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M.
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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
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REASON FOR TRANSMITTAL:
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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
DW-02 50103208550000
ؐؐDW-02 Lithotrak Caliper data
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
(�-f� 2z3G390
Regg, James B (OGC)
From:
Gathman, Brad / Frazier, Nick (OSH.Lead.Comp.Super)
< Lead.Com p.Super@santos.com>
Sent:
Monday, February 3, 2025 11:00 AM
To:
Regg, James B (OGC); DOA AOGCC Prudhoe Bay, Brooks, Phoebe L (OGC); Wallace,
Chris D (OGC)
Cc:
Senden, Robert (Ty); Gathman, Brad (Brad); Rauchenstein, William (Rock)
Subject:
DW-02 MIT -IA 02.01.2025
Attachments:
DW-02 MIT -IA 02.01.2025.xlsx
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.
Attached is the MIT -IA test form for DW-02 conducted 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
•
mobile: +1 (907) 830-9463
office: +1 (907) 685-4245
e-mail: tead...Gomp.SUp.er@s-anto.s c.om
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
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
Mechanical Integrity Test
Submit to iim.Guat0alaska.00v A0GCC.Insoectors0alaska. Gov: ohoebe.brooks0alaska.aov
OPERATOR:
Oil Search (Santos)
FIELD/UNIT/PAD:
Pikka I NDB
DATE:
02/01125
OPERATOR REP:
Nick Frazier
AOGCC REP:
Adam Earl Waived. EPA onsite for witness. ✓
Chris wallace0alaska.Gov
Well
DW-02
Pressures: Pretest Initial 15 Min. 30 Min. 45 Min, 60 Min.
PTD
223-039
Type ITT
N
Tubing
50
1546 -
1564
1572
Type Test
P
Packer TVD
5690
BBL Pump
1 14
IA
9
4401
4368
4357
Interval
I
Test psi
4000
BBL Return
1 1 d
OA
204
999 -1
965
1 947
Result
P
Natx:
MIT -IA post completion. Witnessed by EPA Evan Osborne and James PM1illips.
Well
Pressures. Pretest Initial 15 Min. 30 MIn. 45 Min. 60 Min.
PTO
Type Inj
Tubing
Type Test
Packer TVD
BBL Pump
IA
Interval
Test psi
BBL Return
OA
Result
Notes:
Well
Pressures: Pretest Install 15 Min. 30 Min. 45 Min. 60 Min.
PTD
Type lnj
Tubing
Type Test
Packer TVD
BBL Pump
IA
Interval
Test psi
BBL Return
OA
Result
Notes:
Well
Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD
Type lnj
Tubing
Type Test
PackerWD
BBL Pump
IA
Interval
Test psi
BBL Return
OA
Result
Notes:
Well
Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 50 Min.
PTD
Type Inj
Tubing
Type Test
Packer TVD
BBL Pump
IA
Interval
Test psi
BBL Return
OA
Result
house:
Well
Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD
Type Inj
Tubing
Type Tesl
Packer TVD
B8L Pump
IA
Interval
Test psi
BBL Return
OA
Result
Notes:
Well
Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD
Type Inj
Tubing
Type Tell
Packer TVD
BBL Pump
IA
Interval
Test psi
BBL Return
OA
Result
Notes:
Wall
Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD
Type lnj
Tubing
Type Test
Packer TVD
BBL Pump
IA
Interval
Test psi
BBL Return
OA
Result
Notes:
TYPE [NJ Cafes
TYPE TEST Cause
INTERVAL Cocoa
Reeun Codes
W=Wao
P=Preesme Taw
1=1nNal Test
P=Pau
G=Gas
0= 01per NesctlMN Notes)
4=Four Year Cycle
F-Fall
5=slurry
V=ReaWeU, Vananm
I - Inccndmive
I=IMusuall wastewaar
0=Mar sacs o,n roles)
N-Nm scon,
Form 10426 (Revised 01/2017)
DW-02 MITIA02 01.2025
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 7,693' feet N/A feet
true vertical 6,265'feet N/A feet
Effective Depth measured N/A feet 7,087' feet
true vertical N/A feet 5,696' feet
Perforation depth Measured depth 7,240' - 7,270'feet
True Vertical depth 5,839' - 5,867'feet
Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6ppf P-110S 7,109' MD 5,717' TVD
Packers and SSSV (type, measured and true vertical depth) Production Packer 7,087' MD 5,696' TVD
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: 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:
Jose Gonzalez
Contact Email:jose.gonzalez@contractor.santos.com
Authorized Title: Sr. Completions Engineer Contact Phone:
346-413-9028
2,247'
Burst Collapse
4,750
measured
TVD
Tieback
Tubing
5267'
2426'
7109'
Casing
Structural
6,265'
2,136'
4.5"
7,693'
2,426'
7,109' 5,717'
Plugs
Junk measured
N/A
Length
128'
2574'
128'Conductor
Surface
Production
20"
9-5/8"
N/A
5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work:
ADL 392984, 391445
Pikka / Undefined Waste Disposal Pool
Pikka DW-02
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
223-039
50-103-20855-00-00
601 W 5th Avenue
Anchorage, AK 99501
3. Address:
7"
8,430
7"
5,410
5,410
7,240
7,240
measured
true vertical
Packer
Representative Daily Average Production or Injection Data
Casing Pressure Tubing PressureGas-Mcf
MDSize
128'
6,8702,574'
324-571
Sr Pet Eng:
7,500
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)
ppp p
ckkk
fttt
ntttttttt e
Fra
O
g
g
s O
g
y 223
e 6. A
y
G
L
PG
25.070, 2
Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov
e foregoing is true and correc
Feb 5th, 2025
By Gavin Gluyas at 3:03 pm, Feb 05, 2025
RBDMS JSB 021825
DSR-2/18/25BJM 3/12/25
A.Dewhurst 04MAR25
Workover Ops Summary Report - AOGCC
Start Date End Date Summary
1/16/2025 1/17/2025 No accidents, incidents or spills.
RDMO PWD-02 well / NPF pad. Move rig to NDP pad. MIRU on DW-02.
1/17/2025 1/18/2025 No accidents, incidents or spills.
Complete MIRU on DW-02. Set rig & check level. Work on rig acceptance checklist. Mobilize & install repaired stinger on
skate. Set all outbuildings. Dress derrick for racking pipe. Rig accepted 22:00 hrs.
January 16, 2025 @ 1pm emailed 48 Hr Notification to the AOGCC of BOPE test on January 18, 2025.
1/18/2025 1/19/2025 No accidents, incidents or spills.
Power up outbuildings, Complete containments around rig. Load & strap 4” DP & 4” HWDP to pipeshed. Take on 10.9 ppg
brine to pits. Install new mousehole. MU first stand 4” DP. Stop & discuss safety with crew, Santos Engineer & CM. Adjust
plan forward to single in 4” DP later in program steps. RU & test squeeze manifold to IA & Tubing.
1/19/2025 1/20/2025 No accidents, incidents or spills.
Bullhead 10.9 ppg brine to tubing & IA. Bleed & monitor increments for ballooning pressure from 1,200 psi to 0 psi. Monitor
30 mins - well static. Install TWCV. Test to 4,100 psi for 10 mins. ND production tree. Begin NU BOPE.
1/20/2025 1/21/2025 No accidents, incidents or spills.
Finish NU & test BOPE. AOGCC Rep Josh Hunt, Waived witness.
- 04:00 -12:00 hrs. All tests charted - 250 psi low, 4,000 psi high for 5 mins except manual operated & super choke tested
250 psi low & 2,000 psi high for 5 mins with 4” and 4 ½” test jts.
- Test annular to 250 psi low & 2,500 psi high, with 4” test jt.
- 3 ½” x 6” Upper rams, 2 7/8” x 5” LPR, test choke valves 1-15, Manual operated & super choke, choke & kill manuals, &
HCRs,4” valve on kill line, 4” FOSV, 4” Dart valve, Upper & lower IBOP, Blind Shear rams.
- All tests passed except manual choke F/P.
Perform rig evacuation drill, FMC pull TWC, Fill & monitor well / 30 mins. Well at 30 bph losses. Pull hanger and landing jt
with 160K PU. LD same. RU & POOH with 4 ½” JFE BEAR tubing to 5,200’.
1/21/2025 1/22/2025 No accidents, incidents or spills.
Continue POOH with 4 ½” JFE BEAR tubing from 5,200’ MD to surface. RD handling equipment. PU & MU Baker Milling
BHA #1, Single in hole on 4” DP with Baker milling BHA #1 to 1,404’ MD, Break circulation, overboard residual diesel to
cuttings box. Circulate surface to surface. Continue single in hole on 4” DP with Baker milling BHA #1 from 1,404’ MD to
3,658’MD. Perform kick while tripping drill.
1/22/2025 1/23/2025 No accidents, incidents or spills.
Continue single in hole on 4” DP with Baker milling BHA #1 from 1,404’ to 7,010’ MD. Kelly up & record parameters for Baker.
Wash & ream from 7,010’ to 7,040’ MD. Tag top of fish at 7,040’ MD. Troubleshoot top drive fault & weight indicator. Mill with
Baker milling BHA #1 from 7,040’ to 7,058’ MD.
1/23/2025 1/24/2025 No accidents, incidents or spills.
Mill with Baker milling BHA #1 @ 7,058’ MD. Decision to POOH & CO Baker Milling BHA. CBU w/ sweep. POOH & LD
milling BHA #1. PU milling BHA #2 to 2,611’. 1/2" Nylon lock nut came out derrick ladder. Stop operations and perform
Derrick inspection and reinstall and tighten Nylox nut. POOH with Baker milling BHA #1 from 2,611’ to 59’ MD. Clean
magnets and boot baskets. Trip in hole with Baker Milling BHA #2 on 4” stands from derrick to 2,831’ MD. Troubleshoot top
drive Dynamatic brake. PJSM with crew coming on hitch, Continue trip in hole with Baker Milling BHA #2 on 4” stands from
2,831’ to 5,033’ MD. Perform kick while tripping drill with new crew coming on hitch. New Crew perform site orientation.
Simops - Prep to offload 4 ½” tubing on drillers side backyard.
1/24/2025 1/25/2025 No accidents, incidents or spills.
Cont trip in hole with Baker Milling BHA #2 on 4” stands from 5,033' to 5,321’ MD. Snagged service loop on stand-pipe clamp
while TIH. Inspect & repair same. Cont trip in hole with Baker Milling BHA #2 on 4” stands from 5,321’ to 7,037’ MD. Wash &
ream in hole from 7,037’ to 7,056’ MD. Mill packer from 7,056’ to 7,058’ MD with no pumps. Chase packer to 7,133’ MD on
elevators. Repair skate cable. Perform derrick inspection. Hold Safety Stand Down. Perform DROPS Survey. Continue chase
packer from 7,133’ to 7,383' MD on elevators. Take weight at 7,383’ MD & work through to 7,385’ MD. Wash & ream in hole
from 7,385’ to 7,479’ MD. Circulate 30 bbl hi vis super sweep surface to surface. Perform flow check- Static. POOH with
Baker Milling BHA #2 on 4” stands from 7,479’ to 359’. Rack back 3 stds 4” HWDP. LD Baker Milling BHA #2 per Baker Rep.
Page of
Workover Ops Summary Report - AOGCC
Start Date End Date Summary
1/25/2025 1/26/2025 No accidents, incidents or spills.
PU & MU Baker Packer Retrieval BHA #3. RIH Baker BHA # 3 to 2,807’ MD. Experienced failure of Electric Dynamic braking
system. Trouble shoot Electric Dynamic brake issue. Simeops; Load, drift, strap & tally 4-½” completion tubing into pipeshed.
Hold PJSM, RIH w/ Baker BHA #3 from 2,807’ to 6,613’ MD. Dynomatic tripped breaker. Continue load, drift, strap & tally 4-
½” completion tubing into pipeshed. Electricians arrived 21:30 hrs to troubleshoot Dynomatic.
1/26/2025 1/27/2025 No accidents, incidents or spills.
Electricians troubleshoot Dynamatic, Isolate single coil, function test operation with empty blocks and with string weight.
Approval to continue operations given by Doyon and Santos supervisory staff, Continue RIH to TOF at 7,480’ MD & engage
fish per Baker Rep. POOH with fish to 339’ MD. LD accelerator & rack back 3 stds 4” HWDP.
1/27/2025 1/28/2025 No accidents, incidents or spills.
LD Spear & Fish. PU/MU BHA #4 Clean out assembly with full gauge string mill to 379’ MD. RIH from 379’ to 2,421’ MD. MU
TDS. Work 6-1/8” Junk mill through Tie-back/Liner hanger from 2,421’ to 2,437’ MD. RIH to 2,727’ MD. MU TDS work string
mill through Tie-back/Liner top from 2,421’ to 2,437’ MD. Circulate hi vis sweep at 2,750’ MD. TIH from 2,750’ to 2,850’ MD.
MU & set 7” storm packer at 80’ per Baker Rep.
Test BOPE.
**AOGCC Petroleum Inspector, Adam Earl, Waived witness at 7:14 hrs on 01/27/25.
- All tests charted - 250 psi low, 4000 psi high for 5 mins except manual operated & super choke tested 250 psi low & 2000
psi high for 5 mins w/ 4” and 4 ½” test jts.
- Test annular to 250 psi low & 2500 psi high, w/ 4” test jt
- 3 ½” x 6” Upper rams, 2 7/8” x 5” LPR, test choke valves 1-15, Manual operated & super choke, choke & kill manuals, &
HCRs, 4” valve on kill line, 4” FOSV, 4” Dart valve, Upper & lower IBOP, Blind Shear rams
- All tests passed
Perform Koomey drawdown test
- ACC 2950 psi, manifold 1450 psi, ACC 1700 psi after all functions on bottles
- 21 sec for 200 psi build w/ 2 electric pumps
- 115 sec to build full system pressure w/ 2 electric & 2 air pumps.
- Closing times: Annular 21 sec, Upr 7 sec, Blind shears 7 sec, LPR 7 sec, Choke HCR 2 sec, Kill HCR 2 sec.
- Test PVT gain / loss & flow out alarms, Test LEL & H2S alarms.
RD BOPE test equipment.
1/28/2025 1/29/2025 No accidents, incidents or spills.
Install Dynomatic. RIH to engage and pull Baker Storm Packer. Lay down same. RIH from 2,850’ to 4,482’ MD.
1/29/2025 1/30/2025 No accidents, incidents or spills.
RIH to 7,470.4’ MD with string mill asym – pump two 20 BBLS super hi vis sweeps. Install windwall post hydromatic
replacement. POOH with string mill asym from 7,470’ MD. 9K over pull at Liner top tie back/ work easy continue to POOH.
LD String mill assy PU test PKR assy RIH to 1,615’ MD by end of report. Heavy slivers on magnets.
1/30/2025 1/31/2025 No accidents, incidents or spills.
RIH with Baker test packer to 7,110' md COE. Test casing (charted) to 4,000 psi 30 min passed. Repair skate recorded
NPT. PUH sideways with test Packer assy. at 1,300' at midnight.
1/31/2025 2/1/2025 No accidents, incidents or spills.
Continue to RIH with 4 ½” 12.6# 563 completion with Doyon casing torque turn assist. Land hanger – bullhead 135 BBLS
10.8 NaCI/NaBr packer fluid 1,290 PSI. Set PKR tested (charted) 30 min to 4,000 psi, witnessed by EPA reps James
Phillips/Evans Osborne.
2/1/2025 2/2/2025 No accidents, incidents or spills.
PT IA, Pull landing jt, Set TWCV and PT, Offload Brine, Flush Stack, mud line and associated equipment, Pull ram blocks
from BOP, Move BOP to stump, remove DSA, Nipple up Production tree and PT same.
2/2/2025 2/3/2025 No accidents, incidents or spills.
PT FMC wellhead to 5,000 PSI (charted) Passed. RIG RELEASE 0200. Continue prep of upcoming ring move.
2/3/2025 2/4/2025 Pull Ball and Rod, Pull DGLV, Freeze protest IA with 45 bbls of diesel. SDFN
2/3/2025 2/4/2025 No accidents, incidents or spills.
Prep for RDMO. Move from NDB to NOP, hold for shift change. Move NOP towards Mustang pad.
2/4/2025 2/5/2025 No accidents, incidents or spills.
Move from Mustang Pad to 1 mile East of KOC/CPF-1 @ 24:00 hrs.
Page of
DW-02 RWO – As Run Well
Schematic
9-5/8" 47 ppf L-80 Surface Casing
@ 2,574' MD / 2,247' TVD
Cemented to surface
20" Insulated Conductor
@ +/- 128' MD/TVD
7", 26ppf L-80 Production Casing
@ 7,693' MD / 6,265' TVD
GLGL
4-½" XN-Nipple @ 7,097' MD / 5,706' TVD
4-½” X 7" Production Packer
@ 7,087' MD / 5,696' TVD
4-½" X-Nipple @ 7,019' MD / 5,633' TVD
4-½" X-Nipple
@ +/- 1,532' MD / 1,463' TVD
WLEG @ 7,109' MD / 5,717' TVD Injection Zone
Upper Confining Zone
Perforations
7,240' MD/5,839' TVD to
7,270' MD/5,867' TVD
4-½" GLM @ 1600' MD / 1,516' TVD
7" Liner Top and Tie Back String / Estimated TOC @ 2426' MD / 2,136' TVD
12-¼” Hole Size
8-½” Hole Size
Tubing Hanger @ 39.7' KB 02/03/2025 - Final
4-½"; 12.6 ppf; P-110S Production Tubing
From:McLellan, Bryan J (OGC)
To:Gonzalez, Jose (Jose)
Cc:Davis, Rachel (Rachel); Senden, Robert (Ty)
Subject:RE: Sundry 324-571_102124 - RWO Pikka DW-02 well
Date:Wednesday, November 6, 2024 8:42:00 AM
Jose,
Oil Search has approval to make the changes to Sundry 324-571 as proposed in the email
below. All conditions of approval on the original sundry apply.
Regards
Bryan McLellan
Senior Petroleum Engineer
Alaska Oil & Gas Conservation Commission
Bryan.mclellan@alaska.gov
+1 (907) 250-9193
From: Gonzalez, Jose (Jose) <Jose.Gonzalez@contractor.santos.com>
Sent: Wednesday, October 30, 2024 1:29 PM
To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Cc: Davis, Rachel (Rachel) <Rachel.Davis@santos.com>; Senden, Robert (Ty)
<Ty.Senden@santos.com>
Subject: RE: Sundry 324-571_102124 - RWO Pikka DW-02 well
Bryan,
We currently have a plug in the X nipple above the packer. However, we are planning to retrieve
it before the cut. The cut will be done prior to killing the well or removing the tree.
Then, we will move in the rig, kill the well (both tubing and IA) with 10.9 ppg brine, install a
TWCV and remove the tree to proceed with the completion recovery and the rest of the
operation.
At the point when the tree needs to be removed, the tubing will have kill weight fluid plus a
TWCV and the IA will have kill weight fluid and the tubing hanger seals.
Below is a reviewed general plan.
Thanks,
Jose
Pre-Rig Move Operations:
1. MIRU Combo E-line unit, pressure test and RIH with SL to retrieve plug from X nipple at 7025
MD. POOH.
2. RIH to cut production tubing above the production packer. POOH. After cut is confirmed, rig
down and demob Combo unit.
Rig Operations:
3. MIRU service rig.
4. Kill IA and tubing with kill weight fluid (10.9 ppg brine + additives as required).
5. Install TWCV, pressure test to 3,000 psi.
6. Remove 4 1/16" X-mass tree and bonnet.
7. Install rig BOP and pressure test to 5,000 psi.
8. Remove TWCV.
9. POOH 4 1/2" tubing.
10. Mill and retrieve production packer as required using work string.
11. Perform casing clean out run before running new completion (optional).
12. Run new completion (includes WLRG, XN nipple, X nipples, GLM and production packer) with
4 1/2"; 12.6 lb/ft; P-110S tubing (Note: Packer not higher than 200 ft from top of
perforations).
13. Land production tubing hanger on tubing spool.
14. Bullhead packer fluid (10.9 ppg brine + additives as required) down IA.
15. Set production packer with ball and rod. Pressure test IA and tubing to 4,000 psi.
16. Install TWCV, pressure test tree to 3000 psi.
17. Remove rig BOP. Install bonnet and 4 1/2" production tree. Pressure test to 5,000 psi.
18. Rig down and demob rig and auxiliary equipment.
Post-Rig Operations:
19. Remove TWCV.
20. MIRU Slick line. Retrieve ball and rod. Retrieve RHC plug. RD and demob slick line.
21. Freeze protect tubing and IA.
22. Perform MIT-IA to 4,000 psi (AOGCC and EPA witnessed).
From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Sent: Wednesday, October 30, 2024 11:59 AM
To: Gonzalez, Jose (Jose) <Jose.Gonzalez@contractor.santos.com>
Cc: Davis, Rachel (Rachel) <Rachel.Davis@santos.com>; Senden, Robert (Ty)
<Ty.Senden@santos.com>
Subject: ![EXT]: RE: Sundry 324-571_102124 - RWO Pikka DW-02 well
Are you planning to put a plug in the XN Nipple below the packer before cutting, or will perfs be
open with pressure below TWC while removing the tree? Please send an updated work plan
which includes pumping kill weight fluid and specify density of fluids to be used.
Bryan McLellan
Senior Petroleum Engineer
Alaska Oil & Gas Conservation Commission
Bryan.mclellan@alaska.gov
+1 (907) 250-9193
From: Gonzalez, Jose (Jose) <Jose.Gonzalez@contractor.santos.com>
Sent: Wednesday, October 30, 2024 10:30 AM
To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Cc: Davis, Rachel (Rachel) <Rachel.Davis@santos.com>; Senden, Robert (Ty)
<Ty.Senden@santos.com>
Subject: RE: Sundry 324-571_102124 - RWO Pikka DW-02 well
Good morning Bryan,
On the original plan for this workover, we were going to cut the production tubing once the rig
was on the well. However, we have an opportunity to do this a few days before the rig arrives to
make the operation more efficient.
Please let us know if you see any issues with this change of plan.
Thank you,
Jose Gonzalez
Sr. Completions Engineer
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.
m: +1 (346) 413-9028 | e: jose.gonzalez@contractor.santos.com
From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Sent: Tuesday, October 22, 2024 2:26 PM
To: Gonzalez, Jose (Jose) <Jose.Gonzalez@contractor.santos.com>
Cc: Davis, Rachel (Rachel) <Rachel.Davis@santos.com>; Senden, Robert (Ty)
<Ty.Senden@santos.com>
Subject: ![EXT]: RE: Sundry 324-571_102124 - RWO Pikka DW-02 well
Jose,
Oil Search has approval to make the change (add a GLM to the completion) as mentioned
below and included in the updated proposed wellbore diagram.
Regards
Bryan McLellan
Senior Petroleum Engineer
Alaska Oil & Gas Conservation Commission
Bryan.mclellan@alaska.gov
+1 (907) 250-9193
From: Gonzalez, Jose (Jose) <Jose.Gonzalez@contractor.santos.com>
Sent: Tuesday, October 22, 2024 11:02 AM
To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Cc: Davis, Rachel (Rachel) <Rachel.Davis@santos.com>; Senden, Robert (Ty)
<Ty.Senden@santos.com>
Subject: Sundry 324-571_102124 - RWO Pikka DW-02 well
Good morning Bryan,
Just wanted to let you know of a small change we are planning for this well RWO.
The general plan remains the same, which is to retrieve the existing production tubing and
jewelry as it was determined that it is leaking. Then, run a new completion of the same size to
very close to the same depths as before.
When the original Sundry approval was requested, it was not planned to run a new gas lift
mandrel. That Sundry was approved. However, now we believe we will be able to secure a new
gas lift mandrel on time for the workover. So, we would like to include this GLM, if we get it on
time. This way, the new completion will be the same as the original one in terms of sizes,
depths, and components.
