Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout224-009
LETTER OF TRANSMITTAL
DETAIL
QTY DESCRIPTION
Baker Hughes has provided us with LithTrak Azimuthal Caliper
data for all 22 previous wells.
Details are provided on following pages with well name and API
table as reference.
Received by:_____________________________ Date: _____________
Please sign and return one copy to:
Santos
ATTN: Shannon Koh
601 W 5th Ave., Anchorage, AK 99501
shannon.koh@santos.com
DATE: 11/18/2025
From:
Shannon Koh
Santos
601 W 5th Ave.
Anchorage, AK 99501
To:
Gavin Glutas
AOGCC
333 W. 7th Avenue, Suite 100
Anchorage, AK 99501
TRANSMISSION TYPE:
܈External Request
܆Internal Request
TRANSMISSION METHOD:
܆CD ܆ Thumb Drive
܆Email ܆SharePoint/Teams
܆Hardcopy ܈Other - FTP
REASON FOR TRANSMITTAL:
܆Approved
܆Approved with Comments
܆For Approval
܈Information Only
܆For Your Review
܆For Your Use
܆To Be Returned
܆With Our Comments
܆Other
COMMENTS:
Gavin
Gluyas
Digitally signed by
Gavin Gluyas
Date: 2025.11.19
08:30:05 -09'00'
LETTER OF TRANSMITTAL
Well API
NDB-010 50103209200000
NDB-011 50103209160000
NDBi-014 50103208690000
NDBi-016 50103208920000
NDBi-018 50103208880000
NDB-024 50103208620000
NDB-025 50103208770000
NDB-027 50103209220000
NDBi-030 50103208730000
NDB-031 50103209120000
NDB-032 50103208600000
NDBi-036 50103209080000
NDB-037 50103208950000
NDBi-043 50103208590000
NDBi-044 50103208650000
NDBi-046 50103208830000
NDB-048 50103209020000
NDBi-049 50103208940000
NDBi-050 50103209040000
NDB-051 50103208800000
DW-02 50103208550000
PWD-02 50103208790000
جؐؐؐDW-02 Lithotrak Caliper data
ؒ SANTOS_DW-02_BHP_8_5_2384_7459ft_RUN5.dlis
ؒ SANTOS_DW-02_BHP_8_5_2384_7459ft_RUN5.las
ؒ
جؐؐؐNDB-010 Lithotrak Caliper data
ؒ SANTOS_NDB-010_BHP_8_5_9620_19462ft_Run3.dlis
ؒ SANTOS_NDB-010_BHP_8_5_9620_19462ft_Run3.las
ؒ
جؐؐؐNDB-011 Lithotrak Caliper data
ؒ جؐؐؐ12.25 in
ؒ ؒ SANTOS_NDB-011_BHP_12_25in_2755_12365ft_RUN2.dlis
ؒ ؒ SANTOS_NDB-011_BHP_12_25in_2755_12365ft_RUN2.las
ؒ ؒ
ؒ ؤؐؐؐ8.5 in
ؒ SANTOS_NDB-011_BHP_8_5in_2755_12365ft_RUN3.dlis
223-039
T41107
225-061
T41108
225-048
T41109
PWD-02 50103208790000
LETTER OF TRANSMITTAL
ؒ SANTOS_NDB-011_BHP_8_5in_2755_12365ft_RUN3.las
ؒ
جؐؐؐNDB-024 Lithotrak Caliper data
ؒ جؐؐؐRun 6
ؒ ؒ Santos_NDB-024_BHP_12_25_2443_6175ft_Run6.dlis
ؒ ؒ Santos_NDB-024_BHP_12_25_2443_6175ft_Run6.las
ؒ ؒ
ؒ ؤؐؐؐRun 7
ؒ SANTOS_NDB-024_BHP_8_5_11466_17969ft_RUN7.dlis
ؒ SANTOS_NDB-024_BHP_8_5_11466_17969ft_RUN7.las
ؒ
جؐؐؐNDB-025 Lithotrak Caliper data
ؒ SANTOS_NDB-025_BHP_8_5_8437_13838ft_Run3.dlis
ؒ SANTOS_NDB-025_BHP_8_5_8437_13838ft_Run3.las
ؒ
جؐؐؐNDB-027 Lithotrak Caliper data
ؒ SANTOS_NDB-027_BHP_6_125in_17280_12862ft_RUN6.dlis
ؒ SANTOS_NDB-027_BHP_6_125in_17280_12862ft_RUN6.las
ؒ
جؐؐؐNDB-031 Lithotrak Caliper data
ؒ SANTOS_NDB-031_BHP_6_125_18706_24362ft_Run4.dlis
ؒ SANTOS_NDB-031_BHP_6_125_18706_24362ft_Run4.las
ؒ
جؐؐؐNDB-032 Lithotrak Caliper data
ؒ جؐؐؐRun 3
ؒ ؒ SANTOS_NDB-032_BHP_12_25_2598_6224ft_Run3.las
ؒ ؒ SANTOS_NDB_032_BHP_12_25_2598_6224ft_Run3.dlis
ؒ ؒ
ؒ ؤؐؐؐRun 4
ؒ SANTOS_NDB-032_BHP_8_5_6285_12280ft_Run4.dlis
ؒ SANTOS_NDB-032_BHP_8_5_6285_12280ft_Run4.las
ؒ
جؐؐؐNDB-037 Lithotrak Caliper data
ؒ SANTOS_NDB-037_BHP_8_25_10871_17793_RUN3.dlis
ؒ SANTOS_NDB-037_BHP_8_25_10871_17793_RUN3.las
ؒ
جؐؐؐNDB-048 Lithotrak Caliper data
ؒ جؐؐؐRun 2
ؒ ؒ SANTOS_NDB-048_BHP_12_25_2252_12112ft_Run2.dlis
ؒ ؒ SANTOS_NDB-048_BHP_12_25_2252_12112ft_Run2.las
ؒ ؒ
ؒ ؤؐؐؐRun 3
223-076
T41110
224-006
T41111
225-066
T41112
225-028
T41113
223-060
T41114
224-124
T41115
224-143
T41116
LETTER OF TRANSMITTAL
ؒ SANTOS_NDB-048_BHP_8_5in_12168_21225ft_Run3.dlis
ؒ SANTOS_NDB-048_BHP_8_5in_12168_21225ft_Run3.las
ؒ
جؐؐؐNDB-051 Lithotrak Caliper data
ؒ جؐؐؐRun 2
ؒ ؒ SANTOS_NDB-051_BHP_12_25_3258_11502_RUN2.dlis
ؒ ؒ SANTOS_NDB-051_BHP_12_25_3258_11502_RUN2.las
ؒ ؒ
ؒ ؤؐؐؐRun 3
ؒ SANTOS_NDB-051_BHP_8_5_11565_17429.dlis
ؒ SANTOS_NDB-051_BHP_8_5_11565_17429.las
ؒ
جؐؐؐNDBi-014 Lithotrak Caliper data
ؒ SANTOS_NDBi-014_BHP_8_5_10448_15362_RUN3.dlis
ؒ SANTOS_NDBi-014_BHP_8_5_10448_15362_RUN3.las
ؒ
جؐؐؐNDBi-016 Lithotrak Caliper data
ؒ SANTOS_NDBi-016_BHP_8_5in_12860_18610ft_RUN4.las
ؒ SANTOS_NDBi-016_BHP_8_5in_12860_18610ft_RUN4_1.dlis
ؒ
جؐؐؐNDBi-018 Lithotrak Caliper data
ؒ جؐؐؐRun 2
ؒ ؒ SANTOS_NDBi-018_BHP_12_25_2580_8193_RUN2.dlis
ؒ ؒ SANTOS_NDBi-018_BHP_12_25_2580_8193_RUN2.las
ؒ ؒ
ؒ ؤؐؐؐRun 3
ؒ SANTOS_NDBi-018_BHP_8_5_8225_13060_RUN3.dlis
ؒ SANTOS_NDBi-018_BHP_8_5_8225_13060_RUN3.las
ؒ
جؐؐؐNDBi-030 Lithotrak Caliper data
ؒ SANTOS_NDBi-030_BHP_8_5in_11200_1743.6ft_Run6.dlis
ؒ SANTOS_NDBi-030_BHP_8_5in_11200_1743.6ft_Run6.las
ؒ
جؐؐؐNDBi-036 Lithotrak Caliper data
ؒ جؐؐؐRun 4
ؒ ؒ SANTOS_NDBi-036_BHP_8_5in_10990_16780ft_Run4.dlis
ؒ ؒ SANTOS_NDBi-036_BHP_8_5in_10990_16780ft_Run4.las
ؒ ؒ
ؒ ؤؐؐؐRun 6
ؒ SANTOS_NDBi-036_BHP_6.125in_16813_22680ft_Run6.dlis
ؒ SANTOS_NDBi-036_BHP_6.125in_16813_22680ft_Run6.las
ؒ
224-013
T41117
223-105
T41118
224-105
T41119
224-085
T41120
223-120
T41121
225-012
T41122
LETTER OF TRANSMITTAL
جؐؐؐNDBi-043 Lithotrak Caliper data
ؒ جؐؐؐRun 2
ؒ ؒ Santos_NDBi-043_BHP_12_25_2443_6175ft_Run2.dlis
ؒ ؒ Santos_NDBi-043_BHP_12_25_2443_6175ft_Run2.las
ؒ ؒ
ؒ ؤؐؐؐRun 4
ؒ Santos_NDBi-043_BHP_8_5_6240_13105ft_Run4.dlis
ؒ Santos_NDBi-043_BHP_8_5_6240_13105ft_Run4.las
ؒ
جؐؐؐNDBi-044 Lithotrak Caliper data
ؒ SANTOS_NDBi-044_BHP_8_5in_11114_17783ft_RUN5.dlis
ؒ SANTOS_NDBi-044_BHP_8_5in_11114_17783ft_RUN5.las
ؒ
جؐؐؐNDBi-046 Lithotrak Caliper data
ؒ SANTOS_NDBi-046_BHP_12_25_3758_12514_RUN2.dlis
ؒ SANTOS_NDBi-046_BHP_12_25_3758_12514_RUN2.las
ؒ
جؐؐؐNDBi-049 Lithotrak Caliper data
ؒ جؐؐؐRun 2
ؒ ؒ SANTOS_NDBi-049_BHP_12_25_2645_115572ft_Run2.dlis
ؒ ؒ SANTOS_NDBi-049_BHP_12_25_2645_115572ft_Run2.las
ؒ ؒ
ؒ ؤؐؐؐRun 3
ؒ SANTOS_NDBi-049_BHP_8_5_11642_19250_RUN3.dlis
ؒ SANTOS_NDBi-049_BHP_8_5_11642_19250_RUN3.las
ؒ
جؐؐؐNDBi-050 Lithotrak Caliper data
ؒ SANTOS_NDBi-050_BHP_6_125_15145_22525ft_Run9.dlis
ؒ SANTOS_NDBi-050_BHP_6_125_15145_22525ft_Run9.las
ؒ
ؤؐؐؐPWD-02 Lithotrak Caliper data
SANTOS_PWD-02_BHP_8_5_6818_9461_Run_4_5_6.dlis
SANTOS_PWD-02_BHP_8_5_6818_9461_Run_4_5_6.las
223-051
T41123
223-087
T41124
224-028
T41125
224-119
T41126
224-154
T41127
224-009
T41128
ؐؐPWD-02 Lithotrak Caliper data
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1a. Well Status:Oil SPLUG Other Abandoned Suspended
1b. Well Class:
20AAC 25.105 20AAC 25.110 Development Exploratory
GINJ WINJ WDSPL No. of Completions: __________________ 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: 4894 FSL, 4267 FEL, S14, T11N, R6E, UM
Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s):
4942 FSL, 1780 FEL, S14, T11N, R6E, UM GL: 34.1 BF: Pikka / Undefined Waste Disposal Pool
Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation:
4942 FSL, 1780 FEL, S14, T11N, R6E, UM ADL 392964
4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number:
Surface: x- y- Zone- 4 LONS 19-003
TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD:20. Thickness of Permafrost MD/TVD:
Total Depth: x- y- Zone- 4
5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD:
Submit electronic information per 20 AAC 25.050 N/A (ft MSL)
22. Logs Obtained:
GR-RES-NEU-DEN-Sonic-Image-NMR-Mudlogs-CBL-WFL
23.
BOTTOM
20"x34" X-52 128'
13-3/8" L-80 2,231'
9-5/8" L-80 6,123'
9-5/8" L-80 2,085'
7" L-80 8,815'
4-1/2" 13Cr-80 8,219'
24. Open to production or injection? Yes No 25.
26.
Was hydraulic fracturing used during completion? Yes No
DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED
27.
Date First Production: Method of Operation (Flowing, gas lift, etc.):
Hours Tested: Production for Gas-MCF:
Test Period
Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr):
Press. 24-Hour Rate
Sr Res EngSr Pet GeoSr Pet Eng
N/A
Oil-Bbl: Water-Bbl:
9,371' - 9,401' MD 30 bbls of 15% HCl
Water-Bbl:
PRODUCTION TEST
Date of Test: Oil-Bbl:
Flow Tubing
9,371' MD - 9,401' MD / 8,679' TVD - 8,709' TVD
3-1/8" Max Force Frac HMX 6 SPF 60 Degree Phasing Gun
Date perf'd - 1/22/25
Gas-Oil Ratio:Choke Size:
Per 20 AAC 25.283 (i)(2) attach electronic information
47#
2,252'
2,081'
Surface
215#
68#
128'
2,247' 6,815'
SIZE DEPTH SET (MD)
8,880' MD / 8,188' TVD
PACKER SET (MD/TVD)
12.6#
6,661'
Surface
42"
26#
Tubing
16"
Grouted to surface
Surface See attached cement rpt
47#
Surface
Surface
2,427'Surface
Surface
CASING WT. PER
FT.GRADE
04/26/24
CEMENTING RECORD
5,964,653.60
1,322' MD / 1,295' TVD
SETTING DEPTH TVD
5,964,653.34
TOP HOLE SIZE AMOUNT
PULLED
433,960.45
433,960.49
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.
N/A
BOTTOM
50-103-20879-00-00
Pikka / PWD-02
03/30/24
9,510' MD / 8,818' TVD
N/A
81.1
601 W 5th Avenue, Anchorage, AK 99501
431,473.44 5,964,627.56
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
Oil Search Alaska, LLC
WAG
Gas
01/16/25 224-009 / 324-557 / 324-697
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date perf'd or liner run):
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
CASING, LINER AND CEMENTING RECORD
List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion,
See attached cement rptTie Back
TUBING RECORD
Uncemented
8,911'
9,507'
See attached cement rpt
5,969'
Surface
12-1/4"
8-1/2"
8,911' MD4-1/2"
N/A
Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment
Received by J. Brooks
on 2/11/2025 at 7:42AM
Completed
1/16/2025
JSB
RBDMS JSB 021925
G
CDW 03/05/2025
DSR-4/7/25BJM 11/10/25
Conventional Core(s): Yes No Sidewall Cores:
30.
MD TVD
Surface Surface
1,369' 1,338'
Top of Productive Interval
Ivishak 8,923' 8,231'
Upper Schrader Bluff 917' 910'
Middle Schrader Bluff 1,788' 1,704'
MCU 2,306' 2,130'
Tuluvak Shale 2,706' 2,460'
Tuluvak Sand 2,792' 2,530'
TS_790 3,270' 2,921'
Seabee 3,708' 3,280'
Nanushuk 4,469' 3,904'
NT8 MFS 4,555' 3,974'
NT7 MFS 4,671' 4,069'
NT6 MFS 4,772' 4,152'
NT5 MFS 5,586' 4,896'
NT4 MFS 5,871' 5,179'
NT3 MFS 6,165' 5,473'
NT2 MFS 6,227' 5,535'
NT1 MFS 6,307' 5,615'
Torok Sandstone 6,334' 5,642'
HRZ 6,535' 5,843'
Kalubik 6,712' 6,020'
LCU 6,831' 6,139'
Miluveach 6,837' 6,145'
UJU 7,117' 6,425'
Alpine A 7,122' 6,430'
7,343' 6,651'
7,393' 6,701'
Lower Nuiqsut 7,507' 6,815'
8,129' 7,437'
8,401' 7,709'
8,630' 7,938'
Shublik 8,739' 8,047'
Ivishak 8,923' 8,231'
31. List of Attachments:
Summary of Daily Operations, Casing & Cement Summaries, Definitive Surveys, Wellbore Schematic
32. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Contact Name: Nicklaus Miller
Digital Signature with Date:Contact Email:nick.miller@santos.com
Contact Phone:1-406-690-2896
Authorized Title: Senior Completions Engineer
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:
Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
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.
Lower Kingak
Upper Kingak
Sag River
Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345),
and/or Easement (ADL 123456) number.
The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements
given in other spaces on this form and in any attachments.
The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic
diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a
well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071.
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis,
paleontological report, production or well test results, per 20 AAC 25.070.
Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each
segregated pool is a completion.
Upper Nuiqsut
Middle Kingak
Formation Name at TD:
TPI (Top of Producing Interval).
Authorized Name and
INSTRUCTIONS
Yes No
Well tested? Yes No
28. CORE DATA
If Yes, list intervals and formations tested, briefly summarizing test results for
each. Attach separate pages if needed and submit detailed test info including
reports and Excel or ASCII tables per 20 AAC 25.071.
NAME
Permafrost - Top
Permafrost - Base
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.
29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS
Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov
2/10/2025
PWD-02 FINAL Well Schematic
GLGL
Primary Injection Zone Ivishak
8,923 MD / 8,231 TVD
to 9,401' MD / 8,709' TVD
Upper Confining Layer - Shublik
Top: 8,739 MD / 8,047 TVD
20" Insulated Conductor128' MD 20" Insulated Conductor128' MD
4-½X-Nipple1530' MD / 1482' TVD 4-½X-Nipple1530' MD / 1482' TVD
4-½12.6ppf 13Cr80 GLM w/ 1" Pocket 1590' MD / 1535' TVD 4-½12.6ppf 13Cr80 GLM w/ 1" Pocket 1590' MD / 1535' TVD
9-5/8" Liner Hanger and Liner Top Packer2247' MD / 2081' TVD 9-5/8" Liner Hanger and Liner Top Packer2247' MD / 2081' TVD
13-3/8" 68 ppf L-80 Surface Casing2427' MD / 2231' TVD 13-3/8" 68 ppf L-80 Surface Casing2427' MD / 2231' TVD
9-5/8" 47 ppf L-80 Tieback2252' MD / 2085' TVD 9-5/8" 47 ppf L-80 Tieback2252' MD / 2085' TVD
9-5/8" 47 ppf L-80 Intermediate Liner6815' MD / 6123' TVD 9-5/8" 47 ppf L-80 Intermediate Liner6815' MD / 6123' TVD
7" Liner Hanger and Liner Top Packer6660' MD / 5968' TVD 7" Liner Hanger and Liner Top Packer6660' MD / 5968' TVD
7" 26 ppf L-80 Production Liner9507' MD / 8815' TVD 7" 26 ppf L-80 Production Liner9507' MD / 8815' TVD
Perforations9371' MD / 8679' TVD -
9401' MD / 8709' TVD Perforations9371' MD / 8679' TVD -
9401' MD / 8709' TVD
4-½X-Nipple8820' MD / 8128' TVD 4-½X-Nipple8820' MD / 8128' TVD
4-½XN-Nipple8901' MD / 8209' TVD 4-½XN-Nipple8901' MD / 8209' TVD
4-½x 7" Production Packer8880' MD / 8188' TVD 4-½x 7" Production Packer8880' MD / 8188' TVD
4-½WLEG8911' MD / 8219' TVD 4-½WLEG8911' MD / 8219' TVD
02.05.2025
Estimated 7" Liner TOC8340' MD / 7648' TVD Estimated 7" Liner TOC8340' MD / 7648' TVD
Alternate Injection Zone Torok
Top: 6,334 MD / 5,642 TVD
Estimated 9-5/8" Liner TOC4100' MD / 3601' TVD Estimated 9-5/8" Liner TOC4100' MD / 3601' TVD
Upper Confining Layer - Torok
Top: 5,847 MD / 5,155 TVD
Lower Confining Layer - HRZ
6,535 MD / 5,843 TVD
4-½12.6ppf TSH-W563 13Cr80 Production Tubing
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
BOPE Test Report for:
Reviewed By:
P.I. Suprv
Comm ________PIKKA PWD-02
JBR 03/13/2025
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:4
TJ's used 4" and 4-1/2". 20 Accumulator bottles 1000psi precharge avg. Fail on annular cycle and pass. Fail Kill HCR Service
pass. Fail CMV #4 replace pass had wait time on this one, they had to bring a valve from deadhorse and forgot the orings were
able to source from parker 272. Fail on manual choke tear down and clean passed. Very short handed crew of 6 people total so
testing was slow.
Test Results
TEST DATA
Rig Rep:T.Shones/A. CarloOperator:Oil Search (Alaska), LLC Operator Rep:G. Rizek/J. Petitjean
Rig Owner/Rig No.:Doyon 16 PTD#:2240090 DATE:1/12/2025
Type Operation:WRKOV Annular:
250/5000Type Test:INIT
Valves:
250/5000
Rams:
250/5000
Test Pressures:Inspection No:bopKPS250112134908
Inspector Kam StJohn
Inspector
Insp Source
Related Insp No:
INSIDE REEL VALVES:
Quantity P/F
(Valid for Coil Rigs Only)
Remarks:
Test Time 23
MASP:
3646
Sundry No:
324-557
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
14 FPNo. Valves
1 FPManual Chokes
1 PHydraulic Chokes
0 NACH Misc
Stripper 0 NA
Annular Preventer 1 13-5/8"FP
#1 Rams 1 3-1/2" x 6" V P
#2 Rams 1 Blinds P
#3 Rams 1 2-7/8" X 5"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 1 3-1/8"P
Check Valve 0 NA
BOP Misc 1 2-1/16" Kill-li P
System Pressure P2925
Pressure After Closure P1600
200 PSI Attained P15
Full Pressure Attained P111
Blind Switch Covers:PAll Stations
Bottle precharge P
Nitgn Btls# &psi (avg)P6@ 2150
ACC Misc NA0
P PTrip Tank
P PPit Level Indicators
P PFlow Indicator
P PMeth Gas Detector
P PH2S Gas Detector
NA NAMS Misc
Inside Reel Valves 0 NA
Annular Preventer P17
#1 Rams P5
#2 Rams P6
#3 Rams P6
#4 Rams NA0
#5 Rams NA0
#6 Rams NA0
HCR Choke P2
HCR Kill P2
9
9
9 9 9999
9
9
9
9
9
9
Fail on annular Fail Kill HCR
Fail CMV #4
Fail on manual choke
P.I. SupvComm:Rig Coil Tubing Unit? NoRig Contractor Rig RepresentativeOperator Operator RepresentativeWell Permit to Drill # 2240090 Sundry Approval # 324-557Operation Inspection LocationWorking Pressure, W/H Flange P Pit Fluid Measurement P Working Pressure PP Flow Rate Sensor P Operating Pressure PP Mud Gas Separator P Fluid Level/Condition PP Degasser P Pressure Gauges PP Separator Bypass P Sufficient Valves PP Gas Detectors P Regulator Bypass PP Alarms Separate/Distinct P Actuators (4-way valves) PP Choke/Kill Line Connections PBlind Ram Handle CoverPP Reserve Pits NA Control Panel, Driller PP Trip Tank P Control Panel, Remote PPFirewallPP2 or More Pumps PP Kelly or TD Valves PIndependent Power SupplyPP Floor Safety Valves P N2 Backup PP Driller's Console P Condition of Equipment PP Flow Monitor PFlow Rate Indicator PPit Level Indicators P Valves PPPE P Gauges P Remote Hydraulic Choke PWell Control Trained P Gas Detection Monitor P FOV Upstream of Chokes PHousekeeping P Hydraulic Control Panel P Targeted Turns PWell Control Plan P Kill Sheet Current P Bypass Line PFAILURES:0CORRECT BY:COMMENTSAll equipment is in good shape andproperly rated (BOP hoses flanges and all iron). Alarms are the way they should be. Not all of the rigs pit modules and motor module (not needed during this run of a couple wells).CHOKE MANIFOLDPikka MUD SYSTEMPikka PWD-02Workover CLOSING UNITALASKA OIL AND GAS CONSERVATION COMMISSIONRIG INSPECTION REPORTHCR Valve(s)Manual ValvesAnnular PreventerWorking Pressure, BOP StackStack AnchoredChoke LineKill LineTargeted TurnsPipe RamsBlind RamsT. Shones/ A. CarloG. Rizek/ J. PetitjeanLocking Devices, RamsBOP STACKKam St.John1/11/2025INSPECT DATEAOGCC INSPECTORDoyon 16DoyonOilSearch (Alaska) LLCMISCELLANEOUSFlange/Hub ConnectionsDrilling Spool OutletsFlow NippleControl LinesRIG FLOOR2025-0112_Rig_Doyon16_Pikka_DW-02_ksj rev. 4-19-2023999999-5HJJ
A lGl_ Pw6-02--
PTb Z74 c rzln
Regg, James B (OGC)
From:
Gathman, Brad / Frazier, Nick (OSH.Lead.Comp.Super)
< Lea d.Co m p.S u per@ sa ntos.co m >
Sent:
Monday, February 3, 2025 10:25 AM
To:
Regg, lames B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC); Wallace,
Chris D (OGC)
Cc:
Senden, Robert (Ty); Gathman, Brad (Brad)
Subject:
PWD-02 MIT -IA 02.01.2025
Attachments:
PWD-02 MIT -IA 02.01.2025.xlsx
0 Some people who received this message don't often get email from lead.comp.super@santos.com. Learn why this is important
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attachments unless you recognize the sender and know the content is safe.
Attached is the MIT -IA test form for PWD-02 conducting on February 1", 2025 and witnessed by EPA Evan Osborne
and James Phillips. Please let me know if you have any questions.
Nick Frazier
Wells Superintendent
Alternate— Brad Gathman
b
mobile: +1 (907) 830-9463
office: + 1 (907) 685-4245
e-mail: Lead,Comp,Super@san.tos,co.m.
Sar:los Ltd A.B.N. 80 007 550 923
D.srlahner 115e intonnation contained In this email is intended only for the use of the person(s) to whom it is addressed and may be confidential or contain
privileged infol mation. if you are not the intended recipient you are hereby notified that any perusal, use, distribution, copying or disclosure is strictly prohibited. If
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STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
Mechanical Integrity Test
Submit to: 'im.reggAalaskagov: Phoebe. bregks0alaska.gov
OPERATOR: Oil Search (Santos)
FIELD I UNIT I PAD: Pikka I NDB
DATE: 0210la5
OPERATOR REP: Nick Frazier
AOGCC REP: Adam Ead Waived. EPA onsite for witness.
chriewallace(®alaska nov
Well
PWD-02
Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTO
224-009—
Type Inj
N -
Tubing 1
0
176-
183
149
Type Test
P
Packer ND
8188'
BBL Pump
5.2
IA
248
4204 _
4160
4167
Interval
Test psi
40W
ftSL Relum 1
5.2
OA I
9
1 11
12
9
Result
P
Notes:
local MIT - A post complete, EPA Evan Osborne and James Phillips onsite forwtness.
Well
Pressures: Pretest Initial 15 Min. W Min. 45 Min. 60 Min.
PTO
Type Inj
Tubing
Type Tesl
Packer ND
BBL Pump
IA
Inteal
ry
Test psi
BBL Return
OA
Result
Notes:
Well
Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTO
Type Inj
Tubing
Type Test
Packer ND
BBL Pump
IA
Interval
Test psi
BBL Return
OA
Result
Notes:
Well
Pressures: Pretest Initial 15 Min. 30 Min, 45 Min. 60 Min.
PTO
Type Inj
Tubing
Type Test
Packer ND
BBL Pump
IA
Interval
Test psi
BBL Return
OA
Result
yore-:
Well
Pressures: Pretest Initial 15 Min. 30 Min, 45 Min. 60 Min.
PTO
Type Inj
Tubing
Type Test
Packer NDI
BBL UMPI
IA
IInterval
Test psi
BBL Re um
OA
Result
Notes:
Well
Pressures. Pretasl Initial 15 Min. 30 Min. 45 Min. EO Min.
PTO
Type Inj
Tubing
Type Test
Packer ND
BBL Pump
IA
Interval
Test psi
BBL Return
OA
Result
Notes:
Well
Pressures: Pretest Initial 15 Min, 30 Min. 45 Min. 60 Min.
PTO
Type Inj
Tubing
Type Test
Packer ND
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
cubing
Type Test
Pecker ND
BBL Pump
IA
Interval
Test psi
BBL Return
OA
Result
y>"as
TYPE MJ Cates
Was TEST peons
INTERVAL Codes
Result Codes
Vyvyveler
P=Pressure Test
1=Initial Test
P=Pau
G -Gss
0= Other (don -toe in Ndea)
4=Four Year Cyde
F=Full
S= Slurry
V = Reputed by Varie.
1= lVenclusrve
I = IMusNai Wanewaler
0=other (aucntc in notes)
N = Not InkMW
Form 10426 (Revised 0112017)
PNa02 MIT -IA poor 2025
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?N/A PWD-02
Yes No
9. Property Designation (Lease Number): 10. Field:
Pikka Undefined Waste Disposal Pool
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD):
9,510' 8,818' N/A N/A N/A N/A
Casing Collapse
Structural
Conductor 2260
Surface 4750
Intermediate 4750
Tie-Back 9210
Liner 9210
Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft):
Removable Production Packer 8,883 MD and 8,191 TVD
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:Nicklaus Miller
Contact Email:nick.miller@santos.com
Contact Phone: 1-406-690-2896
Authorized Title: Senior Completions Engineer
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:
Tubing Size:
PRESENT WELL CONDITION SUMMARY
AOGCC USE ONLY
11590
Tubing Grade: Tubing MD (ft):
N/A
Perforation Depth TVD (ft):
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL 392964
224-009
900 E Benson Boulevard, Suite 500, Anchorage, AK 99508 50-103-20879-00-00
Oil Search Alaska, LLC
Length Size
Proposed Pools:
13Cr80ksi
TVD Burst
8,908
11590
MD
6870
5020
6870
128'
2231'
6123'
128'
2427'
20"x34"
13-3/8"
128'
9-5/8"4568'
2380'
9,374 - 9,401
2209'
7"
8,700
2086'9-5/8"
3,646
12/31/24
9507'2846'
4-1/2 12.6ppf
8815'
N/A
2253'
Perforation Depth MD (ft):
6815'
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
CltiEi
12/11/2024
By Grace Christianson at 8:35 am, Dec 12, 2024
324-697
Perforate
SFD 12/13/2024
10-404
Ivishak SFD
Disposal operations to be in compliance with EPA issued Class I permit.
Other Stimulate
Class I EPA
BJM 1/8/25 DSR-12/16/24&': &':IRU-/&
Gregory C. Wilson Digitally signed by Gregory C. Wilson
Date: 2025.01.09 08:55:52 -09'00'
RBDMS JSB 010925
Page 1 of 1
10 December 2024
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, AK 99501
Re: Application for Sundry - Perforation
Oil Search (Alaska), LLC, a subsidiary of Santos Limited
PWD-02
Dear Sir/Madam
Oil Search (Alaska), LLC hereby applies for a Sundry Application to e-line perforate and stimulate an
onshore service well that is on the NPF pad, North Slope. The PWD-02 well is an Underground Injection
Control (UIC) Class 1 Disposal Well targeting the Ivishak formation as the perforation and injection zone.
The PWD-02 well has been drilled to TD of 9,510’ MD. The well is currently being completed and the sundry
information may be subject to change. Upon the 4-1/2” chrome tubular completion and pressure test, the
drilling rig will de-mobilize, and the perforation will be accomplished with E-line post rig move. Extended
injection test and 15% HCl treatment will not exceed 4,000 psi maximum injection pressure per the original
permit.
Please find enclosed for your review Form 10-403 Sundry with supporting documents containing
information as required by 20 AAC 25.280.
If there are any questions and/or additional information desired, please contact me at (406) 690-2896 or
nick.miller@santos.com.
Respectfully,
Nicklaus Miller
Senior Completions Engineer
Oil Search (Alaska), LLC
Enclosures:
Form 10-403 Sundry
Application for Sundry
Respectfully,
Nicklaus Miller
Original EPA permit (see attached email from Nicklaus Miller 1/8/25). -bjm
Ivishak formation as the perforation and injection zone
Page 1 of 5
PWD-02 Sundry Application Requirements
Per 20 AAC 25.280
1. Current Condition of the Well
1. Pressure tested 7” 26ppf L-80 casing to 4,000 psi for 30 minutes.
2. Circulated completion 10.0 ppg NaCl/KCl corrosion inhibited brine.
3. Removable production packer has been set @ ~8,885’ MD.
4. 4,500 psi for 30 min MIT-T.
5. 4,000 psi for 30 min MIT-IA.
6. IA has been freeze protected to the circulation valve.
7. Production tree has been tested to 5,000 psi.
2. Proposed Program for Well Work
1. MIRU E-Line unit w/ LRS and pressure test lubricator to 500 psi low / 3500 psi
high.
2. RIH with 3-1/8” MaxForce-FRAC HMX 6 SPF perforation guns on E-line. Ensure
log on depth by tying into Gamma Ray log. Perforate 9,374’ – 9,401’MD.
3. Log up for the correlation pass and determine the depth correction needed, note
shift correction in job log. Perform a confirmation pass up to confirm depth. Log up
to place guns into position, verify depth with onsite Santos Completions
Supervisor and Ops Geologist. Fire once depths verified.
4. POOH with perforating tools.
5. Stop at ~300 feet, check all safety switches are in the SAFE position before
proceeding to the surface with the tool-string. Monitor bottom hole pressure for 10
minutes before POOH.
6. Once at surface, verify all shots are fired.
7. Swap to tubing and pump 10 bbls of 10.0 ppg NaCl/KCl brine at up to 2 bpm to
verify injectivity.
8. Perform extended injection test and 15% HCl treatment. Perform step rate test.
pg
Perforate 9,374’ – 9,401’MD
Page 2 of 5
Page 3 of 5
Page 4 of 5
3. A diagram and description of the well control equipment to be used, including if
applicable, a list of the blowout prevention equipment (BOPE) with specifications.
Page 5 of 5
4. Maximum downhole pressure that may be encountered, criteria used to
determine it, and the maximum potential surface pressure based on a pressure
gradient to surface of 0.1 psi per foot of true vertical depth, unless the
commission approves a different methodology.
Max downhole pressure: 4,300 psi based on 9.5 pore pressure gradient at 8,700’
TVD. (8700’ TVD x 9.5 ppg x 0.052)
Max potential surface pressure is 3,430 psi based on pressure gradient to
surface of 0.1 psi per foot. (4,300 psi - (0.1 psi/ft x 8,700’))
5. Description of any wellbore fluid to be used for primary well control.
Prior to running perforation guns with E-line:
x 7” PBTD to 4-1/2” EOT will have 10.0 ppg NaCl/KCl inhibited brine.
x Inner 4-1/2” Tubing will consist of 10.0 ppg NaCl/KCl inhibited brine.
x IA of 4-1/2” Tubing will consist of 10.0 ppg NaCl/KCl inhibited brine to the GLM
circulation valve. Above GLM circulation valve will have diesel freeze protect.
6. Current bottom-hole pressure, or, if data setting out the actual pressure are not
available, an estimate of the current bottom-hole pressure.
Estimated bottom hole pressure:
x 4,524 psi bottom hole pressure
1
McLellan, Bryan J (OGC)
From:Miller, Nicklaus (Nick) <Nick.Miller@santos.com>
Sent:Wednesday, January 8, 2025 3:14 PM
To:McLellan, Bryan J (OGC)
Subject:RE: PWD-02 (PTD 224-009) HCL stim sundry
Bryan,
Happy New Year! See below responses to your quesƟons in RED.
Thank you,
Nicklaus Miller
Senior CompleƟons Engineer, Alaska D&C
t: +1 (907) 646-7091 | m: +1 (406) 690-2896 | e: nick.miller@santos.com
Santos.com | Follow us on LinkedIn, Facebook and Twitter
From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Sent: Monday, December 23, 2024 4:35 PM
To: Miller, Nicklaus (Nick) <Nick.Miller@santos.com>
Subject: ![EXT]: PWD-02 (PTD 224-009) HCL stim sundry
Nick,
I’m reviewing the sundry application for pumping HCl into the new perfs.
What is the max injection pressure in steps 7 & 8 and how does that pressure compare to the frac pressure? The
disposal well is designed to inject above frac pressure to deliver the slurry by initiating a fracture if the fracture
does not propagate into the upper and lower conƱning zones as speciƱed in the EPA permit AK-11024-A (40 CFR. §
146.13 (a) (1)). The Shublik Formation and the Kavik Formation are identiƱed as the Upper and Lower ConƱning
Zones where frac modelling demonstrates that the frac is well contained within these intervals. To understand
fracture geometry and injection well deliverability we have designed a series of step-rate injection tests above frac
pressure as well as an acid treatment to clear residual cement and maximize e Ưective perf area. The max injection
pressure in steps 7&8 should be observed during the 10bpm step on day 2 should be 5226 psi BH and 2723 psi on
surface. This represents a net pressure of 200psi above frac pressure for the 3% NaCL brine (3% seawater). –
Santos Subsurface Team
You mention a 4000 psi pressure already approved in the original permit. Which permit was that approval in? Is
that the EPA disposal permit? Yes, the 4,000 psi surface pressure limitation is outlined in the original permit, see
below screenshot.
