to clean
out to TD, Run SVLN
7. MU Memory CBL logging BHA
8. RIH to flag, log OOH
MU Memory CBL logging BHA
9. MU Memory Halliburton EPX Casing Evaluation Toolstring
10. RIH to flag, log OOH
11. MU Memory GR/CCL/nitrogen sub BHA
12. Conduct Nitrogen safety meeting, review CINGSA Nitrogen SOP
13. RIH to TD, cool down nitrogen pump
14. 5’ above PBTD reverse all fluid from wellbore (~350 bbls to recover)
15. Flag pipe ~100’ above TD, log OOH to above TOL
16. POOH trapping ~1700 psi of nitrogen pressure on wellbore
17. Above closed swab valve, fluid pack coiled tubing with methanol, bleed lubricator dry to slop tank, pop
off
18. Hold TCP perforating safety meeting
19. MU TCP BHA
x Coiled tubing connector, ball drop disco, rupture sub, XO, pressure actuated firing head, (50’) 3-
3/8” 6spf perf guns: BHA OAL = 60’
x Firing head pinned to shear at 4400 psi absolute pressure
20. RIH to flag, correlate to log depth, position top shot, using methanol pressure up coil to ~2600 psi to
perforate, POOH
Gross Planned Perf Interval: ± 8210’ – 10310’ MD / ± 4954’ – 5118’ TVD
x A detailed perforation table will be provided by the geologist
x Perforations will be shot bottom up
x All perforations lie in the Sterling C Gas Storage Pool
21. Shut down coil pump while POOH, bleed coil pressure to 0 psi
x Maintain and monitor open bleed from coiled tubing to slop tank
22. Bleed off lubricator, pop off to confirm guns have fired
23. Repeat steps 17-20 perforating the entire desired footage (Estimated 10 runs)
24. RDMO Coiled Tubing
25. Vent Nitrogen from wellbore
26. Hand well to Operations to flow test through pad test separator
x Permanent flowline will not be installed
x CLUS-6 will be hard-lined to CLUS-05 flowline & choke (CLUS-5 will be SI)
x CLUS-6 will have SSV panel installed at tree with pressure transmitter on CLUS-5 flowline
Gross Planned Perf Interval: ± 8210’ – 10310’ MD / ± 4954’ – 5118’ TVD
Agree. SFD
Venting will stop once elevated LEL levels are measured in the return flow stream. See attached
email from Jake Flora 12
Provide field-quality log images and log
interpretation results to AOGCC as soon as
possible and prior to perforation operations. SFD
MU Memory Halliburton EPX Casing Evaluation Toolstring
Contingency Coiled Tubing Steps: In the event sand is detected during the well test, or additional logging
data is required
1. MIRU 2” Coiled Tubing
2. RU BOPE, perform BOP test to 3000 psi
3. MU cleanout BHA
4. RIH, tag TD, evaluate wellbore for sand entry
5. Log PT survey if water is suspected
6. Perform cleanout or unload well with nitrogen if necessary
7. RDMO Coiled Tubing
Post Perforating & Flow Test:
1. MIRU Slickline, PT lubricator to 2000 psi
2. Pull protection sleeve from hydraulic landing nipple at 173’
3. Set WRSSSV, function test
4. RD Slickline, hand well to Operations
Attachments:
1. Current Wellbore Diagram
2. Proposed Wellbore Diagram
3. Coiled Tubing BOPE Diagram
4. CINGSA Nitrogen SOP
Casing Detail
Size Type Wt Grade ID Top Btm MD / TVD
20"20" Conductor 106.5# J-55 19.000" 0' 158' / 158'
13-3/8" Surface 68# J-55 12.415" 0' 2866' / 2383'
9-5/8" Intermediate 40# L-80 8.998" 0' 8130' / 4939'
7" Tubing 26# L-80 6.276" 0' ~7937' / 4905'
7" Liner 26# L-80 6.276" ~7934' ~10400' / 5126'
Cement Detail
13-3/8"
9-5/8"
7"
Jewelry Detail (planned: tubing & liner have not been run yet)
Item ID Depth
13-3/8"A 5.963" ~173'
B 4.750" ~173'
C Bullet Tieback Seal Assembly, 9.58' 6.180" 7937'
D 7" x 9-5/8" Baker HRD-E ZXP Flex Lock LTP, 11' PBR 6.180" ~7934'
E 7" x 9-5/8" Baker HRD-E ZXP Hanger 6.170" ~7957'
F RN Nipple, No Go, 13cr 5.838" ~7971'
G Baker Landing Collar NA ~10313'
9-5/8"
7"
Last Rev: 12/18/2024
By: Jake Flora
PBTD = ~10313' MD / 5118' TVD
TD = 10402' MD / 5126' TVD
Description
333 bbls 12.0# Class G lead, 78 bbls 15.8# tail, cement to surface
CINGSA
CLU Storage 06
Current Schematic
Hydraulic Landing Nipple, Halliburton RRQ
SVLN Protection Sleeve (to be run w tubing)
384 bbls 12.0# Class G lead, 51 bbls 14# Flexstone tail, TOC ~3016' (12-18-24 CBL)
Displacement pack off occurred 10 bbls from plug bump
planned : 90 bbls 14.0 ppg Class G Flexstone
PTD: 224-112
API: 50-133-20728-00-00
FMC Wellhead: 13-5/8"5k Multibowl
FMC Tree: 7" 5k complete with SSV
Ground Elevation: 33'
KB: 54.4' AMSL
Tubing Minimum ID: 5.963"
Casing Minimum ID: 5.838"
A, B
C, D, E
F
G
9.2 ppg
hi-vis
mud
Casing Detail
Size Type Wt Grade ID Top Btm MD / TVD
20"20" Conductor 106.5# J-55 19.000" 0' 158' / 158'
13-3/8" Surface 68# J-55 12.415" 0' 2866' / 2383'
9-5/8" Intermediate 40# L-80 8.998" 0' 8130' / 4939'
7" Tubing 26# L-80 6.276" 0' ~7937' / 4905'
7" Liner 26# L-80 6.276" ~7934' ~10400' / 5126'
Cement Detail
13-3/8"
9-5/8"
7"
Jewelry Detail (planned: tubing & liner have not been run yet)
Item ID Depth
13-3/8"A 5.963" ~173'
B 3.495"~173'
C Bullet Tieback Seal Assembly, 9.58' 6.180" 7937'
D 7" x 9-5/8" Baker HRD-E ZXP Flex Lock LTP, 11' PBR 6.180" ~7934'
E 7" x 9-5/8" Baker HRD-E ZXP Hanger 6.170" ~7957'
F RN Nipple, No Go, 13cr 5.838" ~7971'
G Baker Landing Collar NA ~10313'
Perforation Detail (PLANNED Gross Interval)
9-5/8"Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date
Sterling C ± 8210' ± 10310' ± 4954' ± 5118' ± 976' PLANNED
7"
Last Rev: 12/18/2024
By: Jake Flora
PBTD = ~10313' MD / 5118' TVD
TD = 10402' MD / 5126' TVD
384 bbls 12.0# Class G lead, 51 bbls 14# Flexstone tail, TOC ~3016' (12-18-24 CBL)
Displacement pack off occurred 10 bbls from plug bump
planned : 90 bbls 14.0 ppg Class G Flexstone
Description
Hydraulic Landing Nipple, Halliburton RRQ
WRSSSV, Halliburton
333 bbls 12.0# Class G lead, 78 bbls 15.8# tail, cement to surface
CINGSA
CLU Storage 06
Proposed Schematic
PTD: 224-112
API: 50-133-20728-00-00
FMC Wellhead: 13-5/8"5k Multibowl
FMC Tree: 7" 5k complete with SSV
Ground Elevation: 33'
KB: 54.4' AMSL
Tubing Minimum ID: 5.963"
Casing Minimum ID: 5.838"
A, B
C, D, E
F
G
CINGSA Storage CLUS-6/7
Well Head Rig Up
1
1
1
1
Hydraulic Stripper over/under 4 1/6" 10K
4 1/16" 15K Lubricator 5X or 6X - 10 ft bowen
connectoin, 50' or 60' total as necessary for tool length
100" Gooseneck
HR680 Injector Head
4 1/16" 10K Flow Cross, 2" 1502 10k Flanged
Valves
ϰϭͬϭϲΗƚŽƉĨůĂŶŐĞ ϭϱŬďŽǁĞŶ
4 1/16" 10K Combi BOPs
Blind/Shear Ram
Pipe/Slip Ram
API Crossover flange to bowen10K to 15K
API Flange Adapter 10K to 5K for riser/wellhead
CINGSA General Safety & Well Procedure
For Nitrogen Operations
Safety/Awareness While Working With Nitrogen & Stop Work Authority
To be reviewed prior to job with all personnel on location.
x Hold Pre-job safety meetings to discuss nitrogen asphyxiation awareness and note areas in
which nitrogen could accumulate and personnel can access.
x Recognize tank location and wind direction. Be aware of weather forecast/changes in wind
direction.
x Make certain ALL work personnel are informed of Stop Work Authority.
Safety Procedure While Working With Nitrogen
1. MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport.
2. Notify Pad Operator of upcoming nitrogen operations.
3. Hold pre-job safety meeting. Review vendor standard operating procedures, safety, and
appropriate Safety Data Sheets for all materials on location.
4. Record risks and mitigations plans. Confirm flow paths and safety barriers are in place.
NITROGEN DISPLACES OXYGEN. Make sure ALL personnel on location are aware of nitrogen
asphyxiation causes and signs and identify emergency muster location.
5. Spot N2 pumping unit and transport. Record N2 volumes in transport.
6. Rig up flow lines from N2 pumping unit to the well and returns to frac tank.
7. Place signs and placards warning of high pressure and nitrogen operations on location where
nitrogen could accumulate or be released.
8. Have pressure gauges downstream of liquid and nitrogen pumps to appropriately measure
tubing and casing pressures.
9. Set pressure gauges upstream and downstream of any check valves.
10. Ensure valve positions are in correct position.
11. Confirm 4-gas detection is on location, calibrated and tested to detect H2S/CO2/LEL/O2 levels
accurately.
12. Pressure test lines upstream of well to approved Sundry pressure or Maximum Potential
Surface Pressure (MSPS) (whichever is greater). Pressure test lines downstream of well at or
greater than MSPS. Visually inspect lines for any leaks.
13. Bleed off pressure and prepare for pumping nitrogen.
14. Pump nitrogen at desired rate, monitor rate and pressure. All nitrogen returns to be routed to
frac tank.
15. Once desired nitrogen levels have been achieved, isolate well from nitrogen pump unit and
bleed down lines between well and nitrogen pump unit.
16. Confirm lines are bled down, be aware of trapped pressure, and any accumulation of nitrogen.
Once confirmed begin rigging down nitrogen pump unit.
17. Note final rates, pressures, and volumes from the job. Record remaining nitrogen in transport.
18. Demob nitrogen pumping unit and transport.
1
McLellan, Bryan J (OGC)
From:Flora, Jacob <JFlora@asrcenergy.com>
Sent:Tuesday, December 24, 2024 12:31 PM
To:McLellan, Bryan J (OGC); Isaacson, William
Cc:Dewhurst, Andrew D (OGC); Roby, David S (OGC)
Subject:RE: CLU S6 (PTD 224-112) 9-5/8" CBL
Attachments:CLU_Storage_6_CBL_18DEC24_CementProcessedLog Reduced.pdf
Hi Bryan,
Please see attached CBL.
I’ll check on the spacing exception and follow up.
Yes, the Nitrogen gets vented to atmosphere until LELs are read with a gas meter. This can be accomplished two
ways:
1) Flowing to the closed top Ʋowback tank through the coil Ʋowback equipment and checking LELs at the
hatch (wind direction is important here)
2) Flowing through the CINGSA pad test separator and venting there until LELs are observed at which
point the well can Ʋow through the separator and on to the plant
We are anticipating using method 2 as it will expedite moving the coil unit the next well.
I owe Andrew a handful of logs and will get those over ASAP as well
Thanks and enjoy your Christmas!
Jake
From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Sent: Tuesday, December 24, 2024 9:13 AM
To: Flora, Jacob <JFlora@asrcenergy.com>
Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>
Subject: CLU S6 (PTD 224-112) 9-5/8" CBL
Jake, A few questions about this procedure.
1. Could you send me the 9-5/8” CBL that was run in this well?
2. There is a CoA on the PTD stating that the well can not be tested or put on regular production until the
spacing exception has been approved. Do you know if that has happened yet?
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.
❚❛❜CAUTION: EXTERNAL SENDER This email originated from outside of the organization. Do not click
links or open attachments unless you recognize the sender and know the content is safe.
2
3. In step 25, CINGSA is planning to vent Nitrogen from wellbore. Are you venting to atmosphere? Since the
well has perfs, how will you know when you are done venting nitrogen and have started venting natural
gas? Please provide a more detailed procedure for this step, including a Ʋow diagram and discussion
about how to know when to stop venting.
Bryan McLellan
Senior Petroleum Engineer
Alaska Oil & Gas Conservation Commission
Bryan.mclellan@alaska.gov
+1 (907) 250-9193
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
BOPE Test Report for:
Reviewed By:
P.I. Suprv
Comm ________CANNERY LOOP UNIT S-6
JBR 01/30/2025
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:1
4-1/2" and 7" TJ used, F/P on meth alarm on floor had to work on wiring to get a different sound than the h2s alarm.
Accumulator bottle pre charge avg 1036 psi
Test Results
TEST DATA
Rig Rep:Kelly/StuckartOperator:Cook Inlet Natural Gas Storage Alaska, LL Operator Rep:LeBlanc/Drury
Rig Owner/Rig No.:Nordic 37 PTD#:2241120 DATE:12/12/2024
Type Operation:DRILL Annular:
250/3000Type Test:BIWKLY
Valves:
250/3000
Rams:
250/3000
Test Pressures:Inspection No:bopKPS241212050951
Inspector Kam StJohn
Inspector
Insp Source
Related Insp No:
INSIDE REEL VALVES:
Quantity P/F
(Valid for Coil Rigs Only)
Remarks:
Test Time 4.5
MASP:
1728
Sundry No:
Control System Response Time (sec)
Time P/F
Housekeeping:P
PTD On Location P
Standing Order Posted P
Well Sign P
Hazard Sec.P
Test Fluid W
Misc NA
Upper Kelly 1 P
Lower Kelly 1 P
Ball Type 1 P
Inside BOP 1 P
FSV Misc 0 NA
12 PNo. Valves
1 PManual Chokes
1 PHydraulic Chokes
0 NACH Misc
Stripper 0 NA
Annular Preventer 1 13-5/8"P
#1 Rams 1 4-1/2" fixed P
#2 Rams 1 7" fixed P
#3 Rams 1 Blinds 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 1 3-1/8"P
Check Valve 0 NA
BOP Misc 1 4" kill demco P
System Pressure P3000
Pressure After Closure P1720
200 PSI Attained P21
Full Pressure Attained P106
Blind Switch Covers:PAll Stations
Bottle precharge P
Nitgn Btls# &psi (avg)P4 @ 2362
ACC Misc NA0
P PTrip Tank
P PPit Level Indicators
P PFlow Indicator
P FPMeth Gas Detector
P PH2S Gas Detector
NA NAMS Misc
Inside Reel Valves 0 NA
Annular Preventer P23
#1 Rams P5
#2 Rams P5
#3 Rams P5
#4 Rams NA0
#5 Rams NA0
#6 Rams NA0
HCR Choke P1
HCR Kill P1
9999
9
99
9
9
9
Meth Gas Detector FP
F/P on meth alarm on floor
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
BOPE Test Report for:
Reviewed By:
P.I. Suprv
Comm ________CANNERY LOOP UNIT S-6
JBR 01/29/2025
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:5
Tested with a 4-1/2" & 9-5/8" Test Joint.