I am including a slide with this change for your reference.
Please let me know if you see any issues with this
Thank you,
Jose Gonzalez
Sr. Completions Engineer
m: +1 (346) 413-9028 | e: jose.gonzalez@contractor.santos.com
CAUTION: This email originated from outside the State of Alaska mail system. Do not
click links or open attachments unless you recognize the sender and know the content
is safe.
From:McLellan, Bryan J (OGC)
To:Gonzalez, Jose (Jose)
Cc:Davis, Rachel (Rachel); Senden, Robert (Ty)
Subject:RE: Sundry 324-571_102124 - RWO Pikka DW-02 well
Date:Tuesday, October 22, 2024 2:26:00 PM
Jose,
Oil Search has approval to make the change (add a GLM to the completion) as mentioned
below and included in the updated proposed wellbore diagram.
Regards
Bryan McLellan
Senior Petroleum Engineer
Alaska Oil & Gas Conservation Commission
Bryan.mclellan@alaska.gov
+1 (907) 250-9193
From: Gonzalez, Jose (Jose) <Jose.Gonzalez@contractor.santos.com>
Sent: Tuesday, October 22, 2024 11:02 AM
To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Cc: Davis, Rachel (Rachel) <Rachel.Davis@santos.com>; Senden, Robert (Ty)
<Ty.Senden@santos.com>
Subject: Sundry 324-571_102124 - RWO Pikka DW-02 well
Good morning Bryan,
Just wanted to let you know of a small change we are planning for this well RWO.
The general plan remains the same, which is to retrieve the existing production tubing and
jewelry as it was determined that it is leaking. Then, run a new completion of the same size to
very close to the same depths as before.
When the original Sundry approval was requested, it was not planned to run a new gas lift
mandrel. That Sundry was approved. However, now we believe we will be able to secure a new
gas lift mandrel on time for the workover. So, we would like to include this GLM, if we get it on
time. This way, the new completion will be the same as the original one in terms of sizes,
depths, and components.
I am including a slide with this change for your reference.
Please let me know if you see any issues with this
Thank you,
Jose Gonzalez
Sr. Completions Engineer
m: +1 (346) 413-9028 | e: jose.gonzalez@contractor.santos.com
1
For Internal Use only
DW-02 Workover –Schematics
Current Schematic Approved Sundry Schematic New Proposed Schematic
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?DW-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):
Casing Collapse
Structural
Conductor
Surface 4750
Production Liner 5410
Production Tieback 5410
Tubing 7500
Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft):
Production Packer 7080' MD / 5668' 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:Jose Gonzalez
Contact Email:
jose.gonzalez@contractor.santos.com
Contact Phone: 346-413-9028
Authorized Title:Sr. 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
8430
Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft):
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL 392984/ADL 391445
223-039
601 5th Avenue, Anchorage AK 99501 50-103-20855-00-00
Oil Search Alaska LLC (Santos)
Length Size
Proposed Pools:
13Cr
TVD Burst
7100'
7240
MD
7240
6870
128
2,247
6,267
128
25,74
2,1357"
20"
9-5/8"
128
7"5,272
2,574
Surface - 2,424
Perforation Depth MD (ft):
2,424 - 7,696
7217' - 7247'
2,424
4.5"
5818' - 5846'
11/15/2024
Surface - 7,1007,100
4-1/2" 12.6 ppf
5,708
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
going is true and the procedur
324-571
By Grace Christianson at 2:27 pm, Oct 01, 2024
5839' - 5867'
SFD
7240' - 7270'
SFD
SFD 10/17/2024 DSR-10/2/24BJM 10/17/24
6,265' SFD
X
Class I EPA
Disposal operations authorized by EPA under Class 1 permit conditions.
CDW 10/03/2024
7,693' SFD
10-404
X
X-bjm
Initial BOP test to 5000 psi, initial annular test to 2500 psi if this is the first well in Doyon 16 campaign
Subsequent BOP tests to 4000 psi, subsequent annular tests to 2500 psi.
Production packer to be set <200 ft above top perf per 20 AAC 25.412(b)
2628 psi -bjm
JLC 10/21/2024
Gregory Wilson Digitally signed by Gregory Wilson
Date: 2024.10.21 08:55:34 -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
1/1
October 1
st,2024
Commissioner
State of Alaska
Alaska Oil & Gas Conservation Commission
333 West 7th Avenue Suite 100
Anchorage, Alaska 99501
Re: Application for Sundry Approval on Workover for Tubing Replacement –DW-02
disposal well
Commissioner,
Please find attached Form 10-403 Application for Sundry Approval to perform a workover on
disposal well DW-02 to replace its production tubing. This well failed its annual MIT. After
multiple pressure testing and diagnostic logs, it was determined that there was a leak on the
production tubing. The objective of this proposed workover is to retrieve the existing
production tubing and replace it with a new string landed at similar depth as the original. No
changes to well perforations or casing components are planned.
Please see the attached proposed workover plan and both current and proposed wellbore
schematics.
Yours sincerely,
Jose Gonzalez
Sr. Completions Engineer
Oil Search LLC. A subsidiary of Santos Limited
1For Internal Use onlyOBJECTIVE: After multiple tests and logs, it has been determined that there is atubing leak on this well. Therefore, the production tubing needs tobe replaced. The objective of this job includes cutting and retrievingthe existing production tubing. Then, run a new production tubingstring to approximately the same depth of the original one. Nochanges to perforations or casing components are planned.DW-02 Workover – PlanGENERAL WORK PLAN:1. Install TWCV, pressure test to 4000 psi2. MIRU service rig3. Remove 4 1/16" X-mass tree and bonnet4. Install rig BOP and pressure test to 4000 psi5. Remove TWCV6. MIRU SL and retrieve plug from X nipple @ 7025 ft MD7. Kill well with brine by bullheading down production tubing8. Cut 4 1/2" tubing as close to packer as possible (~ 7070 ft MD)9. POOH 4 1/2" tubing10. Mill and retrieve production packer using work string11. Run new production TNT packer and 4 1/2"; 12.6 lb/ft; P-110S tubing (WLRG no higher that 200 ft from top of perforations)12. Land production tubing hanger on tubing spool13. Bullhead packer fluid and freeze protect for tubing and IA with ~30 bbls of diesel)14. Set production packer and pressure test IA to 1000 psi15. Install TWCV, pressure test tree to 4000 psi16. Remove rig BOP17. Install bonnet and 4 1/2" production tree. Pressure test to 4000 psi18. Rig down and demob rig and auxiliary equipment19. Remove TWCV20. Perform MIT-IA to 4000 psi (AOGCC and EPA witnessed)
Circulate KWF into IA before pulling tubing. -bjm
Rig Doyon 16 will be used. -bjm
Will use minimum 10.9 ppg brine for kill. -bjm
Production packer <200 ft above
top perf. - bjm
Pressure test SL and EL lubricators
to 3000 psi. -bjm
2For Internal Use onlyDW-02 Workover – SchematicsCurrent SchematicProposed Schematic
,7(0123$57180%(5'(6&5,37,2147<+.%:2)6+,.$/1$&(%9&:678'6 1876%1$75+,.$/%$//9$/9(1$&(75,007 &+2.(9$/9((6&+2.(B.5$&78$7('&+2.(9$/9(&5266%/2&.:$<;;;;;:$<&5266%/2&.01$&(&5266%/2&.:$<;;;;:$<&5266%/2&.01$&(+.7) 36,7$5*(7)/$1*()/$1*(536,)/$1*(5;25,1* )/$1*(2536,)/$1*(25,1*;6322/63$&(56322//21*5;25,1*6322/63$&(56322//21*5;25,1*6322/63$&(56322/ /21*5;25,1*6322/63$&(56322//21*5;25,1*6322/25,1*7225,1*63$&(56322/+.5563$&(56322/+.+'0$18$/+$1'/(;[%0;%0678';[%0;%0678' ;+0+0187;B %0 ;%0678'6;B +0 +0187'(6&5,37,21 $66(0%/<'5$:,1*12 :35(6685( B.'28%/(% %6,1*/(*870$1,)2/'6+((712 '$7( '$7( '$7( ;;;$1*/(65(9 6,=( %:(,*+7 6&$/( '21276&$/('5$:,1*5(3$,5.,7 6($/.,7 &+(&.('%< &5($7('%< $33529('%< $//',0(16,216,1,1&+(65(9,6('%< '$7( 7+,5'$1*/(352-(&7,21(&1 &&1 352-(&7),/( '(6,*1),/( 81/(6627+(5:,6(63(&,),('1$1$1$1$1$1$/%636,Click to BUY NOW!PDF-XChangeEditorw w w .tracker-software.comClick to BUY NOW!PDF-XChangeEditorw w w .tracker-software.comWhat is the OD ofthe four spools onthe manifold
7239,(:%$&.9,(:6,'(9,(:'(6&5,37,21 $66(0%/<'5$:,1*12 :35(6685( B.'28%/(% %6,1*/(*870$1,)2/'6+((712 '$7( '$7( '$7( ;;;$1*/(65(9 6,=( %:(,*+7 6&$/( '21276&$/('5$:,1*5(3$,5.,7 6($/.,7 &+(&.('%< &5($7('%< $33529('%< $//',0(16,216,1,1&+(65(9,6('%< '$7( 7+,5'$1*/(352-(&7,21(&1 &&1 352-(&7),/( '(6,*1),/( 81/(6627+(5:,6(63(&,),('1$1$1$1$1$1$/%636,Click to BUY NOW!PDF-XChangeEditorw w w .tracker-software.comClick to BUY NOW!PDF-XChangeEditorw w w .tracker-software.com
1
McLellan, Bryan J (OGC)
From:Gonzalez, Jose (Jose) <Jose.Gonzalez@contractor.santos.com>
Sent:Tuesday, October 15, 2024 3:43 PM
To:McLellan, Bryan J (OGC)
Cc:Davis, Rachel (Rachel)
Subject:RE: DW-02 (PTD 223-039) RWO sundry
Attachments:Rig 16 BOP Diagram - EBOOK.pdf; Doyon Drilling 10-17-23.pdf
Hello Bryan,
Please read below. Let me know if you need anything else.
Thanks,
Jose
From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Sent: Tuesday, October 15, 2024 10:23 AM
To: Gonzalez, Jose (Jose) <Jose.Gonzalez@contractor.santos.com>
Subject: ![EXT]: DW-02 (PTD 223-039) RWO sundry
Jose,
A few questions about the sundry application for this well:
1. What rig will be used for the RWO? Please send schematics of the rig’s BOP stack and choke manifold.
A: We will be using Doyon-16. Schematics for the BOP and choke manifold are attached
2. When was the last time this rig was in service with the planned BOP stack?
A: This rig last operated in 2017. However, the rig is currently being refurbished and will undergo an API 53
audit conducted by Subsea Solutions in November 2024 prior to the commencement of operations
3. What is the max potential surface pressure? Please provide supporting calculations, assuming max
anticipated reservoir pressure minus a gas column of 0.1 psi/ft to surface.
A: Based on a Pressure/Temperature survey ran last month (snapshot included below), BHP is ~3212 psi.
Assuming a full column of gas to surface, this equates to: 3212 psi – (5839 ft (TVD) x 0.1 psi/ft) = 2628 psi
maximum potential surface pressure
4. What is the brine weight required to kill the well in step 7?
A: We are planning to use a brine with a minimum density of 10.9 ppg. It could be higher if we need to add a
diesel cap for freeze protect at any point of the job
5. How are you planning to cut the tubing in step 8?
A: Still evaluating alternatives, but most likely it will be either a HAL JRC Gen 1 cutter or a WT Bell Premium
cutter. Both are jet cutters
6. Need to circulate out the Annulus Ʋuids with KWF before pulling tubing. When do you plan to do that?
A: Yes, we will replace the existing Ʋuid with kill weight brine in both tubing and IA. We may perform the cut
rigless before moving the WO rig. Then, the initial top kill will be done after the cut and again before
retrieving the production tubing. Also, we will be monitoring and re-kill as needed during the operation
7. New production packer needs to be set no more than 200 ft above top perf per 20 AAC 25.412(b).
A: Yes. That is the intention. As close as possible to where the existing packer is currently set
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
8. What is the density of the completion Ʋuids you plan to pump? Will they overbalance the reservoir?
A: The planned minimum density for the kill/work Ʋuid is 10.9 ppg. This will overbalance the reservoir
Bryan McLellan
Senior Petroleum Engineer
Alaska Oil & Gas Conservation Commission
Bryan.mclellan@alaska.gov
+1 (907) 250-9193
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Thursday, August 29, 2024
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Josh Hunt
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
Oil Search (Alaska), LLC
DW-02
PIKKA DW-02
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 08/29/2024
DW-02
50-103-20855-00-00
223-039-0
I
SPT
5711
2230390 4000
1746 1750 1746 1745
0 0 0 0
OTHER F
Josh Hunt
7/19/2024
This is the second attempt to pass an MIT on this well. They installed an additional block valve to eliminate any possible surface leaks on the
pump truck. This test also failed, due to to much pressure loss and no stabilization. Also noted that they lost 1/2 a barrel of fluid when they bled
the pressure off. The well was shut in after discussing it with Jim Regg. They are thinking that the gas lift valve down hole may be leaking and
are planning on replacing it. EPA UIC permit AK-11019-A
30 MinPretestInitial15 Min
Well Name
Type Test
Notes:
Interval P/F
Well
Permit Number:
Type Inj TVD
PTD Test psi
API Well Number Inspector Name:PIKKA DW-02
Inspection Date:
Tubing
OA
Packer Depth
106 4151 3952 3850IA
1744
0
45 Min
3758
1743
0
60 Min
3673
Rel Insp Num:
Insp Num:mitJDH240719154544
BBL Pumped:2.5 BBL Returned:2
Thursday, August 29, 2024 Page 1 of 1
9
9
9
9
9
9
99
9 9 99
9 9 9
9 9
8,&&ODVV,'LVSRVDO:HOO
9
9
8,&&ODVV,'LVSRVDO:HOO
second attempt
well was shut in
James B. Regg Digitally signed by James B. Regg
Date: 2024.08.29 16:11:18 -08'00'
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Thursday, August 29, 2024
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Josh Hunt
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
Oil Search (Alaska), LLC
DW-02
PIKKA DW-02
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 08/29/2024
DW-02
50-103-20855-00-00
223-039-0
I
SPT
5711
2230390 4000
1752 1756 1754 1752
0 0 0 0
OTHER F
Josh Hunt
7/19/2024
This is an EPA regulated well which requires them to test to the maximum anticipated injection pressure of 4000 psi to start the test.This well is
also required to be tested annually by the EPA. They ran the test longer to see if it would stabilize and it did not. It also lost to much pressure in
the second half of the test, over 50% of the initial loss of the first 15 minutes. They're injecting mostly crude from well flowback operations. EPA
UIC permit AK-11019-A
30 MinPretestInitial15 Min
Well Name
Type Test
Notes:
Interval P/F
Well
Permit Number:
Type Inj TVD
PTD Test psi
API Well Number Inspector Name:PIKKA DW-02
Inspection Date:
Tubing
OA
Packer Depth
18 4350 4180 4090IA
1751
0
45 Min
4000
60 Min
Rel Insp Num:
Insp Num:mitJDH240719152605
BBL Pumped:2.7 BBL Returned:2.6
Thursday, August 29, 2024 Page 1 of 1
9
9
9
9
9
9
9 9
9 999
9 99
9
8,&&ODVV,'LVSRVDOZHOO99
9
9
James B. Regg Digitally signed by James B. Regg
Date: 2024.08.29 16:08:01 -08'00'
LETTER OF TRANSMITTAL
DETAIL
QTY DESCRIPTION
DW-02 (50-103-20855-0000)
Supplemental submittals -
Details in Following page
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: 1/29/2024
From:
Shannon Koh
Santos
P.O. Box 240927
Anchorage, AK 99524-0927
To:
Kayla Junke
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:
PTD: 223-039
T38443
1/29/2024
Kayla
Junke
Digitally signed
by Kayla Junke
Date: 2024.01.29
11:25:42 -09'00'
LETTER OF TRANSMITTAL
جؐؐؐBaker LWD
ؒ جؐؐؐDigital Data
ؒ ؒ DW-02_AP_R02_RM_TIME.las
ؒ ؒ DW-02_AP_R03_RM_TIME.las
ؒ ؒ DW-02_AP_R05_RM_TIME.las
ؒ ؒ
ؒ جؐؐؐGeoscience
ؒ ؒ DW-02_LWD_R02_SDTK_DTC_Run2_110ft_2575ft_5MD.dlis
ؒ ؒ DW-02_LWD_R02_SDTK_DTC_Run2_110ft_2575ft_5MD.dlis.txt
ؒ ؒ DW-02_LWD_R02_SDTK_DTC_Run2_110ft_2575ft_5MD.las
ؒ ؒ DW-02_LWD_R02_SDTK_DTC_Run2_110ft_2575ft_5MD.meta
ؒ ؒ DW-02_LWD_R02_SDTK_DTC_Run2_110ft_2575ft_5MD.PDF
ؒ ؒ DW-02_mem_AZCAL_R2.dlis
ؒ ؒ DW-02_mem_AZCAL_R2_Drilled_0120scl.meta
ؒ ؒ DW-02_mem_AZCAL_R2_Drilled_0120scl.pdf
ؒ ؒ DW-02_mem_AZCAL_R2_Drilled_0240scl.meta
ؒ ؒ DW-02_mem_AZCAL_R2_Drilled_0240scl.pdf
ؒ ؒ DW-02_mem_AZCAL_R5.dlis
ؒ ؒ DW-02_mem_AZCAL_R5_Drilled_0120scl.meta
ؒ ؒ DW-02_mem_AZCAL_R5_Drilled_0120scl.pdf
ؒ ؒ DW-02_mem_AZCAL_R5_Drilled_0240scl.meta
ؒ ؒ DW-02_mem_AZCAL_R5_Drilled_0240scl.pdf
ؒ ؒ
ؒ ؤؐؐؐGraphics
ؒ DW-02_AP_RM_TIME.pdf
ؒ DW-02_AP_RM_TIME_np.pdf
ؒ
ؤؐؐؐMudlogging
DW-02_G5_GAS_RATIOS_Composite_7696 ft.pdf
DW-02_GasPeaks.xlsx
DW-02_GasRatioLog_7696ft_MD.pdf
DW-02_GasRpt_Final.xlsx
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: 2538 FSL, 1845 FEL, S4, T11N, R6E, UM
Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s):
3369 FSL, 4831 FEL, S4, T11N, R6E, UM GL: 46.42 BF: 22
Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation:
3646 FSL, 550 FEL, S5, T11N, R6E, UM
4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number:
Surface: x- y- Zone- 4
TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD:20. Thickness of Permafrost MD/TVD:
Total Depth: x- y- Zone- 4
5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD:
Submit electronic information per 20 AAC 25.050 N/A (ft MSL)
23.
BOTTOM
20" X-65 58'
9-5/8" L80 2247'
7" L80 6264'
7" L80 2140'
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:
Water-Bbl:
PRODUCTION TEST
Date of Test: Oil-Bbl:
Flow Tubing
7240' - 7270' MD / 5839' - 5867' TVD
Halliburton Maxforce HMX 6 spf @ 60° phasing (180 .4" holes)
Date perf'd - 7/15/23
Gas-Oil Ratio:Choke Size:
Per 20 AAC 25.283 (i)(2) attach electronic information
26
2432'
2137'
Surface
78
47
Surface
2429' 7693'
SIZE DEPTH SET (MD)
7080' MD / 5690' TVD
PACKER SET (MD/TVD)
42"
12-1/4"
Grouted to Surface
Surface See attached Surface Rpt
26
Surface
Surface
2574'Surface
128'
CASING WT. PER
FT.GRADE
06/30/23
CEMENTING RECORD
5,973,771.11
1409' MD / 1360' TVD
SETTING DEPTH TVD
5,974,058.34
TOP HOLE SIZE AMOUNT
PULLED
420,421.57
419,425.56
TOP
SETTING DEPTH MD
N/A
BOTTOM
50-103-20855-00-00
DW-02
ADL 392984 / ADL 391445
19-003
06/18/23
7,696' MD / 6,267' TVD
N/A
68.7
900 E Benson Boulevard, Anchorage, AK 99508
423,383.56 5,972,909.70
Pikka / Undefined Waste Disposal Pool
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
Oil Search (Alaska), LLC
WAG
Gas
07/08/23 223-039 / 323-373
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
22.Logs Obtained: 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,
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.
*55(61(8'(16RQLF,PDJH/RJ0XGORJV&%/,PDJH/RJPerf Log
N/A8-1/2"
TUBING RECORD
See attached Production Rpt8-1/2"
7094'4-1/2"
G
s d 1
0 p
dB P
L
(att
Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment
By Grace Christianson at 12:30 pm, Aug 21, 2023
Completed
7/8/2023
JSB
RBDMS JBS 083023
G
Class I EPA
CDW 09/05/2023
2537 FSL 3418 FWL on the surveyor's plat SFD
46.4
SFD
22.2
SFD 11/8/2023BJM 9/14/23 DSR-11/26/25
Conventional Core(s): Yes No Sidewall Cores:
30.
MD TVD
Surface Surface
1168' 1100'
Upper Schrader Bluff 1065' 1051'
Permafrost Transition 1456' 1407'
Middle Schrader Bluff 1923' 1761'
MCU 2426' 2136'
Tuluvak Shale 2829' 2438'
Tuluvak Sand 2904' 2494'
Seabee 3846' 3195'
Nanushuk 4739' 3862'
NT8 MFS 4760' 3877'
NT7 MFS 4789' 3898'
NT6 MFS 4880' 3966'
NT5 MFS 4971' 4034'
NT4 MFS 5080' 4115'
NT3 MFS 5586' 4492'
NT 3.2 Top Reservoir (NT3) 5662' 4519'
Top of Torok 6540' 5211'
Top of Productive Interval 7040' 5653'
(Base of Top Torok Confining Layer)
Disposal Zone 2 7240' 5840'
Disposal Zone 1 7270' 5868'
HRZ 7596' 6173'
HRZ 7696' 6267'
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: Garret Staudinger
Digital Signature with Date:Contact Email:garret.staudinger@santos.com
Contact Phone:907-440-6892
Authorized Title: Senior Drilling 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:
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.
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.
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis,
paleontological report, production or well test results, per 20 AAC 25.070.
Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool
is a completion.
TPI (Top of Producing Interval).
Authorized Name and
Formation Name at TD:
INSTRUCTIONS
Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation,
or Other.
If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed).
Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired.
Yes No
Well tested? Yes No
28. CORE DATA
If Yes, list intervals and formations tested, briefly summarizing test results for
each. Attach separate pages if needed and submit detailed test info including
reports and Excel or ASCII tables per 20 AAC 25.071.
NAME
Permafrost - Top
Permafrost - Base
29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS
N
Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov
egoing is true and correct to the bes
8/17/2023
DW-02 As Drilled Well Schematic
9-5/8" 47 ppf L-80 Surface Casing
@ 2,574' MD / 2,247' TVD
Cemented to surface
20" Insulated Conductor
@ +/- 128' MD/TVD
7", 26ppf L-80 Production Casing
@ 7,693' MD / 6,265' TVD
GL
4-½" XN-Nipple @ 7,093' MD / 5,702' TVD
4-½” X 7" Production Packer
@ 7,080' MD / 5,690' TVD
4-½" X-Nipple @ 7,025' MD / 5,638' TVD
4-½" X-Nipple
@ +/- 1,546' MD / 1,473' TVD
WLEG @ 7,100' MD / 5,708' TVD Injection Zone
Upper Confining Zone
Perforations
7,240' MD/5,839' TVD to
7,270' MD/5,867' TVD
4-½" GLM @ 1601' MD / 1,517' TVD
7" Liner Top and Tie Back String / Estimated TOC @ 2426' MD / 2,136' TVD
12-¼” Hole Size
8-½” Hole Size
KB-Base Flange – 46.42'07/26/2023 - Final
Ops Summary Report All Jobs - AOGCC
Start Date End Date
Start Depth
(ftKB) Depth Prog (ft)
Dens Last
Mud (lb/gal) Summary
6/16/2023 6/17/2023 0 No accidents, incidents or spills. Install 544 delta saver sub on TD, torqued to 50k. Moved
surface BHA in pipe shed to prep for picking up 5" DP. Diverter drill at 10:00 as per SANTOS rep.
