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Alaska Oil and Gas Conservation Commission
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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: ______________________
Development Exploratory
Stratigraphic Service 6. API Number:
7. Property Designation (Lease Number): 8. Well Name and Number:
9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s):
11. Present Well Condition Summary:
Total Depth measured 9,464 feet 5,040 feet
true vertical 5,997 feet N/A feet
Effective Depth measured 4,954 feet N/A feet
true vertical 3,838 feet N/A feet
Perforation depth Measured depth N/A feet
True Vertical depth N/A feet
Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 549 (MD) 548 (TVD)
Packers and SSSV (type, measured and true vertical depth) N/A & N/A
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure:
13a.
Prior to well operation:
Subsequent to operation:
13b. Pools active after work:N/A
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:
Contact Email:
Authorized Title: Contact Phone:
4,750psi
3,090psi
6,870psi
1,095 1,067
Burst Collapse
1,540psi
measured
TVD
Production
Liner
5,115
Casing
Structural
3,9205,115
264
1,095
264Conductor
Surface
Intermediate
20"
13-3/8"
9-5/8"
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
223-011
50-733-20064-03-00
3. Address:
Hilcorp Alaska, LLC
3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
N/A
5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work:
ADL0018731 / ADL0017597 / ADL0392195
Trading Bay / Undefined Gas
Trading Bay Unit A-10RD3
Plugs
Junk measured
Length
measured
true vertical
Packer
Representative Daily Average Production or Injection Data
Casing Pressure Tubing Pressure
14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283)
0
Gas-Mcf
MD
N/A
0
Size
264
0 00
0 00
0
N/A
Sr Pet Eng: Sr Pet Geo: Sr Res Eng:
WINJ WAG
0
Water-BblOil-Bbl
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Casey Morse
Casey.Morse@hilcorp.com
907 777-8322Operations Manager
N/A
Development Service
GINJ SUSP SPLUG
Gas
Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov
Digitally signed by Dan
Marlowe (1267)
DN: cn=Dan Marlowe (1267)
Date: 2024.05.15 07:19:32 -
08'00'
Dan Marlowe
(1267)
By Grace Christianson at 11:28 am, May 15, 2024
DSR-5/15/24
Suspended Well Inspection Data
Well: TBU A-10RD3
Surface Location: 1602 FSL, 550 FEL, Sec 4, T9N, R13W, SM, AK
Permit to Drill: 223-011
API: 50-733-20064-03-00
AOGCC Inspection Date: 05/13/2024
AOGCC Inspector: Waived per email from Jim Regg, 5/13/2024
Size Pressure (psi)
Kill String 4-1/2 0
Casing 9-5/8 0
OA 13-3/8 92
*Note: Wellhead pressures to be recorded monthly at minimum.
Other Notes:
Condition of Wellhead:
See pictures below
Condition of Surrounding Surface Location:
See pictures below
Follow Up Actions needed:
Currently, the open hole is isolated with cement and a retainer. A kill string was left in
the well to a depth of 549 inside the 9-5/8 casing. This well is currently being
evaluated as a future sidetrack candidate.
Attachments:
Current Well Schematic
Picture(s)
Plat - 1/4mile radius of wellbore
_____________________________________________________________________________________
Updated By: CJD 6/9/23
Current Schematic
Trading Bay Unit
Well: A-10RD3
PTD: 223-011
API: 50-733-20064-03-00
Cement Detail
Item
Suspension Pumped 84 bbls of 15.3 ppg cement below cmt retainer, Lay 7.2 bbls of 15.3
ppg cement above retainer (TOC tagged @ 4,954)
CASING DETAIL
Size Wt Grade Conn ID Top Btm
20Conductor Pile Surface ~264
13-3/861 K-55 BTC 12.515Surface 1,095
9-5/8 47 L-80 DWC/C 8.681 Surface
5,115
(TOW)
Kill
String 12.6 L-80 IBT 3.992 Surface 549
JEWELRY DETAIL
No Depth
(MD)Item
1 5,040Cement Retainer
2 5,115TOW
Well Sign
WELL NAME API PTD LEASE #
TRADING BAY ST A-01RD 50-733-10055-01-00 190-147 ADL0018731
TRADING BAY ST A-02 50-733-10056-00-00 166-049 ADL0018731
TRADING BAY ST A-03RD3 50-733-10057-03-00 197-130 ADL0018731
TRADING BAY ST A-04 50-733-20001-00-00 167-002 ADL0018731
TRADING BAY ST A-05RD2 50-733-20011-01-00 176-025 ADL0018731
TRADING BAY ST A-06 50-733-20020-00-00 167-025 ADL0018731
TRADING BAY ST A-07 50-733-20036-00-00 167-046 ADL0018731
TRADING BAY ST A-08RD2 50-733-20043-02-00 197-067 ADL0018731
TRADING BAY ST A-09RD 50-733-20062-01-00 181-036 ADL0018731
TRADING BAY UNIT A-10RD3 50-733-20064-03-00 223-011 ADL0017597/ADL0018731/ADL0392195
TRADING BAY ST A-11 50-733-20214-00-00 170-024 ADL0018731
TRADING BAY ST A-12RD 50-733-20076-01-00 171-029 ADL0018731
TRADING BAY ST A-13 50-733-20077-00-00 168-002 ADL0018731
TRADING BAY ST A-14 50-733-20099-00-00 168-027 ADL0018731
TRADING BAY ST TBU A-15RD2 (ML) 50-733-20105-02-00 202-019 ADL0018731
TRADING BAY ST A-16RD 50-733-20111-01-00 188-038 ADL0018731
TRADING BAY ST A-17RD 50-733-20135-01-00 181-067 ADL0018731
TRADING BAY ST A-18 50-733-20143-00-00 168-076 ADL0018731
TRADING BAY ST A-19RD 50-733-20151-01-00 188-001 ADL0018731
TRADING BAY ST A-20RD 50-733-20302-01-00 190-041 ADL0018731
TRADING BAY ST A-21RD 50-733-20223-01-00 170-047 ADL0018731
TRADING BAY ST A-22 50-733-20218-00-00 170-031 ADL0018731
TRADING BAY ST A-23DPN 50-733-20227-90-00 172-020 ADL0018731
TRADING BAY ST A-24RD 50-733-20226-01-00 181-040 ADL0018731
TRADING BAY ST A-25RD 50-733-20242-01-00 188-137 ADL0018731
TRADING BAY ST A-26 50-733-20230-00-00 171-020 ADL0018731
TRADING BAY ST A-27RD2 50-733-20246-02-00 216-028 ADL0017594 / ADL0018731
TRADING BAY ST A-28RD 50-733-20255-01-00 189-092 ADL0017597
TRADING BAY ST TBU A-29RD 50-733-20245-01-00 202-004 ADL0017594 / ADL0018731
TRADING BAY ST A-30 50-733-20253-00-00 173-014 ADL0018731
TRADING BAY ST A-31 50-733-20627-00-00 214-033 ADL0018731 / ADL0392193
TRADING BAY ST A-32 50-733-20301-00-00 177-018 ADL0018731
Hilcorp Alaska, LLC
MONOPOD PLATFORM
NE 1/4, SE 1/4, Section 04, Twn 9N, Range 13W, SM, AK
Picture Tubing (kill string) Pressure Gauge
Picture IA Pressure Gauge
Picture OA Pressure Gauge
Wellhead Looking North
Wellhead Looking South
Wellhead Looking West
Plat Quarter-mile Buffer
1a. Well Status:Oil SPLUG Other Abandoned Suspended
1b. Well Class:
20AAC 25.105 20AAC 25.110 Development Exploratory
GINJ WINJ WDSPL No. of Completions: _0 Service Stratigraphic Test
2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry:
Aband.:
3. Address: 7. Date Spudded: 15. API Number:
4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number:
Surface:
Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): North Trading Bay Unit
GL: N/A BF: N/A
Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation:
4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number:
Surface: x- y- Zone- 4
TPI: x- y- Zone- 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD:
Total Depth: x- y- Zone- 4
5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD:
Submit electronic information per 20 AAC 25.050 66 (ft MSL)
22. Logs Obtained:
23.
BOTTOM
20" - 264'
13-3/8" K-55 1,068'
9-5/8" L-80 3,920'
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
4-1/2"
SIZE DEPTH SET (MD)
N/A
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date perf'd or liner run):
Surface 5,115' (TOW)
Surface
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
CASING, LINER AND CEMENTING RECORD
List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion,
TUBING RECORD
Stg 1 - 750 sx / Stg 2 - 630 sx12-1/4"
549'
17-1/2"
Driven
Surface 1200 sx
Surface
1,095'
3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503
218864 2523116
50-733-20064-03-00March 24, 2023
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
Hilcorp Alaska, LLC
WAG
Gas
5/10/2023 223-011 / 323-272
N/A
TBU A-10RD3April 30, 20231602' FSL, 550' FEL, Sec 4, T9N, R13W, SM, AK
101'
BOTTOMCASINGWT. PER
FT.GRADE CEMENTING RECORD
N/A
SETTING DEPTH TVD
2527152
TOP HOLE SIZE
LWD (GR, RES, Neu) + PB1
Trading Bay Undef Gas Pool
ADL18731, ADL17597, ADL392195
Date of Test: Oil-Bbl:
N/A
Gas-Oil Ratio:
AMOUNT
PULLED
N/A
222633
TOP
SETTING DEPTH MD
suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud
log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing
collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary.
PACKER SET (MD/TVD)
Cond
N/A
5,115' MD / 3,920' TVD
N/A
9,464' MD / 5,997' TVD
4,954' MD / 3,838' TVD
N/A
447' FSL, 2174' FEL, Sec 34, T10N, R13W, SM, AK
Choke Size:
Surface
Per 20 AAC 25.283 (i)(2) attach electronic information
47# Surface
-
61#
264'
Water-Bbl:
PRODUCTION TEST
N/A
Sr Res EngSr Pet GeoSr Pet Eng
Oil-Bbl: Water-Bbl:
N/A
Flow Tubing
WINJ
SPLUG Other Abandoned Suspended
Stratigraphic Test
No
No
(attached) No
Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment
By Grace Christianson at 2:39 pm, Jun 09, 2023
Suspended
5/10/2023
JSB
RBDMS JSB 060923
GDSR-6/28/23
Conventional Core(s): Yes No Sidewall Cores:
30.
MD TVD
Top of Productive Interval N/A
6,685' 4,682'
6,973' 4,819'
7,447' 5,044'
31. List of Attachments:
32. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Contact Name: Cody Dinger
Digital Signature with Date:Contact Email:cdinger@hilcorp.com
Contact Phone: 907-777-8389
General:
Item 1a:
Item 1b:
Item 4b:
Item 9:
Item 15:
Item 19:
Item 20:
Item 22:
Item 23:
Item 24:
Item 27:
Item 28:
Item 30:
Item 31:
If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if
needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired.
Yes No
Well tested? Yes No
28. CORE DATA
If Yes, list intervals and formations tested, briefly summarizing test results for
each. Attach separate pages if needed and submit detailed test info including
reports and Excel or ASCII tables per 20 AAC 25.071.
NAME
Permafrost - Top
Permafrost - Base
29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS
Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345),
and/or Easement (ADL 123456) number.
The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements
given in other spaces on this form and in any attachments.
The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic
diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from
a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071.
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core
analysis, paleontological report, production or well test results, per 20 AAC 25.070.
Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each
segregated pool is a completion.
TPI (Top of Producing Interval).
Authorized Name and
Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
Tyonek C1
Tyonek C2
Tyonek C3
Formation Name at TD:
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.
INSTRUCTIONS
Tyonek
Wellbore Schematic, Drilling Reports, Definitive Surveys (+PB1)
Authorized Title: Drilling Manager
No
NoSidewall Cores: Yes No
Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov
For Monty Myers
Digitally signed by Cody
Dinger (2323)
DN: cn=Cody Dinger (2323)
Date: 2023.06.09 13:08:21 -
08'00'
Cody Dinger
(2323)
_____________________________________________________________________________________
Updated By: CJD 6/9/23
Current Schematic
Trading Bay Unit
Well: A-10RD3
PTD: 223-011
API: 50-733-20064-03-00
Cement Detail
Item
Suspension Pumped 84 bbls of 15.3 ppg cement below cmt retainer, Lay 7.2 bbls of 15.3
ppg cement above retainer (TOC tagged @ 4,954’)
CASING DETAIL
Size Wt Grade Conn ID Top Btm
20”Conductor Pile Surface ~264’
13-3/8”61 K-55 BTC 12.515”Surface 1,095’
9-5/8”47 L-80 DWC/C 8.681” Surface
5,115’
(TOW)
Kill
String 12.6 L-80 IBT 3.992” Surface 549’
JEWELRY DETAIL
No Depth
(MD)Item
1 5,040’Cement Retainer
2 5,115’TOW
Activity Date Ops Summary
3/1/2023 install walkway to rig cellar, rig up glycol lines to rig, stow 4 knack box's under heliport and shovel snow from same.;Last chopper load of Enterprise crew arrived
at 11:30hrs. Orient all crew to Monopod and hold Hilcorp expectation meeting and pre-job. Conduct walk thru with Co.Men, crew and Pushers on work needing
completion.;Install new shortened bleed off line in cellar, remove mud bucket hose. Pull hand rails on back of sub. Set strong backs for cement silo's and 500bbl
tanks from boat. Install HP mud line to sub, LP mud line to sub and turn on Glycol to sub and check for leaks and fix same.;Blow air thru deluge system and
make sure lines and jets are clear. Install deluge line to sub. Set fork lift in dry sack room. Hang power cable for vac-unit. Shovel snow from rig floor.;Rest crews.
3/2/2023 Fix glycol heater under hopper rm. Chip ice from water flood roof and spot Top Drive VFD and hyd. unit. Spot slop tank in cellar and blow air thru each drain
hose, rig up diaphragm pump and pump out same. Cont. shovel rig floor and pipe deck.;Send cutting box tank stand to weld shop for modification. Rig up jet
heater to thaw out mud ditch with flow lines froze in them. Spot cuttings tank stand, clean and power up elect/mechanics shops.;Install 10" air boot and plug in
shaker water base ditch. Thaw shaker and koomey hoses with jet heater, shovel off pits. Service and inspect used choke and kill hoses from steelhead and
install cover plates on same and ready for back load to DW.
Unable to get a boat today due to 404 rig move.;Use jet heater to thaw 2 more boxes of koomey hoses. Change out fitting and install glycol heater behind drill
console. Install flow line from poor boy and well to mud ditch and hook up ground lines. Pull cover on rotary table traction motor, pull desiccant packs, install
brushes and armatures.;Rest crews...