H2S Audible and Visual F/P, LEL Visual F/P. Wiring issue after the rig move.
F/P on Manual Choke, the cone seperated from the shaft inside the choke. Rebuilt and passed.
F/P on HCR Kill, greased and failed retest, rebuilt then had a hydraulic seal failure. Passed retest.
Test Results
TEST DATA
Rig Rep:Woods / BorgenOperator:Cook Inlet Natural Gas Storage Alaska, LL Operator Rep:Ackerman / LeBlanc
Rig Owner/Rig No.:Nordic 37 PTD#:2241120 DATE:11/28/2024
Type Operation:DRILL Annular:
250/3000Type Test:INIT
Valves:
250/3000
Rams:
250/3000
Test Pressures:Inspection No:bopJDH241129134653
Inspector Josh Hunt
Inspector
Insp Source
Related Insp No:
INSIDE REEL VALVES:
Quantity P/F
(Valid for Coil Rigs Only)
Remarks:
Test Time 20
MASP:
1728
Sundry No:
Control System Response Time (sec)
Time P/F
Housekeeping:P
PTD On Location P
Standing Order Posted P
Well Sign P
Hazard Sec.P
Test Fluid W
Misc NA
Upper Kelly 1 P
Lower Kelly 1 P
Ball Type 1 P
Inside BOP 1 P
FSV Misc 0 NA
12 PNo. Valves
1 FPManual Chokes
1 PHydraulic Chokes
0 NACH Misc
Stripper 0 NA
Annular Preventer 1 13-5/8"P
#1 Rams 1 4-1/2"P
#2 Rams 1 9-5/8"P
#3 Rams 1 Blinds 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"FP
Kill Line Valves 2 3-1/8"P
Check Valve 0 NA
BOP Misc 0 NA
System Pressure P2980
Pressure After Closure P1850
200 PSI Attained P36
Full Pressure Attained P105
Blind Switch Covers:PAll Stations
Bottle precharge P
Nitgn Btls# &psi (avg)P4@2100
ACC Misc NA0
P PTrip Tank
P PPit Level Indicators
P PFlow Indicator
FP PMeth Gas Detector
FP FPH2S Gas Detector
0 NAMS Misc
Inside Reel Valves 0 NA
Annular Preventer P23
#1 Rams P6
#2 Rams P6
#3 Rams P6
#4 Rams NA0
#5 Rams NA0
#6 Rams NA0
HCR Choke P2
HCR Kill P2
9999
9
9 9
9
9
99
9
9
9
H2S Audible and Visual F/P, LEL Visual F/P
F/P on Manual Choke
F/P on HCR Kill hydraulic seal failure
FP
FP
FP
FP FP
1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown
Suspend Perforate Other Stimulate Pull Tubing Change Approved Program
Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________
2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number:
Exploratory Development
3.Address:Stratigraphic Service
6. API Number:
7.If perforating:8. Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool?
Yes No
9. Property Designation (Lease Number): 10. Field:
Cannery Loop / Sterling C Storage Pool
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD):
Casing Collapse
Structural
Conductor
Surface
Intermediate
Production
Liner
Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft):
N/A N/A
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:William Isaacson
Contact Email:wisaacson@asrcenergy.com
Contact Phone: 907-339-6455
Authorized Title: CINGSA Director
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
CLU Storage 6N/A
Subsequent Form Required:
Suspension Expiration Date:
Will perfs require a spacing exception due to property boundaries?
Current Pools:
MPSP (psi): Plugs (MD):
17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval.
Authorized Name and
Digital Signature with Date:
Tubing Size:
PRESENT WELL CONDITION SUMMARY
AOGCC USE ONLY
Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft):
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL 391627
224-112
PO Box 190989, Anchorage, AK 99519 50-133-20728-00-00
Cook Inlet Natural Gas Storage Alaska, LLC
Length Size
Proposed Pools:
N/A
TVD Burst
N/A
MD
15815820"137'
Perforation Depth MD (ft):
N/A N/A
15-Nov-24
N/A
approval: Notify AOGCC so that a representative may witness Sundry Number:
BOP TestMechanical Integrity Test Location Clearance
ons of Approval:
ection MIT Req'd? Yes No Subsequent Form Required:
Suspension Expiration Date:
AOGCC USE ONLY
Contact Name:William Isaacson
Contact Email:wisaacson@asrcenergy.com
Contact Phone:907-339-6455
e: CINGSA Director
certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval.
me and
ure with Date:
Date for 15. Well Status after proposed work:
Operations: OILWINJ W DSPL Suspended
proval: Date: GASWAGGSTOR SPLUG
esentative: GINJ Op Shutdown Abandoned
15-Nov-24
nts: Proposal Summary Wellbore schematic13. Well Class after proposed work:
ations Program BOP SketchExploratory Stratigraphic Development Service
SSSV Type: Packers and SSSV MD (ft) and TVD (ft):
N/A N/A
Tubing Size:Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft):
N/A N/A
pth MD (ft):
N/A N/A
quest: Abandon Plug PerforationsFracture Stimulate Repair We Operations shutdownpair Well
Suspend Perforate Other Stimulate Pull Tubing Change Approved Programll Tubing
Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: er Casing ___________________
ame: 4. Current Well Class: 5. Permit to Drill Number:
Exploratory Development
Stratigraphic Service 6.API Number:
g:8. Well Name and Number:
ation or Conservation Order governs well spacing in this pool?
Yes No
esignation (Lease Number): 10. Field:
Cannery Loop / Sterling C Storage Pool
D (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD):
g Collapse
al
or
e
ate
on
CLU Storage 6N/A
quire a spacing exception due to property boundaries?
Current Pools:
() g( )
PRESENT WELL CONDITION SUMMARY
7
224-112
89, Anchorage, AK 99519 50-133-20728-00-00
ural Gas Storage Alaska, LLC
Length Size
Proposed Pools:
TVD BurstMD
15815820"137'
Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
By Grace Christianson at 3:53 pm, Nov 05, 2024
Matthew
Federle
Digitally signed by Matthew
Federle
Date: 2024.11.05 14:37:44
-09'00'
Include with PTD 10-407
All conditions of approval in the original permit still apply.
BJM 11/7/24
DSR-11/6/24SFD 11/6/2024JLC 11/12/2024
Gregory Wilson Digitally signed by Gregory Wilson
Date: 2024.11.12 15:39:43 -09'00'11/12/24
RBDMS JSB 111424
Cook Inlet Natural Gas Storage Alaska, LLC
3000 Spenard Road
PO Box 190989
Anchorage, AK 99519-0989
Main: 907-334-7980
Fax: 907-334-7671
www.cingsa.com
November 2024
Rev. 0
November 5, 2024
Mrs. Jessie Chmielowski, Commissioner
Mr. Greg Wilson, Commissioner
Alaska Oil and Gas Conservation Commission
333 W 7th Ave., Suite 100
Anchorage, Alaska 99501
RE: Request Changes to the Approved Program for FIT Values & Cementing the 9-5/8” Casing
Cook Inlet Natural Gas Storage Alaska, LLC (CINGSA): CLU Storage 6
(PTD: 224-112 / API: 50-133-20728-00-00)
Dear Commissioners,
Cook Inlet Natural Gas Alaska, LLC (CINGSA), hereby requests sundry approval for changes to the
cementing plan for the 9-5/8” casing and the planned Formation Integrity Test (FIT) values on the CLU
Storage 6 well, as approved in the permit to drill.
The proposed plan approved in the permit to drill was to cement the 9-5/8” casing in two stages bringing
cement back to surface. The revised plan is to cement using a single stage job and bring cement back into
the 13-3/8” surface casing, but not bring cement to surface.
The FIT values proposed in the original application for permit to drill were well more than what was needed
for kick tolerance or other operational needs for the well. In addition, learnings from the drilling operations
on CLU Storage 7 have driven the decision to reduce the FIT values at both the surface casing and
intermediate casing shoes.
Please find attached for review of the Commission the 10-403 Form, Revised Drilling & Completion
Procedure highlighting these changes, the 9-5/8” Cement Program and a Proposed Well Schematic.
If you have any questions regarding the enclosed application, please contact William Isaacson at (907) 339-
6455 (office).
Sincerely,
Matthew Federle
CINGSA Director
Sincerely,
p
but not bring cement to surface.
Cook Inlet Natural Gas Storage Alaska, LLC
3000 Spenard Road
PO Box 190989
Anchorage, AK 99519-0989
Main: 907-334-7980
Fax: 907-334-7671
www.cingsa.com
November 2024
Rev. 0
Changes to Approved Permit to Drill
CLUS 6 (Cannery Loop Unit Storage 6)
PTD 224-112 / API 50-133-20728-00-00
Kenai, Alaska
November 2024
Prepared for
Alaska Oil and Gas Conservation Commission
333 W 7th Ave., Suite 100
Anchorage, Alaska 99501
Cook Inlet Natural Gas Storage Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 1 November 2024
Rev. 0
TABLE OF CONTENTS
Page
Table of Contents .......................................................................................................................................... 1
1.0Drilling Hazard Analysis (Kick Tolerance) ..................................................................................... 2
2.09-5/8” Intermediate Cement Program .............................................................................................. 2
3.0Proposed Drilling Program .............................................................................................................. 3
4.0Proposed Wellbore Schematic ......................................................................................................... 4
Cook Inlet Natural Gas Storage Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 2 November 2024
Rev. 0
1.0 Drilling Hazard Analysis (Kick Tolerance)
Below are the newly proposed FIT values and associated kick tolerance calculations.
Kick Tolerance: 12-¼” Hole: 172 bbls with 9.2 ppg mud, a 12.5 ppg FIT at surface shoe
8-½” Hole: Infinite with 9.2 ppg mud, and a 11.5 ppg FIT at intermediate shoe
Note: The above kick tolerance calculations are based upon using 4-1/2” drill pipe in both sections, with a
145’ x 8.25” BHA in the 12.25” hole and 175’ x 6.75” BHA in the 8.5” hole section. They also assume the
same formation depths and pore pressure estimates as provided in the original permit to drill application.
2.0 9-5/8” Intermediate Cement Program
Below is the revised cementing plan for a single stage cement operation, as opposed to a two-stage job, as
well as the basis and calculated volumes for the single stage job.
9-5/8” Intermediate Casing – w/ Shoe at 7994’ MD
PreFlush / Spacer: 50 bbl 10.7 ppg MudPush II
Lead Slurry: Top of slurry: At 2000’ MD, inside surface casing shoe
Extended Class G Cement, 11.8 to 12.0 ppg density
15% excess in open hole + 9-5/8” x 13-3/8” annulus
Yield: 2.41 cu ft/sk
Volume: 347 bbls (808 sx) including excess
Tail Slurry: Top of slurry: 500’ MD above shoe
FlexStone cement, 14.0 ppg density
15% excess in open hole + shoe track
Yield: 1.63 cu ft/sk
Volume: 39 bbls (135 sx) including excess & shoe track
Cook Inlet Natural Gas Storage Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 3 November 2024
Rev. 0
3.0 Proposed Drilling Program
Below is the original Drilling Program Summary as submitted with the application for permit to drill. The areas of
change are highlighted below, with yellow being the original plan and green being the requested change.
CONDUCTOR:
1. Drive/drill 20" conductor to ~140’ below ground (or refusal if earlier). Install 20" 2000# landing ring.
2. Move in and rig up rotary drilling rig.
3. Nipple up 21-¼", 2M diverter, 16" diverter valve, and 16" diverter line.
4. Function test diverter and diverter valve. Notify regulatory agencies 24 hours prior to test.
SURFACE:
1. Directionally Drill a 16" hole to surface hole TD, as per the directional plan.
2. RIH with 13-3/8" casing. Rig up false table and RIH with inner string and sting into stab-in float collar.
3. Cement 13-3/8" casing. Un-sting and circulate drill pipe clean. POH with inner string.
4. Lift riser, install 13-3/8” slips and cut off 13-3/8" casing. ND diverter.
5. Install and test 13-3/8" slip lock connection x 13-5/8" 5M flanged multi-bowl wellhead.
6. Nipple up 13-5/8" 5M BOP'S. Test BOP's and choke manifold to 250psi low / 3000 psi high. Notify
regulatory agencies 24 hours prior to test.
7. Set wear bushing. Make up 12-¼" BHA and RIH to shoe. Pressure test 13-3/8” Casing to 2000 psi.
INTERMEDIATE:
1. Drill out float equipment and make 20' of new hole. CBU.
2. Perform Formation Integrity Test to 14.0 ppg 12.5 ppg EMW.
3. Directional drill 12-¼" hole to intermediate hole TD as per directional program. Exact depth will be
determined by Geologist, with base plan as 25’ MD below Top Sterling C1 plus rat hole.
4. At TD circulate hole clean. Make wiper trip. Circulate hole clean and POH.
5. Run and cement 9-5/8" casing in two stages a single stage. Back out landing joint and set wear bushing.
PRODUCTION:
1. Pick up 8-½" bit and directional BHA. Drill out DV and pressure test casing to 3000 psi. Continue to RIH
and drill float equipment and 20' of new formation. CBU.
2. Perform Formation Integrity Test to 13.0 ppg 11.5 ppg EMW.
3. Directionally drill 8-½" hole to production hole TD as per the directional program. Note: exact TD will be
determined in real time from the top of Sterling C2 pick, targeting a minimum of 15' vertically above the
Beluga Sand formation.
4. At TD circulate hole clean. Make wiper trip as required. Circulate well clean. POH.
5. Rig up e-line unit and Run CBL.
6. Set Test Plug and test 4-½" x 7" variable rams if not done previously with 7" pipe.
7. Pick up 7" liner assembly (~200' Liner Lap) and RIH on drillpipe. Circulate and condition hole. Cement liner
according to program. Set hanger and liner top packer. Circulate casing and drill pipe clean. POH.
COMPLETION:
1. Pick up polish mill and RIH. Test liner, liner lap, and 9-5/8" casing to 3,000 psi for 30 minutes.
2. Polish seal bore extension and displace well to completion brine. POH laying down drill pipe.
3. Pull wear bushing. Pick up 7" seal assembly and RIH on tubing. Stab into Liner hanger polished bore
receptacle. Pressure up back side to 1000 psi confirming stab in.
4. Pick up and space out. Reverse in 8.7 ppg packer fluid. Stab into polished bore receptacle. Land and test
hanger seals and Annulus to 1,500 psi. Test tubing to 3,000 psi.