Clean and clear rig floor. Dress out shakers. Pick up 5" DP stands. Knife valve open time = 28
sec, annular close time = 30 sec. Draw down test to 3100 psi start, 2400 psi final. 11 sec to +200
psi, 45 sec to full psi. Continue to stage Baker surface BHA. Bring on 285 bbl 10 ppg, 50 vis
spud mud to the pits. Continue P/U 5" DP stands, total of 75 stds. Bring baker short surface BHA
tools to rig floor. Calibrate blocks w/ Baker Rep. Bring 5" HWDP into pipe shed, strap and tally
HWDP. Bring mud motor and jar into pipe shed. Build 5" HWDP stands offline.
Note: Held Diverter Drill at 10:00 hrs as per Santos WSS.
Note: Diverter system test witnessed by AOGCC Rep Austin McLeod at 15:00 hrs on 6/16/23,
good test.
6/17/2023 6/18/2023 0 No accidents, incidents or spills. Bring spud mud up from 10 ppg to 10.5 ppg. Build 5" stands
HWDP offline. P/U lift subs and X/O’s, inspect handling equipment for BHA. R/U 9 5/8" casing
elevators to preform dummy run w/ hanger. Build 5" stands HWDP offline. Prep handling
equipment for BHA. Bring in hanger and landing jt. M/U hanger to landing jt. Make dummy run w/
hanger and mark landing jt. Change elevators for 5" DP. PJSM make up BHA w/ Baker Rep, M/U
stab, flex collar, and filter sub. P/U mud motor and torque lift sub, M/U 12-1/4" bit. Continue to
condition mud.
Note: At 17:30 hrs on 6/17/2023 Held Pre-spud meeting with all vendors and rig day crew.
6/18/2023 6/19/2023 128 730.00 10.50 No accidents, incidents or spills. Hold pre-spud with drilling & support crews. M/U BHA #1 tag
btm at 128'. Test surface lines. Drill 12-1/4” Surface hole from 128’ MD to 245’ MD (245’ TVD).
Monitor well for 10 minutes: Static POOH on elevators from 245' MD to 51' MD. M/U BHA #2
(Surface) P/U 5" HWDP RIH, tag @ 242' MD. Drill 12.25” Surface hole from 245’ MD to 641' MD
(640' TVD). Rack back HWDP, pick up jars, RIH to 641'. Drill 12.25” Surface hole from 641’ MD
to 858’ MD (854' TVD).
6/19/2023 6/20/2023 858 1,207.00 10.60 No accidents, incidents or spills. Drill 12.25” Surface hole from 858’ MD to 951’ MD. Encountered
heavy torque, unable to rotate or PU/SO. Engage jars to get free. Worked pipe thru tight spots.
Drill 12.25” Surface hole from 951’ MD to 961’ MD. POOH from 961' MD to 923’MD. Reciprocate
and pump to hole. TIH from 825’ MD to 961' MD. Drill 12.25” Surface hole from 961’ MD to 2065’
MD.
6/20/2023 6/21/2023 2,065 510.00 10.50 No accidents, incidents or spills. Drill 12.25” Surface hole from 2065’ MD to 2575’ MD. Circulate
at 675 GPM, 2400 PSI, pull up from 2575' MD to 2539’ MD while back reaming out and from
2539’ to 2444’. Pump 30 bbl, 250 vis sweep out. Orient motor to high side. 10 min flow check
well, no flow. SPP initial 2450, SPP final 2400. CBU 2 times to reduce vis from 300+ to 220 out.
POOH from 2444’ to 2352’ observed swabbing due to thick mud. Performed flow check -
observed gas hydrates breaking out, no flow observed. RIH from 2352’ to 2530’. CBU at 675
GPM. 335 units max gas, 670 GPM, 2450 PSI. POOH from 2530’ to 2490’ flow check, well static.
Pump out of hole from 2490’ to 2010 at 20 FPM, 400 GPM, 1080 PSI SPP observed pack off and
partial losses. RIH to 2250’ stage up pumps to 300 GPM. Observed partial losses and pumps
cavitating. RIH to bottom at 2575' MD. Stage up pumps, pumps cavitating, clean pump screens,
pumps still cavitating. Clean lines, prime pumps and circulate and condition mud. Backream out
of hole from 2575’ MD to 2257’ MD.
6/21/2023 6/22/2023 2,575 0.00 10.45 No accidents, incidents or spills. Back ream operations from TD to BHA. Flow check, lay down
BHA. R/U and begin to run 9.625 Casing as per running tally. Run first 11 joints, displacement
good, no losses to formation. Break circulation, hole condition dirty, circulate to clean hole. Joint
11 at 445 MD CBU. Run joints 12 -18 with no issues. Suspected ledging of joint 19 at 739' MD
and joint 20 at 777' MD. Worked pipe, cannot get past ledge on joint 20 at 782'.
NOTE: At 04:45 on 6/21/23 submitted a request to AOGCC to witness BOP test on Fri 6/23/23 at
05:00.
Well Name Wellbore Name PTD # Start Drill Date End Drill Date
Page 1 of 5
Well Name
DW-02
Wellbore Name
Original Hole
PTD #
223-039
Start Drill Date
6/18/2023
End Drill Date
7/9/2023
Ops Summary Report All Jobs - AOGCC
Start Date End Date
Start Depth
(ftKB) Depth Prog (ft)
Dens Last
Mud (lb/gal) Summary
6/22/2023 6/23/2023 2,575 0.00 10.45 No accidents or incidents. 1 cup of diesel dripped on pad from vac truck. PJSM, Run 9.625, 47#,
L-80, surface casing from 780’ MD. Lay down top Jt and install rotation bracket as per Parker
Wellbore casing Rep. Trouble shoot CRT and top drive hydraulic system not engaging. Run
9.625, 47#, L-80, surface casing from 780’ to 1730’ MD. CBU at 1750' MD. Continue run 9.625,
47#, L-80, surface casing from 1730’ to 1809’ MD.
*Note: At 21:00 on 6/22/23 submitted a request to AOGCC to witness BOP test on Sat 6/24/23 at
21:00.
6/23/2023 6/24/2023 2,575 0.00 10.50 No accidents, incidents or spills. Continue to run 9.625”, 47#, L-80, surface casing from 1809' to
2575’ MD. Stage up to cementing rate in 1 BPM increments to final circulating rate of 8 BPM. Lay
down 3 joints of casing to pick up and land hanger. 10 RPM 15K torque at 6 BPM, 145 PSI while
working up on third joint 15K-20K overpull with 15K torque stalls at 2515' MD return to bottom
with 10 RPM 6 BPM 15K down tag bottom 2575' MD. Stage up to cementing rate in 1 BPM
increments to final circulating rate of 8 BPM. Park 1' off bottom CIRC with 10 RPM 12K TQ.
PJSM, cement 9.625” surface casing as per Halliburton and Santos cementing program. R/D
cement equipment. Drain stack and flush clean. N/D diverter pipe and diverter. N/D knife valve,
R/D diverter adapter from conductor and obtain samples for cement job. Tag up on cement 10'
from top of conductor. Received verbal approval from Bryan McLellan with AOGCC to proceed
ahead. Prep well head for 9.625" emergency slips.
6/24/2023 6/25/2023 2,575 0.00 10.50 No accidents, incidents or spills. Center string to allow emergency slips to be set. Remove knife
valve off diverter, unbolt diverter to riser flange to allow cutting of casing. Make rough cut on
9.625" casing. Lay down 1 full joint casing plus one cut joint 27.56. Clean pits. Rig down CRT
tool and handling equipment. Raise surface risers to break bolts from flange and set back down
on diverter adapter. Spot and rig up Halliburton Cement to top off conductor. Pump 1 bbl 11.0
ppg cement. PJSM, suck fluid out of casing in prep for cut, measure and cut 2.95' off of 9.675"
surface casing stump. Install lower and upper wellhead, torque wellhead to spec. N/U BOPE,
N/U DSA, P/U and N/U HP riser, N/U stack to HP riser, torque all studs to spec, install flow nipple
and air up boots, install turnbuckles. Continue to R/U for BOPE test.
6/25/2023 6/26/2023 2,575 0.00 10.80 No accidents, incidents or spills. R/U for BOP testing, fill choke, gas buster, and stack with H2O,
purge air and shell test to 5K. Test BOPE to 250 PSI low, 5000 PSI high for 5 minutes each. Test
with 4.5” and 7” test joints. All tests charted, see attached bop test charts. R/D BOPE test
equipment. P/U 8.5" production BHA as per Baker MWD/DD. RIH F/712' MD T/2390' MD.
Working to shallow hole test tools at 1200' MD 500 GPM, 1300 PSI, 30 RPM, 1-2K torque.
Progress is slowed due to thick mud consistency. Continue to shallow test tools while
conditioning mud. Wash down at 2 BPM from 2250' MD to 2390' MD intermittent cement
stringers at 2390’. Ream down from 2390' MD to 2440' MD. Noticed variations in torque at 2440'
indicating cement stringers. Tagged up TOC at 2445'.
Note: BOPE test witnessed by AOGCC rep Brian Bixby.
6/26/2023 6/27/2023 2,575 0.00 10.95 No accidents, incidents or spills. Displace 10.5 PPG spud with 11.0 PPG OBM, 420 GPM, Rotate
30 RPM, reciprocate pipe 60 FT Circulate until MI rep verify OBM to spec. Circulate both ways
down kill and drill pipe to fluid pack lines. Attempted to conduct casing pressure test to 3500 psi,
small bleed. Continued with same attempts, with similar trends of ~3 psi per minute / 20 psi
every 5 minutes. Discuss with Leadership Team, decide to mobilize RTTS (Retrievable Treat,
Test, Squeeze packer). Flow check off bottom, static, POH with BHA. Flow check at 700’ (top of
BHA) and fluid level dropping – troubleshoot, find check valve on Trip Tank failed. Continue to
POH, repair check valve with BHA at surface. Conduct pressure test against Float Collar with
Blinds closed, similar trend to previous tests.
Page 2 of 5
g
cement 9.625” surface casing as per Halliburton and Santos cementing program.
Ta g up on cement 10'p
from top of conductor.
Ops Summary Report All Jobs - AOGCC
Start Date End Date
Start Depth
(ftKB) Depth Prog (ft)
Dens Last
Mud (lb/gal) Summary
6/27/2023 6/28/2023 2,575 20.00 11.00 No accidents, incidents or spills. TIH with RTTS and set at 2467' MD. Pressure up annulus 2597
PSI, 2.1 BBLS to pressure up. Passing test, total of 57 psi lost with stabilized trend in last 15
minutes. Bleed pressure from annulus, pressure up, down DP to 2440 PSI, pressure bled down
to 2383 PSI in 7 minutes, bled off per well site supervisor due to bleed rate. Pumped 2.5 BBLS
down DP bled back 1 BBL. Flow Check for 10 minutes, static. POOH on elevators from 2480’
MD to 108’ MD. Flow check at surface, static. Lay down RTTS as per Halliburton Rep. Make up
bit and bit sub as per Baker DD, RIH with 8.5” dumb iron BHA from 581’ MD to 2380’ MD - RIH
on elevators out of derrick. Wash to top of plugs from 2384' MD to 2490' MD. Tag top of plugs @
2495' MD, drill out plugs, confirm plugs at surface, drill out cement, shoe track, and 20' of new
hole from 2490' MD to 2595' MD. Circulate hole clean for upcoming LOT. Rig up and perform
LOT. Sucessful LOT, EMW of 16.6 ppg. Flow check for 10 minutes, static. POH on elevators
from 2595’ md to surface, flow check - Static. PJSM, make up 8.5" drilling BHA as per Baker
DD/MWD, make up bit, verify float is in good condition, plug in and upload tools, install sources
in tools.
Note: Kick while tripping drill with after action review, have choke and stripping drill as per Santos
rep.
6/28/2023 6/29/2023 2,595 1,349.00 11.00 No accidents, incidents or spills. RIH with 8-1/2" BHA from 137' to 1184' monitoring
displacement. Shallow hole test with 500 GPM, 1550 PSI, 30 RPM. Continue to RIH with 8-1/2"
BHA from 1184' to 2595' MD. Drill 8-1/2” Production hole from 2595’ MD to 3944’ MD (3266’
TVD).
6/29/2023 6/30/2023 3,944 2,092.00 11.00 No accidents, incidents or spills. Drill 8-1/2” Production hole from 3944’ MD to 6036’ MD (4825’
TVD).
6/30/2023 7/1/2023 6,036 1,660.00 11.00 No accidents, incidents or spills. Drill 8.5" production hole from 6036' MD to TD at 7696' MD.
Circulate bottoms up 5 times while rotating and reciprocating from 7696‘ MD to 7616‘ MD. PJSM,
Monitor well for 10 minutes, Static. POOH on elevators from 7696' MD to 4036' MD. Mud weight:
11.0 PPG in, 11.0 PPG out.
7/1/2023 7/2/2023 7,696 0.00 11.05 No accidents, incidents or spills. PJSM, POOH on elevators with 8.5" Baker Autotrak BHA from
4036' to 2525' MD. Circulate bottoms up inside shoe 2 times at 2525'. Continue POOH with 8.5"
on elevators from 2525' to BHA at 712' MD. Flow check and POOH with HWDP R/B in derrick
from 712' to 137' MD. L/D BHA to pipe barn from 137' to surface. R/U Halliburton wireline. M/U
Formation Imager/Sonic tool string and RIH from surface to 76', monitoring well on trip tank. Run
#1 with Formation Imager/sonic tool assembly from surface to 2654’ MD. Wire line having trouble
working past 2654'. POOH with wireline tool assembly from 2654' MD to surface and reconfigure
wire line assembly. Rig evacuation drill, all hands muster up at weld shop for safety stand down
discussion. PJSM, Halliburton wireline, add flex joint to wireline assembly. Run #2 with Formation
Imager/sonic tool assembly from surface to 2668’ MD. Wireline having trouble working past
2668'. POOH and L/D Formation Imager. Run #3 with sonic tool assembly from surface to 2674’
MD, having trouble working past 2674' MD. POOH with wireline tool assembly from 2674' MD to
surface and R/D wireline. Monitor wellbore via trip tank.
7/2/2023 7/3/2023 7,696 0.00 11.25 No accidents, incidents or spills. POOH and R/D wireline toolstring and equipment. M/U and RIH
with 8.5" BHA for clean-out to 1858'. Conducted simulated kick while tripping drill, secured well
and evacuated all personnel to weld shop muster point for safety stand down. Continued RIH
with clean out BHA F/1858' to 3469' and started backreaming F/3469' to 2944' observing
excessive cuttings across shakers. RIH with 8.5" clean out assembly F/2944' to 7696'. Circulate
bottoms-up 1 time. Backream out of hole from 7696’ MD to 3948’ MD. Backreaming speeds from
1200 ft/hr - 1800 ft/hr.
7/3/2023 7/4/2023 7,696 0.00 11.20 No accidents, incidents or spills. Continue BROOH from 3948' MD to 1386' MD. POOH on
elevators from 1478' MD to 625' MD. Rack back HWDP L/D clean out assembly. PJSM rigging
up wireline equipment and toolstring. RIH with logging tools F/106' to 3565'. Wireline could not
get past 3565'. Toolstring became stuck, attempted to free. Pulled max 14.5K. Set jars off 2
times. Freed tools. Decision made to abandon logging program and POOH. Wireline with
Sonic/Formation Imager logging from 3544'MD to 2575' MD. Wireline POOH from 2575' MD to
surface. R/U CBL wireline assembly, calibrate tool. RIH from surface to 2550' MD. Wireline
perform CBL from 2550' MD to surface. PJSM, R/D CBL wireline assembly, R/D wireline
sheaves, continue sending out all wireline tools from pipeshed. PJSM, R/U to run 7" production
casing.
Page 3 of 5
gggg
R/U CBL wireline assembly, calibrate tool. RIH from surface to 2550' MD. Wireliney,
perform CBL from 2550' MD to surface.
Rungg ,gp
#1 with Formation Imager/sonic tool assembly from surface to 2654’ MD. Wire line having troublegy g
working past 2654'. POOH with wireline tool assembly from 2654' MD to surface and reconfiguregp
wire line assembly. Rig y
Run #2 with Formation,,j y
Imager/sonic tool assembly from surface to 2668’ MD. Wireline having trouble working pastgy ggp
2668'. POOH and L/D Formation Imager. Run #3 with sonic tool assembly from surface to 2674’g
MD, having trouble working past 2674' MD
pg , , ,
Circulate hole clean for upcoming LOT. Rig up and perform
LOT. Sucessful LOT, EMW of 16.6 ppg
Ops Summary Report All Jobs - AOGCC
Start Date End Date
Start Depth
(ftKB) Depth Prog (ft)
Dens Last
Mud (lb/gal) Summary
7/4/2023 7/5/2023 7,696 11.20 No accidents, incidents or spills. RIH W/Hydril 563 casing, 26#, F/Surface, T/5191' MD, run
centralizers as per Santos program. P/U liner top packer, mix Xanplex per liner Rep, continue
running liner. RIH with 5” DP from 5191' to 7651’ MD. Stage up to cementing rate in 1 BPM
increments to final circulating rate of 5 BPM.
7/5/2023 7/6/2023 7,696 10.70 No accidents, incidents or spills. Circulated prior to cement job. P/U cement head & dropped 1.5"
ball. Tagged at 7696', pick up to 7693'. Pumped ball down, ball seated & pressured up to 3800
psi, P/U to verify hanger set. R/U & pump 60 bbl spacer, release bottom plug, pump 136 bbl lead
& 50 bbl tail cement, released top plug. Displace cement with 177 bbls of 10.7 ppg Brine. R/D
cement lines & equip. POOH from 2429'. Dummy run with 7" tie-back landing jt. P/U & RIH with
polish mill assy to 2429' MD & polish liner top. POOH from 2429' & L/D polish assy. Perform rig
service.
7/6/2023 7/7/2023 7,696 10.69 No accidents, incidents or spills. R/U & pull wear bushing. RIH with 7" tie-back & hanger, freeze
protect 9-5/8"x7" annular, land hanger in wellhead, pressure test annulus - good test, L/D landing
jt & R/D handling tools, set packoff & test void to 5000 psi - good test, pressure test 7" tie-
back/liner casing to 4000 psi - good test, R/D test equip, R/U HES wireline & RIH with CBL
assembly to 7250' MD.
7/7/2023 7/8/2023 7,696 10.69 No accidents, incidents or spills. Completed HES CBL log from 7300' MD to 7250' MD. POOH &
L/D CBL assembly. P/U & RIH with HES Sonic assembly. Log from 7563' MD to 2429' MD.
POOH & L/D Sonic assembly. R/D HES wireline & equip. Dummy run 4.5" Completion hanger &
landing jt. R/U 4.5" tubing handling tools & equip. RIH with 4.5" 12.6# 13CR80 JFEBEAR
Completion string from surface to 6590' MD. Rig Service.
7/8/2023 7/9/2023 7,696 10.69 No accidents, incidents or spills. RIH & land 4.5" 12.6# 13CR80 JFEBEAR Completion string,
WLEG at 7095' MD. Displace well with 9.4 ppg
NaCl inhibited Brine. Received AOGCC approval to set fpacker. Pressure up to 4000 psi to set
packer - successful, observed pressures equalize & pumped 2 bbls to verify packer sheared.
Freeze protected with 30 bbls of diesel. Install TWCV. Blow down & R/D test lines. N/D BOPE.
Clean wellhead, install API ring, N/U adapter flange.
7/9/2023 7/9/2023 7,696 10.69 No accidents, incidents or spills. Prep rig floor for skidding, clean pits, prep pipe barn for splitting,
disconnect lines and hoses, verify items on pre-move checklist. Installed tree and cleaned out
cellar box. Lowered derrick and preppared modules for separation and rig move.
*Rig released from DW-02 at 12:00 hrs on 7/9/23.
7/12/2023 7/13/2023 0 Pressure tested tree to 5,000 psi, performed tubing hanger test to 5000 psi, and IC hanger test to
3000 psi (all passed).
Initial T/I/O = 0/0/0
Final T/I/O = 0/0/0
7/13/2023 7/14/2023 0 Pulled ball & rod, swap shear valve to dummy valve.
Initial T/I/O = 0/0/0
Final T/I/O = 0/0/0
7/14/2023 7/15/2023 0 RIH, pull RHC plug body. Run a 3-1/8 x 30' long dummy perf gun. MIRU E-Line & MU tool
string. Unable to PT PCE, LDFN.
Initial T/I/O = 0/0/0
Final T/I/O = 0/0/0
7/15/2023 7/16/2023 0 RIH & perforate zone 7,240' through 7,270'MD w/maxforce HMX charge, 6 shots/foot 60° phase.
Initial T/I/O = 0/0/0
Final T/I/O = 1900/450/0
7/19/2023 7/20/2023 0 MIT-IA to 4000 psi (passed) AOGCC witnesses by Guy Cook. Perform step rate test, initial
breakover seen at 1.5 bpm, SD for 30 minutes and monitor pressure. Continue increasing rate to
6 bpm @ 2200 psi.
Page 4 of 5
Log from 7563' MD to 2429' MD.y
POOH & L/D Sonic assembly
with CBLg
assembly to 7250' MD.
Completed HES CBL log from 7300' MD to 7250' MD.
pp,pp
R/U & pump 60 bbl spacer, release bottom plug, pump 136 bbl leadp, y g p p p , pg,p p
& 50 bbl tail cement, released top plug. Displace cement with 177 bbls of 10.7 ppg Brine
MIT-IA to 4000 psi (passed) AOGCC witnesses by Guy Cook
Ops Summary Report All Jobs - AOGCC
Start Date End Date
Start Depth
(ftKB) Depth Prog (ft)
Dens Last
Mud (lb/gal) Summary
7/20/2023 7/21/2023 0 Perform temperature gradient run from 7300' - 1200'. Run spinner past perforations at 30/60/90/
fpm while pumping 6 bpm (all perfs accepting fluid). Perform Water-Flow log for EPA, no upward
movement seen behind pipe above top perforation.