3/3/2023 Work boat: Off load top drive connex, cement silo, centrifuge, centrifuge VFD, stand alone transfer pump, back-up choke/kill hoses and misc. cargo. Back load
misc. over packs, steelhead old choke/kill hoses, oily waste totes.;Hand reported getting water in his ear on the 1st March and sent to beach to get it cleared
before going to 151 to assist on their rig up. Hand was cleared for work without restrictions and the incident was classified as a first aid on HAK report.;Spot
cement silo, cross chain to strong back and weld dwn same. Spot jet heater in cellar to cont. heat up rig and Top Drive VFD. Install koomey line in cellar.;Spot
centrifuge, centrifuge VFD and stand alone transfer pump. Install mouse hole, spot back-up choke/kill hoses in cellar. Cont. installing koomey hoses.;Boat un-
able to retrieve man camp from Baker Platform do to weather.;Install hand rails on strong back for 500bbl tank. Install catwalk under beaver slide. Spot vac
shock/cuttings tanks. Meg all electric motor except mud pumps, and checked all brushes and armatures. Start draining choke manifold.;Rest crews....
3/4/2023 Finish installing koomey lines, dress mud pump #1, install blank on J-tube overboard line from shakers. Start hanging SRL's on rig and start to rig up vac unit
lines. Finish Megging electric motors on mud pumps and check brushes and armatures. Install bleeder on driller glycol heater.;Finish hanging SRL's on rig and
draining choke manifold oil. Welder building manifold for vac unit, begin wiring MWD,centrifuge VFD and stand-alone transfer pump.Well head hand set BPV
and check pressures,ann/tubing 0/0, 13-3/8"-85, surf pipe-87psi. Derrick inspection.;Work Boat: Off-load 500bbl tank and spot, empty 2ea. ISO's of diesels,
hydril, single gate, dbl gate, riser pipe, BOP lifter and mud cross w/choke and kill valves. Misc. cargo.;Rest crews...
3/5/2023 Safe out RPM tank w/hand rails and ladder. Empty hopper rm of hoses and lay out on top RPM tank.Dress #1pump and start on #2. Finish welding vac. hose
manifold and install fittings. Install bridge from rig to top of water flood for access to VFD and HPU.;Cont. hook up power/comms to MWD shack, centrifuge and
transfer pump.;Turn centrifuge 180 and install new dump shoot. R/U suction/discharge lines from RPM tank to transfer pump, pits and reserve pit. Inspectors
from All-Rigs started inspecting derrick.;Held muster and abandon platform drill with all personnel, then held post drill meeting to discuss any issues
(12min.).;Rest crews...
3/6/2023 Install hand rails were we could, welder working on the rest. Power up man camps, spot porta-john and clean up deck around weld shot. Cont. house keeping in
drilling area's-pits, pipe deck and cellar. Spot top drive connex next to man camp.;Start plumbing vac lines to rig cellar and building manifold. Hand Canrig,
Sperry and camera screens at driller's console. Install camera in cellar. Finish installing new centrifuge dump line.;Finish hanging service lines to to top drive
VFD and hyd. unit and plug in same. Load Master finished derrick inspection, waiting on report. All Rig still performing MPI's and sling inspections. finish vac line
plumbing to rig cellar and floor.;Welder starting to install handrail and stiff arm on centrifuge unit. C/o cable on manrider/winches and air tugger.;Rest crews...
3/7/2023 Plumbed: 2" base oil line f/deck t/top of pits, 3" suction t/centrifuge feed pump and 2" discharge valve w/blow down, 6" centrifuge under flow t/4" discharge hose
into pits. Centrifuge Rep. commissioned unit-good.;House keeping in all drilling area's. CanRig rep. on location taking inventory and laying out equipment for rig
up. Install 26" elephant trunk duct from rig drawworks motors t/water flood. CCI welder cont. installing hand rail and strong arm for cuttings vac hose.;Stack mud-
X on single gate and install lifter. Mechanic discovered oil in the glycol reservoir from the oil cooling coil, pulled oil coil and pressure tested, leaking at bulk head
fitting, removed and cleaned fittings and re-installed with sealant-letting dry until tomorrow.;Drained glycol to re-use in draw works cooler and drained oil for
pickling choke manifold on stack out. oil and glycol will be on tomorrows boat. Enterprise welder working on bridge and stairs to RPM tank.;Safety audit from
Main office went well no major issues: cellar stair, forklift seat belt, bridge /stairs t/RPM tank-WIP and PPE locker.;Rest crews....
3/8/2023 CanRig cont. R/U, Run DWKs-checked COM, crown saver, brake cooler and Dyno. Dyno kept tripping in drill mode and had a burnt card, installed spare-tested
good. Hung last SRL at the crown. Removed old service loop wrap.;Welder finished mid-rails on strong arm rail, hung splitter for cutting box and pump rm
w/valves. Hung shaker vac hose on strong arm w/chain fall. Install 2" centrifuge feed line to unit. Wired up power to centrifuge feed pump.;Welder working on
man camp roof hand railing, 2nd welder finished bridge stairs to RPM tank. Pull dry hole tree from A10-RD3 and install HP riser, single gate and mud-X. Start
install of new service loop.;Work boat- get rid of back load to free up deck space for pipe tomorrow. Off-load from boat -ST-80, ISO32 hyd. oil, glycol, test
jts/pups, bails, trash pumps, ST-80 tool box and DSA.;Rest crews...
n (LAT/LONG):
evation (RKB):
API #:
Well Name:
Field:
County/State:
TBU A-10RD3
Trading Bay North
Hilcorp Energy Company Composite Report
, Alaska
Contractor
AFE #:
AFE $:
Job Name:231-00045 TBU A-10RD3 Drilling
Spud Date:
3/9/2023 Cont. CanRig R/u. Welders working on hand rails on man camp and ladder on RPM tank. Crane hoses from RPM tank to pipe deck and lay out for fill up line
and vac. Quadco rep. on board for gauge calibrations. Fill Top Drive Hyd. unit w/oil and cooling tank w/glycol, purge out air in hyd. lines.;Install new service line
and new wrap for same. Rig electrician pulled away to rig 151-lost heat; all wire connections work stopped until return. R/U 2-50ft 3" fill up lines for Base oil and
reserve tanks. Hung 3" hose to pump room and cuttings box.;Clear west pipe deck for Drill pipe coming on boat. Set iron ruff neck on rig floor, no pedestal-on
boat. Work on DS tongs-froze up. Prep DSA's, manual valves, HCR's and Choke/kill hoses for install.;Welders finish hand rails on man camp. Quadco rep.
finished gauge calibration.;Rest crews...work boat-off load Iron ruff neck base, 174jt 4.5"DP, DC and HW. Take on water.;Rest crews...
3/10/2023 Replace all 3 multiple hose fill up lines w/new 3"-50ft hoses to base oil, reserve tank and RPM tank. Remove off-set from iron ruffneck pedestal and instal on ruff
neck. Install ruffneck on rig floor and check all functions-good. Install torque gauge in drillers console. Fixed Dyno-Matic;Free up ODS frozen tong. Welders
working on 6" mud bucket line and drillers console screen mount. Run test pump, c/o 1/4 turn valves and order parts.;Clean RPM tank of debris. Welder finish
drillers console screen mount. Start commissioning TOP Drive-pipe handler function working, link tilt working, no rotation-just rocking back n forth. Set brake and
rocking stops as if brake is holding.;Cont. trouble shoot: Got top drive to spin in drill, increased to 35rpm then it faulted out VFD with many codes....cont. trouble
shoot. Remove bell guide air boot and 1/2 moon plates f/rig floor t/cellar.;Simop-N/U BOPs-move all manual and HCR valves into cellar and install both manuals
and 1 HCR. Start working boat off-loading OBM.;Finish working boat-off loading OBM @1900hrs. Rest crews...
3/11/2023 Call NOV and start process for tech consultation on top drive-waiting on call back. Rig mech/electrician powered up system and top drive operated like it is
supposed to forward/reverse etc.. Shut down and repeat-good, M/U and B/O subs w/grabber-good- Top Drive commissioned.;Commission Iron ruffneck: spin
subs in.out and trq same, break out subs and compare trq readings on unit to console-good. N/U BOP's-HCR, DSA's. Dress mud pump #2 with seats and
valves. Install duct on DWKs.;Cont. N/U BOP's-choke/kill hoses, DBL Gate, Annular. Free up under flow risers in mud pits and replace winch. Close up pits bulk
head. Test reserve tank agitators and transfer pump.;Test Degasser and pit agitators, tested RPM tank agitators and transfer pump. Hang all hoses on top of
RPM tank on hand rails.;Rest crews.....
3/12/2023 Torque up BOP's, Paint mud bucket line. Repair hydraulic leak on iron ruffneck. Clean out dry sack/pump room for mud product. Grease all agitator, pumps and
motors.;Fill pill pit #1 and #2 w/60bbls sea water and transfer fluid to reserve pit #4, trip tank, RPM tank #1, RPM tank #2 and active pits to confirm system
containment integrity, c/o leaky valves. Clean and organize pipe deck. Install 6" mud bucket hose under rig floor. Cont. torquing BOP's.;Rest crew....Boat
scheduled for 2300hrs with mud product and OBM...
3/13/2023 Finish torquing up BOP's and side outlet lines. Install drylocks on BOP's and hook up koomey lines. Received 84bbls OBM into reserve pit #4. Transfer OBM
from RPM tank #3 to active pit #1 and #2 and treat same.;Pressure up accumulator and check for leaks, function test same from unit. Grease choke manifold.
Set Bell nipple air boot flange on annular. Work boat.;Open doors pull top 2-7/8 x 5-1/2 var. rams and inspect/compare seals with bottom 2-7/8 x 5-1/2 var rams-
take measurements and pic's, stamp lower rams with UOCD #'s and correct size (mis-labled from vendor) re-install both top/bottom rams and re-torque
doors.;P/U bails and install on top drive, pressure up koomey and function test from both remotes. Cont. treat mud and work boat. M/U 4.5" test jt. set and fill
stack w/water for shell test, set mouse hole and bring subs, slips and elevators to floor. set half moons around stack and mouse hole.;Replace shaker bed
rubber and dress shaker...
3/14/2023 Troubleshoot and repair test pump - changeout valve and regulator.;BOP pressure assurance tests: shell test against annular with 4.5" test joint 250/3500 psi -
good test. Pressure test against UPR with 4.5" test joint 250/5000 psi;Held Pre-Spud meeting with Drill crews, Production crews, and Hilcorp representatives -
CIO Area Operations Manager, Drilling Manager, Drilling Engineer, Reservoir Engineer, Geologist, Safety and DSMs in attendance.;Resume BOP pressure
assurance tests. Troubleshoot Top Drive link-tilt, pipe handler and IBOP functions: issue with pump on Top Drive HPU - remove and send in for
repairs.;Function IBOP manually and continue with BOP pressure assurance tests. Troubleshoot and retorque connections on stack. Work boat and offload 2
iso's base oil (DrillSol) and scraper assembly. Troubleshoot and remove seized pump on reserve pit. Troubleshoot and repair regulator on test pump.;Hook up
rig HPU to top drive and function test pipe handler, IBOP and link-tilt - good.;Continue to chase leaks on BOP pressure assurance tests. Isolate Lower Kelly
Valve on Top Drive - leaking. Grease and function choke manifold valves.
Observe leak at open casing valve.
Build and condition mud per mud engineer.;Continue to build and condition mud per mud engineer.
Clear ice from reserve tank suction line and centrifugal pump. Blow down top drive and test equipment.
3/15/2023 Continue with BOP pressure assurance testing. Test UPR and LPR with both 4.5" and 5" test joints 250/5000 psi.
Continue to build and condition mud.
Thaw, repair and replace centrifugal pump on reserve pit.
Sperry DD and MWD, rig up shack and strap tools.;Remove and replace lower IBOP on top drive.
Yellow Jacket rep pull and replace lower pipe ram shaft seal.
Continue to build and condition mud.
Spot and rig up Sperry GeoSpan.;Pressure test LPR to 5000 psi and verify ram shaft seal and door seal holding.
Transfer mud from Pits 1 & 2 to Reserve. Transfer Base oil to Pits 1 & 2 and resume building mud.
Send out 48hr notice to AOGCC for initial BOP test.
Strap 4.5" drill pipe on deck.
3/16/2023 Continue to build and condition mud. Blow down and rig down test hoses and test equipment.
Blow down top drive and clear rig floor of test equipment.
Assist Sperry and install plumbing for GeoSpan.
Change out bladder on accumulator bottle #4.
Install bell nipple and turnbuckles on stack.;Continue to build and condition mud.
Install drip pan above annular. Rig up ropes and belly belts in derrick.
Continue to work on rig acceptance checklist.;Continue to build and condition mud. Continue to work on rig acceptance checklists.
General housekeeping throughout rig - re-route hoses to reduce trip hazards.
Clean out hydraulic reservoir for top drive HPU.;Continue to build and condition mud. Continue to work on rig acceptance checklists.
General housekeeping throughout rig.
3/17/2023 Continue to work on rig acceptance checklist.
General housekeeping - work on organizing rig floor and cellar areas.;Continue to work on rig acceptance checklist.
Dress mud bucket and modify outlets to fit return line.
Install glycol heat lines on mud pump jumper hose.
General housekeeping - continue to organize rig floor and prep to pick up drill pipe.;Held PJSM with rig crew prior to picking up and racking back 4.5" drill pipe.
Driller found 4.5" elevators were mis-marked.;Strap, tally pick up and rack back 4.5" drill pipe in derrick.;Lost power to rig - standby while production crew
troubleshot issue and got power back on.
Restart agitators in pits and check equipment.;Strap, tally pick up and rack back 4.5" drill pipe in derrick.;Rig up to test BOPE. Install 4.5" test joint and make up
test assemblies.
3/18/2023 Rig up to test BOPE. Purge air from system and perform shell test while waiting for AOGCC rep Adam Earl to arrive on location.;Test BOPE per Hilcorp /
AOGCC 250/5000 psi for 5/5 charted min each. Test Annular to 250/3500 psi for 5/5 charted min. Tests #1-8 performed with 4.5" test joint. Test gas alarms: 1
FP- change out head and re-tested good. Perform drawdown test - good.;Troubleshoot BOP test. Replace stem packing on Choke HCR. CMV #4 re-grease
valve. Top Drive Lower Kelly Valve Adjust Torque Fenner ring and re-grease.;Troubleshoot leak during blind ram test: Tighten HCR Shoke Stem Protector.
Changeout leaking grease zerk on CMV #4. Troubleshoot test manifold and replace 2 leaking valves and a plugged needle valve.;Test Upper and Lower VBRs
with 5" test joint 250/5000 psi for 5/5 charted min. Test #2 FOSV and Upper and Lower Kelly valves on top drive - good tests. Attempt to work boat - high wind
and seas, unable to offload.;Pull and lay down 5" test joint and rig up to re-test blind rams.;While attempting to test blind rams, observed issue with accumulator
tri-plex. Found packing on inner plunger on pump #1 had come apart. Repair pump and replace packings on all 3 plungers. Work boat that was loaded on 3/17
and had been on weather hold.