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
Thanks
Bryan McLellan
Senior Petroleum Engineer
Alaska Oil & Gas Conservation Commission
Bryan.mclellan@alaska.gov
+1 (907) 250-9193
Santos Ltd A.B.N. 80 007 550 923
Disclaimer: The information contained in this email is intended only for the use of the person(s) to whom it is addressed and may be confidential or contain
privileged information. If you are not the intended recipient you are hereby notified that any perusal, use, distribution, copying or disclosure is strictly prohibited. If
you have received this email in error please immediately advise us by return email and delete the email without making a copy. Please consider the environment
before printing this email
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 nick.miller@santos.com. Learn why this is important
From:Wallace, Chris D (OGC)
To:AOGCC Records (CED sponsored)
Subject:FW: PWD-02 (PTD 216-063) RWO sundry
Date:Tuesday, October 15, 2024 12:09:18 PM
Attachments:PWD-02_CAST-CBL_28APR24_ProcessedLog_V2_9.625 in.pdf
From: Miller, Nicklaus (Nick) <Nick.Miller@santos.com>
Sent: Tuesday, October 15, 2024 10:35 AM
To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Cc: Roby, David S (OGC) <dave.roby@alaska.gov>; Davies, Stephen F (OGC)
<steve.davies@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Dewhurst, Andrew
D (OGC) <andrew.dewhurst@alaska.gov>; Noll, Christian (Christian) <Christian.Noll@santos.com>
Subject: RE: PWD-02 (PTD 216-063) RWO sundry
Bryan,
Thank you for the thorough response. Please see my comments to your questions below in RED.
The CAST CBL log for the 9-5/8” cement job is attached for reference.
Regards,
Nicklaus Miller
Senior Completions Engineer, Alaska D&C
t: +1 (907) 646-7091 | m: +1 (406) 690-2896 | e: nick.miller@santos.com
Santos.com | Follow us on LinkedIn, Facebook and Twitter
From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Sent: Monday, October 14, 2024 5:46 PM
To: Miller, Nicklaus (Nick) <Nick.Miller@santos.com>
Cc: Roby, David S (OGC) <dave.roby@alaska.gov>; Davies, Stephen F (OGC)
<steve.davies@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Dewhurst, Andrew
D (OGC) <andrew.dewhurst@alaska.gov>; Noll, Christian (Christian) <Christian.Noll@santos.com>
Subject: ![EXT]: PWD-02 (PTD 216-063) RWO sundry
Nick,
There is an issue with the planned completion design in your sundry application for this well.
The upper packer being 2500 ft above the primary injection zone means that there is no way to
know if those 2500’ of tubing or sliding sleeve develop a leak, there’s no way to know that you
are injecting out of zone. The request for variance in the initial PTD still met the intent of this
regulation, however the new variance request does not. We are discussing this internally, but
I’m not sure if that contingent injection perfs and shallow packer will be permitted. The upper
9-5/8” packer is 61’ away from the alternate/approved Torok injection zone. In the highly
unlikely event of a leaking sliding sleeve or tubing leak in the 2,500’ section between the 7” and
9-5/8” packers, any miniscule fluid volume injected in that area would be confined to the
Torok formation since there is adequate cement bond present to effectively isolate the
proposed Torok injection perforations. To confirm tubing integrity, a plug could be set in the
lower XN nipple on an annual basis and an MIT could be performed to eliminate any concerns
of a leak in this 2,500’ section. If the sliding sleeve is found to be leaking, a blanking sleeve
can be installed across the sliding sleeve and injection into the Ivishak can be resumed.
Adequate cement is present from 5,980’ to 6,660’ per the 9-5/8” CAST CBL log (attached) run
on 4/29/24. In summary, there is 381’ of adequate cement bond above the top Torok
perforation and 269’ of adequate cement bond below the bottom Torok perforation. The
Lower HRZ confining layer to the Torok is completely isolated by high quality cement. Any fluid
injected into this wellbore will be isolated to the approved Torok or Ivishak formation, no fluid
will be injected out of approved zone(s).
In the mean time, I have a few other questions about the permit application:
1. There’s no mention in the procedure of perforating the Ivishak, although the proposed
diagram shows ivishak perfs. Are you planning to submit a separate sundry for that?
Ivishak perforations will be added post rig and a separate sundry will be submitted for
those operations.
2. Your plan will not pressure test the lower packer. How do you plan to prove integrity of
the lower packer to confine injected fluids to the Ivishak? Once upper and lower packer
are set, 1-7/8” standard ball and rod will be retrieved with slickline. Lower packer will be
tested by pressuring down the 4-1/2” tubing and testing 7” packer from below to 4,000
psi. 7” casing was pressure tested to 4,000 psi on 4/29/2024.
3. What’s the maximum approved injection pressure for the well? 4,000 psi for Ivishak
injection and 2,500 psi for Torok injection.
4. Please submit the BOP stack and choke diagram for the rig you plan to use for this
operation. Final configuration nearing internal approval and I will send to you for review
once it’s received.
5. Has Doyon 16 been working under continuous operation for other operators? If not, how
long has it been since it last work with the planned BOP stack. Doyon 16 has been
stacked for approx. 7 years. A thorough two week commissioning process will begin on
November 1, prior to mobilizing the rig to NDB pad. A full 5 year certification, along with
full Category 4 derrick inspection will be performed.
Thanks
Bryan McLellan
Senior Petroleum Engineer
Alaska Oil & Gas Conservation Commission
Bryan.mclellan@alaska.gov
+1 (907) 250-9193
Santos Ltd A.B.N. 80 007 550 923
Disclaimer: The information contained in this email is intended only for the use of the person(s) to whom it is addressed and may be
confidential or contain privileged information. If you are not the intended recipient you are hereby notified that any perusal, use,
distribution, copying or disclosure is strictly prohibited. If you have received this email in error please immediately advise us by return
email and delete the email without making a copy. Please consider the environment before printing this email
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........................................................................... Fold here__________-______-____--_______-__________-_____-_____-____________--____--
Service Ticket No: PGM Version:
Logs Processed, CAST-CBLM Date Logged04/28/2024 Type of Fluid in Hole'.
DIRECTIONAL INFORMATION
Maximum Deviation ea KOP ea
Remarks
1, LOG OBJECTIVE'. CEMENT EVALUATION BEHIND 9.625" CASING.
2. PLESE REFER TO THE REPORT FOR THE DETAIL ANALYSIS.
HALLIBURTON DOES NOT GUARANTEE THE ACCURACY OF ANY INTERPRETATION OF THE LOG DATA, CONVERSION OF LOG DATA TO PHYSICAL ROCK
PARAMETERS OR RECOMMENDATIONS WHICH MAY BE GIVEN BY HALLIBURTON PERSONNEL OR WHICH APPEAR ON THE LOG OR IN ANY OTHER FORM.
ANY USER OF SUCH DATA, INTERPRETATIONS, CONVERSIONS, OR RECOMMENDATIONS AGREES THAT HALLIBURTON IS NOT RESPONSIBLE EXCEPT
WHERE DUE TO GROSS NEGLIGENCE OR WILLFUL MISCONDUCT, FOR ANY LOSS, DAMAGES, OR EXPENSES RESULTING FROM THE USE THEREOF.
HALLIBURTON
i , L
4325-4382 GOOD I Good bonding and coverage seen in these areas. Cement bond index is
4445-4572 greater than 80%
4606-4742
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?N/A PWD-02
Yes No
9. Property Designation (Lease Number): 10. Field:
Pikka Undefined Waste Disposal Pool
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD):
9,510' 8,818' N/A N/A N/A N/A
Casing Collapse
Structural
Conductor 2260
Surface 4750
Intermediate 4750
Tie-Back 9210
Liner 9210
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:Nicklaus Miller
Contact Email:nick.miller@santos.com
Contact Phone: 1-406-690-2896
Authorized Title: Senior Completions Engineer
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:
Tubing Size:
PRESENT WELL CONDITION SUMMARY
AOGCC USE ONLY
11590
Tubing Grade: Tubing MD (ft):
N/A
Perforation Depth TVD (ft):
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL 392964
224-009
601 W 5th Avenue, Anchorage, AK 99501 50-103-20879-00-00
Oil Search Alaska, LLC
Length Size
Proposed Pools:
P-110S
TVD Burst
1,682'
11590
MD
6870
5020
6870
128'
2231'
6123'
128'
2427'
20"x34"
13-3/8"
128'
9-5/8"4568'
2380'
N/A
2209'
7"
N/A
2086'9-5/8"
3,646
11/15/24
9507'2846'
4-1/2:
8815'
N/A
2253'
Perforation Depth MD (ft):
6815'
m
ns
2
6
5
6
t
_
c
N
Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
9/26/2024
324-557
By Grace Christianson at 4:09 pm, Sep 26, 2024
CDW 10/14/2024
X
Disposal operations to be in compliance with EPA issued Class I permit.
BJM 10/18/24
10-404
X
If this is the first well in the Doyon 16 RWO campaign, the initial BOP test will be to 5000 psi.
Provide 24 hrs notice for AOGCC opportunity to witness MIT-IA to 4000 psi. -bjm
EPA Class I
SFD 10/7/2024
Separate sundry is required before perforating.
X-bjm
DSR-9/27/24
Perforate
BOP test to 4000 psi. Annular test to 3000 psi.
*&:
Jessie L. Chmielowski
Digitally signed by Jessie L.
Chmielowski
Date: 2024.10.21 09:05:49 -08'00'10/21/24
RBDMS JSB 102224
Oil Search (Alaska), LLC
a subsidiary of Santos Limited
601 W 5th Avenue
Anchorage, Alaska 99501
PO Box 240927
Anchorage, Alaska 99524
(T) +1 907 375 4642
—santos.com
1/2
26 September 2024
Bryan McLellan
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, AK 99501
Re: Requested changes to PWD-02 (PTD Number 224-009)
Dear Mr. McLellan
Santos representatives met with AOGCC and presented a petrophysical analysis of Tuluvak,
Alpine and Nuiqsut formations present in the PWD-02 wellbore. Tuluvak pay estimation did
not change (no significant hydrocarbon was identified) per the original PTD. Alpine and
Nuiqsut formations showed no significant hydrocarbons in the PWD-02 wellbore, per updated
pay cutoff definitions using core-based industry best practices. The AOGCC agreed with
Santos’ assessment; therefore, Tuluvak, Alpine and Nuiqsut formations in PWD-02 wellbore
do not require cement isolation per AOGCC Regulation 20 AAC 25.030 (d)(5). Existing PWD-
02 wellbore will not require remedial cement work prior to 4-1/2” completion installation. This
is included for AOGCC’s final consideration and written approval.
The PWD-02 9-5/8” and 7” liner cement jobs provide adequate cement coverage across the
Ivishak (primary) and Torok (alternate) injection formations. The requested change from
original completion design will allow selective injection into Ivishak or Torok formations without
requiring a rig workover. The Torok formation will be perforated on-rig, prior to installing the
completion. A variance is required to place the 7” production packer greater than 200’ above
the top Ivishak perforation and was granted assuming following conditions were met per
original PTD comments: 1) Packer set less than 50’ above base of Shublik mudstone upper
confining interval, and 2) There is at least 100’ of cement across Shublik mudstone upper
confining interval above the packer. The 9-5/8” production packer isolating alternate Torok
injection perforations will be set at 6,300 ft which satisfies requirements of AOGCC Regulation
20 AAC 25.412(b). The proposed Torok injection interval has adequate cement coverage
and perforations will be isolated by 4-1/2” tubing and a mechanical sliding sleeve run between
9-5/8” and 7” production packers. Selective Torok formation injection can be accomplished
by setting a PXN plug below 7” packer to isolate Ivishak perforations followed by opening the
mechanical sliding sleeve with slickline as needed. Adding Torok perforations on-rig and
installing a 9-5/8” packer for Torok isolation is a requested change to the approved PTD.
The attached schematics show the current mechanical status of the well and proposed
completion design. The plan will be to return to NPF pad with Doyon Rig 16 and rig up on
PWD-02 mid-November as road conditions allow.
Current Status:
The 7” Liner was run and cemented. An ultrasonic cement log was run in the 9-5/8” liner and
7” liner. E-line was rigged down and the 7” liner was successfully pressure tested to 4,000
psi. A 9-5/8” retrievable bridge plug was set at 2,488’ MD and tested to 4,000 psi and a kill
string was run to 1,680’ MD and freeze protected to surface. Santos was granted permission
to temporarily shut down drilling operations.
Torok perforations
and secondary packer
are not authorized.
A single packer above
the Ivishak will be set
per the conditions
included in the PTD
and mentioned here.
-bjm
2/2
Proposed plan Forward
1. Pull 4-1/2” Kill String and pull retrievable bridge plug
2. Perforate Torok formation On-rig
3. Install 4-1/2” premium completion string with packers isolating Ivishak and Torok
injection zones
4. RDMO Doyon 16 drilling rig
7” Liner Cement Isolation (Ivishak)
A Wireline CAST-M Cement Evaluation log was run in the 7” Liner. The log results showed
top of cement at 8,340’ MD. The log shows adequate cement from 8,340’ MD – 9,423’ MD.
The TOC is within the Kingak formation, and the cement isolates the target injection zone in
the Ivishak from all other permeable zones. The proposed 7” packer setting depth is 8,883’
and is less than 50’ above base of Shublik (8,923’ MD) mudstone formation. Over 100’ of
adequate cement is present across the Shublik mudstone upper confining interval above the
7” packer. This meets variance requirements outlined in original PTD for placing the packer
greater than 200’ from proposed Ivishak perforations located from 9,374’ – 9,401’ MD. Setting
a production packer at base of Shublik gives the greatest flexibility for adding future
perforations depending on well injection performance. If future perforations are required, they
can be added off-rig without moving the production packer and performing a rig workover.
9-5/8” Liner Cement Isolation (Torok)
A Wireline CAST-M Cement Evaluation Log was run in the 9-5/8” Liner. The log results show
TOC at 4,100’ MD. The log shows adequate cement from 4,100’ MD - 6,662’ MD. The TOC
is within the Seabee formation and cement isolates the Nanushuk. The proposed 9-5/8”
packer setting depth is 6,300’ and Torok perforations will be added on-rig from 6,361’ – 6,391’
MD. This packer setting depth satisfies AOGCC Regulation 20 AAC 25.412(b). The proposed
Torok injection interval has adequate cement coverage and perforations will be isolated by 4-
1/2” tubing and a mechanical sliding sleeve run between the 9-5/8” and 7” production packers.
Selective Torok formation injection can be accomplished by setting a PXN plug below 7”
packer to isolate Ivishak perforations followed by opening the mechanical sliding sleeve using
slickline. This configuration will provide injection redundancy without requiring a rig workover
to add Torok perforations. Adding Torok perforations on-rig and installing a 9-5/8” packer for
Torok isolation is a requested change to the approved PTD.
If there are any questions and/or additional information desired, please contact me at (406)
690-2896 or Nick.Miller@Santos.com
Respectfully,
Nicklaus Miller
Senior Completions Engineer
Oil Search (Alaska), LLC
Enclosures:
Form 10-403 Application for Sundry Approvals
Torok perforations and 2nd packer are not approved as part of this sundry. -bjm
Proposed Ivishak
primary injection
interval is adequately
cement isolated and
confined. SFD
The variance approved in the PTD and described below is still valid. -bjm
A single packer will be installed to isolate the Ivishak. Torok will not be perforated at this time.
Proposed Torok
secondary injection
interval is adequately
cement isolated and
confined. SFD
13. Proposed Drilling Program
20 AAC 25.005 (c) (13)
A copy of the proposed drilling program; the drilling program must indicate if a well is
proposed for hydraulic fracturing as defined in 20 AAC 25.283(m); to seek approval to perform
hydraulic fracturing, a person must make a separate request by submitting an Application for
Sundry Approvals (Form 10-403) with the information required under 20 AAC 25.280 and 20
AAC 25.283;
The proposed drilling program to PWD-02 is listed below. Please review attached schematics
and steps highlighted in RED for proposed changes to PTD.
Proposed Drilling Program
1. Drill 20” conductor to ~128’ MD/TVD. Cement to surface. Install Cellar and landing
ring on conductor.
2. Move in / rig up Parker 272.
3. Nipple up spacer spools and diverter over the 20” conductor. Verify that the diverter
line is at least 75’ away from a potential source of ignition and beyond the drill rig
substructure.
4. Function test diverter and knife valve as per AOGCC regulations. Provide AOGCC
24hrs notice for witnessing diverter test.
5. Pick up 5-7/8” drill pipe, fill pits with spud mud and prepare for surface hole drilling.
Make up 16” motor BHA with MWD and LWD tools.
6. Spud well and drill surface hole section to TD. Perform wiper trips as required.
Circulate and condition hole to run casing. POOH and lay down BHA.
7. Run 13-3/8” 68# surface casing as per casing tally and land on pre-installed landing
ring. Circulate and condition mud prior to commencing cement job.
8. Cement 13-3/8” casing as per cement program. Verify cement returns to surface.
9. ND diverter and NU casing head and spacer spool. NU BOPE (configured from top to
bottom: annular preventor, 4-1/2” x 7” VBR, blind/shear, mud cross, 9-5/8” fixed
rams). Test rams to 4000 psi high and annular to 3000 psi high as per AOGCC
regulations. Provide AOGCC 24hrs notice for witnessing BOP test.
10. Close blind shear rams and pressure test casing to 3000 psi for 30 min.
11. Make up 12-1/4” RSS BHA with MWD and LWD tools. RIH, clean out to top of float
equipment and displace well to 12.0 ppg MOBM.
12. Drill out shoe track and 20 - 50’ of new formation. Perform leak off test.
13. Directionally drill 12-1/4” intermediate hole section to TD ~15’ TVD above the
Kuparuk C. Perform wiper trips as required. Circulate and condition hole to perform
wireline logging. POOH.
14. Rig up wireline and run open hole logging runs as per program. Log tail cement on
13-3/8” surface casing.
15. Perform 12-1/4” cleanout run to TD. Close BOP and circulate BU through choke.
POOH.
16. Run 9-5/8” production liner as per casing tally then run on 5-7/8” DP. Circulate and
condition mud prior to commencing cement job.
17. Cement 9-5/8” liner as per cement program. Monitor returns during displacement.
Bump plug and set liner hanger and liner top packer.
18. Un-sting from liner hanger, circulate out any excess cement, POOH and LD liner
running tools.
19. Run 9-5/8” tie-back string. Freeze protect the 13-3/8” x 9-5/8” annulus with diesel
and land tie-back.
20. Pressure test 13-3/8” x 9-5/8” to 3000 psi for 30 min.
21. Pressure test the 9-5/8” liner and tieback to 4000 psi for 30 min.
22. Change out lower BOP rams from 9-5/8” fixed to 4-1/2” x 7” VBR and test to 4000 psi.
23. Make up 8-1/2” RSS BHA with MWD and LWD tools. RIH, clean out to top of float
equipment and condition 12.0 ppg MOBM.
24. Drill out shoe track and 20 - 50’ of new formation. Perform formation integrity test.
25. Directionally drill 8-1/2” hole section as per well plan to TD. Perform wiper trips as
required. POOH.
26. RU and run 7” production liner as per casing tally, then run on 5” DP to TD. Circulate
and condition mud prior to commencing cement job.
27. Cement 7” liner as per cement program and displace cement with 10 ppg brine.
Monitor returns during displacement.
28. Set liner top packer, un-sting from liner hanger and displace wellbore to 10 ppg
corrosion inhibited brine. POOH and LD liner running tools.
29. Perform 7” x 9-5/8” casing test to 4000 psi for 30 min.
30. Rig up wireline and run CBL to log cement on 9-5/8” intermediate liner and 7”
production liner.
31. Temporarily shut down well ops and set retrievable bridge plug in 9-5/8” liner @
2,488’ MD. Run 4-1/2” kill string run down to 1,641’ MD. COMPLETED 5/1/2024
32. RU Doyon Rig 16 and pull 4-1/2” kill string.
33. RIH with 4” DP and retrieve bridge plug set in 9-5/8” liner.
34. Perforate Torok alternate injection zone.
35. RU and run 4-1/2” 12.6 ppf 13Cr-80 upper completion.
36. Land tubing hanger. Drop ball/rod, set 4-1/2” x 9-5/8” production packer and 4-1/2”
x 7” production packer at 4,800 psi.
37. Pressure test tubing to 4,000 psi for 30 mins MIT-T.
38. Bleed tubing pressure to 3,000 psi and hold.
39. Pressure up on the annulus to 4,000 psi for 30 mins MIT-IA. Bleed pressure on tubing
and shear valve in the sidepocket gaslift mandrel.
40. Reverse circulate freeze protect and U-Tube.
41. Install TWC, pressure test to 1,000 psi for 10 mins from below. ND BOPE, NU
Production Tree.
42. RDMO
Provide 24 hrs notice for AOGCC opportunity to witness MIT-IA to 4000 psi after the well has been warmed up and
is on line injecting. -bjm
Ivishak will be perforated post-rig and is not authorized as part of this sundry. -bjm
PWD-02 Current Well Schematic
Primary Injection Zone – Ivishak
Top: 9,004’ MD / 8,321’ TVD
Upper Confining Zone - Shublik
Top: 8,666’ MD / 7,975’ TVD
20" Insulated Conductor128' MD 20" Insulated Conductor128' MD
9-5/8" Liner Hanger and Liner Top Packer2247' MD 9-5/8" Liner Hanger and Liner Top Packer2247' MD
13-3/8" 68 ppf L-80 Surface Casing2427' MD 13-3/8" 68 ppf L-80 Surface Casing2427' MD
9-5/8" 47 ppf L-80 Tieback2252' MD 9-5/8" 47 ppf L-80 Tieback2252' MD
9-5/8" 47 ppf L-80 Intermediate Liner6815' MD 9-5/8" 47 ppf L-80 Intermediate Liner6815' MD
7" Liner Hanger and Liner Top Packer6660' MD 7" Liner Hanger and Liner Top Packer6660' MD
7" 26 ppf L-80 Production Liner9507' MD 7" 26 ppf L-80 Production Liner9507' MD
09.26.2024
Estimated 9.625" Liner TOC4100' MD Estimated 9.625" Liner TOC4100' MD
Nuiqsut
Top: 7,393’ MD / 6,701’ TVD
Base: 7,596' MD / 6,904' TVD
Alpine
Top: 7,122’ MD / 6,430’ TVD
Base: 7,343' MD / 6,651' TVD
Estimated 7" Liner TOC8340' MD
Nanushuk
Top: 4,469’ MD / 3,823’ TVD
Base: 6,307' MD / 5,615' TVD
Tuluvak
Top: 2,706’ MD / 2,460’ TVD
Base: 3,708' MD / 3,280' TVD
4-½” 12.6 ppf P-110S Kill String1682' MD 4-½” 12.6 ppf P-110S Kill String1682' MD
9-5/8" Retrievable Bridge Plug2488' MD 9-5/8" Retrievable Bridge Plug2488' MD
Alternate Injection Zone – Torok
Top: 6,334’ MD / 5,642’ TVD
PWD-02 Proposed Well Schematic
GLGL
Primary Injection Zone – Ivishak
8,923’ MD / 8,231’ TVD
Upper Confining Layer - Shublik
8,739’ MD / 8,048’ TVD
20" Insulated Conductor128' MD 20" Insulated Conductor128' MD
4-½” X-Nipple~1,514' MD 4-½” X-Nipple~1,514' MD
4-½” GLM w/ 1" Pocket~1,568' MD 4-½” GLM w/ 1" Pocket~1,568' MD
9-5/8" Liner Hanger and Liner Top Packer2247' MD 9-5/8" Liner Hanger and Liner Top Packer2247' MD
13-3/8" 68 ppf L-80 Surface Casing2427' MD 13-3/8" 68 ppf L-80 Surface Casing2427' MD
9-5/8" 47 ppf L-80 Tieback2252' MD 9-5/8" 47 ppf L-80 Tieback2252' MD
9-5/8" 47 ppf L-80 Intermediate Liner6815' MD 9-5/8" 47 ppf L-80 Intermediate Liner6815' MD
7" Liner Hanger and Liner Top Packer6660' MD 7" Liner Hanger and Liner Top Packer6660' MD
7" 26 ppf L-80 Production Liner9507' MD 7" 26 ppf L-80 Production Liner9507' MD
Perforations~9374' MD/8682' TVD -
~9401' MD/8709' TVD Perforations~9374' MD/8682' TVD -
~9401' MD/8709' TVD
4-½” X-Nipple~8825' MD 4-½” X-Nipple~8825' MD
4-½” XN-Nipple~8898' MD 4-½” XN-Nipple~8898' MD
4-½” x 7" Production Packer~8883' MD 4-½” x 7" Production Packer~8883' MD
4-½” WLEG~8908' MD 4-½” WLEG~8908' MD
10.18.2024
Estimated 7" Liner TOC8340' MD Estimated 7" Liner TOC8340' MD
Alternate Injection Zone – Torok
Top: 6,334’ MD / 5,642’ TVD
Estimated 9-5/8" Liner TOC4100' MD Estimated 9-5/8" Liner TOC4100' MD
Upper Confining Layer - Torok
Top: 5,847’ MD / 5,155’ TVD
Lower Confining Layer - HRZ
6,535’ MD / 5,843’ TVD
PWD-02 Proposed Well Schematic
GLGL
Primary Injection Zone – Ivishak
Top: 9,004’ MD / 8,321’ TVD
Upper Confining Zone Top - Shublik
8,666’ MD / 7,975’ TVD
20" Insulated Conductor128' MD 20" Insulated Conductor128' MD
4-½” X-Nipple~1,514' MD 4-½” X-Nipple~1,514' MD
4-½” GLM w/ 1" Pocket~1,568' MD 4-½” GLM w/ 1" Pocket~1,568' MD
9-5/8" Liner Hanger and Liner Top Packer2247' MD 9-5/8" Liner Hanger and Liner Top Packer2247' MD
13-3/8" 68 ppf L-80 Surface Casing2427' MD 13-3/8" 68 ppf L-80 Surface Casing2427' MD
9-5/8" 47 ppf L-80 Tieback2252' MD 9-5/8" 47 ppf L-80 Tieback2252' MD
9-5/8" 47 ppf L-80 Intermediate Liner6815' MD 9-5/8" 47 ppf L-80 Intermediate Liner6815' MD
7" Liner Hanger and Liner Top Packer6660' MD 7" Liner Hanger and Liner Top Packer6660' MD
7" 26 ppf L-80 Production Liner9507' MD 7" 26 ppf L-80 Production Liner9507' MD
Perforations~9374' MD/8682' TVD -
~9401' MD/8709' TVD Perforations~9374' MD/8682' TVD -
~9401' MD/8709' TVD
4-½” X-Nipple~8825' MD 4-½” X-Nipple~8825' MD
4-½” XN-Nipple~8898' MD 4-½” XN-Nipple~8898' MD
4-½” x 7" Production Packer~8883' MD 4-½” x 7" Production Packer~8883' MD
4-½” WLEG~8908' MD 4-½” WLEG~8908' MD
09.26.2024
Estimated 7" Liner TOC8340' MD Estimated 7" Liner TOC8340' MD
Alternate Injection Zone – Torok
Top: 6,334’ MD / 5,642’ TVD
4-½” X-Nipple~6242' MD 4-½” X-Nipple~6242' MD
Perforations~6361' MD/5669' TVD -
~6391' MD/5699' TVD Perforations~6361' MD/5669' TVD -
~6391' MD/5699' TVD
4-½” x 9-5/8" Production Packer~6300' MD 4-½” x 9-5/8" Production Packer~6300' MD
4-½” X-Nipple~6315' MD 4-½” X-Nipple~6315' MD
4-½” Sliding Sleeve~6357' MD 4-½” Sliding Sleeve~6357' MD
X
X
Superseded
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1
McLellan, Bryan J (OGC)
From:Miller, Nicklaus (Nick) <Nick.Miller@santos.com>
Sent:Friday, October 18, 2024 2:57 PM
To:McLellan, Bryan J (OGC)
Cc:Roby, David S (OGC); Davies, Stephen F (OGC); Wallace, Chris D (OGC); Dewhurst,
Andrew D (OGC); Noll, Christian (Christian)
Subject:RE: PWD-02 (PTD 216-063) RWO sundry
Attachments:PWD-02 Schematic Ivishak EPA 10.18.24.pdf
Bryan,
Updated proposed completion schematic is attached. Please let me know if you need anything else and thank you for
your time.
Nicklaus Miller
Senior CompleƟons Engineer, Alaska D&C
t: +1 (907) 646-7091 | m: +1 (406) 690-2896 | e: nick.miller@santos.com
Santos.com | Follow us on LinkedIn, Facebook and Twitter
From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Sent: Friday, October 18, 2024 9:56 AM
To: Miller, Nicklaus (Nick) <Nick.Miller@santos.com>
Cc: Roby, David S (OGC) <dave.roby@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Wallace, Chris D
(OGC) <chris.wallace@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Noll, Christian
(Christian) <Christian.Noll@santos.com>
Subject: ![EXT]: RE: PWD-02 (PTD 216-063) RWO sundry
Nick,
Thanks for the update. The new plan is in line with our regulations also, so we can easily approve that.
Please send an updated proposed completion? I’ll strike step 34 and modify step 36 from the sundry application
as shown below, and I’ll put a comment on the cover letter saying the Torok won’t be perf’d at this time and will
also modify the “Proposed plan forward”.
2
Bryan McLellan
Senior Petroleum Engineer
Alaska Oil & Gas Conservation Commission
Bryan.mclellan@alaska.gov
+1 (907) 250-9193
From: Miller, Nicklaus (Nick) <Nick.Miller@santos.com>
Sent: Friday, October 18, 2024 9:46 AM
To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Cc: Roby, David S (OGC) <dave.roby@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Wallace, Chris D
(OGC) <chris.wallace@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Noll, Christian
(Christian) <Christian.Noll@santos.com>
Subject: RE: PWD-02 (PTD 216-063) RWO sundry
Bryan,
We met with the EPA yesterday and reviewed the proposed two packer and sliding sleeve completion design. They liked
the concept but had concerns about the tubing and/or sliding sleeve developing a small leak between the packers and
unknowingly subjecting the Torok formation to higher Ivishak injection pressures. Given the time expected for EPA
approval of this two packer design change and the tight timeframe we are working under regarding rig schedule, we feel
it would be preferred to pursue the original 7” single packer design and focus our efforts on injecting into the Ivishak.
The EPA did verbally approve setting the 7” Ivishak injection packer greater than 200’ from the injection perforations in
a single packer scenario.
As expected, they will not allow comingled injection into the Torok and Ivishak and Santos fully agrees with that
approach.
3
Nicklaus Miller
Senior CompleƟons Engineer, Alaska D&C
t: +1 (907) 646-7091 | m: +1 (406) 690-2896 | e: nick.miller@santos.com
Santos.com | Follow us on LinkedIn, Facebook and Twitter
From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Sent: Thursday, October 17, 2024 8:21 AM
To: Miller, Nicklaus (Nick) <Nick.Miller@santos.com>
Cc: Roby, David S (OGC) <dave.roby@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Wallace, Chris D
(OGC) <chris.wallace@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Noll, Christian
(Christian) <Christian.Noll@santos.com>
Subject: ![EXT]: RE: PWD-02 (PTD 216-063) RWO sundry
Nick,
Does EPA allow co-mingled injection into the Torok and Ivishak?
Bryan McLellan
Senior Petroleum Engineer
Alaska Oil & Gas Conservation Commission
Bryan.mclellan@alaska.gov
+1 (907) 250-9193
From: Miller, Nicklaus (Nick) <Nick.Miller@santos.com>
Sent: Wednesday, October 16, 2024 1:20 PM
To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Cc: Roby, David S (OGC) <dave.roby@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Wallace, Chris D
(OGC) <chris.wallace@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Noll, Christian
(Christian) <Christian.Noll@santos.com>
Subject: RE: PWD-02 (PTD 216-063) RWO sundry
Bryan,
It is not our intent to comingle injection into the Torok and Ivishak. The likelihood of a tubing or sliding sleeve leak
between the 9-5/8” and 7” production packers is extremely low. Although there is no specific language regarding
comingled injection in the EPA permit, it does state we are allowed injection into two specific formations:
“The Permittee may only inject fluid into approved injection zones. The approved injection zones are defined as the
Ivishak Formation and the Lower Torok Formation”.
4
Nicklaus Miller
Senior CompleƟons Engineer, Alaska D&C
t: +1 (907) 646-7091 | m: +1 (406) 690-2896 | e: nick.miller@santos.com
Santos.com | Follow us on LinkedIn, Facebook and Twitter
From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Sent: Wednesday, October 16, 2024 12:02 PM
To: Miller, Nicklaus (Nick) <Nick.Miller@santos.com>
Cc: Roby, David S (OGC) <dave.roby@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Wallace, Chris D
(OGC) <chris.wallace@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Noll, Christian
(Christian) <Christian.Noll@santos.com>
Subject: ![EXT]: RE: PWD-02 (PTD 216-063) RWO sundry
Nick,
Does Oil Search have approval for comingled injection into both Torok and Ivishak from the EPA?
Bryan McLellan
Senior Petroleum Engineer
Alaska Oil & Gas Conservation Commission
Bryan.mclellan@alaska.gov
+1 (907) 250-9193
From: Miller, Nicklaus (Nick) <Nick.Miller@santos.com>
Sent: Tuesday, October 15, 2024 10:35 AM
To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Cc: Roby, David S (OGC) <dave.roby@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Wallace, Chris D
(OGC) <chris.wallace@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Noll, Christian
(Christian) <Christian.Noll@santos.com>
Subject: RE: PWD-02 (PTD 216-063) RWO sundry
Bryan,
Thank you for the thorough response. Please see my comments to your questions below in RED.
The CAST CBL log for the 9-5/8” cement job is attached for reference.
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.
5
Regards,
Nicklaus Miller
Senior CompleƟons Engineer, Alaska D&C
t: +1 (907) 646-7091 | m: +1 (406) 690-2896 | e: nick.miller@santos.com
Santos.com | Follow us on LinkedIn, Facebook and Twi Ʃer
From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Sent: Monday, October 14, 2024 5:46 PM
To: Miller, Nicklaus (Nick) <Nick.Miller@santos.com>
Cc: Roby, David S (OGC) <dave.roby@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Wallace, Chris D
(OGC) <chris.wallace@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Noll, Christian
(Christian) <Christian.Noll@santos.com>
Subject: ![EXT]: PWD-02 (PTD 216-063) RWO sundry
Nick,
There is an issue with the planned completion design in your sundry application for this well. The upper packer
being 2500 ft above the primary injection zone means that there is no way to know if those 2500’ of tubing or sliding
sleeve develop a leak, there’s no way to know that you are injecting out of zone. The request for variance in the
initial PTD still met the intent of this regulation, however the new variance request does not. We are discussing
this internally, but I’m not sure if that contingent injection perfs and shallow packer will be permitted. The upper 9-
5/8” packer is 61’ away from the alternate/approved Torok injection zone. In the highly unlikely event of a leaking
sliding sleeve or tubing leak in the 2,500’ section between the 7” and 9-5/8” packers, any miniscule Ʋuid volume
injected in that area would be conƱned to the Torok formation since there is adequate cement bond present to
eƯectively isolate the proposed Torok injection perforations. To conƱrm tubing integrity, a plug could be set in the
lower XN nipple on an annual basis and an MIT could be performed to eliminate any concerns of a leak in this
2,500’ section. If the sliding sleeve is found to be leaking, a blanking sleeve can be installed across the sliding
sleeve and injection into the Ivishak can be resumed.
Adequate cement is present from 5,980’ to 6,660’ per the 9-5/8” CAST CBL log (attached) run on 4/29/24. In
summary, there is 381’ of adequate cement bond above the top Torok perforation and 269’ of adequate cement
bond below the bottom Torok perforation. The Lower HRZ conƱning layer to the Torok is completely isolated by
high quality cement. Any Ʋuid injected into this wellbore will be isolated to the approved Torok or Ivishak
formation, no Ʋuid will be injected out of approved zone(s).
In the mean time, I have a few other questions about the permit application:
1. There’s no mention in the procedure of perforating the Ivishak, although the proposed diagram shows
ivishak perfs. Are you planning to submit a separate sundry for that? Ivishak perforations will be added
post rig and a separate sundry will be submitted for those operations.
2. Your plan will not pressure test the lower packer. How do you plan to prove integrity of the lower packer to
conƱne injected Ʋuids to the Ivishak? Once upper and lower packer are set, 1-7/8” standard ball and rod
will be retrieved with slickline. Lower packer will be tested by pressuring down the 4-1/2” tubing and
testing 7” packer from below to 4,000 psi. 7” casing was pressure tested to 4,000 psi on 4/29/2024.
3. What’s the maximum approved injection pressure for the well? 4,000 psi for Ivishak injection and 2,500 psi
for Torok injection.
4. Please submit the BOP stack and choke diagram for the rig you plan to use for this operation. Final
conƱguration nearing internal approval and I will send to you for review once it’s received.
6
5. Has Doyon 16 been working under continuous operation for other operators? If not, how long has it been
since it last work with the planned BOP stack. Doyon 16 has been stacked for approx. 7 years. A thorough
two week commissioning process will begin on November 1, prior to mobilizing the rig to NDB pad. A full 5
year certiƱcation, along with full Category 4 derrick inspection will be performed.