7/21/2023 7/21/2023 0 LRS pumped 78bbls of Arctic grade diesel to freeze protect 4 1/2" tubing
Page 5 of 5
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TD Shoe Depth: PBTD:
Fluid Description:
Liner hanger Info (Make/Model): Liner top Packer?: Yes X No
Liner hanger test pressure:
Centralizer Placement:
Preflush (Spacer)
Type: Density (ppg) Volume pumped (BBLs)
Lead Slurry
Type: Yield (Ft3/sack):
Density (ppg) Volume (BBLs/sacks): Mixing / Pumping Rate (bpm):
Tail Slurry
Type: Yield (Ft3/sack):
Density (ppg) Volume (BBLs/sacks): Mixing / Pumping Rate (bpm):
Post Flush (Spacer)
Type Density (ppg) Rate (bpm): Volume:
Displacement:
Type Density (ppg) Rate (bpm): Volume (actual / calculated):
FCP (psi): Pump used for disp: Plug Bumped?X Yes No
Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job
Cement returns to surface?X Yes No Spacer returns? Yes X No Vol to Surf:
Cement In Place At: Date: Estimated TOC:
Method Used To Determine TOC:
80
135 BBL
17:00 HRS 06/23/23 Surface
Visual / physical confirmation of cement
Spud Mud 10.5 5 174.6 bbls
781 Rig Pumps Bump press 1208
10.5 PPG water based Spud Mud
na
na
1 per every joint to 50' below conductor shoe
CEMENTING REPORT
FI
R
S
T
S
T
A
G
E
Tuned Spacer 10.7 80
15.3 49 BBL 4
Fresh Water 8.3 5 10
ArcticCEM 2.544
11 318 BBL 6
Type I/II 1.242
Csg Wt. On Slips: PU = 180K Type of Shoe: Bull Nose Casing Crew: Parker
Csg Wt. On Hook: PU = 123K Type Float Collar: Baker No. Hrs to Run: 35
Casing (58-63)9-5/8 47 L80 HYD563 Tenaris 135.16 178.49 43.33
Casing (3-57)9-5/8 2,495.17 219.90
XO Joint 9-5/8 47 L80 HYD563 Tenaris 41.41 219.90 178.49
47 L80 TXP BTC Tenaris 2,275.27
Float Collar 9-5/8 47 L80 BTC Baker 1.39 2,496.56 2,495.17
2,574.00 2,572.18
Casing (1-2)9-5/8 47 L80 BTC Tenaris 75.62 2,572.18 2,496.56
Float Shoe 9-5/8 47 L80 BTC Baker 1.82
No. of Jts. Size Wt. Grade THD Make
Casing (Or Liner) Detail Setting Depths
County Alaska State Alaska Supv. Lawson / O'Neal
Length Bottom Top
Oil Search Alaska
SURFACE CASING & CEMENTING REPORT
Well No./ PTD # DW-02 / 50-103-20855-00-00 / 223-039 Date 24-Jun-23
CASING RECORD
2575' MD / 2248' TVD 2574' MD / 2247' TVD 2495' MD / 2188' TVD
TD Shoe Depth: PBTD:
Fluid Description:
Liner hanger Info (Make/Model): Liner top Packer?:X Yes No
Liner hanger test pressure:
Centralizer Placement:
Preflush (Spacer)
Type: Density (ppg) Volume pumped (BBLs)
Lead Slurry
Type: Yield (Ft3/sack):
Density (ppg) Volume (BBLs/sacks): Mixing / Pumping Rate (bpm):
Tail Slurry
Type: Yield (Ft3/sack):
Density (ppg) Volume (BBLs/sacks): Mixing / Pumping Rate (bpm):
Post Flush (Spacer)
Type Density (ppg) Rate (bpm): Volume:
Displacement:
Type Density (ppg) Rate (bpm): Volume (actual / calculated):
FCP (psi): Pump used for disp: Plug Bumped?X Yes No
Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job
Cement returns to surface? Yes X No Spacer returns?X Yes No Vol to Surf:
Cement In Place At: Date: Estimated TOC:
Method Used To Determine TOC:
100
20 BBLs
07:26 hrs 07/05/23 TOL
HES CAST-M Cement Bond Log
CaCl2 Brine 10.7 3.7 222 BBLs
560 Rig Pumps Bump press 1150
11.2ppg VERSACLEAN MOBM
Baker Uniflex Pro 7" x 9-5/8"
3500 psi
1 centralizer per joint to surface casing shoe.
CEMENTING REPORT
FI
R
S
T
S
T
A
G
E
Tuned Spacer 11.5 60
15.3 50 BBLs 4
Fresh Water 8.3 4 10
ExtendaCem 2.354
12 136 BBLs 4
Type I/II 1.237
Csg Wt. On Slips: N/A Type of Shoe: Baker Casing Crew: Parker
Csg Wt. On Hook: PU = 200K Type Float Collar: Baker No. Hrs to Run: 18.5
LH/LTP 7 x 9-5/8 29 L80 VT HT Baker 27.47 2,456.51 2,429.04
Crossover 7 26 L80 VT HT Tenaris 2.04 2,458.55 2,456.51
Pup Joint 7 26 L80 HYD563 Tenaris 3.82 2,462.37 2,458.55
Casing (4-126)7 26 L80 HYD563 Tenaris 5,108.88 7,571.25 2,462.37
Casing (3)7 7,613.80 7,574.77
Landing Collar 7 26 L80 BTC Baker 3.52 7,574.77 7,571.25
26 L80 BTC Tenaris 39.03
Float Collar 7 26 L80 BTC Baker 1.30 7,615.10 7,613.80
7,693.00 7,691.00
Casing (1-2)7 26 L80 BTC Tenaris 75.90 7,691.00 7,615.10
Float Shoe 7 26 L80 BTC Baker 2.00
No. of Jts. Size Wt. Grade THD Make
Casing (Or Liner) Detail Setting Depths
County Alaska State Alaska Supv. Buzby / Whitlatch
Length Bottom Top
Oil Search Alaska
PRODUCTION LINER & CEMENTING REPORT
Well No./ PTD # DW-02 / 50-103-20855-00-00 / 223-039 Date 05-Jul-23
CASING RECORD
7696' MD / 6267' TVD 7693' MD / 6264' TVD 7575' MD / 6153' TVD
TD Shoe Depth: PBTD:
Fluid Description:
Liner hanger Info (Make/Model): Liner top Packer?: Yes X No
Liner hanger test pressure:
Centralizer Placement:
Preflush (Spacer)
Type: Density (ppg) Volume pumped (BBLs)
Lead Slurry
Type: Yield (Ft3/sack):
Density (ppg) Volume (BBLs/sacks): Mixing / Pumping Rate (bpm):
Tail Slurry
Type: Yield (Ft3/sack):
Density (ppg) Volume (BBLs/sacks): Mixing / Pumping Rate (bpm):
Post Flush (Spacer)
Type: Density (ppg) Rate (bpm): Volume:
Displacement:
Type: Density (ppg) Rate (bpm): Volume (actual / calculated):
FCP (psi): Pump used for disp: Plug Bumped? Yes No
Casing Rotated? Yes No Reciprocated? Yes No % Returns during job
Cement returns to surface? Yes No Spacer returns? Yes No Vol to Surf:
Cement In Place At: Date: Estimated TOC:
Method Used To Determine TOC:
Bump press
10.7ppg CaCl2 Brine
N/A
1 per joint on Joint # 1 and 2
CEMENTING REPORT
FI
R
S
T
S
T
A
G
E
N/A
N/A
Csg Wt. On Slips: N/A Type of Shoe: N/A Casing Crew: Parker
Csg Wt. On Hook: PU = 92K Type Float Collar: N/A No. Hrs to Run: 7
Csg Hanger 7 26 L80 HYD563 FMC 0.55 44.29 43.74
Hanger Pup 7 26 L80 HYD563 FMC 2.57 46.86 44.29
Pup Jt 7 91.26 88.23
Casing (57)7 26 L80 HYD563 Tenaris 41.37 88.23 46.86
26 L80 HYD563 Tenaris 3.03
Pup Jt 7 26 L80 HYD563 Tenaris 3.08 94.34 91.26
2,431.50 2,424.71
Casing (1-56)7 26 L80 HYD563 Tenaris 2,330.37 2,424.71 94.34
Seal Assy 7 26 L80 BTC Baker 6.79
No. of Jts. Size Wt. Grade THD Make
Casing (Or Liner) Detail Setting Depths
County Alaska State Alaska Supv. Buzby / Whitlatch
Length Bottom Top
Oil Search Aalska
TIEBACK CASING & CEMENTING REPORT
Well No./ PTD # DW-02 / 50-103-20855-00-00 / 223-039 Date 06-Jul-23
CASING RECORD
N/A 2432' MD / 2140' TVD N/A
LETTER OF TRANSMITTAL
DETAIL
QTY DESCRIPTION
2 logs
DW-02 (50-103-20855-0000)
DW-02 Per Log in PDF and LAS
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: 8/17/2023
From:
Shannon Koh
Santos
P.O. Box 240927
Anchorage, AK 99524-0927
To:
Kayla Junke
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:
8/17/2023
PTD: 223-039
T37939
Kayla
Junke
Digitally signed
by Kayla Junke
Date: 2023.08.17
12:54:36 -08'00'
LETTER OF TRANSMITTAL
DETAIL
QTY DESCRIPTION
DW-02 (50-103-20855-0000)
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
907-375-4607 phone
shannon.koh@santos.com
DATE: 8/7/2023
From:
Eileen Guthrie
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:
PTD:223-039
T37913
8/8/2023
Kayla
Junke
Digitally signed by
Kayla Junke
Date: 2023.08.08
10:02:20 -08'00'
LETTER OF TRANSMITTAL
AOGCC\AOGCC\Wellsite Geologist Final Well Report\Wellsite Geologist FWR DW-02.doc
AOGCC\AOGCC\Log Digital Data\Cement Evaluation Logs\DW-02_CAST-CBL_06JUL23_ProcessedLog_3040-7542ft.dlis
AOGCC\AOGCC\Log Digital Data\Cement Evaluation Logs\DW-02_CAST-CBL_06JUL23_Raw_3040-7542ft.dlis
AOGCC\AOGCC\Log Digital Data\LWD\DW-02_LWD_RM_7696ft.dlis
AOGCC\AOGCC\Log Digital Data\Cement Evaluation Logs\DW-02_CAST-CBL_03JUL23_ProcessedLog.dlis
AOGCC\AOGCC\Log Digital Data\LWD\DW-02_LWD_RM_7696ft.las
AOGCC\AOGCC\Log Digital Data\Cement Evaluation Logs\DW-02_CAST-CBL_03JUL23_Raw.dlis
AOGCC\AOGCC\Log Digital Data\Cement Evaluation Logs\DW-02_CAST-CBL_06JUL23_ProcessedLog.pdf
AOGCC\AOGCC\Log Digital Data\Cement Evaluation Logs\DW-02_CAST-CBL_03JUL23_ProcessedLog.pdf
AOGCC\AOGCC\Log Digital Data\Cement Evaluation Logs\DW-02_CAST-CBL_06JUL23_ProcessedLog_2400-3040ft.dlis
AOGCC\AOGCC\Mudlog\Mudlogging EOW Report\Santos_DW-02_Geolog Mudlogging FWR.pdf
AOGCC\AOGCC\Log Digital Data\LWD\DW-02_DMD_RM_7696ft.las
AOGCC\AOGCC\Log Digital Data\Cement Evaluation Logs\DW-02_CAST-CBL_06JUL23_Raw_2400-3040ft.dlis
AOGCC\AOGCC\Log Digital Data\Wireline Logging\SANTOS_DW-02_STX6_COMPOSITE_INTERPRETATION_1to20.pdf
AOGCC\AOGCC\Mudlog\Mudlogging Daily Reports\DW-02 Geological Reports Compilation.pdf
AOGCC\AOGCC\Log Digital Data\LWD\DW-02_LWD_RM_5MD_7696ft.pdf
AOGCC\AOGCC\Log Digital Data\LWD\DW-02_LWD_RM_5TVD_7696ft.pdf
AOGCC\AOGCC\Log Digital Data\LWD\DW-02_DMD_RM_7696ft.pdf
AOGCC\AOGCC\Log Digital Data\LWD\DW-02_LWD_RM_2MD_7696ft.pdf
AOGCC\AOGCC\Log Digital Data\LWD\DW-02_DMT_RM.pdf
AOGCC\AOGCC\Log Digital Data\LWD\DW-02_LWD_RM_2TVD_7696ft.pdf
AOGCC\AOGCC\Log Digital Data\LWD\DW-02_DMT_R05_RM.las
AOGCC\AOGCC\Mudlog\Mudlogging Final Data\DW-02_Mudlog_7696ft_MD.pdf
AOGCC\AOGCC\Log Digital Data\LWD\DW-02_DMT_R02_RM.las
AOGCC\AOGCC\Mudlog\Mudlogging Final Data\DW-02_DrillGas_ASCII_depth_7696ft.las
AOGCC\AOGCC\Log Digital Data\LWD\DW-02_DMT_R03_RM.las
AOGCC\AOGCC\Mudlog\Mudlogging Final Data\DW-02_Lithology_7696ft.xlsx
AOGCC\AOGCC\Directional Survey\DW-02 NAD27 Compass Survey Report.pdf
AOGCC\AOGCC\Directional Survey\DW-02 NAD83 Compass Survey Report.pdf
AOGCC\AOGCC\Analyses\SAN-230701 DW-02, North Slope, AK, Gas Analyses.xlsx
AOGCC\AOGCC\Directional Survey\DW-02 Vertical Section Compass Report.pdf
AOGCC\AOGCC\Directional Survey\DW-02 Plan view Compass Report.pdf
AOGCC\AOGCC\Mudlog\Oil Gas and Hydrate Show list\Show Report Geolog_DW-02_4971-5020_ii.pdf
AOGCC\AOGCC\Mudlog\Oil Gas and Hydrate Show list\Show Report Geolog_DW-02_5850-5910_iii_e.pdf
AOGCC\AOGCC\Mudlog\Oil Gas and Hydrate Show list\Show Report Geolog_DW-02_5730-5790_iii_c.pdf
AOGCC\AOGCC\Mudlog\Oil Gas and Hydrate Show list\Show Report Geolog_DW-02_5910-6000_iii_f.pdf
AOGCC\AOGCC\Mudlog\Oil Gas and Hydrate Show list\Show Report Geolog_DW-02_5790-5850_iii_d.pdf
AOGCC\AOGCC\Mudlog\Oil Gas and Hydrate Show list\Show Report Geolog_DW-02_5670-5730_iii_b.pdf
AOGCC\AOGCC\Mudlog\Oil Gas and Hydrate Show list\Show Report Geolog_DW-02_4880-4920_i.pdf
AOGCC\AOGCC\Mudlog\Oil Gas and Hydrate Show list\Show Report Geolog_DW-02_6620-6720_iv.pdf
AOGCC\AOGCC\Mudlog\Oil Gas and Hydrate Show list\Show Report Geolog_DW-02_5621-5670_iii_a.pdf
AOGCC\AOGCC\Mudlog\Oil Gas and Hydrate Show list\Show Report Geolog_DW-02_7190-7260-_v.pdf
LETTER OF TRANSMITTAL
AOGCC\AOGCC\Core Data\No Data.docx
AOGCC\AOGCC\Log Digital Data\Wireline Logging\SANTOS_DW-02_STRATA_XAMINER_6_BEDDING_AND_FRACTURE_DIPS.las
AOGCC\AOGCC\Log Digital Data\Wireline Logging\SANTOS_DW-02_STRATA_XAMINER_6_NATURAL_FRAC_FREQUENCY.las
AOGCC\AOGCC\Log Digital Data\Wireline Logging\SANTOS_DW-02_STRATA_XAMINER_6_BEDDING_AND_FRACTURE_DIPS.csv
AOGCC\AOGCC\Directional Survey\DW-02 NAD27 Compass Survey Reports.txt
AOGCC\AOGCC\Directional Survey\DW-02 NAD83 Compass Survey Reports.txt
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Friday, September 15, 2023
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Guy Cook
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
Oil Search (Alaska), LLC
DW-02
PIKKA DW-02
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 09/15/2023
DW-02
50-103-20855-00-00
223-039-0
N
SPT
5711
2230390 1500
1071 1604 1594 1576
0 0 0 0
INITAL P
Guy Cook
7/19/2023
MIT-IA to 4000 psi as per procedure. Class 1 disposal well. Testing was completed with a Little Red Services pump truck and calibrated gauges.
30 MinPretestInitial15 Min
Well Name
Type Test
Notes:
Interval P/F
Well
Permit Number:
Type Inj TVD
PTD Test psi
API Well Number Inspector Name:PIKKA DW-02
Inspection Date:
Tubing
OA
Packer Depth
412 4203 4138 4119IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitGDC230719165322
BBL Pumped:2.1 BBL Returned:2.2
Friday, September 15, 2023 Page 1 of 1
9
9
9
9
9
9
9 9
999
9
9
MIT-IA to 4000 psi Class 1 disposal well.
James B. Regg Digitally signed by James B. Regg
Date: 2023.09.15 13:54:09 -08'00'
From:Lambe, Steven (Steven)
To:Rixse, Melvin G (OGC); Johnson, Vernon (Vern)
Cc:Staudinger, Garret (Garret); Tirpack, Robert (Robert); Regg, James B (OGC); Loepp, Victoria T (OGC); McLellan, Bryan J (OGC); Davies, Stephen F (OGC); Guhl, Meredith D (OGC);
Carlisle, Samantha J (OGC); Roby, David S (OGC)
Subject:RE: Additional Information Request and Previous Request for information - Gas Bubbling Notification - AOGCC Drilling Reports Review PTD223-039
Date:Friday, July 7, 2023 7:00:59 AM
Attachments:image005.png
You don't often get email from steven.lambe@contractor.santos.com. Learn why this is important
Mel-
Thank you for taking time on the phone with Garret and I.
The Santos internal IMT has stood down effective this morning. All the flow and associated bubbling has ceased, and been non active for over 48
hours now. We had continuous gas monitoring and a visual inspection on an hourly basis. There was a decreasing trend noted during the first day.
At the time, DW-02 was drilled to section TD
Garret has forwarded the requested Drilling Report summary and the Cement Bond Log on the 9-5/8”.
Enclosed is a snap shot picture of the flow anomaly with a Boom wrapped around the site. The Gauge stick was installed to monitor fluid level.
Estimating a flow quantity is always a challenge. It was described to me as a Garden Hose Capacity. We were able to measure ~ 5% gas in air right at
the site. From the Mud Loggers, we were able to test gas as Methane with a slight trace of Ethane.
Santos explored the source initially as Naturally occurring event, or well related. After reviewing our Bond Log and the well status, we are focussing our
forward efforts on understanding the Geotechnical lens. I have also attached an overview map with the location.
We are sending samples outside of Alaska for the isotope analysis. This will allow us to finger print the gas as either Biogenic or Thermogenic.
Santos will continue to monitor the site through the weekend on frequent basis.
If you need any further information, please reach out to me directly.
Steven
Steven Lambe
Senior Operations Manager Drilling & Completion
t: +1 907 375 4647 | m: +1 907 330 9219 | e: steven.lambe@contractor.santos.com
Santos.com | Follow us on LinkedIn, Facebook and Twitter
<Country acknowledgment of Traditional Owners and Custodians of the Land.>
From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>
Sent: Thursday, July 6, 2023 9:22 AM
To: Johnson, Vernon (Vern) <Vern.Johnson@santos.com>
Cc: Staudinger, Garret (Garret) <Garret.Staudinger@santos.com>; Lambe, Steven (Steven) <Steven.Lambe@contractor.santos.com>; Tirpack, Robert
(Robert) <Robert.Tirpack@santos.com>; Regg, James B (OGC) <jim.regg@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@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>; Lambe, Steven (Steven) <Steven.Lambe@contractor.santos.com>; Carlisle, Samantha J (OGC)
<samantha.carlisle@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>
Subject: ![EXT]: Additional Information Request and Previous Request for information - Gas Bubbling Notification - AOGCC Drilling Reports Review
PTD223-039
Vern,
As described in the original AOGCC request, please provide the daily drilling reports to AOGCC for DW-02.
AOGCC requests additional information as follows:
1. Pictures or videos of the bubbling.
2. A quantitative estimate of the rate of flow of the anomaly.
3. The current Santos explanation as to the likely cause of the anomaly.
4. A statement regarding why it take two weeks to perform a gas chromatograph analysis of the samples. (AOGCC experience is that it is
straight forward process and there are labs on the North Slope and in Seattle that can provide the service.)
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 vern.johnson@santos.com. Learn why this is important
5. Daily status updates of the anomaly until diminished.
Mel Rixse
Senior Petroleum Engineer (PE)
Alaska Oil and Gas Conservation Commission
907-793-1231 Office
907-297-8474 Cell
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the
intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended
recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or
(Melvin.Rixse@alaska.gov).
cc. Garret Staudinger, Steven Lambe, Rob Tirpack, Roby, Davies, Guhl, Loepp, McLellan, Regg
From: Johnson, Vernon (Vern) <Vern.Johnson@santos.com>
Sent: Wednesday, July 5, 2023 5:31 PM
To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>
Cc: Staudinger, Garret (Garret) <Garret.Staudinger@santos.com>; Lambe, Steven (Steven) <Steven.Lambe@contractor.santos.com>; Tirpack, Robert
(Robert) <Robert.Tirpack@santos.com>; Anderson, Tammie (Tammie) <Tammie.Anderson@santos.com>; Fencil, Kollin (Kollin)
<Kollin.Fencil@santos.com>; Regg, James B (OGC) <jim.regg@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@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>;
Lambe, Steven (Steven) <Steven.Lambe@contractor.santos.com>
Subject: RE: Gas Bubbling Notification - AOGCC Drilling Reports Review PTD223-039
Mel,
See the attached note, which answers most of your questions. Additionally, per your questions, DW-02 is not on injection, and the area is visually
inspected multiple times per day. The frequency of sampling has changed over the last day due to the fact that there was nothing to sample.
Let me know if you have any other questions.
Vern
Vern Johnson–Vice President Drilling &CompletionsOil Search (Alaska), LLC a subsidiary of Santos Limited
P.O. Box 240927 Anchorage, Alaska 99524-0927
o: +1 (907) 375-4668 | m: +1 (907) 575-9430
vern.johnson@santos.com
https://www.santos.com/
From: Staudinger, Garret (Garret)
Sent: Wednesday, July 5, 2023 12:19 PM
To: Rixse, Melvin G (OGC) < Tirpack, Robert (Robert) <Robert.Tirpack@santos.com>
Cc:
Subject: RE: Gas Bubbling Notification - AOGCC Drilling Reports Review PTD223-039
Mel,
Thanks for the email. These questions have been submitted to our Incident Management Team (IMT) and will be addressed shortly. Expect
correspondence from the IMT later today.
Regards,
Garret Staudinger
Senior Drilling Engineer
t: +1 (907) 375-4666 | m: +1 (907) 440-6892
From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>
Sent: Wednesday, July 5, 2023 10:28 AM
To: Staudinger, Garret (Garret) <Garret.Staudinger@santos.com>; Tirpack, Robert (Robert) <Robert.Tirpack@santos.com>
Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@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>
Subject: ![EXT]: Gas Bubbling Notification - AOGCC Drilling Reports Review PTD223-039
Garret, Rob,
Steve Lamb notified AOGCC of gas bubbling from a small pond off the NDB drilling pad. AOGCC would like to review the daily drilling reports for
well DW-02 (PTD223-039) or other relevant drilling reports to assure there is no link between recent drilling and the observed gas bubbling.
AOGCC would also request answers to the following information:
1. Is the gas bubbling rate changing?
2. Is Santos continually monitoring the pond?
3. What is your sampling frequency?
4. Is Santos running an isotopic analysis?
5. Is DW-02 on any injection?
Mel Rixse
Senior Petroleum Engineer (PE)
Alaska Oil and Gas Conservation Commission
907-793-1231 Office
907-297-8474 Cell
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the
intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended
recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or
(Melvin.Rixse@alaska.gov).
cc. Jim Regg, Victoria Loepp, Bryan McLellan, Steve Davies, Meredith Guhl
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 intendedrecipient 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
From:Rixse, Melvin G (OGC)
To:Lambe, Steven (Steven); Johnson, Vernon (Vern)
Cc:Staudinger, Garret (Garret); Tirpack, Robert (Robert); Regg, James B (OGC); Loepp, Victoria T (OGC); McLellan, Bryan J (OGC); Davies, Stephen F (OGC); Guhl, Meredith D (OGC);
Carlisle, Samantha J (OGC); Roby, David S (OGC)
Subject:RE: Additional Information Request and Previous Request for information - Gas Bubbling Notification - AOGCC Drilling Reports Review PTD223-039
Date:Friday, July 7, 2023 10:42:00 AM
Attachments:image001.png
Steve,
I appreciate your response. If I need something more I will let you know.