3/19/2023 Continue to repair accumulator pump. Work boat that was loaded on 3/17 and had been on weather hold.;Complete BOPE test. Test blind rams 250/5000 psi or
5/5 charted min.;Install riser and flow line down to stack. Pull bell nipple and replace leaking air boots. Install gasket and re-seal rotary pan. Change out regulator
on accumulator.;Calibrate block heights with CanRig and Sperry MWD. Prep rig floor for picking up 4.5" drill pipe.;Strap, tally, pick up and rack back remainder
of 4.5" CDS40 drill pipe in derrick.;Flush all surface lines and pressure test mud lines to 3000 psi with water.;Change handling equipment. Pick up Sperry ADR
and break. Lay down to deck in 2 sections to allow MWD to reset battery.;Assist Vault Wellhead rep. Retrieve blanking sub and lay down. Pick up dry-rod and
retrieve BPV and lay down. Make up landing joint, XO's to tubing hanger and FOSV.;Rig up Parker Wellbore tongs and 4.5" tubing handling equipment. Vault
Wellhead rep back out lock down screws on tubing hanger.;Make up landing joint into hanger and rig up trip tank. Fill stack and assess leaks on low pressure
riser. Work boat - offload additional mud product.;Pull hanger off seat at 45 Klbs pull free to floor at 34 Klbs. Lay down landing joint and hanger with 6.81' hanger
pup.;Pull and lay down 4.5", 12.6# IBT Kill string - recovered 16 full joints, 1 muleshoe, 6.81' hanger pup and hanger.;Rig down and Parker Wellbore tongs and
handling equipment and clear rig floor. Rig up to repair leaks on low pressure riser.;Mobilize casing scraper BHA to rig floor. Replace leaking air boots on low
pressure riser.;Pick up and run in the hole with 8.5" casing scraper assembly.
3/20/2023 Run in the hole and set wear ring. Run in 2 lockdowns, pull out of the hole and lay down running tool.;Work boat - offload additional 5" drill pipe and WTT tools.
Install pollution pan under rig floor.;Mobilize WTT tools and NRPs to rig floor. Verify NRP placement on 5" drill pipe.;Hold PJSM with rig crew, DD, WTT and
crane crew on picking up BHA and 5" drill pipe from deck. Make up and run in the hole with bit, scraper and 6.5" drill collars to 100' MD.;Hold fire and platform
abandonment drill with all personnel on platform.;Finish picking up and running in the hole with casing scraper assembly to 287'. Monitor well with trip tank while
running in - correct displacement.;Run in the hole with casing scraper assembly, picking up 5" drill pipe off deck to 1449'. Install 2 NRP's per joint with WWT per
plan. Monitor well with trip tank while running in - correct displacement.;Work boat with crane crew. Perform trip drill with rig crew and work through derrick
rescue drill and manrider hydraulic failure. Free up rotary locks and organize NRP's on rig floor. Walk drill crew through pit light water system and rig deluge
system.;Continue to trip in the hole with scraper assembly, picking up 5" drill pipe and installing 2 NRP's per joint with WTT to 2195'. Monitor well with trip tank
while running in - correct displacement.;Work boat with crane crew - offload and empty 1 Iso of base oil to pits. Organize and mobilize additional NRPs to rig
floor. Walk drill crew through pit light water system and rig deluge system.;Continue to trip in the hole with scraper assembly, picking up 5" drill pipe and
installing 2 NRP's per joint with WTT to ~3000'. Monitor well with trip tank while running in - correct displacement.
3/21/2023 Continue to trip in the hole with scraper assembly, picking up 5" drill pipe and installing 2 NRP's per joint with WTT to 3290'. Monitor well with trip tank while
running in - correct displacement.;While filling pipe, H2S sensor at the bell nipple alarmed with 25 ppm. Shut in well and all personnel mustered. Notifications
were made. Plan to run in the hole and circulate the well over to FIW.;Continue to trip in the hole with scraper assembly, picking up 5" drill pipe and installing 2
NRP's per joint with WTT to 4333'. Monitor well with trip tank while running in - correct displacement.;Continue to trip in the hole with scraper assembly, picking
up 5" drill pipe and installing 2 NRP's per joint with WTT to 5273'. Monitor well with trip tank while running in - correct displacement.;Rig down WTT NRP
equipment from rig floor. Strap and tally 5" HWDP on deck. Change gear oil and oil filters on top drive. Troubleshoot gear oil pump pressure issue.;Pick up 5"
HWDP and continue in the hole. Tag top of liner with 5 Klbs at 5531'. PU 160 Klbs, SO 90 Klbs.;Trip out of the hole F/ 5531' T/ 5273' and rack back 5" HWDP
stands.;Trip in the hole picking up 5" HWDP F/ 5273' T/ 5456' and then stand back in derrick.;Change handling equipment, strap and tally 4.5" HWDP and rack
back in the derrick (4 stands);Re-position pollution pan in cellar and secure. Move jacking HPU out of cellar area and square up Jet heater on strong back. Clear
drain line under pipe racks.;Displace well to clean FIW. PJSM with production crew and walk shipping lines.
3/22/2023 Continue displace well to fresh FIW taking returns to production @ 2 bpm and total of 600 bbls;Adjust fluid level in TDS. Calibrate block height. Commission
auto driller, service TDS, DWK, blocks and crown. Check stroke counter on #2 mud pump and rod wash mtr failed. Work on Swaco stroke counter and Elmago
brake controller. Charge pump #1 mech seal failed. Work boat.;Pooh rack back 5" dp F/ 5456' T/ 287' while monitoring well on trip tank. New rod wash motor
arrived on helicopter.;Pull and rack back 6.5" drill collars. Lay down bit and scraper assembly. Work on replacing rod wash motor.;Replace check valve on
accumulator. Rebuild leaking blind ram 4-way valve on accumulator. Adjust bails and Fenner ring on top drive. Replace rod wash motor. Run lines from Mud
Pump #2 to shipping header for displacement.;Pick up and make up 9-5/8" x 3-1/2" Model D Packer with Tripoint rep. Mobilize additional NRP's to rig floor and
stage for trip in the hole.;Trip in the hole with Model D packer on 5 stands of 5" HWDP from derrick. Continue to trip in the hole on 5" DP, adding 2 NRP's per
joint on the first 3 stands. Adjust additional NRP's on trip in. Monitor well on trip tank for proper displacement. At ~ 4000'.
3/23/2023 Continue Rih slow w/ Tri-point 9-5/8" CIBP f/ 4000' t/ 5440' and Finish adjusting and installing NRP's;Establish parameters Up/dn 145k/100k and drop 1" ball let
fall for 30 min bring pump on line w/ no ball seat dn pump and wait additional 10 min bring pump on line w/ ball on seat and stage up pressure t/ sheer out @
3350 psi p/up and re-tag w/ 35k w/ Top of CIBP @ 5440' DPM;Prep for OBM chg over;PJSM w/ all involved and displace well f/ FIW t/ 9.5 ppg OBM @ 3.5 bpm
@ 450 psi and taking FIW returns to production and catching spacer in trip tanks;Continue and finish rebuild of pump on centrifugal transfer pump @ pill pit.
While finishing prepping rig floor for OBM and clean water out of pits and transfer spacer to RPM pit #3. Work boat. Circulate 3x hole volume to shear mud stage
up to 450 gpm, 2400 psi. Build and pump slug prior to pulling.;Complete rig acceptance checklist.;Trip out of the hole F/ 5400' T/ 3085', wiping pipe and cleaning
OBM from NRP's on trip out. Monitor well with trip tank and hole fill for proper fill.;Repair service loop sleeve. Clean rig floor and place absorb on walkways to
help mitigate tracking OBM throughout platform.;Continue to trip out of the hole F/ 3085' T/ 1935' at time of report, wiping pipe and cleaning OBM from NRP's on
trip out. Monitor well with trip tank and hole fill for proper fill.
3/24/2023 Continue to trip out of the hole F/ 1935' wiping pipe and cleaning OBM from NRP's on trip out. Monitor well with trip tank and hole fill for proper fill. Clean, inspect
and lay down packer setting tool.;Clean rig floor and dispose of OBM soaked waste. Troubleshoot elmagco brake fire control card.;Rig up and pressure test 9-
5/8" casing to top of packer at 5440' - 3500 psi for 30 charted min - good test initial test pressure 3648 psi, lost 58 psi over 30 min period. Test with 9.2 ppg
OBM. Troubleshoot elmagco brake fire control card.;Hold safety meeting with crew, MWD and WIS. Pick up and run in the hole with 9-5/8" whipstock and
window milling assembly T/ 365'. Pulse test MWD - good.;Run in the hole with 9-5/8" whipstock and window milling assembly T/ 5413' monitoring well on trip
tank - good displacement. Run in the hole at ~3 min per stand, checking NRP's on trip in.;Stage up pumps in 1 bpm increments to 10 bpm, 428 psi. Orient
whipstock to 35 LOHS with MWD and slack off to set whipstock. Trip anchor, engage slips and shear off mills - shear bolt went at 28 kbs. PU 152 Klbs, SO 97
Klbs.;Mill window in 9-5/8" casing F/ 5412' (4065' TVD) T/ 5421' (9') per WIS representative. 428 gpm, 1625 psi, 80 rpm, 13 Kft-lbs torque, 0-2 Klbs WOB, PU
152 Klbs, SO 97 Klbs, ROT 112 Klbs. MW in/out 9.3 ppg.;Troubleshoot top drive VFD fault.
3/25/2023 Continue troubleshoot top drive VFD Fault while circ at 428gpm @ 1600 psi @ 5419' w/ 240 lbs iron recovered expedite rig 169 electrician to platform for
assistance;Continue troubleshoot top drive VFD fault at reduced rate of 220 gpm @ 500 psi;Continue troubleshoot top drive VFD fault Manually L/dn two singles
and park starter mill @ 5410' w/ TOW at 5412' and top drive Low derrick for access and cease circ.;Monitor well on trip tank while continue troubleshoot top
drive fault w/ some tech support from NOV and I rig electrician via phone and rig maintenance and house keeping. Work boat - offload 2 Iso's of OBM.;Break out
top drive from stand to aid in troubleshooting. Continue troubleshoot top drive fault w/ some tech support from NOV and I rig electrician via phone and rig
maintenance and house keeping. Install FOSV in string and monitor well on trip tank.;Support personnel timed out. Perform rig maintenance and house keeping.
Perform weekly BOP function test. Will function blind rams on next trip out of the hole.
3/26/2023 Resume and Continue troubleshoot top drive VFD fault / was able to achieve and sustained 20 rpm w/ no faults / general house keeping and service equipment
throughout rig / found two abandon bare wires that were touching that ended up being hot and secured same;Continue troubleshoot top drive VFD fault / wait on
scope from steelhead / build OBM / general house keeping and service equipment throughout rig;Continue troubleshoot top drive VFD fault / take scope reading
and send reading To NOV tech support;Button up TDS and go through all functions and commission same. Stage rpms up to 100 rpm. Stop and screw into
string and torque up. Back out and re-screw into string. Pick up out of slips and stage up to 100 rpm. Set back in slips and attempt to back out - encoder and
VFD fault.;Continue troubleshoot top drive VFD fault / take scope reading of A & B signal at VFD and send reading To NOV tech support. Back out of string and
open top drive cover to get readings at encoder, get Z signal reading and send to NOV tech support. Work boat and offload 165 jts of 4.5" DP.;Support
personnel timed out. Perform rig maintenance and house keeping. Assist production crew with pulling failed water pump.
3/27/2023 Continue monitor well on trip tank and Resume and Continue troubleshoot top drive VFD fault w/ NOV tech support / Expedite parts from I-rig to Monopod /
Continue housekeeping and rig maintenance throughout rig;Troubleshoot top drive VFD fault with NOV tech support. Change pulse encoder interface card and
encoder isolator module.;Troubleshoot top drive VFD fault with NOV tech support. Break out top drive from string with rotary and attempt to index with spin mode
- encoder fault error. Prep top drive to remove and replace encoder in drive motor. install exhaust extension on vac system. Install back up HPU in
cellar.;General housekeeping and maintenance. Work boat - offload 2 Iso's from Granite Point.
3/28/2023 . Continue finish working boat M/V Endeavor - offload 2 Iso's from Granite Point took on total 187 bbls of 8.1 ppg obm to RMP tank #3 and pill pit . General
housekeeping and maintenance and resume. Troubleshoot top drive VFD fault with NOV tech support;Continue Troubleshoot top drive VFD fault with NOV tech
support. Attempting ID run / L/dn other single to get TDS to the floor and spin quill w/ chain tongs t/ capture scope reading / work M/V Discovery / Expedite NOV
FST from slope to Monopod / General housekeeping and maintenance;NOV FST on board platform orientation and safety meeting / Continue Troubleshoot top
drive Issue,;General housekeeping and maintenance.;General housekeeping and maintenance / install foam board insulation in cellar, Clean MP's and piping.
Clean out behind draw works.
3/29/2023 Continue rig maintenance, organization / Resume trouble shoot TDS issues w/ NOV FST / successfully completed the ID run / ran top drive at various rpm's w/
no issue / found rpm off 11 rpm working issue / found issue with cooling pumps programing and cycling chk system and flow switches.;Continue rig
maintenance, organization / Continue trouble shoot TDS issues w/ NOV FST / Calibrated and chk RPM good / found glycol hose quick connect loose in derrick /
opened hood NOV chk all connections found one loose / run continuity chks /;check shielding grounding / c/o encoder and check clearances-same problems
persist / FST and electricians timed out-shut down for the night @00:00hrs.;Continue rig maintenance, organization and cleaning / c/o cracked 45 deg. couplings
on poor boy flow line.
3/30/2023 Continue monitoring well on trip tank / Resume and continue trouble shoot TDS issues w/ NOV FST and tech support while preforming rig maintenance,
organization / Changed 3701 fault status to a warring status and tested TDS functions (ok) p/up std from V-door that was l/dn.;Expedite WIS hand back to
platform while staging up pump rate and warming mud.;Resume Milling window f/ 5421'TOW t/ 5426'BOW and 24' new hole t/5450'MD, While Nov FST monitors
TDS system via lap top. 105spm, 1600psi, 100rpm, 9k trq, p/u=125k, s/o=95k.;Polish window as per WIS rep., drift thru window with and without rotary and
pump-no drag. (105spm, 1600psi, 100 rpm, 9k trq, p/u=125k, s/o=95k).;pump 30bbl sweep out @102spm, 424gpm, 1500psi. 9.3PPG in /out. POOH 1std to
above window.;Perform FIT w/9.3ppg test mud to 932psi, for 13.7EMW for 30min. charted, 2.5bbl to reach pressure and 2.4bbl bled back.;R/d test equipment
and clear lines of OBM. Monitor well, Fill trip tanks and pump slug.;POOH f/5412' t/89', inspect window mills and l/d same, l/d DC and HW. Clean and clear rig
floor. Monitoring fill on trip tank.
3/31/2023 Continue l/d gauged and clean Mills and MWD assy, starter mill @ 3/16", fallow mill @ 1/8" and gauge mill @ 1/8", all within tolerances / while monitoring well
on trip tank.;Rih w/6-1/2" DC's t/ 273' Pooh l/d same, cleaning ID/OD and prep same for boat.;Clean and clear floor from tripping operations.;Remove wear ring
and wash out stack and well head w/wash tool @8.5 bpm and 50 rpm / Sent 48 hr notice for bope test and witness was waived by Mr. Jim Regg.;Close blinds
bleed down koomey unit change out 4 check valves repair leaks on unions and rebuild upper rams and choke line 4 way valves while working boat.;L/d 5"
HWDP out of mouse hole cleaning ID/OD and prep same for boat, move 4-1/2" HWDP to collar fingers.;P/U 4.5" 16.6# S-135 CDS-40dp and build stds in
mouse hole and rack in derrick. Hold spill drill and after action review, service rig-crown-block-Top drive-DW and ST-80.