Thanks
Bryan McLellan
Senior Petroleum Engineer
Alaska Oil & Gas Conservation Commission
Bryan.mclellan@alaska.gov
+1 (907) 250-9193
Santos Ltd A.B.N. 80 007 550 923
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LETTER OF TRANSMITTAL
DETAIL
QTY DESCRIPTION
3 files
PWD-02 (50103208790000)
2024.08.15\RCA
2024.08.15\AS0550-0552 Geochemical Summary Sheets.pdf
2024.08.15\Export Database to Excel.xls
Received by:_____________________________ Date: _____________
Please sign and return one copy to:
Santos
ATTN: Shannon Koh
P.O. Box 240927, Anchorage, AK 99524-0927
907-375-4607 phone
shannon.koh@santos.com
DATE: 8/15/2024
From:
Shannon Koh
Santos
P.O. Box 240927
Anchorage, AK 99524-0927
To:
Meredith Guhl
AOGCC
333 W. 7th Avenue, Suite 100
Anchorage, AK 99501
TRANSMISSION TYPE:
܈External Request
܆Internal Request
TRANSMISSION METHOD:
܆CD ܆ Thumb Drive
܈Email ܆SharePoint/Teams
܆Hardcopy ܆Other
REASON FOR TRANSMITTAL:
܆Approved
܆Approved with Comments
܆For Approval
܈Information Only
܆For Your Review
܆For Your Use
܆To Be Returned
܆With Our Comments
܆Other
COMMENTS:
224-009
T39455
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2024.08.15 10:07:00 -08'00'
LETTER OF TRANSMITTAL
DETAIL
QTY DESCRIPTION
PWD-02 (50-103-20879-0000)
Final Well data Submittal
Details on following pages
Received by:_____________________________ Date: _____________
Please sign and return one copy to:
Santos
ATTN: Shannon Koh
P.O. Box 240927, Anchorage, AK 99524-0927
shannon.koh@santos.com
DATE: 5/31/2024
From:
Shannon Koh
Santos
P.O. Box 240927
Anchorage, AK 99524-0927
To:
Gavin Gluyas
AOGCC
333 W. 7th Avenue, Suite 100
Anchorage, AK 99501
TRANSMISSION TYPE:
܈ External Request
܆ Internal Request
TRANSMISSION METHOD:
܆ CD ܆ Thumb Drive
܆ Email ܆ SharePoint/Teams
܆ Hardcopy ܈ Other – FTP
REASON FOR TRANSMITTAL:
܆ Approved
܆ Approved with Comments
܆ For Approval
܆ Information Only
܈ For Your Review
܆ For Your Use
܆ To Be Returned
܆ With Our Comments
܆ Other
COMMENTS:
224-009
T38872
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2024.05.31 15:32:22 -08'00'
LETTER OF TRANSMITTAL
جؐؐؐAnalyses
ؒ ؤؐؐؐFluid Samples Analysis Reports
ؒ PWD-02_Fluids Sample Quality Assesment CoreLab.xlsx
ؒ PWD-02_RDT Report_4_8_Preliminary_Rev2.pdf
ؒ Santos_PWD-02_FieldSampleSummary_RDT_ALL_rev2.pdf
ؒ SANTOS_PWD-02_R1D4-R1D7_RDT_SUMMARIES_04-14-2024.pdf
ؒ SANTOS_PWD-02_R1D4-R1D7_RDT_SUMMARIES_04-14-2024.tif
ؒ
جؐؐؐCore Data - Conventional Core and Sidewall Cores Lab Studies
ؒ PWD-02_Request for Extension_30May2024.pdf
ؒ
جؐؐؐDirectional Survey
ؒ PWD-02 Definitive Compass Survey Report - NAD27.pdf
ؒ PWD-02 Definitive Compass Survey Report - NAD83.pdf
ؒ PWD-02 Definitive Survey - NAD27.txt
ؒ PWD-02 Definitive Survey - NAD83.txt
ؒ PWD-02 Plan View.pdf
ؒ PWD-02 Vertical Section View.pdf
ؒ
جؐؐؐLog Digital Data (LWD and WL)
ؒ جؐؐؐCement Evaluation Logs
ؒ ؒ جؐؐؐDigital Data
ؒ ؒ ؒ جؐؐؐIntermediate
ؒ ؒ ؒ ؒ PWD-02_CAST-CBL_28APR24_ProcessedLog.dlis
ؒ ؒ ؒ ؒ PWD-02_CAST-CBL_28APR24_ProcessedLog.las
ؒ ؒ ؒ ؒ PWD-02_CAST-CBL_28APR24_Raw.dlis
ؒ ؒ ؒ ؒ PWD-02_CAST-CBL_28APR24_Raw.las
ؒ ؒ ؒ ؒ SANTOS_PWD-02_RBT_2427-1700-04-11-2024.las
ؒ ؒ ؒ ؒ
ؒ ؒ ؒ جؐؐؐProduction
ؒ ؒ ؒ ؒ PWD-02_CAST-CBL_29APR24_ProcessedLog.dlis
ؒ ؒ ؒ ؒ PWD-02_CAST-CBL_29APR24_ProcessedLog.las
ؒ ؒ ؒ ؒ PWD-02_CAST-CBL_29APR24_Raw.dlis
ؒ ؒ ؒ ؒ PWD-02_CAST-CBL_29APR24_Raw.las
ؒ ؒ ؒ ؒ
ؒ ؒ ؒ ؤؐؐؐSurface
ؒ ؒ ؒ PWD-02_RBT_11APR24_ProcessedLog.dlis
ؒ ؒ ؒ PWD-02_RBT_11APR24_ProcessedLog.las
ؒ ؒ ؒ PWD-02_RBT_11APR24_Raw-Repeat.dlis
ؒ ؒ ؒ PWD-02_RBT_11APR24_Raw-Repeat.las
ؒ ؒ ؒ PWD-02_RBT_11APR24_Raw.dlis
ؒ ؒ ؒ PWD-02_RBT_11APR24_Raw.las
LETTER OF TRANSMITTAL
ؒ ؒ ؒ
ؒ ؒ ؤؐؐؐGraphics Data
ؒ ؒ جؐؐؐIntermediate
ؒ ؒ ؒ PWD-02_CAST-CBL_28APR24_ProcessedLog_V2.pdf
ؒ ؒ ؒ PWD-02_CAST-CBL_28APR24_ProcessedLog_V2_img.tiff
ؒ ؒ ؒ PWD-02_CAST-CBL_28APR24_Report_9.625in.pdf
ؒ ؒ ؒ
ؒ ؒ جؐؐؐProduction
ؒ ؒ ؒ PWD-02_CAST-CBL_29APR24_ProcessedLog.pdf
ؒ ؒ ؒ PWD-02_CAST-CBL_29APR24_ProcessedLog_img.tiff
ؒ ؒ ؒ PWD-02_CAST-CBL_29APR24_Report_7.0in.pdf
ؒ ؒ ؒ
ؒ ؒ ؤؐؐؐSurface
ؒ ؒ PWD-02_RBT_11APR24_ProcessedLog.pdf
ؒ ؒ PWD-02_RBT_11APR24_ProcessedLog.tif
ؒ ؒ PWD-02_RBT_11APR24_Report.pdf
ؒ ؒ SANTOS_PWD-02_RBT_2427-1700-04-11-2024.pdf
ؒ ؒ
ؒ جؐؐؐLWD
ؒ ؒ جؐؐؐDigital Data
ؒ ؒ ؒ جؐؐؐFE Data
ؒ ؒ ؒ ؒ PWD-02_LWD_GR_Res_Den_Neu_Cal_SDK_RM_9510ft.las
ؒ ؒ ؒ ؒ
ؒ ؒ ؒ جؐؐؐPWD
ؒ ؒ ؒ ؒ PWD-02_AP_R1_RM_20240401.las
ؒ ؒ ؒ ؒ PWD-02_AP_R2_RM_20240408.las
ؒ ؒ ؒ ؒ PWD-02_AP_R3_RM_20240413.las
ؒ ؒ ؒ ؒ PWD-02_AP_R4_RM_20240416.las
ؒ ؒ ؒ ؒ PWD-02_AP_R5_RM_20240422.las
ؒ ؒ ؒ ؒ PWD-02_AP_R6_RM_20240424.las
ؒ ؒ ؒ ؒ PWD-02_AP_R7_RM_20240426.las
ؒ ؒ ؒ ؒ
ؒ ؒ ؒ ؤؐؐؐVSS
ؒ ؒ ؒ PWD-02_DMD_RM_9510ft.las
ؒ ؒ ؒ PWD-02_DMT_R01_20240401.las
ؒ ؒ ؒ PWD-02_DMT_R02_20240408.las
ؒ ؒ ؒ PWD-02_DMT_R03_20240413.las
ؒ ؒ ؒ PWD-02_DMT_R04_20240416.las
ؒ ؒ ؒ PWD-02_DMT_R05_20240422.las
ؒ ؒ ؒ PWD-02_DMT_R06_20240424.las
ؒ ؒ ؒ PWD-02_DMT_R07_20240426.las
ؒ ؒ ؒ
LETTER OF TRANSMITTAL
ؒ ؒ جؐؐؐGeoScience Deliverables
ؒ ؒ ؒ جؐؐؐImageTrak
ؒ ؒ ؒ ؒ PWD-02_SANTOS_LWD_ITK-PROC_9234-9561FT.dlis
ؒ ؒ ؒ ؒ PWD-02_SANTOS_LWD_ITK-PROC_9234-9561FT_1-200FT.meta
ؒ ؒ ؒ ؒ PWD-02_SANTOS_LWD_ITK-PROC_9234-9561FT_1-200FT.pdf
ؒ ؒ ؒ ؒ PWD-02_SANTOS_LWD_ITK-PROC_9234-9561FT_1-240FT.meta
ؒ ؒ ؒ ؒ PWD-02_SANTOS_LWD_ITK-PROC_9234-9561FT_1-240FT.pdf
ؒ ؒ ؒ ؒ PWD-02_SANTOS_LWD_ITK-PROC_9234-9561FT_1-40FT.meta
ؒ ؒ ؒ ؒ PWD-02_SANTOS_LWD_ITK-PROC_9234-9561FT_1-40FT.pdf
ؒ ؒ ؒ ؒ
ؒ ؒ ؒ جؐؐؐMagTrak
ؒ ؒ ؒ ؒ PWD-02_LMR110.dlis
ؒ ؒ ؒ ؒ PWD-02_LMR110.las
ؒ ؒ ؒ ؒ PWD-02_LMR110.lst
ؒ ؒ ؒ ؒ
ؒ ؒ ؒ ؤؐؐؐSoundTrak
ؒ ؒ ؒ جؐؐؐRun 1
ؒ ؒ ؒ ؒ PWD-02_LWD_MEM_SDTK_DTC_95_2435.cgm
ؒ ؒ ؒ ؒ PWD-02_LWD_MEM_SDTK_DTC_95_2435.dlis
ؒ ؒ ؒ ؒ PWD-02_LWD_MEM_SDTK_DTC_95_2435.las
ؒ ؒ ؒ ؒ PWD-02_LWD_MEM_SDTK_DTC_95_2435.PDF
ؒ ؒ ؒ ؒ PWD-02_LWD_MEM_SDTK_DTC_95_2435_dlis.txt
ؒ ؒ ؒ ؒ PWD-02_LWD_MEM_SDTK_WIDEBED_95_2435.cgm
ؒ ؒ ؒ ؒ PWD-02_LWD_MEM_SDTK_WIDEBED_95_2435.PDF
ؒ ؒ ؒ ؒ
ؒ ؒ ؒ ؤؐؐؐRun 2
ؒ ؒ ؒ PWD-02_LWD_MEM_SDTK_DTC_2400_6820.cgm
ؒ ؒ ؒ PWD-02_LWD_MEM_SDTK_DTC_2400_6820.PDF
ؒ ؒ ؒ PWD-02_LWD_MEM_SDTK_DTC_DTS_2400_6820.dlis
ؒ ؒ ؒ PWD-02_LWD_MEM_SDTK_DTC_DTS_2400_6820.las
ؒ ؒ ؒ PWD-02_LWD_MEM_SDTK_DTC_DTS_2400_6820_dlis.txt
ؒ ؒ ؒ PWD-02_LWD_MEM_SDTK_DTS_2400_6820.cgm
ؒ ؒ ؒ PWD-02_LWD_MEM_SDTK_DTS_2400_6820.PDF
ؒ ؒ ؒ PWD-02_LWD_MEM_SDTK_WIDEBED_2400_6820.cgm
ؒ ؒ ؒ PWD-02_LWD_MEM_SDTK_WIDEBED_2400_6820.PDF
ؒ ؒ ؒ
ؒ ؒ ؤؐؐؐGraphics Images
ؒ ؒ جؐؐؐCGM
ؒ ؒ ؒ جؐؐؐFE
ؒ ؒ ؒ ؒ PWD-02_LWD_GR_Res_Den_Neu_Cal_Acoustic_RM_9510ft_2MD.cgm
ؒ ؒ ؒ ؒ PWD-02_LWD_GR_Res_Den_Neu_Cal_Acoustic_RM_9510ft_5MD.cgm
ؒ ؒ ؒ ؒ PWD-02_LWD_GR_Res_Den_Neu_Cal_RM_9510ft_2MD.cgm
LETTER OF TRANSMITTAL
ؒ ؒ ؒ ؒ PWD-02_LWD_GR_Res_Den_Neu_Cal_RM_9510ft_2TVD.cgm
ؒ ؒ ؒ ؒ PWD-02_LWD_GR_Res_Den_Neu_Cal_RM_9510ft_5MD.cgm
ؒ ؒ ؒ ؒ PWD-02_LWD_GR_Res_Den_Neu_Cal_RM_9510ft_5TVD.cgm
ؒ ؒ ؒ ؒ
ؒ ؒ ؒ جؐؐؐPWD
ؒ ؒ ؒ ؒ PWD-02_AP_RM_20240427.cgm
ؒ ؒ ؒ ؒ
ؒ ؒ ؒ ؤؐؐؐVSS
ؒ ؒ ؒ PWD-02_DMD_RM_9510ft.cgm
ؒ ؒ ؒ PWD-02_DMT_RM_20240427.cgm
ؒ ؒ ؒ
ؒ ؒ ؤؐؐؐPDF
ؒ ؒ جؐؐؐFE
ؒ ؒ ؒ PWD-02_LWD_GR_Res_Den_Neu_Cal_Acoustic_RM_9510ft_2MD.pdf
ؒ ؒ ؒ PWD-02_LWD_GR_Res_Den_Neu_Cal_Acoustic_RM_9510ft_5MD.pdf
ؒ ؒ ؒ PWD-02_LWD_GR_Res_Den_Neu_Cal_RM_9510ft_2MD.pdf
ؒ ؒ ؒ PWD-02_LWD_GR_Res_Den_Neu_Cal_RM_9510ft_2TVD.pdf
ؒ ؒ ؒ PWD-02_LWD_GR_Res_Den_Neu_Cal_RM_9510ft_5MD.pdf
ؒ ؒ ؒ PWD-02_LWD_GR_Res_Den_Neu_Cal_RM_9510ft_5TVD.pdf
ؒ ؒ ؒ
ؒ ؒ جؐؐؐPWD
ؒ ؒ ؒ PWD-02_AP_RM_20240427.pdf
ؒ ؒ ؒ
ؒ ؒ ؤؐؐؐVSS
ؒ ؒ PWD-02_DMD_RM_9510ft.pdf
ؒ ؒ PWD-02_DMT_RM_20240427.pdf
ؒ ؒ
ؒ ؤؐؐؐWireline Logging
ؒ جؐؐؐDigital Data
ؒ ؒ جؐؐؐR1D2 (STX6-ACRT)
ؒ ؒ ؒ PWD-02_HFBI_RAW_IMAGE_RUN1.dlis
ؒ ؒ ؒ SANTOS_PWD-02_R1D2_BHV_3380FT-2350FT_2IN_MD_04-08-2024.emz
ؒ ؒ ؒ SANTOS_PWD-02_R1D2_GR-RESISTIVITY_3050FT-2200_5INTVD_04-08-2024.emz
ؒ ؒ ؒ SANTOS_PWD-02_R1D2_GR-RESISTIVITY_3380FT-2400_1IN_MD_04-08-2024.emz
ؒ ؒ ؒ SANTOS_PWD-02_R1D2_GR-RESISTIVITY_3380FT-2400_5IN_MD_04-08-2024.emz
ؒ ؒ ؒ SANTOS_PWD-02_R1D2_GR-RESISTIVITY_DLIS_MD_04-08-2024.dlis
ؒ ؒ ؒ SANTOS_PWD-02_R1D2_GR-RESISTIVITY_DLIS_TVD_04-08-2024.dlis
ؒ ؒ ؒ SANTOS_PWD-02_R1D2_GR-RESISTIVITY_LAS_MD_04-08-2024.las
ؒ ؒ ؒ SANTOS_PWD-02_R1D2_GR-RESISTIVITY_LAS_TVD_04-08-2024.las
ؒ ؒ ؒ SANTOS_PWD-02_R1D2_HFBI-6_3380FT-2350FT_60IN_MD_04-08-2024.emz
ؒ ؒ ؒ
ؒ ؒ جؐؐؐR1D6 (STX6)
LETTER OF TRANSMITTAL
ؒ ؒ ؒ SANTOS_PWD-02_R1D6_BHV_DLIS_MD_04-13-2024.dlis
ؒ ؒ ؒ SANTOS_PWD-02_R1D6_BHV_LAS_MD_04-13-2024.las
ؒ ؒ ؒ SANTOS_PWD-02_R1D6_HFBI_DLIS_MD_04-13-2024.dlis
ؒ ؒ ؒ SANTOS_PWD-02_R1D6_HFBI_LAS_MD_04-13-2024.las
ؒ ؒ ؒ
ؒ ؒ ؤؐؐؐR1D7 (RDT)
ؒ ؒ SANTOS_PWD-02_R1D7_2789.8_LAS_MD.dlis
ؒ ؒ SANTOS_PWD-02_R1D7_2789.8_LAS_MD.las
ؒ ؒ SANTOS_PWD-02_R1D7_2790.8_LAS_MD.dlis
ؒ ؒ SANTOS_PWD-02_R1D7_2790.8_LAS_MD.las
ؒ ؒ SANTOS_PWD-02_R1D7_2791.8_LAS_MD.dlis
ؒ ؒ SANTOS_PWD-02_R1D7_2791.8_LAS_MD.las
ؒ ؒ SANTOS_PWD-02_R1D7_2801.8_LAS_MD.dlis
ؒ ؒ SANTOS_PWD-02_R1D7_2801.8_LAS_MD.las
ؒ ؒ SANTOS_PWD-02_R1D7_2933.7_LAS_MD.dlis
ؒ ؒ SANTOS_PWD-02_R1D7_2933.7_LAS_MD.las
ؒ ؒ SANTOS_PWD-02_R1D7_2934.6_LAS_MD.dlis
ؒ ؒ SANTOS_PWD-02_R1D7_2934.6_LAS_MD.las
ؒ ؒ SANTOS_PWD-02_R1D7_2935.7_LAS_MD.dlis
ؒ ؒ SANTOS_PWD-02_R1D7_2935.7_LAS_MD.las
ؒ ؒ SANTOS_PWD-02_R1D7_2960.6_LAS_MD.dlis
ؒ ؒ SANTOS_PWD-02_R1D7_2960.6_LAS_MD.las
ؒ ؒ SANTOS_PWD-02_R1D7_2977.71_LAS_MD.dlis
ؒ ؒ SANTOS_PWD-02_R1D7_2977.71_LAS_MD.las
ؒ ؒ SANTOS_PWD-02_R1D7_2977.7_LAS_MD.dlis
ؒ ؒ SANTOS_PWD-02_R1D7_2977.7_LAS_MD.las
ؒ ؒ SANTOS_PWD-02_R1D7_2979.71_LAS_MD.dlis
ؒ ؒ SANTOS_PWD-02_R1D7_2979.71_LAS_MD.las
ؒ ؒ SANTOS_PWD-02_R1D7_2979.7_LAS_MD.dlis
ؒ ؒ SANTOS_PWD-02_R1D7_2979.7_LAS_MD.las
ؒ ؒ SANTOS_PWD-02_R1D7_2992.7_LAS_MD.dlis
ؒ ؒ SANTOS_PWD-02_R1D7_2992.7_LAS_MD.las
ؒ ؒ SANTOS_PWD-02_R1D7_4592.5_DLIS_MD.dlis
ؒ ؒ SANTOS_PWD-02_R1D7_4592.5_LAS_MD.las
ؒ ؒ SANTOS_PWD-02_R1D7_4641_DLIS_MD.dlis
ؒ ؒ SANTOS_PWD-02_R1D7_4641_LAS_MD.las
ؒ ؒ SANTOS_PWD-02_R1D7_4683.56_DLIS_MD.dlis
ؒ ؒ SANTOS_PWD-02_R1D7_4683.56_LAS_MD.las
ؒ ؒ SANTOS_PWD-02_R1D7_4685_DLIS_MD.dlis
ؒ ؒ SANTOS_PWD-02_R1D7_4685_LAS_MD.las
ؒ ؒ SANTOS_PWD-02_R1D7_4698.63_DLIS_MD.dlis
ؒ ؒ SANTOS_PWD-02_R1D7_4698.63_LAS_MD.las
LETTER OF TRANSMITTAL
ؒ ؒ SANTOS_PWD-02_R1D7_4700_DLIS_MD.dlis
ؒ ؒ SANTOS_PWD-02_R1D7_4700_LAS_MD.las
ؒ ؒ SANTOS_PWD-02_R1D7_4774.64_DLIS_MD.dlis
ؒ ؒ SANTOS_PWD-02_R1D7_4774.64_LAS_MD.las
ؒ ؒ SANTOS_PWD-02_R1D7_4776.7_DLIS_MD.dlis
ؒ ؒ SANTOS_PWD-02_R1D7_4776.7_LAS_MD.las
ؒ ؒ SANTOS_PWD-02_R1D7_4784.65_DLIS_MD.dlis
ؒ ؒ SANTOS_PWD-02_R1D7_4784.65_LAS_MD.las
ؒ ؒ SANTOS_PWD-02_R1D7_4815.7_DLIS_MD.dlis
ؒ ؒ SANTOS_PWD-02_R1D7_4815.7_LAS_MD.las
ؒ ؒ SANTOS_PWD-02_R1D7_4815_DLIS_MD.dlis
ؒ ؒ SANTOS_PWD-02_R1D7_4815_LAS_MD.las
ؒ ؒ SANTOS_PWD-02_R1D7_4841.3_DLIS_MD.dlis
ؒ ؒ SANTOS_PWD-02_R1D7_4841.3_LAS_MD.las
ؒ ؒ SANTOS_PWD-02_R1D7_4841_DLIS_MD.dlis
ؒ ؒ SANTOS_PWD-02_R1D7_4841_LAS_MD.las
ؒ ؒ SANTOS_PWD-02_R1D7_4843_DLIS_MD.dlis
ؒ ؒ SANTOS_PWD-02_R1D7_4843_LAS_MD.las
ؒ ؒ SANTOS_PWD-02_R1D7_4844_DLIS_MD.dlis
ؒ ؒ SANTOS_PWD-02_R1D7_4844_LAS_MD.las
ؒ ؒ SANTOS_PWD-02_R1D7_4907.69_DLIS_MD.dlis
ؒ ؒ SANTOS_PWD-02_R1D7_4907.69_LAS_MD.las
ؒ ؒ SANTOS_PWD-02_R1D7_4908.72_DLIS_MD.dlis
ؒ ؒ SANTOS_PWD-02_R1D7_4908.72_LAS_MD.las
ؒ ؒ SANTOS_PWD-02_R1D7_4953.4_DLIS_MD.dlis
ؒ ؒ SANTOS_PWD-02_R1D7_4953.4_LAS_MD.las
ؒ ؒ SANTOS_PWD-02_R1D7_5004_DLIS_MD.dlis
ؒ ؒ SANTOS_PWD-02_R1D7_5004_LAS_MD.las
ؒ ؒ SANTOS_PWD-02_R1D7_5018_DLIS_MD.dlis
ؒ ؒ SANTOS_PWD-02_R1D7_5018_LAS_MD.las
ؒ ؒ SANTOS_PWD-02_R1D7_5168_DLIS_MD.dlis
ؒ ؒ SANTOS_PWD-02_R1D7_5168_LAS_MD.las
ؒ ؒ SANTOS_PWD-02_R1D7_5375_DLIS_MD.dlis
ؒ ؒ SANTOS_PWD-02_R1D7_5375_LAS_MD.las
ؒ ؒ SANTOS_PWD-02_R1D7_5380.5_DLIS_MD.dlis
ؒ ؒ SANTOS_PWD-02_R1D7_5380.5_LAS_MD.las
ؒ ؒ SANTOS_PWD-02_R1D7_5381_DLIS_MD.dlis
ؒ ؒ SANTOS_PWD-02_R1D7_5381_LAS_MD.las
ؒ ؒ SANTOS_PWD-02_R1D7_5394_DLIS_MD.dlis
ؒ ؒ SANTOS_PWD-02_R1D7_5394_LAS_MD.las
ؒ ؒ SANTOS_PWD-02_R1D7_5395_DLIS_MD.dlis
ؒ ؒ SANTOS_PWD-02_R1D7_5395_LAS_MD.las
LETTER OF TRANSMITTAL
ؒ ؒ SANTOS_PWD-02_R1D7_PUMPOUT_2802.10_LAS_MD.dlis
ؒ ؒ SANTOS_PWD-02_R1D7_PUMPOUT_2802.10_LAS_MD.las
ؒ ؒ SANTOS_PWD-02_R1D7_PUMPOUT_2980.01_LAS_MD.dlis
ؒ ؒ SANTOS_PWD-02_R1D7_PUMPOUT_2980.01_LAS_MD.las
ؒ ؒ SANTOS_PWD-02_R1D7_PUMPOUT_2993.06_LAS_MD.dlis
ؒ ؒ SANTOS_PWD-02_R1D7_PUMPOUT_2993.06_LAS_MD.las
ؒ ؒ SANTOS_PWD-02_R1D7_PUMPOUT_4640.96_LAS_MD.dlis
ؒ ؒ SANTOS_PWD-02_R1D7_PUMPOUT_4640.96_LAS_MD.las
ؒ ؒ SANTOS_PWD-02_R1D7_PUMPOUT_5394.01_LAS_MD.dlis
ؒ ؒ SANTOS_PWD-02_R1D7_PUMPOUT_5394.01_LAS_MD.las
ؒ ؒ SANTOS_PWD-02_R1D7_PUMPOUT_5395.09_LAS_MD.dlis
ؒ ؒ SANTOS_PWD-02_R1D7_PUMPOUT_5395.09_LAS_MD.las
ؒ ؒ
ؒ ؤؐؐؐGraphics Images
ؒ جؐؐؐR1D2 (STX6-ACRT)
ؒ ؒ SANTOS_PWD-02_R1D2_BHV_3380FT-2350FT_2IN_MD_04-08-2024.pdf
ؒ ؒ SANTOS_PWD-02_R1D2_BHV_3380FT-2350FT_2IN_MD_04-08-2024.tif
ؒ ؒ SANTOS_PWD-02_R1D2_GR-RESISTIVITY_3050FT-2200_5INTVD_04-08-2024.pdf
ؒ ؒ SANTOS_PWD-02_R1D2_GR-RESISTIVITY_3050FT-2200_5INTVD_04-08-2024.tif
ؒ ؒ SANTOS_PWD-02_R1D2_GR-RESISTIVITY_3380FT-2400_1IN_MD_04-08-2024.pdf
ؒ ؒ SANTOS_PWD-02_R1D2_GR-RESISTIVITY_3380FT-2400_1IN_MD_04-08-2024.tif
ؒ ؒ SANTOS_PWD-02_R1D2_GR-RESISTIVITY_3380FT-2400_5IN_MD_04-08-2024.pdf
ؒ ؒ SANTOS_PWD-02_R1D2_GR-RESISTIVITY_3380FT-2400_5IN_MD_04-08-2024.tif
ؒ ؒ SANTOS_PWD-02_R1D2_HFBI-6_3380FT-2350FT_60IN_MD_04-08-2024.pdf
ؒ ؒ SANTOS_PWD-02_R1D2_HFBI-6_3380FT-2350FT_60IN_MD_04-08-2024.tif
ؒ ؒ
ؒ جؐؐؐR1D6 (STX6)
ؒ ؒ SANTOS_PWD-02_R1D6_BHV_6000FT-4460FT_60IN_MD_04-13-2024.pdf
ؒ ؒ SANTOS_PWD-02_R1D6_BHV_6000FT-4460FT_60IN_MD_04-13-2024.tif
ؒ ؒ SANTOS_PWD-02_R1D6_HFBI-6_6000FT-4460FT_60IN_MD_04-13-2024.pdf
ؒ ؒ SANTOS_PWD-02_R1D6_HFBI-6_6000FT-4460FT_60IN_MD_04-13-2024.tif
ؒ ؒ
ؒ ؤؐؐؐR1D7 (RDT)
ؒ Santos_PWD-02_FieldSampleSummary_RDT_ALL_rev2.pdf
ؒ SANTOS_PWD-02_R1D4-R1D7_RDT_SUMMARIES_04-14-2024.pdf
ؒ SANTOS_PWD-02_R1D4-R1D7_RDT_SUMMARIES_04-14-2024.tif
ؒ
ؤؐؐؐMudlog
جؐؐؐGeological Reports (compilation in PDF)
ؒ PWD-02 Mudlogging Daily Reports compilation.pdf
ؒ
ؤؐؐؐMudlogging final data
LETTER OF TRANSMITTAL
No realtime Geoisotopes.docx
PWD-02_DrillGas_DeltaTGas_depth_9510ft MD.las
PWD-02_DrillGas_depth_9510ft MD.las
PWD-02_DrillGas_Lithology_depth_9510ft MD.las
PWD-02_GasRatioLog_2in_9510ft MD.pdf
PWD-02_GasRatioLog_5in_9510ft MD.pdf
PWD-02_GasRpt.xlsx
PWD-02_Lithology.xlsx
PWD-02_MudLog_2in_9510ft MD.pdf
PWD-02_MudLog_5in_9510ft MD.pdf
1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown
Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program
Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: ______________________
Oil Search Alaska, LLC Development Exploratory
Stratigraphic Service 6. API Number:
7. Property Designation (Lease Number):8. Well Name and Number:
9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s):
11. Present Well Condition Summary:
Total Depth measured 9,510 feet feet
true vertical 8,818 feet N/A feet
Effective Depth measured N/A feet N/A feet
true vertical N/A feet N/A feet
Perforation depth Measured depth N/A feet
True Vertical depth feet
Tubing (size, grade, measured and true vertical depth)4-1/2" P-110S 1,682' MD 1,615' TVD
Packers and SSSV (type, measured and true vertical depth)N/A
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure:
13a.
Prior to well operation:
Subsequent to operation:
13b. Pools active after work:
15. Well Class after work:
Daily Report of Well Operations Exploratory Development Service Stratigraphic
Copies of Logs and Surveys Run 16. Well Status after work: Ops Shutdown Oil Gas WDSPL
Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG
Sundry Number or N/A if C.O. Exempt:
Authorized Name and
Digital Signature with Date:Contact Name:Jacob Thompson
Contact Email:jacob.thompson@santos.com
Authorized Title:Senior Drilling Engineer Contact Phone:
1-907-854-4377
2231'
Burst Collapse
2260
4750
measured
TVD
Tie-Back
Liner
4568'
2209'
2846'
Casing
Structural
6123'
2086'
7"
6815'
2253'
9507'8815'
Plugs
Junk measured
Length
128'
2380'
128'Conductor
Surface
Intermediate
20"x34"
13-3/8"
GR-RES-NEU-DEN-Sonic, NMR, Image, Dual Induction Res, Mudlogs
GS S
5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work:
ADL 392964
Undefined Waste Disposal Pool
PWD-02
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
224-009
50-103-20879-00-00
900 E Benson Boulevard, Suite 500
Anchorage, AK 99508
3. Address:
9-5/8"
11590
9-5/8"
4750
9210
6870
11590
measured
true vertical
Packer
Representative Daily Average Production or Injection Data
Casing Pressure Tubing PressureGas-Mcf
MD
N/A
Size
128'5020
68702427'
324-261
Sr Pet Eng:
9210
Sr Pet Geo:Sr Res Eng:
WINJ WAG
Water-BblOil-Bbl
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283)
p
k
ft
t
Fra
O
s O
224
6.A
G
L
PG
,
C
Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov
e:5/30/24
By Grace Christianson at 8:16 am, May 31, 2024
RBDMS JSB 060624
11/10/2025 DSR-6/4/24
Operations Summary Report - AOGCC
Start Date End Date
Start Depth
(ftKB) Depth Prog (ft)
Dens Last
Mud (lb/gal) Summary
3/27/2024 3/28/2024 0 No accidents, incidents or spills. Complete freeze protect of Inner Annulus x Tubing on well NDBi
-030. Install and test TWC from both directions. Begin rig down operations concurrent with
installing 10k Frac Tree. Terminate control line connections through Frac Tree, pressure test tree
and flange to 5000 psi. Conduct pressure test of tubing packoff to 5000 psi. Well NDBi-030
secure at 1700 hrs. Continue with preparing for rig move.
3/28/2024 3/29/2024 0 No accidents, incidents or spills.
Complete prep for rig move. Move modules off of matting, line up for move. Conduct rig move
from NDBi-030 to well PWD-02 on NPF pad. Begin Rig up process.
3/29/2024 3/30/2024 0 10.00 No accidents, incidents or spills.
Complete Rig up process and rig acceptance, Rig accept at 0300 hrs on 3-29-2024. Install
Speed Head to Landing ring, Nipple up Diverter, function test. Load in HWDP, Drill Pipe and build
stands. Load in 13-3/8” casing. Load in drilling mud, fluid pack and pressure test lines. Calibrate
alarms.
***AOGCC Diverter Function Test.
-Conduct Rig Evac drill followed by Pre-Spud meeting.
3/30/2024 3/31/2024 125 145.00 10.00 No accidents, incidents or spills.
Build drill pipe and build Jar stand. Spud well PWD-02. Drill 16” Surface Section on Diverter per
well program to 270’ md.
3/31/2024 4/1/2024 270 1,618.00 10.10 No accidents, incidents or spills.
Drill 16” Surface Section on Diverter per well program from 270’ to 1,888’. Circulate 3x bottoms
up, persistent clay returns but volume reduced by 50%. Conduct planned wiper trip.
4/1/2024 4/2/2024 1,920 515.00 10.05 No accidents, incidents or spills.
Complete Wiper trip back to last drilled TD of 1888’. Drill ahead in 16” Surface Section on
Diverter per well program from 1888’ to TD of 2435’. Circulate 6x bottoms up from TD, shakers
cleaned up significantly. Backream to base of Permafrost, POOH on elevators to HWDP with no
issues and good displacement. Run in hole to TD, CBU x2, returns cleaned up very well. POOH
on elevators to 1055’.
4/2/2024 4/3/2024 2,435 0.00 10.00 No accidents, incidents or spills.
POH on elevators to surface, LD BHA. Rig up for running casing. Run 13-3/8” casing per
running tally. Circulate to condition wellbore while rigging up cementers.
4/3/2024 4/4/2024 2,435 0.00 10.00 No accidents, incidents or spills.
Cement 13-3/8” surface casing per plan. Pumped 420 bbls of 11.0 ppg ArcticCem lead cement
and 69 bblsType I/II Tail cement observed 253 bbls returned to surface, final pressure to 630 psi
at 3 bpm. CIP at 0415 hrs. Clean out stack. ND Diverter. Install Wellhead Adapter, test seals.
Conduct inspections per the BOP Maintenance Program requirements concurrent with ND of
Diverter and NU of BOP. Complete NU of BOP, fluid pack and function test / shell test BOP.
4/4/2024 4/5/2024 2,435 0.00 12.00 No accidents, incidents or spills. Test BOP to 250 psi low, 4,000 psi high for 5 minutes each. Test
with 5-7/8" and 9-5/8" test joints, test annular with 5-7/8" joint. Tested all 15 valves total from
midnight to 0700. Test witnessed waived by AOGCC Rep Sean Sullivan. Tested 13-3/8" casing
to 250 psi low for 5 minutes and 3,000 psi high. Pumped 4.8 bbls in and received 4.8 bbls back.
Good test. RD from test. MU 12-1/4” Autotrak Drilling BHA #2. RIH, displace 10.0 ppg Water
Base Mud to 12.0 ppg Oil Base mud. Drill out cemented shoe track to 2,364’.
4/5/2024 4/6/2024 2,435 1,235.00 11.95 No accidents, incidents or spills.
Drill out cemented shoe track and 20’ of new formation to 2,455’. Pull into casing, circulate to
condition mud surface to surface. Conduct LOT per well program at 2,427' MD (2,229' TVD),
Mud Wt 12.0 ppg with max FIT to 16.0 ppg EMW reached. Drill ahead in 12-1/4” Intermediate
hole section from 2,462' to 3,670'.
4/6/2024 4/7/2024 3,670 1,628.00 12.00 No accidents, incidents or spills.
Drill ahead from 3,670’ to 5,268’ with reduced ROP for logging Nanushuk interval in 12-1/4”
Intermediate hole section per program.
Well Name Wellbore Name PTD # Start Drill Date End Drill Date
Page 1 of 4
Well Name
PWD-02
Wellbore Name
Original Hole
PTD #
224-009
Start Drill Date
4/1/2023
End Drill Date
5/2/2024
Operations Summary Report - AOGCC
Start Date End Date
Start Depth
(ftKB) Depth Prog (ft)
Dens Last
Mud (lb/gal) Summary
4/7/2024 4/8/2024 5,298 1,429.00 12.10 No accidents, incidents or spills.
Drill ahead from 5,268’ to 6,727’ with reduced ROP for logging Nanushuk interval (to ~6,100’) in
12-1/4” Intermediate hole section per program.
4/8/2024 4/9/2024 6,727 93.00 12.25 No accidents, incidents or spills.
Drilled 12-1/4” Intermediate hole from 6,727’ to TD of 6,820’ MD (6,128’ TVD) per program,
Circulated bottoms up from 6,820’ 2 times. Conduct clean-up cycles while standing back two
stands. POH from 6,633' to surface. LD 12-1/4” Drilling BHA #2. RU and conduct wireline logging
per well program.
4/9/2024 4/10/2024 6,820 0.00 12.05 No accidents, incidents or spills.
MU StrataXaminer + Dual Induction Resistivity tools to Wireline, attempt to run to base of
Nanushuk, tag shallow at 3,382’. Obtain core samples from Tuluvak formation from 3,382’ to
2,702’ With StrataXaminer and Dual Induction Resistivity tools. Swap tools, obtain core samples
from Tuluvak interval with Xaminer 1.5” Sidewall Core tool.
4/10/2024 4/11/2024 6,820 0.00 12.15 No accidents, incidents or spills.
Complete logging runs of Upper Tuluvak interval with Xaminer 1.5” Sidewall Core tool. Swap
tools to RDT Dual Probe and Oval Probe tools and RIH on wireline to evaluate formation section
pressures and obtain samples evaluation in Tuluvak formation. Swap tools to Radial Bond Log
tool, begin to RIH on wireline.
4/11/2024 4/12/2024 6,820 0.00 12.20 No accidents, incidents or spills.