Please let us know the results of the isotopic analysis.
Mel Rixse
Senior Petroleum Engineer (PE)
Alaska Oil and Gas Conservation Commission
907-793-1231 Office
907-297-8474 Cell
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the
intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended
recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or
(Melvin.Rixse@alaska.gov).
From: Lambe, Steven (Steven) <Steven.Lambe@contractor.santos.com>
Sent: Friday, July 7, 2023 7:01 AM
To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Johnson, Vernon (Vern) <Vern.Johnson@santos.com>
Cc: Staudinger, Garret (Garret) <Garret.Staudinger@santos.com>; Tirpack, Robert (Robert) <Robert.Tirpack@santos.com>; Regg, James B (OGC)
<jim.regg@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@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>; Carlisle, Samantha J (OGC) <samantha.carlisle@alaska.gov>;
Roby, David S (OGC) <dave.roby@alaska.gov>
Subject: RE: Additional Information Request and Previous Request for information - Gas Bubbling Notification - AOGCC Drilling Reports Review PTD223-
039
Mel-
Thank you for taking time on the phone with Garret and I.
The Santos internal IMT has stood down effective this morning. All the flow and associated bubbling has ceased, and been non active for over 48
hours now. We had continuous gas monitoring and a visual inspection on an hourly basis. There was a decreasing trend noted during the first day.
At the time, DW-02 was drilled to section TD
Garret has forwarded the requested Drilling Report summary and the Cement Bond Log on the 9-5/8”.
Enclosed is a snap shot picture of the flow anomaly with a Boom wrapped around the site. The Gauge stick was installed to monitor fluid level.
Estimating a flow quantity is always a challenge. It was described to me as a Garden Hose Capacity. We were able to measure ~ 5% gas in air right at
the site. From the Mud Loggers, we were able to test gas as Methane with a slight trace of Ethane.
Santos explored the source initially as Naturally occurring event, or well related. After reviewing our Bond Log and the well status, we are focussing our
forward efforts on understanding the Geotechnical lens. I have also attached an overview map with the location.
We are sending samples outside of Alaska for the isotope analysis. This will allow us to finger print the gas as either Biogenic or Thermogenic.
Santos will continue to monitor the site through the weekend on frequent basis.
If you need any further information, please reach out to me directly.
Steven
Steven Lambe
Senior Operations Manager Drilling & Completion
t: +1 907 375 4647 | m: +1 907 330 9219 | e: steven.lambe@contractor.santos.com
Santos.com | Follow us on LinkedIn, Facebook and Twitter
<Country acknowledgment of Traditional Owners and Custodians of the Land.>
From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>
Sent: Thursday, July 6, 2023 9:22 AM
To: Johnson, Vernon (Vern) <Vern.Johnson@santos.com>
Cc: Staudinger, Garret (Garret) <Garret.Staudinger@santos.com>; Lambe, Steven (Steven) <Steven.Lambe@contractor.santos.com>; Tirpack, Robert
(Robert) <Robert.Tirpack@santos.com>; Regg, James B (OGC) <jim.regg@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@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>; Lambe, Steven (Steven) <Steven.Lambe@contractor.santos.com>; Carlisle, Samantha J (OGC)
<samantha.carlisle@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>
Subject: ![EXT]: Additional Information Request and Previous Request for information - Gas Bubbling Notification - AOGCC Drilling Reports Review
PTD223-039
Vern,
As described in the original AOGCC request, please provide the daily drilling reports to AOGCC for DW-02.
AOGCC requests additional information as follows:
1. Pictures or videos of the bubbling.
2. A quantitative estimate of the rate of flow of the anomaly.
3. The current Santos explanation as to the likely cause of the anomaly.
4. A statement regarding why it take two weeks to perform a gas chromatograph analysis of the samples. (AOGCC experience is that it is
straight forward process and there are labs on the North Slope and in Seattle that can provide the service.)
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 vern.johnson@santos.com. Learn why this is important
5. Daily status updates of the anomaly until diminished.
Mel Rixse
Senior Petroleum Engineer (PE)
Alaska Oil and Gas Conservation Commission
907-793-1231 Office
907-297-8474 Cell
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the
intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended
recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or
(Melvin.Rixse@alaska.gov).
cc. Garret Staudinger, Steven Lambe, Rob Tirpack, Roby, Davies, Guhl, Loepp, McLellan, Regg
From: Johnson, Vernon (Vern) <Vern.Johnson@santos.com>
Sent: Wednesday, July 5, 2023 5:31 PM
To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>
Cc: Staudinger, Garret (Garret) <Garret.Staudinger@santos.com>; Lambe, Steven (Steven) <Steven.Lambe@contractor.santos.com>; Tirpack, Robert
(Robert) <Robert.Tirpack@santos.com>; Anderson, Tammie (Tammie) <Tammie.Anderson@santos.com>; Fencil, Kollin (Kollin)
<Kollin.Fencil@santos.com>; Regg, James B (OGC) <jim.regg@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@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>;
Lambe, Steven (Steven) <Steven.Lambe@contractor.santos.com>
Subject: RE: Gas Bubbling Notification - AOGCC Drilling Reports Review PTD223-039
Mel,
See the attached note, which answers most of your questions. Additionally, per your questions, DW-02 is not on injection, and the area is visually
inspected multiple times per day. The frequency of sampling has changed over the last day due to the fact that there was nothing to sample.
Let me know if you have any other questions.
Vern
Vern Johnson–Vice President Drilling &CompletionsOil Search (Alaska), LLC a subsidiary of Santos Limited
P.O. Box 240927 Anchorage, Alaska 99524-0927
o: +1 (907) 375-4668 | m: +1 (907) 575-9430
vern.johnson@santos.com
https://www.santos.com/
From: Staudinger, Garret (Garret)
Sent: Wednesday, July 5, 2023 12:19 PM
To: Rixse, Melvin G (OGC) < Tirpack, Robert (Robert) <Robert.Tirpack@santos.com>
Cc:
Subject: RE: Gas Bubbling Notification - AOGCC Drilling Reports Review PTD223-039
Mel,
Thanks for the email. These questions have been submitted to our Incident Management Team (IMT) and will be addressed shortly. Expect
correspondence from the IMT later today.
Regards,
Garret Staudinger
Senior Drilling Engineer
t: +1 (907) 375-4666 | m: +1 (907) 440-6892
From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>
Sent: Wednesday, July 5, 2023 10:28 AM
To: Staudinger, Garret (Garret) <Garret.Staudinger@santos.com>; Tirpack, Robert (Robert) <Robert.Tirpack@santos.com>
Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@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>
Subject: ![EXT]: Gas Bubbling Notification - AOGCC Drilling Reports Review PTD223-039
Garret, Rob,
Steve Lamb notified AOGCC of gas bubbling from a small pond off the NDB drilling pad. AOGCC would like to review the daily drilling reports for
well DW-02 (PTD223-039) or other relevant drilling reports to assure there is no link between recent drilling and the observed gas bubbling.
AOGCC would also request answers to the following information:
1. Is the gas bubbling rate changing?
2. Is Santos continually monitoring the pond?
3. What is your sampling frequency?
4. Is Santos running an isotopic analysis?
5. Is DW-02 on any injection?
Mel Rixse
Senior Petroleum Engineer (PE)
Alaska Oil and Gas Conservation Commission
907-793-1231 Office
907-297-8474 Cell
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the
intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended
recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or
(Melvin.Rixse@alaska.gov).
cc. Jim Regg, Victoria Loepp, Bryan McLellan, Steve Davies, Meredith Guhl
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 intendedrecipient 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 vern.johnson@santos.com. Learn why this is important
From:Rixse, Melvin G (OGC)
To:Johnson, Vernon (Vern)
Cc:Staudinger, Garret (Garret); Lambe, Steven (Steven); Tirpack, Robert (Robert); Regg, James B (OGC); Loepp, Victoria T
(OGC); McLellan, Bryan J (OGC); Davies, Stephen F (OGC); Guhl, Meredith D (OGC); Lambe, Steven (Steven); Carlisle,
Samantha J (OGC); Roby, David S (OGC)
Subject:Additional Information Request and Previous Request for information - Gas Bubbling Notification - AOGCC Drilling Reports
Review PTD223-039
Date:Thursday, July 6, 2023 9:22:31 AM
Vern,
As described in the original AOGCC request, please provide the daily drilling reports to AOGCC for
DW-02.
AOGCC requests additional information as follows:
1. Pictures or videos of the bubbling.
2. A quantitative estimate of the rate of flow of the anomaly.
3. The current Santos explanation as to the likely cause of the anomaly.
4. A statement regarding why it take two weeks to perform a gas chromatograph analysis of the
samples. (AOGCC experience is that it is straight forward process and there are labs on the North
Slope and in Seattle that can provide the service.)
5. Daily status updates of the anomaly until diminished.
Mel Rixse
Senior Petroleum Engineer (PE)
Alaska Oil and Gas Conservation Commission
907-793-1231 Office
907-297-8474 Cell
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation
Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.
The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail,
please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-
793-1231 ) or (Melvin.Rixse@alaska.gov).
cc. Garret Staudinger, Steven Lambe, Rob Tirpack, Roby, Davies, Guhl, Loepp, McLellan, Regg
From: Johnson, Vernon (Vern) <Vern.Johnson@santos.com>
Sent: Wednesday, July 5, 2023 5:31 PM
To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>
Cc: Staudinger, Garret (Garret) <Garret.Staudinger@santos.com>; Lambe, Steven (Steven)
<Steven.Lambe@contractor.santos.com>; Tirpack, Robert (Robert) <Robert.Tirpack@santos.com>;
Anderson, Tammie (Tammie) <Tammie.Anderson@santos.com>; Fencil, Kollin (Kollin)
<Kollin.Fencil@santos.com>; Regg, James B (OGC) <jim.regg@alaska.gov>; Loepp, Victoria T (OGC)
<victoria.loepp@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>; Lambe, Steven
(Steven) <Steven.Lambe@contractor.santos.com>
Subject: RE: Gas Bubbling Notification - AOGCC Drilling Reports Review PTD223-039
Mel,
See the attached note, which answers most of your questions. Additionally, per your questions, DW-02 is
not on injection, and the area is visually inspected multiple times per day. The frequency of sampling has
changed over the last day due to the fact that there was nothing to sample.
Let me know if you have any other questions.
Vern
Vern Johnson–Vice President Drilling &CompletionsOil Search (Alaska), LLC a subsidiary of Santos Limited
P.O. Box 240927 Anchorage, Alaska 99524-0927
o: +1 (907) 375-4668 | m: +1 (907) 575-9430
vern.johnson@santos.com
https://www.santos.com/
From: Staudinger, Garret (Garret)
Sent: Wednesday, July 5, 2023 12:19 PM
To: Rixse, Melvin G (OGC) < Tirpack, Robert (Robert) <Robert.Tirpack@santos.com>
Cc:
Subject: RE: Gas Bubbling Notification - AOGCC Drilling Reports Review PTD223-039
Mel,
Thanks for the email. These questions have been submitted to our Incident Management Team (IMT) and
will be addressed shortly. Expect correspondence from the IMT later today.
Regards,
Garret Staudinger
Senior Drilling Engineer
t: +1 (907) 375-4666 | m: +1 (907) 440-6892
From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>
Sent: Wednesday, July 5, 2023 10:28 AM
To: Staudinger, Garret (Garret) <Garret.Staudinger@santos.com>; Tirpack, Robert (Robert)
<Robert.Tirpack@santos.com>
Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@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>
Subject: ![EXT]: Gas Bubbling Notification - AOGCC Drilling Reports Review PTD223-039
Garret, Rob,
Steve Lamb notified AOGCC of gas bubbling from a small pond off the NDB drilling pad. AOGCC would
like to review the daily drilling reports for well DW-02 (PTD223-039) or other relevant drilling reports to
assure there is no link between recent drilling and the observed gas bubbling.
AOGCC would also request answers to the following information:
1. Is the gas bubbling rate changing?
2. Is Santos continually monitoring the pond?
3. What is your sampling frequency?
4. Is Santos running an isotopic analysis?
5. Is DW-02 on any injection?
Mel Rixse
Senior Petroleum Engineer (PE)
Alaska Oil and Gas Conservation Commission
907-793-1231 Office
907-297-8474 Cell
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation
Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.
The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail,
please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-
793-1231 ) or (Melvin.Rixse@alaska.gov).
cc. Jim Regg, Victoria Loepp, Bryan McLellan, Steve Davies, Meredith Guhl
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 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
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:Rixse, Melvin G (OGC)
To:Carlisle, Samantha J (OGC)
Subject:20230705 1302 OSA : Gas Bubbling Notification - AOGCC Drilling Reports Review PTD223-039
Date:Wednesday, July 5, 2023 2:30:15 PM
From: Rixse, Melvin G (OGC)
Sent: Wednesday, July 5, 2023 1:02 PM
To: Staudinger, Garret (Garret) <Garret.Staudinger@santos.com>
Cc: Tirpack, Robert (Robert) <Robert.Tirpack@santos.com>; Regg, James B (OGC)
<jim.regg@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@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>
Subject: Re: Gas Bubbling Notification - AOGCC Drilling Reports Review PTD223-039
Thanks Garret.
Mel Rixse
On Jul 5, 2023, at 12:18 PM, Staudinger, Garret (Garret)
<Garret.Staudinger@santos.com> wrote:
Mel,
Thanks for the email. These questions have been submitted to our Incident
Management Team (IMT) and will be addressed shortly. Expect correspondence from
the IMT later today.
Regards,
Garret Staudinger
Senior Drilling Engineer
t: +1 (907) 375-4666 | m: +1 (907) 440-6892
From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>
Sent: Wednesday, July 5, 2023 10:28 AM
To: Staudinger, Garret (Garret) <Garret.Staudinger@santos.com>; Tirpack, Robert
(Robert) <Robert.Tirpack@santos.com>
Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Loepp, Victoria T (OGC)
<victoria.loepp@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>
Subject: ![EXT]: Gas Bubbling Notification - AOGCC Drilling Reports Review PTD223-039
Garret, Rob,
Steve Lamb notified AOGCC of gas bubbling from a small pond off the NDB drilling
pad. AOGCC would like to review the daily drilling reports for well DW-02 (PTD223-
039) or other relevant drilling reports to assure there is no link between recent drilling
and the observed gas bubbling.
AOGCC would also request answers to the following information:
1. Is the gas bubbling rate changing?
2. Is Santos continually monitoring the pond?
3. What is your sampling frequency?
4. Is Santos running an isotopic analysis?
5. Is DW-02 on any injection?
Mel Rixse
Senior Petroleum Engineer (PE)
Alaska Oil and Gas Conservation Commission
907-793-1231 Office
907-297-8474 Cell
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil
and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may
contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may
violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or
forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 )
or (Melvin.Rixse@alaska.gov).
cc. Jim Regg, Victoria Loepp, Bryan McLellan, Steve Davies, Meredith Guhl
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 addressedand may be confidential or contain privileged information. If you are not the intended recipient you are hereby notifiedthat 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
LETTER OF TRANSMITTAL
223-o3q
I351
Santos
DATE: 7/11/2023
From:
To:
Shannon Koh
Meredith Guhl
Santos
AOGCC
P.O. Box 240927
333 W. 7th Avenue, Suite 100
Anchorage, AK 99524-0927
Anchorage, AK 99501
TRANSMISSION TYPE:
TRANSMISSION METHOD:
XExternal Request
❑CD ❑ Thumb Drive
I] Internal Request
[]Email ❑SharePoint
L9J. Hardcopy ❑Other- FTP
REASON FOR TRANSMITTAL:
❑Approved XInformation Only ']To Be Returned
❑Approved with Comments []For Your Review ❑With Our Comments
For Approval []For Your Use ❑Other
COMMENTS:
r)FTAII
QTY DESCRIPTION
DW-02 (50-103-20855-0000)
6 boxes of drill cuttings sample
Details on following page
RECEIVED
JUL 11 2023
AOGCC PC-'3
Received by: Date:
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
GEOLOG DRILL =_v MANIFEST Santos
CUTTINGS SAMPLE ANIFEST
WELL NAME
Pikka DW-02
WELL API
50-10320855-00-DC
Date Drilled
FROM 601812023 TO 16rM2023
Am / Locahon
North Slope Borough 1 Alaska
WASHED & OVEN -DRIED SAMPLES Box = SET #1, #2, #3
Box 1
Box 2
Box-3-
Box 4
Box 6
Box 6
MD
MD
MD
MD
MD
MD
>:6$
1470
2850
4080
5060
6480
2
180
1500
2860
4110
5080
6510
3
210
1530
2910
4140
5100
1 6540
4
240
1560
2940
4170
5130
6570
5
270
1590
2970
1 4200
5160
6600
6
300
1620
3000
4230
5190
6630
7
330
1650
3030
4260
5220
6660
8
360
1580
3060
4290
5290
6690
9
390
1710
3090
4320
5'280
6720
tD
420
1740
3120
4350
5310
6750
vi
450
1770
3150
4380
5340
6780
12
480
1800
3180
4410
5370
6810
f3
510
1830
3210
4440
5400
G840
14
540
1860
3240
4470
5430
6870
15
570
1890
3270
4500
5460
6900
16
600
1920
3300
4530
5490
6930
17
630
1950
3330
4560
5520
6960
t8
660
1980
3360
4590
5550
6900
`9
690
2010
3390
4620
5580
7020
20
720
2040
3420
a650
5610
7050
21
750
2070
1 3450
4665
5640
7080
22
780
2100
3480
4700
5670
7110
23
810
2130
3510
a720
5700
7140
24
840
2160
3540
1 4740
5730
7170
25
870
2190
3570
47G5
5760
7200
26
900
2220
3600
4780
5790
7230
27
930
2250
3630
4820
5820
7260
28
960
2260
3660
4840
5850
7290
29
990
2310
3690 1
4860
5880
7320
36
1020
2340
3720
4880
5910
7350
31
1050
2370
3750
4900
5940
7380
32
1080
2400
3780
4920
5970
7410
33
1110
2430
3810
4940
6000
7440
34
1140
2460
3840
4960
6030
7470
35
1170
2490
3870
4980
6050
7500
36
1200
2520
3900
5000
6100
7530
37
1230
2550
3930
5020
6150
7560
38
1260
2580
3960
5040
G200
7590
39
1290
2610
3990
6250
7620
40
1320
2640
4020
6300
7650
41
1350
2670
4050
6350
7680
42
1380
2700
6390
7696
43
1410
2730
6420
TD
44
1440
2760
6450
45
2790
46
2820
47
48
49
50
51
Prepara8on Date
613012023
Prepared BY
Geolog
ContacP
7 bol r n
SET #2 (AOGCQ TOTAL BOXES 5
TOTAL SAMPLE BAGS 255
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?DW-02
Yes No
9. Property Designation (Lease Number): 10. Field:
Undefined Waste Disposal Pool
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD):
7696'
Casing Collapse
Structural
Conductor
Surface 4750
Production Liner 5410
Production Tieback 5410
Tubing 7500
Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft):
Permanent Packer 7,100 MD
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:Jared Brake
Contact Email:jared.brake@contractor.santos.com
Contact Phone: 907-375-4673
Authorized Title:
Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number:
Plug Integrity BOP Test Mechanical Integrity Test Location Clearance
Other Conditions of Approval:
Post Initial Injection MIT Req'd? Yes No
APPROVED BY
Approved by: COMMISSIONER THE AOGCC Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
Subsequent Form Required:
Suspension Expiration Date:
Will perfs require a spacing exception due to property boundaries?
Current Pools:
MPSP (psi): Plugs (MD):
17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval.
Authorized Name and
Digital Signature with Date:
Tubing Size:
PRESENT WELL CONDITION SUMMARY
AOGCC USE ONLY
8430
Tubing Grade: Tubing MD (ft):
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL 392984/ADL 391445
223-039
900 E Benson Boulevard, Anchorage, AK 99508 50-103-20855-00-00
Oil Search (Alaska), LLC
Length Size
Proposed Pools:
128
13 Chrome 80 ksi
TVD Burst
7,121
7240
MD
7240
68702,247
6,267
128
25,74
2,1357"
20"
9-5/8"
128
7"5,272
2,574
Surface - 2,424
Perforation Depth MD (ft):
2,424 - 7,696
7,240-7,270
2,424
4.5"
5840'
Perforation Depth TVD (ft):
Well Integrity & Intervention Specialist
07/10/23
Surface - 7,1217,121
4-1/2"
5,797
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
7/05/2023
323-373
By Grace Christianson at 11:10 am, Jul 05, 2023
X
X
Statewide spacing of 20 AAC 25.055 SFD
DSR-7/6/23SFD 7/7/2023
PIKKA
VTL 7/7/2023
BOP test to 4000 psig
Undefined Waste Disposal
10-407
GCW 07/11/2023
For Brett W. Huber, Sr.
7/11/23
Samantha
Carlisle
Digitally signed by
Samantha Carlisle
Date: 2023.07.11
11:11:42 -08'00'
RBDMS JSB 071323
Page 1 of 1
05 July 2023
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
DW-02
Dear Sir/Madam
Oil Search (Alaska), LLC hereby applies for a Sundry Application to e-line perforate on an onshore service
well that is on the NDB pad, North Slope. The DW-02 well is an Underground Injection Control (UIC) Class
1 Disposal Well targeting the Torok Formation as the perforation zone.
The DW-02 well has been drilled to TD of 7,696’ MD. The well is currently being completed and the sundry
information may be subject to change. Upon the 4-1/2” tubular completion and pressure test, the drilling rig
will de-mobilize, and the perforation will be accomplished with E-line post rig move.
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 (907) 375-4673 or
jared.brake@contactor.santos.com.
Respectfully,
Jared Brake
Well Integrity & Intervention Specialist
Oil Search (Alaska), LLC
Enclosures:
Form 10-403 Sundry
Application for Sundry
Respectfully,
Jared Brake
Page 1 of 4
DW-02 Sundry Application Requirements
Per 20 AAC 25.280
1. Current Condition of the Well
1. Pressure tested 7” casing to 4,000 psi for 30mins.
2. Circulated completion 9.4 ppg NaCl Inhibited brine.
3. Permanent packer has been set @ ~7,100’ MD.
4. 4,000 psi for 30 min MIT-T.
5. 4,000 psi for 30 min MIT-IA.
6. Tubing IA has been freeze protected to the circulation valve.
7. Production tree has been tested 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 7,240’ – 7,270’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 3% NaCl Brine at up to 2 bpm to verify
injectivity.
8. Prepare for step rate test.
Page 2 of 4
Page 3 of 4
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 4 of 4
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.
Max downhole pressure: 2,612 psi based on 8.6 pore pressure gradient at 5,840’
TVD. (5840’ TVD x 8.6 ppg x 0.052)
Max potential surface pressure is 2,028 psi based on pressure gradient to
surface of 0.1 psi per foot. (2,612 psi - (0.1 psi/ft x 5,840’))
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 10.7 ppg CaCl Brine
x Inner 4-1/2” Tubing will consist of 9.4 ppg NaCl inhibited brine.
x IA of 4-1/2” Tubing will consist of 9.4 ppg NaCl inhibited brine to the GLM
circulation valve. Above GLM circulation valve will have 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 2,862 psi bottom hole pressure
CAUTION: This email originated from outside the State of Alaska mail system.
Do not click links or open attachments unless you recognize the sender and know
the content is safe.
From:McLellan, Bryan J (OGC)
To:Staudinger, Garret (Garret)
Subject:RE: PTD 223-039 DW-02 Surface Casing Cement
Date:Tuesday, June 27, 2023 12:18:00 PM
Garret,
As discussed verbally, Oilsearch’s plan for surface casing cement top job described below is
approved.