4/1/2023 Continue P/U 4.5" 16.6# S-135 CDS-40dp and build stds in mouse hole and rack in derrick. total footage of DP in derrick = 15,877.49' / Production continue
reinstall A-5 Head on MTU #2.;Clear and clean rig floor and service rig.;Run two std in hole and attempt to M/up open hole sub to TDS for trial run / OD to large
for bell guide take measurement's clean sub and send in for Machining Rack back two stds / Assist production mech w/ MTU #2 work.;Continue to prep rig for
drill ready, Rig maintenance & housekeeping / Continue assist production mech w/ MTU #2 work having injector issues / NOV FST #2 arrived on location
@10:30 platform orientation and Electricians briefing Resume troubleshooting TDS Issue / Reinstall 1502 cmt manifold rig floor;Continue troubleshoot TDS
issue w/ #2 NOV FST and NOV tech support / Continue Assist production mech w/ injector issue on MTU#2 prime mover / Continue prep rig for drill ready / Pull
failed #1 trip tank pump and inspect same / continue go through DP thread protectors.;Continue troubleshoot TDS issue w/ #2 NOV FST and NOV tech support
until timed out and shut down for the night. Clean top deck around top drive VFD and hyd. unit.;Cont. prep for drill ready and maintenance, c/o spin wrench on
ST-80, paint fire cabinet stand, trouble shoot LVT power wash pump.
4/2/2023 Continue monitor well on trip tank Cont. troubleshoot TDS issue w/ #2 NOV FST and NOV tech support / Cont. prep for drill ready and maintenance / Put #2
MTU on line, still experiencing injector issue resolve issue on line and monitoring same.;Continued Troubleshoot TDS issue w/ #2 NOV FST and NOV tech
support / Reclaimed OBM from stack blew dn line / serviced choke manifold and kill and choke valves /;Prep for BOP test- m/u test jts and floor valves w/test
cap, install test cap on top drive. Attempt to set test plug, stopped approx. 1ft high. Pull LDS and observe bottom of test plug, attempt again setting down harder-
no movement. Pull multiple LDS and attempt again-no movement.;Remove test caps and valves from test jt and cap from top drive and kelly up on test jt., set
down with 20k to seat test plug. Re-install floor valves and test caps, fill stack with H2O.;Test all 13-5/8 5m BOPE t/250psi-low and 3500psi-high for 5min. on
chart as per AOGCC and Hilcorp procedure.
4/3/2023 Continue test bopes as per AOGCC regulations on 4-1/2" and 5" test jt 250L/3500H w/ one FP on blind rams and fail on CMV # 6 / Resume trouble shooting
TDS issues w/ NOV FST and NOV tech support.;Unable to rebuild do to exhausted part supply of discontinued valve type, 1 spare on platform, 2nd valve flown
out. / Replace CMV #6 and # 7 w/ new valves / Continue trouble shooting TDS issues w/ NOV FST and NOV tech support.;Cont. to replace CMV #6 and # 7 w/
new valves, torq and grease same.;Resume testing Bop as per AOGCC regulations all brakes on choke manifold and new valves tested 250L/ 5000H 5/5 on
chart.;R/d testing equipment , break floor valves and test subs and l/d same. Pump out stack to pill pit #2 and transfer to RPM tank #2.
4/4/2023 Finish pumping out stack to pill pit #2 and transfer to RPM tank #2 / Resume troubleshooting TDS issue w/ NOV FST and NOV tech support / General rig
maintenance and house keeping.;Continue troubleshooting TDS issue w/ NOV FST and NOV tech support / General rig maintenance and house
keeping.;Received orders from town to continue ahead with drilling operation's / Contact service personnel and mobilize same back to rig / Currently on weather
hold set up boat call out at 15:00 hrs if not flying / Continue troubleshooting TDS issue w/ NOV FST and NOV tech support.;Continue troubleshooting TDS issue
w/ NOV FST and NOV tech support / Install wear ring / tie wire and secure bolts on encoder access door and drive mtr inspection gate and preform complete
inspection of TSD.;Work boat off load service hands / Prep and p/up BHA #2 w/8-1/2" bit and Motor assembly. Shallow pulse test @725'md, 457gpm, 1340psi,
39% flow-good signal.;RIH f/725"md t/1720'md.;Fill pipe and circ. surf/surf., 450gpm, 1400psi, 40% flow, p/u wt=66k, s/o wt=30k.;RIH f/1720"md t/3594'md.;Fill
pipe and circ. surf/surf., 440gpm, 1480psi, 37% flow, p/u wt=104k, s/o wt=93k, rpm=14, trq=6k.;RIH f/3594'md t/4645'md.;Fill pipe and circ. Bottoms up.,
440gpm, 1740psi, 40% flow, p/u wt=110k, s/o wt=96kk, rpm=20, trq=6-7k.;RIH f/4645'md t/5378'md.;Fill pipe and circ. Bottoms up., 440gpm, 1950psi, 40% flow,
p/u wt=159k, s/o wt=90kk. Get SPR's pmp #1 30spm/440psi, 40spm/500psi, pmp #2 30spm/400psi, 40spm/480psi @5445'md/4082'TVD w/9.3# OBM.;Drill/Slide
f/5450' t/5500'+-approx. as per DD and wp01. 450gpm, 1950psi, 40% flow, 12k WOB, 50ROP+-.
4/5/2023 Continue Drill/Slide f/5490' t/5689' as per DD and wp01. 450gpm, 1950psi, 40% flow, 12k WOB, 8-9k TQ 50ROP+-.;Circulate and reciprocate hole clean @
457gpm, 1890psi, 40% flow, 40 rpm, 9-11k trq, p/u wt=123k, s/o wt=103k.;POOH f/5698' t/5300', monitoring fill on trip tank.;Clean and clear rig floor from wet
trip. Simop-Fix Brake water cooling system, radiator failed. Put cooling pump in bypass, Dyno-Matic started spilling out the vent overflow, shut down. Decision
made to plumbed in rig glycol heater to replace radiator and take cooling pump out of bypass.;Slip/cut drill line 95ft. cut. Adjusted cooling water to Dyno to 3-1/2
turns closed on left/right. Simop-plumbed brake water cooling tower into rig glycol heater to replace radiator and take cooling pump out of bypass.;Simop-
pumped 35bbl dry job...Run top drive up and down fast while adjusting flow on brake water cooling on Dyno-Matic to max without running out the vent overflow.
(3-1/2 turns closed on left and right valves).;POOH f/5300' t/512', stand back HWDP and flex DC, down load MWD, Break off bit and L/D motor.;Stand back
HWDP and flex DC, down load MWD, Break off bit and L/D motor.;Distance to plan: 16.1ft, 3.1ft high and 15.8ft left. Projected to current TD@5689ft.
4/6/2023 P/U BHA#4 8-1/2" Geo-pilot assy., upload MWD and shallow pulse test w/Haliburton DD/MWD t/536'md.;TIH f/536' t/5369'md. Monitoring displacement on trip
tank.;Service rig-lubricate top drive, crown, drawworks, and ST-80. Top drive lube oil low/foamy, topped off w/150w.;Crew change out, new crew on-boarding
w/production. Gather crew and show them the area's they are responsible for: shakers/vacuum unit, pumps, cellar, brucker etc. and inform them of Hilcorp
expectations. Had Driller make 3 connections w/crew to show qualification.;RIH f/5369' t/5497'md, w/5-10k set down, trq=5-6k drag w/rotating 10rpm, work slow
thru window w/geo-pilot non-rotating sleeve.;Wash/Ream f/5497' t/5513'md w/25k set down w/geo-pilot non-rotating sleeve, @ 40rpm, 5k trq, 350gpm,
1220psi.;C/O shaker screens from 220's to 170 on #1 and 100's on #2, could not get up to drilling rates as they were.;Wash/Ream f/5513' t/5689'md w/25k set
down w/geo-pilot non-rotating sleeve, @ 40rpm, 5k trq, 450gpm, 2020psi.;Drilling 8-1/2" hole f/5689' t/6000', @100rpm, 7k trq, 450gpm, 2020psi, 12k wob, avg
ROP=50fph.;Distance to Well Plan wp01: 19.5ft; 5ft high; 18.8ft left...Total bit Krevs:18.
4/7/2023 Drill 8-1/2 hole w/steerable assy. As per DD/wp01, f/5994 t/6679md, 140rpm, 500gpm, 2500psi, 8k trq, 10k wob, p/u wt=140k, s/o wt=96k, rot wt=110k. Back
reaming every std and sweep hole every 500.;MTU #2 down loud noise heard by drilling mechanic, drilled at diminished capacity for .5hrs. Production
notified.;Circ. B/U and hole clean @500gpm, 80rpm, 2500psi. Get SPRs, monitor well.;POOH on elevators t/5365 monitoring fill on the trip tank. Perform well
control drill-valve stabbed 34sec/total 3:48sec.;Service rig- top drive, drawworks, crown, block. Re-work containment tarps in cellar around bell nipple, clean
BOPs, cellar and rig floor from containment failure/wet trip.;RIH t/6679', wash down last 2 stds tight @ 6488', 6529', 6540', 6580', 6590'. 420gpm, 2090psi,
20rpm, 4-9k trq.;Stage up pumps until to shear mud,Cont.drilling 8-1/2hole w/Geo-pilot as per DD/wp01 t/6743 @430gpm, 2060psi, 140rpm, 8-9k trq, 10-12k
wob.;Cutting out running vacuum system and cuttings boxes, pull off bottom and circ. slow while cutting totes are switched out and shute sucked
out.;Cont.drilling 8-1/2hole w/Geo-pilot as per DD/wp01 t/6850 @530gpm, 2830psi, 130rpm, 8k trq, 13k wob, avg. ROP=57ft/hr.;Distance to Well Plan wp01:
19.6ft; 2.8ft high; 19.4ft right...bit Krevs=110.0.
4/8/2023 Drill 8-1/2 hole . As per DD/wp01, F/6850' T/7577', 727' @60 FPH average, 140rpm, , 9-10k tq, 11-20k WOB, 550gpm, 3000psi, P/Uwt=150k, SOwt=95k,
ROTwt=115k, MW 9.7, Vis 58, Max gas 324.;Back reaming full stand. Finished Directional work at 6800'.;Drill 8-1/2 hole . As per DD/wp01, F/7577' T/7715'. 138'
@69 FPH average, 137rpm, , 9-10k tq, 17k WOB, 550gpm, 3000psi, PUwt=150k, SOwt=95k, ROTwt=115k, MW 9.7, Vis 68, Max gas 469.;Pump sweep 20ft off
bottom while drilling last std down, finish circ./reciprocating out sweep @550gpm, 3000psi, 44% flow out, 77rpm, 7-9k trq. Shakers heavy increase in cutting
@B/U, circ. clean as per Mud Engineer. Get SPR's. Monitor well f/5min.-static.;POOH on elevators f/7715' t/6485', monitoring fill on trip tank. Tight spots
@6985', 6928', 6860' pulled 20-25k over.;RIH on elevators f/6485' t/7715', monitoring displacement on trip tank. Ratty spots @6813'-6859', 6934'-6956', Kelly up
and wash down last std. Stage up pumps due to thick mud and packing off: f/250gpm t/540gpm, 1300-3000psi. Ratty spots @7625'-7715'. 5ft fill.;Drill 8-1/2 hole
. As per DD/wp01, F/7715' T/7940'. 225' @ 50FPH average, 137rpm, , 9-10k tq, 17k WOB, 550gpm, 3000psi, PUwt=150k, SOwt=95k, ROTwt=115k, MW 9.7,
Vis 68, Max gas 469.
4/9/2023 Drill f/7940' t/9034' as per DD/wp01, 1094' drilled @ 64fph avg. ROP, 545gpm,3360psi, 12-20k wob, 140rpm, 10-12k trq, p/u wt=200k, s/o wt=115k, rot wt=122k,
421 max gas. Sweep hole every 500' and back ream every std.;Sweep hole and circ./reciprocate until clean @544gpm, 3290psi, 140rpm, 76rpm, 9-12k trq.;Get
SPR's, fill trip tanks, monitor well-static.;POOH on elevators f/9034' t/8560, monitoring fill on the trip tank. Tight spot depth: 8912'-8872', 8812', 8749', 8710'-
8580', 8592'-8580', 8583'-8559'. Pump 25bbl 11.8ppg slug and chase w/15bbl.;Cont. POOH on elevators f/8560' t/5300', monitoring fill on the trip tank. Tight
spots depth: 8538'-8468', 8453', 8374', 8337', 8291', 8128', 7921', 7847'-7801', 7713', 6536', 6495'.;Found a wash out on top of std 14, l/d same and p/u last jt of
5"dp, re-install NRP's.;Circulate bottoms up @ window 424gpm, 1800psi.;Distance to Well Plan wp01: 3.78ft, 1.1ft high, 3.6ft left. Total Krevs: 342.0.
4/10/2023 cont. circ. B/U at the window 5369'md, 450gpm, 1800psi. flow check well-static, pump slug.;POOH f/5369' t/72'. monitoring fill on the trip tank.;BHA, c/o bit,
down/up load MWD, check oil in geo-pilot. function blind rams w/out of the hole. Monitor hole w/blind rams shut on choke manifold while c/o koomey manifold
regulator. RIH w/ NMDC, and HWDP,jars t/167'.;Function test top and bottom variable rams on 4.5"DP.;TIH f/167' t/5380', while monitoring displacement on the
trip tank.;Re-set pop-off f/4000psi t/4500psi, service blocks and top drive.;circ. condition mud, stage pumps up t/500gpm, 2570psi.;TIH washing and reaming
f/5380' t/6470', work stds down and wash and ream as needed, 325gpm, 1770psi, 22rpm, 6k trq, 34% flow . Packing off pull up 1 std and rack back t/6350'.;Find
free point and stage pumps up to 550gpm, 3200psi, 9rpm, 6k trq, 45% flow, circ. b/u, heavy ycutting on b/u.;Work tight hole f/6310' t/6250'.