RIH with RBL tool on wireline to 13-3/8” casing shoe at 2,427’. Log 700’ interval for cement
evaluation, POH to surface and LD tools. Place wireline unit on standby. MU Autotrak cleanout
BHA, crossover to 5-7/8” drill pipe, conduct 7-day BOP function test with 5-7/8” drill pipe across
rams and Annular, Good test. RIH with cleanout BHA to TD for dedicated cleanout run, conduct
per plan. Wash and ream down small intervals to get to TD of 6,820’. CBU from TD.
4/12/2024 4/13/2024 6,820 0.00 12.00 No accidents, incidents or spills.
Complete clean up cycles while pulling stands, circulate bottoms up 3 times with diminished
formation returns throughout. POH on elevators, log two zones of interest to capture MWD data,
Backream from 4,900’ MD to 2,535’ MD.
4/13/2024 4/14/2024 6,820 0.00 12.10 No accidents, incidents or spills.
Complete planned Backream up to 13-3/8” casing shoe at 2,427’ MD. Pull into shoe with
Autotrak Cleanout BHA, circulate bottoms up, flow check well-static. RIH on elevators for
planned hole evaluation to 6,000’ MD. POH on elevators, LD Autotrak Cleanout BHA #3. MU
StrataXaminer and Dual Imaging tools onto wireline, RIH to 6,300’ MD and log up pass for sub-
surface evaluation. Pull to surface, begin swap out of tools.
4/14/2024 4/15/2024 6,820 0.00 12.10 No accidents, incidents or spills.
RIH with Xaminer sidewall coring tool on wireline line to 6,000’ MD, obtain core samples in
Nanushuk formation. POH, swap tools to RDT and RIH on wireline. Obtain pressure and fluid
samples from Nanushuk formation down to 5,375' MD.
4/15/2024 4/16/2024 6,820 0.00 12.25 No accidents, incidents or spills.
Complete wireline logging with RDT tool from 5,375’ MD to planned depth of 5,922’ MD. POH,
rig down Wireline operations. MU Autotrak Cleanout BHA #4 for dedicated cleanout run before
running 9-5/8” casing.
4/16/2024 4/17/2024 6,820 0.00 12.20 No accidents, incidents or spills.
Complete MU of Autotrak Cleanout BHA #4 for dedicated cleanout run before running 9-5/8”
casing. Conduct cleanout run to TD, circulate to condition wellbore. POH, LD BHA #4. RU 9-5/8"
casing tools. MU & RIH with 9-5/8” Intermediate Liner per running order to 1,547’ MD.
4/17/2024 4/18/2024 6,820 0.00 11.65 No accidents, incidents or spills.
Complete MU 9-5/8” Intermediate Liner per running order. Crossover and RIH on 5-7/8” Drill
Pipe / HWDP to TD. Condition wellbore
Page 2 of 4
Operations Summary Report - AOGCC
Start Date End Date
Start Depth
(ftKB) Depth Prog (ft)
Dens Last
Mud (lb/gal) Summary
4/18/2024 4/19/2024 6,820 0.00 11.75 No accidents, incidents or spills.
Cement 9-5/8" liner. Mixed and pumped 242 sxs to yield 80 bbls 13.5 ppg tuned spacer at 3.5
bpm 325 psi. Mix and pump 1488 sxs to yield 370 bbls 14.5 ppg Primary slurry at 3.5 bpm 429
psi. Switched to the rig pumps and displaced with 310 bbls 11.6 ppg MOBM, 40 bbls 12 ppg
spacer and 17 bbls 11.6 ppg MOBM. Bumped the plug with 1157 psi 564 psi over last
displacement pressure of 593 psi. Due to losses reduced the displacement rate from 4 bpm to
3.5 bpm at 77 bbls displaced and 3.5 bpm to 3.2 bpm at 118 bbls displaced and 3.2 bpm to 2.5
bpm at 213 bbls displaced. CIP at 11:30. Total 185 bbls lost during cement job. Set the top of
packer at 2247'. POOH on elevators from 2247' to suface. Test 13-5/8" BOPE to 250 psi low,
4,000 psi high for 5 minutes each. Test with 4.5”, 5” and 9-5/8” test joints, test annular with 4.5”
Joint. Test witness waived by AOGCC Rep Guy Cook.
4/19/2024 4/20/2024 6,820 0.00 11.60 No accidents, incidents or spills.
Complete BOPE test to 250 psi low, 4,000 psi high for 5 mins each. MU & RIH with Polish Mill
Assy to 2251'. Polish liner top from 2253' to 2262'. Circulate bottoms up X3 at 2240’. POOH &
LD Polish Mill Assy. RU TRS 9-5/8” casing tools. Run 9-5/8” 47# L-80 Hydrill 563 Tie-Back to
2247'. Confirm liner top intergrity by closing the annular and pressure up to 3000 psi for 10 min,
good test. Freeze protect the 9-5/8” tie-back. Close the annular and reverse in 137 bbls of diesel.
ICP= 145 PSI, FCP= 650 PSI. Land hanger in wellhead. Close annular and pressure test 13-3/8”
x 9-5/8” OA to 3,000 PSI for 30 mins. Pumped 2.5 bbls in to 3,250 PSI, bleed back 2.5 bbls.
Good test. RU & set Packoff, test packoff void to 5,000 PSI for 10 mins. Good test. Pressure test
9-5/8” Casing to 4,000 psi for 30 mins. Pumped 8.4 bbls in to 4,186 PSI. Bleed back 8.4 bbls.
Good test.
4/20/2024 4/21/2024 6,820 0.00 11.55 No accidents, incidents or spills.
Continue to pressure test casing to 4,000 PSI for 30 mins. Pumped 8.4 bbls in to 4,186 PSI.
Bleed back 8.4 bbls. Good test. Change lower rams to 4-1/2” x 7” VBR. Test 7” and 4.5” test
joints on UPR’s and LPR’s 250 PSI low / 4,000 PSI high. Make up 8.5” bit and BHA. RIH to
6736'. Drill float equipment, shoe track, 20’ of new formation to 6840'. Perform LOT, mud weight:
11.55 ppg, Pump 2.5 bbls to 1,016 psi, bleed back 2.5 bbls. LOT EMW = 14.7 ppg.
4/21/2024 4/22/2024 6,820 1,908.00 11.60 No accidents, incidents or spills.
Drill 8-1/2" Production hole from 6840’ to 8728’ (8032’ TVD).
4/22/2024 4/23/2024 8,728 328.00 11.65 No accidents, incidents or spills.
Drill 8-1/2" Production hole from 8728' to 9056’. Pump 40 bbls LCM pill. LCM pill packed off the
MWD tools. POOH to 405' md.
4/23/2024 4/24/2024 9,056 33.00 11.65 No accidents, incidents or spills.
Lay down BHA as per Baker Rep. Pick up 8.5” directional BHA and RIH to 3259'. Perform
shallow tests at 3259' and 3450'. Circulate bottoms up at the shoe. Run in hole to 8833'. Wash to
bottom from 8833' to 9056'. Drill Production hole from 9056' to 9089'.
4/24/2024 4/25/2024 9,089 208.00 11.10 No accidents, incidents or spills.
Drill 8-1/2" Production hole from 9089' to 9276'. Began taking severe losses while drilling from
9,276’ to 9,290’. Build and spot LCM pill. Pull above LCM pill and circulate. Lower mud weight
from 11.6 ppg to 11.1 ppg.
4/25/2024 4/26/2024 9,296 51.00 10.60 No accidents, incidents or spills.
Pool out of hole with 8-1/2” Autotrak assembly. Lay down and inspect BHA components. Make up
new 8-1/2” Autotrak BHA, run in hole from surface to 8000’. Circulate and lower the mud weight
from 11.6 ppg to 10.6 ppg. Wash down from 8000’ to 9296’ md at 40 ft/min. Drill 8-1/2”
Production hole from 9296’ to 9347’ (8655’ TVD). Cut and slip 102’ drilling line.
4/26/2024 4/27/2024 9,347 163.00 10.60 No accidents, incidents or spills.
Drill 8-1/2” Production hole from 9296’ to 9510’ Call TD (8,817’ TVD). Circulate 2 bottoms up to
clean the hole. Pull out of hole to surface. Lay down BHA. Rig up TRS 7" liner running
equipment. Run 7" L-80 26# Hyd 563 liner from surface to 2816'.
4/27/2024 4/28/2024 9,510 0.00 10.65 No accidents, incidents or spills.
Run 7” L-80 26# Hyd563 Liner from 2,816 to 9,507’. Circulate and condition wellbore. Conduct
cement job. Pump 125 bbls of 14.5 ppg Tail Cement. NO CEMENT Returns observed at surface.
CIP at 00:15 on 4/28/24.
Page 3 of 4
Operations Summary Report - AOGCC
Start Date End Date
Start Depth
(ftKB) Depth Prog (ft)
Dens Last
Mud (lb/gal) Summary
4/28/2024 4/29/2024 9,510 0.00 10.01 No accidents, incidents or spills.
Complete cementing 7” Liner in place. POOH. Rig up and run wireline CBL-CAST-GR logs.
Funtion test the BOP's. test passed without incident.
4/29/2024 4/30/2024 9,510 0.00 10.01 No accidents, incidents or spills.
Run in hole with the CBL-Cast-GR. Log the 7” casing from 9424’ to 6630’. Rig down E-line. Test
9-5/8” X 7” liner 4000 psi/30 min. Pressure casing up to 4270 psi bled off to 4198 psi in 30 min.
Bled off 51 psi the first 15 min and 21 psi the second 30 min. Good test. Pumped in 6.5 bbls and
bled back 6.5 bbls. Wait on plan forward. Run Baker RBP in hole on 5" DP to 1955'.
4/30/2024 5/1/2024 9,510 0.00 10.01 No accidents, incidents or spills.
Set RBP successfully at 2488’. Pressure test RBP to 250 low for 5 mins and 4000 high for 30
mins. Pressure start: 4178 psi. Pressure at15 mins: 4137 psi. Pressure at 30 mins: 4120 psi.
Pumped 2.4 bbls. Bleed back 2.4 bbls. Good test. POOH laying down 5” DP. Run 4.5” 12.6PPF
TSH 563 kill string to 1641’. Freeze protect, with 120 bbls diesel. Down IA. Install TWC in tubing
hanger Per FMC rep. Nipple down BOPE. Nipple up Tree.
5/1/2024 5/1/2024 9,510 0.00 10.01 No accidents, incidents or spills.
Continue to test tree to 5,000 PSI for 30 mins. Begin Rig Move.
**Rig release at 01:00 5/01/24
Page 4 of 4
Santos Definitive Survey Report28 May, 2024Design: PWD-02Santos NAD27 ConversionPikkaNPFPWD-02PWD-02
Project:Company:Local Co-ordinate Reference:TVD Reference:Site:Santos NAD27 ConversionPikkaNPFSantos Definitive Survey ReportWell:Wellbore:PWD-02PWD-02Survey Calculation Method:Minimum CurvatureParker 272 @ 80.8usftDesign:PWD-02Database:EDM STO AlaskaMD Reference:Parker 272 @ 80.8usftNorth Reference:Well PWD-02TrueMap System:Geo Datum:ProjectMap Zone:System Datum:US State Plane 1927 (Exact solution)NAD 1927 (NADCON CONUS)Pikka, North Slope Alaska, United StatesAlaska Zone 04Mean Sea LevelUsing Well Reference PointUsing geodetic scale factorSite Position:From:SiteLatitude:Longitude:Position Uncertainty:Northing:Easting:Grid Convergence:NPFusftMapusftusft°-0.52Slot Radius:"365,964,627.56431,473.440.970° 18' 49.449 N150° 33' 19.316 WWellWell PositionLongitude:Latitude:Easting:Northing:usft+E/-W+N/-SPosition UncertaintyusftusftusftGround Level:PWD-02usftusft0.00.05,964,627.56431,473.4434.1Wellhead Elevation:usft0.970° 18' 49.449 N150° 33' 19.316 WWellboreDeclination(°)Field Strength(nT)Sample Date Dip Angle(°)PWD-02Model NameMagneticsIFR 16/04/2024 24.76 80.60 57,284.46039134Phase:Version:Audit Notes:DesignPWD-021.0 ACTUALVertical Section:Depth From (TVD)(usft)+N/-S(usft)Direction(°)+E/-W(usft)Tie On Depth:46.788.880.00.046.728/05/2024 4:17:06PMCOMPASS 5000.17 Build 02 Page 2
Project:Company:Local Co-ordinate Reference:TVD Reference:Site:Santos NAD27 ConversionPikkaNPFSantos Definitive Survey ReportWell:Wellbore:PWD-02PWD-02Survey Calculation Method:Minimum CurvatureParker 272 @ 80.8usftDesign:PWD-02Database:EDM STO AlaskaMD Reference:Parker 272 @ 80.8usftNorth Reference:Well PWD-02TrueFrom(usft)Survey ProgramDescriptionTool NameSurvey (Wellbore)To(usft)Date28/05/2024SDI_URSA1_I4 SDI URSA-1 gyroMWD (ISCWSA Rev 4)125.0 361.801 SDI URSA GyroMWD 16in Hole <46-363_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sag387.6 2,364.502 BH OntraK 16in Hole <387-2364> (PW3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sag2,459.1 6,780.103 BH OntraK 12.25in Hole <2459-6780> 3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sag6,841.8 8,933.204 BH OntraK 8.5in Hole <6841-8933> (PW3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sag9,033.5 9,228.705 BH OntraK 8.5in Hole <9033-9228> (PW3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sag9,321.4 9,510.006 BH OntraK 8.5in Hole <9321-9510> (PWMD(usft)Inc(°)Azi (azimuth)(°)N/S(usft)E/W(usft)Northing(usft)TVDSS(usft)Easting(usft)SurveyTVD(usft)DLeg(°/100usft)V. Sec(usft)46.7 0.00 0.00 46.7 -34.1 0.0 0.0 5,964,627.56 431,473.44 0.00 0.0125.0 0.00 332.58 125.0 44.2 0.0 0.0 5,964,627.56 431,473.44 0.00 0.0128.0 0.01 218.67 128.0 47.2 0.0 0.0 5,964,627.56 431,473.44 0.19 0.020" Conductor Driven173.5 0.09 218.67 173.5 92.7 0.0 0.0 5,964,627.53 431,473.42 0.19 0.0267.1 0.35 125.16 267.1 186.3 -0.3 0.2 5,964,627.31 431,473.60 0.39 0.2361.8 2.64 90.35 361.8 281.0 -0.4 2.6 5,964,627.10 431,476.02 2.49 2.6387.6 4.02 92.06 387.5 306.7 -0.5 4.1 5,964,627.05 431,477.51 5.37 4.1420.9 5.88 88.09 420.7 339.9 -0.5 7.0 5,964,627.04 431,480.39 5.67 6.9452.2 6.33 88.65 451.8 371.0 -0.4 10.3 5,964,627.11 431,483.71 1.45 10.3482.8 7.35 89.80 482.2 401.4 -0.3 13.9 5,964,627.12 431,487.36 3.36 13.9577.3 7.91 90.01 575.8 495.0 -0.3 26.5 5,964,627.03 431,499.90 0.59 26.5673.7 9.15 90.69 671.2 590.4 -0.4 40.8 5,964,626.80 431,514.20 1.29 40.8773.4 10.44 91.04 769.4 688.6 -0.6 57.7 5,964,626.39 431,531.15 1.30 57.7870.4 11.92 89.86 864.6 783.8 -0.8 76.5 5,964,626.08 431,549.95 1.54 76.5917.0 13.17 88.96 910.1 829.3 -0.7 86.7 5,964,626.10 431,560.07 2.71 86.6Upper Schrader Bluff965.5 14.47 88.19 957.1 876.3 -0.4 98.2 5,964,626.28 431,571.65 2.71 98.21,060.0 15.55 86.63 1,048.4 967.6 0.7 122.7 5,964,627.18 431,596.10 1.22 122.728/05/2024 4:17:06PMCOMPASS 5000.17 Build 02 Page 3
Project:Company:Local Co-ordinate Reference:TVD Reference:Site:Santos NAD27 ConversionPikkaNPFSantos Definitive Survey ReportWell:Wellbore:PWD-02PWD-02Survey Calculation Method:Minimum CurvatureParker 272 @ 80.8usftDesign:PWD-02Database:EDM STO AlaskaMD Reference:Parker 272 @ 80.8usftNorth Reference:Well PWD-02TrueMD(usft)Inc(°)Azi (azimuth)(°)N/S(usft)E/W(usft)Northing(usft)TVDSS(usft)Easting(usft)SurveyTVD(usft)DLeg(°/100usft)V. Sec(usft)1,154.5 17.40 87.43 1,139.1 1,058.3 2.1 149.4 5,964,628.31 431,622.88 1.97 149.51,249.7 21.96 88.73 1,228.6 1,147.8 3.1 181.5 5,964,629.05 431,654.91 4.81 181.51,343.424.94 88.46 1,314.6 1,233.8 4.1 218.7 5,964,629.63 431,692.18 3.18 218.81,369.0 25.18 88.46 1,337.8 1,257.0 4.4 229.6 5,964,629.82 431,703.04 0.95 229.6Permafrost Base1,400.3 25.48 88.45 1,366.1 1,285.3 4.7 243.0 5,964,630.06 431,716.42 0.95 243.01,469.7 26.24 87.48 1,428.6 1,347.8 5.8 273.2 5,964,630.87 431,746.71 1.25 273.31,533.6 27.37 89.02 1,485.6 1,404.8 6.7 302.0 5,964,631.48 431,775.51 2.08 302.11,628.1 29.93 89.28 1,568.6 1,487.8 7.3 347.3 5,964,631.73 431,820.81 2.71 347.41,723.1 32.19 88.63 1,649.9 1,569.1 8.2 396.3 5,964,632.19 431,869.77 2.41 396.41,788.0 33.46 88.96 1,704.4 1,623.6 9.0 431.5 5,964,632.60 431,904.97 1.98 431.6Middle Schrader Bluff1,816.3 34.02 89.09 1,727.9 1,647.1 9.3 447.2 5,964,632.73 431,920.67 1.98 447.31,912.7 34.42 88.78 1,807.7 1,726.9 10.3 501.4 5,964,633.24 431,974.88 0.45 501.52,007.9 35.63 88.39 1,885.6 1,804.8 11.6 556.1 5,964,634.10 432,029.52 1.29 556.22,102.6 36.06 88.93 1,962.4 1,881.6 12.9 611.5 5,964,634.88 432,084.94 0.56 611.62,198.1 34.43 88.40 2,040.4 1,959.6 14.2 666.6 5,964,635.66 432,140.06 1.74 666.72,292.2 33.34 88.94 2,118.5 2,037.7 15.4 719.1 5,964,636.40 432,192.53 1.20 719.22,306.0 33.44 88.89 2,130.0 2,049.2 15.6 726.6 5,964,636.48 432,200.10 0.76 726.8MCU2,364.5 33.87 88.68 2,178.7 2,097.9 16.2 759.0 5,964,636.87 432,232.52 0.76 759.22,427.0 33.97 87.94 2,230.6 2,149.8 17.3 793.9 5,964,637.58 432,267.38 0.68 794.1Tuluvak Shale - 13-3/8" Surface Casing2,435.0 33.99 87.84 2,237.2 2,156.4 17.4 798.4 5,964,637.70 432,271.85 0.68 798.6Tuluvak Sand2,459.1 34.03 87.56 2,257.22,176.418.0 811.9 5,964,638.12 432,285.35 0.68 812.12,490.4 34.52 87.70 2,283.1 2,202.3 18.7 829.5 5,964,638.69 432,302.96 1.59 829.72,584.3 35.11 88.73 2,360.2 2,279.4 20.4 883.0 5,964,639.87 432,356.55 0.89 883.328/05/2024 4:17:06PMCOMPASS 5000.17 Build 02 Page 4
Project:Company:Local Co-ordinate Reference:TVD Reference:Site:Santos NAD27 ConversionPikkaNPFSantos Definitive Survey ReportWell:Wellbore:PWD-02PWD-02Survey Calculation Method:Minimum CurvatureParker 272 @ 80.8usftDesign:PWD-02Database:EDM STO AlaskaMD Reference:Parker 272 @ 80.8usftNorth Reference:Well PWD-02TrueMD(usft)Inc(°)Azi (azimuth)(°)N/S(usft)E/W(usft)Northing(usft)TVDSS(usft)Easting(usft)SurveyTVD(usft)DLeg(°/100usft)V. Sec(usft)2,680.2 35.11 88.90 2,438.6 2,357.8 21.5 938.2 5,964,640.50 432,411.69 0.10 938.42,706.0 35.13 88.97 2,459.7 2,378.9 21.8 953.0 5,964,640.65 432,426.52 0.16 953.3TS 7902,775.2 35.18 89.14 2,516.3 2,435.5 22.4 992.9 5,964,640.94 432,466.36 0.16 993.12,792.0 35.17 89.20 2,530.0 2,449.2 22.6 1,002.5 5,964,640.99 432,476.03 0.20 1,002.8Seabee2,869.9 35.13 89.46 2,593.7 2,512.9 23.1 1,047.4 5,964,641.11 432,520.89 0.20 1,047.62,965.0 35.10 89.15 2,671.5 2,590.7 23.8 1,102.1 5,964,641.27 432,575.56 0.19 1,102.33,058.6 35.12 89.96 2,748.1 2,667.3 24.2 1,155.9 5,964,641.20 432,629.39 0.50 1,156.13,153.2 35.09 89.34 2,825.5 2,744.7 24.5 1,210.3 5,964,641.04 432,683.83 0.38 1,210.63,248.3 35.11 88.99 2,903.2 2,822.4 25.3 1,265.0 5,964,641.33 432,738.46 0.21 1,265.23,270.0 35.12 88.79 2,921.0 2,840.2 25.6 1,277.5 5,964,641.46 432,750.96 0.54 1,277.7Nanushuk3,342.7 35.17 88.11 2,980.5 2,899.7 26.7 1,319.3 5,964,642.21 432,792.83 0.54 1,319.63,437.1 35.05 87.74 3,057.7 2,976.9 28.7 1,373.6 5,964,643.68 432,847.08 0.26 1,373.93,531.9 35.00 87.68 3,135.3 3,054.5 30.8 1,427.9 5,964,645.36 432,901.45 0.06 1,428.33,627.0 34.89 87.90 3,213.3 3,132.5 32.91,482.45,964,646.96 432,955.89 0.18 1,482.73,708.0 34.95 88.09 3,279.7 3,198.9 34.6 1,528.7 5,964,648.16 433,002.24 0.15 1,529.1NT8 MFS3,722.0 34.96 88.12 3,291.2 3,210.4 34.8 1,536.7 5,964,648.36 433,010.25 0.15 1,537.13,816.9 34.97 87.92 3,368.9 3,288.1 36.7 1,591.0 5,964,649.74 433,064.59 0.12 1,591.43,911.7 34.90 88.20 3,446.6 3,365.8 38.5 1,645.3 5,964,651.08 433,118.86 0.18 1,645.74,006.2 34.89 88.50 3,524.1 3,443.3 40.1 1,699.3 5,964,652.14 433,172.90 0.18 1,699.84,101.0 34.89 88.88 3,601.9 3,521.1 41.3 1,753.6 5,964,652.89 433,227.14 0.23 1,754.04,194.9 34.95 89.34 3,678.9 3,598.1 42.2 1,807.3 5,964,653.23 433,280.88 0.29 1,807.84,289.7 34.91 89.54 3,756.7 3,675.9 42.7 1,861.6 5,964,653.27 433,335.18 0.13 1,862.14,385.2 34.93 89.75 3,835.0 3,754.2 43.0 1,916.3 5,964,653.11 433,389.85 0.13 1,916.728/05/2024 4:17:06PMCOMPASS 5000.17 Build 02 Page 5
Project:Company:Local Co-ordinate Reference:TVD Reference:Site:Santos NAD27 ConversionPikkaNPFSantos Definitive Survey ReportWell:Wellbore:PWD-02PWD-02Survey Calculation Method:Minimum CurvatureParker 272 @ 80.8usftDesign:PWD-02Database:EDM STO AlaskaMD Reference:Parker 272 @ 80.8usftNorth Reference:Well PWD-02TrueMD(usft)Inc(°)Azi (azimuth)(°)N/S(usft)E/W(usft)Northing(usft)TVDSS(usft)Easting(usft)SurveyTVD(usft)DLeg(°/100usft)V. Sec(usft)4,469.0 34.97 89.97 3,903.6 3,822.8 43.2 1,964.3 5,964,652.79 433,437.82 0.16 1,964.7NT7 MFS4,480.0 34.97 90.00 3,912.7 3,831.9 43.2 1,970.6 5,964,652.73 433,444.13 0.16 1,971.04,555.0 34.99 90.19 3,974.1 3,893.3 43.1 2,013.6 5,964,652.27 433,487.11 0.15 2,014.0NT6 MFS4,575.0 34.99 90.24 3,990.5 3,909.7 43.0 2,025.0 5,964,652.12 433,498.59 0.15 2,025.54,670.5 34.97 90.92 4,068.7 3,987.9 42.5 2,079.8 5,964,651.07 433,553.30 0.41 2,080.24,671.0 34.97 90.92 4,069.1 3,988.3 42.5 2,080.1 5,964,651.06 433,553.60 0.00 2,080.5NT5 MFS4,764.434.74 89.48 4,145.8 4,065.0 42.32,133.45,964,650.39 433,606.97 0.91 2,133.94,772.0 34.57 89.45 4,152.0 4,071.2 42.3 2,137.7 5,964,650.39 433,611.28 2.27 2,138.2NT4 MFS4,859.6 32.59 89.14 4,225.0 4,144.2 42.9 2,186.2 5,964,650.54 433,659.70 2.27 2,186.64,952.8 29.62 89.26 4,304.8 4,224.0 43.6 2,234.3 5,964,650.77 433,707.86 3.19 2,234.85,048.6 26.68 89.23 4,389.3 4,308.5 44.2 2,279.5 5,964,650.96 433,753.06 3.07 2,280.05,143.0 24.18 89.10 4,474.5 4,393.7 44.8 2,320.0 5,964,651.17 433,793.58 2.65 2,320.55,237.1 21.24 88.60 4,561.3 4,480.5 45.5 2,356.4 5,964,651.56 433,829.89 3.13 2,356.85,332.2 18.38 87.78 4,650.8 4,570.0 46.5 2,388.6 5,964,652.27 433,862.12 3.02 2,389.05,428.4 15.53 88.65 4,742.8 4,662.0 47.4 2,416.6 5,964,652.90 433,890.15 2.98 2,417.15,522.4 12.82 89.41 4,834.0 4,753.2 47.8 2,439.6 5,964,653.10 433,913.18 2.89 2,440.15,586.0 10.80 88.34 4,896.24,815.448.1 2,452.6 5,964,653.23 433,926.18 3.20 2,453.1NT3 MFS5,618.1 9.78 87.63 4,927.7 4,846.9 48.32,458.45,964,653.37 433,931.91 3.20 2,458.85,712.5 7.09 87.04 5,021.1 4,940.3 48.9 2,472.2 5,964,653.88 433,945.75 2.85 2,472.75,807.6 3.86 90.33 5,115.8 5,035.0 49.2 2,481.3 5,964,654.08 433,954.81 3.41 2,481.85,871.0 2.23 91.36 5,179.1 5,098.3 49.1 2,484.6 5,964,654.01 433,958.18 2.58 2,485.1NT2 MFS5,901.9 1.43 92.72 5,210.0 5,129.2 49.1 2,485.6 5,964,653.97 433,959.16 2.58 2,486.128/05/2024 4:17:06PMCOMPASS 5000.17 Build 02 Page 6
Project:Company:Local Co-ordinate Reference:TVD Reference:Site:Santos NAD27 ConversionPikkaNPFSantos Definitive Survey ReportWell:Wellbore:PWD-02PWD-02Survey Calculation Method:Minimum CurvatureParker 272 @ 80.8usftDesign:PWD-02Database:EDM STO AlaskaMD Reference:Parker 272 @ 80.8usftNorth Reference:Well PWD-02TrueMD(usft)Inc(°)Azi (azimuth)(°)N/S(usft)E/W(usft)Northing(usft)TVDSS(usft)Easting(usft)SurveyTVD(usft)DLeg(°/100usft)V. Sec(usft)5,996.7 0.07 107.37 5,304.8 5,224.0 49.0 2,486.9 5,964,653.88 433,960.40 1.44 2,487.36,091.4 0.07 151.88 5,399.4 5,318.6 49.0 2,486.9 5,964,653.81 433,960.48 0.06 2,487.46,165.0 0.02 347.76 5,473.1 5,392.3 48.9 2,487.0 5,964,653.78 433,960.50 0.12 2,487.4NT1 MFS6,186.3 0.04 339.80 5,494.4 5,413.6 48.9 2,487.0 5,964,653.79 433,960.50 0.12 2,487.46,227.0 0.04 0.75 5,535.1 5,454.3 49.0 2,486.9 5,964,653.82 433,960.49 0.04 2,487.4Torok Sandstone Top6,280.0 0.04 28.49 5,588.0 5,507.2 49.0 2,487.0 5,964,653.85 433,960.50 0.04 2,487.46,307.0 0.02 72.79 5,615.1 5,534.3 49.0 2,487.0 5,964,653.86 433,960.51 0.11 2,487.4HRZ6,334.0 0.03 137.18 5,642.1 5,561.3 49.0 2,487.0 5,964,653.86 433,960.52 0.11 2,487.5Kalubik6,374.7 0.07 161.24 5,682.8 5,602.0 49.0 2,487.0 5,964,653.83 433,960.54 0.11 2,487.56,469.7 0.07 290.33 5,777.8 5,697.0 48.9 2,487.0 5,964,653.79 433,960.50 0.13 2,487.46,535.0 0.06 248.43 5,843.1 5,762.3 48.9 2,486.9 5,964,653.79 433,960.43 0.07 2,487.4LCU6,564.0 0.07 231.20 5,872.0 5,791.2 48.9 2,486.9 5,964,653.78 433,960.40 0.07 2,487.36,659.0 0.07 114.08 5,967.1 5,886.3 48.9 2,486.9 5,964,653.72 433,960.41 0.13 2,487.36,712.0 0.05 132.42 6,020.1 5,939.3 48.8 2,486.9 5,964,653.69 433,960.46 0.05 2,487.4Miluveach6,754.5 0.04 158.63 6,062.5 5,981.7 48.8 2,486.9 5,964,653.66 433,960.47 0.05 2,487.46,780.1 0.09 42.30 6,088.1 6,007.3 48.8 2,486.9 5,964,653.67 433,960.49 0.44 2,487.46,815.0 0.06 148.11 6,123.1 6,042.3 48.8 2,487.0 5,964,653.67 433,960.520.342,487.5UJU - 9-5/8" Intermediate Liner6,820.0 0.07 158.02 6,128.1 6,047.3 48.8 2,487.0 5,964,653.67 433,960.52 0.34 2,487.5Alpine A6,831.0 0.11 170.29 6,139.1 6,058.3 48.8 2,487.0 5,964,653.65 433,960.53 0.34 2,487.5Upper Kingak28/05/2024 4:17:06PMCOMPASS 5000.17 Build 02 Page 7
Project:Company:Local Co-ordinate Reference:TVD Reference:Site:Santos NAD27 ConversionPikkaNPFSantos Definitive Survey ReportWell:Wellbore:PWD-02PWD-02Survey Calculation Method:Minimum CurvatureParker 272 @ 80.8usftDesign:PWD-02Database:EDM STO AlaskaMD Reference:Parker 272 @ 80.8usftNorth Reference:Well PWD-02TrueMD(usft)Inc(°)Azi (azimuth)(°)N/S(usft)E/W(usft)Northing(usft)TVDSS(usft)Easting(usft)SurveyTVD(usft)DLeg(°/100usft)V. Sec(usft)6,837.0 0.12 174.15 6,145.1 6,064.3 48.8 2,487.0 5,964,653.64 433,960.53 0.34 2,487.5Upper Nuiqsut (Nuiqsut)6,841.8 0.14 176.48 6,149.9 6,069.1 48.8 2,487.0 5,964,653.63 433,960.53 0.34 2,487.56,937.1 0.10 86.85 6,245.2 6,164.4 48.7 2,487.1 5,964,653.52 433,960.62 0.18 2,487.57,031.9 0.09 53.53 6,340.0 6,259.2 48.7 2,487.2 5,964,653.56 433,960.76 0.06 2,487.77,117.0 0.04 13.51 6,425.1 6,344.3 48.8 2,487.3 5,964,653.63 433,960.82 0.07 2,487.8Lower Nuiqsut7,122.0 0.04 8.78 6,430.1 6,349.3 48.8 2,487.3 5,964,653.64 433,960.82 0.07 2,487.8Middle Kingak7,127.40.04 3.32 6,435.5 6,354.7 48.8 2,487.3 5,964,653.64 433,960.82 0.07 2,487.87,222.1 0.06 252.70 6,530.26,449.448.8 2,487.2 5,964,653.66 433,960.78 0.09 2,487.77,317.3 0.10 195.25 6,625.4 6,544.6 48.7 2,487.2 5,964,653.56 433,960.71 0.09 2,487.67,343.0 0.10 186.27 6,651.1 6,570.3 48.7 2,487.2 5,964,653.52 433,960.70 0.06 2,487.6Lower Kingak7,393.0 0.10 168.03 6,701.1 6,620.3 48.6 2,487.2 5,964,653.44 433,960.70 0.06 2,487.6Sag River7,412.7 0.10 161.17 6,720.8 6,640.0 48.5 2,487.2 5,964,653.41 433,960.71 0.06 2,487.67,507.0 0.10 244.48 6,815.1 6,734.3 48.4 2,487.1 5,964,653.29 433,960.66 0.14 2,487.6Shublik7,507.40.10 244.71 6,815.4 6,734.6 48.4 2,487.1 5,964,653.29 433,960.66 0.14 2,487.67,602.4 0.10 94.41 6,910.5 6,829.7 48.4 2,487.1 5,964,653.25 433,960.67 0.20 2,487.67,697.6 0.07 358.39 7,005.7 6,924.9 48.4 2,487.2 5,964,653.30 433,960.75 0.13 2,487.77,793.0 0.10 348.65 7,101.1 7,020.3 48.6 2,487.2 5,964,653.44 433,960.73 0.03 2,487.77,888.5 0.10 115.32 7,196.6 7,115.8 48.6 2,487.2 5,964,653.49 433,960.79 0.19 2,487.77,983.9 0.11 321.56 7,292.0 7,211.2 48.7 2,487.3 5,964,653.52 433,960.81 0.21 2,487.78,078.1 0.06 262.61 7,386.2 7,305.4 48.7 2,487.2 5,964,653.59 433,960.71 0.10 2,487.68,129.0 0.04 330.63 7,437.1 7,356.3 48.7 2,487.1 5,964,653.60 433,960.67 0.11 2,487.6Ivishak28/05/2024 4:17:06PMCOMPASS 5000.17 Build 02 Page 8
Project:Company:Local Co-ordinate Reference:TVD Reference:Site:Santos NAD27 ConversionPikkaNPFSantos Definitive Survey ReportWell:Wellbore:PWD-02PWD-02Survey Calculation Method:Minimum CurvatureParker 272 @ 80.8usftDesign:PWD-02Database:EDM STO AlaskaMD Reference:Parker 272 @ 80.8usftNorth Reference:Well PWD-02TrueMD(usft)Inc(°)Azi (azimuth)(°)N/S(usft)E/W(usft)Northing(usft)TVDSS(usft)Easting(usft)SurveyTVD(usft)DLeg(°/100usft)V. Sec(usft)8,173.5 0.07 14.71 7,481.6 7,400.8 48.8 2,487.1 5,964,653.64 433,960.67 0.11 2,487.68,268.4 0.07 270.80 7,576.4 7,495.6 48.8 2,487.1 5,964,653.70 433,960.63 0.12 2,487.68,363.40.07 149.90 7,671.4 7,590.6 48.8 2,487.1 5,964,653.65 433,960.60 0.13 2,487.58,401.0 0.01 58.59 7,709.1 7,628.3 48.8 2,487.1 5,964,653.63 433,960.61 0.19 2,487.5Lower Kingak8,459.1 0.11 339.05 7,767.2 7,686.4 48.8 2,487.1 5,964,653.68 433,960.60 0.19 2,487.58,554.4 0.10 107.55 7,862.5 7,781.7 48.9 2,487.1 5,964,653.74 433,960.64 0.20 2,487.68,630.0 0.04 338.45 7,938.1 7,857.3 48.9 2,487.2 5,964,653.75 433,960.70 0.17 2,487.6Sag River8,649.0 0.07 322.27 7,957.1 7,876.3 48.9 2,487.1 5,964,653.76 433,960.69 0.17 2,487.68,739.0 0.06 244.54 8,047.1 7,966.3 48.9 2,487.1 5,964,653.79 433,960.61 0.09 2,487.5Shublik8,742.9 0.06 241.69 8,051.0 7,970.2 48.9 2,487.1 5,964,653.79 433,960.61 0.09 2,487.58,838.9 0.10 195.45 8,147.0 8,066.2 48.8 2,487.0 5,964,653.68 433,960.54 0.08 2,487.58,923.0 0.09 260.81 8,231.1 8,150.3 48.7 2,486.9 5,964,653.60 433,960.45 0.12 2,487.4Ivishak8,933.2 0.10 267.15 8,241.3 8,160.5 48.7 2,486.9 5,964,653.60 433,960.44 0.12 2,487.49,033.5 0.06 85.72 8,341.6 8,260.8 48.7 2,486.9 5,964,653.60 433,960.40 0.16 2,487.39,132.4 0.07 72.31 8,440.5 8,359.7 48.8 2,487.0 5,964,653.62 433,960.51 0.02 2,487.49,228.7 0.10 215.97 8,536.8 8,456.0 48.7 2,487.0 5,964,653.57 433,960.52 0.17 2,487.49,321.40.06 164.19 8,629.5 8,548.7 48.6 2,486.9 5,964,653.46 433,960.48 0.08 2,487.49,416.1 0.03 173.80 8,724.1 8,643.3 48.5 2,487.0 5,964,653.39 433,960.50 0.03 2,487.49,484.6 0.03 191.44 8,792.7 8,711.9 48.5 2,487.0 5,964,653.35 433,960.50 0.01 2,487.49,507.0 0.03191.448,815.1 8,734.3 48.5 2,487.0 5,964,653.34 433,960.49 0.00 2,487.47" Production Liner9,510.0 0.03191.448,818.1 8,737.3 48.5 2,487.0 5,964,653.34 433,960.49 0.00 2,487.4Projection TD28/05/2024 4:17:06PMCOMPASS 5000.17 Build 02 Page 9
Project:Company:Local Co-ordinate Reference:TVD Reference:Site:Santos NAD27 ConversionPikkaNPFSantos Definitive Survey ReportWell:Wellbore:PWD-02PWD-02Survey Calculation Method:Minimum CurvatureParker 272 @ 80.8usftDesign:PWD-02Database:EDM STO AlaskaMD Reference:Parker 272 @ 80.8usftNorth Reference:Well PWD-02TrueVertical Depth(usft)Measured Depth(usft)CasingDiameter(")HoleDiameter(")NameCasing Points20" Conductor Driven128.0128.020 2013-3/8" Surface Casing2,230.62,427.013-3/8 169-5/8" Intermediate Liner6,123.16,815.09-5/8 12-1/47" Production Liner8,815.19,507.078-1/228/05/2024 4:17:06PMCOMPASS 5000.17 Build 02 Page 10
Project:Company:Local Co-ordinate Reference:TVD Reference:Site:Santos NAD27 ConversionPikkaNPFSantos Definitive Survey ReportWell:Wellbore:PWD-02PWD-02Survey Calculation Method:Minimum CurvatureParker 272 @ 80.8usftDesign:PWD-02Database:EDM STO AlaskaMD Reference:Parker 272 @ 80.8usftNorth Reference:Well PWD-02TrueMeasuredDepth(usft)VerticalDepth(usft)DipDirection(°)Name LithologyDip(°)Formations8,739.0 8,047.1 Shublik5,586.0 4,896.2 NT3 MFS7,122.0 6,430.1 Middle Kingak4,555.0 3,974.1 NT6 MFS2,792.0 2,530.0 Seabee6,837.0 6,145.1 Upper Nuiqsut (Nuiqsut)4,671.0 4,069.1 NT5 MFS7,393.0 6,701.1 Sag River6,712.0 6,020.1 Miluveach917.0 910.1 Upper Schrader Bluff3,708.0 3,279.7 NT8 MFS5,871.0 5,179.1 NT2 MFS4,469.0 3,903.6 NT7 MFS8,401.0 7,709.1 Lower Kingak6,307.0 5,615.1 HRZ6,820.0 6,128.1 Alpine A6,535.0 5,843.1 LCU8,630.0 7,938.1 Sag River1,788.0 1,704.4 Middle Schrader Bluff2,306.0 2,130.0 MCU2,427.0 2,230.6 Tuluvak Shale7,507.0 6,815.1 Shublik6,165.0 5,473.1 NT1 MFS8,129.0 7,437.1 Ivishak6,227.0 5,535.1 Torok Sandstone Top7,343.0 6,651.1 Lower Kingak7,117.0 6,425.1 Lower Nuiqsut6,815.0 6,123.1 UJU2,435.0 2,237.2 Tuluvak Sand2,706.0 2,459.7 TS 7901,369.0 1,337.8 Permafrost Base4,772.0 4,152.0 NT4 MFS3,270.0 2,921.0 Nanushuk28/05/2024 4:17:06PMCOMPASS 5000.17 Build 02 Page 11
Project:Company:Local Co-ordinate Reference:TVD Reference:Site:Santos NAD27 ConversionPikkaNPFSantos Definitive Survey ReportWell:Wellbore:PWD-02PWD-02Survey Calculation Method:Minimum CurvatureParker 272 @ 80.8usftDesign:PWD-02Database:EDM STO AlaskaMD Reference:Parker 272 @ 80.8usftNorth Reference:Well PWD-02True8,923.0 8,231.1 Ivishak6,334.0 5,642.1 Kalubik6,831.0 6,139.1 Upper KingakMeasuredDepth(usft)VerticalDepth(usft)+E/-W(usft)+N/-S(usft)Local CoordinatesCommentDesign Annotations9,510.0 8,818.1 2,487.048.5 Projection TDApproved By:Checked By:Date:28/05/2024 4:17:06PMCOMPASS 5000.17 Build 02 Page 12
PWD-02 Well Schematic
Primary Injection Zone – Ivishak
Top: 9,004’ MD / 8,321’ TVD
Upper Confining Zone - Shublik
Top: 8,666’ MD / 7,975’ TVD
20" Insulated Conductor128' MD
9-5/8" Liner Hanger and Liner Top Packer2247' MD
13-3/8" 68 ppf L-80 Surface Casing2427' MD
9-5/8" 68 ppf L-80 Tieback2252' MD
9-5/8" 47 ppf L-80 Intermediate Liner6815' MD
7" Liner Hanger and Liner Top Packer6660' MD
7" 26 ppf L-80 Production Liner9507' MD
04.30.2024
Estimated 9.625" Liner TOC4100' MD
Nuiqsut
Top: 7,393’ MD / 6,701’ TVD
Base: 7,596' MD / 6,904' TVD
Alpine
Top: 7,122’ MD / 6,430’ TVD
Base: 7,343' MD / 6,651' TVD
Estimated 7" Liner TOC8340' MD
Nanushuk
Top: 4,469’ MD / 3,823’ TVD
Base: 6,307' MD / 5,615' TVD
Tuluvak
Top: 2,706’ MD / 2,460’ TVD
Base: 3,708' MD / 3,280' TVD
4-½” 12.6 ppf P-110S Killstring1682' MD
9-5/8" Retrievable Bridge Plug2488' MD
LETTER OF TRANSMITTAL
DETAIL
QTY DESCRIPTION
8 boxes of washed and dried
cutting samples
PWD-02 (50-103-20879-0000)
Received by:_____________________________ Date: _____________
Please sign and return one copy to:
Santos
ATTN: Shannon Koh
P.O. Box 240927, Anchorage, AK 99524-0927
shannon.koh@santos.com
DATE: 5/1/2024
From:
Shannon Koh
Santos
P.O. Box 240927
Anchorage, AK 99524-0927
To:
Meredith Guhl
AOGCC
333 W. 7th Avenue, Suite 100
Anchorage, AK 99501
TRANSMISSION TYPE:
܈External Request
܆Internal Request
TRANSMISSION METHOD:
܆CD ܆ Thumb Drive
܆Email ܆SharePoint/Teams
܆Hardcopy ܈Other – Dry cutting samples
REASON FOR TRANSMITTAL:
܆Approved
܆Approved with Comments
܆For Approval
܆Information Only
܆For Your Review
܈For Your Use
܆To Be Returned
܆With Our Comments
܆Other
COMMENTS:
224-009
1882
Meredith Guhl Digitally signed by Meredith Guhl
Date: 2024.05.13 12:23:02 -08'00'
1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown
Suspend Perforate Other Stimulate Pull Tubing Change Approved Program
Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________
2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number:
Exploratory Development
3. Address:Stratigraphic Service
6. API Number:
7. If perforating: 8. Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool?N/A PWD-02
Yes No
9. Property Designation (Lease Number): 10. Field:
Pikka Undefined Waste Disposal Pool
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD):
9,510' 8,818' N/A N/A N/A N/A
Casing Collapse
Structural
Conductor 2260
Surface 4750
Intermediate 4750
Tie-Back 9210
Liner 9210
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: Yes Date: GAS WAG GSTOR SPLUG
AOGCC Representative: GINJ Op Shutdown Abandoned
Contact Name:Jacob Thompson
Contact Email:jacob.thompson@santos.com
Contact Phone: 1-907-854-4377
Authorized Title: Senior Drilling Engineer
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:
Tubing Size:
PRESENT WELL CONDITION SUMMARY
AOGCC USE ONLY
11590
Bryan McLellan
04/25/24
Tubing Grade: Tubing MD (ft):
N/A
Perforation Depth TVD (ft):
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL 392964
224-009
900 E Benson Boulevard, Suite 500, Anchorage, AK 99508 50-103-20879-00-00
Oil Search Alaska, LLC
Length Size
Proposed Pools:
P-110S
TVD Burst
1,682'
11590
MD
6870
5020
6870
128'
2231'
6123'
128'
2427'
20"x34"
13-3/8"
128'
9-5/8"4568'
2380'
N/A
2209'
7"
N/A
2086'9-5/8"
3,646
04/30/24
9507'2846'
4-1/2:
8815'
N/A
2253'
Perforation Depth MD (ft):
6815'
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
D illi E i
:5/1/24
By Grace Christianson at 1:03 pm, May 01, 2024
CDW 05/01/2024
DSR-5/1/24SFD 5/3/2024
Operations shutdownn
BJM 5/9/24
10-404
OSA to present logs and and evidence to support interpreted lack of hydrocarbon in Tuluvak and obtain
AOGCC approval to leave the Tuluvak uncemented. This evidence and approval are not required as part
of this sundry, but will be required during review of future completion or remedial cement sundry.