5. Back out landing joint. Set BPV. ND BOPs.
6. NU adapter assembly and tree. Test to 5,000 psi.
7. Rig down and move out drilling rig.
Note: Perforating will be done post rig with coiled tubing. Separate sundry required for perforating. -bjm
Cook Inlet Natural Gas Storage Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 4 November 2024
Rev. 0
4.0 Proposed Wellbore Schematic
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.govMathew Federle
CINGSA Director
Cook Inlet Natural Gas Storage Alaska, LLC
PO Box 190989
Anchorage, AK, 99519
Re: Cannery Loop, Sterling C Pool, CLU Storage 6
Cook Inlet Natural Gas Storage Alaska, LLC
Permit to Drill Number: 224-112 revised
Surface Location: 717' FNL 1660' FEL SEC 9 T5N R11W
Bottomhole Location: 2592' FNL 1926' FEL SEC 8 T5N R11W
Dear Mr. Federle:
Enclosed is the approved application for the permit to drill the above referenced well.
The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce or inject is
contingent upon issuance of a conservation order approving a spacing exception. The Operator assumes the
liability of any protest to the spacing exception that may occur.
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,
*UHJRU\&:LOVRQ
Commissioner
DATED this th day of October 2024.
Sincerely,
1a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for:
Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates
Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas
2. Operator Name: 5. Bond: Blanket Single Well 11. Well Name and Number:
Bond No.
3. Address: 6. Proposed Depth: 12. Field/Pool(s):
MD: TVD:
4a. Location of Well (Governmental Section): 7. Property Designation:
Surface:
Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date:
Total Depth: 9. Acres in Property: 14. Distance to Nearest Property:
4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 15. Distance to Nearest Well Open
Surface: x- y- Zone- to Same Pool:
16. Deviated wells: Kickoff depth: feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035)
Maximum Hole Angle: degrees Downhole: Surface:
Hole Casing Weight Grade Coupling Length MD TVD MD TVD
19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations)
Junk (measured):
TVD
Hydraulic Fracture planned? Yes No
20. Attachments: Property Plat BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis
Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements
Contact Name:
Contact Email:
Contact Phone:
Date:
Permit to Drill API Number: Permit Approval
Number:Date:
Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales:
Samples req'd: Yes No Mud log req'd: Yes No
H2S measures: Yes No Directional svy req'd: Yes No
Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No
Post initial injection MIT req'd: Yes No
APPROVED BY
Approved by: COMMISSIONER THE COMMISSION Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
21. I hereby certify that the foregoing is true and the procedure approved herein will not be
deviated from without prior written approval.
Surface
Perforation Depth TVD (ft):
GL / BF Elevation above MSL (ft):
Commission Use Only
See cover letter for other
requirements.
Perforation Depth MD (ft):
Authorized Title:
Authorized Signature:
Production
Liner
Intermediate
Effect. Depth MD (ft): Effect. Depth TVD (ft):
Conductor/Structural
LengthCasing
Cement Quantity, c.f. or sacks
Cement Volume MDSize
Plugs (measured):
(including stage data)
18. Casing Program: Top - Setting Depth - BottomSpecifications
Total Depth MD (ft): Total Depth TVD (ft):
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
20 AAC 25.005
Authorized Name:
Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g)
By Grace Christianson at 7:57 am, Oct 03, 2024
See section 17.0 for
variance conditions.
A.Dewhurst 03OCT24
BJM 10/3/24
Diverter waiver approved - see attached email.
DSR-10/3/24JLC 10/7/2024
Gregory Wilson Digitally signed by Gregory Wilson
Date: 2024.10.07 14:06:36 -08'00'10/7/24
09/27/24
RBDMS JSB 100924
Cook Inlet Natural Gas Storage Alaska, LLC
3000 Spenard Road
PO Box 190989
Anchorage, AK 99519-0989
Main: 907-334-7980
Fax: 907-334-7671
www.cingsa.com
August 2024
Rev. 0
August 14, 2024
Mrs. Jessie Chmielowski, Commissioner
Mr. Greg Wilson, Commissioner
Alaska Oil and Gas Conservation Commission
333 W 7th Ave., Suite 100
Anchorage, Alaska 99501
RE: Application for Permit to Drill
Cook Inlet Natural Gas Storage Alaska, LLC (CINGSA): CLU Storage 6
Dear Commissioners,
Cook Inlet Natural Gas Alaska, LLC (CINGSA), hereby applies for a Permit to Drill for the CLU Storage
6 gas storage injection well, located in Kenai, Alaska.
Please find attached for review of the Commission the 10-401 Form, Drilling & Completion Procedures,
Geological Information, Proposed Well Schematics, and Hazard Analysis, as required by 20 AAC 25.005.
Additional information includes MASP Calculations, Rig Layout, BOP & Choke Diagrams, as well as Mud,
Cement, and Directional Programs.
Nordic-Calista Rig 37x will be used to complete this work, commencing approximately October 1, 2024.
If you have any questions regarding the enclosed application, please contact William Isaacson at (907) 339-
6455 (office).
Sincerely,
Mathew Federle
CINGSA Director
Sincerely,
Cook Inlet Natural Gas Storage Alaska, LLC
3000 Spenard Road
PO Box 190989
Anchorage, AK 99519-0989
Main: 907-334-7980
Fax: 907-334-7671
www.cingsa.com
August 2024
Rev. 0
Permit to Drill (10-401)
CLUS 6 (Cannery Loop Unit Storage 6)
Kenai, Alaska
August 2024
Prepared for
Alaska Oil and Gas Conservation Commission
333 W 7th Ave., Suite 100
Anchorage, Alaska 99501
Cook Inlet Natural Gas Storage Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 1 August 2024
Rev. 0
TABLE OF CONTENTS
Page
Table of Contents .......................................................................................................................................... 1
1.0CLU Storage 6 ................................................................................................................................. 3
1.1Well Summary .................................................................................................................. 3
1.2General Well Information ................................................................................................... 3
2.0Location Summary ........................................................................................................................... 3
2.1Well Trajectory & Proximity Risk ...................................................................................... 4
3.0Diverter System Information ........................................................................................................... 4
4.0Blowout Prevention Equipment Information ................................................................................... 4
5.0Drilling Hazard Analysis ................................................................................................................. 5
6.0Geologic Summary & Abnormal Pressure Formations ................................................................... 5
7.0Formation Integrity Test Procedure ................................................................................................. 6
8.0Casing & Cement Program .............................................................................................................. 7
9.0Drilling Fluid Program & Fluid System .......................................................................................... 8
10.0Evidence of Bonding........................................................................................................................ 8
11.0Proposed Drilling Program .............................................................................................................. 9
12.0Proposed Wellbore Schematic ....................................................................................................... 10
13.0Bottom Hole Assemblies & Well Trajectory ................................................................................. 11
14.0Drilling Waste Storage ................................................................................................................... 11
15.0Logging Plan .................................................................................................................................. 11
16.0Mud Logging Plan ......................................................................................................................... 12
17.0Regulatory Waivers and Special Procedures Requests .................................................................. 12
List of Tables
Table 2.0-1. Well Location Details ............................................................................................................... 3
Table 6.0-1. Geologic Formation Tops ......................................................................................................... 6
Table 9.0-1. Mud Program Detail - Surface Hole ......................................................................................... 8
Table 9.0-2. Mud Program Detail - Intermediate Hole ................................................................................. 8
Table 9.0-3. Mud Program Detail - Production Hole .................................................................................... 8
Cook Inlet Natural Gas Storage Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 3 August 2024
Rev. 0
1.0 CLU Storage 6
Requirements of 20 AAC 25.005(f)
1.1 Well Summary
Cook Inlet Natural Gas Storage Alaska LLC’s (“CINGSA”) is planning to drill two additional wells at the
underground natural gas storage facility in the City of Kenai, Alaska. The wells will be Cannery Loop Unit
Storage 6 and 7 (CLUS 6 & CLUS 7). The CLU Storage 6 well is planned as the second of the two (2)
wells. Drilling on CLUS 7 is slated to begin September 1, 2024 and the time required to drill and complete
each well is estimated at approximately 35 days (70 days total). CLUS 6 will begin in early October.
The overall objective of the program is to drill two (2) new gas storage wells into the Sterling C Sand Pool
in 2H of 2024. These wells will be in addition to the five (5) existing gas storage wells drilled from the pad
in 2011 – 2012 and will add to the ability of CINGSA to manage the varying gas demand in south central
Alaska. The two new wells will have a casing and completion design similar to the existing wells.
1.2 General Well Information
Reservoir Pressure / TVD: 2219 psi (7969’ MD / 4910’ TVD @ 0.452 psi/ft maximum)
MASP: 1728 psi (4910’ TVD with 0.10 psi/ft gas gradient to surface)
Wellhead Type/Pressure Rating: FMC – 3M x 5M psi - Wellhead Assembly
BOP Configuration: 13-5/8” 5M - Annular/Pipe Rams/Pipe Rams/Blind/Choke & Kill Line
Well Type: Service Well
Estimated Start Date: October 1, 2024
2.0 Location Summary
Requirements of 20 AAC 25.005(c)(2)
General Location Kenai, Alaska
Ground Elevation 33.0’ above MSL
KB Elevation 21.1’ above Ground Elevation
RKB 54.1’ above MSL
Table 2.0-1. Well Location Details
Date X-Coordinate Y-Coordinate FNL/FSL FEL/FWL Sec / T / R
Surface Location 281945.470 2392833.240 717’ / 4563’ 1660’ / 3620’ Sec 9/T5N/R11W UM
Top of Production Zone 276430.450 2392921.290 730’ / 4550’ 1904’ / 3376’ Sec 8/T5N/R11W UM
Bottom Hole Location 274949.660 2391087.200 2592’ / 2688’ 3354’ / 1926’ Sec 8/T5N/R11W UM
See Attachment 1: Cannery Loop Gas Storage Lease Map
See Attachment 2: As-Built Pad Design
Cook Inlet Natural Gas Storage Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 4 August 2024
Rev. 0
2.1 Well Trajectory & Proximity Risk
Requirements of 20 AAC 25.005(c)(2) & (d)
At surface, the nearest wells to the planned CLUS 6 wellbore are the existing CINGSA wells on the pad,
with the planned CLUS 7 being the closest at approximately 50 ft directly east. The surface hole will be
closely monitored for verticality and will kick-off at 300 ft and build to the west of CLUS 7, therefore
mitigating any shallow anti-collision concerns with this well. As the CLUS 6 well profile builds to the west
it passes between the existing CLUS 2 & 3 wells at a depth range of 1300 – 1700’ MD, where they have
begun to diverge from each other and opening a window for CLUS 6 to pass. The well path of CLUS 6
will need to stay close to plan and MWD readings monitored closely for magnetic interference as the well
passes CLUS 2 & 3. The only wells which fall within 200’ of any portion of the planned CLUS 6 wellbore
are the existing CINGSA wells at surface and with the subsurface close approach as outlined above. These
wells and all wells in the area were scanned and pass SLB major risk anti-collision rules.
See Attachment 3: Directional Program
3.0 Diverter System Information
Requirements of 20 AAC 25.005 (c)(7)
The diverter system has a working pressure of 2000 psi and a 16” diverter vent line.
See Attachment 4: Diverter Schematic
4.0 Blowout Prevention Equipment Information
Requirements of 20 AAC 25.005(c)(3)
BOP Configuration: 13-5/8” 5M BOPE - Annular/Pipe Rams/Pipe Rams/Blind/Choke & Kill Line
The BOP system of Nordic-Calista Rig 37x is rated at 5,000 psi working pressure, however, the wellhead
rated working pressure is 3000 psi on the lower flange and 5000 psi after the intermediate casing is installed.
The calculated maximum anticipated surface pressure in this well is 1728 psi, therefore the initial and all
subsequent BOP tests will test all equipment to 3000 psi, except the annular BOP which will be tested to
50% of its rated working pressure (~2500 psi). The stack is designed to comply with requirements for an
operation of 3000 psi or less, however an additional set of pipe rams will be installed to allow the inclusion
of the required casing rams for the operation. The BOPE will be tested every 14 days per 20 ACC 25.035.
See Attachment 5: BOPE Schematic
See Attachment 6: Choke Manifold Schematic
See Attachment 7: Wellhead / Tree Schematic
p,
The surface hole will bepgppyy
closely monitored for verticality and will kick-off at 300 ft and build to the west of CLUS 7, thereforeyy
mitigating any shallow anti-collision concerns with this well.
Diverter waiver was requested by email (attached) as an amendment to this PTD application. Diverter waiver approved. -bjm
Cook Inlet Natural Gas Storage Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 5 August 2024
Rev. 0
5.0 Drilling Hazard Analysis
Requirements of 20 AAC 25.005(c)(4)
Maximum Down Hole Pressure: = (0.052)*(8.69)*(4910’ TVD)
= 2219 psi
Maximum Anticipated Surface Pressure: = (2219) - (0.1 psi/ft * 4910’ TVD)
MASP: = 1728 psi
Kick Tolerance: 12-¼” Hole: 281 bbls with 9.2 ppg mud, a 14.0 ppg FIT at surface shoe
8-½” Hole: Infinite with 9.2 ppg mud, and a 13.0 ppg FIT at intermediate shoe
Abnormal Pressure: Abnormally pressured hazards are not anticipated in the drilling of CLUS
6 & 7 as based upon the historical drilling of other wells in the area and on
the CINGSA pad. See Geologic Prognosis for additional information.
Potential Oil & Gas Zones: No oil sands are expected to be encountered and the first potential gas zone
is the Sterling A at 3955’ TVDss. The potential for gas continues through
the Sterling B and will be encountered in the targeted Sterling C. The
Sterling A & B have a most likely pore pressure of a fresh water gradient
and the Sterling C may be slightly sub-normal with the potential for
isolated sand packages at original normal pressure gradient. Monitoring
the well for proper hole fill and indications of swabbing will be key.
Hydrogen Sulfide: H2S containing strata are not targeted in this well.
Potential Hole Problems: Surface: Minor Gravel Sloughing, Tight hole and Stuck Pipe.
Intermediate: Lost Circulation, Differential Sticking, Tight Hole & Stuck
Pipe due to Coals, and Directional Difficulties due to soft formations.
6.0 Geologic Summary & Abnormal Pressure Formations
Requirements of 20 AAC 25.005 (c)(9) & 20 AAC 25.071
The CINGSA gas storage reservoir interval is the Cannery Loop Sterling C Gas Pool, which is vertically
defined as the formations comprising the C1 and C2 sands. The pool is bound above by the B5 coal at the
base of the Sterling B sands and below by the Upper Beluga formation. The gross reservoir thickness
averages ~200’ across the pool area, and average net sand thickness is ~95’. The interval is comprised of
fluvial channel sandstones with interbedded silty sands and shales folded in a structural 4-way dip closure
and the original gas accumulation was charged by biogenic methane. The overlying Sterling A & B sands
are transient sands never tested and may contain gas.
Oil sands have not been encountered in the area across the targeted interval and are not expected in the
drilling of CLUS 6 & 7. Additionally, no abnormal gradients are expected. The original pressures within
the interval from surface through the Sterling Sands existed at a normal gradient. The initial 5 wells all
successfully drilled the overburden at mud weights in the 9.0-9.4 ppg range, and the Sterling C Pool was
significantly depleted at that time. The Sterling C is expected to be in the ~1950 psi (7.5 ppg) range at the
time of drilling CLUS 6 & 7, with the potential for isolated sand packages at original pressure.