4/11/2023 Wash & Ream F/6330' T/ 6580. Stage up pumps to 350 GPM. 80 RPM, 8K TQ. MW coming back 9.9ppag, Vis 90+. Getting lots of coal & Fines back through
btm up. Circ clean.;RIH on elevators F/ 6580' T/ 6770'. Set down. Took some work to establish circ due to pack offs. Stage up pumps to Wash & Ream F/
6770' T/ 7140' @ 300-450 GPM. End of turn 6800' +/-. Just fine cuttings and smaller coals in returns. Not much. Circ clean.;RIH on elevators. F/ 7140' T/
7636'. Tag up in big coal. Wash & Ream F/ 7636' T/ 7980'. 80RPM, 9000 TQ, 2500 PSI at 450 GPM. Work Geo pilot through coals. Fighting through pack
offs. Pump at 350-450 GPM 80 RPM working through. MW 9.7, Vis 78, No Losses.;Normal reaming cuttings at shakers while working down except for BTM up
from 7636' After establishing circ lots of smaller coals.;Cont. to Wash & Ream F/ 7980' T/ 8377'. 80 RPM, 9-10K TQ, 2500 PSI at 450 GPM. Work Geo pilot
and stab 53' back from bit through coals. MW 9.7, Vis 70, No Losses with normal reaming cuttings at shakers.;Cont. to Wash & Ream F/ 8377' T/ 8906'. 80
RPM, 8-13K TQ, 2500 PSI at 450 GPM 80 RPM working through coals. MW 9.7, Vis 70. After stab passed through coals at 8500' reamed down to 8906' with no
issues.;At 8906 started to set weight and tq stall at 15K tq packing off, attempted to pick up out of tight spot unable to with 30K overpull. Shut down pumps and
rotary bled off pressure. Worked pipe up and dwn with 20-30 and 50K over pull and 50K down establishing a free point.;Staged pumps slowly to 450 GPM, 80
RPM and allowed hole to clean up. Prior to moving forward.;Wash and ream down to 8920' Getting pack offs around Geo pilot. Continue to work stand and
Ream connection. 500 GPM, 140 RPM, 11K TQ.
4/12/2023 Continue to Wash and Ream F/ 8835 to 9034 at 500 GPM, 140 RPM 11-14K Tq 2-4K WOB. MW 9.5ppg, Vis 68. Tag btm on depth. Pump sweep around with
no increase in cuttings & back on time.;Drill ahead F/ 9034 T/9458' 424' @ 56 FPH average, 550 GPM, 3500 PSi, 140 RPM, , TQ 13K, WOB 5-15 9.5 MW,
Vis 68 & 10.3 ECD. Max Gas 600 Units.;Cont. Drilling F/9458' T/9744' 286' @ 48 FPH average, 550 GPM, 3485 PSi, 140 RPM, TQ 11-13K, WOB 7-15 9.5
MW, Vis 65 & 10.3 ECD. Max Gas 212 Units.;Cont. Drilling F/9744' T/10056' 312' @ 62.4 FPH average, 550 GPM, 3520 PSi, 140 RPM, TQ 11-13K, WOB 5-
15 9.5 MW, Vis 65 & 10.3 ECD. Max Gas Units Distance to plan- 3.78', High 1.1', Left 3.6'.;Pump 20 bbl 9.6 ppg 110 vis sweep, 550 GPM, 3520 PSi, 140
RPM, TQ 11-13K. Reaming from 10056' to 9963'. Sweep back on time with no increase in cutting returns.;Metal recovered Daily = # 52
Metal recovered Total= # 757
Total shipped cutting totes = 62
4/13/2023 Monitor well, POOH on elevators F/ 10055 T/ 8900. 10-20 Bobbles and overpulled up to 50K in coals & Shales. Work past.;. RIH on elevators F/ 8900 T/ 9525.
Tag up in coal. Unable to work past. Work pipe to free point & Work on establishing circulation working through pack offs. Stage up pumps to 450 GPM, 80
RPM, 2500 PSi. , Ream out stand F/ 9484 T/ 9525.;Wash & Ream F/ 9525 T/ 9732 without issues. 450 GPM, 2500 PSI, 80 RPM, Pack off at 9732'.;Work
through pack offs in coal at 9732-9770. Keeps packing off around Geopilot. Bring RPMs to 150 & Able to ream through slow with out pack off. Back ream back
through and fight the same issues with Geopilot housing pack offs.;Wash and ream working string to keep Packing off around Geopilot. F/ 9770' T/ 10055'. @
150 RPM, 450 GPM, 11K TQ. UP/DN/ROT 225/100/125. MW 9.5, Vis 61.;Staged up pumps to 550 GPM, 3510 PSI, 150 RPM, 12K TQ. Reaming from 10055' to
9960' circulating a BU prior to drilling ahead.;Drill ahead F/10056' T/10338' 282' @ 63 FPH average, 550 GPM, 3585 PSi, 140 RPM, TQ 13K, WOB 10-15
9.5 MW, Vis 60 & 10.4 ECD. Max Gas 274 Units PU 225K, SO 100K, ROT 135K.;Drill ahead F/10338' T/10700' 362' @ 60 FPH average, 550 GPM, 3660
PSi, 140 RPM, TQ 13K, WOB 10-15 9.6 MW, Vis 62 & 10.5 ECD. Max Gas 528 Units PU 225K, SO 105K, ROT 135K Distance to Plan- 3.90', Low 1', Left
3.8'.;Pumped 20 bbl 9.5/110 vis sweep around at 10524', back on time with no increase in cuttings.;Metal recovered Daily = # 18
Metal recovered Total= # 775
Total shipped cutting totes = 76
4/14/2023 Drill ahead F/10700' T/10799' 99' @ 28 FPH average, 550 GPM, 3700 PSi, 140 RPM, TQ 13K, WOB 10-15K 9.6 MW, Vis 62 & 10.5 ECD. Max Gas 265
Units PU 225K, SO 105K, ROT 138K.;. Lost 2K TQ taking wt. Back ream up 13 and Geo pilot hung up in coal. Make several att to back ream but packing off at
geopilot. Over pull up to 80 over working back down. Geo pilot hung up at 10785. Lower flow rates to 450 Increase RPM to 150. Work wt down getting slight
movement.;Ream out stand and work our way back in to the coal 5 at a time until clean. Circ clean. Small ground up coal in returns.;Drill ahead F/10799'
T/10895' 362' @ 38 FPH average, 550 GPM, 3700 PSi, 140 RPM, TQ 13K, WOB 10-15K 9.6 MW, Vis 62 & 10.5 ECD. Max Gas 520 Units PU 225K, SO
105K, ROT 138K.;Drill ahead F/10895' T/11088' 362' @ 38 FPH average, 550 GPM, 3700 PSi, 140 RPM, TQ 13K, WOB 10-15K 9.6 MW, Vis 62 & 10.5
ECD. Max Gas 572 Units PU 225K, SO 105K, ROT 138K Distance to plan- 2.53', High .62', Left 2.45'.;CBU at 550 GPM, 3730 PSI, 140 RPM, TQ 13K.
Pumped sweep with no increase in cuttings back on time. Get final survey and SPR's, Flow check well- static.;BROOH F/11088' T/10565' working through
slight pack-offs in coals. 500 GPM, 3250 PSI, 140 RPM, TQ 11-13K, 9.7 MW, Vis 64 & 10.5 ECD. Max Gas 599 Units PU 235K, SO 105K, ROT 135K.;At
10565' encountered torque swings from 13-18K and packing off, worked or way down to 10585' reducing pump rate to 340 GPM. Observed no return flow, shut
down pumps and slowed RPM's down to 90 while working down observing pressure decreasing and flow intermittently returning. Worked down to 10599'.;While
ROT at 90 RPM we Pick up and wt spiked to 267K ( 132K over ). Felt jar at surface and observed hook load missing 100K, and TQ was 5-6K. Turned on
pumps at 550 GPM, 600 PSI. PU 125K, SO 100K.;Reamed in the hole slowly at 150 GPM, 10-20 RPM, TQ 4-6K to tag fish. Tagged fish 10' in on 5" stand #28
with 5-10K down, 2-5K TQ spikes and up to 200 psi pressure increase. Pressure and wt falling off.;POOH on elevators observing calculated displacement.
Recovered 28 stds of 5" DP and 35 stds of 4.5", 11' fish for a total of 5819.92' recovered pipe. 2 good size rocks wedged inside fish from set down. See pics in
O-drive Left in hole all BHA, 44 stds of 4.5 DP and Fish for a total of 4799.67'.;Metal recovered Daily = # 0
Metal recovered Total= # 775
Total shipped cutting totes = 92
4/15/2023 Inspect fish and call out fishing tools. Clear and clean rig floor and cellar from wet trips. Service ST-80 and clear pipe deck for fishing tools.;Service accumulator
and trouble shoot drips. Cont. cleaning in pump room and around shakers. Load fishing tools on pipe deck. Tighten glycol connection on top drive.;PJSM MU
fishing BHA #6 - overshot bowl and grapple cut lip guide, bumper sub and oil jars. RIH with 9 jts of 6 1/4" spiral collars. MU accelerator and xo to 323'.;RIH with
11 stds of 4.5" 16.6# CDS-40 DP to 1363'. Swap out elevators and remove OH sub from top drive. Cont. RIH with stds of 5" 19.5# NC-50 DP to 2869'. Held well
control drill, well secured in 42 sec.;Cont. RIH with fishing BHA #6 F/2869' T/5314'. MU up FOSV and top drive to stump and prep for Cut & Slip. Clean rig floor
from burp through dp while RIH with overshot.;R/U block hanging line and hang off blocks Cut & Slip drilling line. Cut off 11 wraps ( 79' ) of drill line Check crown-
o-matic. Submitted 48 hr notice to the state for BOPE test.;Circulate and condition mud staging up pumps. 300 GPM, 625 PSI, Max gas 139 units.
4/16/2023 Finish warming up mud at 450 GPM, Wash down F/ 5300' T/ 5412'. Wash through shoe to 5460'. Start taking wt. Rot at 20-50 RPM working through set downs
and slight pack offs F/ 5460' T/ 5829'. 450 GPM 40 RPM, 8K TW, 1250 PSi.;Set down on fish at 5829' Tag fish slow Rot. Stall out at 13K Set down 50K several
times. Saw pressure increase. Shut down pumps Hamer down several times to engage grapple. Over pull starting at 50K over. Try to circ and pressured
up.;Work pull up to 250. Fire jars. Wt fell off and pressure also. Gained Returns. Attempt to engage fish again. Stall outs and no over pulls. Pull up 30' & Wash
& ream back down working over shot through pack offs. Tag fish at 5829'. Stall TQ at 13K. Set down 50K Several times.;P/U to 200, working wt up to 250. Fire
jars at 250, 325 three times. Pump pressure not showing we have fish with full returns. Continued to pull up hole and wt started falling off to fishing BHA up wt.
Decided to POOH & Inspect grapple.;. Pull out of the hole two stands then pump out to shoe getting 20-50K over pulls. Still over pulling at shoe. Circ and pull
slow through shoe. Had to Rot 1/2 turn twice to get through shoe.;Circ btm up at shoe at 500 GPM. Working pipe F/ 5390' T/ 5310'. Current wt and pressure the
same as on the trip in.;POOH on elevators F/ 5390' T/ 5130'. Started to get over pulls in casing. Circ sweep around with 30 RPM, 6500 TQ 600 GPM, 1800 PSI.
Got good amount of jagged rock and coal at shakers ranging from 1/2-3/4 Size. Circ until clean. Working full stand.;Monitor well- static, Fill trip tanks, POOH
F/5130' T/4270', stopped and removed broken hose from ST-80, Cont. out of the hole F/4270' T/3700' and replaced hose on ST-80. Cont. POOH F/3700'
T/2574'.;POOH on elevators F/2574' T/323'. L/D Accelerator, rack back 3 collar stds, L/D oil jars and remove cut lip guide. Cut lip guide starting edge was bent
in closing I.D from 7" to 6 1/16" O.D. of overshot still remained 8 1/8". Grapple showed no indication fish was latched.;Clear and clean rig floor from wet trip.
4/17/2023 M/U fishing BHA #2. 8 1/8 Burn shoe, Overshot EXT, Overshot bowl with Grapple, XO, Bumper sub, Jar, 9 6 1/8 DC, Xo, Accelerator. to 327'. Flowing out of
collars while RIH. Shut down and clean up derrick and service lines.;RIH with 11 Stands of 4.5 DP, utilize thread protector & valve to keep from flowing mud out
of stand while RIH. Change handling equipment. RIH on 5'' DP M/U TD to each stand while RIH to prevent mud flowing out of pipe while RIH. RIH to shoe at
5225''. Circ & condition mud before going in open hole.;Circulate & Condition mud before going in open hole at 5225. Stage up pumps to 500 GPM. ROT &
Reciprocating pipe.;Wash & Ream in hole F/5225' T/ 5400'. Taking wt off and on F/ 5325' T/ 5400'. Working through pack offs. Rocks getting along side of
our 8 1/8 over shots. Circ 250-500 GPM, 20-50 RPM, Getting stall outs at 13K. Work pipe to get free. Over pulls up to 50K over.;Slow pumps to 250 GPM & try
and slide through window. Stacking out at 5412'. TOP of window. Try and roll in with 1/4 turns. No luck. Still getting 25K drag up.;Work pipe down to to 5412'.
TOW. Stacking wt. Stand back stand and P/U Single for working room. P/U above window to & bring RPMs to 50 to get debris past us. Still getting TQ & Drag.
5353' Discuss with drilling engineer and decide to try and push in to open hole to clean up.;Attempt to work debris in to open hole. Tag up in window at 5414'.
Work pipe up and down attempting to push through window. Making 1/4 turns in pipe. Over pulling coming up. Discuss with drilling engineer.;Rot down to set
down at 5418'. Try and jog through. Not making any footage. Try and ream through at 20-50 RPM. No footage made. Got hole cleaned up no additional torque
or drag. Still unable to get through window.;Circ HV sweep around at max rate 650 GPM, 2250 Psi. Got busted up 1/2 size rocks and some coal back in
returns. Not much.;Pump Slug & POOH F/ 5400' T/ 3324', at 3424' encountered tight spot with 40K over. Went down with no issues or drag. Came down and
allowed crews to change out. PU 110K, SO 80K.;Pulled up into tight spot at 3324' two more times with no success. MU top drive and rotated at 20 RPM's going
past with a quick torque spike of 14K and then no other issues. PU weights didn't change once past 3324', Cont. POOH on elevators F/3324' T/333', L/D
accelerator, racked back 3 stds of DC.;Pulled oil jars, bumper sub and overshot grapple assembly to rig floor finding whipstock wedge inside burn shoe. L/D
whipstock and burn shoe. L/D oil jars and bumper sub.;Clear and clean rig floor after trip out.
4/18/2023 Continue Clean rig floor organize tools and equipment service ST-80.;Retrieve wear ring and flush out stack and well head w/ wash tool @ 500 gpm / Pump out
OBM and fill stack w/ FIW.;M/up 4-1/2" test joint and set test plug.;Test BOPE per Hilcorp / AOGCC 250/3500 psi for 5/5 charted min each. Test Annular with
4.5" test jt. UPR/LPR with 4.5" and 5" test jts. Perform drawdown test - good- 200 PSI= 61 sec, Full system pressure = 226 sec. Nitrogen Ave= 6@2400 PSI.
Witness waived by AOGCC rep Jim Regg.;R/D testing equipment and pull test plug. L/D 5" test jt and pump FIW from stack. Line up on trip tank and monitor
well via trip tank.;L/D 4.5" DP utilizing mouse hole to keep pipe dry. No solid end protectors. L/D 17 out of 67 stds.