JLC 5/9/2024
PWD-02 Temporary Shutdown of Drilling Operations
The PWD-02 9-5/8 and 7
PWD-02 -5/8 liner and a kill
1,668
well.
7 liner. as it is
-
Current Status:
The 7 Liner was run and cement. An ultrasonic cement job was run in the 9-5/8 liner and 7 liner. E-
A 9-5/8
Proposed plan Forward
1. Install TWCV
2.
3. RDMO
5.
6.
A Wireline CAST-
9-
A Wireline CAST--
- 6,662 MD. The TOC is within the
OSA to present logs and and evidence to support interpreted lack of hydrocarbon in Tuluvak and obtain AOGCC approval to leave the Tuluvak
uncemented. This evidence and approval are not required as part of this sundry, but will be required during review of future completion sundry.
-bjm
PWD-02 Well Schematic
Primary Injection Zone Ivishak
Top: 9,004 MD / 8,321 TVD
Upper Confining Zone - Shublik
Top: 8,666 MD / 7,975 TVD
20" Insulated Conductor128' MD
9-5/8" Liner Hanger and Liner Top Packer2247' MD
13-3/8" 68 ppf L-80 Surface Casing2427' MD
9-5/8" 68 ppf L-80 Tieback2252' MD
9-5/8" 47 ppf L-80 Intermediate Liner6815' MD
7" Liner Hanger and Liner Top Packer6660' MD
7" 26 ppf L-80 Production Liner9507' MD
04.30.2024
Estimated 9.625" Liner TOC4100' MD
Nuiqsut
Top: 7,393 MD / 6,701 TVD
Base: 7,596' MD / 6,904' TVD
Alpine
Top: 7,122 MD / 6,430 TVD
Base: 7,343' MD / 6,651' TVD
Estimated 7" Liner TOC8340' MD
Nanushuk
Top: 4,469 MD / 3,823 TVD
Base: 6,307' MD / 5,615' TVD
Tuluvak
Top: 2,706 MD / 2,460 TVD
Base: 3,708' MD / 3,280' TVD
4-½ 12.6 ppf P-110S Killstring1682' MD
9-5/8" Retrievable Bridge Plug2488' MD
1
Coldiron, Samantha J (OGC)
From:McLellan, Bryan J (OGC)
Sent:Monday, April 29, 2024 6:07 PM
To:Thompson, Jacob (Jacob)
Cc:Dewhurst, Andrew D (OGC); Davies, Stephen F (OGC); Tirpack, Robert (Robert); Senden, Robert (Ty);
Kono, Randy (Randy); Brake, Jared (Jared); D&C WSS NDB; Lambe, Steven (Steven); D&C Super NDB
Subject:Re: PTD 224-009 PWD-02 Permission to Temporary Suspension RDMO
Jacob,
OSA has approval to proceed with the plan in your email below. Please submit an ops shutdown sundry
within 3 days and submit open hole logs and CBL as soon as they become available.
Regards
Bryan McLellan
Sent from my iPhone
> On Apr 29, 2024, at 5:23 PM, Thompson, Jacob (Jacob) <Jacob.Thompson@santos.com> wrote:
>
> 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.
>
>
> Bryan,
>
> The preliminary ultrasonic cement evaluation results on the 9-5/8” and 7” liners were just received and are
discussed below. Both liner cement jobs experienced losses, but had indication of good lift pressure as cement
was displaced into the annulus. OSA is requesting approval to temporarily suspend PWD-02 by setting a
retrievable bridge plug in the 9-5/8” liner and a kill string down to ~1500 MD. The attached schematic shows
the recommended temporary suspension plan as well as the current mechanical status of the well. This change
of operations is requested to adequately plan and execute a safe and appropriate remediation. The rig is
currently located at NPF. The remaining wells are on NDB and it is best practice to move the rig back to
location with frozen roads. The plan will be to return to NPF pad and rig up on PWD-02 once roads become
frozen within 1 year.
>
> Current Status:
> The 7” Liner was run and cement. An ultrasonic cement job was run in the 9-5/8” liner and 7” liner. E-line
was rigged down and the 7” liner was successfully pressure tested to 4,000 psi.
>
> Proposed plan Forward
>
> 1. Run 9-5/8” RBP to 2500’ MD.
> 2. Pressure test RBP to 4,000 psi for 30 minutes and charted as combo MIT.
> 3. Run 4-1/2” 12.6# P110S TSH563 kill string to ~1500’ MD .
> 4. Circulate down tubing 105 bbls of diesel freeze protect taking returns IA.
> 5. Install TWCV
> 6. ND BOP, NU production tree.
> 7. RDMO
> 8. Pressure test tree to 5,000 psi for 30 minutes 9. Pressure test
2
> the tubing packer off to 5,000 psi and casing hanger pack off to 3,000 psi for 10 minutes.
> 7” Liner cement evaluation results
> A Wireline CAST-M Cement Evaluation log was run in the 7” Liner. The log results showed a top of cement
at 8,340’ MD. The log shows adequate cement from 8,340’ MD – 9,423’ MD. The TOC is within the Kingak
formation and the cement isolates the target injection zone in the Ivishak from all other permeable zones. The
upper portion of the interval from 7” Liner top 6,661’ MD – 8,340’ MD shows free pipe. This leaves both
hydrocarbon bearing zones the Nuiqsut and Alpine formations uncemented. OSA is requesting a change in
operations. We would like to temporarily suspend the well so that a remediation plan can be developed,
equipment procured, and operations commenced later. This is a change to the approved sundry.
>
> 9-5/8” Liner Cement Evaluation
> A Wireline CAST-M Cement Evaluation Log was run in the 9-5/8” Liner. The log results show a TOC at
4,100’ MD. The log shows adequate cement from 4,100’ MD - 6,662’ MD. The TOC is within the Seabee
formation and the cement isolates the Nanushuk. The TOC is below the Tuluvak formation. However, the
petrophysical thin bed analysis shows that there is ~1.6’ of net pay across the Tuluvak in this area of the field.
It is OSA’s interpretation that there is no regulatory requirement for the Tuluvak to be isolated with cement
based on these results. This is for the AOGCC’s consideration and does not affect our decision to move off the
well.
>
> We are currently waiting for the retrievable bridge plug to be delivered to location and would appreciate a
prompt response with approval to move forward with the proposed plan.
>
> Thanks,
>
> [cid:image001.jpg@01DA9A41.878A4AF0]<https://gcc02.safelinks.protectio
> n.outlook.com/?url=https%3A%2F%2Fwww.santos.com%2F&data=05%7C02%7Cbrya
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> ad942f7927359ea83fcfa38%7C0%7C0%7C638500370258148062%7CUnknown%7CTWFpb
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> reserved=0>
>
> Jacob Thompson – Senior Drilling Engineer Oil Search (Alaska), LLC a
> subsidiary of Santos Limited P.O. Box 240927 Anchorage, Alaska
> 99524-0927
> o: +1 (907) 646-7079| m: +1 (907) 854-4377
> Jacob.Thompson@santos.com<mailto:Jacob.Thompson@santos.com>
>
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>
>
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> 258159351%7CUnknown%7CTWFpbGZsb3d8eyJWIjoiMC4wLjAwMDAiLCJQIjoiV2luMzIi
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> 321%7CUnknown%7CTWFpbGZsb3d8eyJWIjoiMC4wLjAwMDAiLCJQIjoiV2luMzIiLCJBTi
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>
> Santos Ltd A.B.N. 80 007 550 923
> Disclaimer: The information contained in this email is intended only
> for the use of the person(s) to whom it is addressed and may be
> confidential or contain privileged information. If you are not the
> intended recipient you are hereby notified that any perusal, use,
> distribution, copying or disclosure is strictly prohibited. If you
> have received this email in error please immediately advise us by
> return email and delete the email without making a copy. Please
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> <PWD-02_CAST-CBL_28APR24_Report_9.625in.pdf>
CAUTION: This email originated from outside the State of Alaska mail system. Do not
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From:McLellan, Bryan J (OGC)
To:Thompson, Jacob (Jacob); Dewhurst, Andrew D (OGC)
Cc:Guthrie, Eileen (Eileen); Meyer, Jeffrey (Jeff); Staudinger, Mark (Mark); Tirpack, Robert (Robert); Noll, Christian (Christian)
Subject:RE: PTD 224-009 PWD-02 Production Hydrocarbon Analysis and Cement Design Change
Date:Thursday, April 25, 2024 8:41:00 AM
Attachments:image007.png
image008.png
image009.png
Mr. Thompson
OSA has approval to make the changes to the proposed cementing plan as described below. Since the entire
7” liner will be cemented, the 7” cement job may begin before all the data listed in Andy Dewhurst’s note
has been submitted.
Regards
Bryan McLellan
Senior Petroleum Engineer
Alaska Oil & Gas Conservation Commission
Bryan.mclellan@alaska.gov
+1 (907) 250-9193
From: Thompson, Jacob (Jacob) <Jacob.Thompson@santos.com>
Sent: Tuesday, April 23, 2024 3:57 PM
To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Dewhurst, Andrew D (OGC)
<andrew.dewhurst@alaska.gov>
Cc: Guthrie, Eileen (Eileen) <Eileen.Guthrie@santos.com>; Meyer, Jeffrey (Jeff)
<Jeff.Meyer@contractor.santos.com>; Staudinger, Mark (Mark) <Mark.Staudinger@santos.com>; Tirpack,
Robert (Robert) <Robert.Tirpack@santos.com>; Noll, Christian (Christian) <Christian.Noll@santos.com>
Subject: FW: PTD 224-009 PWD-02 Production Hydrocarbon Analysis and Cement Design Change
Mr. McLellan / Dewhurst,
The Approved PTD states “Send AOGCC field-quality well log curves, directional survey, formation picks, and
evaluation of significant HC as soon as available and before cementing production liner. -A.Dewhurst
22FEB24” OSA has completed an initial evaluation of the PWD-02 8-1/2” Production Hole and concluded
that both the Alpine and Nuiqsut contain hydrocarbon accumulations requiring them to be isolated. To
accommodate this finding, the 7” production liner cement plan will be altered to fully cement the 7” Liner
with a 14.5 ppg cement 30% excess, liner lap and 200’ above the LTP, thus isolating the zones from each
other.
The interpretation best represents our current thoughts around cutoffs, and that may be subject to change.
The identified accumulation does not represent a commercial discovery but does require isolation. Attached
is a summary petrophysical interpretation based on real time log data. We have yet to TD the section,
however, the formation picks, well log curves, and directional surveys will be sent over after TD is reached.
Feel free to contact us with any questions.
Thanks,
Jacob Thompson – Senior Drilling EngineerOil Search (Alaska), LLC a subsidiary of Santos Limited
P.O. Box 240927 Anchorage, Alaska 99524-0927
o: +1 (907) 646-7079| m: +1 (907) 854-4377
Jacob.Thompson@santos.com
https://www.santos.com/
Santos Ltd A.B.N. 80 007 550 923Disclaimer: The information contained in this email is intended only for the use of the person(s) to whom it is addressed and may be confidential or
contain privileged information. If you are not the intended recipient you are hereby notified that any perusal, use, distribution, copying or disclosure isstrictly prohibited. If you have received this email in error please immediately advise us by return email and delete the email without making a copy.Please consider the environment before printing this email
1
For Internal Use only
Petrophysical Analysis 23-4-2024
PWD-02 Alpine and Nuiqsut
2
For Internal Use only Well: PWD-02
7122UJU7343Upper Kingak7393NuiqsutZone
TOPS.TOPS_1Well Schematic
Clay Volume
GR_18GAPI0 200
VSH_21V/V0 1
715072007250730073507400745075007550DEPTHFEET1 : 240
6350637564006425645064756500652565506575660066256650667567006725675067756800TVDSSFEET
Resistivity
RT_17
OHMM0.2 200
RSAND_TS_5OHMM0.2 200
RACSLM_2
0.2 200
Fm Por
WR.DTCUS/F140 40
WR.RHOB
G/C31.65 2.65
WR.NPHI
V/V0.6 0
SURVEY.INCL
DEG0 150
BH Rugosity
WR.DRHO
G/C3-0.24 0.4
WR.BITSIZEIN7 14
WR.CALI
IN7 14
wr.badhole
10 0
Fm Por
phitV/V0.5 0
PHIEV/V0.5 0
phieV/V0.5 0
PHIT
V/V0.5 0
PHIT_D
V/V0.5 0
Fm Sw
SWTV/V1 0
SWEV/V1 0
PAY_PAY
10 0
Mudlog Gas Out
C1_OUT
IN1 100000
C2_OUT
IN1 100000
C3_OUT
IN1 100000
IC4_OUT
IN1 100000
NC4_OUT
IN1 100000
IC5_OUT
IN1 100000
NC5_OUT
IN1 100000
Delta T-Gas & C1
delta
IN0 60000
DELTA_C1
IN0 60000
delta
PPM0 60000
SILTY SHALE (7090'-7120')
SILTY SHALE (7120'-7150')
SILTY SHALE (7150'-7180')
SILTY SHALE (7180'-7210')
SILTSTONE (7210'-7240')
SILTY SHALE (7240'-7270')
SILTY SHALE (7270'-7300')
SILTSTONE (7300'-7330')
SILTY SHALE (7330'-7360')
SILTSTONE (7360'-7390')
SILTSTONE (7390'-7420')
SILTSTONE (7420'-7450')
SILTSTONE (7450'-7480')
SILTSTONE (7480'-7510')
SILTSTONE (7510'-7540')
SILTSTONE (7540'-7570')
Cuttings
LITH.DESCRIPTION_9
7122UJU7343Upper Kingak7393NuiqsutZone
TOPS_ACTUAL.TOPS_ACTUAL_2Zone
TOPS.TOPS_1Zone
TOPS_ACTUAL.TOPS_ACTUAL_2Alpine A (UJU)
Top MD: 7122.0 ft MD
Base MD: 7343.0 ft MD
Top TVD: 6430.0 fttvdss
Base TVD: 6651.0 fttvdss
Net Reservoir: 21.75 ft
NTG 0.04
Avg. Net Pay Total Porosity: 0.14 v/v
Net Pay: 8.75 ft
Avg. Total Sw in Net Pay: 0.636 v/v
Cutoffs
PHIT >= 0.129 V/V
SWT <= 0.7 V/V
VSH <= 0.394 V/V
Nuiqsut
Top MD: 7393.0 ft MD
Base MD: 7596.0 ft MD
Top TVD: 6701.05 fttvdss
Base TVD: 6904.05 fttvdss
Net Reservoir: 83.5 ft
Avg. Net Pay Total Porosity: 0.131 v/v
Net Pay: 35.25 ft
Avg. Total Sw in Net Pay: 0.642 v/v
Cutoffs
PHIT >= 0.09 V/V
SWT <= 0.8 V/V
VSH <= 0.498 V/V
Alpine UJU shows a continuous
hydrocarbon column of which 8.75
feet satisfy pay criteria.
Nuiqsut shows a continuous
hydrocarbon column of which
35.25 feet satisfy pay criteria.
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From:McLellan, Bryan J (OGC)
To:Thompson, Jacob (Jacob)
Cc:Staudinger, Mark (Mark); Tirpack, Robert (Robert); Dewhurst, Andrew D (OGC)
Subject:RE: PTD 224-009 PWD-02 Reduction in 8-1/2" Production Hole Mud Weight
Date:Wednesday, April 24, 2024 10:22:00 AM
Attachments:image007.png
image008.png
image009.png
Jake,
Oilsearch has approval to reduce mud weight as described in your email below.
Regards
Bryan McLellan
Senior Petroleum Engineer
Alaska Oil & Gas Conservation Commission
Bryan.mclellan@alaska.gov
+1 (907) 250-9193
From: Thompson, Jacob (Jacob) <Jacob.Thompson@santos.com>
Sent: Wednesday, April 24, 2024 9:12 AM
To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Cc: Staudinger, Mark (Mark) <Mark.Staudinger@santos.com>; Tirpack, Robert (Robert)
<Robert.Tirpack@santos.com>
Subject: PTD 224-009 PWD-02 Reduction in 8-1/2" Production Hole Mud Weight
Bryan,
As we discussed on the phone we’ve encountered severe lost circulation in the 8-1/2” production hole
section on PWD-02. In the PTD we planned a 11.5 - 12.0 ppg mud weight range for this section. This mud
weight range was selected so that the mud weight from the previous hole section could be used. The
maximum pore pressure expected from a permeable zone in the 8-1/2” production interval is 9.82 ppg in
the Kuparuk. We would like to maintain the option of dropping our mud weight to within 75 psi overbalance
to the Kuparuk formation to aid in our lost circulation and cementing operations. This equates to a minimum
allowable mud weight of 10.1 ppg EMW. Let me know if you approve of this change.
Thanks,
Jacob Thompson – Senior Drilling Engineer
Oil Search (Alaska), LLC a subsidiary of Santos Limited
P.O. Box 240927 Anchorage, Alaska 99524-0927
o: +1 (907) 646-7079| m: +1 (907) 854-4377
Jacob.Thompson@santos.com
https://www.santos.com/
Santos Ltd A.B.N. 80 007 550 923Disclaimer: The information contained in this email is intended only for the use of the person(s) to whom it is addressed and may be confidential orcontain privileged information. If you are not the intended recipient you are hereby notified that any perusal, use, distribution, copying or disclosure is
strictly prohibited. If you have received this email in error please immediately advise us by return email and delete the email without making a copy.Please consider the environment before printing this email
CAUTION: This email originated from outside the State of Alaska mail system. Do not click
links or open attachments unless you recognize the sender and know the content is safe.
From:Lawson, Rowland (Rowland)
To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC)
Subject:BOP test Parker 272 4 19 24
Date:Friday, April 19, 2024 1:31:55 PM
Attachments:Parker 272 BOPE Test Form 4-19-24.xlsx
You don't often get email from rowland.lawson@contractor.santos.com. Learn why this is important
Please find attached the BOP test form for Parker 272 for the BOP test done on 4/19/24.
Thank you
Rowland Lawson - Day Wellsite Supervisor
Mobile: 907-268-0648
Email: rowland.lawson@contractor.santos.com
Alternate: Brian Buzby – brian.buzby@contractor.santos.com
3LNND3:'
37'
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
*All BOPE reports are due to the agency within 5 days of testing*
SSub m it to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov
Rig Owner: Rig No.:272 DATE: 4/19/24
Rig Rep.: Rig Email:
Operator:
Operator Rep.: Op. Rep Email:
Well Name:PTD #22240090 Sundry #
Operation: Drilling: X Workover: Explor.:
Test: Initial: Weekly: Bi-Weekly: X Other:
Rams:250/4000 Annular:250/4000 Valves:250/4000 MASP:3646
MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES:
Test Result/Type Test Result Quantity Test Result
Housekeeping P Well Sign P Upper Kelly 1P
Permit On Location P Hazard Sec.P Lower Kelly 1P
Standing Order Posted P Misc.NA Ball Type 1P
Test Fluid Water Inside BOP 1P
FSV Misc 0NA
BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm
Stripper 0NATrip Tank PP
Annular Preventer 1 13-5/8" 5M P Pit Level Indicators PP
#1 Rams 1 4-1/2 x 7" VBR P Flow Indicator PP
#2 Rams 1 Blind/Shear P Meth Gas Detector PP
#3 Rams 1 9 5/8" FBR P H2S Gas Detector PP
#4 Rams 0 N/A NA MS Misc 0NA
#5 Rams 0 N/A NA
#6 Rams 0 N/A NA ACCUMULATOR SYSTEM:
Choke Ln. Valves 1 3-1/8 P Time/Pressure Test Result
HCR Valves 2 3-1/8 P System Pressure (psi)2900 P
Kill Line Valves 2 2-1/16" 3-1/8"P Pressure After Closure (psi)1950 P
Check Valve 0 N/A NA 200 psi Attained (sec)21 P
BOP Misc 0 N/A NA Full Pressure Attained (sec)75 P
Blind Switch Covers: All stations Yes
CHOKE MANIFOLD:Bottle Precharge:P
Quantity Test Result Nitgn. Bottles # & psi (Avg.): 14@2200 P
No. Valves 15 P ACC Misc 0NA
Manual Chokes 1P
Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result
CH Misc 0NA Annular Preventer 27 P
#1 Rams 6 P
Coiled Tubing Only:#2 Rams 8 P
Inside Reel valves 0NA #3 Rams 6 P
#4 Rams NA NA
Test Results #5 Rams NA NA
#6 Rams NA NA
Number of Failures:0 Test Time:6.0 HCR Choke 2 P
Repair or replacement of equipment will be made within days. HCR Kill 2 P
Remarks:
AOGCC Inspection
24 hr Notice Yes Date/Time 4/16/2024 09:00
Waived By
Test Start Date/Time:4/18/2024 19:30
(date) (time)Witness
Test Finish Date/Time:4/19/2024 1:30
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Guy Cook
Parker
Tested with 4 1/2 , 5", & 9-5/8" test joints. Encountered air in the testing system after changing out test joints on Test # 7,
worked air out of testing system - Good Test
Sonny Clark
Oil Search (Alaska) LLC
Rowland Lawson
Pikka PWD-02
Test Pressure (psi):
2.seniormanager@parkerwellbor
D&C.WSS.NDB@santos.com
Form 10-424 (Revised 08/2022) 2024-0419_BOP_Parker272_Pikka_PWD-2
MEU
9
9
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From:Staudinger, Mark (Mark)
To:McLellan, Bryan J (OGC)
Subject:PWD-02 Surface Casing FIT results
Date:Friday, April 5, 2024 9:36:27 AM
Attachments:13.375. LOT & Casing test chart 4-5-24.pdf
PWD-02 13.375 FIT - Csg testing.xls
Bryan,
We successfully performed the FIT at the 13-3/8” surface shoe last night. We brought it up to 16ppg
EMW and it held solid. See attached data.
Currently drilling ahead in the 12-1/4” INT hole. Let me know if you have any questions.
Thanks,
Mark
Mark Staudinger
Senior Drilling Engineer
t: +1 (907) 375-4654 | m: +1 (520) 273-6643 | e: Mark.Staudinger@santos.com
Santos.com | Follow us on LinkedIn, Facebook and Twitter
Santos Ltd A.B.N. 80 007 550 923
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CASING AND LEAK-OFF FRACTURE TESTS
Well Name:PWD-02 Date:4/5/2024
Csg Size/Wt/Grade:13 3/8" / 68# / L-80 Supervisor:Buzby
Csg Setting Depth:2,427 TMD 2,229 TVD
Mud Weight:12 ppg Leakoff pressure =465 psi
LOT=16.0 ppg Hole Depth =2,464 md
Fluid Pumped=1.3 Bbls Volume Back =1.2 bbls
Estimated Pump Output:0.1007 Barrels/Stroke
LEAK-OFF DATA CASING TEST DATA
Enter Strokes Enter Pressure Enter Strokes Enter Pressure
Here Here Here Here
->0 0 ->0 0
->1 17 ->6 420
->2 45 ->12 848
->3 87 ->18 1221
->4 104 ->24 1600
->5 128 ->30 2000
->6 148 ->36 2385
->7 170 ->42 2840
->8 190 ->48 3250
->9 248 ->
->10 300 ->
->11 344 ->
->12 395 ->
->13 465 ->
Enter Holding Enter Holding Enter Holding
Time Here Time Here Pressure Here
->0 465 ->0 3250
->1 456 ->1 3246
->2 447 ->2 3245
->3 441 ->4 3243
->4 433 ->6 3242
->5 427 ->8 3240
->6 420 ->10 3238
->7 418 ->15 3234
->8 412 ->20 3231
->9 407 ->25 3228
->10 403 ->30 3226
-> ->
-> ->
-> ->
0
100
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400
500
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700
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2400
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2600
2700
2800
2900
3000
3100
3200
3300
3400
3500
3600
0 10 20 30 40 50 60Pressure (psi)Strokes (# of)
LEAK-OFF DATA CASING TEST DATA
0
100
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3600
0 5 10 15 20 25 30Pressure (psi)Time (Minutes)
LEAK-OFF DATA CASING TEST DATA
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From:Buzby, Brian (Brian)
To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC)
Cc:O"Neal, Robert (Rob); Staudinger, Mark (Mark)
Subject:Parker Rig 272 BOPE Test Report 4-4-24
Date:Thursday, April 4, 2024 3:29:57 PM
Attachments:BOPE Test Form 4-4-24.xlsx
You don't often get email from brian.buzby@contractor.santos.com. Learn why this is important
Gents Here is the Initial BOPE Test report for Parker Rig 272, Well # PWD-02
Thanks
Brian Buzby
Brian Buzby – Well Site Supervisor Parker 272
Oil Search (Alaska), LLC a subsidiary of Santos Limited
P.O. Box 240927 Anchorage, Alaska 99524-0927
o: +1 (907) xxx-xxx | m: +1 (907) 355-4253
Brian.buzby@contractor.santos.com
https://www.santos.com/
3LNND3:'
37'
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
*All BOPE reports are due to the agency within 5 days of testing*
SSu bmitt to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov
Rig Owner: Rig No.:272 DATE: 4/4/24
Rig Rep.: Rig Email:
Operator:
Operator Rep.: Op. Rep Email:
Well Name:PTD #2240090 Sundry #
Operation: Drilling: X Workover: Explor.:
Test: Initial: X Weekly: Bi-Weekly: X Other:
Rams:250/4000 Annular:250/4000 Valves:250/4000 MASP:3646
MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES:
Test Result/Type Test Result Quantity Test Result
Housekeeping P Well Sign P Upper Kelly 1P
Permit On Location P Hazard Sec.P Lower Kelly 1P
Standing Order Posted P Misc.NA Ball Type 1P
Test Fluid Water Inside BOP 1P
FSV Misc 0NA
BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm
Stripper 0NATrip Tank PP
Annular Preventer 1 13-5/8" 5M P Pit Level Indicators PP
#1 Rams 1 4-1/2 x 7" VBR P Flow Indicator PP
#2 Rams 1 Blind/Shear P Meth Gas Detector PP
#3 Rams 1 9 5/8" FBR P H2S Gas Detector PP
#4 Rams 0 N/A NA MS Misc 0NA
#5 Rams 0 N/A NA
#6 Rams 0 N/A NA ACCUMULATOR SYSTEM:
Choke Ln. Valves 1 3-1/8 P Time/Pressure Test Result
HCR Valves 2 3-1/8 P System Pressure (psi)2950 P
Kill Line Valves 2 2-1/16" 3-1/8"P Pressure After Closure (psi)2075 P
Check Valve 0 N/A NA 200 psi Attained (sec)18 P
BOP Misc 0 N/A NA Full Pressure Attained (sec)67 P
Blind Switch Covers: All stations Yes
CHOKE MANIFOLD:Bottle Precharge:P
Quantity Test Result Nitgn. Bottles # & psi (Avg.): 14@2250 P
No. Valves 15 P ACC Misc 0NA
Manual Chokes 1FP
Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result
CH Misc 0NA Annular Preventer 12 P
#1 Rams 6 P
Coiled Tubing Only:#2 Rams 6 P
Inside Reel valves 0NA #3 Rams 6 P
#4 Rams NA NA
Test Results #5 Rams NA NA
#6 Rams NA NA
Number of Failures:1 Test Time:7.0 HCR Choke 2 P
Repair or replacement of equipment will be made within days. HCR Kill 2 P
Remarks:
AOGCC Inspection
24 hr Notice Yes Date/Time 4/2/2024 06:10
Waived By
Test Start Date/Time:4/4/2024 0:00
(date) (time)Witness
Test Finish Date/Time:4/4/2024 7:00
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Sully Sullivan
Parker
Tested with 5-7/8" and 9-5/8" test joints. Needle valve (test equipment) leaked on test #4. Test #9b Choke Valve B had loose
seat, Tightened and passed.
Sonny Clark
Oil Search (Alaska) LLC
Brian Buzby
Pikka PWD-02
Test Pressure (psi):
72.seniormanager@parkerwellbore
D&C.WSS.NDB@santos.com
Form 10-424 (Revised 08/2022) 2024-0404_BOP_Parker272_Pikka_PWD-2
9
9
9
9
9
9 9 99
9
9
9
9
-5HJJ
est #9b Choke Valve B had loose
seat
FP
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
DIVERTER Test Report for:
Reviewed By:
P.I. Suprv
Comm ________PIKKA PWD-02
JBR 05/21/2024
MISC. INSPECTIONS:
GAS DETECTORS:
DIVERTER SYSTEM:MUD SYSTEM:
P/F
P/F
P/F
Alarm
Visual Alarm
Visual Time/Pressure
Size
Number of Failures:0
Remarks:Tests were done with 5-7/8" Test joint.