Cook Inlet Natural Gas Storage Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 6 August 2024
Rev. 0
Table 6.0-1. Geologic Formation Tops
7.0 Formation Integrity Test Procedure
Requirements of 20 AAC 25.005 (c)(5)
Surface casing shoe will be tested to a pre-determined equivalent mud weight. Prior to drilling out of casing
strings, test BOPs to the specified pressure listed in the BOP Program section, and casing to pressure listed
in Proposed Drilling Program section. Plot test and record volume required on the drilling report.
Formation Integrity tests (FIT) are to be conducted as described below:
•Drill 20' to 25' of new formation below the casing shoe and condition the mud to the same properties in and out
• Pull drill bit into the casing shoe and close pipe ram preventer. Line up to choke manifold with a closed choke
•Begin pumping fluid down the drill string at ½ bpm while recording casing & drill pipe pressures at ½ bbl intervals
•The Drill Site Manager will keep a running plot of pressure versus volume while the test is in progress
•Plot volume and pressure until the appropriate surface pressure is achieved for the FIT at the shoe.
•Shut down at the required surface pressure. Monitor and plot pressure drop and time after shut-in for a minimum
of 10 minutes or until the shut-in pressure stabilizes
•Bleed the pressure off and record the fluid volume recovered.
The pre-determined surface pressure for each formation integrity test is based on achieving an EMW at
least 1.0 ppg higher than the EMW’s estimated for all planned cementing operations, and to allow for an
appropriate amount of kick tolerance in case well control measures are required.
Cook Inlet Natural Gas Storage Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 7 August 2024
Rev. 0
8.0 Casing & Cement Program
Requirements of 20 AAC 25.005 (c)(6)
See Attachment 8: Casing Design Program
13-3/8” Surface Casing w/ Shoe at 2879’ MD
PreFlush / Spacer: 80 bbl 10.5 ppg MudPush II
Lead Slurry: Top of slurry: Surface
Extended Class G Cement, 12.0 ppg density
75% excess in open hole + excess to surface for stab-in job
Yield: 2.41 cu ft/sk
Volume: 318 bbls (741 sx) including excess
Tail Slurry: Top of slurry: 500’ MD above shoe
Class G Cement, 15.8 ppg density
75% excess in open hole + 80’ shoe track
Yield: 1.16 cu ft/sk
Volume: 78 bbls (378 sx) including excess & Shoe track
9-5/8” Intermediate Casing – 1st Stage w/ Shoe at 7994’ MD
PreFlush / Spacer: 50 bbl 10.7 ppg MudPush II
Lead Slurry: Top of slurry: At Stage Tool at 3500’ MD
Extended Class G Cement, 12.0 ppg density
15% excess in open hole + 100’ MD above stage collar
Yield: 2.41 cu ft/sk
Volume: 250 bbls (583 sx) including excess
Tail Slurry: Top of slurry: 700’ MD above shoe
FlexStone cement, 14.0 ppg density
15% excess in open hole + shoe track
Yield: 1.63 cu ft/sk
Volume: 51 bbls (176 sx) including excess & shoe track
9-5/8” Intermediate Casing – 2nd Stage w/ Stage Collar at ~3500’ MD
PreFlush / Spacer: 45 bbl 10.5 ppg MudPush II
Lead Slurry: Top of slurry: Surface
Extended Class G Cement, 12.0 ppg density
15% excess in open hole + cased hole + 40 bbls excess to surface
Yield: 2.41 cu ft/sk
Volume: 252 bbls (587 sx) including excess
7” Production Liner w/ Shoe at 10,384’ MD and Liner Top at 7794’ MD
PreFlush / Spacer: 35 bbl 11.0 ppg MudPush II
Tail Slurry: Top of slurry: At 7” Liner Top
FlexStone cement, 14.0 ppg density
10% excess in open hole + liner lap + 200’ DP x Casing annulus + shoe track
Yield: 1.63 cu ft/sk
Volume: 77 bbls (265 sx) including excess & shoe track
Verified cement calcs -bjm
Cook Inlet Natural Gas Storage Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 2 August 2024
Rev. 0
Table 9.0-4. Fluid System Equipment .......................................................................................................... 8
Table 13.0-1. BHA Program ....................................................................................................................... 11
Table 15.0-1. Logging Program – 16” Surface Hole .................................................................................. 11
Table 15.0-2. Logging Program – 12-¼” Intermediate Hole ...................................................................... 12
Table 15.0-3. Logging Program – 8-½” Production Hole ........................................................................... 12
List of Figures
Figure 12.0-1. Proposed Wellbore Schematic ............................................................................................ 10
List of Attachments
Attachment 1 – Cannery Loop Gas Storage Lease Map
Attachment 2 – As-Built Pad Design
Attachment 3 – Directional Program
Attachment 4 – Diverter Schematic
Attachment 5 – BOPE Schematic
Attachment 6 – Choke Manifold Schematic
Attachment 7 – Wellhead / Tree Schematic
Attachment 8 – Casing Design Program
Attachment 9 – Rig Equipment, Layout & Fluids System
Cook Inlet Natural Gas Storage Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 8 August 2024
Rev. 0
9.0 Drilling Fluid Program & Fluid System
Requirements of 20 AAC 25.005 (c)(8)
See Attachment 9: Rig Equipment, Layout & Fluids System
Table 9.0-1. Mud Program Detail - Surface Hole
Interval Mud System Mud Wt
(ppg) PV YP
(lb/100ft2) Fluid Loss Funnel Vis pH Drill Solids
(%)
16” Gel Spud Mud 8.8-9.4 15-24 >30 <18 70-150 8.0-9.0 <6
Table 9.0-2. Mud Program Detail - Intermediate Hole
Interval Mud System Mud Wt
(ppg)
PV
(cP)
YP
(lb/100ft2) Fluid Loss Funnel Vis pH Drill Solids
(%)
12-¼”KLASHIELD 9.0-9.4 10-16 16-22 5-7 30-50 9.5-10.0 <6
Table 9.0-3. Mud Program Detail - Production Hole
Interval Mud System Mud Wt
(ppg)
PV
(cP)
YP
(lb/100ft2) Fluid Loss Funnel Vis pH Drill Solids
(%)
8-½”KLASHIELD 9.0-9.4 10-16 16-20 4-6 40-50 9.5-10.0 <6
Table 9.0-4. Fluid System Equipment
Item Equipment Specification
Shakers 3 Derrick Hyperpool shakers
Centrifuge Brandt HS-1960 Fully Variable Speed (external unit)
Mud Pit Capacity 920 bbls with 830 bbls usable & 23 bbl trip tank
10.0 Evidence of Bonding
Requirements of 20 AAC 25.005 (c)(12)
Bond Number 105639794
Cook Inlet Natural Gas Storage Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 9 August 2024
Rev. 0
11.0 Proposed Drilling Program
Requirements of 20 AAC 25.005 (c)(13)
CONDUCTOR:
1. Drive/drill 20" conductor to ~140’ below ground (or refusal if earlier). Install 20" 2000# landing ring.
2. Move in and rig up rotary drilling rig.
3. Nipple up 21-¼", 2M diverter, 16" diverter valve, and 16" diverter line.
4.Function test diverter and diverter valve. Notify regulatory agencies 24 hours prior to test.
SURFACE:
1. Directionally Drill a 16" hole to surface hole TD, as per the directional plan.
2. RIH with 13-3/8" casing. Rig up false table and RIH with inner string and sting into stab-in float collar.
3. Cement 13-3/8" casing. Un-sting and circulate drill pipe clean. POH with inner string.
4. Lift riser, install 13-3/8” slips and cut off 13-3/8" casing. ND diverter.
5. Install and test 13-3/8" slip lock connection x 13-5/8" 5M flanged multi-bowl wellhead.
6. Nipple up 13-5/8" 5M BOP'S. Test BOP's and choke manifold to 250psi low / 3000 psi high. Notify
regulatory agencies 24 hours prior to test.
7. Set wear bushing. Make up 12-¼" BHA and RIH to shoe. Pressure test 13-3/8” Casing to 2000 psi.
INTERMEDIATE:
1. Drill out float equipment and make 20' of new hole. CBU.
2. Perform Formation Integrity Test to 14.0 ppg EMW.
3. Directional drill 12-¼" hole to intermediate hole TD as per directional program. Exact depth will be
determined by Geologist, with base plan as 25’ MD below Top Sterling C1 plus rat hole.
4. At TD circulate hole clean. Make wiper trip. Circulate hole clean and POH.
5. Run and cement 9-5/8" casing in two stages. Back out landing joint and set wear bushing.
PRODUCTION:
1. Pick up 8-½" bit and directional BHA. Drill out DV and pressure test casing to 3000 psi. Continue to RIH
and drill float equipment and 20' of new formation. CBU.
2. Perform Formation Integrity Test to 13.0 ppg EMW.
3. Directionally drill 8-½" hole to production hole TD as per the directional program. Note: exact TD will be
determined in real time from the top of Sterling C2 pick, targeting a minimum of 15' vertically above the
Beluga Sand formation.
4. At TD circulate hole clean. Make wiper trip as required. Circulate well clean. POH.
5. Rig up e-line unit and Run CBL.
6. Set Test Plug and test 4-½" x 7" variable rams if not done previously with 7" pipe.
7. Pick up 7" liner assembly (~200' Liner Lap) and RIH on drillpipe. Circulate and condition hole. Cement liner
according to program. Set hanger and liner top packer. Circulate casing and drill pipe clean. POH.
COMPLETION:
1. Pick up polish mill and RIH. Test liner, liner lap, and 9-5/8" casing to 3,000 psi for 30 minutes.
2. Polish seal bore extension and displace well to completion brine. POH laying down drill pipe.
3. Pull wear bushing. Pick up 7" seal assembly and RIH on tubing. Stab into Liner hanger polished bore
receptacle. Pressure up back side to 1000 psi confirming stab in.
4. Pick up and space out. Reverse in 8.7 ppg packer fluid. Stab into polished bore receptacle. Land and test
hanger seals and Annulus to 1,500 psi. Test tubing to 3,000 psi.
5. Back out landing joint. Set BPV. ND BOPs.
6. NU adapter assembly and tree. Test to 5,000 psi.
7. Rig down and move out drilling rig.
Note: Perforating will be done post rig with coiled tubing.
Perforating is not authorized with this PTD. Separate sundry required for perforating. -bjm
Note: Perforating will be done post rig with coiled tubingt
Diverter waiver was requested by email (attached) as an amendment to this PTD application. Diverter waiver approved.
-bjm
Cook Inlet Natural Gas Storage Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 10 August 2024
Rev. 0
12.0 Proposed Wellbore Schematic
Figure 12.0-1. Proposed Wellbore Schematic
Cook Inlet Natural Gas Storage Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 11 August 2024
Rev. 0
13.0 Bottom Hole Assemblies & Well Trajectory
Table 13.0-1. BHA Program
16” Surface BHA 12-¼” Drilling BHA 8-½” Drilling BHA
Mill Tooth Bit
Motor
TeleScope (GR/MWD)
NMDC
HWDP
Jar
HWDP
Drillpipe
PDC Bit
RSS
arcVISION (GR/Res)
TeleScope (MWD)
NMDC
HWDP
Jar
HWDP
Drillpipe
PDC Bit
RSS
arcVISION (GR/Res)
TeleScope (MWD)
ADN (Den/Neu)
NMDC
HWDP
Jar
HWDP
Drillpipe
14.0 Drilling Waste Storage
Requirements of 20 AAC 25.005 (c)(14)
Drilling wastes will be either granular solids (cuttings), or liquids (drilling mud or water). Cuttings and
fluids will be disposed of in either:
Hilcorp Alaska’s Kenai Grind & Inject Facility or Alaska Eco Resources Nikiski Monofill Cell Facility
Cuttings vac boxes or totes will be used to deliver cuttings and entrained fluids to the G&I or Monofill
facility, while Vac trucks will transport bulk fluids. Disposal will be per the agreement between CINGSA
and Hilcorp and/or Alaska Eco Resources. Every load will be manifested prior to leaving location in
accordance with CINGSA and receiving facility manifest requirements.
CINGSA will not request authorization under 20 AAC 25.080 for an Annular Disposal Operation.
15.0 Logging Plan
Requirements of 20 AAC 25.071 (a)
Table 15.0-1. Logging Program – 16” Surface Hole
Type BHA Details
Drilling GR
Open Hole None
Cased Hole None
Cook Inlet Natural Gas Storage Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 12 August 2024
Rev. 0
Table 15.0-2. Logging Program – 12-¼” Intermediate Hole
Type BHA Details
Drilling GR/Resistivity
Open Hole None
Cased Hole CBL
Table 15.0-3. Logging Program – 8-½” Production Hole
Type BHA Details
Drilling GR/Resistivity/Neutron/Density
Open Hole None
Cased Hole None
16.0 Mud Logging Plan
A four-man mud logging crew (2 mud loggers & 2 sample catchers) will be on location, rigged up, and
logging from below the surface casing shoe through TD of the production hole section.
x Gas chromatography
x Dry cuttings samples (30’ intervals)
x Wet cuttings samples (30’ intervals)
17.0 Regulatory Waivers and Special Procedures Requests
(1) AOGCC 20 AAC 25.412 (b)… The packer must be placed within 200 feet measured depth above
the top of the perforations, unless the commission approves a different placement depth as the
commission considers appropriate given the thickness and depth of the confining zone.
CINGSA requests to increase the distance between the packer and top perforations to 500' MD for this
well. The 9-5/8” intermediate casing string will be cemented into the top of the Sterling C, however,
the expected top perforations may be 200 to 300’ MD below the 9 5/8" shoe. The exact location will
not be known until the logs are processed. The liner lap is designed to be 200' MD to provide optimal
liner lap isolation with cement. The packer is planned as a BakerHughes ZXP liner top packer.
CINGSA believes the primary isolation of injection to the reservoir is the ~500-700' of high
compressive strength premium cement used for the tail slurry of the 9 5/8" cement job. Secondary
protection is the cemented 7" liner with calculated top of cement above the liner top. Tertiary protection
is then provided by the liner top packer.