4/19/2023 Continue L/D all the 4.5" DP out of derrick utilizing mouse hole to keep pipe dry. L/D total of 201 jts out of derrick cleaning ID and OD;Set wear ring;P/up M/up
Bha#1 = 8-1/2" RR roller cone bit + 9-5/8" scraper assy and 3 DC to 287';P/U 3 singles 5" 19.5# DP, jars and 9 more 5" 19.5# DP to 698'. Cont. RIH on elevators
F/698' T/5397'. Worked scrapper from 5110' to 5200' 3 times, PU 135K, SO 90K,
Worked boat- sent out 210 jts of 4.5" DP, 1 jt 4.5" HWDP and off-loaded 118 Jts of 5" 19.5# DP and 21 5" 49.9# 5" HWDP.;Condition mud staging pumps up to
550 GPM, 1670 PSI, max gas 486 units for 2 full circulations to thin back and lighten mud.
Pumped 30 bbl Hi-vis sweep- no increase in cutting returns. Monitored well- static. Pumped dry job.;POOH F/5397' T/287' inspecting NRP as per rep. L/D jars,
Sim-ops removed all the 4.5" CDS connection XO's, FOSV and Dart valve from rig floor.;Rack back 3 stds of DC, remove bit, bit sub and scraper.
4/20/2023 Finish l/dn inspecting Bha #1 good / clear clean floor / service and inspect TDS and chg out hose on same;P/up and M/up Bha #2 = Tri-point 9-5/8" X 3-1/2"
Model D packer w/ bull plug installed + 9-5/8" model D setting sleeve + 9-5/8" model D setting tool + XO + XO + XO = 15.43';Rih w/ model D packer on 5" DP
out of derrick slow 1-1/2- 2 min std t/5095';New crew on board Platform orientation and PTSM / Crew change out and walk dn of all drilling areas and
equipment;Drop ball and Continue rih f/ 5095' and put packer on depth @ 5145' establish parameters up/dn 125/95k / Pump ball on seat and start to pressure
up and seen two shifts at 900 psi falling to 700 psi each time / continue to pressure up t/ 3500 psi w/ no sheer out calculated @ 2800 psi;Continue to pressure
up t/ 4100 psi still w/ no sheer out / continued bleed off and pressure up many times w/ no sheer out \ unable to go dn past set depth just stacking weight w/ 2' of
free travel up / Attempt reverse ball off seat and possible clear debris w/ NRP very close to annular element;w/ not much luck \ Re pressure up t/ 4100 psi and
bleed off a few more times w/ no joy \ discuss options w/ town and decided attempt pull up past a casing collar / P/up 7' w/ no drag and rih and set dn w/ 35k at
set depth / Pick up again 7' to bare pipe and shut in and attempted informal casing;Test by pumping dn back side t/ 3600 psi w/ 6 bbls and monitoring a 150 psi
bleed off in 5 min \ Relay information to town and discuss options;R/up reversing lines and attempt to reverse 1" ball to surface, staged up pumps to 5 BPM, 420
PSI for 3 full DP volumes. Observed ball off seat at 1425 PSI, did not find ball at surface. R/up and circulated down the DP seeing an instant pressure increase
at 1 BPM, 2950 PSI;pressure slowly started falling off. Was able to get to 7 BPM, 2670 PSI.;P\U single for space out. Pressure test 9 5/8" CSG and Model D
Packer to 3500 PSI for 30 charted min - good test. R/D testing equipment and blow down surface lines.;Walked driller and floor hands through line up on filling
the trip tank. Pumped 20 bbl dry job and L/D single;POOH F/5091' to surface. L/D running tool. Sleeve functioned fully to release packer. No definitive answer
seen at surface as to why ball seat didn't shear.;Clear and clean rig floor and prep deck for P/U pipe.;Total shipped cuttings totes= 99
Daily metal recovered= 0 #
Total Metal recovered= 805 #
4/21/2023 P/up RR 6" mill tooth bit + bit sub and rih p/up rabbiting and strapping 6 jts of 5" HWDP + 6-1/2" Jars + 5 jts of 5" HWDP and 45 jts of S-135 19.5# DP f/ deck to
1785';Continue p/up rabbiting strapping and rih w/ 5" S-135 19.5# DP F\ 1785' T\3988' total 5" in hole and derrick = 9396.55';Brake circulation and stage up
pump t/ 550 gpm @ 550 psi and circ btm/up \ flow chk static \ pump dry job;Pooh racking back;Clear and clean rig floor, Hold PJSM for Whipstock BHA #2;Make
up TM and DM collars and pump through at 350 GPM, 650 PSI to check pulse tool. L/D TM/DM assembly. Wasn't able to get detection due to lack of
pressure.;M/U tri-mill, running tool, 5" HWDP flex jt, MCBPV and float sub. Install float and verify direction. M/U TM/DM collars and scribe ( 278.83 Deg offset ).
Close blinds and P/U Hyd. set Whipstock with tugger and RIH. Install false bowl open blinds and set on rotary table.;Install 55K shear pin, nozzle plugs and Hyd
hose. RIH and Break MCBPV, poor in oil and install piston, torque back up and RIH. RIH with 3 stds of DC and 3 stds of 5" HWDP. P/U 1 single of 5" DP and
RIH to 690'.;RIH with Whipstock BHA #2 on 5" stds of DP F/690' T/2565', running speed 2-3 min a std as per wellbore rep. Filled pipe and performed a shallow
pulse test @ 2565', 400 GPM, 1250 PSI;Cont. RIH with Whipstock F/2565' T/3025'
4/22/2023 Cont. RIH with WBI 9-5/8" Hydraulic set Whipstock F\ 3025' t/ tag @ 5143' w/ 5k x2;Establish circulation and orientate and cycle pumps to initiate set and
pressuring up to 3000 psi and setting anchor on 5th cycle @ 47deg LOHS working weight t/ 50k over and sheered @ 55k dn wt / brake hose and mill stubs and
establish parameter's;Mill window f/ 5115.53' t/ 5122' @ 400 gpm @ 1810psi 80 rpm w/ 8-15k TQ w/ 9k free TQ off btm up/dn/rot 147/98/114k;Continue mill
window f/ 5122' t/ 5129.55' w/ 274# iron recovered thus far;Mill Rat hole t/ 5150' at 400 GPM, 1768 PSI, 80 RPM, 7-13K TQ, max gas- 237 units. Worked
through window multiple times while rotating with no issues. Worked through window with no rotation with and without pumps with no issues.;Pump 20 bbl hi-vis
sweep 395 GPM, 1705 PSI, 35 RPM, 7-8K TQ. Stayed in CSG once sweep was out of OH. No increase in cuttings back on time.;Rack back std. R/U and
perform FIT to 815 PSI, EMW= 13.7 ppg, MW in/out= 9.7 PPG, Pumped 2 bbls and bled back 1.8 bbls, Monitored well= static;Pump dry job and POOH F/5101'
T/1586' inspecting NRP's on the way out.;Cont. POOH F/1586' T/690';L/D single of 5" DP, Rack back 3 stds of HWDP and DC. Pull up and gage mills (Lead
mill= 1/4" under, Follow mill= 1/8" under, Dressing mill= 1/16" under, All within WBI mill tolerance). L/D flex jt, shift tool and tri-mills.;;M/U bit, bit sub with float
and RIH with 3 stds of DC's. Poor some base oil inside and POOH L/D 6 of 9 drill collars wiping inside with ball prior to L/D.;Total cutting totes shipped= 102
Daily metal recovery = 603 #
Total metal recovery = 1463 #
4/23/2023 Continue l/dn DC's cleaning ID and OD Brk dn bit and bit sub;Remove wear ring;P/up wash tool and wash out and flush well head stack and lines. Reinstall wear
ring;PJSM p/up bha #4 RR 8-1/2" bit and mtr assy;Rih out of derrick w/ bha #4 ill pipe @ 2300' and test tools good / continue rih t/ 4245';Platform Drill / well
secured / all mustered and accounted for and then proceeded to abandoned platform drill \ all personnel went to correct bucker capsule / Held
debriefing;Resume RIH F/4245' T/5110', Circulated and warmed up mud. Oriented TF 47 deg LOHS to exit window. RIH F/5110' T/5150' with no
issues.;Slide/Rotary drilled F/5150' T/5346'-196' Ave ROP 33' FPH at 475 GPM, 2300 PSI, 10-18K WOB, 40-60 RPM's, 7-10K TQ, Max Gas- 362 units.;Hit a
hard spot at 5345' staging WOB from 10-18K with slow drill off. P/U off bottom and shot survey obtaining our first clean survey verifying good separation from
CSG;Pumped a 20 bbl Hi-vis sweep around, 475 GPM, 2269 PSI. Sweep back on time with minimal to no increase. Once the sweep was out of the hole, hole
unloaded with small 1/4-1\2" pieces of coal and rock.;Cont. circulating for a total of 3 BU. Oriented 47 deg LOHS, Acquire SPR's.;POOH F/5346' T/5110' on
elevators, pulled into window with no issues. Off bottom PU 150K, SO 95K;Circulate 1.5x BU cleaning CSG, 500 GPM, 2355 PSI, 30 RPM, 8K TQ, Pulling up
slowly. Cuttings coming over the shakers were the same coal and rock 1/4"-1/2" in size. Circulated until shakers cleaned up;Monitor well- static, Pump dry job,
POOH F/5110' T/513';Total totes shipped= 102
Daily Metal recovered= 86 #
Total Metal recovered= 1549 #
4/24/2023 Work BHA #4 f/ 141' to surface and function blinds when OOH bit graded 1-1-in;Clear and clean rig floor While Sperry preps tools on deck;P/up m/up Bha #5 /
P/up geo-pilot and m/up PDC bit P\up DM collar ADR + DGR + PWD + HOC / Upload tools / run std flex collars from derrick and m/up float sub t\ 174' / while
having platform UA;Crew change Run HWDP from derrick;Crew misaligned trip tank and over flowed flow nipple w/ 1.12 bbls of OMB to BOPs and cellar deck
secondary containment / re- align trip tank and monitor well on trip tank while cleaning up same and make notification's;Resume RIH F/548' T/5054 filling pipe
and breaking in geo-pilot at 2423' and 5054'.;Hang off blocks, cut and slip 79' of drilling line. Sim-ops circulated at 450 GPM , 1800 psi during cut and slip
operations.;RIH on elevators F/5054' T/5343' with no issues. Washed down T/5346' no fill.;Circulate and condition mud moving pipe F/5346' T/5333' while
production starts, monitors and sync's MTU #2.;Directional drill F/5346' T/5399' - 53' drilled (Ave ROP- 9 FPH) 500 GPM, 2300 PSI, 80-140 RPM, 7-12K TQ, 5-
10K WOB, Max gas- 270 units. PU 142K, SO 96K, ROT 115K;Directional drill F/5399' T/5564' - 154' drilled (Ave ROP- 27 FPH) 540 GPM, 2400 PSI, 80-140
RPM, 7-12K TQ, 5-10K WOB, Max gas- 270 units. PU 142K, SO 96K, ROT 115K, working through stick slip and TQ swings of 5-10K;Distance to Plan- 6.17',
Low 1.45', Left 6';Total totes shipped= 105
Daily metal recov.= 60 #
Total metal recov.= 1609 #
4/25/2023 Directional drill 8-1/2" hole F/5564' T/5720' - 173' drilled (Ave ROP- 28.8 FPH) 540 GPM, 2400 PSI, 80-140 RPM, 7-12K TQ, 5-10K WOB, Max gas- 9.7 units.
PU 158K, SO 95K, ROT 112K, working all parameters, rebuilt MTU #1 head #5A.;Directional drill 8-1/2" hole F/5720' T/6180' - 460' drilled (Ave ROP- 38.3 FPH)
540 GPM, 2550 PSI, 80-140 RPM, 7-12K TQ, 5-10K WOB, Max gas- 9.7 units. PU 165K, SO 95K, ROT 115K,working all parameters;Directional drill 8-1/2" hole
F/6180' T/6362' - 182' drilled (Ave ROP- 30.3 FPH) 540 GPM, 2550 PSI, 80-140 RPM, 7-12K TQ, 5-10K WOB, Max gas- 9.7 units. PU 170K, SO 98K, ROT
117K,working all parameters;pump sweep and circulate hole clean.;Distance to well plan wp2 :5.89', 4.34' high, 3.98' low; Bit Krevs:128
4/26/2023 Finish circ clean / Obtain TD survey and SPR.;Pooh on elevators w/ no issues w/ hole of window f/ 6365' t\ 4990'.;Rotate and Recip. and work full std f/ 4990' t/
5038' @ 536 gpm @ 2300 psi and chk csg for clean w/ no increase observed \ service rig \ Preform trial run P/up and racking back 6 jts of 5" dp w/ soft m/up w/
tuggers w/ TDS at high derrick\ Put # 1 MTU on line \ Medivac hand due to health concerns.;Rih f\ 4990' t\ 6275' and kelly up wash last std to btm w/ no issues
w/ window or hole and 4' fill.;Resume Directional drill 8-1/2" hole F/6365' T/6553' - 188' drilled (Ave ROP-37.6 FPH) 540 GPM, 2550 PSI, 80-140 RPM, 7-12K
TQ, 5-10K WOB, Max gas- 9.7 units. PU 170K, SO 98K, ROT 117K, working all parameters.;Cont. Directional drill 8-1/2" hole F/6553' T/7060' - 507' drilled (Ave
ROP-42.3 FPH) 540 GPM, 2650 PSI, 80-140 RPM, 7-12K TQ, 5-12K WOB, Max gas- 14units. PU 170K, SO 100K, ROT 115K, working all parameters.;Distance
from wp2: 0.91ft, 0ft high, 0.91ft left; Bit Krevs=210.
4/27/2023 Cont. Directional drill 8-1/2" hole f/7060' t/7321' - 261' drilled (Ave ROP-43.5 FPH) 540 GPM, 2680 PSI, 80-130 RPM, 7-12K TQ, 5-12K WOB, Max gas- 4units.
PU 170K, SO 100K, ROT 120K, working all parameters to trying to mitigate slip/stick and vibration.;Cont. Directional drill 8-1/2" hole f/7321' t/7402' - 81' drilled
(Ave ROP-81 FPH) 540 GPM, 2680 PSI, 80-130 RPM, 7-12K TQ, 5-12K WOB, Max gas- 60units. PU 175K, SO 95K, ROT 115K, working all parameters to
trying to mitigate slip/stick and vibration.;Back ream connection X2 / Circ clean / TD survey and SPR.;Pooh on elevators f/ 7402' t\6365', pulled clean.;Service
ST-80 clean rig floor.;RIH on elevators f/6365' t/7402', with a few 10-15k bobbles and no fill.;Cont. Directional drill 8-1/2" hole f/7402' t/8009' - 607' drilled (Ave
ROP-50 FPH) 540GPM, 2770PSI, 80-140 RPM, 10-12K TQ, 5-15K WOB, Max gas- 502 units. PU 178K, SO 95K, ROT 115K, working all parameters to trying
to mitigate slip/stick and vibration.;Distance to plan wp02: 1.13ft, .64ft low, .93ft left; Tota bit Krevs=326.