TEST DATA
Rig Rep:Pat LynchOperator:Oil Search (Alaska), LLC Operator Rep:Rob O'Neal/ Rowland Larso
Contractor/Rig No.:Parker 272 PTD#:2240090 DATE:3/29/2024
Well Class:DEV Inspection No:divJDH240329140940
Inspector Josh Hunt
Inspector
Insp Source
Related Insp No:
Test Time:3
ACCUMULATOR SYSTEM:
Location Gen.:P
Housekeeping:P
Warning Sign P
24 hr Notice:P
Well Sign:P
Drlg. Rig.P
Misc:NA
Methane:P P
Hydrogen Sulfide:P P
Gas Detectors Misc:0 NA
Designed to Avoid Freeze-up?P
Remote Operated Diverter?P
No Threaded Connections?P
Vent line Below Diverter?P
Diverter Size:21.25
Hole Size:16
Vent Line(s) Size:16 P
Vent Line(s) Length:40.25 P
Closest Ignition Source:90 P
Outlet from Rig Substructure:51 P
Vent Line(s) Anchored:P
Turns Targeted / Long Radius:NA
Divert Valve(s) Full Opening:P
Valve(s) Auto & Simultaneous:
Annular Closed Time:26 P
Knife Valve Open Time:23 P
Diverter Misc:0 NA
Systems Pressure:P2950
Pressure After Closure:P2300
200 psi Recharge Time:P17
Full Recharge Time:P40
Nitrogen Bottles (Number of):P14
Avg. Pressure:P2250
Accumulator Misc:NA0
P PTrip Tank:
P PMud Pits:
P PFlow Monitor:
0 NAMud System Misc:
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From:McLellan, Bryan J (OGC)
To:Staudinger, Mark (Mark)
Cc:Kono, Randy (Randy)
Subject:RE: PWD-02 PTD (224-009) proposed changes
Date:Tuesday, March 5, 2024 3:27:00 PM
Mark,
Oilsearch has approval for all of the changes requested below.
Regards
Bryan McLellan
Senior Petroleum Engineer
Alaska Oil & Gas Conservation Commission
Bryan.mclellan@alaska.gov
+1 (907) 250-9193
From: Staudinger, Mark (Mark) <Mark.Staudinger@santos.com>
Sent: Friday, March 1, 2024 12:21 PM
To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Cc: Kono, Randy (Randy) <Randy.Kono@santos.com>
Subject: PWD-02 PTD (224-009) proposed changes
Bryan,
We’ve been doing some optimization on the plan that was submitted in the original PTD application
for PWD-02 (PTD# 224-009). I’ve attached a revised schematic and proposed operation summary.
The Ops summary has all of the changes made in red. I’d like to highlight the following:
1. Production Packer Placement – reference well schematic. We’ve looked at this in more
detail, and would like to request to move the packer up to the base of the confining layer, as
proposed in the schematic. We would like to target a packer placement within the lowest
100’ MD of the upper confining layer. This will allow even further flexibility of future
perforation intervals in the injection interval. Note that our proposed initial perforation
interval has also been roughly defined and is only about 30’ long – to be finalized by as-drilled
log data.
2. Ram Configuration – reference revised ops summary. Propose to keep our current BOP
configuration in the INT section due to the MASP <3000 psi as an efficiency.
3. Circulation through Choke - reference revised ops summary. Noted a planned circulation
through the choke during the 12-1/4” cleanout run after wireline logging operations, just in
case the fluid sampling brought in any gas in the wellbore.
4. Displacement to 10 ppg brine - reference revised ops summary. Planning to displace the 7”
cement job with 10 ppg brine. This will eliminate the need for a future cleanout run, as well
as the complications of picking up 4” DP. We need to be at 10 ppg to maintain our
overbalance since the 7” liner will not be tested at that point.
Please let me know if you have any questions on the above changes and if you are good with them.
Thanks,
Mark
Mark Staudinger
Senior Drilling Engineer
t: +1 (907) 375-4654 | m: +1 (520) 273-6643 | e: Mark.Staudinger@santos.com
Santos.com | Follow us on LinkedIn, Facebook and Twitter
Santos Ltd A.B.N. 80 007 550 923Disclaimer: The information contained in this email is intended only for the use of the person(s) to whom it is addressed and may beconfidential or contain privileged information. If you are not the intended recipient you are hereby notified that any perusal, use,
distribution, copying or disclosure is strictly prohibited. If you have received this email in error please immediately advise us by return
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13. Proposed Drilling Program
20 AAC 25.005 (c) (13)
A copy of the proposed drilling program; the drilling program must indicate if a well is
proposed for hydraulic fracturing as defined in 20 AAC 25.283(m); to seek approval to perform
hydraulic fracturing, a person must make a separate request by submitting an Application for
Sundry Approvals (Form 10-403) with the information required under 20 AAC 25.280 and 20
AAC 25.283;
The proposed drilling program to PWD-02 is listed below. Please refer to Attachments 8-10
for a Well Schematic, Formation Evaluation Program, and Wellhead & Tree Diagram.
Proposed Drilling Program
1. Drill 20” conductor to ~128’ MD/TVD. Cement to surface. Install Cellar and landing
ring on conductor.
2. Move in / rig up Parker 272.
3. Nipple up spacer spools and diverter over the 20” conductor. Verify that the diverter
line is at least 75’ away from a potential source of ignition and beyond the drill rig
substructure.
4. Function test diverter and knife valve as per AOGCC regulations. Provide AOGCC
24hrs notice for witnessing diverter test.
5. Pick up 5-7/8” drill pipe, fill pits with spud mud and prepare for surface hole drilling.
Make up 16” motor BHA with MWD and LWD tools.
6. Spud well and drill surface hole section to TD. Perform wiper trips as required.
Circulate and condition hole to run casing. POOH and lay down BHA.
7. Run 13-3/8” 68# surface casing as per casing tally and land on pre-installed landing
ring. Circulate and condition mud prior to commencing cement job.
8. Cement 13-3/8” casing as per cement program. Verify cement returns to surface.
9. ND diverter and NU casing head and spacer spool. NU BOPE (configured from top to
bottom: annular preventor, 4-1/2” x 7” VBR, blind/shear, mud cross, 9-5/8” fixed
rams). Test rams to 4000 psi high and annular to 3000 psi high as per AOGCC
regulations. Provide AOGCC 24hrs notice for witnessing BOP test.
10. Close blind shear rams and pressure test casing to 3000 psi for 30 min.
11. Make up 12-1/4” RSS BHA with MWD and LWD tools. RIH, clean out to top of float
equipment and displace well to 12.0 ppg MOBM.
12. Drill out shoe track and 20 - 50’ of new formation. Perform leak off test.
13. Directionally drill 12-1/4” intermediate hole section to TD ~15’ TVD above the
Kuparuk C. Perform wiper trips as required. Circulate and condition hole to perform
wireline logging. POOH.
14. Rig up wireline and run open hole logging runs as per program. Log tail cement on
13-3/8” surface casing.
15. Perform 12-1/4” cleanout run to TD. Close BOP and circulate BU through choke.
POOH.
16. Change out lower BOP rams from 4-1/2” x 7” VBR to 9-5/8” fixed and test to 4000 psi.
17. Run 9-5/8” production liner as per casing tally then run on 5-7/8” DP. Circulate and
condition mud prior to commencing cement job.
18. Cement 9-5/8” liner as per cement program. Monitor returns during displacement.
Bump plug and set liner hanger and liner top packer.
19. Un-sting from liner hanger, circulate out any excess cement, POOH and LD liner
running tools.
20. Run 9-5/8” tie-back string. Freeze protect the 13-3/8” x 9-5/8” annulus with diesel
and land tie-back.
21. Pressure test 13-3/8” x 9-5/8” to 3000 psi for 30 min.
22. Pressure test the 9-5/8” liner and tieback to 4000 psi for 30 min.
23. Change out lower BOP rams from 9-5/8” fixed to 4-1/2” x 7” VBR and test to 4000 psi.
24. Make up 8-1/2” RSS BHA with MWD and LWD tools. RIH, clean out to top of float
equipment and condition 12.0 ppg MOBM.
25. Drill out shoe track and 20 - 50’ of new formation. Perform formation integrity test.
26. Directionally drill 8-1/2” hole section as per well plan to TD. Perform wiper trips as
required. POOH.
27. RU and run 7” production liner as per casing tally, then run on 5” DP to TD. Circulate
and condition mud prior to commencing cement job.
28. Cement 7” liner as per cement program and displace cement with 10 ppg brine.
Monitor returns during displacement.
29. Set liner top packer, un-sting from liner hanger and displace wellbore to 10 ppg
corrosion inhibited brine. POOH and LD liner running tools.
30. Perform cleanout run on 5” x 4” DP and clean out to top of float equipment. Perform
7” x 9-5/8” casing test to 4000 psi for 30 min.
31. Displace well to 9.40 ppg NaCl Corrosion Inhibited Brine and POOH.
32. Rig up wireline and run CBL to log cement on 9-5/8” intermediate liner and 7”
production liner.
33. RU and run 4-1/2” 12.6 ppf 13Cr-80 upper completion.
34. Land tubing hanger, drop ball and set the 4-1/2” x 7” production packer at 4,800 psi.
35. Pressure test tubing to 4,000 psi for 30 mins MIT-T.
36. Bleed tubing pressure to 3,000 psi and hold.
37. Pressure up on the annulus to 4,000 psi for 30 mins MIT-IA. Bleed pressure on tubing
and shear valve in the sidepocket gaslift mandrel.
38. Reverse circulate freeze protect and U-Tube.
39. Install TWC, pressure test to 1,000 psi for 10 mins from below. ND BOPE, NU
Production Tree.
40. RDMO
PWD-02 Proposed Well Schematic
GL
Primary Injection Zone – Ivishak
9,178’ MD / 8,480’ TVD
To 9,802’ MD / 9,104’ TVD
Upper Confining Zone Top
8,826’ MD / 8,128’ TVD
20" Insulated Conductor128' MD
4-½” X-Nipple~1,514' MD
4-½” GLM w/ 1" Pocket~1,568' MD
9-5/8" Liner Hanger and Liner Top Packer2375' MD
13-3/8" 68 ppf L-80 Surface Casing2525' MD
9-5/8" 68 ppf L-80 Tieback2375' MD
9-5/8" 47 ppf L-80 Intermediate Liner6972' MD
7" Liner Hanger and Liner Top Packer6822' MD
7" 26 ppf L-80 Production Liner9952' MD
Perforations~9501' MD/8803' TVD -
~9531' MD/8833' TVD
4-½” X-Nipple~9107 MD
4-½” XN-Nipple~9178' MD
4-½” x 7" Production Packer~9163' MD
4-½” WLEG~9188' MD
03.01.2024
Estimated 7" Liner TOC8678' MD
Alaska Oil and Gas
Conservation Commission
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
Mark Staudinger
Senior Drilling Engineer
Oil Search Alaska, LLC
900 E Benson Boulevard
Anchorage, AK, 99508
Re: Pikka Field, Undefined Waste Disposal Pool, PWD-02
Oil Search Alaska, LLC
Permit to Drill Number: 224-009
Surface Location: 4,899’ FSL, 4,267’ FEL, Sec 14, T11N, R6E, UM
Bottomhole Location: 4,959’ FSL, 1,780’ FEL, Sec 14, T11N, R6E, UM
DearMr. Staudinger:
Enclosedis the approvedapplication forthe permit to drill the above referenced well.
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run must
be submitted to the AOGCCwithin 90days after completion,suspension, or abandonment of thiswell, or
within 90days ofacquisition of the data, whichever occurs first.Proposed dryditch sampleinterval from
Attachment9 accepted with modification of Ivishak (notto exceed 30').
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 AOGCCreserves the right to withdraw the permit in
the event it was erroneously issued.
Operations must be conducted in accordance with AS 31.05 andTitle 20, Chapter 25 of the Alaska
Administrative Code unless the AOGCCspecifically authorizes a variance. Failure to comply with an
applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC
order, or the terms and conditions of this permit may result in the revocation or suspension of the permit.
Sincerely,
Jessie Chmielowski
Commissioner
DATED this 26 day ofFebruary 2024.
Jessie L.
Chmielowski
Digitally signed by
Jessie L. Chmielowski
Date: 2024.02.26
15:49:16 -09'00'
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: 9952'TVD:9254'
4a. Location of Well (Governmental Section): 7. Property Designation:
Surface:
Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date:
03/25/24
Total Depth: 9. Acres in Property: 14. Distance to Nearest Property:
1780'
4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 81.1 15. Distance to Nearest Well Open
Surface: x- 431473 y- 5,964,626.99 Zone- 4 34.1 (GL) to Same Pool:N/A
16. Deviated wells: Kickoff depth: 350 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035)
Maximum Hole Angle: 34.93 degrees Downhole: Surface:
Hole Casing Weight Grade Coupling Length MD TVD MD TVD
42” 20”x34” 215# X-52 Welded 80’ Surface
Surface 127' 127'
16” 13-3/8” 68# L-80 BTC 2,525’ Surface
Surface 2,525' 2,306'
12-1/4” 9-5/8” 47# L-80 HYD 563 4,597’ 2,375’
2,183' 6,972' 6,274'
Tie Back 9-5/8” 47# L-80 HYD 563 2,375’ Surface
Surface 2,375' 2,183'
8-1/2” 7” 26# L-80 HYD 563 3,130’ 6,822’
6,124' 9,952' 9,254'
Tubing 4-1/2” 12.6# 13Cr-80 JFE Bear ~9,250’ Surface
Surface ~9,250' 8,551'
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: Mark Staudinger
Mark Staudinger Contact Email:mark.staudinger@santos.com
Senior Drilling Engineer Contact Phone:1-520-273-6643
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):
Perforation Depth MD (ft):
N/A
N/A
Effect. Depth MD (ft): Effect. Depth TVD (ft):
Authorized Title:
Authorized Signature:
Production
Liner
Intermediate
Authorized Name:
Conductor/Structural
LengthCasing Cement Volume MDSize
Plugs (measured):
(including stage data)
Grouted to surface
See attachment 6
See attachment 6
2,560 acres
18. Casing Program: Top - Setting Depth - BottomSpecifications
4571
Total Depth MD (ft): Total Depth TVD (ft):
OO 197
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
20 AAC 25.005
See attachment 6
36
4,959’ FSL, 1,780’ FEL, Sec 14, T11N, R6E, UM
4,959’ FSL, 1,780’ FEL, Sec 14, T11N, R6E, UM
19-003
900 E Benson Boulevard, Anchorage, AK 99508
Oil Search Alaska, LLC
4,899’ FSL, 4,267’ FEL, Sec 14, T11N, R6E, UM ADL 392964
PWD-02
NPF Pad
Cement Quantity, c.f. or sacks
Commission Use Only
See cover letter for other
requirements.
s N
ype of W
l
1b
S
Class:
os N s No
s N o
s h
s
s
h
h
o
well is p
G
S
S
20 A
SS
S
s No s No
G
S
G
E
S
s No
s
Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g)
g
Senior Drilling Engineer
February 13, 2024
By Grace Christianson at 12:37 pm, Feb 13, 2024
50-103-20879-00-00
~11,600' to WD-02
Pikka, Undefined Waste
Disposal Pool
Send AOGCC field-quality well log curves, directional survey, formation picks, and evaluation of significant HC as soon as available and before cementing production liner. -A.Dewhurst 22FEB24
224-009
A.Dewhurst 22FEB24
Pikka
Submit FIT/LOT results within 48 hrs of performing tests.
If LOT < 13 ppg, notify AOGCC and gain approval before drilling production hole.
BJM 2/23/24
Submit CBL log of production liner and intermediate liner to AOGCC.
Provide 24 hrs notice for AOGCC opportunity to witness MIT-IA.
Variance to 20 AAC 25.412(b), to allow injection packer to be set >200' above top perf is approved. See conditions listed in section 15.
BOP test to 4000 psi. Annular test to 3000 psi
DSR02/13/24*&:
Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski
Date: 2024.02.26 15:49:02 -09'00'
02/26/24
02/26/24
Page 1 of 1
13 February 2024
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, AK 99501
Re: Application for Permit to Drill
Oil Search (Alaska), LLC, a subsidiary of Santos Limited
PWD-02
Dear Sir / Madam,
Oil Search (Alaska), LLC hereby applies for a Permit to Drill an onshore service well from the NPF
production pad on the North Slope of Alaska. PWD-02 is planned to be an Underground Injection
Control (UIC) Class 1 Disposal Well targeting the Ivishak Formation. The approximate spud date
is anticipated to be March 25th, 2024. Parker Rig 272 will be used to drill this well.
The 16” surface hole will TD above the Tuluvak sand and then 13-3/8” casing will be set and
cemented.
The 12-1/4” intermediate hole will be drilled to above the top of the Kuparuk C formation at an
inclination of 35 degrees, dropping to 0 degrees at TD. A 9-5/8” liner will be set and cemented
from TD to secure the shoe and cover the Torok, Nanushuk and Tuluvak sands. A 9-5/8” tieback
will be run to the top of the 9-5/8” liner.
The vertical 8-1/2” production hole will be drilled and set in the top of the Kavik formation. A 7”
production liner will be run and cemented from TD to secure the shoe and cover the injection zone
(Ivishak formation). The well will be completed with a 4-1/2” tubing upper completion string with
a production packer.
Please find enclosed for your review Form 10-401 Permit to Drill with a supporting Application for
Permit to Drill containing information as required by 20 AAC 25.005.
If there are any questions and/or additional information desired, please contact me at (520) 273-
6643 or Mark.Staudinger@Santos.com.
Respectfully,
Mark Staudinger
Senior Drilling Engineer
Oil Search (Alaska), LLC
Enclosures:
Form 10-401 Permit to Drill
Application for Permit to Drill
Respectfully,
Application for Permit to Drill
PWD-02 Well
Table of Contents
1. Well Name.................................................................................................................................3
2. Location Summary.....................................................................................................................3
3. Blowout Prevention Equipment Information..............................................................................4
4. Drilling Hazards Information......................................................................................................5
5. Procedure for Conducting Formation Integrity Tests..................................................................6
6. Casing and Cementing Program.................................................................................................6
7. Diverter System Information......................................................................................................7
8. Drilling Fluid Program................................................................................................................7
9. Abnormally Pressured Formation Information...........................................................................8
10. Seismic Analysis.......................................................................................................................8
11. Seabed Condition Analysis.......................................................................................................8
12. Evidence of Bonding................................................................................................................8
13. Proposed Drilling Program.......................................................................................................9
14. Discussion of Mud and Cuttings Disposal and Annular Disposal..............................................11
15. Proposed Variance Request...................................................................................................11
Attachments............................................................................................................................................13
Attachment 1: Location Maps......................................................................................................14
Attachment 2: Directional Plan....................................................................................................15
Attachment 3: BOPE Equipment..................................................................................................1 6
Attachment 4: Drilling Hazards....................................................................................................17
Attachment 5: Leak Off Test Procedure.......................................................................................19
Attachment 6: Cement Summary.................................................................................................20
Attachment 7: Prognosed Formation Tops...................................................................................22
Attachment 8: Well Schematic.....................................................................................................23
Attachment 9: Formation Evaluation Program.............................................................................24
Attachment 10: Wellhead & Tree Diagram ..................................................................................25
Attachment 11: Injector Area of Review......................................................................................26
An application for a Permit to Drill must be accompanied by each of the following items, except for an
item already on file with the commission and identified in the application.
1. Well Name
20 AAC 25.005 (f)
Each well must be identified by a unique name designated by the operator and a unique API
number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well
branches, each branch must similarly be identified by a unique name and API number by adding a
suffix to the name designated for the well by the operator and to the number assigned to the well
by the commission.
The well for which this application for a Permit to Drill is submitted is designated as PWD-02. This
will be an Underground Injection Control (UIC) Class 1 Disposal Well.
2. Location Summary
20 AAC 25.005 (c) (2)
A plat identifying the property and the property's owners and showing:
(A)the coordinates of the proposed location of the well at the surface, at the top of each objective
formation, and at total depth, referenced to governmental section lines;
(B) the coordinates of the proposed location of the well at the surface, referenced to the state plane
coordinate system for this state as maintained by the National Geodetic Survey in the National
Oceanic and Atmospheric Administration;
(C)the proposed depth of the well at the top of each objective formation and at total depth
Location at Surface
Reference to Government Section Lines 4,899’ FSL, 4,267’ FEL, Sec 14, T11N, R6E, UM
NAD 27 Coordinate System N 5,964,627 E 431,473
Rig KB Elevation 47’ above GL
Ground Level 34.1’ above MSL
Location at Top of Productive Interval
Reference to Government Section Lines 4,959’ FSL, 1,780’ FEL, Sec 14, T11N, R6E, UM
NAD 27 Coordinate System N 5,964,661’ E 433,961’
Measured Depth, Rig KB (MD) 9,178’
Total Vertical Depth, Rig KB (TVD) 8,480’
Total vertical Depth, Subsea (TVDSS) 8,399’
Location at Bottom of Productive Interval
Reference to Government Section Lines 4,959’ FSL, 1,780’ FEL, Sec 14, T11N, R6E, UM
NAD 27 Coordinate System N 5,964,661’ E 433,961’
Measured Depth, Rig KB (MD) 9,802’
Total Vertical Depth, Rig KB (TVD) 9,104’
Total vertical Depth, Subsea (TVDSS) 9,023’
(D) other information required by 20 AAC 25.050(b);
20 AAC 25.050 (b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form
10-401) must:
(1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including
all adjacent wellbores within 200 feet of any portion of the proposed well; and
Please refer to Attachment 2: Directional Plan for further details.
(2) for all wells within 200 feet of the proposed wellbore:
(A) list the names of the operators of those wells, to the extent that those names are known or
discoverable in public records, and show that each named operator has been furnished a copy of
the application by certified mail; or
(B) state that the applicant is the only affected owner.
The applicant is the only affected owner.
3. Blowout Prevention Equipment Information
20 AAC 25.005 (c) (3)
A diagram and description of the blowout prevention equipment (BOPE) as required by 20 AAC
25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable;
BOP test frequency for NDB-025 will be 14-days. Except in the event of a significant operational
issue that may affect well integrity or pose safety concerns, an extension to the 14-day BOP test
period should not be requested.
Parker 272 BOP Equipment:
BOP Equipment
x NOV Shaffer Spherical annular BOP, 13-5/8” x 5000 psi
x NOV T3 6012 double gate, 13-5/8” x 5000 psi
x Mud cross, 13-5/8” x 5000 psi with 2 ea. 3-1/8" x 5000 psi side outlets
x Choke Line, 3-1/8” x 5000 psi with 3-1/8” manual and HCR valve
x Kill Line, 2-1/16” x 5000 psi with 3-1/8” manual and HCR valve
x NOV T3 6012 single gate, 13-5/8” x 5000 psi
Choke Manifold
x 3-1/8” x 5000 psi working pressure with Axon Type S remote controlled chokes and NRG
mud/gas separator
BOP Closing Unit
x NOV SARA Koomey Control System, 316 gallon, 299 gallon reservoir. Twenty Four 15 gallon
bottles. Equipped with 1 electric and 3 air pumps with emergency power.
Please refer to Attachment 3: BOPE Equipment for further details.
4. Drilling Hazards Information
20 AAC 25.005 (c) (4)
Information on drilling hazards, including
(A) the maximum downhole pressure that may be encountered, criteria used to determine it, and
maximum potential surface pressure based on a pressure gradient to surface of 0.1 psi per foot of
true vertical depth, unless the commission approves a different pressure gradient that provides a
more accurate means of determining the maximum potential surface pressure;
12-1/4” Intermediate Hole Pressure Data
Maximum anticipated BHP 3,236 psi in the Kalubik at 6,274’ TVD
(9.9ppg EMW Kalubik formation to section TD)
Maximum surface pressure 2,609 psi from the Kalubik
(0.10 psi/ft gas gradient to surface, 6,274’ TVD)
Planned BOP test pressure
Rams test to 4,000 psi / 250 psi
Annular test to 3,000 psi / 250 psi
[Test pressure driven by Production Hole MASP]
Integrity Test – 12-1/4” hole LOT after drilling 20’-50’ of new hole. 14.2 ppg LOT required
for Kick Tolerance.
13-3/8” Casing Test 3,000 psi surface pressure
[Test pressure driven by MASP]
8-1/2” Production Hole Pressure Data
Maximum anticipated BHP 4,571 psi in the Kavik at 9,254’ TVD
(9.5ppg EMW Kavik formation to section TD)
Maximum surface pressure 3,646 psi from the Kavik
(0.10 psi/ft gas gradient to surface, 9,254’ TVD)
Planned BOP test pressure
Rams test to 4,000 psi / 250 psi
Annular test to 3,000 psi / 250 psi
[Test pressure driven by MASP]
Integrity Test – 8-1/2” hole FIT after drilling 20’-50’ of new hole to 15.0 ppg. (12.9 ppg
EMW LOT Required for kick tolerance.)
9-5/8” Liner Test
4,000 psi surface pressure
[Test pressure driven by MASP]
(B) data on potential gas zones; and
The Tuluvak formation is expected in this area and has a high potential for gas as based on offset
Exploration and Appraisal well data. The Tuluvak is expected to be overpressured at 9.8ppg pore
pressure. The well plan is designed to safely manage pressures consistent with offset wells in the
same manner that hydrocarbons are handled in the reservoir zone. BOPE will be installed before
entering any hydrocarbon zones and appropriate mud weights will be utilized to provide sufficient
overbalance.
(C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost
circulation zones, and zones that have a propensity for differential sticking;
13.0 ppg EMW LOT required for 15 bbls
Kick Tolerance minmum. -bjm
The Tuluvak formation is expected in this area and has a hi gh potential for gas as based on offset
Exploration and Appraisal well data. The Tuluvak is expected to be overpressured at 9.8ppg pore
pressure. T
Please refer to Attachment 4: Drilling Hazards
5. Procedure for Conducting Formation Integrity Tests
20 AAC 25.005 (c) (5)
A description of the procedure for conducting formation integrity tests, as required under 20 AAC
25.030(f);
Please refer to Attachment 5: Leak Off Test Procedure
6. Casing and Cementing Program
20 AAC 25.005 (c) (6)
A complete proposed casing and cementing program as required by 20 AAC 25.030, and a
description of any slotted liner, pre-perforated liner, or screen to be installed;
Casing/Tubing Program
Hole Size Liner /
Tbg O.D.Wt/Ft Grade Conn Length Top
MD
Bottom
MD / TVD
42” 20”x34” 215# X-52 Welded 80’ Surface 127’ /127’
16” 13-3/8” 68# L-80 BTC 2,525’ Surface 2,525’ / 2,306’
12-1/4” 9-5/8” 47# L-80 HYD 563 4,597’ 2,375’ 6,972’ / 6,274’
Tie Back 9-5/8” 47# L-80 HYD 563 2,375’ Surface 2,375’ / 2,183’
8-1/2” 7” 26# L-80 HYD 563 3,130’ 6,822’ 9,952’ / 9,254’
Tubing 4-1/2” 12.6# 13Cr-80 JFE Bear ~9,250’ Surface ~9,250’ / 8,551’
Please refer to Attachment 6: Cement Summary for further details.
7. Diverter System Information
20 AAC 25.005 (c) (7)
A diagram and description of the diverter system as required by 20 AAC 25.035, unless this
requirement is waived by the commission under 20 AAC 25.035(h)(2);
Parker 272 Diverter Equipment:
x Hydril MSP annular BOP, 21 1/4” x 2000 psi, flanged
x Diverter Spool 21 1/4” x 2000 psi with 16-3/4” flanged sidearm connection. Interlocked
knife/gate valves.
x 16” Diverter Line
Please refer to Attachment 3: BOPE Equipment for further details.
8. Drilling Fluid Program
20 AAC 25.005 (c) (8)
A drilling fluid program, including a diagram and description of the drilling fluid system, as required
by 20 AAC 25.033;
Drilling Fluid Program Summary
Surface Hole Intermediate Hole Production Hole
Mud Type Water based Spud
Mud
Mineral Oil Based
Mud
Mineral Oil Based
Mud
Mud Properties:
Mud Weight
Funnel Vis
PV
YP
API Fluid Loss
HPHT Fluid Loss
pH
MBT
10 ppg
100-300 seconds
ALAP
30-80
< 10 ml/30min
n/a
8.6-10.5
<35
11.5 - 12.0 ppg
50-80 seconds
ALAP
15-30
n/a
< 5 ml/30min
n/a
n/a
11.5 - 12.0 ppg
50-80 seconds
ALAP
15-30
n/a
< 5 ml/30min
n/a
n/a
A diagram of drilling fluid system on Parker 272 is on file with AOGCC.
9. Abnormally Pressured Formation Information
20 AAC 25.005 (c) (9)
For an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted
abnormally geo-pressured strata as required by 20 AAC 25.033(f);
N/A – Application is not for an exploratory or stratigraphic test well.
10. Seismic Analysis
20 AAC 25.005 (c) (10)
For an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required
by 20 AAC 25.061(a);
N/A – Application is not for an exploratory or stratigraphic test well.
11. Seabed Condition Analysis
20 AAC 25.005 (c) (11)
For a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or
floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(b);
The PWD-02 Well is to be drilled from an onshore location.
12. Evidence of Bonding
20 AAC 25.005 (c) (12)
Evidence showing that the requirements of 20 AAC 25.025 have been met;
PWD-02 is an EPA Class 1 Underground Injection Control (UIC) well and financial assurance is
maintained in accordance with 40 CFR § 144.63 through the EPA directly. Oil Search Alaska has
requested a waiver from the AOGCC abandonment bonding obligation for this reason.
13. Proposed Drilling Program
20 AAC 25.005 (c) (13)
A copy of the proposed drilling program; the drilling program must indicate if a well is proposed for
hydraulic fracturing as defined in 20 AAC 25.283(m); to seek approval to perform hydraulic
fracturing, a person must make a separate request by submitting an Application for Sundry
Approvals (Form 10-403) with the information required under 20 AAC 25.280 and 20 AAC 25.283;
The proposed drilling program to PWD-02 is listed below. Please refer to Attachments 8-10 for a
Well Schematic, Formation Evaluation Program, and Wellhead & Tree Diagram.
Proposed Drilling Program
1. Drill 20” conductor to ~128’ MD/TVD. Cement to surface. Install Cellar and landing ring on
conductor.
2. Move in / rig up Parker 272.
3. Nipple up spacer spools and diverter over the 20” conductor. Verify that the diverter line is
at least 75’ away from a potential source of ignition and beyond the drill rig substructure.
4. Function test diverter and knife valve as per AOGCC regulations. Provide AOGCC 24hrs
notice for witnessing diverter test.
5. Pick up 5-7/8” drill pipe, fill pits with spud mud and prepare for surface hole dri lling. Make
up 16” motor BHA with MWD and LWD tools.
6. Spud well and drill surface hole section to TD. Perform wiper trips as required. Circulate
and condition hole to run casing. POOH and lay down BHA.
7. Run 13-3/8” 68# surface casing as per casing tally and land on pre-installed landing ring.
Circulate and condition mud prior to commencing cement job.
8. Cement 13-3/8” casing as per cement program. Verify cement returns to surface.
9. ND diverter and NU casing head and spacer spool. NU BOPE (configured from top to
bottom: annular preventor, 4-1/2” x 7” VBR, blind/shear, mud cross, 4-1/2” x 7” VBR). Test
rams to 4000 psi high and annular to 3000 psi high as per AOGCC regulations. Provide
AOGCC 24hrs notice for witnessing BOP test.
10. Close blind shear rams and pressure test casing to 3000 psi for 30 min.
11. Make up 12-1/4” RSS BHA with MWD and LWD tools. RIH, clean out to top of float
equipment and displace well to 12.0 ppg MOBM.
12. Drill out shoe track and 20 - 50’ of new formation. Perform leak off test.
13. Directionally drill 12-1/4” intermediate hole section to TD ~15’ TVD above the Kuparuk C.
Perform wiper trips as required. Circulate and condition hole to perform wireline logging.
POOH.
14.Rig up wireline and run open hole logging runs as per program. Log tail cement on 13-3/8”
surface casing.
15. Perform 12-1/4” cleanout run to TD. POOH.
16. Change out lower BOP rams from 4-1/2” x 7” VBR to 9-5/8” fixed and test to 4000 psi.
17. Run 9-5/8” production liner as per casing tally then run on 5-7/8” DP. Circulate and
condition mud prior to commencing cement job.
18. Cement 9-5/8” liner as per cement program. Monitor returns during displacement. Bump
plug and set liner hanger and liner top packer.
19. Un-sting from liner hanger, circulate out any excess cement, POOH and LD liner running
tools.
20. Run 9-5/8” tie-back string. Freeze protect the 13-3/8” x 9-5/8” annulus with diesel and
land tie-back.
21. Pressure test 13-3/8” x 9-5/8” to 3000 psi for 30 min.
22. Pressure test the 9-5/8” liner and tieback to 4000 psi for 30 min.
23. Change out lower BOP rams from 9-5/8” fixed to 4-1/2” x 7” VBR and test to 4000 psi.
24. Make up 8-1/2” RSS BHA with MWD and LWD tools. RIH, clean out to top of float
equipment and condition 12.0 ppg MOBM.
25. Drill out shoe track and 20 - 50’ of new formation. Perform formation integrity test.
26. Directionally drill 8-1/2” hole section as per well plan to TD. Perform wiper trips as
required. POOH.
27. RU and run 7” production liner as per casing tally, then run on 5” DP to TD. Circulate and
condition mud prior to commencing cement job.
28. Cement 7” liner as per cement program. Monitor returns during displacement.
29. Set liner top packer, un-sting from liner hanger, POOH and LD liner running tools.
30. Perform cleanout run on 5” x 4” DP and clean out to top of float equipment. Perform 7” x
9-5/8” casing test to 4000 psi for 30 min.
31. Displace well to 9.40 ppg NaCl Corrosion Inhibited Brine and POOH.
32. Rig up wireline and run CBL to log cement on 9-5/8” intermediate liner and 7” producti on
liner.
33. RU and run 4-1/2” 12.6 ppf 13Cr-80 upper completion.
34. Land tubing hanger, drop ball and set the 4-1/2” x 7” production packer at 4,800 psi.
35. Pressure test tubing to 4,000 psi for 30 mins MIT-T.
36. Bleed tubing pressure to 3,000 psi and hold.
37. Pressure up on the annulus to 4,000 psi for 30 mins MIT-IA. Bleed pressure on tubing and
shear valve in the sidepocket gaslift mandrel.
38. Reverse circulate freeze protect and U-Tube.
39. Install TWC, pressure test to 1,000 psi for 10 mins from below. ND BOPE, NU Production
Tree.
40. RDMO
If LOT is <13.0 ppg, notify AOGCC and obtain approval before drilling
production hole. Additional swab-kick prevention measures will be required.
-bjm
Submit CBL log to AOGCC within 48 hrs of obtaining the log.
14. Discussion of Mud and Cuttings Disposal and Annular Disposal
20 AAC 25.005 (c) (14)
A general description of how the operator plans to dispose of drilling mud and cuttings and a
statement of whether the operator intends to request authorization under 20 AAC 25.080 for an
annular disposal operation in the well.
Water-based and oil-based drilling muds and cuttings will typically be hauled directly offsite via
truck as it is generated. Contractual arrangements have been made with other operators on the
North Slope to utilize their waste injection/disposal facilities (Class 1 and Class 2) at Prudhoe Bay,
Kuparuk and Milne Point. If waste cannot be hauled directly offsite, it may be stored temporarily in
drilling waste cuttings bins or a bermed cuttings storage cell in accordance with a drilling waste
temporary storage plan approved by Alaska Department of Conservation (ADEC) Solid Waste
Program until it can be transported for proper disposal.
There is no intention to request authorization under 20 AAC 25.080 for any annular disposal
operation in the well.
15. Proposed Variance Requests
20 AAC 25.412. Casing, cementing, and tubing of injection wells for enhanced recovery, disposal,
and storage
(b) A well used for injection must be equipped with tubing and a packer, or with other equipment
that isolates pressure to the injection interval, unless the commission approves the operator's use
of alternate means to ensure that injection of fluid is limited to the injection zone. The minimum
burst pressure of the tubing must exceed the maximum surface injection pressure by at least 25
percent. 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.
A variance is requested to the above regulation 20 AAC 25.412 (b) to not place the production
packer within 200 feet measured depth above the top of the perforations. The upper confining
zone for the Ivishak is the Shublik mudstone formation and it is estimated to be 375 feet thick.
The Ivishak zone is estimated to be 600 feet thick and plan to place the production packer below
the top of Ivishak zone.
20 AAC 25.537. Public and confidential information.
(a) The commission will routinely make available to the public, by means of records or reports, in its
offices or elsewhere, or by means of regular publication, the following information:
(1) surface and proposed bottom-hole locations of each well after approval of the Permit to
Drill (Form 10-401);
(2) total depth, bottom-hole location and well status after the Well Completion or
Recompletion Report and Log (Form 10-407) is filed;
(3) all reports and information required by this chapter for development and service wells;
(4) regular production data and regular production reports, as required to be filed by the
operator each month;
(5) injection data and injection reports, as required to be filed by the operator each month; and
Variance to 20 AAC 25.412(b) to place the packer >200' above the top perforation approved if:
1. Packer is set within the Ivishak injection interval or packer is set less than 50' above the base of the
upper confining interval.
2. There is at least 100' of cement across the upper confining interval above the packer. -bjm
(6) all data filed on a well as required by this chapter upon expiration of the confidential period
described in (d) of this section.
(b) Engineering, geologic, geophysical, and other commercial information not required by this
chapter, but voluntarily filed with the commission will be kept confidential if the person filing the
information so requests. This subsection does not apply to information submitted in a public
hearing under 20 AAC 25.540.
The PWD-02 well will be drilled to a location outside of the existing Nanushuk Oil Pool (NOP). The
PWD-02 well program includes plans for enhanced data collection not otherwise required by the
Commission (“Enhanced Data”). Collection of Enhanced Data will serve to delineate the Nanushuk
reservoir outside of the existing NOP. Pursuant to AS 31.05.035(d), 20 AAC 25.537(b) and to the
fullest extent allowed by law, OSA requests that the Commission keep Enhanced Data under the PWD-
02 well program confidential. Due to the commercial sensitivity of information resulting from the
program, OSA requests that the Commission consider all information other than Enhanced Data that
is submitted regarding the PWD-02 well program as confidential for a period of twenty-four (24)
months following OSA’s submission.
Logs and geologic data required to be filed with the commission are covered in 20 AAC 25.071.