Regards
Bryan McLellan
Senior Petroleum Engineer
Alaska Oil & Gas Conservation Commission
Bryan.mclellan@alaska.gov
+1 (907) 250-9193
From: Staudinger, Garret (Garret) <Garret.Staudinger@santos.com>
Sent: Friday, June 23, 2023 10:33 PM
To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Subject: PTD 223-039 DW-02 Surface Casing Cement
Bryan,
As discussed, we pumped our surface casing cement job this afternoon and did not get any pure
cement back to surface. When we split the stack to set our surface casing slips, we found good
cement 10’ below ground level.
The rig is currently in the process of sucking out the water based freezable fluid on top of the
cement with a super sucker. Plan forward after that will be to set surface casing slips. Within the
next few days we will cement the air gap between top of cement to surface through the 4”
conductor valve with more Halliburton ArcticCem cement.
Please let me know if you have any questions.
Thanks,
Garret
Garret Staudinger
Senior Drilling Engineer
t: +1 (907) 375-4666 | m: +1 (907) 440-6892 | e: garret.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
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:McLellan, Bryan J (OGC)
To:Staudinger, Garret (Garret)
Cc:Tirpack, Robert (Robert); Lambe, Steven (Steven)
Subject:Re: PTD 223-039 Surface Casing Pressure Test Variance Request
Date:Monday, June 26, 2023 2:23:08 PM
Garret,
Oilsearch has approval to test the surfatcasing to 2000 psi as requested based on the reasons
given below in your email.
Regards
Bryan McLellan
Sent from my iPhone
On Jun 26, 2023, at 1:47 PM, Staudinger, Garret (Garret)
<Garret.Staudinger@santos.com> wrote:
Bryan,
As discussed, we have had some difficulties getting a good pressure test to 3500 psi on
our 9-5/8” 47# surface casing. We are pressuring up to ~3900 psi and only loosing
~160 psi over 30 minutes (4% pressure loss), but the pressure loss trend is not
stabilizing. We are consistently loosing 10-20 psi every 5 minutes. The rig pumped
approximately 4 bbls to pressure up, and approximately 4 bbls were returned after the
last attempt.
I would like to request a variance to 20 AAC 25.030 (e) that states the casing must be
tested to hold a minimum surface pressure equal to 50 percent of the casing internal
yield pressure. We would like to test the 9-5/8” surface casing to 2000 psi to see if we
can get a passing test. The reason for the 2000 psi pressure test is that this exceeds
our calculated MASP in the Torok formation (~1700 psi MASP), which is the permeable
formation that creates the highest MASP for this particular well. This will cover us for
all anticipated load cases this surface casing could see during future operations for this
well. As an FYI, we are also planning to run a 7” tieback on our production liner and
this surface casing will be covered up.
Please let me know if you are good with this variance request and plan forward, and if
you have any additional questions.
Regards,
Garret
Garret Staudinger
Senior Drilling Engineer
<image002.jpg>
t: +1 (907) 375-4666 | m: +1 (907) 440-6892 | e: garret.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 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
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
BOPE Test Report for:
Reviewed By:
P.I. Suprv
Comm ________PIKKA DW-02
JBR 08/01/2023
MISC. INSPECTIONS:
FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK:
ACCUMULATOR SYSTEM:MUD SYSTEM:
P/F P/F
P/FP/FP/F
Visual Alarm
QuantityQuantity
Time/Pressure
SizeQuantity
Number of Failures:1
Tested all gas alarms, PVT's and Ram Locks, Pit Sensor faulted and was reset and passed, Trip Tank #1 is removed form
service until PVT can be fixed. They will just use trip tnak #2. Tested with 4 1/2" and 7" terst joints. 24 Each Precharge Bottles =
1@1000psi, 8@1120psi, 9@1150psi and 6@1175psi.
Test Results
TEST DATA
Rig Rep:S. ClarkOperator:Oil Search (Alaska), LLC Operator Rep:R. Lawson
Rig Owner/Rig No.:Parker 272 PTD#:2230390 DATE:6/25/2023
Type Operation:DRILL Annular:
250/5000Type Test:INIT
Valves:
250/5000
Rams:
250/5000
Test Pressures:Inspection No:bopBDB230627154454
Inspector Brian Bixby
Inspector
Insp Source
Related Insp No:
INSIDE REEL VALVES:
Quantity P/F
(Valid for Coil Rigs Only)
Remarks:
Test Time 6
MASP:
2566
Sundry No:
Control System Response Time (sec)
Time P/F
Housekeeping:P
PTD On Location P
Standing Order Posted P
Well Sign P
Hazard Sec.P
Test Fluid W
Misc NA
Upper Kelly 1 P
Lower Kelly 1 P
Ball Type 1 P
Inside BOP 1 P
FSV Misc 0 NA
15 PNo. Valves
1 PManual Chokes
1 PHydraulic Chokes
0 NACH Misc
Stripper 0 NA
Annular Preventer 1 13 5/8 P
#1 Rams 1 4 1/2x7 P
#2 Rams 1 Blind/Shear P
#3 Rams 1 4 1/2x7 P
#4 Rams 0 NA
#5 Rams 0 NA
#6 Rams 0 NA
Choke Ln. Valves 1 3 1/8 P
HCR Valves 2 3 1/8 P
Kill Line Valves 2 2 1/16,3 1/8 P
Check Valve 0 NA
BOP Misc 0 NA
System Pressure P3100
Pressure After Closure P2200
200 PSI Attained P16
Full Pressure Attained P66
Blind Switch Covers:PYES
Bottle precharge P
Nitgn Btls# &psi (avg)P14@2200
ACC Misc NA0
P PTrip Tank
P FPPit Level Indicators
P PFlow Indicator
P PMeth Gas Detector
P PH2S Gas Detector
0 NAMS Misc
Inside Reel Valves 0 NA
Annular Preventer P27
#1 Rams P6
#2 Rams P6
#3 Rams P6
#4 Rams NA0
#5 Rams NA0
#6 Rams NA0
HCR Choke P1
HCR Kill P1
9
9
9
9
9999
9
9
FP
Pit Sensor faulted and was reset and passed,Trip Tank #1 is removed form
service until PVT can be fixed.
P.I. Supv
Comm:
Rig Coil Tubing Unit? No
Rig Contractor Rig Representative
Operator Contractor Representative
Well Permit to Drill # 223-039 Sundry Approval #
Operation Inspection Location
Working Pressure, W/H Flange P Pit Fluid Measurement FP Working Pressure P
P Flow Rate Sensor P Operating Pressure P
P Mud Gas Separator P Fluid Level/Condition P
P Degasser P Pressure Gauges P
P Separator Bypass P Sufficient Valves P
P Gas Detectors P Regulator Bypass P
P Alarms Separate/Distinct P Actuators (4-way valves) P
P Choke/Kill Line Connections P Blind Ram Handle Cover P
P Reserve Pits NA Control Panel, Driller P
P Trip Tank P Control Panel, Remote P
P Firewall P
P 2 or More Pumps P
P Kelly or TD Valves P Independent Power Supply P
P Floor Safety Valves P N2 Backup P
P Driller's Console P Condition of Equipment P
P Flow Monitor P
Flow Rate Indicator P
Pit Level Indicators FP Valves P
PPE P Gauges P Remote Hydraulic Choke P
Well Control Trained P Gas Detection Monitor P FOV Upstream of Chokes P
Housekeeping P Hydraulic Control Panel P Targeted Turns P
Well Control Plan P Kill Sheet Current P Bypass Line P
FAILURES:1 CORRECT BY:
CHOKE MANIFOLD
Pikka DW-02
MUD SYSTEM
DW-02
Drilling
CLOSING UNIT
ALASKA OIL AND GAS CONSERVATION COMMISSION
RIG INSPECTION REPORT
HCR Valve(s)
Manual Valves
Annular Preventer
Working Pressure, BOP Stack
Stack Anchored
Choke Line
Kill Line
Targeted Turns
Pipe Rams
Blind Rams
R. Larson / R. O'neal
Niguel / S. Clark
Locking Devices, Rams
BOP STACK
COMMENTS
Brian Bixby
6/25/2023
One of the PVT senors on the active system was calibrated or reset and passed. Trip tank 2 sensor tube needs changed out prior to
use (waiting on rescue team to get into pit). Still have one working trip tank.
INSPECT DATE
AOGCC INSPECTOR
Prior to use
Parker 272
Parker
Oil Search (Alaska) LLC
MISCELLANEOUS
Flange/Hub Connections
Drilling Spool Outlets
Flow Nipple
Control Lines
RIG FLOOR
2023-0625_Rig_Parker272_Pikka_DW-02_bb rev. 5-8-18
9
9
9
9
9
9
9
9
9
-%5
FP
FP
PVT senors Trip tank 2 sensor tube
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
DIVERTER Test Report for:
Reviewed By:
P.I. Suprv
Comm ________PIKKA DW-02
JBR 07/27/2023
MISC. INSPECTIONS:
GAS DETECTORS:
DIVERTER SYSTEM:MUD SYSTEM:
P/F
P/F
P/F
Alarm
Visual Alarm
Visual Time/Pressure
Size
Number of Failures:1
Remarks:5" joint. Annular Psi increased & cycled for pass. Annular closed time: 30; Knife Valve open time: 28.
TEST DATA
Rig Rep:Sonny ClarkOperator:Oil Search (Alaska), LLC Operator Rep:Rowland Lawson
Contractor/Rig No.:Parker 272 PTD#:2230390 DATE:6/16/2023
Well Class:DEV Inspection No:divSAM230617130359
Inspector Austin McLeod
Inspector
Insp Source
Related Insp No:
Test Time:1.5
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:NA NA
Designed to Avoid Freeze-up?P
Remote Operated Diverter?P
No Threaded Connections?P
Vent line Below Diverter?P
Diverter Size:21.25 P
Hole Size:12.25 P
Vent Line(s) Size:16 P
Vent Line(s) Length:193 P
Closest Ignition Source:120.5 P
Outlet from Rig Substructure:171 P
Vent Line(s) Anchored:P
Turns Targeted / Long Radius:NA
Divert Valve(s) Full Opening:P
Valve(s) Auto & Simultaneous:
Annular Closed Time:48 FP
Knife Valve Open Time:35 P
Diverter Misc:0 NA
Systems Pressure:P3100
Pressure After Closure:P2400
200 psi Recharge Time:P11
Full Recharge Time:P45
Nitrogen Bottles (Number of):P14
Avg. Pressure:P2400
Accumulator Misc:NA0
P PTrip Tank:
P PMud Pits:
P PFlow Monitor:
NA NAMud System Misc:
9
9 9
9
9
9
9Annular closed time: 30; Knife Valve open time: 28.
From:Davies, Stephen F (OGC)
To:Lewallen, Anna (Anna); Guhl, Meredith D (OGC)
Cc:Staudinger, Garret (Garret); Harvey, Brett (Brett); Noll, Christian (Christian); Thompson, Jacob (Jacob)
Subject:RE: DW-02 & NDBi-043 Variance request for sample interval of dried and washed cuttings
Date:Thursday, May 25, 2023 5:00:21 PM
Anna,
Oil Search’s proposed variance request for DW-02 is acceptable. Oil Search’s proposed variance request for
the planned NDBi-043 and PB1 development well is reasonable. Please request and justify this
variance in the Permit to Drill application for NDBi-043 and PB1.
Regards and Be Well,
Steve Davies
Senior Petroleum Geologist
Alaska Oil and Gas Conservation Commission (AOGCC)
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation
Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.
The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail,
please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at
907-793-1224 or steve.davies@alaska.gov.
From: Lewallen, Anna (Anna) <Anna.Lewallen@santos.com>
Sent: Thursday, May 25, 2023 3:56 PM
To: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Davies, Stephen F (OGC)
<steve.davies@alaska.gov>
Cc: Staudinger, Garret (Garret) <Garret.Staudinger@santos.com>; Harvey, Brett (Brett)
<Brett.Harvey@contractor.santos.com>; Noll, Christian (Christian) <Christian.Noll@santos.com>; Thompson,
Jacob (Jacob) <Jacob.Thompson@santos.com>
Subject: DW-02 & NDBi-043 Variance request for sample interval of dried and washed cuttings
Meredith,
Yes, we plan to collect a full suite of dried and washed cutting samples representative of the geology in the
first Nanushuk 3 reservoir development well at NDB pad. The well name is NDBi-043. We ask for a variance
on that well due to its length of the lateral since it is planned to exceed 5,000 ft MD. Please consider
approving the below two variance requests on the first two wells.
DW-02 G & I disposal well:
The zone of interest for G & I disposal in the DW-02 well is in the Torok formation, which is prognosed
to be ~700 ft MD (650 ft TVD). Due to the purpose of this well to be G & I disposal in the Torok over a
thick gross section, an increase in sample density to 10 ft MD intervals does not provide any
additional marketable geologic value. Therefore, we are requesting a variance for dried and washed
cuttings sample intervals to be collected as 50’ MD sample intervals until drilling rates slow, at which
point 30’ MD sample intervals are required from surface to TD of DW-02. All sample depths collected
will be provided in a sample set submitted to the AOGCC per regulation 20 AAC 25.071(b)(2).
NDBi-043 & PB1 development well:
The zone of interest in NDBi-043 is the Nanushuk 3 reservoir. This well is planned to have a horizontal
section in the reservoir of ~6,400 ft MD. As required from surface, we plan to collect 50’ ft MD
sample intervals until drilling rates slow, at which point 30’ ft MD sample intervals are required from
surface to the top reservoir of the Nanushuk 3. In the Nanushuk 3 reservoir top section to the landing
point of the horizontal where the well reaches 90-degree inclination, we plan to take 10 ft MD
samples representative of the zone of interest. Due to the long length of the lateral and the basis
that 30 ft samples will adequately be representative of the geologic section beyond that, we request a
variance along the lateral after the landing to resume back to 30 ft MD samples to TD. This proposal
meets the requirement to adequate represent the geologic zone of interest as well as staying withing
practical ROP and safety recommended practices. All sample depths collected will be provided in a
sample set submitted to the AOGCC per regulation 20 AAC 25.071(b)(2).
Please let us know your decision on both variance requests for the first two wells on the pad at NDB. I am
available to discuss if more detail or clarity is needed.
All the best,
Anna
From: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>
Sent: Thursday, May 25, 2023 7:45 AM
To: Lewallen, Anna (Anna) <Anna.Lewallen@santos.com>; Davies, Stephen F (OGC)
<steve.davies@alaska.gov>
Cc: Staudinger, Garret (Garret) <Garret.Staudinger@santos.com>; Harvey, Brett (Brett)
<Brett.Harvey@contractor.santos.com>
Subject: ![EXT]: RE: DW-02 Variance request for sample interval of dried and washed cuttings
Good Morning Anna,
Does Oil Search (Alaska) plan to acquire a full suite of cuttings samples in the first development well drilled
from this pad?
Thanks,
Meredith
Meredith Guhl (she/her)
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.
Petroleum Geology Assistant
Alaska Oil and Gas Conservation Commission
333 W. 7th Ave, Anchorage, AK 99501
meredith.guhl@alaska.gov
Direct: (907) 793-1235
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas
Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential
and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you
are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the
mistake in sending it to you, contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov.
From: Lewallen, Anna (Anna) <Anna.Lewallen@santos.com>
Sent: Monday, May 15, 2023 5:06 PM
To: Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC)
<meredith.guhl@alaska.gov>
Cc: Staudinger, Garret (Garret) <Garret.Staudinger@santos.com>; Harvey, Brett (Brett)
<Brett.Harvey@contractor.santos.com>
Subject: DW-02 Variance request for sample interval of dried and washed cuttings
Steve and Meredith,
I hope my email finds you well. I am writing to request a variance for the mud logging dried and washed
cuttings sample interval for DW-02. Since the PTD has been submitted and approved, I am following up via
email with the variance request in writing.
Justification of requested variance:
The zone of interest for G & I disposal in the DW-02 well is in the Torok formation, which is
prognosed to be ~700 ft MD (650 ft TVD). Due to the purpose of this well to be G & I disposal in
the Torok over a thick gross section, an increase in sample density to 10 ft MD intervals does not
provide any additional marketable geologic value. Therefore, we are requesting a variance for
dried and washed cuttings sample intervals to be collected as 50’ MD sample intervals until drilling
rates slow, at which point 30’ MD sample intervals are required from surface to TD of DW-02. All
sample depths collected will be provided in a sample set submitted to the AOGCC per regulation
20 AAC 25.071(b)(2).
Please let me know if we should have a discussion again, or if anything more needs to be done to official
document this request.
I look forward to hearing from you soon.
Thank you,
Anna
Anna M. LewallenSenior Geologist, SubsurfaceOil Search (Alaska), LLC a subsidiary of Santos Limited
P.O. Box 240927 Anchorage, Alaska 99524-0927
Tel: 907-375-4635 | Mob: 225-287-5921
anna.lewallen@santos.com
https://www.santos.com/
From: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>
Sent: Wednesday, 12 April 2023 12:09 PM
To: Harvey, Brett (Brett) <Brett.Harvey@contractor.santos.com>
Cc: Davies, Stephen F (OGC) <steve.davies@alaska.gov>
Subject: ![EXT]: RE: Santos Phase 1 NDB pad
Hi Brett,
Yes, I’m the right person to send the samples to (address below). Please ensure ever box is labeled similarly
to the photo attached on at least the end of the box and another side. Sample inventories should be
submitted both with the samples in paper format and via email to me (example attached).
Volumes are cited in regulation 20 AAC 25.071(b)(2): (2) a complete set of washed and dried, legibly identified
samples of all drill cuttings, as caught by the operator in accordance with good geological practices, consisting of a
minimum of one-quarter cup in volume or three ounces in weight of cuttings for each sample interval;
50’ sample intervals are allowable until drilling rates slow, at which point 30’ sample intervals are required,
and 10’ sample intervals through zones of interest. Variances can be requested in the permit to drill
application package to these interval requirements.
It’s also great if I can get a heads up the day before samples are delivered. Not required, but easier on our
office to plan for their arrival and storage.
Thanks,
Meredith
Meredith Guhl (she/her)
Petroleum Geology Assistant
Alaska Oil and Gas Conservation Commission
333 W. 7th Ave, Anchorage, AK 99501
meredith.guhl@alaska.gov
Direct: (907) 793-1235
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas
Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential
and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you
are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the
mistake in sending it to you, contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov.
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 orcontain 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
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
Garret Staudinger
Senior Drilling Engineer
Oil Search (Alaska), LLC
900 E Benson Boulevard,
Anchorage, AK 99508
Re: Undefined Waste Disposal Pool, DW-02
Oil Search (Alaska), LLC
Permit to Drill Number: 223-039
Surface Location: 2537.36 FSL, 1853.55 FEL, S4, T11N, R6E, UM
Bottomhole Location: 3645.41 FSL, 550.55 FEL, S5, T11N, R6E, UM
Dear Mr. Staudinger:
Enclosed is the approved application for the permit to drill the above referenced well.
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.
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run
must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this
well, or within 90 days of acquisition of the data, whichever occurs first.
This permit to drill does not exempt you from obtaining additional permits or an approval required by law
from other governmental agencies and does not authorize conducting drilling operations until all other
required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw
the permit in the event it was erroneously issued.
Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska
Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an
applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC
order, or the terms and conditions of this permit may result in the revocation or suspension of the permit.
Sincerely,
Brett W. Huber, Sr.
Chair, Commissioner
DATED this ___ day of May, 2023.
11
Brett W.
Huber, Sr.
Digitally signed by Brett W.
Huber, Sr.
Date: 2023.05.11 10:05:33
-08'00'
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: 7695'TVD:6270'
4a. Location of Well (Governmental Section): 7. Property Designation:
Surface:
Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date:
3562.24 FSL, 267.86 FEL, S5, T11N, R6E, UM 05/15/23
Total Depth: 9. Acres in Property: 14. Distance to Nearest Property:
3645.41 FSL, 550.55 FEL, S5, T11N, R6E, UM 13,569'
4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 68.7 15. Distance to Nearest Well Open
Surface: x- 1423384 y- 5972909.3 Zone- 22 to Same Pool:N/A
16. Deviated wells: Kickoff depth: 300 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035)
Maximum Hole Angle: 42 degrees Downhole: Surface:
Hole Casing Weight Grade Coupling Length MD TVD MD TVD
42" 20" 78# X-65 Welded 80' Surface Surface 128' 58'
12-1/4" 9-5/8" 47# L-80 TXP BTC 2553' Surface Surface 2600' 2193'
8-1/2" 7" 26# L-80 HYD 563 5245' 2450' 2190' 7695' 6200'
Tie Back 7" 26# L-80 HYD 563 2403' Surface Surface 2450' 2080'
Tubing 4-1/2" 12.6# 13CR-80 JFEBEAR 7205' Surface Surface 7252' 5785'
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: Garret Staudinger
Garret Staudinger Contact Email:garret.staudinger@santos.com
Senior Drilling Engineer Contact Phone:907-440-6892
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
Top - Setting Depth - BottomSpecifications
3185 psi
Cement Volume MDSize
Plugs (measured):
(including stage data)
Grouted to surface
11.0ppg Lead: 315bbls, 1768cuft,
614sks ArcticCem
15.8ppg Tail: 48bbls, 269cuft, 215sks
VersaCem Type I/II
Total Depth MD (ft): Total Depth TVD (ft):
N/A
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
20 AAC 25.005
12.0ppg Lead: 116bbls, 651cuft,
262sks ExtendaCem
15.3ppg Tail: 51bbls, 286cuft, 230sks
SwiftCem Type I/II
2566 psi
19-003
900 E Benson Boulevard, Anchorage, AK 99508
Oil Search (Alaska), LLC
2537.36 FSL, 1853.55 FEL, S4, T11N, R6E, UM ADL 392984/ADL 391445
640/640 = 1280
18. Casing Program:
DW-02
Nanushuk Oil Pool
Cement Quantity, c.f. or sacks
Commission Use Only
See cover letter for other
requirements.
s N
ype of W
L
l R
L
1b
S
Class:
os N s No
s N o
D tsh
iis
Ye
hh
o
well is p
G
S
S
S
20
S S
S
s No s No
S
G
y 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)
4/19/2023
By Kayla Junke at 3:19 pm, Apr 19, 2023
Undefined Waste Disposal Pool
SFD
4 SFD
Initial BOP test to Rated Working Pressure. Subsequent BOP tests to 4000 psi.
50-103-20855-00-00
Other Order 197
Class I EPA
SFD 5/2/2023
CDW 04/20/2023
Submit FIT/LOT data to AOGCC and obtain approval before drilling 8.5" hole section.
Submit 7" Cement eval log to AOGCC and obtain approval before running tbg.
DSR-4/27/23BJM 5/10/23
223-039
GCW 05/11/23JLC 5/11/2023
5/11/2023Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr.
Date: 2023.05.11 10:07:27 -08'00'
5/11/2023
RBDMS JSB 051523
Page 1 of 1
18 April 2023
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
DW-02
Dear Sir/Madam
Oil Search (Alaska), LLC hereby applies for a Permit to Drill an onshore development well from
the NDB drilling pad on the North Slope of Alaska. DW-02 is planned to be an Underground
Injection Control (UIC) Class 1 Disposal Well targeting the Torok formation. The approximate
spud date is anticipated to be June 17th, 2023. Parker Rig 272 will be used to drill this well.
The 12-1/4” surface hole will TD above the Tuluvak sand and then 9-5/8” casing will be set and
cemented.
The 8-1/2” production hole will be drilled to below the top of the HRZ formation at an inclination
of ~42 degrees, dropping to ~20 degrees at TD. A 7” liner will be set and cemented from TD to
secure the shoe and cover the Tuluvak sand.