4/28/2023 Cont. Directional drill 8-1/2" hole f/8009' t/8283' - 274' drilled (Ave ROP-45.6 FPH) 540GPM, 2820PSI, 80-140 RPM, 10-12K TQ, 5-15K WOB, Max gas- 320
units. PU 195K, SO 100K, ROT 130K, working all parameters to trying to mitigate slip/stick and vibration and maximize ROP Back reaming each conn
X2.;Directional drill 8-1/2" hole f/8283' t/8437' - 154' drilled (Ave ROP- 30.8FPH) 540GPM, 2820PSI, 80-140 RPM, 10-12K TQ, 5-15K WOB, Max gas- 51 units.
PU 195K, SO 100K, ROT 130K, working all parameters to trying to mitigate slip/stick and vibration and maximize ROP Back reaming each conn X2.;Pump
sweep around while circ clean w/ no increase / TD survey and SPR / Monitor well-static.;Pooh on elevators f/ 8437' t/7200', work tight spots as needed w/25-30k
overpull. Monitor well-static, pump dry job.;Cont. POOH f/7200' t/3352', work tight hole @7100-7190' w/50k overpull and f/7190' t/7000' w/20-30k over pull. no
other issues with hole or window.;RIH w/slick pipe (no NRP's) f/3352' t/4755', cont. single in the hole f/4755' t/5100'.;Circ condition mud @ window.;cont. single
in the hole f/5100' t/5500'.;Cont. RIH out of the derrick f/5500' t/7012', start working pipe@ 7012'-6970'-s/o t/75-100k, p/u t/205-250k- working tight hole.;Working
tight hole@ 7012'-6970'-s/o t/75-100k, p/u t/205-250k- work pumps up t/500gpm, 2900psi, 38-42% flow while fighting packing off.;Distance to plan wp02:1.13ft,
.64ft low, .93ft left. Total bit Krevs=402.
4/29/2023 Continue Working tight hole and pack off f/6970' t\8344'.;Wash and ream last stand to btm @ 8437' and stage up pumps.;Resume Directional drill 8-1/2" hole
f/8437' t/9000' - 563' drilled (Ave ROP-38.8 FPH) 540GPM, 3000PSI, 80-140 RPM, 10-14K TQ, 5-15K WOB, Max gas- 897 units. PU 235K, SO 115K, ROT
130K, working all parameters to trying to mitigate slip/stick and vibration and maximize ROP Back reaming each conn X2;Distance to plan wp02: 3.00, 1.3ft high,
2.78ft left. Total bit Krevs=460.
4/30/2023 Continue Dir. drill 8-1/2" hole f/9000' t/9215' - 215' drilled (Ave ROP-35.8 FPH) 540GPM, 3000PSI, 80-140 RPM, 12-14K TQ, 5-15K WOB, Max gas- 460 units.
PU 215K, SO 100K, ROT 135K, working all parameters to trying to mitigate slip/stick and vibration and maximize ROP Back reaming each conn X2.;Continue
Dir. drill 8-1/2" hole f/9215' t/9464' - 249' drilled (Ave ROP-33.2FPH) 530GPM, 3000PSI, 80-140 RPM, 12-16K TQ, 5-18K WOB, Max gas- 291 units. PU 245K,
SO 120K, ROT 145K, working all parameters to trying to mitigate slip/stick and vibration and maximize ROP Back reaming each conn X2.;Circ clean while
reaming connection / take survey / monitor well-static \ TD survey and get SPR.;preform wiper trip pooh on elevators f/9464' t/7070', working tight hole as
needed.;Circ.b/u x2, stage @530pm, 2925psi, 90rpm, 12-14k free trq., reciprocate until clean.;preform wiper trip pooh on elevators f/7070' t/5840', working tight
hole as needed.;Distance from plan wp02: 1.34, .94ft high, .96ft right. Total Krevs:556.
5/1/2023 Continue Pooh on elevators f/5840' to above window @ 5056' working tight hole as needed, w/ no pack-off or issues entering window, attempting to wipe all over
pulls above 25k clean, trouble area appears to be f/6950' - 7100' having to kelly up and wash and ream.;Rotate and reciprocate full std and check casing for
clean @ 5056' w/450 gpm @ 1750 psi w/no increase in cuttings, while cleaning rig floor.;Monitor hole w/ 1/3 BPH seepage loss while securing service loop
cover and installing new Pump in rip tank #1, pump dry job.;Pooh rack back f/ 5056' t\ Bha.;L\d BHA ILS, down load MWD\LWD data, l/d same, break off bit and
l/d Go-pilot. Clean and clear rig floor.;Pull wear rind, drain stack, set test plug. Fill stack and choke with water. M/u floor valve-dart-pump in sub and test cap, m/u
test cap on top drive, run all test hoses.;Test BOP components as per AOGCC/Hilcorp procedure to 250psi low and 3500 psi high for 5min ea.;Tested: upper pip
rams, lower pipe rams, blind rams, annular, manual choke and kill valves, choke and kill HCR's, Kill demco, CMV-1 thru 16, Super choke A, Manual choke B
and Manual choke C, Accumulator draw down.;Rig down test equipment, floor valves and test caps. Pull test plug and set wear ring, l/d test jt.;P/U BHA as per
DD/MWD: iCruise, Bit, LWD/MWD.
5/2/2023 Continue P/U BHA as per DD/MWD: iCruise, Bit, LWD/MWD.;Up load data having communications issues. Change out computer and cables. Upload tools.
Good.;Surface test pad operations. Good. 410 GPM, 950 psi 500 GPM 1350 PSi. Downlink tools. Good.;RIH with 5''HWDP & Stands from derrick t/1450'. P/U
5'' Dp t/4224'. Strap tally and drift in V door. TIH t/5075' w/5"dp from derrick. Monitoring displacement on the trip tank.;Service rig- grease crown, top drive, draw
works and ST-80.;Slip/cut drill line, cut 557' line do to flat spots and 3-4 strands broken per lay. trq deadman to spec, check crown-o-matic and crown saver bell.
Monitoring well on the trip tank.;C/O saver sub: remove trq ring and safety wire, lift trq wrench and break connection and l/d saver. re-install new saver, trq to
spec, install trq ring and trq t/spec. and install safety wire.;Circulate and condition mud before running into open hole @ 300gpm, 915psi. Kelly up and get hoist
and slack off wts, pump 200gpm and wash thru window w/iCruise and back w/o issues.;RIH t/5164' t/6300'on elevators, monitoring displacement on the trip tank.
5/3/2023 RIH on elevators F/ 6300 to 6400. Set down. Unable to work through on elevators. Work on establishing circulation with pack offs and tight hole. Follow Icruze
procedure at 300 GPM, attempt to wash through. NO go.;ROT at 10-25 RPM 13 K TQ. immediate stall outs at 17k 6400. Bring ROT to 60 RPM and wash and
ream trying not to pack off or stall out. . Wash and ream down to 6470. RIH on elevators F/ 6470 T/ 6746. Stack out.;Establish circulation and getting pipe
free. Wash and ream stand working through pack offs and stall outs F. 6701 T/ 6757. Work on cleaning up stand with hole unloading coal. Stuck pipe and
packed off at 6702. Work on establishing circ and stage up pumps to 300 GPM.;Wash in the hole F. 6701 T/ 6935 working through tight spots and slight pack
offs with no rotary. Stack out & pack off at 6972'. Establish circulation and getting pipe free. Wash and ream stand working through pack offs and stall outs. 60
RPM,300 GPM, 13K Free TQ, 17K Stall.;Work jars at 75K -100K over to get pack off free to establish circ. Then clean up and ROT & Work pipe through tight
spots F/ 6950' T/ 6971'.;Stall out and pack off @ 6971', back off pumps and work trq out of pipe, start hitting jars 75k over, then 100k over, slowly working up the
hole fighting pack off's to 6946'.;Establish circulation and stage up pumps to 300gpm, 1050psi, 32% flow, circulate b/u, keeping pipe moving up the hole, rack
back 1 std and continue cleaning hole t/6906'.;Wash/ream in the hole f/6906' t/6983', 300gpm, 1050psi, 80rpm, 14-20k trq 32% flow. Stall out/pack off, release
trq, back off the pumps to reduced rate and begin hitting jars at 100k over, shut pumps down and bleed off pressure and ont. hitting jars at 100k over working
pipe up the hole to 6948'.;Call town and decision made to POOH before getting stuck and losing tool string. Jar on pipe at 100k over until freed, establish
circulation and back ream 1 std out, wash out 2more -no rotary, pull on elevators to the window and work as directed by Sperry DD pulling thru the window
@5115'.;Circulate B/U at 300gpm, 915psi, 32%flow.;POOH t/4500'
5/4/2023 POOH on elevators F\ 4500' T/ 172'. Stand bac NMFC & Download MWD.;L/D 8.5 Rotarty steering assembly & BHA. L/D Bit. Bit Grade- xxxxxxxxx;Clean &
Clear Rig Floor, Prep for NRP removal.;RIH with 42 stands with 2 NRPs per joint. Remove NRPS on trip in.;Monitor well on TT. Stacking NRPs from in crates to
load on boat between ISO's.. prep RPM tank for OBM transfer to ISO.;Work Boat: load sperry tools, Flex DC, cutting totes, 2-ISO's of base oil and WWT crates
w/NRP's.;Pump dry job, POOH f/4820' to surface racking in derrick.;L/D 5"dp in the mouse hole, wipe dwn every tool jt and vacuuming out residual OBM. 10 to a
bundle for the boat. 30std of 40 rental pipe l/d at report time.
5/5/2023 Finish L/D 120 Joints of rental 5'' pipe. L/D HWDP & Jars. Vacuum two balls through and clean threads. Monitoring hole on the Trip Tank.;Off load Iso tanks
and work boat. Transfer 160 bbl oil base mud to Iso tanks and load on boat. Prep mud product to load out. R/D Geospan and MWD transducers from rig floor.
R/D Draw works encoder.;Dropped object while R/D Gooseneck transducer. Wires pulled from J box and fell to rig floor. See Reports.;Clear flow line, Shaker
beds, Possom Belly, Rig floor of OBM solids with vacuum. Install flange on FIW pump from production to feed cmt unit. Prep to run lines. Work boat. Back load
DP & Mud product.;L/D 120 Joints of 5'' pipe. Vacuum two balls through and clean threads. Clean top of pits, ditch, grating, shaker and agitators. Load 12
bundles of 5"dp on boat. Monitoring hole on the Trip Tank.;Going to grab a basket with bits for the boat-crane swing gear fell off, crane dogged out and
mechanic called to fix same, swing gear is stripped out.;Cleaning pill pits and readying dry products for boat. Monitoring hole on the Trip Tank.
5/6/2023 Continue cleaning Solids from shaker area, Centrifuge and rig floor. Crane Mechanic Replace swing gear on Ctrax crane. Work boat. Off load HES cmt
equipment.;R/U Cmt unit & lines. M/U Cmt retainer & RIH with 5'' DP to 5040'. Set Retainer as per Tripoint. 12 Turns to right Slack off and P/U to 40 over to set
slips. Set down 50K. good. P/U 5K over up wt. Turn 12 turns to right. Saw good indication of Release.;Circ & condition mud. R/U Pups and side entry sub to cmt
line. Test CMt retainer to 2000 psi for 5 min. Good. Sting in retainer and establish injection rates at .5-3 bpm.
1 BPM @ 1000
1.5 @ 1225psi
2 @ 1410
2.5 @ 1570
3 @ 1710
Pumped 23 bbl total, up wt=135k, dwn wt=90k.;Hold for 6 min. Pressure bled down at
1 Min 1420
2 Min 1394
3 Min 1380
4 Min 1370
5 Min 1365
6 Min 1344
Bled down and got back 11 bbl.
Conduct PJSM with all hands for cmt job.;Cementers pump 5bbl spacer @2bpm/150psi, shut dwn and low pressure test lines t/870psi-good, hi-pressure test
t/3550psi-good.;Cementers pump 35bbls musal/surf-B spacer ahead @2bpm/180psi, shut dwn and batch up 15.3#/gal..;Cementers pump 49bbls
@2bpm/900psi. Closed annular and held 800-1200psi back pressure thru the choke.;Cementers ump 7bbls musal/surf-B spacer behind @bpm/180psi cont.
holding 800-1200psi back pressure thru the choke. Swap to rig pump-pump 9bbls 10.2# mud, had to bleed down back pressure to sting in after pumping
9bbls.;Rig cont. pumping/inject another 60bbls 10.2# mud 4.8bpm/1570psi. Rig bled down pressure on choke and unstung from retainer-well was on a vac,
spotting 7.2bbls of cement on top of retainer.;POOH 5 stds t/4550', up wt=130k, dwn wt=90K.;Circulate wiper ball and bottoms up until clean
@208GPM/1350PSI.;Monitor well while mixing slug. Fill trip tanks. Pump slug and POOH t/surface, l/d retainer stinger/running tool. Work boat-;P/U-M/U 8-1/2"
rock bit, 9-5/8" scraper and bit sub, RIH f/surface t/4804';Prep for displacement, clean mud from drains and gator backs, blow down lines etc.
5/7/2023 Clean rig floor drains, pipe racks, flow box before displacing w/FIW, clean w/base oil, pressure washers and scrub brushes. SIMOP-cleaning pill pits, mix 35bbl
Baraklean Dual sweep for interface in pill pit #2.;Kelly up and wash down f/4894' t/4954' set dwn 10k x2 @1bpm/165psi, dwn wt=90k, TOC=4954' (86ft cement
plug on retainer).;Circulate B/U 3-1/2X @500gpm/1165psi. Hole unloaded fines and coal chips on 2nd B/U then cleaned up.;Pre-job on reverse displacement
t/FIW. Rig up reverse manifold on rig floor and line up FIW and return pit t/RPM tanks.;Start reverse circ. displacement to FIW- Pump Baraklean pill from pill pit
#2 @3BPM/200psi, swap to pill pit #1 (FIW) and stage pumps up t/8bpm/328gpm/1180psi, at 3000stks slowed pumps t/5bpm/200gpm/265psi to catch
interface.;Shut down @3492stks and take interface to the trip tank approx. 45bbls. 3953stks total pumped for 395bbls. All mud returns caught in pits 2&3 and
transferred to RPM tank #3.;Pump out interface from rip Tanks #1 & #2 into ISO. SIMOP-R/D reverse manifold and flush thru stack, choke manifold w/ annular
and LPR shut.;R/U to test casing on chart recorder to 2500psi/30min. Test 2725psi/30min.-good. R/D test equipment. Fill Trip tanks w/FIW.;POOH f/4954'
t/surface, l/d bit, scraper and bit sub. P\U wash tool. SIMOP-clean pit, fill ISO w/OBM.;Cont. cleaning pit #1 for FIW.