Variance to 20 AAC 25.412(b) approved to allow liner-top packer to be set no more than 250' MD above the 9-5/8" casing shoe
and packer must be set within the confining zone above the Sterling C injection interval. -bjm
Mudlogging not required, but if acquired, a set of samples must be provided to the
AOGCC as per 20 AAC 25.071 (b)(2). -A.Dewhurst 18SEP24
Cook Inlet Natural Gas Storage Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 13 July 2024
Rev. 0
Attachment 1 – Cannery Loop Gas Storage Lease Map
Borehole: Well: Field: Structure:CLU S-6 wp08 Plan: CLU S-6 Alaska - Kenai Unit Cannery Loop UnitGravity & Magnetic Parameters Surface Location NAD27 Alaska State Plane, Zone 04, US Feet MiscellaneousModel: BGGM 2024 Dip: 73.427° Date: 01-Sep-2024MagDec: 13.978° FS: 55064.992nT Gravity FS: 1001.319mgn (9.80665 Based)Lat: N 60 32 39.03 Northing:2392833.24ftUSGrid Conv: -1.0546°Lon: W 151 12 40.18 Easting: 281945.47ftUS Scale Fact: 0.99995411Slot: CLU S-6 TVD Ref: Rotary Table(54.08ft above MSL)Plan: CLU S-6 wp08-12000-11000-10000-9000-8000-7000-6000-5000-4000-3000-2000-10000100020003000-6000-5000-4000-3000-2000-100001000200030004000-12000-11000-10000-9000-8000-7000-6000-5000-4000-3000-2000-10000100020003000-6000-5000-4000-3000-2000-100001000200030004000EW (ft) Scale = 1:2000.00(ft)NS (ft) Scale = 1:2000.00(ft)13-08CLU S-6 wp080TVD1000TVD2000TVD3000TVD4000TVD5000TVD5123TVDCLU-59 9 9 T V D1999TVD2999TVD3999TVD4999TVD5999TVD
6 9 9 9 T V D
7999TVD8999TVD9999TVD10242TVDCLU S-51 T V D
1001T V D
2001T V D
3001T V D
4001TV D
5001TVD512 7 T V DCLU-81 3 T V D1013TVD
2 0 1 3 T V D
3 0 1 3 T V D
4 0 1 3 TV D
5 0 1 3 T V D6013TVD
7013 TVD7953TVD
CLU-11011TVD2011TVD3011TVD4011TVD5011TVD6011TVD7011TVD8011TVD
9 0 1 1 T V D
1 0 0 1 1 T V D10226TVD CLU-6RD-4TVD9 9 6T V D
1 9 9 6 T V D
2 9 9 6 T V D
3 9 9 6 T V D
4 4 7 3 T V D CLU-1416TVD1 01 6 T V D
2 0 16 T V D
3 016 T V D
4 0 16 T V D5016TVD6016TVD7016TVD8016TVD8059TVDCLU-151 TVD1001 TVD2001TVD3001TVD4001TVD5001TVD6001TVD7001TVD7960TVDCLU-5RD16TVD1 0 1 6 T V D2016TVD3016TVD4016TVD5016TVD6016TVD7016TVD8016TVD9016TVD10016TVD11016TVD
1 1 2 6 9 T V D
CLU-1314TVD1 0 1 4 T V D2014TVD
3 0 1 4 T V D
4 0 1 4 T V D
5 0 14 T V D
6 0 1 4 T V D7014TVD8014TVD8745TVDCLU-419 TVD1019TVD2019TV D
3 0 1 9 T V D
4 0 1 9 T V D
5 0 1 9 T V D
6 0 1 9 T V D
7 0 19 T V D
8 0 1 9 T V D
9 0 1 9 T V D
100 19T V D
11019TV D
12019TVD 13019 TVD14019TVD15019TVD15979TVDCLU-319TVD1019TVD2019TVD3019TVD4019TVD5019TVD6019TVD7019TVD8019TVD9019TVD10019TVD10571TVDCLU-1013TVD1013TVD2013TVD3013TVD4013TVD5013TVD6 0 1 3 T V D7013TVD
8013 TVD8015TVDCLU-11-2TVD998TV D
1998TV D
2998TV D
3998TVD
4 998TV D
5 9 9 8 T V D
6998TVD7913TVDCLU-1RDPB113TVD1013TVD2013TVD3013TVD4013TVD5013TVD6013TVD7013TVD8013TVD8695TVD
CLU S-44TVD1 0 0 4 T V D
2 0 0 4 T V D
3 0 0 4 T V D
4 0 0 4 T V D
5 0 0 4 T V D
5 1 1 6 T V DCLU S-11TVD1001TV D2 0 0 1 T V D
3 0 0 1 T V D
4 0 0 1 T V D
5001TVD5165TVDCLU-1616TVD1016TVD2016TVD3016TVD4016 TVD5016TVD6016TVD7016TVD7689TVDCLU-1RD13TVD1013TVD2013TVD3013TVD4013TVD5013TVD6013TVD7013TVD
8 0 13 T V D8651TVD
CLU-71 2 T V D1012TVD2012TVD3012TVD4012TVD5012TVD6012TVD7012TVD8004TVD13-083 TVD1003 TVD2003 TVD3003 TVD4003 TVD5003 TVD5509 TVDCLU-12 -1 4 T V D
9 8 6 T V D
1 9 8 6 T V D
2 9 8 6 T V D
3 9 8 6 T V D
4 9 8 6 T V D
5 98 6 T V D
6986TVD7986TVD8070TVDCLU S-2-1TVD9 99TV D
1 9 9 9 T V D
2 9 9 9 T V D
3 9 9 9 T V D
49 9 9 T V D
510 9 T V DCLU S-7 wp16.10TVD1000TVD2000TVD3 0 0 0 T V D
3405 TVD
4000TVD4360TVD5000TVD5104TVD5104TVDCLU-912TVD1012 TVD
201 2 T V D
3 012 TVD
4 0 12 TVD
5012 TVD6012TVD7012TVD
8 0 1 2T V D
8 0 53T V DCLU S-31 TVD1001TV D
2 0 0 1 T V D
3 0 0 1 T V D
4 0 0 1 T V D
5001TVD5108TVDCLU-6-9TVD9 9 1 T V D1991TVD2991TVD3991TVD4991TVD5270TVDCLU-5RD216TVD1 0 1 6 T V D2016TVD3016TVD4016TVD5016TVD6016TVD7016TVD8016TVD8439TVDCLU-10RD17TVD1017TVD2017TVD3017TVD40 1 7 T VD5017TVD6017TVD7017TVD7856TVD
GridTrueMag
TRACT E
KN 2005-122
CITY OF KENAI
TRACT F1
KN 2014-20
STATE OF ALASKA BRIDGE
ACCESS
ROAD
S4 S3
S9 S10
SECTION 4 T5N R11W
SECTION 9 T5N R11W
SECTION 9 T5N R11WSECTION 10 T5N R11WSECTION LINE
NOT TO SCALE
B
E
A
V
E
R
L
O
O
P
R
O
A
D
CLU S-1
CLU S-2
CLU S-3
CLU S-4
CLU S-5
SECTION CORNER
NAD83
N:2393280.90'
E:1423637.27'
NAD27
N:2393518.79'
E:283617.10'
CINGSA
DRILL PAD
CLU S-6 CLU S-7 SECTION LINENOT TO SCALEREVISION:
DATE:
DRAWN BY:
SCALE:
PROJECT NO.
BOOK NO.
SHEET
OF
ENGINEERING / MAPPING / SURVEYING / TESTING
P.O. BOX 468 SOLDOTNA, AK. 99669
VOICE: (907) 283-4218 FAX: (907) 283-3265
PROJECT
LOCATION SECTION 9, T5N, R11W,
SEWARD MERIDIAN, ALASKA
1
7/3/2024
BGB
1"=150'
243002
24-04
1 2
CINGSA
CLU S-6 & CLU S-7 WELLS AS-BUILT
SURFACE LOCATION DIAGRAM
717'
FNL
1660'
FEL
1610'
FEL
716'
FNL
REVISION:
DATE:
DRAWN BY:
SCALE:
PROJECT NO.
BOOK NO.
SHEET
OF
ENGINEERING / MAPPING / SURVEYING / TESTING
P.O. BOX 468 SOLDOTNA, AK. 99669
VOICE: (907) 283-4218 FAX: (907) 283-3265
1
7/3/2024
BGB
N/A
243002
24-04
2 2
CONTROL NOTE
PROJECT
LOCATION SECTION 9, T5N, R11W,
SEWARD MERIDIAN, ALASKA
CINGSA
CLU S-6 & CLU S-7 WELLS AS-BUILT
SURFACE LOCATION DIAGRAM
1) BASIS OF HORIZONTAL CONTROL; NAD83 US SURVEY FEET POSITION (EPOCH 2010) IS AN OPUS
SOLUTION FROM NGS STATIONS AC23 SOLDOTNA__AK2007 CORS ARP, AC47 SLOPEMTN__AK2007 CORS
ARP & DRIFTRIVERAK2006 CORS ARP for ADOT&PF BM 601
THE ALASKA STATE PLANE NAD83 ZONE 4 COORDINATES ARE:
N: 2393464.701
E: 1422055.725
LAT: 60°32'45.5509"N
LONG: -151°12'46.71771"W
2)BASIS OF VERTICAL CONTROL IS ADOT&PF BM 601 LOCATED AT BRIDE ACCESS RD. & BEAVER LOOP
RD INTERSECTION PER AKSAS PROJECT NO. 58703.
ELEV: 42.20' (NORTH AMERICAN VERTICAL DATUM OF 1988 (GEOID12A)
3)DATUM TRANSFORMATIONS FROM NAD83 TO NAD27 WERE DONE USING CORPSCON SOFTWARE
VERSION 6.0.1.
4)SURVEY PERFORMED BY MCLANE CONSULTING INC. ON JULY 3, 2024.
1
Cook Inlet Natural Gas Storage Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 14 July 2024
Rev. 0
Attachment 2 – As-Built Pad Design
Superseded by updated as-built. -A.Dewhurst 02OCT24
Cook Inlet Natural Gas Storage Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 15 July 2024
Rev. 0
Superseded by updated as-built. -A.Dewhurst 02OCT24
Cook Inlet Natural Gas Storage Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 16 July 2024
Rev. 0
Attachment 3 – Directional Program
Cook Inlet Natural Gas Storage Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 17 July 2024
Rev. 0
Cook Inlet Natural Gas Storage Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 18 July 2024
Rev. 0
Cook Inlet Natural Gas Storage Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 19 July 2024
Rev. 0
Attachment 4 – Diverter Schematic
Diverter will not be used. Diverter waive r
approved. -bjm
Cook Inlet Natural Gas Storage Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 20 July 2024
Rev. 0
Attachment 5 – BOPE Schematic
Cook Inlet Natural Gas Storage Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 21 July 2024
Rev. 0
Attachment 6 – Choke Manifold Schematic
Cook Inlet Natural Gas Storage Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 22 July 2024
Rev. 0
Attachment 7 – Wellhead / Tree Schematic
Cook Inlet Natural Gas Storage Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 23 July 2024
Rev. 0
Attachment 8 – Casing Design Program
Cook Inlet Natural Gas Storage Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 24 July 2024
Rev. 0
Attachment 9 – Rig Equipment, Layout & Fluids System
Cook Inlet Natural Gas Storage Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 25 July 2024
Rev. 0
Cook Inlet Natural Gas Storage Alaska, LLC (CINGSA) Kenai, AK
Alaska Oil and Gas Conservation Commission 26 July 2024
Rev. 0
Analysis Date-24hr Time:
Client:
Field:
Structure:
Slot:
Well:
Borehole:
Scan MD Range:
Trajectory Error Model:
Wellhead distance scan:
Selection filters:
Offset Trajectory Allow Sep. Controlling Reference Trajectory Alert Status
Ct-Ct (ft) MAS (ft) EOU (ft) Dev. (ft) Fact. Rule MD (ft) TVD (ft) Alert Minor Major
Warning Alert
219.13 32.81 216.06 186.32 118.55 MAS = 10.00 (m) 478.11 478.04 MinPt-O-SF
163.53 32.81 153.20 130.72 17.83 MAS = 10.00 (m) 1570.75 1524.26 MinPts
163.56 32.81 153.18 130.75 17.72 MAS = 10.00 (m) 1579.82 1532.10 MINPT-O-EOU
165.48 32.81 154.74 132.67 17.27 MAS = 10.00 (m) 1651.75 1593.44 MinPt-O-SF
555.15 62.60 513.09 492.55 13.49 OSF1.50 2899.14 2410.44 MinPt-O-SF
1061.00 105.02 990.66 955.98 15.28 OSF1.50 4037.85 3049.21 MinPt-O-SF
825.54 250.43 658.26 575.11 4.96 OSF1.50 7082.66 4705.81 OSF<5.00 Enter Alert
431.59 192.57 302.88 239.01 3.37 OSF1.50 7197.74 4747.93 MinPt-O-SF
355.19 141.87 260.28 213.32 3.77 OSF1.50 7223.93 4756.90 MinPt-O-ADP
327.19 107.09 255.47 220.11 4.61 OSF1.50 7239.25 4762.04 MINPT-O-EOU
321.13 99.18 254.68 221.95 4.89 OSF1.50 7248.83 4765.22 MinPt-CtCt
336.83 132.82 247.96 204.01 3.82 OSF1.50 7265.40 4770.63 MINPT-O-EOU
358.75 159.95 251.79 198.80 3.38 OSF1.50 7273.84 4773.35 MinPt-O-ADP
417.68 201.03 283.33 216.65 3.12 OSF1.50 7288.28 4777.95 MinPt-O-SF
867.18 262.91 691.58 604.27 4.96 OSF1.50 7348.72 4796.42 OSF>5.00 Exit Alert
998.51 268.35 819.28 730.16 5.60 OSF1.50 7361.79 4800.24 TD
CLU-7 (Def Survey)Warning Alert
10086.30 32.81 10084.39 10053.49 N/A MAS = 10.00 (m) 12.08 12.08 MinPts
10086.44 32.81 10084.31 10053.63 48957.60 MAS = 10.00 (m) 92.08 92.08 MINPT-O-EOU
10086.60 32.81 10084.30 10053.79 26042.87 MAS = 10.00 (m) 132.08 132.08 MINPT-O-EOU
10087.51 32.81 10084.40 10054.70 8442.73 MAS = 10.00 (m) 324.32 324.32 MINPT-O-EOU
599.04 185.04 475.10 414.01 4.89 OSF1.50 7884.62 4902.57 OSF<5.00 Enter Alert
402.94 284.02 213.06 118.92 2.13 OSF1.50 8020.97 4914.62 MinPt-CtCt
403.29 285.11 212.68 118.18 2.13 OSF1.50 8028.15 4915.25 MinPts
679.87 205.89 542.08 473.98 4.98 OSF1.50 8314.54 4940.35 OSF>5.00 Exit Alert
2247.06 77.11 2195.12 2169.95 44.61 OSF1.50 10383.80 5122.90 TD
CLU-15 (Def Survey)Warning Alert
3467.39 32.81 3466.27 3434.58 778223.62 MAS = 10.00 (m) 21.08 21.08 WRP
788.26 97.09 722.98 691.17 12.37 OSF1.50 5323.12 3770.18 MinPt-O-SF
527.32 146.95 429.03 380.37 5.41 OSF1.50 6136.37 4226.37 MinPt-CtCt
530.17 159.88 423.25 370.29 5.00 OSF1.50 6184.97 4253.64 OSF<5.00 Enter Alert
532.71 164.47 422.73 368.23 4.88 OSF1.50 6203.10 4263.81 MINPT-O-EOU
538.00 170.93 423.72 367.07 4.74 OSF1.50 6229.15 4278.42 MinPt-O-ADP
583.50 197.50 451.51 386.00 4.45 OSF1.50 6358.77 4351.13 MinPt-O-SF
718.40 216.89 573.47 501.50 4.98 OSF1.50 6613.59 4491.48 OSF>5.00 Exit Alert
3427.42 123.89 3344.50 3303.54 41.82 OSF1.50 7929.71 4906.67 TD
CLU S-7 wp16.1 (Def Plan)Pass
50.00 32.81 48.78 17.19 N/A MAS = 10.00 (m) 0.00 0.00 Surface
50.00 32.81 47.27 17.19 32.43 MAS = 10.00 (m) 300.00 300.00 MinPts
50.04 32.81 47.24 17.23 31.03 MAS = 10.00 (m) 329.61 329.61 MINPT-O-EOU
50.44 32.81 47.48 17.63 28.33 MAS = 10.00 (m) 398.70 398.69 MinPt-O-SF
82.45 32.81 76.90 49.64 18.78 MAS = 10.00 (m) 925.00 922.04 MinPt-O-SF
1575.45 79.85 1521.86 1495.60 29.98 OSF1.50 2865.19 2391.40 MinPt-O-SF
1415.60 146.48 1317.62 1269.12 14.58 OSF1.50 5677.93 3969.21 MinPt-O-SF
1088.31 70.96 1040.68 1017.36 23.31 OSF1.50 5985.07 4141.50 MinPt-CtCt
1093.57 83.50 1037.57 1010.07 19.86 OSF1.50 6033.60 4168.72 MINPT-O-EOU
1107.16 99.59 1040.44 1007.57 16.83 OSF1.50 6086.10 4198.17 MinPt-O-ADP
1339.18 210.84 1198.30 1128.34 9.57 OSF1.50 6577.25 4472.25 MinPt-O-SF
CLU S-3 (Def Survey)Pass
57.00 32.81 48.95 24.19 8.17 MAS = 10.00 (m) 1363.81 1340.00 MinPts
57.04 32.81 48.94 24.23 8.13 MAS = 10.00 (m) 1373.84 1349.16 MINPT-O-EOU
58.55 32.81 50.21 25.74 8.06 MAS = 10.00 (m) 1413.86 1385.48 MinPt-O-SF
77.64 32.81 67.00 44.83 8.11 MAS = 10.00 (m) 1553.19 1509.03 MinPt-O-SF
99.67 32.81 86.22 66.86 8.06 MAS = 10.00 (m) 1662.44 1602.43 MinPt-O-SF
2341.28 281.78 2153.10 2059.50 12.50 OSF1.50 7870.82 4901.17 MinPts
2306.93 293.02 2111.26 2013.91 11.84 OSF1.50 8157.39 4926.51 MinPts
1789.48 246.74 1624.65 1542.73 10.92 OSF1.50 10383.80 5122.90 MinPts
CLU S-2 (Def Survey)Pass
179.86 32.81 178.64 147.05 N/A MAS = 10.00 (m) 0.00 0.00 MinPts
180.32 32.81 178.41 147.51 263.64 MAS = 10.00 (m) 188.53 188.53 MINPT-O-EOU
59.61 32.81 47.60 26.80 5.42 MAS = 10.00 (m) 1657.92 1598.64 MinPt-O-SF
59.22 32.81 47.38 26.41 5.46 MAS = 10.00 (m) 1676.91 1614.56 MINPT-O-EOU
59.17 32.81 47.44 26.37 5.51 MAS = 10.00 (m) 1686.39 1622.47 MinPts
182.92 37.31 157.63 145.60 7.55 OSF1.50 2289.51 2064.31 MinPt-O-SF
272.45 56.38 234.51 216.07 7.36 OSF1.50 2570.30 2225.98 MinPt-O-SF
1663.51 304.90 1459.91 1358.61 8.21 OSF1.50 8153.14 4926.14 MinPt-O-SF
1660.04 303.45 1457.41 1356.59 8.23 OSF1.50 8188.35 4929.21 MinPt-O-ADP
929.26 237.74 770.44 691.52 5.88 OSF1.50 9680.27 5061.56 MinPts
CLU S-5 (Def Survey)Pass
98.44 32.81 96.20 65.64 95.51 MAS = 10.00 (m) 270.52 270.52 MinPts
98.49 32.81 96.16 65.68 88.41 MAS = 10.00 (m) 290.52 290.52 MINPT-O-EOU
779.34 62.44 737.36 716.90 19.02 OSF1.50 2488.06 2179.85 MinPt-O-SF
794.57 63.64 751.78 730.93 19.02 OSF1.50 2511.30 2192.88 MinPt-O-SF
3371.30 268.52 3191.96 3102.78 18.90 OSF1.50 7604.74 4860.28 MinPt-O-SF
- All Non-Def Surveys when no Def-Survey is set in a borehole - All Non-Def Plans when no Def-Plan is set in a borehole
Database \ Project:
ISCWSA0 3-D 95.000% Confidence 2.7955 sigma, for subject well. For
offset wells, error model version is specified with each well respectively.