Confidentiality is not granted to service wells as covered in 20 AAC 25.537(a)(3).
Operator has requested to rescind this request. See attached email. -A.Dewhurst 22FEB24
Attachments
Attachment 1: Location Maps
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OIL SEARCH (ALASKA) LLC A SUBSIDIARY OF SANTOS LTD
RIG OUTLINES
DIVERTER
PWD-02 SURFACE HOLE
DATE: 2/6/2024. By: JB
0204010
Feet
Project: AP-DRL-GEN_assorted Layout: AP-DRL-GEN-M_PWD02_well_diverter
GCS: NAD 1983 StatePlane Alaska 4 FIPS 5004 Feet
010205
Meters
PIKKA DEVELOPMENT
PWD-02 WELL DIVERTER
87.5 ͲŌ
Latitude (decimal
degree)
Long (decimal
degree)Latitude Longitude Y (ft) x (ft)
70.313416 Ͳ150.558494 N 70° 18' 48.3" W 150° 33' 30.577" 5,964,375.81 1,571,506.11
Latitude (decimal
degree)
Long (decimal
degree)Latitude Longitude y (ft) x (ft)
70.313733 Ͳ150.555368 N 70° 18' 49.44" W 150° 33' 19.323" 5,964,626.52 431,473.17
State Plane NAD83 Zone 4 (as-staked)
StatePlane NAD27 Zone 4 (as-staked)
Attachment 2: Directional Plan
SECTION DETAILS
Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation
1 47.0 0.00 0.00 47.0 0.0 0.0 0.00 0.00 0.0
2 350.0 0.00 0.00 350.0 0.0 0.0 0.00 0.00 0.0 Start Build 2.62
3 997.9 17.00 88.68 988.4 2.2 95.4 2.62 88.68 95.4 Start 150.0 hold at 997.9 MD
4 1147.9 17.00 88.68 1131.8 3.2 139.2 0.00 0.00 139.3 Start Build 3.00
5 1745.5 34.93 88.68 1667.0 9.2 399.8 3.00 0.00 399.9 Start 3046.7 hold at 1745.5 MD
6 4792.2 34.93 88.68 4164.9 49.4 2143.8 0.00 0.00 2144.3 Start Drop -3.00
7 5956.6 0.00 0.00 5258.4 57.3 2487.7 3.00 180.00 2488.4 Start 3822.7 hold at 5956.6 MD
8 9779.3 0.00 0.00 9081.1 57.3 2487.7 0.00 0.00 2488.4 PWD 2 Central 3000' BHL Start 23.0 hold at 9779.3 MD
9 9802.3 0.00 0.00 9104.1 57.3 2487.7 0.00 0.00 2488.4 Start 150.0 hold at 9802.3 MD
10 9952.3 0.00 0.00 9254.1 57.3 2487.7 0.00 0.00 2488.4 TD at 9952.3
47 310
310 510
510 760
760 1010
1010 1260
1260 1510
1510 1760
1760 2010
2010 2510
2510 3010
3010 3510
3510 4510
4510 5510
5510 6510
6510 7510
7510 8510
8510 9510
9510 11010
11010 12010
12010 13010
13010 14010
14010 15010
15010 16010
16010 17010
17010 18010
Plan: PWD-02 Rev E.1 Plan Summary
0
3
Do
g
l
e
g
S
e
v
e
r
i
t
y
0 1500 3000 4500 6000 7500 9000
Measured Depth
20" Conductor Casing13-3/8" Surface Casing 9-5/8" Intermediate Casing7"
45
45
90
90
0
90
180
270
30
210
60
240 120
300
150
330
Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [90 usft/in]
8610012515017520022525027530032535037540042545047550052555057560062362565067570072575077580082585087590092595097510001025105010751100112511501175
12.1 PWD3
86100125150175200225250275300325350375
400425450475500525550575600625650675700725750775800825850875900925950975993100010251050107510821100112511501175120012251250127513001325135013751400142514501475150015251550157516001625165016751700172517501775180018251850
12.1 PWD1
4750
Tr
u
e
V
e
r
t
i
c
a
l
D
e
p
t
h
0 350 700 10501400175021002450
Vertical Section at 88.68°
20" Conductor Casing
13-3/8" Surface Casing
9-5/8" Intermediate Casing
7"
0
28
55
Ce
n
t
r
e
t
o
C
e
n
t
r
e
S
e
p
a
r
a
t
i
o
n
0 275 550 825 1100 1375 1650 1925
Measured Depth
Equivalent Magnetic Distance
DDI
5.458
SURVEY PROGRAM
Date: 2024-03-01T00:00:00 Validated: Yes Version:
Depth From Depth To Survey/Plan Tool
47.0 300.0 Plan: PWD-02 Rev E.1 (PWD-02)SDI_URSA1_I4
300.0 1300.0 Plan: PWD-02 Rev E.1 (PWD-02)3_MWD+IFR2+Sag
300.0 2525.0 Plan: PWD-02 Rev E.1 (PWD-02)3_MWD+IFR2+MS+Sag
2525.0 3525.0 Plan: PWD-02 Rev E.1 (PWD-02)3_MWD+IFR2+Sag
2525.0 6972.0 Plan: PWD-02 Rev E.1 (PWD-02)3_MWD+IFR2+MS+Sag
6972.0 7972.0 Plan: PWD-02 Rev E.1 (PWD-02)3_MWD+IFR2+Sag
6972.0 9952.3 Plan: PWD-02 Rev E.1 (PWD-02)3_MWD+IFR2+MS+Sag
Surface Location
North / 5964375.81
East / 1571506.11
Elevation / 34.1
CASING DETAILS
TVD MD
Name
127.0 127.020" Conductor Casing
2306.0 2525.013-3/8" Surface Casing
6273.8 6972.09-5/8" Intermediate Casing
9253.8 9952.0 7"
Mag Model & Date: IGRF2000 31-Dec-04
Magnetic North is 24.76° East of True North (Magnetic Decl
Mag Dip & Field Strength: 80.60° 57284.54025705nT
FORMATION TOP DETAILS
TVDPathFormation
1025.1 Upper SB
1355.1Permafrost Base
1725.4Middle SB
2155.9 MCU
2581.1Tuluvak Shale
2644.3Tuluvak Sand
3224.6 Seabee
3974.3Nanushuk
4125.5 NT7 MFS4281.1TM_BRO_030_21
4287.7NT6 MFS
4679.8NT5 MFS
4761.1Top of Torok (Shale)
5023.1Torok Disposal Zone
5262.5NT4 MFS
5446.4NT3 MFS
5624.8NT2 MFS
5746.3NT1 MFS
5935.6 Top HRZ
6073.1 Kalubik
6288.5Kuparuk C
6643.6 UJU
6776.0Upper Kingak
7209.1Middle kingak
7590.2Lower Kingak
8128.0 Shublik
8480.1 Ivishak
9104.1 Kavik
By signing this I acknowledge that I have been informed of all risks, checked that the data is correct, ensured it's completeness, and all surroundingwells are assigned to the proper position, and I approve the scan and collision avoidance plan as set out in the audit pack.I approve it as the basiis
for the final well plan and wellsite drawings. I also acknowledge that unless notified otherwise all targets have a 100 feet lateral tolerance.
Prepared by Checked by
BHI DE
Accepted by
BHI PSD
Approved by
Santos DE
Plan: Parker 272 @ 81.1usft
Standard Planning Report - Geographic
31 January, 2024
Plan: Plan: PWD-02 Rev E.1
Santos NAD27 Conversion
Pikka
NPF
PWD-02
PWD-02
Santos Ltd
Planning Report - Geographic
Well PWD-02Local Co-ordinate Reference:Database:EDM
Plan: Parker 272 @ 81.1usftTVD Reference:Santos NAD27 ConversionCompany:
Plan: Parker 272 @ 81.1usftMD Reference:PikkaProject:
TrueNorth Reference:NPFSite:
Minimum CurvatureSurvey Calculation Method:PWD-02Well:
PWD-02Wellbore:
Plan: PWD-02 Rev E.1Design:
Map System:
Geo Datum:
Project
Map Zone:
System Datum:US State Plane 1927 (Exact solution)
NAD 1927 (NADCON CONUS)
Pikka, North Slope Alaska, United States
Alaska Zone 04
Mean Sea Level
Using Well Reference Point
Using geodetic scale factor
Site Position:
From:
Site
Latitude:
Longitude:
Position Uncertainty:
Northing:
Easting:
NPF
Map
Slot Radius:0.9 usft
usft
usft
"
5,964,647.16
431,487.49
36
70° 18' 49.643 N
150° 33' 18.911 W
Well
Well Position
Longitude:
Latitude:
Easting:
Northing:
+E/-W
+N/-S
Position Uncertainty Ground Level:
PWD-02
Wellhead Elevation:0.9
0.0
0.0
5,964,626.99
431,473.18
70° 18' 49.444 N
150° 33' 19.323 W
34.1
usft
usft
usft
usft
usft
usft usft
°-0.52Grid Convergence:
Wellbore
Declination
(°)
Field Strength
(nT)
Sample Date Dip Angle
(°)
PWD-02
Model NameMagnetics
IGRF2020 31/12/2023 14.38 80.54 57,173.96141516
Phase:Version:
Audit Notes:
Design Plan: PWD-02 Rev E.1
PLAN
Vertical Section: Depth From (TVD)
(usft)
+N/-S
(usft)
Direction
(°)
+E/-W
(usft)
Tie On Depth:47.0
88.680.00.047.0
Plan Survey Tool Program
RemarksTool NameSurvey (Wellbore)
Date 31/01/2024
Depth To
(usft)
Depth From
(usft)
SDI_URSA1_I4
SDI URSA-1 gyroMWD (ISC
Plan: PWD-02 Rev E.1 (PWD-02147.0 300.0
3_MWD+IFR2+Sag
A012Mb: IIFR dec correctio
Plan: PWD-02 Rev E.1 (PWD-022300.0 1,300.0
3_MWD+IFR2+MS+Sag
A013Mb: IIFR dec & multi-s
Plan: PWD-02 Rev E.1 (PWD-023300.0 2,525.0
3_MWD+IFR2+Sag
A012Mb: IIFR dec correctio
Plan: PWD-02 Rev E.1 (PWD-0242,525.0 3,525.0
3_MWD+IFR2+MS+Sag
A013Mb: IIFR dec & multi-s
Plan: PWD-02 Rev E.1 (PWD-0252,525.0 6,972.0
3_MWD+IFR2+Sag
A012Mb: IIFR dec correctio
Plan: PWD-02 Rev E.1 (PWD-0266,972.0 7,972.0
3_MWD+IFR2+MS+Sag
A013Mb: IIFR dec & multi-s
Plan: PWD-02 Rev E.1 (PWD-0276,972.0 9,952.3
31/01/2024 09:39:17 COMPASS 5000.17 Build Page 2
Santos Ltd
Planning Report - Geographic
Well PWD-02Local Co-ordinate Reference:Database:EDM
Plan: Parker 272 @ 81.1usftTVD Reference:Santos NAD27 ConversionCompany:
Plan: Parker 272 @ 81.1usftMD Reference:PikkaProject:
TrueNorth Reference:NPFSite:
Minimum CurvatureSurvey Calculation Method:PWD-02Well:
PWD-02Wellbore:
Plan: PWD-02 Rev E.1Design:
Inclination
(°)
Azimuth
(°)
+E/-W
(usft)
TFO
(°)
+N/-S
(usft)
Measured
Depth
(usft)
Vertical
Depth
(usft)
Dogleg
Rate
(°/100usft)
Build
Rate
(°/100usft)
Turn
Rate
(°/100usft)
Plan Sections
Target
0.000.000.000.000.00.047.00.000.0047.0
0.000.000.000.000.00.0350.00.000.00350.0
88.680.002.622.6295.42.2988.488.6817.00997.9
0.000.000.000.00139.23.21,131.888.6817.001,147.9
0.000.003.003.00399.89.21,667.088.6834.931,745.5
0.000.000.000.002,143.849.44,164.888.6834.934,792.2
180.000.00-3.003.002,487.757.35,258.40.000.005,956.6
0.000.000.000.002,487.757.39,081.10.000.009,779.3 PWD 2 Central 300
0.000.000.000.002,487.757.39,104.10.000.009,802.3
0.000.000.000.002,487.757.39,254.10.000.009,952.3
31/01/2024 09:39:17 COMPASS 5000.17 Build Page 3
Santos Ltd
Planning Report - Geographic
Well PWD-02Local Co-ordinate Reference:Database:EDM
Plan: Parker 272 @ 81.1usftTVD Reference:Santos NAD27 ConversionCompany:
Plan: Parker 272 @ 81.1usftMD Reference:PikkaProject:
TrueNorth Reference:NPFSite:
Minimum CurvatureSurvey Calculation Method:PWD-02Well:
PWD-02Wellbore:
Plan: PWD-02 Rev E.1Design:
Measured
Depth
(usft)
Inclination
(°)
Azimuth
(°)
+E/-W
(usft)
Map
Northing
(usft)
Map
Easting
(usft)
+N/-S
(usft)Latitude Longitude
Planned Survey
Vertical
Depth
(usft)
47.0 0.00 47.0 0.0 0.00.00 431,473.185,964,626.99 70° 18' 49.444 N 150° 33' 19.323 W
100.0 0.00 100.0 0.0 0.00.00 431,473.185,964,626.99 70° 18' 49.444 N 150° 33' 19.323 W
127.0 0.00 127.0 0.0 0.00.00 431,473.185,964,626.99 70° 18' 49.444 N 150° 33' 19.323 W
20" Conductor Casing
200.0 0.00 200.0 0.0 0.00.00 431,473.185,964,626.99 70° 18' 49.444 N 150° 33' 19.323 W
300.0 0.00 300.0 0.0 0.00.00 431,473.185,964,626.99 70° 18' 49.444 N 150° 33' 19.323 W
350.0 0.00 350.0 0.0 0.00.00 431,473.185,964,626.99 70° 18' 49.444 N 150° 33' 19.323 W
Start Build 2.62
400.0 1.31 400.0 0.0 0.688.68 431,473.755,964,627.00 70° 18' 49.444 N 150° 33' 19.306 W
500.0 3.94 499.9 0.1 5.188.68 431,478.335,964,627.06 70° 18' 49.445 N 150° 33' 19.173 W
600.0 6.56 599.5 0.3 14.388.68 431,487.485,964,627.19 70° 18' 49.447 N 150° 33' 18.906 W
700.0 9.18 698.5 0.6 28.088.68 431,501.175,964,627.38 70° 18' 49.450 N 150° 33' 18.507 W
800.0 11.81 796.8 1.1 46.288.68 431,519.385,964,627.63 70° 18' 49.454 N 150° 33' 17.975 W
900.0 14.43 894.2 1.6 68.988.68 431,542.075,964,627.95 70° 18' 49.459 N 150° 33' 17.313 W
997.9 17.00 988.4 2.2 95.488.68 431,568.575,964,628.32 70° 18' 49.465 N 150° 33' 16.540 W
Start 150.0 hold at 997.9 MD
1,000.0 17.00 990.4 2.2 96.088.68 431,569.205,964,628.33 70° 18' 49.465 N 150° 33' 16.522 W
1,036.2 17.00 1,025.1 2.5 106.688.68 431,579.795,964,628.47 70° 18' 49.468 N 150° 33' 16.213 W
Upper Schrader Bluff
1,100.0 17.00 1,086.1 2.9 125.288.68 431,598.435,964,628.73 70° 18' 49.472 N 150° 33' 15.669 W
1,147.9 17.00 1,131.8 3.2 139.288.68 431,612.425,964,628.93 70° 18' 49.475 N 150° 33' 15.261 W
Start Build 3.00
1,200.0 18.56 1,181.5 3.6 155.188.68 431,628.345,964,629.15 70° 18' 49.479 N 150° 33' 14.797 W
1,300.0 21.56 1,275.4 4.4 189.488.68 431,662.645,964,629.63 70° 18' 49.487 N 150° 33' 13.796 W
1,386.5 24.16 1,355.1 5.1 223.088.68 431,696.235,964,630.09 70° 18' 49.494 N 150° 33' 12.817 W
Permafrost Base
1,400.0 24.56 1,367.4 5.3 228.688.68 431,701.805,964,630.17 70° 18' 49.495 N 150° 33' 12.654 W
1,500.0 27.56 1,457.2 6.3 272.588.68 431,745.725,964,630.78 70° 18' 49.505 N 150° 33' 11.373 W
1,600.0 30.56 1,544.6 7.4 321.188.68 431,794.295,964,631.46 70° 18' 49.516 N 150° 33' 9.956 W
1,700.0 33.56 1,629.4 8.6 374.188.68 431,847.365,964,632.20 70° 18' 49.528 N 150° 33' 8.408 W
1,745.5 34.93 1,667.0 9.2 399.888.68 431,872.985,964,632.55 70° 18' 49.534 N 150° 33' 7.661 W
Start 3046.7 hold at 1745.5 MD
1,800.0 34.93 1,711.7 9.9 430.988.68 431,904.165,964,632.99 70° 18' 49.541 N 150° 33' 6.751 W
1,816.8 34.93 1,725.4 10.2 440.688.68 431,913.775,964,633.12 70° 18' 49.543 N 150° 33' 6.471 W
Middle Schrader Bluff
1,900.0 34.93 1,793.6 11.2 488.288.68 431,961.405,964,633.78 70° 18' 49.554 N 150° 33' 5.081 W
2,000.0 34.93 1,875.6 12.6 545.488.68 432,018.655,964,634.58 70° 18' 49.567 N 150° 33' 3.411 W
2,100.0 34.93 1,957.6 13.9 602.788.68 432,075.905,964,635.37 70° 18' 49.580 N 150° 33' 1.741 W
2,200.0 34.93 2,039.6 15.2 659.988.68 432,133.145,964,636.17 70° 18' 49.593 N 150° 33' 0.072 W
2,300.0 34.93 2,121.6 16.5 717.288.68 432,190.395,964,636.97 70° 18' 49.606 N 150° 32' 58.402 W
2,341.9 34.93 2,155.9 17.1 741.288.68 432,214.395,964,637.30 70° 18' 49.611 N 150° 32' 57.702 W
MCU
2,400.0 34.93 2,203.6 17.8 774.488.68 432,247.645,964,637.76 70° 18' 49.619 N 150° 32' 56.732 W
2,500.0 34.93 2,285.5 19.2 831.688.68 432,304.885,964,638.56 70° 18' 49.632 N 150° 32' 55.062 W
2,525.0 34.93 2,306.0 19.5 846.088.68 432,319.205,964,638.76 70° 18' 49.635 N 150° 32' 54.644 W
13-3/8" Surface Casing
2,600.0 34.93 2,367.5 20.5 888.988.68 432,362.135,964,639.36 70° 18' 49.645 N 150° 32' 53.392 W
2,700.0 34.93 2,449.5 21.8 946.188.68 432,419.385,964,640.15 70° 18' 49.658 N 150° 32' 51.722 W
2,800.0 34.93 2,531.5 23.1 1,003.488.68 432,476.625,964,640.95 70° 18' 49.670 N 150° 32' 50.052 W
2,860.5 34.93 2,581.1 23.9 1,038.088.68 432,511.235,964,641.43 70° 18' 49.678 N 150° 32' 49.042 W
Tuluvak Shale
2,900.0 34.93 2,613.5 24.4 1,060.688.68 432,533.875,964,641.75 70° 18' 49.683 N 150° 32' 48.382 W
2,937.6 34.93 2,644.3 24.9 1,082.188.68 432,555.385,964,642.05 70° 18' 49.688 N 150° 32' 47.755 W
Tuluvak Sand
3,000.0 34.93 2,695.5 25.8 1,117.988.68 432,591.125,964,642.54 70° 18' 49.696 N 150° 32' 46.712 W
3,100.0 34.93 2,777.5 27.1 1,175.188.68 432,648.365,964,643.34 70° 18' 49.709 N 150° 32' 45.042 W
3,200.0 34.93 2,859.4 28.4 1,232.388.68 432,705.615,964,644.14 70° 18' 49.722 N 150° 32' 43.372 W
3,300.0 34.93 2,941.4 29.7 1,289.688.68 432,762.865,964,644.93 70° 18' 49.735 N 150° 32' 41.703 W
31/01/2024 09:39:17 COMPASS 5000.17 Build Page 4
Santos Ltd
Planning Report - Geographic
Well PWD-02Local Co-ordinate Reference:Database:EDM
Plan: Parker 272 @ 81.1usftTVD Reference:Santos NAD27 ConversionCompany:
Plan: Parker 272 @ 81.1usftMD Reference:PikkaProject:
TrueNorth Reference:NPFSite:
Minimum CurvatureSurvey Calculation Method:PWD-02Well:
PWD-02Wellbore:
Plan: PWD-02 Rev E.1Design:
Measured
Depth
(usft)
Inclination
(°)
Azimuth
(°)
+E/-W
(usft)
Map
Northing
(usft)
Map
Easting
(usft)
+N/-S
(usft)Latitude Longitude
Planned Survey
Vertical
Depth
(usft)
3,400.0 34.93 3,023.4 31.0 1,346.888.68 432,820.105,964,645.73 70° 18' 49.748 N 150° 32' 40.033 W
3,500.0 34.93 3,105.4 32.4 1,404.188.68 432,877.355,964,646.53 70° 18' 49.761 N 150° 32' 38.363 W
3,600.0 34.93 3,187.4 33.7 1,461.388.68 432,934.605,964,647.32 70° 18' 49.773 N 150° 32' 36.693 W
3,645.4 34.93 3,224.6 34.3 1,487.388.68 432,960.605,964,647.68 70° 18' 49.779 N 150° 32' 35.934 W
Seabee
3,700.0 34.93 3,269.4 35.0 1,518.588.68 432,991.845,964,648.12 70° 18' 49.786 N 150° 32' 35.023 W
3,800.0 34.93 3,351.4 36.3 1,575.888.68 433,049.095,964,648.91 70° 18' 49.799 N 150° 32' 33.353 W
3,900.0 34.93 3,433.3 37.6 1,633.088.68 433,106.345,964,649.71 70° 18' 49.812 N 150° 32' 31.683 W
4,000.0 34.93 3,515.3 38.9 1,690.388.68 433,163.585,964,650.51 70° 18' 49.825 N 150° 32' 30.013 W
4,100.0 34.93 3,597.3 40.3 1,747.588.68 433,220.835,964,651.30 70° 18' 49.838 N 150° 32' 28.343 W
4,200.0 34.93 3,679.3 41.6 1,804.888.68 433,278.085,964,652.10 70° 18' 49.851 N 150° 32' 26.673 W
4,300.0 34.93 3,761.3 42.9 1,862.088.68 433,335.325,964,652.90 70° 18' 49.863 N 150° 32' 25.003 W
4,400.0 34.93 3,843.3 44.2 1,919.288.68 433,392.575,964,653.69 70° 18' 49.876 N 150° 32' 23.333 W
4,500.0 34.93 3,925.3 45.5 1,976.588.68 433,449.815,964,654.49 70° 18' 49.889 N 150° 32' 21.663 W
4,559.8 34.93 3,974.3 46.3 2,010.788.68 433,484.045,964,654.97 70° 18' 49.897 N 150° 32' 20.665 W
Nanushuk
4,600.0 34.93 4,007.2 46.9 2,033.788.68 433,507.065,964,655.29 70° 18' 49.902 N 150° 32' 19.994 W
4,700.0 34.93 4,089.2 48.2 2,091.088.68 433,564.315,964,656.08 70° 18' 49.915 N 150° 32' 18.324 W
4,744.2 34.93 4,125.5 48.8 2,116.388.68 433,589.645,964,656.43 70° 18' 49.920 N 150° 32' 17.585 W
NT7 MFS
4,792.2 34.93 4,164.8 49.4 2,143.888.68 433,617.115,964,656.82 70° 18' 49.927 N 150° 32' 16.783 W
Start Drop -3.00
4,800.0 34.70 4,171.2 49.5 2,148.288.68 433,621.545,964,656.88 70° 18' 49.928 N 150° 32' 16.654 W
4,900.0 31.70 4,254.9 50.8 2,202.988.68 433,676.285,964,657.64 70° 18' 49.940 N 150° 32' 15.057 W
4,930.7 30.78 4,281.1 51.1 2,218.888.68 433,692.175,964,657.86 70° 18' 49.943 N 150° 32' 14.594 W
TM_BRO_030_21
4,938.4 30.55 4,287.7 51.2 2,222.888.68 433,696.115,964,657.92 70° 18' 49.944 N 150° 32' 14.479 W
NT6 MFS
5,000.0 28.70 4,341.3 51.9 2,253.288.68 433,726.565,964,658.34 70° 18' 49.951 N 150° 32' 13.591 W
5,100.0 25.70 4,430.2 53.0 2,298.988.68 433,772.255,964,658.98 70° 18' 49.961 N 150° 32' 12.258 W
5,200.0 22.70 4,521.4 53.9 2,339.988.68 433,813.235,964,659.55 70° 18' 49.970 N 150° 32' 11.062 W
5,300.0 19.70 4,614.7 54.7 2,376.088.68 433,849.375,964,660.05 70° 18' 49.978 N 150° 32' 10.008 W
5,368.8 17.63 4,679.8 55.3 2,398.088.68 433,871.385,964,660.35 70° 18' 49.983 N 150° 32' 9.366 W
NT5 MFS
5,400.0 16.70 4,709.7 55.5 2,407.288.68 433,880.595,964,660.48 70° 18' 49.985 N 150° 32' 9.097 W
5,453.5 15.09 4,761.1 55.8 2,421.988.68 433,895.245,964,660.69 70° 18' 49.989 N 150° 32' 8.670 W
Top of Torok (Shale)
5,500.0 13.70 4,806.1 56.1 2,433.488.68 433,906.805,964,660.85 70° 18' 49.991 N 150° 32' 8.333 W
5,600.0 10.70 4,903.9 56.6 2,454.688.68 433,927.925,964,661.14 70° 18' 49.996 N 150° 32' 7.717 W
5,700.0 7.70 5,002.6 56.9 2,470.588.68 433,943.905,964,661.36 70° 18' 50.000 N 150° 32' 7.251 W
5,720.7 7.08 5,023.1 57.0 2,473.288.68 433,946.565,964,661.40 70° 18' 50.000 N 150° 32' 7.173 W
Torok Disposal Zone
5,800.0 4.70 5,102.0 57.2 2,481.388.68 433,954.695,964,661.51 70° 18' 50.002 N 150° 32' 6.936 W
5,900.0 1.70 5,201.8 57.3 2,486.988.68 433,960.275,964,661.59 70° 18' 50.003 N 150° 32' 6.773 W
5,956.6 0.00 5,258.4 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
Start 3822.7 hold at 5956.6 MD
5,960.7 0.00 5,262.5 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
NT4 MFS
6,000.0 0.00 5,301.8 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
6,100.0 0.00 5,401.8 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
6,144.6 0.00 5,446.4 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
NT3 MFS
6,200.0 0.00 5,501.8 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
6,300.0 0.00 5,601.8 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
6,323.0 0.00 5,624.8 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
NT2 MFS
6,400.0 0.00 5,701.8 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
31/01/2024 09:39:17 COMPASS 5000.17 Build Page 5
Santos Ltd
Planning Report - Geographic
Well PWD-02Local Co-ordinate Reference:Database:EDM
Plan: Parker 272 @ 81.1usftTVD Reference:Santos NAD27 ConversionCompany:
Plan: Parker 272 @ 81.1usftMD Reference:PikkaProject:
TrueNorth Reference:NPFSite:
Minimum CurvatureSurvey Calculation Method:PWD-02Well:
PWD-02Wellbore:
Plan: PWD-02 Rev E.1Design:
Measured
Depth
(usft)
Inclination
(°)
Azimuth
(°)
+E/-W
(usft)
Map
Northing
(usft)
Map
Easting
(usft)
+N/-S
(usft)Latitude Longitude
Planned Survey
Vertical
Depth
(usft)
6,444.5 0.00 5,746.3 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
NT1 MFS
6,500.0 0.00 5,801.8 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
6,600.0 0.00 5,901.8 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
6,633.8 0.00 5,935.6 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
Top HRZ
6,700.0 0.00 6,001.8 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
6,771.3 0.00 6,073.1 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
Kalubik
6,800.0 0.00 6,101.8 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
6,900.0 0.00 6,201.8 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
6,972.0 0.00 6,273.8 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
9-5/8" Intermediate Casing
6,986.7 0.00 6,288.5 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
Kuparuk C
7,000.0 0.00 6,301.8 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
7,100.0 0.00 6,401.8 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
7,200.0 0.00 6,501.8 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
7,300.0 0.00 6,601.8 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
7,341.8 0.00 6,643.6 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
UJU
7,400.0 0.00 6,701.8 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
7,474.2 0.00 6,776.0 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
Upper Kingak
7,500.0 0.00 6,801.8 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
7,600.0 0.00 6,901.8 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
7,700.0 0.00 7,001.8 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
7,800.0 0.00 7,101.8 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
7,900.0 0.00 7,201.8 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
7,907.3 0.00 7,209.1 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
Middle kingak
8,000.0 0.00 7,301.8 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
8,100.0 0.00 7,401.8 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
8,200.0 0.00 7,501.8 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
8,288.4 0.00 7,590.2 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
Lower Kingak
8,300.0 0.00 7,601.8 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
8,400.0 0.00 7,701.8 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
8,500.0 0.00 7,801.8 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
8,600.0 0.00 7,901.8 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
8,700.0 0.00 8,001.8 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
8,800.0 0.00 8,101.8 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
8,826.2 0.00 8,128.0 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
Shublik
8,900.0 0.00 8,201.8 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
9,000.0 0.00 8,301.8 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
9,100.0 0.00 8,401.8 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
9,178.3 0.00 8,480.1 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
Ivishak
9,200.0 0.00 8,501.8 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
9,300.0 0.00 8,601.8 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
9,400.0 0.00 8,701.8 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
9,500.0 0.00 8,801.8 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
9,600.0 0.00 8,901.8 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
9,700.0 0.00 9,001.8 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
9,779.3 0.00 9,081.1 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
Start 23.0 hold at 9779.3 MD
9,800.0 0.00 9,101.8 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
31/01/2024 09:39:17 COMPASS 5000.17 Build Page 6
Santos Ltd
Planning Report - Geographic
Well PWD-02Local Co-ordinate Reference:Database:EDM
Plan: Parker 272 @ 81.1usftTVD Reference:Santos NAD27 ConversionCompany:
Plan: Parker 272 @ 81.1usftMD Reference:PikkaProject:
TrueNorth Reference:NPFSite:
Minimum CurvatureSurvey Calculation Method:PWD-02Well:
PWD-02Wellbore:
Plan: PWD-02 Rev E.1Design:
Measured
Depth
(usft)
Inclination
(°)
Azimuth
(°)
+E/-W
(usft)
Map
Northing
(usft)
Map
Easting
(usft)
+N/-S
(usft)Latitude Longitude
Planned Survey
Vertical
Depth
(usft)
9,802.3 0.00 9,104.1 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
Start 150.0 hold at 9802.3 MD - Kavik
9,900.0 0.00 9,201.8 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
9,952.0 0.00 9,253.8 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
7"
9,952.3 0.00 9,254.1 57.3 2,487.70.00 433,961.115,964,661.60 70° 18' 50.003 N 150° 32' 6.749 W
TD at 9952.3
Target Name
- hit/miss target
- Shape
TVD
(usft)
Northing
(usft)
Easting
(usft)
+N/-S
(usft)
+E/-W
(usft)
Design Targets
LongitudeLatitude
Dip Angle
(°)
Dip Dir.
(°)
Torok Target 5,270.1 5,964,661.05 433,961.1056.8 2,487.70.00 0.00 70° 18' 49.998 N 150° 32' 6.749 W
- plan misses target center by 0.5usft at 5968.3usft MD (5270.1 TVD, 57.3 N, 2487.7 E)
- Point
Ivishak Target 8,486.1 5,964,661.16 433,961.1056.9 2,487.70.00 0.00 70° 18' 49.999 N 150° 32' 6.749 W
- plan misses target center by 0.4usft at 9184.3usft MD (8486.1 TVD, 57.3 N, 2487.7 E)
- Point
PWD 2 Central 3000' 9,081.1 5,964,661.11 433,961.0956.8 2,487.70.00 0.00 70° 18' 49.999 N 150° 32' 6.749 W
- plan misses target center by 0.5usft at 9779.3usft MD (9081.1 TVD, 57.3 N, 2487.7 E)
- Point
Vertical
Depth
(usft)
Measured
Depth
(usft)
Casing
Diameter
(")
Hole
Diameter
(")Name
Casing Points
20" Conductor Casing127.0127.0 20 20
13-3/8" Surface Casing2,306.02,525.0 13-3/8 16
9-5/8" Intermediate Casing6,273.86,972.0 9-5/8 12-1/4
7"9,253.89,952.0 78-1/2
31/01/2024 09:39:17 COMPASS 5000.17 Build Page 7
Santos Ltd
Planning Report - Geographic
Well PWD-02Local Co-ordinate Reference:Database:EDM
Plan: Parker 272 @ 81.1usftTVD Reference:Santos NAD27 ConversionCompany:
Plan: Parker 272 @ 81.1usftMD Reference:PikkaProject:
TrueNorth Reference:NPFSite:
Minimum CurvatureSurvey Calculation Method:PWD-02Well:
PWD-02Wellbore:
Plan: PWD-02 Rev E.1Design:
Measured
Depth
(usft)
Vertical
Depth
(usft)
Dip
Direction
(°)Name Lithology
Dip
(°)
Formations
1,036.2 Upper Schrader Bluff1,025.1
1,386.5 Permafrost Base1,355.1
1,816.8 Middle Schrader Bluff1,725.4
2,341.9 MCU2,155.9
2,860.5 Tuluvak Shale2,581.1
2,937.6 Tuluvak Sand2,644.3
3,645.4 Seabee3,224.6
4,559.8 Nanushuk3,974.3
4,744.2 NT7 MFS4,125.5
4,930.7 TM_BRO_030_214,281.1
4,938.4 NT6 MFS4,287.7
5,368.8 NT5 MFS4,679.8
5,453.5 Top of Torok (Shale)4,761.1
5,720.7 Torok Disposal Zone5,023.1
5,960.7 NT4 MFS5,262.5
6,144.6 NT3 MFS5,446.4
6,323.0 NT2 MFS5,624.8
6,444.5 NT1 MFS5,746.3
6,633.8 Top HRZ5,935.6
6,771.3 Kalubik6,073.1
6,986.7 Kuparuk C6,288.5
7,341.8 UJU6,643.6
7,474.2 Upper Kingak6,776.0
7,907.3 Middle kingak7,209.1
8,288.4 Lower Kingak7,590.2
8,826.2 Shublik8,128.0
9,178.3 Ivishak8,480.1
9,802.3 Kavik9,104.1
Measured
Depth
(usft)
Vertical
Depth
(usft)
+E/-W
(usft)
+N/-S
(usft)
Local Coordinates
Comment
Plan Annotations
350.0 350.0 0.0 0.0 Start Build 2.62
997.9 988.4 2.2 95.4 Start 150.0 hold at 997.9 MD
1,147.9 1,131.8 3.2 139.2 Start Build 3.00
1,745.5 1,667.0 9.2 399.8 Start 3046.7 hold at 1745.5 MD
4,792.2 4,164.8 49.4 2,143.8 Start Drop -3.00
5,956.6 5,258.4 57.3 2,487.7 Start 3822.7 hold at 5956.6 MD
9,779.3 9,081.1 57.3 2,487.7 Start 23.0 hold at 9779.3 MD
9,802.3 9,104.1 57.3 2,487.7 Start 150.0 hold at 9802.3 MD
9,952.3 9,254.1 57.3 2,487.7 TD at 9952.3
31/01/2024 09:39:17 COMPASS 5000.17 Build Page 8
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30 January, 2024
Anticollision Summary Report
Santos
Pikka
NPF
PWD-02
PWD-02
Plan: PWD-02 Rev E.1
Santos Ltd
Anticollision Summary Report
Well PWD-02Local Co-ordinate Reference:SantosCompany:
Plan: Parker 272 @ 81.1usftTVD Reference:PikkaProject:
Plan: Parker 272 @ 81.1usftMD Reference:NPFReference Site:
TrueNorth Reference:0.9 usftSite Error:
Minimum CurvatureSurvey Calculation Method:PWD-02Reference Well:
Output errors are at 2.79 sigmaWell Error:0.9 usft
Reference Wellbore PWD-02 Database:EDM
Offset DatumReference Design:Plan: PWD-02 Rev E.1 Offset TVD Reference:
Interpolation Method:
Depth Range:
Reference
Error Model:
Scan Method:
Error Surface:
Filter type:
ISCWSA
Closest Approach 3D
Combined Pedal Curve
GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of refere
MD Interval 25.0usft
Unlimited
Maximum centre distance of 1,190.5usft
Plan: PWD-02 Rev E.1
Results Limited by:
SigmaWarning Levels Evaluated at:2.79 ISCWSA TESTCasing Method:
From
(usft)
Survey Tool Program
DescriptionTool NameSurvey (Wellbore)
To
(usft)
Date 30/01/2024
SDI_URSA1_I4 SDI URSA-1 gyroMWD (ISCWSA Rev 4)47.0 300.0 Plan: PWD-02 Rev E.1 (PWD-02)
3_MWD+IFR2+Sag A012Mb: IIFR dec correction + sag300.0 1,300.0 Plan: PWD-02 Rev E.1 (PWD-02)
3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sag300.0 2,525.0 Plan: PWD-02 Rev E.1 (PWD-02)
3_MWD+IFR2+Sag A012Mb: IIFR dec correction + sag2,525.0 3,525.0 Plan: PWD-02 Rev E.1 (PWD-02)
3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sag2,525.0 6,972.0 Plan: PWD-02 Rev E.1 (PWD-02)
3_MWD+IFR2+Sag A012Mb: IIFR dec correction + sag6,972.0 7,972.0 Plan: PWD-02 Rev E.1 (PWD-02)
3_MWD+IFR2+MS+Sag A013Mb: IIFR dec & multi-station analysis + sag6,972.0 9,952.3 Plan: PWD-02 Rev E.1 (PWD-02)
Offset Well - Wellbore - Design
Reference
Measured
Depth
(usft)
Offset
Measured
Depth
(usft)
Between
Centres
(usft)
Between
Ellipses
(usft)
Separation
Factor
Warning
Summary
Site Name
Distance
NPF
Level 4, CCPWD-01 - Wellbore #1 - 12.1 PWD1 1,082.0 1,007.0 16.4 2.9 1.666
Level 4, ES, SFPWD-01 - Wellbore #1 - 12.1 PWD1 1,125.0 1,049.9 16.7 2.5 1.584
CCPWD-03 - Wellbore #1 - 12.1 PWD3 623.4 540.5 14.7 4.7 2.176
ES, SFPWD-03 - Wellbore #1 - 12.1 PWD3 625.0 542.1 14.7 4.7 2.174
30/01/2024 16:20:20 COMPASS 5000.17 Build
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
Page 2
Santos Ltd
Anticollision Summary Report
Well PWD-02Local Co-ordinate Reference:SantosCompany:
Plan: Parker 272 @ 81.1usftTVD Reference:PikkaProject:
Plan: Parker 272 @ 81.1usftMD Reference:NPFReference Site:
TrueNorth Reference:0.9 usftSite Error:
Minimum CurvatureSurvey Calculation Method:PWD-02Reference Well:
Output errors are at 2.79 sigmaWell Error:0.9 usft
Reference Wellbore PWD-02 Database:EDM
Offset DatumReference Design:Plan: PWD-02 Rev E.1 Offset TVD Reference:
0
300
600
900
1200
Ce
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t
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p
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t
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0 700 1400 2100 2800 3500 4200
Measured Depth
Ladder Plot
PWD-01, Wellbore #1, 12.1 PWD1 V0 PWD-03, Wellbore #1, 12.1 PWD3 V0
L E G E N D
Coordinates are relative to: PWD-02
Coordinate System is US State Plane 1983, Alaska Zone 4
Grid Convergence at Surface is: -0.53°Central Meridian is 150° 0' 0.000 W
Offset Depths are relative to Offset Datum
Reference Depths are relative to Plan: Parker 272 @ 81.1usft
30/01/2024 16:20:20 COMPASS 5000.17 Build
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
Page 3
Santos Ltd
Anticollision Summary Report
Well PWD-02Local Co-ordinate Reference:SantosCompany:
Plan: Parker 272 @ 81.1usftTVD Reference:PikkaProject:
Plan: Parker 272 @ 81.1usftMD Reference:NPFReference Site:
TrueNorth Reference:0.9 usftSite Error:
Minimum CurvatureSurvey Calculation Method:PWD-02Reference Well:
Output errors are at 2.79 sigmaWell Error:0.9 usft
Reference Wellbore PWD-02 Database:EDM
Offset DatumReference Design:Plan: PWD-02 Rev E.1 Offset TVD Reference:
0.00
3.00
6.00
9.00
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t
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0 750 1500 2250 3000 3750
Measured Depth
Level 1
Level 3
Level 4
Separation Factor Plot
PWD-01, Wellbore #1, 12.1 PWD1 V0 PWD-03, Wellbore #1, 12.1 PWD3 V0
L E G E N D
Coordinates are relative to: PWD-02
Coordinate System is US State Plane 1983, Alaska Zone 4
Grid Convergence at Surface is: -0.53°Central Meridian is 150° 0' 0.000 W
Offset Depths are relative to Offset Datum
Reference Depths are relative to Plan: Parker 272 @ 81.1usft
30/01/2024 16:20:20 COMPASS 5000.17 Build
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
Page 4
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Plan: PWD-02 Rev E.1 Ladder View
0
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SURVEY PROGRAM
Depth From Depth To Survey/Plan Tool
47.0 300.0 Plan: PWD-02 Rev E.1 (PWD-02)SDI_URSA1_I4
300.0 1300.0 Plan: PWD-02 Rev E.1 (PWD-02)3_MWD+IFR2+Sag
300.0 2525.0 Plan: PWD-02 Rev E.1 (PWD-02)3_MWD+IFR2+MS+Sag
2525.0 3525.0 Plan: PWD-02 Rev E.1 (PWD-02)3_MWD+IFR2+Sag
2525.0 6972.0 Plan: PWD-02 Rev E.1 (PWD-02)3_MWD+IFR2+MS+Sag
6972.0 7972.0 Plan: PWD-02 Rev E.1 (PWD-02)3_MWD+IFR2+Sag
6972.0 9952.3 Plan: PWD-02 Rev E.1 (PWD-02)3_MWD+IFR2+MS+Sag
8:43, January 31 2024
CASING DETAILS
TVD MD Name
127.0 127.020" Conductor Casing
2306.0 2525.013-3/8" Surface Casing
6273.8 6972.09-5/8" Intermediate Casing
9253.8 9952.0 7"
Attachment 3: BOPE Equipment
21
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Attachment 4: Drilling Hazards
16” Surface Hole Section
Hazard Mitigations
Conductor Broach Monitor conductor for any indications of broaching. Monitor pit
volumes for any losses.