A 7” tieback will be run to the top of the 7” liner top, and a 4-1/2” tubing upper completion string
will be run with 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 (907) 440-
6892 or garret.staudinger@santos.com.
Respectfully,
Garret Staudinger
Senior Drilling Engineer
Oil Search (Alaska), LLC
Enclosures:
Form 10-401 Permit to Drill
Application for Permit to Drill
Class 1 Disposal Well
Service SFD
cover the Tuluvak
targeting the Torok formation.
DW-02 PTD Rev2 20230418.docx - 1 - 18-Apr-23
Application for Permit to Drill
DW-02 Well
DW-02 PTD Rev2 20230418.docx - 2 - 18-Apr-23
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
Attachments..................................................................................................................................................12
Attachment 1: Location Map............................................................................................................13
Attachment 2: Directional Plan........................................................................................................15
Attachment 3: BOPE Equipment ......................................................................................................24
Attachment 4: Drilling Hazards.........................................................................................................28
Attachment 5: Leak Off Test Procedure...........................................................................................29
Attachment 6: Cement Summary.....................................................................................................30
Attachment 7: Prognosed Formation Tops......................................................................................31
Attachment 8: Well Schematic.........................................................................................................32
Attachment 9: Formation Evaluation Program................................................................................33
Attachment 10: Wellhead & Tree Diagram......................................................................................34
DW-02 PTD Rev2 20230418.docx - 3 - 18-Apr-23
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 DW-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 2537.36’ FSL, 1853.55’ FEL, Sec 4, T11N, R6E, UM
NAD 27 Coordinate System N 5,972,909.3 E 423,383.6
Rig KB Elevation 47’ above ground level
Ground Level 22.7’ above MSL
Location at Base of Upper Torok Confining Layer
Reference to Government Section Lines 3562.24’ FSL, 267.86’ FEL, Sec 5, T11N, R6E, UM
NAD 27 Coordinate System N 5,973,984 E 419,699.7
Measured Depth, Rig KB (MD) 6,090’
Total Vertical Depth, Rig KB (TVD) 4,870’
Total vertical Depth, Subsea (TVDSS) 5,460’
Bottom Hole Location
Reference to Government Section Lines 3645.41’ FSL, 550.55’ FEL, Sec 5, T11N, R6E, UM
NAD 27 Coordinate System N 5,974,050 E 419,423.5
Measured Depth, Rig KB (MD) 7,695’
Total Vertical Depth, Rig KB (TVD) 6,270’
Total vertical Depth, Subsea (TVDSS) 6,201’
DW-02 PTD Rev2 20230418.docx - 4 - 18-Apr-23
(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 DW-02 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.
DW-02 PTD Rev2 20230418.docx - 5 - 18-Apr-23
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;
8-1/2” Intermediate Hole Pressure Data
Maximum anticipated BHP 3,185 psi in the HRZ at 6,188’ TVD
(9.9ppg EMW top HRZ formation)
Maximum surface pressure 2,566 psi from the HRZ
(0.10 psi/ft gas gradient to surface, 6188’ TVD)
Planned BOP test pressure
Rams test to 4,000 psi / 250 psi
Annular test to 3,500 psi / 250 psi
[Test pressure driven by 7” casing pressure test]
Integrity Test – 8-1/2” hole LOT after drilling 20’-50’ of new hole
9-5/8” Casing Test 3,500 psi surface pressure
[Test pressure driven by 50% of surface casing yield]
(B) data on potential gas zones; and
The Tuluvak formation is expected to be encountered and has the potential for gas.
Please refer to Attachment 7: Prognosed Formation Tops
(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;
Nearby offset Exploration and Appraisal wells in the area suggest that no significant hole problems are
to be expected.
Please refer to Attachment 4: Drilling Hazards
Tuluvak expected to be over-
pressured (10.0 ppg EMW, see
p. 31). SFD 4/29/23
Tuluvak formation is expected to be encountered and has the potential for gas.
DW-02 PTD Rev2 20230418.docx - 6 - 18-Apr-23
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 /
TVDss
Cement Program
42” 20” 78# X-65 Welded 80’ Surface 128’ / 58’ Grouted to Surface
12-1/4” 9-5/8” 47# L-80 TXP BTC 2,553’ Surface
2,600’ /
2,193’
11.0ppg Lead:315bbls, 1768cuft, 614sks
ArcticCem, Yield: 2.88 cuft/sk
15.8ppg Tail: 48bbls, 269cuft, 215sks
VersaCem Type I/II – 1.25 cuft/sk
8-1/2” 7” 26# L-80 HYD 563 5,245’ 2,450’
7,695’ /
6,200’
12.0ppg Lead:116bbls, 651cuft, 262sks
ExtendaCem, Yield: 2.37 cuft/sk
15.3ppg Tail: 51bbls, 286cuft, 230sks
SwiftCem Type I/II – 1.24 cuft/sk
Tie Back 7” 26# L-80 HYD 563 2,403’ Surface
2,450’ /
2,080’n/a
Tubing 4-1/2” 12.6#
13CR-
80 JFEBEAR 7,205’ Surface
7,252’ /
5,785’n/a
Please refer to Attachment 6: Cement Summary for further details. *262 sks X 2.37 cuft/sk = 621 cuft = 111 bbls SFD
15.3ppg tail, per G.
Staudinger.
-bjm
*
DW-02 PTD Rev2 20230418.docx - 7 - 18-Apr-23
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
128’ – 2600’ MD
Production Hole
2600’ – 7695’ MD
Mud Type Water based Spud Mud Mineral Oil Based Mud
Mud Properties:
Mud Weight
Funnel Vis
PV
YP
API Fluid Loss
HPHT Fluid Loss
pH
MBT
10.5ppg
85-200 seconds
30-50
30-80
< 10 ml/30min
n/a
9.5-10
<35
11.0ppg
60-100 seconds
20-40
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.
10.5ppg 11.0ppgMud Weight
DW-02 PTD Rev2 20230418.docx - 8 - 18-Apr-23
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 DW-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;
DW-02 is an EPA regulated disposal well, and bonding will be done through the EPA directly. Oil
Search Alaska has requested a waiver from the AOGCC abandonment bonding obligation for this
reason.
Waiver approved per Other Order 197. -bjm
Oil
Search Alaska has requested a waiver from the AOGCC abandonment bonding obligation for this
reason.
DW-02 PTD Rev2 20230418.docx - 9 - 18-Apr-23
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 DW-02 is listed below. Please refer to Attachments 8-10 for a
Well Schematic, Formation Evaluation Program, and Wellhead & Tree Diagram.
Proposed Drilling Program
DW-02
1. Drill/drive 20” conductor to ~128’ MD/TVD. Cement to surface. Install Cellar.
2. Install wellhead landing ring on 20” conductor.
3. Move in / rig up Parker Rig 272.
4. 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.
5. Function test diverter and knife valve as per AOGCC regulations. Provide AOGCC 24hrs
notice for witnessing diverter test.
6. Pick up 5” drill pipe, fill pits with spud mud and prepare for surface hole drilling. Make up
12-1/4” motor BHA with MWD and LWD tools.
7. Spud well and drill surface hole section as per well plan to ~2600’ MD / 2262’ TVD. Make
directional corrections and wiper trips as required. Circulate and condition hole and then
POOH.
8. Run 9-5/8” surface casing as per casing tally and land on pre-installed landing ring.
Circulate and condition mud prior to commencing cement job.
9. Cement 9-5/8” casing as per cement program. Adequate excess cement will be pumped to
ensure surface casing is cemented to surface.
10. Nipple down diverter and nipple up BOPE and test to 250 / 4000 psi as per AOGCC
regulations. Provide AOGCC 24hrs notice for witnessing BOP test.
11. Make up 8-1/2” RSS BHA with MWD and LWD tools. RIH, clean out to top of float
equipment and displace well to 11.0ppg MOBM. Pressure test casing to 3500 psi for 30
min.
12. Drill out shoe track and 20 - 50’ of new formation. Perform leak off test.
13. Directionally drill 8-1/2” intermediate hole section to TD at top HRZ at ~7695’ MD / 6270’
TVD. Perform wiper trips as required. Circulate and condition hole to run casing. POOH.
14. Rig up wireline and complete open hole wireline as per formation evaluation program.
15. Run 7” production liner as per casing tally. Circulate and condition mud prior to
commencing cement job.
16. Cement 7” liner with single stage cement job as per cement program. Monitor returns
during displacement. Set liner top packer and circulate any excess cement to surface.
single stage cement job a
Initial BOP test to Rated Working Pressure. Subsequent BOP tests to 4000 psi. -bjm
13.5 ppg minimum LOT required to drill planned 8.5" hole. -bjm
displace well to 11.0ppg MOBM.
DW-02 PTD Rev2 20230418.docx - 10 - 18-Apr-23
17. Run 7” tie-back string. Freeze protect 9-5/8” x 7” annulus with diesel and land tie-back.
18. Pressure test 9-5/8” x 7” annulus to 3500psi for 30mins.
19. Pressure test 7” casing to 4000psi for 30mins.
20. Rig up wireline and complete cased hole cement evaluation log.
21. Run and land 4-1/2” completion.
22. Reverse circulate completion brine with corrosion inhibitor. Drop ball and rod and set
production packer. Test tubing to 4500 psi for 30 min. Drop tubing pressure to 3000 psi
and test IA to 4000 psi for 30 min.
23. Shear gas lift valve and circulate diesel freeze protect cap as needed. Set TWC and test to
3500 psi.
24. Nipple down BOPE. Nipple up adapter and dry hole tree and test to 5000 psi.
25. RDMO Parker 272.
Submit Cement eval log to AOGCC and obtain approval before running tbg. -bjm
DW-02 PTD Rev2 20230418.docx - 11 - 18-Apr-23
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.
DW-02 PTD Rev2 20230418.docx - 12 - 18-Apr-23
Attachments
DW-02 PTD Rev2 20230418.docx - 13 - 18-Apr-23
Attachment 1: Location Map
DW-02 PTD Rev2 20230418.docx - 15 - 18-Apr-23
Attachment 2: Directional Plan
Torok_Disposal_2
DW-02 TD Rev12
Tie On
End of Tangent
3.00°/100ft
End of Build
3.00°/100ft
End of Tangent
End of 3D Arc
End of Tangent
End of TangentTrue Vertical Depth (ft)
Vertical Section (ft)
Azimuth 285.66° with reference 0.00 N, 0.00 E
0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000
-500
0
500
1000
1500
2000
2500
3000
3500
4000
4500
5000
5500
6000
6500
Scale 1 inch = 1000Scale 1 inch = 1000
Offset wellpath MDs are referenced to each path's default MD datum
Mean Sea Level to Ground level (At Slot: DW-02): 0 feet
Rig on W-02 (RT) to Mean Sea Level: 69.7 feet
Reference wellpath measured depths are referenced to Rig on W-02 (RT)
True vertical depths are referenced to Rig on W-02 (RT)
Plot reference wellpath is DW-02 Rev A.0
Created by: meyedavr on 2023-03-31; Database: WellArchitectDB
Depths are in feet
Coordinates are in feet referenced to Slot
Scale: True distance
North Reference: True north
Grid System: NAD83 / TM Alaska SP, Zone 4 (5004), US feet
Facility:
Location:
Field:
Pikka
Pikka
Unknown
Santos
Wellbore:
Well:
Slot:
DW-02
DW-02
DW-02
DW-02 TD Rev12
Torok_Disposal_2
DW-02 Northing (ft)
Easting (ft)
-4200 -3600 -3000 -2400 -1800 -1200 -600 0
-600
0
600
1200
Scale 1 inch = 1200
End of Tangent
End of Tangent
End of 3D Arc
End of Tangent
End of Build
End of Tangent
Tie On
Design Comment
7695.45
7321.92
7045.02
6322.75
1735.98
347.00
20.001
20.001
20.001
41.669
41.669
0.000
47.00 0.000
MD (ft) Inc (°)
285.658
285.658
285.658
285.665
285.665
285.665
285.665
Az (°)
Well Profile Data
6270.70
5919.70
5659.50
5043.02
1616.74
347.00
47.00
TVD (ft)
1113.24
1078.75
1053.19
953.84
130.47
0.00
0.00
Local N (ft)
-3970.00
-3846.97
-3755.78
-3401.43
-465.26
0.00
0.00
Local E (ft) DLS (°/100ft)
0.00
0.00
3.00
0.00
3.00
0.00
0.00
4123.13
3995.36
3900.65
3532.64
483.21
0.00
0.00
VS (ft)
RigonW-02(RT)toMeanSeaLevel
Mean Sea Level to Ground level (At Slot: DW-02)
Rig on W-02 (RT) to Ground level (At Slot: DW-02)
DW-02
Slot
0.00
Local N (ft)
Pikka
Facility Name
0.00
Local E (ft)
1563416.330
Grid East (US ft)
1563416.330
Grid East (US ft)
Location Information
Grid North (US ft)
Grid North (US ft)
5972657.910
5972657.910
69.7ft
0ft
69.7ft
70°20'8.9895"N
70°20'8.9895"N
Latitude
Latitude
150°37'29.0730"W
Longitude
150°37'29.0730"W
Longitude
REFERENCE WELLPATH IDENTIFICATION
Operator Santos Well DW-02 NAD 27
Field Pikka NAD27 API/Legal
Facility Pikka NAD27 Wellbore DW-02 NAD 27
Slot DW-02 NAD 27
REPORT SETUP INFORMATION
Projection System NAD27 / TM Alaska SP, Zone 4 (5004), US
feet
Software System WellArchitect® 6.0
North Reference True User Meyedavr
Scale 0.999907 Report Generated 4/6/2023 at 5:38:07 PM
Convergence at slot 0.59° West Database WellArchitectDB
WELLPATH LOCATION
Local coordinates Grid coordinates Geographic coordinates
North[ft] East[ft] Easting[US ft] Northing[US ft] Latitude Longitude
Slot Location 0.00 0.00 423383.56 5972909.70 70°20'10.1378"N 150°37'17.7961"W
Facility Reference Pt 423383.56 5972909.70 70°20'10.1378"N 150°37'17.7961"W
Field Reference Pt 423383.56 5972909.70 70°20'10.1378"N 150°37'17.7961"W
WELLPATH DATUM
Calculation method Minimum curvature
Rig on DW-02 NAD 27 (RT) to
Facility Vertical Datum
69.70ft
Horizontal Reference Pt Slot Rig on DW-02 NAD 27 (RT) to
Mean Sea Level
69.70ft
Vertical Reference Pt Rig on DW-02 NAD 27 (RT)
Rig on DW-02 NAD 27 (RT) to
Ground Level at Slot (DW-02 NAD
27)
69.70ft
MD Reference Pt Rig on DW-02 NAD 27 (RT)Section Origin N 0.00, E 0.00 ft
Field Vertical Reference Mean Sea Level Section Azimuth 285.66°
Actual Wellpath Report
DW-02 Rev A.0 NAD27
Page 1 of 3
Page 1 of 5Wellpath Report
4/6/2023file:///C:/WellArchitect/DW-02_Rev_A.0_NAD27.xml
REFERENCE WELLPATH IDENTIFICATION
Operator Santos Well DW-02 NAD 27
Field Pikka NAD27 API/Legal
Facility Pikka NAD27 Wellbore DW-02 NAD 27
Slot DW-02 NAD 27
Actual Wellpath Report
DW-02 Rev A.0 NAD27
Page 2 of 3
WELLPATH DATA (83 stations)† = interpolated, ‡ = extrapolated station
MD
[ft]
Inclination
[°]
Azimuth
[°]
TVD
[ft]
TVDSS
[ft]
Vert Sect
[ft]
North
[ft]
East
[ft]
Grid East
[US ft]
Grid North
[US ft]
DLS
[°/100ft]
0.00† 0.000 285.665 0.00 -69.70 0.00 0.00 0.00 423383.55 5972909.70 0.00
47.00 0.000 285.665 47.00 -22.70 0.00 0.00 0.00 423383.55 5972909.70 0.00
147.00 0.000 285.665 147.00 77.30 0.00 0.00 0.00 423383.55 5972909.70 0.00
247.00 0.000 285.665 247.00 177.30 0.00 0.00 0.00 423383.55 5972909.70 0.00
347.00 0.000 285.665 347.00 277.30 0.00 0.00 0.00 423383.55 5972909.70 0.00
447.00 3.000 285.665 446.95 377.25 2.62 0.71 -2.52 423381.04 5972910.43 3.00
547.00 6.000 285.665 546.63 476.93 10.46 2.82 -10.07 423373.51 5972912.62 3.00
647.00 9.000 285.665 645.77 576.07 23.51 6.35 -22.64 423360.98 5972916.27 3.00
747.00 12.000 285.665 744.08 674.38 41.74 11.27 -40.18 423343.49 5972921.37 3.00
847.00 15.000 285.665 841.31 771.61 65.08 17.57 -62.66 423321.08 5972927.90 3.00
947.00 18.000 285.665 937.18 867.48 93.48 25.24 -90.00 423293.82 5972935.85 3.00
1047.00 21.000 285.665 1031.43 961.73 126.85 34.25 -122.14 423261.78 5972945.19 3.00
1147.00 24.000 285.665 1123.81 1054.11 165.12 44.58 -158.98 423225.05 5972955.90 3.00
1247.00 27.000 285.665 1214.06 1144.36 208.16 56.21 -200.43 423183.73 5972967.94 3.00
1347.00 30.000 285.665 1301.93 1232.23 255.87 69.09 -246.37 423137.93 5972981.29 3.00
1447.00 33.000 285.665 1387.18 1317.48 308.12 83.20 -296.67 423087.78 5972995.91 3.00
1547.00 36.000 285.665 1469.59 1399.89 364.75 98.49 -351.20 423033.41 5973011.76 3.00
1647.00 39.000 285.665 1548.91 1479.21 425.62 114.92 -409.81 422974.98 5973028.79 3.00
1735.98 41.669 285.665 1616.73 1547.03 483.21 130.47 -465.26 422919.70 5973044.90 3.00
1747.00 41.669 285.665 1624.97 1555.27 490.53 132.45 -472.31 422912.66 5973046.95 0.00
1847.00 41.669 285.665 1699.67 1629.97 557.02 150.40 -536.33 422848.84 5973065.55 0.00
1947.00 41.669 285.665 1774.37 1704.67 623.50 168.35 -600.34 422785.02 5973084.16 0.00
2047.00 41.669 285.665 1849.07 1779.37 689.98 186.30 -664.35 422721.20 5973102.76 0.00
2147.00 41.669 285.665 1923.77 1854.07 756.46 204.25 -728.37 422657.38 5973121.36 0.00
2247.00 41.669 285.665 1998.47 1928.77 822.95 222.21 -792.38 422593.56 5973139.96 0.00
2347.00 41.669 285.665 2073.17 2003.47 889.43 240.16 -856.39 422529.74 5973158.57 0.00
2447.00 41.669 285.665 2147.87 2078.17 955.91 258.11 -920.41 422465.92 5973177.17 0.00
2547.00 41.669 285.665 2222.57 2152.87 1022.39 276.06 -984.42 422402.10 5973195.77 0.00
2647.00 41.669 285.665 2297.26 2227.56 1088.88 294.01 -1048.43 422338.28 5973214.37 0.00
2747.00 41.669 285.665 2371.96 2302.26 1155.36 311.96 -1112.45 422274.46 5973232.97 0.00
2847.00 41.669 285.665 2446.66 2376.96 1221.84 329.91 -1176.46 422210.64 5973251.58 0.00
2947.00 41.669 285.665 2521.36 2451.66 1288.32 347.86 -1240.47 422146.82 5973270.18 0.00
3047.00 41.669 285.665 2596.06 2526.36 1354.81 365.81 -1304.49 422083.00 5973288.78 0.00
3147.00 41.669 285.665 2670.76 2601.06 1421.29 383.77 -1368.50 422019.18 5973307.38 0.00
3247.00 41.669 285.665 2745.46 2675.76 1487.77 401.72 -1432.51 421955.36 5973325.99 0.00
3347.00 41.669 285.665 2820.16 2750.46 1554.26 419.67 -1496.53 421891.54 5973344.59 0.00
3447.00 41.669 285.665 2894.86 2825.16 1620.74 437.62 -1560.54 421827.72 5973363.19 0.00
3547.00 41.669 285.665 2969.56 2899.86 1687.22 455.57 -1624.55 421763.90 5973381.79 0.00
3647.00 41.669 285.665 3044.26 2974.56 1753.70 473.52 -1688.57 421700.08 5973400.40 0.00
3747.00 41.669 285.665 3118.96 3049.26 1820.19 491.47 -1752.58 421636.26 5973419.00 0.00
3847.00 41.669 285.665 3193.66 3123.96 1886.67 509.42 -1816.59 421572.44 5973437.60 0.00
3947.00 41.669 285.665 3268.36 3198.66 1953.15 527.37 -1880.60 421508.61 5973456.20 0.00
4047.00 41.669 285.665 3343.06 3273.36 2019.63 545.33 -1944.62 421444.79 5973474.81 0.00
Page 2 of 5Wellpath Report
4/6/2023file:///C:/WellArchitect/DW-02_Rev_A.0_NAD27.xml
WELLPATH DATA (83 stations)† = interpolated, ‡ = extrapolated station
MD
[ft]
Inclination
[°]
Azimuth
[°]
TVD
[ft]
TVDSS
[ft]
Vert Sect
[ft]
North
[ft]
East
[ft]
Grid East
[US ft]
Grid North
[US ft]
DLS
[°/100ft]
4147.00 41.669 285.665 3417.76 3348.06 2086.12 563.28 -2008.63 421380.97 5973493.41 0.00
4247.00 41.669 285.665 3492.46 3422.76 2152.60 581.23 -2072.64 421317.15 5973512.01 0.00
Page 3 of 5Wellpath Report
4/6/2023file:///C:/WellArchitect/DW-02_Rev_A.0_NAD27.xml
REFERENCE WELLPATH IDENTIFICATION
Operator Santos Well DW-02 NAD 27
Field Pikka NAD27 API/Legal
Facility Pikka NAD27 Wellbore DW-02 NAD 27
Slot DW-02 NAD 27
Actual Wellpath Report
DW-02 Rev A.0 NAD27
Page 3 of 3
WELLPATH DATA (83 stations)
MD
[ft]
Inclination
[°]
Azimuth
[°]
TVD
[ft]
TVDSS
[ft]
Vert Sect
[ft]
North
[ft]
East
[ft]
Grid East
[US ft]
Grid North
[US ft]
DLS
[°/100ft]
4347.00 41.669 285.665 3567.16 3497.46 2219.08 599.18 -2136.66 421253.33 5973530.61 0.00
4447.00 41.669 285.665 3641.86 3572.16 2285.56 617.13 -2200.67 421189.51 5973549.22 0.00
4547.00 41.669 285.665 3716.56 3646.86 2352.05 635.08 -2264.68 421125.69 5973567.82 0.00
4647.00 41.669 285.665 3791.26 3721.56 2418.53 653.03 -2328.70 421061.87 5973586.42 0.00
4747.00 41.669 285.665 3865.96 3796.26 2485.01 670.98 -2392.71 420998.05 5973605.02 0.00
4847.00 41.669 285.665 3940.66 3870.96 2551.49 688.94 -2456.72 420934.23 5973623.63 0.00
4947.00 41.669 285.665 4015.36 3945.66 2617.98 706.89 -2520.74 420870.41 5973642.23 0.00
5047.00 41.669 285.665 4090.06 4020.36 2684.46 724.84 -2584.75 420806.59 5973660.83 0.00
5147.00 41.669 285.665 4164.76 4095.06 2750.94 742.79 -2648.76 420742.77 5973679.43 0.00
5247.00 41.669 285.665 4239.46 4169.76 2817.43 760.74 -2712.78 420678.95 5973698.03 0.00
5347.00 41.669 285.665 4314.16 4244.46 2883.91 778.69 -2776.79 420615.13 5973716.64 0.00
5447.00 41.669 285.665 4388.86 4319.16 2950.39 796.64 -2840.80 420551.31 5973735.24 0.00
5547.00 41.669 285.665 4463.56 4393.86 3016.87 814.59 -2904.82 420487.49 5973753.84 0.00
5647.00 41.669 285.665 4538.26 4468.56 3083.36 832.54 -2968.83 420423.67 5973772.44 0.00