CLU S-1 (Def Survey)
Every 10.00 Measured Depth (ft)Alaska - Kenai Unit Depth Interval:
2.10.836.0
D&M AntiCollision Standard S002 v5.1/5.2
All local minima indicated.
Cannery Loop Unit
Separation
CLU S-6
Offset Trajectories Summary
Offset Selection Criteria
Restricted within 51394.3 ft
Definitive Surveys - Definitive Plans - Definitive surveys exclude definitive plans
localhost\drilling-ScottyD
Risk Level
CLU S-6 wp08 Anti-Collision Summary Report
Version / Patch:
CLU S-6
Plan: CLU S-6
Min Pts:
Rule Set:
Reference Trajectory:
Normal Plane
CLU S-6 wp08 (Def Plan)ASRC
August 14, 2024 - 07:12 Analysis Method:
0.00ft ~ 10383.80ft
Drilling Office 2.10.836.0 Alaska - Kenai Unit\Cannery Loop Unit\Plan: CLU S-6\CLU S-6\CLU S-6 wp08 Page 1 of 3
Offset Trajectory Allow Sep. Controlling Reference Trajectory Alert Status
Ct-Ct (ft) MAS (ft) EOU (ft) Dev. (ft) Fact. Rule MD (ft) TVD (ft) Alert Minor Major
Separation Risk Level
3361.54 265.78 3184.02 3095.75 19.04 OSF1.50 7821.97 4895.65 MinPt-O-ADP
3361.24 265.37 3184.00 3095.87 19.06 OSF1.50 7839.78 4897.77 MINPT-O-EOU
3360.83 264.09 3184.44 3096.73 19.15 OSF1.50 7892.85 4903.36 MinPt-CtCt
3360.20 272.36 3178.31 3087.85 18.57 OSF1.50 8110.18 4922.39 MinPt-CtCt
3360.25 273.66 3177.48 3086.59 18.48 OSF1.50 8156.25 4926.41 MinPts
2897.18 226.51 2745.85 2670.67 19.26 OSF1.50 10382.90 5122.82 MinPts
CLU S-4 (Def Survey)Pass
112.05 32.81 110.82 79.24 N/A MAS = 10.00 (m) 3.58 3.58 MinPts
112.39 32.81 110.71 79.59 242.34 MAS = 10.00 (m) 143.58 143.58 MINPT-O-EOU
114.35 32.81 111.40 81.54 65.53 MAS = 10.00 (m) 427.11 427.09 MINPT-O-EOU
570.87 61.15 529.75 509.72 14.23 OSF1.50 2445.45 2155.95 MinPt-O-SF
1620.38 122.99 1538.06 1497.39 19.91 OSF1.50 4219.28 3150.98 MinPt-O-SF
2860.55 273.59 2677.83 2586.96 15.73 OSF1.50 7542.95 4847.03 MinPt-O-SF
2859.25 273.22 2676.78 2586.03 15.75 OSF1.50 7641.21 4867.45 MinPts
2859.11 272.98 2676.80 2586.14 15.76 OSF1.50 7673.67 4873.41 MinPt-CtCt
2839.03 279.85 2652.13 2559.18 15.27 OSF1.50 8150.50 4925.91 MinPts
2204.25 240.25 2043.76 1964.00 13.81 OSF1.50 10383.80 5122.90 MinPts
CLU-1RD (Def Survey)Pass
10248.57 32.81 10242.50 10215.76 2465.24 MAS = 10.00 (m) 292.08 292.08 MinPts
10248.58 32.81 10242.49 10215.77 2457.61 MAS = 10.00 (m) 306.01 306.01 MinPts
874.50 87.51 815.63 787.00 15.24 OSF1.50 10155.04 5102.95 MinPt-O-SF
595.38 68.73 549.02 526.65 13.27 OSF1.50 10383.80 5122.90 MinPts
CLU-1RDPB1 (Def Survey)Pass
10248.57 32.81 10242.50 10215.76 2465.24 MAS = 10.00 (m) 292.08 292.08 MinPts
10248.58 32.81 10242.49 10215.77 2457.61 MAS = 10.00 (m) 306.01 306.01 MinPts
874.50 87.51 815.63 787.00 15.24 OSF1.50 10155.04 5102.95 MinPt-O-SF
595.38 68.73 549.02 526.65 13.27 OSF1.50 10383.80 5122.90 TD
CLU-11 (Def Survey)Pass
3477.45 32.81 3475.54 3444.64 N/A MAS = 10.00 (m) 8.08 8.08 MinPts
821.12 208.00 681.45 613.12 5.99 OSF1.50 6566.86 4466.69 MinPt-O-SF
817.07 206.15 678.66 610.92 6.01 OSF1.50 6600.26 4484.47 MinPt-O-ADP
816.74 205.78 678.57 610.96 6.02 OSF1.50 6605.77 4487.37 MINPT-O-EOU
816.38 204.58 679.03 611.81 6.05 OSF1.50 6622.22 4496.00 MinPt-CtCt
3222.28 94.44 3158.73 3127.83 52.12 OSF1.50 7449.10 4824.26 TD
CLU-6 (Def Survey)Pass
10359.81 32.81 10356.78 10327.00 9298.16 MAS = 10.00 (m) 290.06 290.06 MinPts
10359.82 32.81 10356.73 10327.01 8832.00 MAS = 10.00 (m) 307.41 307.41 MINPT-O-EOU
1151.06 304.59 947.42 846.47 5.69 OSF1.50 7884.41 4902.55 MinPt-CtCt
1151.57 305.86 947.08 845.71 5.67 OSF1.50 7927.71 4906.49 MINPT-O-EOU
1151.79 306.13 947.12 845.66 5.67 OSF1.50 7934.37 4907.07 MinPt-O-ADP
1155.26 308.03 949.32 847.23 5.65 OSF1.50 7987.75 4911.72 MinPt-O-SF
1707.43 105.46 1636.58 1601.96 24.64 OSF1.50 10383.80 5122.90 TD
CLU-1 (Def Survey)Pass
10248.57 32.81 10242.54 10215.76 2487.28 MAS = 10.00 (m) 290.08 290.08 MinPts
10248.58 32.81 10242.53 10215.77 2477.50 MAS = 10.00 (m) 307.52 307.52 MinPts
4747.07 270.81 4565.33 4476.26 26.63 OSF1.50 8626.01 4968.33 MinPt-O-SF
2702.74 119.38 2621.86 2583.36 35.05 OSF1.50 9708.85 5064.05 MinPt-O-SF
1215.52 88.79 1154.92 1126.73 21.49 OSF1.50 10383.80 5122.90 MinPts
CLU-12 (Def Survey)Pass
3455.88 32.81 3454.65 3423.07 N/A MAS = 10.00 (m) 0.00 0.00 MinPts
3456.12 32.81 3454.03 3423.31 4016.12 MAS = 10.00 (m) 226.07 226.07 MINPT-O-EOU
1295.42 287.68 1102.78 1007.74 6.80 OSF1.50 7527.14 4843.42 MinPt-CtCt
1295.52 288.05 1102.64 1007.47 6.79 OSF1.50 7535.66 4845.38 MINPT-O-EOU
1295.67 288.21 1102.68 1007.45 6.79 OSF1.50 7539.89 4846.34 MinPt-O-ADP
1297.34 288.85 1103.93 1008.49 6.78 OSF1.50 7560.72 4850.99 MinPt-O-SF
3413.90 138.26 3321.40 3275.64 37.29 OSF1.50 7998.90 4912.70 TD
CLU-8 (Def Survey)Pass
10336.79 32.81 10333.58 10303.98 8005.06 MAS = 10.00 (m) 292.03 292.03 MinPts
10336.79 32.81 10333.55 10303.99 7754.70 MAS = 10.00 (m) 305.92 305.92 MinPts
1381.16 214.09 1237.90 1167.07 9.74 OSF1.50 10225.58 5109.10 MinPt-O-SF
1369.05 209.69 1228.72 1159.36 9.86 OSF1.50 10292.03 5114.90 MinPt-O-ADP
1368.78 209.37 1228.67 1159.42 9.87 OSF1.50 10295.99 5115.24 MINPT-O-EOU
1368.11 207.24 1229.41 1160.86 9.97 OSF1.50 10320.16 5117.35 MinPt-CtCt
1371.66 200.74 1237.30 1170.92 10.32 OSF1.50 10383.80 5122.90 TD
CLU-5A (P1) (Def Plan)Pass
10164.69 32.81 10163.47 10131.88 N/A MAS = 10.00 (m) 0.00 0.00 Surface
10161.95 32.81 10159.44 10129.14 7880.72 MAS = 10.00 (m) 298.96 298.96 MinPts
10161.95 32.81 10159.43 10129.14 7846.84 MAS = 10.00 (m) 300.80 300.80 MinPts
2529.46 69.10 2483.06 2460.36 55.68 OSF1.50 10383.80 5122.90 MinPts
CLU-13 (Def Survey)Pass
10075.93 32.81 10074.78 10043.12 351625.27 MAS = 10.00 (m) 33.98 33.98 MinPts
10076.38 32.81 10074.14 10043.58 8941.89 MAS = 10.00 (m) 310.95 310.95 MINPT-O-EOU
2706.72 84.82 2649.84 2621.90 48.41 OSF1.50 10383.80 5122.90 MinPts
CLU-4 (Def Survey)Pass
3424.07 32.81 3422.15 3391.26 N/A MAS = 10.00 (m) 18.78 18.78 MinPts
2933.65 116.56 2855.34 2817.09 38.33 OSF1.50 3997.05 3026.32 MinPt-CtCt
2937.36 127.50 2851.75 2809.86 35.04 OSF1.50 4180.60 3129.29 MINPT-O-EOU
2940.31 131.05 2852.33 2809.25 34.11 OSF1.50 4242.00 3163.73 MinPt-O-ADP
3216.39 184.65 3092.65 3031.74 26.39 OSF1.50 5559.51 3902.78 MinPt-O-SF
11192.94 131.59 11103.81 11061.35 131.75 OSF1.50 7810.80 4894.26 TD
CLU-3 (Def Survey)Pass
3191.02 88.48 3131.45 3102.54 55.17 OSF1.50 3095.16 2520.41 MinPt-CtCt
3191.54 89.90 3131.02 3101.64 54.29 OSF1.50 3127.38 2538.48 MINPT-O-EOU
3191.84 90.26 3131.08 3101.59 54.07 OSF1.50 3135.44 2543.00 MinPt-O-ADP
4283.95 407.18 4011.74 3876.76 15.86 OSF1.50 6638.04 4504.22 MinPt-O-SF
7178.92 465.93 6867.08 6713.00 23.28 OSF1.50 7299.62 4781.51 TD
13-08 (Def Survey)Pass
8429.33 56.61 8391.25 8372.72 227.46 OSF1.50 293.48 293.48 MinPts
8429.34 56.61 8391.26 8372.73 227.45 OSF1.50 306.64 306.64 MinPt-O-SF
8439.84 32.81 8437.03 8407.04 4728.42 MAS = 10.00 (m) 601.38 601.07 MinPt-O-SF
CLU-14 (Def Survey)Pass
10138.17 32.81 10137.03 10105.37 362221.50 MAS = 10.00 (m) 33.68 33.68 MinPts
Drilling Office 2.10.836.0 Alaska - Kenai Unit\Cannery Loop Unit\Plan: CLU S-6\CLU S-6\CLU S-6 wp08 Page 2 of 3
Offset Trajectory Allow Sep. Controlling Reference Trajectory Alert Status
Ct-Ct (ft) MAS (ft) EOU (ft) Dev. (ft) Fact. Rule MD (ft) TVD (ft) Alert Minor Major
Separation Risk Level
10138.31 32.81 10135.06 10105.50 4736.62 MAS = 10.00 (m) 215.68 215.68 MINPT-O-EOU
10138.34 32.81 10135.08 10105.53 4715.41 MAS = 10.00 (m) 240.68 240.68 MinPt-O-SF
10138.34 32.81 10135.50 10105.53 5859.57 MAS = 10.00 (m) 295.68 295.68 MinPts
10138.34 32.81 10135.48 10105.54 5802.44 MAS = 10.00 (m) 303.34 303.34 MINPT-O-EOU
10138.65 32.81 10135.21 10105.84 4368.55 MAS = 10.00 (m) 345.87 345.86 MINPT-O-EOU
10138.93 32.81 10135.44 10106.12 4271.69 MAS = 10.00 (m) 365.19 365.19 MinPt-O-SF
10145.24 32.81 10142.56 10112.43 6502.19 MAS = 10.00 (m) 519.61 519.49 MinPt-O-SF
CLU-5 (Def Survey)Pass
10164.69 32.81 10163.47 10131.88 N/A MAS = 10.00 (m) 0.00 0.00 Surface
10161.95 32.81 10159.44 10129.14 7880.28 MAS = 10.00 (m) 298.96 298.96 MinPts
10161.95 32.81 10159.43 10129.14 7846.40 MAS = 10.00 (m) 300.80 300.80 MinPts
10172.59 32.81 10169.77 10139.78 6370.67 MAS = 10.00 (m) 532.69 532.55 MinPt-O-SF
CLU-16 wp02 (Def Plan)Pass
10222.32 32.81 10219.77 10189.51 7123.95 MAS = 10.00 (m) 296.08 296.08 MinPts
10222.32 32.81 10219.75 10189.51 7033.28 MAS = 10.00 (m) 302.97 302.97 MinPts
10229.24 32.81 10226.58 10196.44 6613.12 MAS = 10.00 (m) 514.80 514.69 MinPt-O-SF
CLU-10 (Def Survey)Pass
10343.62 32.81 10341.00 10310.81 14862.73 MAS = 10.00 (m) 203.08 203.08 MinPts
10343.40 32.81 10340.43 10310.59 9808.31 MAS = 10.00 (m) 293.08 293.08 MinPts
10343.41 32.81 10340.39 10310.60 9420.83 MAS = 10.00 (m) 305.10 305.10 MINPT-O-EOU
10350.77 32.81 10347.32 10317.96 6737.26 MAS = 10.00 (m) 511.03 510.92 MinPt-O-SF
CLU-9 (Def Survey)Pass
10396.68 32.81 10393.64 10363.87 9250.37 MAS = 10.00 (m) 298.07 298.07 MinPts
10396.68 32.81 10393.63 10363.87 9156.14 MAS = 10.00 (m) 301.42 301.42 MINPT-O-EOU
10403.75 32.81 10400.30 10370.95 6772.68 MAS = 10.00 (m) 510.94 510.84 MinPt-O-SF
CLU-2 (Def Survey)Pass
11800.03 32.81 11798.80 11767.22 N/A MAS = 10.00 (m) 0.00 0.00 Surface
11799.52 32.81 11795.47 11766.71 4177.93 MAS = 10.00 (m) 316.84 316.84 MinPts
11799.90 32.81 11794.72 11767.09 2981.85 MAS = 10.00 (m) 346.04 346.04 MINPT-O-EOU
11800.97 32.81 11795.37 11768.16 2694.49 MAS = 10.00 (m) 372.58 372.58 MinPt-O-SF
11827.96 32.81 11818.83 11795.15 1496.59 MAS = 10.00 (m) 558.04 557.84 MinPt-O-SF
11910.39 32.81 11900.22 11877.58 1332.06 MAS = 10.00 (m) 741.35 740.37 MinPt-O-SF
12323.75 32.81 12306.66 12290.95 769.89 MAS = 10.00 (m) 1100.52 1092.73 MinPt-O-SF
12456.29 32.81 12439.11 12423.48 774.55 MAS = 10.00 (m) 1169.88 1159.03 MinPt-O-SF