Gas Hydrates Keep mud cool, optimize pump rates, minimize any excess
circulation.
Lost Returns Pump LCM as required (consult prepared lost returns decisions
tree), slow pump rates, reduce ROP or trip speed when necessary.
Hole Swabbing Reduce tripping speed, lower mud rheology, pump out of the hole
if required.
Washouts/Hole Enlargement Keep mud cool, optimize pump rates, minimize any excess
circulation.
Tight Hole/Stuck Pipe Conduct wiper trip if required, drilling jars included in BHA,
monitor torque and drag trends.
Shallow Gas Shallow hazards assessment, sufficient mud weight, on site
surveillance (mud loggers, trained drilling personnel).
12-1/4” Intermediate Hole Section
Hazard Mitigations
Lost Returns Pump LCM as required (consult prepared lost returns decisions
tree), slow pump rates, reduce ROP or trip speed when necessary.
Monitor ECD with MWD tools. Run Circulation sub in BHA.
Hole Swabbing Reduce tripping speed, lower mud rheology, pump out of the hole
if required.
Washouts/Hole Enlargement Drill with oil-based mud, maintain mud in specifications, use
sufficient mud weight to hold back formations.
Tight Hole/Stuck Pipe Conduct wiper trip if required, drilling jars included in BHA,
monitor torque and drag trends, use sufficient mud weight to hold
back formations.
Open Hole Wireline Logging
Tight Hole
Ensure mud system is in spec prior to wireline logging, monitor for
tight spots during trip with BHA, equipment available for drill pipe
conveyed TLC wireline logging.
Pack Off During Cementing Proper wellbore cleanup procedure prior to running in hole. Stage
circulation rates up while running in hole with liner. Circulate
bottoms up at multiple depths to condition mud the way in the
hole. Circulate at TD to planned cementing rates and ensure hole
is clean.
8-1/2” Production Hole Section
Hazard Mitigations
Lost Returns Pump LCM as required (consult prepared lost returns decisions
tree), slow pump rates, reduce ROP or trip speed when necessary.
Monitor ECD with MWD tools.
Hole Swabbing Reduce tripping speed, lower mud rheology, pump out of the hole
if required.
Tight Hole/Stuck Pipe Conduct wiper trip if required, drilling jars included in BHA,
monitor torque and drag trends, use sufficient mud weight to hold
back formations.
Wellbore Instability Maintain adequate mud weight for wellbore stability. Monitor
cuttings returns, LWD logs, and drilling parameters for signs of
washout.
Pack Off During Cementing Proper wellbore cleanup procedure prior to running in hole. Stage
circulation rates up while running in hole with liner. Circulate
bottoms up at multiple depths to condition mud the way in the
hole. Circulate at TD to planned cementing rates and ensure hole
is clean.
* Note that no H2S has been encountered on nearby offset wells, and H2S is not anticipated in this well.
Attachment 5: Leak Off Test Procedure
1. Drill out shoe track, cement plus minimum of 20’ of new formation. Circulate bottoms up and
confirm cuttings are observed at surface.
2. Circulate and condition the mud:
a. While circulating the hole clean of cuttings, circulate/ treat the mud to achieve desired
mud properties. Consider pulling the bit into the casing shoe to prevent wash out.
b. Accurately measure the mud weight with a recently calibrated pressurized mud balance;
c. Confirm that mud weight-in is equal to mud weight-out;
d. Do not change the mud weight until after the test.
3. Pull the bit back into the casing shoe.
4. Rig up high pressure lines as required to pump down the drill string. Pressure test lines to above
expected test pressure.
a. Record pressure at surface with calibrated chart recorder.
5. Break circulation down the string.
6. Verify the hole is filled up and close the BOP (annular or upper pipe ram).
7. Perform the LOT or FIT pumping at a constant rate of 0.25bbl/min. Record pump pressures at
0.25bbl increments.
8. Record and plot the volume pumped against pressure until leak-off is observed, or until the
predetermined limit pressure/EMW has been reached for a FIT.
a. Leak-off is defined as the first point on the volume/pressure plot where either the initial
static pressure or the final static pressure deviates from the trend observed in the
previous observations.
b. If the pump pressure suddenly drops, stop pumping but keep the well closed in. This
indicates a leak in the system, cement failure or formation breakdown. Record the
pressures every minute until they stabilize. If the drop in pressure is related to formation
breakdown, this data can be used to derive the minimum in-situ stress.
c. If FIT skip step 9.
9. Once a leak off is observed pump an additional 0.75bbls to confirm the leak off.
10. Stop pumping, shut in and record pressures. Monitor shut-in pressure for 10 min. Record initial
shut-in pressure 10 seconds after shutting in. Then record pressures at thirty second increments
for the first five minutes and then every one minute for the remainder of the shut in period.
11. If the pressure does not stabilize, this may be an indication of a system leak or a poor cement
bond.
12. Bleed off pressure (through annulus if a float is in the string) and record the volume returned to
establish the volume of mud lost to the formation. Top up and close the annulus valve between
the casing and the previous casing string.
13. Open the BOP.
Attachment 6: Cement Summary
Surface Casing Cement
Casing
Size 13-3/8” 68# L-80 BTC Surface Casing
Basis
Lead Open hole volume + 250% excess in permafrost / 50% excess below permafrost
Lead TOC Surface
Tail Open hole volume + 50% excess + 80 ft shoe track
Tail TOC 500 ft MD above casing shoe
Total
Cement
Volume
Spacer ~80 bbls of 10.5 ppg Clean Spacer
Lead 11.0ppg Lead: 417.0 bbls, 2341.6 cuft, 923.7 sks ArcticCem, Yield: 2.535 cuft/sk
Tail 15.3ppg Tail: 68.9 bbls, 386.9 cuft, 312.0 sks HalCem Type I/II – 1.24 cuft/sk
Temp BHST 53° F
Verification Method Cement returns to surface.
Ultrasonic Wireline on Tail Cement.
Notes Job will be mixed on the fly
PWD-02 13-3/8" SURFACE CEMENT JOB
Description TOP BOTTOM LENGTH CAPACITY VOLUME (bbls)
Shoe track length 2440 2525 85 0.14973 12.7
TAIL LENGTH 2025 2525 500 0.07491 37.5
TAIL EXCESS 50% 18.7
LEAD TOP TO BASE OF PERMA 1387 2025 638 0.07491 47.8
EXCESS FACTOR FOR ABOVE 50% 23.9
PERMAFROST ANNULUS(Lead) 128 1387 1259 0.07491 94.3
EXCESS FACTOR FOR ABOVE 250% 235.8
CASED HOLE ANNULUS 46 128 82 0.18620 15.3
Intermediate Liner Cement
Casing
Size 9-5/8” 47# L-80 Hydril 563 Intermediate Liner
Basis
Lead N/A
Lead TOC N/A
Tail Open hole volume + 30% excess + 150’ liner lap + 85 ft shoe track
Tail TOC Top of Liner
Total
Cement
Volume
Spacer ~80 bbls of 13.5 ppg Spacer
Lead N/A
Tail 14.5ppg Tail: 337.7 bbls, 1896.0 cuft, 1358.1sks ExtendaCem – 1.396 cuft/sk
Temp BHST 140° F
Notes Job will be mixed on the fly.
Densities/excess may be adjusted during detailed engineered cement design.
Verification Method Cement returns off liner top.
Ultrasonic Wireline.
Verified cement calcs - bjm
PWD-02 9.625" INTERMEDIATE LINER CEMENT JOB
Description TOP BOTTOM LENGTH CAPACITY VOLUME (bbls)
Shoe track length 6887 6972 85 0.07321 6.2
TAIL LENGTH 2525 6972 4447 0.05578 248.1
TAIL EXCESS 30% 74.4
Liner Lap 13-3/8" 68# x
9-5/8" 47# LNR
2375 2525 150 0.05974 9.0
Production Liner Cement
Casing
Size 7” 26# L-80 Hydril 563 Intermediate Liner
Basis
Lead N/A
Lead TOC N/A
Tail Open hole volume + 30% excess + 120 ft shoe track
Tail TOC 500’ MD above the Ivishak Injection Disposal Zone
Total
Cement
Volume
Spacer ~80 bbls of 13.5 ppg Spacer
Lead N/A
Tail 15.3ppg Tail:42.0 bbls, 235.8 cuft, 190.2 sks HalCem Type I/II – 1.24 cuft/sk
Temp BHST 199° F
Notes
Job will be mixed on the fly.
Cement is not planned across the Alpine formation, as no significant
hydrocarbons are expected. If greater than 5 ft of continuous net pay is
encountered (based on real-time log data), the cement plan will be adjusted to
cement that formation as per AOGCC Regulation 20 AAC 25.030 (d)(5).
Verification Method Ultrasonic Wireline.
PWD-02 7" PRODUCTION LINER CEMENT JOB
Description TOP BOTTOM LENGTH CAPACITY VOLUME (bbls)
Shoe track length 9832 9952 120 0.03826 4.6
TAIL LENGTH 8678 9952 1274 0.02259 28.8
TAIL EXCESS 30% 8.6
verified cement calcs. -bjm
Send AOGCC field-quality well log curves, directional survey, formation picks, and evaluation of significant
HC as soon as available and before cementing production liner. -A.Dewhurst 22FEB24
verified cement calcs. -bjm
Attachment 7: Prognosed Formation Tops
PWD-02 Prognosed Tops
Formation MD
(ft)
TVD KB
(ft)
TVD Path
(ft)
Uncertainty
Range
(±ft)
Pore Pressure
(ppg)
Upper Schrader Bluff 1036.2 1025.1 944.0 100 7.14
Permafrost Base 1386.5 1355.1 1274.0 100 7.26
Middle Schrader Bluff 1816.8 1725.4 1644.3 100 7.55
MCU 2341.9 2155.9 2074.8 100 7.77
Tuluvak Shale 2860.5 2581.1 2500.0 100 7.91
Tuluvak Sand 2937.6 2644.3 2563.2 100 9.79
Seabee 3645.4 3224.6 3143.5 100 9.13
Nanushuk 4559.8 3974.3 3893.2 100 8.84
NT7 MFS 4744.2 4125.5 4044.4 100 8.77
NT6 MFS 4938.4 4287.7 4206.6 100 8.69
NT5 MFS 5368.8 4679.8 4598.7 100 8.62
NT4 MFS 5960.7 5262.5 5181.4 100 8.60
NT3 MFS 6144.6 5446.4 5365.3 100 8.60
NT2 MFS 6323.0 5624.8 5543.7 100 8.60
NT1 MFS 6444.5 5746.3 5665.2 100 8.59
Top HRZ 6633.8 5935.7 5854.5 100 9.98
Kalubik 6771.3 6073.1 5992.0 100 9.92
Kuparuk C 6986.7 6288.5 6207.4 100 9.82
UJU 7341.8 6643.6 6562.5 100 9.43
Upper Kingak 7474.2 6776.0 6694.9 100 9.64
Middle kingak 7907.3 7209.1 7128.0 100 9.63
Lower Kingak 8288.4 7590.2 7509.1 100 9.65
Shublik 8826.2 8128.0 8046.9 100 9.56
Ivishak 9178.3 8480.1 8399.0 100 9.51
Kavik 9802.3 9104.1 9023.0 100 9.42
Attachment 8: Well Schematic
Attachment 9: Formation Evaluation Program
16” Surface Hole
LWD
Gamma Ray
Resistivity
Multipole Sonic
Cased Hole Wireline Ultra Sonic Cement Evaluation – Tail Only
12-1/4” Intermediate Hole
LWD
Gamma Ray
Resistivity
Density Neutron
NMR
Multipole Sonic
Open Hole Wireline
Gamma Ray
Image
Rotary Sidewall Cores
Formation Fluid/Pressure Samples
Cased Hole Wireline Ultra Sonic Cement Evaluation
8-1/2” Production Hole
LWD
Gamma Ray
Resistivity
Multipole Sonic
Density Neutron
Cased Hole Wireline Ultra Sonic Cement Evaluation
Mudlogging
Mudlogging will be utilized from surface to TD on PWD-02.
For PWD-02, from the surface to TD, cutting samples will be collected, dried, and washed at intervals
ranging from 30-50 ft MD. Zones with high ROPs exceeding 5 samples per hour, or those that do not
provide any additional marketable geologic value, will have an increased sample interval, up to 50 ft MD.
Specifically, over the Ivishak Formation (~600 ft MD; 600 ft TVD), the sample interval will be held at 50 ft
MD, as per the reasons previously stated. All sample depths collected will be provided in a sample set
submitted to the AOGCC per Regulation 20 AAC 25.071(b)(2).
Sample interval in Ivishak not to exceed 30'. -A.Dewhurst 22FEB24
Attachment 10: Wellhead & Tree Diagram
Attachment 11: Injector Area of Review
Wells within
¼ mile of
proposed
injection
well.
Distance Annulus
integrity
Area of Review Information
None N/A N/A N/A
1
Christianson, Grace K (OGC)
From:Staudinger, Mark (Mark) <Mark.Staudinger@santos.com>
Sent:Thursday, February 22, 2024 4:24 PM
To:McLellan, Bryan J (OGC)
Cc:Dewhurst, Andrew D (OGC); Davies, Stephen F (OGC); Guthrie, Eileen (Eileen)
Subject:RE: PWD-02 Shallow gas
Bryan,
YesOilSearch’soriginalpreͲdrillshallowhazardsassessmentcoveredboththeNDBandNPFpadareas.Theassessment
forbothpadlocaƟonsishydrateswithinthesurfaceholeinterval,andfreegaswithintheTuluvak,aswehaveseenat
NDB.IfyouwouldlikefurtherinformaƟon,I’vecc’edthedevelopmentgeologist,EileenGuthrie,whocouldanswerany
detailedquesƟonsyoumayhave.
Thanks,
Mark
MarkStaudinger
SeniorDrillingEngineer
t:+1(907)375Ͳ4654|m:+1(520)273Ͳ6643|e:Mark.Staudinger@santos.com
Santos.com|FollowusonLinkedIn,FacebookandTwiƩer
From:McLellan,BryanJ(OGC)<bryan.mclellan@alaska.gov>
Sent:Thursday,February22,20243:28PM
To:Staudinger,Mark(Mark)<Mark.Staudinger@santos.com>
Cc:Dewhurst,AndrewD(OGC)<andrew.dewhurst@alaska.gov>;Davies,StephenF(OGC)<steve.davies@alaska.gov>
Subject:![EXT]:PWDͲ02Shallowgas
Mark,
Thiswellisbeingdrilledquiteadistancefromotherwellsinthearea.HasOilsearchdoneanassessmentofshallowgas
riskinthesurfaceholesecƟon?
BryanMcLellan
SeniorPetroleumEngineer
AlaskaOil&GasConservationCommission
Bryan.mclellan@alaska.gov
+1(907)250Ͳ9193
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
Santos Ltd A.B.N. 80 007 550 923
Disclaimer: The information contained in this email is intended only for the use of the person(s) to whom it is addressed and may be confidential or contain
privileged information. If you are not the intended recipient you are hereby notified that any perusal, use, distribution, copying or disclosure is strictly prohibited. If
you have received this email in error please immediately advise us by return email and delete the email without making a copy.Please consider the environment
before printing this email
1
Christianson, Grace K (OGC)
From:Staudinger, Mark (Mark) <Mark.Staudinger@santos.com>
Sent:Thursday, February 22, 2024 4:24 PM
To:McLellan, Bryan J (OGC)
Cc:Dewhurst, Andrew D (OGC); Davies, Stephen F (OGC); Guthrie, Eileen (Eileen)
Subject:RE: PWD-02 Shallow gas
Bryan,
YesOilSearch’soriginalpreͲdrillshallowhazardsassessmentcoveredboththeNDBandNPFpadareas.Theassessment
forbothpadlocaƟonsishydrateswithinthesurfaceholeinterval,andfreegaswithintheTuluvak,aswehaveseenat
NDB.IfyouwouldlikefurtherinformaƟon,I’vecc’edthedevelopmentgeologist,EileenGuthrie,whocouldanswerany
detailedquesƟonsyoumayhave.
Thanks,
Mark
MarkStaudinger
SeniorDrillingEngineer
t:+1(907)375Ͳ4654|m:+1(520)273Ͳ6643|e:Mark.Staudinger@santos.com
Santos.com|FollowusonLinkedIn,FacebookandTwiƩer
From:McLellan,BryanJ(OGC)<bryan.mclellan@alaska.gov>
Sent:Thursday,February22,20243:28PM
To:Staudinger,Mark(Mark)<Mark.Staudinger@santos.com>
Cc:Dewhurst,AndrewD(OGC)<andrew.dewhurst@alaska.gov>;Davies,StephenF(OGC)<steve.davies@alaska.gov>
Subject:![EXT]:PWDͲ02Shallowgas
Mark,
Thiswellisbeingdrilledquiteadistancefromotherwellsinthearea.HasOilsearchdoneanassessmentofshallowgas
riskinthesurfaceholesecƟon?
BryanMcLellan
SeniorPetroleumEngineer
AlaskaOil&GasConservationCommission
Bryan.mclellan@alaska.gov
+1(907)250Ͳ9193
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
Santos Ltd A.B.N. 80 007 550 923
Disclaimer: The information contained in this email is intended only for the use of the person(s) to whom it is addressed and may be confidential or contain
privileged information. If you are not the intended recipient you are hereby notified that any perusal, use, distribution, copying or disclosure is strictly prohibited. If
you have received this email in error please immediately advise us by return email and delete the email without making a copy.Please consider the environment
before printing this email
1
Dewhurst, Andrew D (OGC)
From:Dewhurst, Andrew D (OGC)
Sent:Thursday, February 22, 2024 08:39
To:Staudinger, Mark (Mark)
Cc:Roby, David S (OGC); McLellan, Bryan J (OGC); Davies, Stephen F (OGC); Guhl, Meredith D (OGC); Noll, Christian
(Christian); Sherry, Patrick F (LAW); Tirpack, Robert (Robert)
Subject:RE: Pikka PWD-02 (PTD 224-009) - Confidentiality
Mark,
Understood. And yes, we can remove the variance request. We will continue the review process under the Service well
class as currently exists.
Andy
From: Staudinger, Mark (Mark) <Mark.Staudinger@santos.com>
Sent: Thursday, February 22, 2024 08:35
To: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Cc: Roby, David S (OGC) <dave.roby@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Davies,
Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Noll, Christian
(Christian) <Christian.Noll@santos.com>; Sherry, Patrick F (LAW) <patrick.sherry@alaska.gov>; Tirpack, Robert (Robert)
<Robert.Tirpack@santos.com>
Subject: Re: Pikka PWD-02 (PTD 224-009) - Confidentiality
Andy,
We discussed as a team and have elected to keep the permit application as-is (permit as a service well). We don't want
to further delay the permitting process or operate under exploratory regulation requirements.
I'm assuming you can just remove the specific variance request in the PTD application?
Thanks,
Mark Staudinger
520-273-6643
Get Outlook for iOS
From: Staudinger, Mark (Mark) <Mark.Staudinger@santos.com>
Sent: Friday, February 16, 2024 7:24 AM
To: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Cc: Roby, David S (OGC) <dave.roby@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Davies,
Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Noll, Christian
(Christian) <Christian.Noll@santos.com>; Sherry, Patrick F (LAW) <patrick.sherry@alaska.gov>; Tirpack, Robert (Robert)
<Robert.Tirpack@santos.com>
Subject: RE: Pikka PWD-02 (PTD 224-009) - Confidentiality
You don't often get email from mark.staudinger@santos.com. Learn why this is important
CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open
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2
Andy,
Thank you. Oil Search is aware of the requirements in AS 31.05.035(a) and 20 AAC 25.071 to file logs and geologic data.
Oil Search also understands that confidentiality is not typically granted to service well information.
The PWD-02 well is being drilled to a location outside of the existing Nanushuk Oil Pool (NOP) and includes plans to
gather enhanced data not normally collected in a service well program. This data collection will serve to delineate the
Nanushuk reservoir outside of the existing NOP.
Due to this enhanced data gathering program and its location outside of an existing pool, Oil Search is requesting a
variance from the requirements of 20 AAC 25.537(a)(3) and asks that the logs and geologic data submitted for the PWD-
02 well program and required by AS 31.05.035(a) and 20 AAC 25.071 to be held confidential in accordance with 20 AAC
25.537(d). Oil Search also requests that any information not required by 20 AAC 25 for a service well but voluntarily filed
with the Commission be kept confidential in accordance with 20 AAC 25.537(b).
Please let me know if you have any questions.
Regards,
Mark
Mark Staudinger
Senior Drilling Engineer
t: +1 (907) 375-4654 | m: +1 (520) 273-6643 | e: Mark.Staudinger@santos.com
Santos.com | Follow us on LinkedIn, Facebook and Twitter
From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Sent: Thursday, February 15, 2024 12:21 PM
To: Staudinger, Mark (Mark) <Mark.Staudinger@santos.com>
Cc: Roby, David S (OGC) <dave.roby@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Davies,
Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Noll, Christian
(Christian) <Christian.Noll@santos.com>; Sherry, Patrick F (LAW) <patrick.sherry@alaska.gov>
Subject: ![EXT]: Pikka PWD-02 (PTD 224-009) - Confidentiality
Mark,
We are reviewing the PTD application for the Pikka PWD-02 (PTD 224-009) well and wanted to provide a statement on
Oil Search’s request for confidentiality.
Logs and geologic data required to be filed with the commission are specified in AS 31.05.035(a) and 20 AAC 25.071.
Confidentiality is not granted to service wells as covered in AS 31.05.035(c) and 20 AAC 25.537(a)(3).
Andy
Andrew Dewhurst
Senior Petroleum Geologist
Alaska Oil and Gas Conservation Commission
333 W. 7th Ave, Anchorage, AK 99501
andrew.dewhurst@alaska.gov
3
Direct: (907) 793-1254
Santos Ltd A.B.N. 80 007 550 923
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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.
224-009
Pikka PWD-02
see note below
UNDEFINED WDSPPIKKA
-A.Dewhurst 22FEB24
Proposed dry ditch sample interval from Attachment 9 accepted with modification of Ivishak (not to exceed 30').
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l
PT
D
#
:
22
4
0
0
9
0
PI
K
K
A
,
U
N
D
E
F
I
N
E
D
W
D
S
P
-
6
0
0
0
3
6
NA
1
P
e
r
m
i
t
f
e
e
a
t
t
a
c
h
e
d
Ye
s
A
D
L
3
9
2
9
6
4
2
L
e
a
s
e
n
u
m
b
e
r
a
p
p
r
o
p
r
i
a
t
e
Ye
s
3
U
n
i
q
u
e
w
e
l
l
n
a
m
e
a
n
d
n
u
m
b
e
r
Ye
s
P
I
K
K
A
,
U
N
D
E
F
I
N
E
D
W
D
S
P
-
6
0
0
0
3
6
-
g
o
v
e
r
n
e
d
b
y
S
t
a
t
e
w
i
d
e
R
e
g
s
4
W
e
l
l
l
o
c
a
t
e
d
i
n
a
d
e
f
i
n
e
d
p
o
o
l
Ye
s
L
e
s
s
t
h
a
n
5
0
0
'
f
r
o
m
u
n
i
t
b
o
u
n
d
a
r
y
,
b
u
t
n
o
c
h
a
n
g
e
i
n
o
w
n
e
r
s
h
i
p
5
W
e
l
l
l
o
c
a
t
e
d
p
r
o
p
e
r
d
i
s
t
a
n
c
e
f
r
o
m
d
r
i
l
l
i
n
g
u
n
i
t
b
o
u
n
d
a
r
y
NA
6
W
e
l
l
l
o
c
a
t
e
d
p
r
o
p
e
r
d
i
s
t
a
n
c
e
f
r
o
m
o
t
h
e
r
w
e
l
l
s
Ye
s
7
S
u
f
f
i
c
i
e
n
t
a
c
r
e
a
g
e
a
v
a
i
l
a
b
l
e
i
n
d
r
i
l
l
i
n
g
u
n
i
t
Ye
s
8
I
f
d
e
v
i
a
t
e
d
,
i
s
w
e
l
l
b
o
r
e
p
l
a
t
i
n
c
l
u
d
e
d
Ye
s
9
O
p
e
r
a
t
o
r
o
n
l
y
a
f
f
e
c
t
e
d
p
a
r
t
y
Ye
s
E
P
A
C
l
a
s
s
1
d
i
s
p
o
s
a
l
w
e
l
l
w
i
t
h
s
e
p
a
r
a
t
e
E
P
A
b
o
n
d
i
n
g
.
C
o
v
e
r
e
d
i
n
O
O
1
9
7
10
O
p
e
r
a
t
o
r
h
a
s
a
p
p
r
o
p
r
i
a
t
e
b
o
n
d
i
n
f
o
r
c
e
Ye
s
11
P
e
r
m
i
t
c
a
n
b
e
i
s
s
u
e
d
w
i
t
h
o
u
t
c
o
n
s
e
r
v
a
t
i
o
n
o
r
d
e
r
Ye
s
12
P
e
r
m
i
t
c
a
n
b
e
i
s
s
u
e
d
w
i
t
h
o
u
t
a
d
m
i
n
i
s
t
r
a
t
i
v
e
a
p
p
r
o
v
a
l
Ye
s
13
C
a
n
p
e
r
m
i
t
b
e
a
p
p
r
o
v
e
d
b
e
f
o
r
e
1
5
-
d
a
y
w
a
i
t
No
E
P
A
C
l
a
s
s
I
d
i
s
p
o
s
a
l
w
e
l
l
P
e
r
m
i
t
N
u
m
b
e
r
:
A
K
-
1
I
0
2
4
-
A
14
W
e
l
l
l
o
c
a
t
e
d
w
i
t
h
i
n
a
r
e
a
a
n
d
s
t
r
a
t
a
a
u
t
h
o
r
i
z
e
d
b
y
I
n
j
e
c
t
i
o
n
O
r
d
e
r
#
(
p
u
t
I
O
#
i
n
c
o
m
m
e
n
t
s
)
(
F
o
r
Ye
s
n
o
n
e
15
A
l
l
w
e
l
l
s
w
i
t
h
i
n
1
/
4
m
i
l
e
a
r
e
a
o
f
r
e
v
i
e
w
i
d
e
n
t
i
f
i
e
d
(
F
o
r
s
e
r
v
i
c
e
w
e
l
l
o
n
l
y
)
No
16
P
r
e
-
p
r
o
d
u
c
e
d
i
n
j
e
c
t
o
r
:
d
u
r
a
t
i
o
n
o
f
p
r
e
-
p
r
o
d
u
c
t
i
o
n
l
e
s
s
t
h
a
n
3
m
o
n
t
h
s
(
F
o
r
s
e
r
v
i
c
e
w
e
l
l
o
n
l
y
)
NA
17
N
o
n
c
o
n
v
e
n
.
g
a
s
c
o
n
f
o
r
m
s
t
o
A
S
3
1
.
0
5
.
0
3
0
(
j
.
1
.
A
)
,
(
j
.
2
.
A
-
D
)
Ye
s
18
C
o
n
d
u
c
t
o
r
s
t
r
i
n
g
p
r
o
v
i
d
e
d
Ye
s
19
S
u
r
f
a
c
e
c
a
s
i
n
g
p
r
o
t
e
c
t
s
a
l
l
k
n
o
w
n
U
S
D
W
s
Ye
s
20
C
M
T
v
o
l
a
d
e
q
u
a
t
e
t
o
c
i
r
c
u
l
a
t
e
o
n
c
o
n
d
u
c
t
o
r
&
s
u
r
f
c
s
g
Ye
s
21
C
M
T
v
o
l
a
d
e
q
u
a
t
e
t
o
t
i
e
-
i
n
l
o
n
g
s
t
r
i
n
g
t
o
s
u
r
f
c
s
g
Ye
s
22
C
M
T
w
i
l
l
c
o
v
e
r
a
l
l
k
n
o
w
n
p
r
o
d
u
c
t
i
v
e
h
o
r
i
z
o
n
s
Ye
s
23
C
a
s
i
n
g
d
e
s
i
g
n
s
a
d
e
q
u
a
t
e
f
o
r
C
,
T
,
B
&
p
e
r
m
a
f
r
o
s
t
Ye
s
24
A
d
e
q
u
a
t
e
t
a
n
k
a
g
e
o
r
r
e
s
e
r
v
e
p
i
t
NA
25
I
f
a
r
e
-
d
r
i
l
l
,
h
a
s
a
1
0
-
4
0
3
f
o
r
a
b
a
n
d
o
n
m
e
n
t
b
e
e
n
a
p
p
r
o
v
e
d
Ye
s
26
A
d
e
q
u
a
t
e
w
e
l
l
b
o
r
e
s
e
p
a
r
a
t
i
o
n
p
r
o
p
o
s
e
d
Ye
s
27
I
f
d
i
v
e
r
t
e
r
r
e
q
u
i
r
e
d
,
d
o
e
s
i
t
m
e
e
t
r
e
g
u
l
a
t
i
o
n
s
Ye
s
28
D
r
i
l
l
i
n
g
f
l
u
i
d
p
r
o
g
r
a
m
s
c
h
e
m
a
t
i
c
&
e
q
u
i
p
l
i
s
t
a
d
e
q
u
a
t
e
Ye
s
29
B
O
P
E
s
,
d
o
t
h
e
y
m
e
e
t
r
e
g
u
l
a
t
i
o
n
Ye
s
M
P
S
P
=
3
6
4
6
p
s
i
.
B
O
P
r
a
t
e
d
t
o
5
0
0
0
p
s
i
.
(
B
O
P
t
e
s
t
t
o
4
0
0
0
p
s
i
)
30
B
O
P
E
p
r
e
s
s
r
a
t
i
n
g
a
p
p
r
o
p
r
i
a
t
e
;
t
e
s
t
t
o
(
p
u
t
p
s
i
g
i
n
c
o
m
m
e
n
t
s
)
Ye
s
31
C
h
o
k
e
m
a
n
i
f
o
l
d
c
o
m
p
l
i
e
s
w
/
A
P
I
R
P
-
5
3
(
M
a
y
8
4
)
Ye
s
32
W
o
r
k
w
i
l
l
o
c
c
u
r
w
i
t
h
o
u
t
o
p
e
r
a
t
i
o
n
s
h
u
t
d
o
w
n
No
33
I
s
p
r
e
s
e
n
c
e
o
f
H
2
S
g
a
s
p
r
o
b
a
b
l
e
NA
34
M
e
c
h
a
n
i
c
a
l
c
o
n
d
i
t
i
o
n
o
f
w
e
l
l
s
w
i
t
h
i
n
A
O
R
v
e
r
i
f
i
e
d
(
F
o
r
s
e
r
v
i
c
e
w
e
l
l
o
n
l
y
)
Ye
s
H
2
S
n
o
t
a
n
t
i
c
i
p
a
t
e
d
a
t
t
h
i
s
w
e
l
l
35
P
e
r
m
i
t
c
a
n
b
e
i
s
s
u
e
d
w
/
o
h
y
d
r
o
g
e
n
s
u
l
f
i
d
e
m
e
a
s
u
r
e
s
Ye
s
S
h
a
l
l
o
w
g
a
s
a
n
t
i
c
i
p
a
t
e
d
a
t
T
u
l
u
v
a
k
.
M
a
x
p
r
e
s
s
u
r
e
g
r
a
d
i
e
n
t
e
x
p
e
c
t
e
d
i
n
H
R
Z
w
i
t
h
9
.
9
8
p
p
g
E
M
W
36
D
a
t
a
p
r
e
s
e
n
t
e
d
o
n
p
o
t
e
n
t
i
a
l
o
v
e
r
p
r
e
s
s
u
r
e
z
o
n
e
s
NA
37
S
e
i
s
m
i
c
a
n
a
l
y
s
i
s
o
f
s
h
a
l
l
o
w
g
a
s
z
o
n
e
s
NA
38
S
e
a
b
e
d
c
o
n
d
i
t
i
o
n
s
u
r
v
e
y
(
i
f
o
f
f
-
s
h
o
r
e
)
NA
39
C
o
n
t
a
c
t
n
a
m
e
/
p
h
o
n
e
f
o
r
w
e
e
k
l
y
p
r
o
g
r
e
s
s
r
e
p
o
r
t
s
[
e
x
p
l
o
r
a
t
o
r
y
o
n
l
y
]
Ap
p
r
AD
D
Da
t
e
2/
2
2
/
2
0
2
4
Ap
p
r
BJ
M
Da
t
e
2/
2
3
/
2
0
2
4
Ap
p
r
AD
D
Da
t
e
2/
2
0
/
2
0
2
4
Ad
m
i
n
i
s
t
r
a
t
i
o
n
En
g
i
n
e
e
r
i
n
g
Ge
o
l
o
g
y
Ge
o
l
o
g
i
c
Co
m
m
i
s
s
i
o
n
e
r
:
Da
t
e
:
En
g
i
n
e
e
r
i
n
g
Co
m
m
i
s
s
i
o
n
e
r
:
Da
t
e
Pu
b
l
i
c
Co
m
m
i
s
s
i
o
n
e
r
Da
t
e
*&
:
JL
C
2
/
2
6
/
2
0
2
4