5747.00 41.669 285.665 4612.96 4543.26 3149.84 850.50 -3032.84 420359.85 5973791.05 0.00
5847.00 41.669 285.665 4687.66 4617.96 3216.32 868.45 -3096.86 420296.03 5973809.65 0.00
5947.00 41.669 285.665 4762.36 4692.66 3282.80 886.40 -3160.87 420232.21 5973828.25 0.00
6047.00 41.669 285.665 4837.06 4767.36 3349.29 904.35 -3224.88 420168.39 5973846.85 0.00
6147.00 41.669 285.665 4911.76 4842.06 3415.77 922.30 -3288.90 420104.57 5973865.46 0.00
6247.00 41.669 285.665 4986.46 4916.76 3482.25 940.25 -3352.91 420040.74 5973884.06 0.00
6322.75 41.669 285.665 5043.04 4973.34 3532.61 953.85 -3401.40 419992.40 5973898.15 0.00
6347.00 40.942 285.665 5061.26 4991.56 3548.62 958.17 -3416.81 419977.03 5973902.63 3.00
6447.00 37.942 285.664 5138.48 5068.78 3612.14 975.32 -3477.98 419916.06 5973920.40 3.00
6547.00 34.942 285.663 5218.91 5149.21 3671.54 991.36 -3535.16 419859.04 5973937.02 3.00
6647.00 31.942 285.663 5302.35 5232.65 3726.64 1006.23 -3588.22 419806.14 5973952.44 3.00
6747.00 28.942 285.662 5388.55 5318.85 3777.30 1019.91 -3637.00 419757.51 5973966.61 3.00
6847.00 25.942 285.661 5477.29 5407.59 3823.38 1032.35 -3681.37 419713.27 5973979.50 3.00
6947.00 22.942 285.659 5568.32 5498.62 3864.75 1043.52 -3721.21 419673.56 5973991.07 3.00
7045.02 20.001 285.658 5659.53 5589.83 3900.63 1053.20 -3755.75 419639.12 5974001.11 3.00
7047.00 20.001 285.658 5661.39 5591.69 3901.30 1053.38 -3756.40 419638.47 5974001.30 0.00
7147.00 20.001 285.658 5755.36 5685.66 3935.51 1062.62 -3789.34 419605.63 5974010.86 0.00
7247.00 20.001 285.658 5849.32 5779.62 3969.71 1071.85 -3822.27 419572.80 5974020.43 0.00
7321.92 20.001 285.658 5919.73 5850.03 3995.34 1078.76 -3846.94 419548.20 5974027.60 0.00
7347.00 20.001 285.658 5943.29 5873.59 4003.91 1081.08 -3855.20 419539.96 5974030.00 0.00
7447.00 20.001 285.658 6037.26 5967.56 4038.12 1090.31 -3888.14 419507.13 5974039.56 0.00
7547.00 20.001 285.658 6131.23 6061.53 4072.32 1099.54 -3921.07 419474.29 5974049.13 0.00
7647.00 20.001 285.658 6225.20 6155.50 4106.53 1108.77 -3954.01 419441.46 5974058.70 0.00
7695.45 20.001 285.658 6270.73 6201.03 4123.10 1113.24 -3969.96 419425.55 5974063.33 0.00
WELLPATH COMPOSITION - Ref Wellbore: DW-02 NAD 27 Ref Wellpath: DW-02 Rev A.0 NAD27
Start MD
[ft]
End MD
[ft]
Positional Uncertainty Model Log Name/Comment Wellbore Survey Date
Page 4 of 5Wellpath Report
4/6/2023file:///C:/WellArchitect/DW-02_Rev_A.0_NAD27.xml
WELLPATH COMPOSITION - Ref Wellbore: DW-02 NAD 27 Ref Wellpath: DW-02 Rev A.0 NAD27
Start MD
[ft]
End MD
[ft]
Positional Uncertainty Model Log Name/Comment Wellbore Survey Date
47.00 7695.45 BH No Uncertainty Plan DW-02 NAD 27 4/6/2023
Page 5 of 5Wellpath Report
4/6/2023file:///C:/WellArchitect/DW-02_Rev_A.0_NAD27.xml
REFERENCE WELLPATH IDENTIFICATION
Operator Santos Well DW-02
Field Pikka API/Legal
Facility Pikka Wellbore DW-02
Slot DW-02
REPORT SETUP INFORMATION
Projection System NAD83 / TM Alaska SP, Zone 4 (5004), US feet Software System WellArchitect® 6.0
North Reference True User Meyedavr
Scale 0.999907 Report Generated 4/10/2023 at 3:34:43 PM
Convergence at slot 0.59° West Database WellArchitectDB
WELLPATH LOCATION
Local coordinates Grid coordinates Geographic coordinates
North[ft] East[ft] Easting[US ft] Northing[US ft] Latitude Longitude
Slot Location 0.00 0.00 1563416.33 5972657.91 70°20'8.9895"N 150°37'29.0730"W
Facility Reference Pt 1563416.33 5972657.91 70°20'8.9895"N 150°37'29.0730"W
Field Reference Pt 1563416.33 5972657.91 70°20'8.9895"N 150°37'29.0730"W
WELLPATH DATUM
Calculation method Minimum Curvature
Rig on W-02 (RT) to Facility Vertical
Datum 69.70ft
Horizontal Reference Pt Slot Rig on W-02 (RT) to Mean Sea Level 69.70ft
Vertical Reference Pt Rig on W-02 (RT)
Rig on W-02 (RT) to Ground Level at
Slot (DW-02)
69.70ft
MD Reference Pt Rig on W-02 (RT)
Field Vertical Reference Mean Sea Level
Closest Approach Clearance Summary
Report
DW-02 Rev A.0 -Santos 2.79 RSS
Page 1 of 2
POSITIONAL UNCERTAINTY CALCULATION SETTINGS
Ellipse Confidence Limit 2.79 Std Dev Ellipse Start MD 47.00ft Surface Position Uncertainty included
Declination 14.80° East of TN Dip Angle 80.59°Mag Field Strength 57197 nT
Slot Surface Uncertainty @1SD Horizontal 0.000ft Vertical 0.000ft
Facility Surface Uncertainty @1SD Horizontal 20.000ft Vertical 3.000ft
Positional Uncertainty values in the WELLPATH DATA table are the projection of the ellipsoid of uncertainty onto the vertical and
horizontal planes
Page 1 of 2Clearance Summary Report
4/10/2023file:///C:/WellArchitect/DW-02_Rev_A.0_CR.xml
NAD 83NAD83 /
REFERENCE WELLPATH IDENTIFICATION
Operator Santos Well DW-02
Field Pikka API/Legal
Facility Pikka Wellbore DW-02
Slot DW-02
CALCULATION RANGE & CUTOFF
From:47.00ft MD To:7695.45ft MD C-C Cutoff:(none)
Closest Approach Clearance Summary
Report
DW-02 Rev A.0 -Santos 2.79 RSS
Page 2 of 2
PROXIMITY-SCAN RULE
Rule Name Santos 2.79 RSS Rule Based On Ratio
Plane of Rule Closest Approach Threshold Value 1.00
Include Casing & Hole Size yes Apply Cone of Safety no
SURVEY PROGRAM - Ref Wellbore: DW-02 Ref Wellpath: DW-02 Rev A.0
Start MD
[ft]
End MD
[ft]
Positional Uncertainty Model Log Name/Comment Wellbore
47.00 47.00 BH Drift Indicator - Estimated Azimuth (Standard) DW-02
47.00 300.00 BH Generic gyro - continuous (Standard) DW-02
300.00 2468.00 OWSG MWD rev2 (MS+IFR2, SAG) DW-02
2468.00 7695.45 OWSG MWD rev2 (MS+IFR2, SAG) DW-02
OFFSET WELL CLEARANCE SUMMARY (2 Offset Wellpaths selected) Ratios are calculated in Closest Approach plane
Offset
Facility
Offset
Slot
Offset
Well
Offset
Wellbore
Offset
Wellpath
Wellbore
Status
C-C Clearance Distance
Rule Separation Ratio
Ref
MD
[ft]
Min C-C
Clear Dist
[ft]
Diverging
from MD
[ft]
Ref MD of
Min Ratio
[ft]
Min
Ratio
Min Ratio
Dvrg from
[ft]
Rule
Status
Pikka B-01 B-01 B-01
B-01 Rev
A.0 Planned 1611.46 141.09 1611.46 1622.34 8.33 1622.34 PASS
Pikka B-02 B-02 B-02
B-02 Rev
A.0 Planned 1661.13 176.22 1661.13 1681.52 10.30 1681.52 PASS
Page 2 of 2Clearance Summary Report
4/10/2023file:///C:/WellArchitect/DW-02_Rev_A.0_CR.xml
DW-02 PTD Rev2 20230418.docx - 24 - 18-Apr-23
Attachment 3: BOPE Equipment
13-5/8" X 5,000#13-5/8" X 5,000#30"13-5/8" X 5,000#186"13-5/8" X 5,000#DUTCH LOCK DOWN
21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#
21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#21-1/4" X 2,000#FORWARD
DW-02 PTD Rev2 20230418.docx - 28 - 18-Apr-23
Attachment 4: Drilling Hazards
12-1/4” 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).
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.
Lost Returns Pump LCM as required (consult prepared lost returns decisions
tree), slow pump rates, reduce ROP or trip speed when necessary.
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.
Abnormal Pore Pressure Pore pressure, fracture gradient prediction study, monitor for
abnormal pressure indicators while drilling and tripping (pit levels,
cuttings/cavings, gas trends). BOP installed and tested, well
control trained personnel.
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.
(mud loggers, trained drilling personnel)
DW-02 PTD Rev2 20230418.docx - 29 - 18-Apr-23
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. Ensure lines have been
pressure tested 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, pump 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.
Drill no more than 50' of new formation before performing FIT. -bjm
DW-02 PTD Rev2 20230418.docx - 30 - 18-Apr-23
Attachment 6: Cement Summary
Surface Casing Cement
Casing Size 9-5/8” 47# L-80 TXP 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 60 bbls of 10.7 ppg Tuned Prime Spacer
Lead 315 bbls, 1768 cuft, 614 sks of 11.0 ppg ArcticCem, Yield: 2.88 cuft/sk
Tail 48 bbls, 269 cuft, 215 sks 15.8 ppg Type I/II – 1.25 cuft/sk
Temp BHST 55° F
Verification Method Cement returns to surface
Ultra Sonic wireline log
Notes Job will be mixed on the fly
Swap to tail cement when lead cement is seen at surface
Production Liner Cement
Casing Size 7” 26# L-80 HYD563 Production Liner
Basis
Lead Open hole volume + 30% excess + Liner Lap + 200 ft 5” DP x 9-5/8” annulus
Lead TOC Top of Liner
Tail Open hole volume + 30% excess + 80 ft shoe track
Tail TOC Top of Torok (4800’ TVDss)
Total
Cement
Volume
Spacer 30 bbls of 11.5 ppg Tuned Prime Spacer
Lead 116 bbls, 651 cuft, 262 sks of 12.0 ppg ExtendaCem, Yield: 2.37 cuft/sk
Tail 51 bbls, 286 cuft, 230 sks 15.3 ppg Type I/II – 1.24 cuft/sk
Temp BHST 140° F
Verification Method Cement returns from top of liner
Ultra Sonic wireline log
Notes Job will be mixed on the fly
*
Verified cement calcs. -bjm
*262 sks X 2.37 cuft/sk = 621 cuft = 111 bbls SFD
15.3 ppg tail per G. Staudinger. -bjm
DW-02 PTD Rev2 20230418.docx - 31 - 18-Apr-23
Attachment 7: Prognosed Formation Tops
DW-02 Prognosed Tops
ftMD ft TVD(KB) ft TVDSS Uncertainty Range Pore Pressure (ppg)
Upper Schrader Bluff 1062 1045 -976 +/- 100ft TVD 7.3
Base Permafrost 1170 1144 -1075 +/- 100ft TVD
MCU 2465 2161 -2092 +/- 100ft TVD 7.9
Tuluvak Shale 2899 2485 -2416 +/- 100ft TVD
Tuluvak Sand 2987 2551 -2482 +/- 100ft TVD 10
Seabee Formation 3925 3252 -3183 +/- 100ft TVD 9.1
Nanushuk Formation 4770 3883 -3814 +/- 100ft TVD 8.9
NT7 MFS 4804 3908 -3839 +/- 100ft TVD
NT6 MFS 4891 3973 -3904 +/- 100ft TVD
8.8 NT5 MFS 5019 4069 -4000 +/- 100ft TVD
NT4 MFS 5095 4126 -4057 +/- 100ft TVD
NT3 MFS 5655 4544 -4475 +/- 100ft TVD
8.6
NT3.2 Top Reservoir 5694 4573 -4504 +/- 100ft TVD
Torok 6090 4869 -4800 +/- 100ft TVD
Base of Torok Confining
Layer 6904 5529 -5460 +/- 100ft TVD
Disposal Zone 2 7111 5721 -5652 +/- 100ft TVD
Disposal Zone 1 7390 5984 -5915 +/- 100ft TVD
HRZ 7608 6188 -6119 +/- 100ft TVD 9.9
TD 7692 6270 -6208 +/- 100ft TVD
HRZ
10
9.9
Tuluvak Sand
DW-02 PTD Rev2 20230418.docx - 32 - 18-Apr-23
Attachment 8: Well Schematic
DW-02 PTD Rev2 20230418.docx - 33 - 18-Apr-23
Attachment9:FormationEvaluationProgram
12Ͳ1/4”SurfaceHole
LWD
GammaRay
Resistivity
DensityNeutron
Sonic
OpenHoleWirelineNone
CasedHoleWirelineUltraSonicCementEvaluation
8Ͳ1/2”ProductionHole
LWD
GammaRay
Resistivity
DensityNeutron
ConventionalCoreNone
OpenHoleWireline
GammaRay
Resistivity
DensityNeutron
Sonic
NMR
SidewallCores
ImageLog
FormationPressures
FormationSamples
CasedHoleWirelineUltraSonicCementEvaluation
MudloggingandSampleProgram
MudloggingwillbeutilizedfromsurfacetoTDonDWͲ02.
Driedcuttingssampleswillbecollectedatamaximumof30ftintervalsfromsurfacetoTD.Cuttings
sampledensitywillbeincreasedoveranyzonesthatwillprovideadditionalgeologicvalue.
DW-02 PTD Rev2 20230418.docx - 34 - 18-Apr-23
Attachment 10: Wellhead & Tree Diagram
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:Staudinger, Garret (Garret)
To:McLellan, Bryan J (OGC)
Subject:RE: DW-02 PTD questions
Date:Friday, May 5, 2023 8:37:27 AM
Bryan,
Please see response in blue below. Let me know if you have any questions.
Thanks,
Garret
From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Sent: Thursday, May 4, 2023 5:27 PM
To: Staudinger, Garret (Garret) <Garret.Staudinger@santos.com>
Subject: ![EXT]: DW-02 PTD questions
Garret,
A few questions about the PTD application:
1. Do you anticipate any H2S? No H2S anticipated
2. Are you planning to run both Sonic and USIT cement evaluation tools for comparison? No, for
DW-02 only CAST-M wireline cement evaluation is planned for both surface and production
casing per EPA. We do not plan to run any BHAs in the production liner after it is installed, so
no real option to run a sonic LWD for comparison.
3. Could you send the rig layout diagram with the proposed diverter line shown? I think what
you are looking for is in the PTD application now under Attachment 3: BOPE equipment. It is
the 2nd drawing in that set of diagrams. Let me know if you are looking for something
different.
4. What is your planned FIT pressure? Minimum LOT needed out of the 9-5/8” casing shoe is
13.2ppg to meet Santos kick tolerance requirements in production hole. However, I plan to
stop at a maximum of 17.0ppg FIT if leak off has not been observed at that point.
5. What is the approximate size, OD and length, of BHA for production hole? 6-3/4” tools to
drill 8-1/2” hole section. Length is approximately 140’ until it transitions to 5” HWDP.
6. What’s the ID of the conductor? 19.25” ID (20” conductor with 3/8” wall thickness)
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
ChokeLinefromBOPPressureGauge1502PressureSensorPressureTransducerBill ofMaterialItemDescriptionToPanicLineItemDescriptionA3Ͳ1/8”– 5,000psi W.P.RemoteHydraulicOperatedChokeB3Ͳ1/8”–5,000psiW.P.AdjustableManualChoke1–14 3Ͳ1/8”– 5,000psi W.P.ManualGateValve1521/16”5 000 i WP152Ͳ1/16”–5,000psiW.P.ManualGateValveToMudGasLegendBlindSpareToTigerTankSeparatorValveNormally OpenValveNormally Closed
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 nogreater
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.
PIKKA UNDEFINED WATER DISPOSAL
PIKKA_DW-02
223-039
WELL PERMIT CHECKLISTCompanyOil Search (Alaska), LLCWell Name:PIKKA DW-02Initial Class/TypeSER / PENDGeoArea890Unit11580On/Off ShoreOnProgramSERField & PoolWell bore segAnnular DisposalPTD#:2230390PIKKA, UNDEFINED WDSP - 600036NA1 Permit fee attachedYes Surface Location lies within ADL0392984; Top Prod Int & TD lie within ADL0391445.2 Lease number appropriateYes3 Unique well name and numberNo Undefined disposal pool in Torok Formation4 Well located in a defined poolYes5 Well located proper distance from drilling unit boundaryYes6 Well located proper distance from other wellsYes7 Sufficient acreage available in drilling unitYes8 If deviated, is wellbore plat includedYes9 Operator only affected partyYes EPA Bond for this Class I Disposal Well10 Operator has appropriate bond in forceYes11 Permit can be issued without conservation orderYes12 Permit can be issued without administrative approvalYes13 Can permit be approved before 15-day waitNA14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (ForYes None15 All wells within 1/4 mile area of review identified (For service well only)NA16 Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)Yes18 Conductor string providedYes19 Surface casing protects all known USDWsYes20 CMT vol adequate to circulate on conductor & surf csgYes21 CMT vol adequate to tie-in long string to surf csgYes22 CMT will cover all known productive horizonsYes23 Casing designs adequate for C, T, B & permafrostYes24 Adequate tankage or reserve pitYes25 If a re-drill, has a 10-403 for abandonment been approvedYes26 Adequate wellbore separation proposedYes27 If diverter required, does it meet regulationsYes28 Drilling fluid program schematic & equip list adequateYes29 BOPEs, do they meet regulationYes MPSP = 2566 psi, BOP rated to 5000 psi (Test pressure = 4000 psi)30 BOPE press rating appropriate; test to (put psig in comments)Yes31 Choke manifold complies w/API RP-53 (May 84)Yes32 Work will occur without operation shutdownNo33 Is presence of H2S gas probableNA34 Mechanical condition of wells within AOR verified (For service well only)Yes None anticipated. Rig will have sensor and alarma.35 Permit can be issued w/o hydrogen sulfide measuresYes Tuluvak and HRZ both anticipated to have pressure equivalent to 10.0 ppg. Tuluvak36 Data presented on potential overpressure zonesNA will be top set by surface casing. Both intervals will be cemented. USIT logs will be run.37 Seismic analysis of shallow gas zonesNA38 Seabed condition survey (if off-shore)NA39 Contact name/phone for weekly progress reports [exploratory only]ApprSFDDate4/29/2023ApprBJMDate5/10/2023ApprSFDDate4/29/2023AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDateGCW 05/11/23JLC 5/11/2023
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
333 West 7th Avenue
Anchorage, Alaska 99501
Re: Request by Oil Search (Alaska), LLC
for reduction in the bonding amount
required under regulation 20 AAC 25.025.
)
)
)
)
)
)
)
)
Docket Number: OTH-23-013
Other Order 197
Oil Search (Alaska), LLC
Bond Reduction Request
April 27, 2023
DECISION AND ORDER
By letter dated April 19, 2023, Oil Search (Alaska), LLC (OSA) requested that the Alaska Oil and
Gas Conservation Commission (AOGCC) waive the bonding requirements for their proposed DW-
02 disposal well, a Class I disposal well under the underground injection control (UIC) program
that is being regulated by United States Environmental Protection Agency (EPA). The EPA has
entered into a trust agreement with OSA, who provided a copy of the agreement to the AOGCC to
review, to cover the cost of plugging and abandoning this well and two additional potential UIC
Class I wells.
FINDINGS:
Based upon the evidence presented by OSA, AOGCC finds as follows:
1. Under 20 AAC 25.025(b)(3)(C) the AOGCC can accept bonding that is in place with the
EPA for the plugging and abandonment of UIC Class I disposal wells.
2. OSA’s request only referenced the DW-02 Class I disposal well but the evidence provided
by OSA indicates the trust agreement with the EPA can cover the cost of abandoning up to
three UIC Class I disposal wells that the EPA approved pursuant to UIC permit AK-1I019-
A.
CONCLUSIONS:
The trust agreement between OSA and the EPA meets the AOGCC’s bonding requirement for the
three EPA authorized UIC Class I disposal wells.
NOW THEREFORE IT IS ORDERED THAT:
So long as OSA maintains the trust agreement with the EPA in good standing it will cover the
plugging and abandonment liability for up to three UIC Class I disposal wells and those wells
will not be included in the well counts used to determine OSA’s bonding liability with the
AOGCC. OSA must notify the AOGCC within 30 days of any changes in the trust agreement.
Other Order: 197
April 27, 2023
Page 2 of 2
DONE at Anchorage, Alaska and dated April 27, 2023.
Brett W. Huber, Sr Jessie L. Chmielowski Gregory C. Wilson
Chair, Commissioner Commissioner Commissioner
RECONSIDERATION AND APPEAL NOTICE
As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the AOGCC
grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration of the matter determined by it.
If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or
decision is believed to be erroneous.
The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within
10 days is a denial of reconsideration. If the AOGCC denies reconsideration, upon denial, this order or decision and the denial of reconsideration
are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails, OR 30
days if the AOGCC otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the
appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed.
If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on
reconsideration will be the FINAL order or decision of the AOGCC, and it may be appealed to superior court. That appeal MUST be filed within
33 days after the date on which the AOGCC mails, OR 30 days if the AOGCC otherwise distributes, the order or decision on reconsideration.
In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period;
the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day
that does not fall on a weekend or state holiday.
Gregory
Wilson
Digitally signed by
Gregory Wilson
Date: 2023.04.27
09:07:40 -08'00'
Jessie L.
Chmielowski
Digitally signed by
Jessie L. Chmielowski
Date: 2023.04.27
09:14:40 -08'00'
Brett W.
Huber, Sr.
Digitally signed by
Brett W. Huber, Sr.
Date: 2023.04.27
09:16:46 -08'00'
From:Carlisle, Samantha J (OGC)
To:AOGCC_Public_Notices
Subject:Other Order 197 (Oil Search)
Date:Thursday, April 27, 2023 9:56:00 AM
Attachments:other197.pdf
Request by Oil Search (Alaska), LLC for reduction in the bonding amount required under
regulation 20 AAC 25.025.
Samantha Carlisle
Special Assistant
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue
Anchorage, AK 99501
(907) 793-1223
Bernie Karl
K&K Recycling Inc.
P.O. Box 58055
Fairbanks, AK 99711