12574.66 32.81 12556.94 12541.85 756.90 MAS = 10.00 (m) 1224.18 1210.40 MinPt-O-SF
12766.95 32.81 12747.07 12734.15 679.93 MAS = 10.00 (m) 1303.80 1284.77 MinPt-O-SF
12835.39 32.81 12815.33 12802.58 677.10 MAS = 10.00 (m) 1329.81 1308.79 MinPt-O-SF
13095.47 32.81 13073.97 13062.67 642.47 MAS = 10.00 (m) 1418.38 1389.56 MinPt-O-SF
13300.47 32.81 13278.71 13267.67 644.64 MAS = 10.00 (m) 1479.21 1444.02 MinPt-O-SF
13657.19 35.95 13632.84 13621.24 588.46 OSF1.50 1572.50 1525.78 MinPt-O-SF
15136.02 46.58 15104.59 15089.44 499.34 OSF1.50 1860.25 1762.73 MinPt-O-SF
15154.28 32.81 15134.80 15121.47 819.38 MAS = 10.00 (m) 1863.11 1764.95 TD
14-02 (Def Survey)Pass
12444.16 32.81 12443.13 12411.35 N/A MAS = 10.00 (m) 0.00 0.00 Surface
12444.16 59.84 12403.92 12384.31 317.33 OSF1.50 294.08 294.08 MinPt-CtCt
12471.77 354.86 12234.87 12116.91 52.86 OSF1.50 550.38 550.20 MinPts
12488.65 366.14 12244.23 12122.51 51.30 OSF1.50 617.63 617.27 MinPt-O-ADP
12678.80 677.15 12227.04 12001.66 28.12 OSF1.50 940.34 937.09 MINPT-O-EOU
12685.69 687.44 12227.07 11998.25 27.72 OSF1.50 946.06 942.70 MINPT-O-EOU
13015.51 1085.51 12291.51 11930.00 18.00 OSF1.50 1153.60 1143.54 MinPt-O-ADP
13341.94 1371.51 12427.27 11970.43 14.60 OSF1.50 1296.49 1278.00 MinPt-O-SF
Drilling Office 2.10.836.0 Alaska - Kenai Unit\Cannery Loop Unit\Plan: CLU S-6\CLU S-6\CLU S-6 wp08 Page 3 of 3
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2040608010012014020406080100120140CLU S-5 1101201281372465
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CLU S-2985 10771168125813471436152416101699178918 7 3
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TRAVELING CYLINDER PLOT
Client ASRC
Field Alaska - Kenai Unit
Structure Cannery Loop Unit
Well Plan: CLU S-6
Borehole CLU S-6
Date 24-Jul-2024
NoGo Region EOU's based on: Oriented EOU Dimension - Minor Risk
Anti-Collision rule used: D&M AntiCollision Standard S002 v5.1/5.2
Well Ticks Type: MD on CLU S-6 wp08
Calculation Method: Normal Plane
Ring Interval 20.00 ft
Azimuth Interval: 10.00 deg
Start Depth: 0.00 ft
End Depth: 10383.80 ft
Offset Well Count: 27
1
Dewhurst, Andrew D (OGC)
From:Dewhurst, Andrew D (OGC)
Sent:Wednesday, 2 October, 2024 17:08
To:Isaacson, William
Cc:Christianson, Grace K (OGC); McLellan, Bryan J (OGC); Davies, Stephen F (OGC); Guhl,
Meredith D (OGC)
Subject:RE: New Permit Number 224-112
Bill,
Yes, that was me. I looked at P.2 of the as-built and saw that it was also repeated on the spacing excep Ɵon applicaƟon. I
did not noƟce the correct drawing on P.1 of the as-built. Either way, I should have asked you about it.
We will issue a corrected PTD and I will also correct it in the dra Ō spacing excepƟon order.
Andy
From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Sent: Wednesday, 2 October, 2024 16:49
To: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Cc: Christianson, Grace K (OGC) <grace.christianson@alaska.gov>
Subject: FW: New Permit Number 224-112
Andy,
I think you had corrected this surface location information on the 10-401 form. Could you address Bill’s question?
Bryan McLellan
Senior Petroleum Engineer
Alaska Oil & Gas Conservation Commission
Bryan.mclellan@alaska.gov
+1 (907) 250-9193
From: Isaacson, William <wisaacson@asrcenergy.com>
Sent: Wednesday, October 2, 2024 9:42 AM
To: Christianson, Grace K (OGC) <grace.christianson@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Cc: Matthew Federle <Matthew.Federle@enstarnaturalgas.com>
Subject: RE: New Permit Number 224-112
Grace & Bryan,
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.
2
I noticed that the surface location information for the planned CLU Storage 6 well are incorrectly listed on the
AOGCC issued approval cover letter as well as on the actual Permit to Drill (the correct were crossed out and
replaced). In looking deeper at the As-Built that was provided for the well, page 1 of that As-Built diagram has the
coordinates correctly listed, however the table on page 2 has them reversed with CLU Storage 7. Therefore, I am
assuming in the review by the AOGCC they were taken from the table on page 2, which is incorrect. I have reached
out to the survey company and asked them to correct this error and enclosed is the updated version.
Since the Permit to Drill was submitted with the correct location on the actual Permit to Drill form, will the AOGCC
resubmit without that information crossed out and changed, or how do we proceed from here? Thank you
Bill Isaacson
Drilling Engineer
ASRC Energy Services Alaska, Inc.
3900 C Street, Suite 701
Anchorage, AK 99503
Direct: 907-339-6455 | Cell: 907-242-7483
One Crew, One Journey
Honoring the values of our founders as we develop the future.
From: Christianson, Grace K (OGC) <grace.christianson@alaska.gov>
Sent: Friday, September 27, 2024 10:01 AM
To: Isaacson, William <wisaacson@asrcenergy.com>; Matthew Federle <Matthew.Federle@enstarnaturalgas.com>
Subject: New Permit Number 224-112
Hello,
Attached is the new Permit for CLU 6.
Thank you,
GGrace Christianson
Executive Assistant,
Alaska Oil & Gas Conservation Commission
(907) 793-1230
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 conƱdential 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 Ʊrst
saving or forwarding it, and so that the AOGCC is aware of the mistake in sending it to you, contact Grace Christianson at (907 -793-1230) or
(grace.christianson@alaska.gov).
❚❛❜CAUTION: EXTERNAL SENDER This email originated from outside of the organization. Do not click
links or open attachments unless you recognize the sender and know the content is safe.
1
Dewhurst, Andrew D (OGC)
From:Isaacson, William <wisaacson@asrcenergy.com>
Sent:Monday, 16 September, 2024 13:20
To:McLellan, Bryan J (OGC); Dewhurst, Andrew D (OGC); Davies, Stephen F (OGC); Guhl,
Meredith D (OGC); Roby, David S (OGC)
Cc:Matthew Federle
Subject:CLU Storage 06 Application for Permit To Drill Supplemental Variance Request
Attachments:CLU 1_Formation Log TVD_Surf-2600.pdf; CLUS 2_ Formation Log TVD_Surf-2600.pdf;
CLUS 3_Formation Log TVD_Surf to TD.pdf; CLUS 4_Formation Log TVD_Surf to
2600.pdf; CLUS 5_Formation Log_TVD_Surf to 2600.pdf; CLUS 3 TVD5MEM_4MPR_TC_
118-8040_pp 9 7 11.pdf
All,
As discussed with Bryan, Andy and Steve, this email is being sent as a supplement to the Application for Permit to
Drill for CLU Storage 6.
Based upon data obtained by CINGSA during the 2011/12 drilling of the Ʊve (5) original wells from the pad, as well
as recent experience during the ongoing drilling of the CLU Storage 7 well, a variance to the diverter system
requirements of 20 AAC 25.035 (c) is being requested. The variance request is that a diverter system will not be
installed for the drilling of the CLU Storage 06 surface hole.
The CLUS 06 surface hole is planned to be drilled to a depth of ~2400’ TVD. Surface hole on the original Ʊve
CINGSA gas storage wells were drilled to depths ranging from ~2015’ TVD to 2410’ TVD, and all of the original wells
and the two new (CLUS 07 &06) are all within ~1250’ of each other at ~2400’ TVD. See the below spider plot
showing the planned and actual well spacing for all wells from the CINGSA Pad.
Mudlogging data was obtained on each of the original CINGSA gas storage wells. Data gathered in the surface
hole section consisted of gas monitoring on all Ʊve wells and full mud logs on the Ʊrst well, CLUS 03. Full mud
logs were also obtained from below the surface casing shoe to TD on all of the Ʊve wells. Enclosed are copies of
the mud logs for each of the original Ʊve CINGSA wells, showing data obtained from surface to ~2600’ TVD. Total
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.
2
gas seen while drilling each of the wells from surface to 2600’ TVD was measured at below 90 units, which is well
below the levels that you would expect to see from an interval with free gas. Listed below are the maximum gas
units seen for each well. Also enclosed are the LWD logs obtained on the CLUS 03 well. Neutron Density logs
were run in the intermediate hole on this well starting from ~2130’ TVD, and the Ʊrst sign of potential free gas, as
indicated by Neu/Den crossover, is within the Sterling A/B formation in the range of ~4300’ – 4380’ TVD. The mud
log on CLUS 03 for this corresponding interval shows ~260 units gas.
CLUS 01 ~83 units @ ~2030’ TVD
CLUS 02 ~38 units @ ~1200’ TVD
CLUS 03 ~40 units @ ~1260’ TVD
CLUS 04 ~45 units @ ~1450’ TVD
CLUS 05 ~30 units @ ~1720’ TVD
In addition to the believed absence of any free gas within the surface hole section, the pore pressures within the
interval are expected to be normally pressured. Each of the wells drilled the interval with mud weights ranging
from 8.6 ppg near surface to a range of 9.1-9.3 ppg near section TD. This is similar to the recently completed
drilling on the ongoing CLUS 07, which started the surface hole interval with 8.6 ppg and reached section TD with a
9.3 ppg mud weight. CLUS 06 is planned to be drilled with similar mud weights as used on CLUS 07. As an added
data point, Hilcorp recently (May 2024) drilled the CLU 16 surface hole section reaching a maximum mud weight of
9.1 ppg at section TD of ~2586’ TVD, and seeing a maximum gas throughout the section of 16 units (as listed on the
daily operations reports).
Please let me know if you have any questions or require additional information in support of your consideration of
this variance request.
Thank you and regards,
Bill Isaacson
Drilling Engineer
ASRC Energy Services Alaska, Inc.
3900 C Street, Suite 701
Anchorage, AK 99503
Direct: 907-339-6455 | Cell: 907-242-7483
One Crew, One Journey
Honoring the values of our founders as we develop the future.
Recommend granting diverter variance to 20 AAC 25.035 (h)(2) based on analysis of the seven
wells referenced above. -A.Dewhurst 18SEP24
1
Dewhurst, Andrew D (OGC)
From:Isaacson, William <wisaacson@asrcenergy.com>
Sent:Wednesday, 4 September, 2024 17:56
To:Dewhurst, Andrew D (OGC)
Cc:Davies, Stephen F (OGC); Guhl, Meredith D (OGC); McLellan, Bryan J (OGC); Roby, David
S (OGC)
Subject:RE: CLU S-6 PTD (224-112): Questions
Attachments:CLU-13_ACE_27FEB15.pdf
Andrew,
Below is the informaƟon for the 2 addiƟonal wells, CLU-13 and CLUS-1. Please review and let me know if addi Ɵonal
informaƟon is required. Thanks
CLU-13
The Sterling C is isolated behind the 7-5/8” casing, which was cemented from the shoe and up to an es Ɵmated TOC at
~800’MD. A CAST-M/CBL combo log was run the day a Ōer cemenƟng and idenƟĮed the TOC at ~2950’ MD. The log also
shows good cement above and below the Sterling C. See below schema Ɵc and Drilling Report for the 7-5/8” cement job
and follow up cement evalua Ɵon logging, and the CAST-M/CBL is a Ʃached.
Key Depths:
Sterling C 5515’ - 5796’
TOC/IsolaƟon 7-5/8” cemented casing, TOC @ ~2950’ (2/26/2015 CBL)
2
CLU 13 Drilling Report Covering 7-5/8” CMT Job
3
CLUS-1
The 9-5/8” casing was set just into the Sterling C1 and cement pumped in two stages to bring cement to surface. The
producƟon hole secƟon was drilled to TD within the C2, at which point a 7” liner was run and cemented. See Schema Ɵc
below. In addiƟon, InjecƟon/produc Ɵon in the well has been ongoing since drilled and completed in 2011/2012 and
recent PNL logging in 3/2024 veriĮed there was no signs of gas migra Ɵon to the shallower Sterling B & A sands (see
comments on analysis log from PNL).
4
5
6
Bill Isaacson
Drilling Engineer
ASRC Energy Services Alaska, Inc.
3900 C Street, Suite 701
Anchorage, AK 99503
Direct: 907-339-6455 | Cell: 907-242-7483
One Crew, One Journey
Honoring the values of our founders as we develop the future.
From: Isaacson, William <wisaacson@asrcenergy.com>
Sent: Wednesday, September 4, 2024 1:56 PM
To: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>;
McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>
Subject: RE: CLU S-6 PTD (224-112): Questions
Andrew,
Just met with my directional planner to look at these wells and it looks like CLU 13 and CLUS 1 are within the ¼
mile and will need a review. 13-08 falls outside ¼ mile, as long as it is assumed a vertical well.
The CLU 13 well was missed on the initial review for wells within ¼ mile. As far as CLUS 1, the review was
performed looking at the same TVD in each oƯset well rather than across the entire TVD of the reservoir. CLUS 1 is
outside ¼ mile at the same TVD in each of the wells, however is within the Sterling C reservoir at the same time
within ¼ mile. Once I reframed the requirement for the review the well showed up as being within ¼ mile.
We will take a look at the CLU 13 and CLUS 1 wells and get back with the requested information. Thank you!
Bill Isaacson
Drilling Engineer
ASRC Energy Services Alaska, Inc.
3900 C Street, Suite 701
Anchorage, AK 99503
Direct: 907-339-6455 | Cell: 907-242-7483
One Crew, One Journey
Honoring the values of our founders as we develop the future.
From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Sent: Tuesday, September 3, 2024 4:59 PM
To: Isaacson, William <wisaacson@asrcenergy.com>
Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>;
McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>
Subject: RE: CLU S-6 PTD (224-112): Questions
7
Bill,
Thank you.
Would you please con Įrm that the following wells are outside the quarter-mile AOR:
x CLU 13 (50-133-20646-00-00)
x CLU S-1 (50-133-20600-00-00)
x KU 13-08 (50-133-10014-00-00)
Thanks,
Andy
From: Isaacson, William <wisaacson@asrcenergy.com>
Sent: Tuesday, 3 September, 2024 13:08
To: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>;
McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>
Subject: RE: CLU S-6 PTD (224-112): Questions
Andrew,
Below is a list of the wells within ¼ mile of the planned completion interval, along with a review of the mechanical
condition and the associated cement isolation across the Sterling C Storage Pool interval for each listed
well. Also, enclosed is the requested map. Please review and let me know if additional information is
required. Thanks
CLU-01
CLU-01RD
CLU-05
CLU-06
CLU-07
CLUS-02
CLU-08, which is not within ¼ mile but just barely outside so included
CLU-01 (P&A’d in 1979, Re-Entered in 1988, Sidetracked in 2003 as CLU-01RD)
The Sterling C is isolated behind the 9-5/8” casing, which was cemented from the shoe and up to a bove 4400’ (CBL stops
at that depth). The bond log shows good cement across, above and below the Sterling C. See below schema Ɵc and
1979 CBL.
Key Depths:
Sterling C 5764’ - 6005’ MD
TOC/IsolaƟon TOC 4400’ + (1979 CBL stops at 4400’)
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8
9-5/8” Casing cemented with 1100sx thru shoe at 9045’, 1266 sx thru DV at 7400’
CLU-01 9-5/8” CBL (1979)
9
10
CLU-01RD (Sidetracked from CLU-01 above the Sterling C)
The Sterling C is isolated behind the 7” casing, which was cemented from the shoe and back to surface. There is also a
string of 4-1/2” that was cemented prior to perfora Ɵng the Beluga, however the Sterling C is isolated behind the 7”
casing. There was not a bond log run on the 7” casing, however the below daily report shows that cement was seen
above the DV collar at 4996’MD, therefore showing that cement was placed below, across and above the Sterling C. See
below schemaƟc and daily report.
Key Depths:
Sterling C 5795’ - 6157’ MD
TOC/IsolaƟon 7” Casing, cemented from the shoe at 9716’ to surface (see cement report on below schema Ɵc showing
cement returns to surface)
4-1/2” Casing, cement circulated below retainer and around 4-1/2” with top found on CBL at 4800 ’ MD
11
12
CLU-05 (PA’d, Sidetracked below CINGSA as CLU-05RD in 2015, which was P&A’d in 2022 and
the well sidetracked as CLU-05RD2)
13
The Sterling C is isolated behind the 9-5/8” casing, which was cemented from the shoe and up to an es Ɵmated depth of
2200’ MD (CBL stops at 5600’). The bond log shows cement across, above and below the Sterling C. See below
schemaƟc and 1996 CBL. Both sidetracks CLU-05RD and RD2 were sidetracked below the base of the Sterling C,
therefore isolaƟon remains the original 9-5/8” cement job.
Key Depths:
Sterling C 6071’ - 6295’ MD
IsolaƟon: 9-5/8” Casing, TOC is es Ɵmated at 2200’ based upon cement volume, but 1996 CBL stops at ~5600’
14
CLU-05 CBL (1996)
15
16
CLU-06 (Wellbore Plugged, Sidetracked from 1743 Ō as CLU-06RD)
CLU-06 was drilled and completed as the Įrst Sterling producer at Cannery Loop in 2000 and the well did not penetrate
below the Sterling C2 interval. In 2012 the C1 & C2 sands were sold to CINGSA and they were isolated from the CLU-06
wellbore by a 6 bbl cement squeeze and retainer with 131’ of cement laid on top. Comple Ɵon aƩempts were made in
the uphole Sterling B & A sands before the well was sidetracked in 2020 as CLU-06RD. The sidetracked well did not
17
penetrate the Sterling C1 & C2, but reached TD in the Sterling B. See below schemaƟcs for CLU-06 & 06RD, as well as
the CBL on CLU-06 showing isola Ɵon above the Sterling C.
Key Depths:
Sterling C 7770’ - TD’
TOC/IsolaƟon 4-1/2” Casing cemented with 141 bbls cement, TOC ~2200’
Cement Retainer, Cement Squeeze
18
19
CLU-06 CBL (06-29-2012) *CBL run in 2012, boƩom logged interval at 7250’
20
21
CLU-07
The Sterling C is isolated par Ɵally behind the 9-5/8” casing and 3-1/2” liner. The 9-5/8” casing was set ~75’ into the
Sterling C and cement was pumped to cover well above the Top Sterling C pool. The 3-1/2” liner was fully cemented and
the bond log shows good cement across and below the Sterling C. See below schema Ɵc and CBL.
Key Depths:
Sterling C 7685’ – 7970’
TOC/IsolaƟon 9-5/8” Casing, cemented with 158 bbls slurry, placing the TOC well above the Sterling C
3-1/2” Liner, TOC inside 9-5/8” casing shoe (2004 CBL)
CLU-07 3.5” Liner CBL (2004)
22
CLUS-2
23
The 9-5/8” casing was set just into the Sterling C1 and cement pumped in two stages to bring cement to surface. The
producƟon hole secƟon was drilled to TD within the C2, at which point a 7” liner was run and cemented. See Schema Ɵc
below. In addiƟon, InjecƟon/produc Ɵon in the well has been ongoing since drilled and completed in 2011/2012 and
recent PNL logging in 3/2024 veriĮed there was no signs of gas migra Ɵon to the shallower Sterling B & A sands (see
comments on analysis log from PNL).
24
25
26
CLU-08
The Sterling C is isolated par Ɵally behind the 9-5/8” casing and 3-1/2” liner. The 9-5/8” casing was set ~32’ into the
Sterling C and cement was pumped to cover well above the Top Sterling C pool. The 3-1/2” liner was fully cemented and
the bond log shows good cement across and below the main Sterling C pool intervals with a base at ~6880’ MD. See
below schemaƟc and CBL.
Key Depths:
Sterling C 6690’ – 6945’
TOC/IsolaƟon 9-5/8” Casing, cemented with 168 bbls slurry, shoe at 6722’
3-1/2” Casing, TOC at 5270’ (4-11-2004 CBL)
27
28
CLU-08 3.5” Casing CBL (2004)
29
30
Bill Isaacson
Drilling Engineer
ASRC Energy Services Alaska, Inc.
3900 C Street, Suite 701
Anchorage, AK 99503
Direct: 907-339-6455 | Cell: 907-242-7483
One Crew, One Journey
Honoring the values of our founders as we develop the future.
From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Sent: Wednesday, August 28, 2024 4:47 PM
To: Isaacson, William <wisaacson@asrcenergy.com>
Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>;
McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>
Subject: CLU S-6 PTD (224-112): Questions
Bill,
I’m Įnishing up my review of the CLU S-6 PTD and have two requests.
x Would you please provide a review of the mechanical condi Ɵon of the wells within a quarter mile of the
producƟve/completed interval of CLU S-6? The cemenƟng reports and CBL summaries that you previously
provided for CLU S-7 were great.
x On a related note, would you accompany the above with an updated map/plat showing the well path with the
locaƟon of these oīset wells?
Thanks,
Andy
Andrew Dewhurst
Senior Petroleum Geologist
Alaska Oil and Gas ConservaƟon Commission
333 W. 7th Ave, Anchorage, AK 99501
andrew.dewhurst@alaska.gov
Direct: (907) 793-1254
❚❛❜CAUTION: EXTERNAL SENDER This email originated from outside of the organization. Do not click
links or open attachments unless you recognize the sender and know the content is safe.
Revised 7/2022
TRANSMITTAL LETTER CHECKLIST
WELL NAME: ______________________________________
PTD: _____________________________________________
___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional
FIELD: __________________________ POOL: ____________________________________
Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter
CHECK OPTIONS TEXT FOR APPROVAL LETTER
MULTI
LATERAL
(If last two digits
in API number are
between 60-69)
The permit is for a new wellbore segment of existing well Permit
Number _____________, API Number 50-______________________.
Production from or injection into this wellbore must be reported under
the original API Number stated above.
Spacing
Exception
The permit is approved subject to full compliance with 20 AAC 25.055.
Approval to produce or inject is contingent upon issuance of a
conservation order approving a spacing exception. The Operator
assumes the liability of any protest to the spacing exception that may
occur.
Dry Ditch Sample
All dry ditch sample sets submitted to the AOGCC must be in no greater
than 30-foot sample intervals from below the permafrost or from where
samples are first caught and 10-foot sample intervals through target
zones.
Non-
Conventional
Well
Please note the following special condition of this permit: Production or
production testing of coal bed methane is not allowed for this well until
after the Operator has designed and implemented a water-well testing
program to provide baseline data on water quality and quantity. The
Operator must contact the AOGCC to obtain advance approval of such
a water-well testing program.
Well Logging
Requirements
Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types
of well logs to be run. In addition to the well logging program proposed
by the Operator in the attached application, the following well logs are
also required for this well:
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071,
composite curves for 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.
CLU S-6
KENAI C.L.U.
224-112
STERL C GAS STORAGE
WELL PERMIT CHECKLISTCompanyCook Inlet Natural Gas Storage Alaska, LLCWell Name:CANNERY LOOP UNIT S-6Initial Class/TypeSER / PENDGeoArea820Unit10320On/Off ShoreOnProgramSERField & PoolWell bore segAnnular DisposalPTD#:2241120KENAI C.L.U., STERL C GAS STOR - 449800NA1 Permit fee attachedYes ADL391627 and separate Natural Gas Storage Lease C-0616692 Lease number appropriateYes3 Unique well name and numberYes KENAI C.L.U., STERL C GAS STOR - 449800 - governed by CO 9A4 Well located in a defined poolNo5 Well located proper distance from drilling unit boundaryNA6 Well located proper distance from other wellsYes7 Sufficient acreage available in drilling unitYes8 If deviated, is wellbore plat includedNo9 Operator only affected partyYes10 Operator has appropriate bond in forceNo11 Permit can be issued without conservation orderYes12 Permit can be issued without administrative approvalYes13 Can permit be approved before 15-day waitYes Storage Injection Order 9A.14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (ForYes15 All wells within 1/4 mile area of review identified (For service well only)NA16 Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)Yes18 Conductor string providedYes19 Surface casing protects all known USDWsYes20 CMT vol adequate to circulate on conductor & surf csgYes21 CMT vol adequate to tie-in long string to surf csgYes22 CMT will cover all known productive horizonsYes23 Casing designs adequate for C, T, B & permafrostYes24 Adequate tankage or reserve pitNA25 If a re-drill, has a 10-403 for abandonment been approvedYes26 Adequate wellbore separation proposedNA Diverter waiver approved. Waiver request email attaced to PTD.27 If diverter required, does it meet regulationsYes28 Drilling fluid program schematic & equip list adequateYes29 BOPEs, do they meet regulationYes MPSP = 1728 psi, BOP rated to 5000 psi (BOP test to 3000 psi)30 BOPE press rating appropriate; test to (put psig in comments)Yes31 Choke manifold complies w/API RP-53 (May 84)Yes32 Work will occur without operation shutdownNo33 Is presence of H2S gas probableYes34 Mechanical condition of wells within AOR verified (For service well only)Yes Measures not required. Nearby wells did not encounter H2S35 Permit can be issued w/o hydrogen sulfide measuresYes No overpressure zones. Target reservoir anticipated to be at 7.7 ppg EMW.36 Data presented on potential overpressure zonesNA37 Seismic analysis of shallow gas zonesNA38 Seabed condition survey (if off-shore)NA39 Contact name/phone for weekly progress reports [exploratory only]ApprADDDate9/9/2024ApprBJMDate9/18/2024ApprADDDate8/28/2024AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDateJLC 10/7/2024