5/8/2023 monitor well on trip tank while cleaning Pit #1. Transfer OBM to ISO tanks on deck. Pull wear ring and rig up 1502 hp hose f/casing valve to production flow
line.;Flush stack and well head w/wash tool @500gpm, 100psi and 10rpm.;M/U wear ring running tool and set same, run in 4 LDS. L\D setting tool.;M/U bit ,
scraper assembly, TIH t/4950'. Monitoring displacement on the trip tank.;Build and pump 30bbl soap pill, circulate surf/surf volume 3x @557gpm, 700psi
reciprocating string.;Build soap pill and inhibitor fluid, fill trip tanks w/inhibitor fluid. Hold pre-job on displacement to production flow line to TBU w/all
involved.;Displace well to TBU-Pumped out extra 89bbl FIW in pit #1, swap to pill pit #2 and pump 63bbl soap pill and finish displacing well w/340bbl FIW
w/inhibitor @4950', 6bpm, 550psi tbg pressure 425psi casing pressure.;Blow down hp hose and rig down line/equipment from casing head to production flow
line.;POOH l/d dp f/4950' to surface, bundling 10 at a time for loading onto boat.
5/9/2023 Continue L/D 5'' DP to surface. L/D Bit and scraper. 159 Joints total. Vacuuming wiper balls and cleaning threads.;Pull Wear bushing. R/U to run 4.5 Kill String.
M/U Mule shoe & Run 16 Joints. M/U landing joint and hanger. Blow down Choke and kill line and drain stack. RIH & Land hanger on depth. RILD. Work Boat.
Fill 4 ISO with mud.;Clean and Clear rig floor. R/D Parker Casing equipment. Off load 17 Bundles of 5'' pipe to boat. Start Removing tarps & Drip pans from
cellar. Pressure wash flow box. Continue to Vac solids from pit #1, #2, and #3. transfer mud to RPM #4.;Clean and clear rig floor of OBM handling tools and
subs while preparing cellar area for N/D removed pollution pans and tarps. Cont. cleaning pitws and work boat.;N/D 13-5/8" 5m BOPE and wash down bell
nipple, annular, choke and kill lines/valves,open doors on dbl /single gate and remove rams wash and prep for storage. Cont.n/d dbl gate , mud-X, single gate
and riser.
5/10/2023 Remove flow box bottom plate and N/D riser. Pull to Rif floor and L/D Same. Install tree and test void to 250/5000. Test & Tree 250\5000. Good Pull TWC 7
turn over to production. Work boat, Receive TD demobe equipment.;Blow down Glycol service loop, Drain Oil from TD. Spot wire for string up. Finish RPM tank
#3 cleaning start on Active pit #2. Remove side outlets on BOPs and clean BOPS with power washer. Unwire Service loops from TD. Install 3 1\8 protector
plates. Organize deck.;Prep top drive to l/d-remove service loop, S-pipe, bails, service loop bracket, S-pipe bracket, remove kelly hose f/top drive, scope up trq
wrench, remove bell guide, remove service loop guard.;Cont. clean and preserve choke/kill valves, target 90's, DSA's and mud X. Work boat-off load
Annular/single gate/dbl gate. Prep rams for storage.;Clean top drive and ST-80 w/hottsy, l/d both mouse hole and bell nipple-clean same.Grease top drive.
Clean and palletize Canrig equipment.;R/D ST-80-install on stand and remove from RF. Slip on 33 wraps drill line so block can reach the floor. R/D choke/kill
hoses and clean same.;Blow down koomey line t/koomey reservoir, clean and pull to RF. Cleaned pit#2.
5/11/2023 Continue cleaning pits. Finish Pit #2 and start on active #1. Finish cleaning and storing accumulator hoses. Remove IDS 350 stationary trolly from TD & Torque
rail. Remove goose neck on Washpipe & Turn around for storage.;Install extension trolly and dog in to torque rail. Unpin blocks. Install Lifting beam on Blocks.
Hook up rigging to Beam and TD bales. Release lower Torque rail clamp and slide alignment been out of the way. Remove Lower torque rail keepers and pin
and L/D top drive. Finish cleaning pit #1.;Cont. cleaning pit #3, R\D top drive-hyd service loop in derrick and set into crate. R\D top drive electrical service loop
in derrick and set in crate. P/U trq tube cradle and slide onto trq tube, run up to crown and engage dogs while holding trq tube release leaver in-release.;Clean
bell nipple, mouse holes.;Hoist block and release trq tube from hanging lug, slack off with spotter in derrick and cont. to l/d trq tube sections until clear the
derrick board, bring spotter dwn and finish l\d last sections and cradle.;Hang Kelly hose under stand pipe out of the way and off the floor-bag and duct tape end.
Remove trq tube hang off lug from crown. Install flange guard plates on choke/kill hoses and set in crate.
5/12/2023 Clean top drive rails, dolly, top side of pits of OBM. Take misc. parts to top drive connex. Remove Trq bar brace and pear from derrick.;Cont. clean pits of OBM,
remove target T from choke line in cellar and install blind. Start r/d top drive saddle, service loops outside of derrick. Stack up tod drive rails on upper pipe rack
for load out.;Finish r/d outside derrick service loops-power, control , hyd., glycol and coil in baskets for boat. Load rails on bjor flat w/spear and T bar for boat.
Cont. cleaning pits of OBM.;Remove tod drive control panel from drill console, cont. cleaning top side of pits of OBM. Blow dwn all line in pits and RPM tank to
pit #4. Cleaning strong back for load out on boat. R/u 2nd vacuum unit.
5/13/2023 Continue cleaning pits Under shakers & cuttings troughs.Transfer fluid in to Reservice pit #4. Working on cleaning OBM out of derrick down to the wind
walls.;Work boat. Off load from Reserve pit to ISO Tanks. Clean and prep TD VFD & TD Hyd unit for shipment. Load on boat with full ISO tanks. Scrub Strong
back for shipment. Load TD service loops & Hardware.;Fill choke with oil. Organize TD conex & take inventory. Finish cleaning OBM out of derrick down to the
wind walls and rig floor. Install caps on all koomey lines and store same.;Cleaning RPM tanks for boat from the top down-remove hoses, felt, plates and misc.
equipment, remove suction lines and vacuuming fluid from inside tanks. Preserve all chicksan hard lines threads w/anti-seize.;Cleaning cellar, lube bridge crane
chains and plug lycol lines. Install cover plate on kill line. Grind off hold down welds on strong back and test rig for boat.
5/14/2023 Finish cleaning RPM Tank and secure for shipping. Cleaning solids out of reserve pit #4. Work boat- Load out Cmt strong back, RPM Tank and RPM strong
back to boat. Continue cleaning cellar. Prep 1502 Iron and load on boat.;Cont. cleaning reserve pit #4. Suck out trip tanks and pill pits. Continue cleaning cellar
area and main deck of OBM. R/D Test pump for shipping back to drilling warehouse, clean same. R/D RPM transfer pump and clean same.;Build 100 bbl
barakleen pill & Flush through all lines.
5/15/2023 Continue to flush through pits and lines with Barakleen pill X2. Pull Right angle cover and service motor & Gear box. Prep Test pump & RPM Transfer pump
for boat. Clean around vac system area and clean pit storage area. Organize decks for storage.;Vack out trip tank #1 &2 Continue cleaning Cellar. Sent in 10
hands to 151. Pull Rotary table and Clean out. All drains plugged. Work boat. Off load two ISO cleaning water/OBM. While cleaning pit storage room floorhand
got a drop of soapy water in his eye. Flushed as per SDS and returned to work.;Send all Barakleen flush to Reserve pit #4. Prep for Corrosion inhibitor flush.
Set Kelly blocks on rig floor for string up.;Rest Crews.
5/16/2023 Pressure wash and clean in pump house under hopper. Rig down DB tongs and stage on deck. Vacuum solids in cellar from rotary table clean out. Pressure
wash rig floor. Remove rain water from deck and sumps.
Mix 100 bbl CI pill.;Pump CI pill through all surface lines and MP's. Blow down MP's and surface lines. Pressure wash beams and sub cleaning OBM in cellar.
Start prep and load hand tools and misc items in fish tote for storage. Suck out residual fluids in pits 1-3 from blowing down lines.;Rest crew
5/17/2023 Cont. to pressure wash and clean sub structure and cellar. Vacuum residue. Remove flow line, fire water hose, and high pressure mud line. Install 90's and
blank flange on mud line connections. Pull stairs to cellar;Skid rig package towards camp and remove MWD shack prepping for boat. Pressure wash drill deck,
start rigging down large vacuum unit- pull and prep for boat. Start going through MP's and prep for stack out.;Work boat loading Sperry shack, 1 full Iso and
large rig vac unit. Transferred remaining base oil to Iso;Rest crews
5/18/2023 Cont. pressure washing and cleaning drill deck, install 90's and blanking flange on rig and pit side of mud line. Move misc items to storage position. Blew down
all base oil lines for fluid transfer back to base oil tank. Start rolling up draining and flushing 3" and 2" high/low pressure lines.;Remove side wall and pull
centrifuge pump and prep for boat. Vacuum out degasser flow line. Cont working through MP's stack out procedure.;Rest crews
5/19/2023 Cont. cleaning west deck, sucking out drains and pulling plugs installing drain screens. Remove beaver slide from floor, skid rig package to parked position and
secure same. Installed pony sub and safe out with hand rails / walk ways.;Cont. working through MP's for stack out. Vacuum out residual fluid from pits #1, 2 and
res 4.;Back load boat;Rest crews
5/20/2023 Finish decommissioning mud pumps. Pressure wash and clean pump room and dry sack room. Clean and segregate hoses and prep for boat. Pressure was and
vacuum rig floor sumps. Prep misc loads for boat.;Perform final wash on sub base and cellar. Cont to organize and put away drilling equipment.;Rest crews
5/21/2023 Finished Pressure washing east drill deck and vacuuming out drains. Remove Drain plugs and install drain screens. Finished pressure washing and clean pump
room and dry sack room. Work boat;Continue organize and stow drilling equipment. Prep and unstring TDS blocks. Continue work on demobe list;Rest crews
5/22/2023 Remove 3/8" cable from TDS blocks and install string up in Kelly blocks. Hook up snake and string up blocks on 8 lines. Spool 3/8" cable back on wooden spool.
Cont. cleaning and stowing misc tools and equipment.;Cut 170' drill line and inspect Levs grooving ( did observe some major wear on levs grooving on drillers
side flange of kicker plates) installed Hook on blocks / tested crown saver bell system and set crown-o-madic and swapped weight indicator face dial to 8 lines
and secured blocks @ 70;with rig up slings \ Reinstalling dead line rubber drill line stabilizers and preforming full derrick inspection. Work boat. Continue
cleaning and stowing misc. drilling equipment. Continue work demobe list;Rest crews
5/23/2023 Continue demobe with Skelton crew / Install Ice and water shield on roof of mtr shed / Prep loads for boat / empty all trash cans / clean out drilling change room /
pack up tool pushers office continue stow drilling equipment / preserve and cover bridge cranes;finish removing SRL's left two emplace for WL work / polish
smooth w/ flapper wheel wore levis grooving kicker pads / secure blocks and LOTO brake handle / remove brushes on dwk traction mtrs / tarp off DWK,
tractions mtrs and drillers consul / load boat / power wash and mop pipe rack;Preformed finial walk through with production Mr. Victor Thompson ***************
finial report for A-10RD3***************
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A A
A
David Douglas Hilcorp Alaska, LLC
Sr. GeoTechnician 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: 907 777-8337
E-mail: david.douglas@hilcorp.com
Please acknowledge receipt by signing and returning one copy of this transmittal.
Received By: Date:
Date: 5/23/2023
To: Alaska Oil & Gas Conservation Commission
Natural Resources Technician
333 W. 7th Ave. Ste#100
Anchorage, AK 99501
DATA TRANSMITTAL
TBU A-10RD3
-PTD 223-011
-API 50-733-20064-03-00
FINAL LWD FORMATION EVALUATION LOGS (03/24/2023 to 04/30/2023)
ABG, DGR, ADR (2” & 5” MD/TVD Color Logs)
Final Definitive Directional Survey
Folder Contents:
TBU A-10RD3PB1
-PTD 223-011
-API 50-733-20064-72-00
FINAL LWD FORMATION EVALUATION LOGS (03/24/2023 to 04/18/2023)
EWR-M5, AGR, ABG (2” & 5” MD/TVD Color Logs)
Final Definitive Directional Survey
Folder Contents:
Please include current contact information if different from above.
PTD: 223-011
TBU A-10RD3: T37666
TBU A-10RD3 PB1: T37667
Kayla
Junke
Digitally signed by
Kayla Junke
Date: 2023.05.23
15:39:53 -08'00'
1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown
Suspend Perforate Other Stimulate Pull Tubing Change Approved Program
Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________
2. Operator Name:4. Current Well Class: 5. Permit to Drill Number:
Exploratory Development
3. Address: Stratigraphic Service
6. API Number:
7. If perforating:8. Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool?
Will planned perforations require a spacing exception?Yes No
9. Property Designation (Lease Number): 10. Field: Current Pools:
11.
Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD):
9,464'N/A
Casing Collapse
Structural
Conductor
Surface 1,540psi
Intermediate 4,750psi
Production
Liner
Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft):
12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work:
Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service
14. Estimated Date for 15. Well Status after proposed work:
Commencing Operations:OIL WINJ WDSPL Suspended
16. Verbal Approval:Yes Date: GAS WAG GSTOR SPLUG
AOGCC Representative: GINJ Op Shutdown Abandoned
Contact Name:
Contact Email:
Contact Phone:
Authorized Title:
Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number:
Plug Integrity BOP Test Mechanical Integrity Test Location Clearance
Other:
Post Initial Injection MIT Req'd? Yes No
Spacing Exception Required? Yes No Subsequent Form Required:
APPROVED BY
Approved by: COMMISSIONER THE AOGCC Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval.
Authorized Name and
Digital Signature with Date:
AOGCC USE ONLY
Sean Mclaughlin
sean.mclaughlin@hilcorp.com
907-223-6784
Bryan McLellan
5/5/2023
Tubing Grade:Tubing MD (ft):
N/A
Perforation Depth TVD (ft):Tubing Size:
5/4/2023
N/A
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL 18731, 17597, 392195
223-011
3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-733-20064-03-00
Hilcorp Alaska LLC
TBU A-10RD3
North Trading Bay Unit / Trading Bay Undefined Gas Pool
N/A
Length Size
Proposed Pools:
TVD Burst
PRESENT WELL CONDITION SUMMARY
5,983'9,464'5,983'2109'N/A
MD
6,870psi
3,090psi
264'
1,058'
3,920'
264'
1,095'
5,115'
20"
13-3/8"
264'
1,095'
Perforation Depth MD (ft):
9-5/8"5,115'
N/A N/A
m
n
P
2
6
5
6
t
_
Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
Drilling Manager 5.5.2023
323-272
By Kayla Junke at 3:04 pm, May 05, 2023
Digitally signed by Monty M Myers
DN: cn=Monty M Myers, c=US,
o=Hilcorp Alaska, LLC, ou=Technical
Services - AK Drilling,
email=mmyers@hilcorp.com
Reason: I am approving this document
Date: 2023.05.05 14:30:30 -08'00'
Monty M
Myers
DSR-5/9/23SFD 5/8/2023
10-407 to be filed with 10-407 for drilling permit.
BJM 5/10/23
Suspension expires 5 years after suspension work is complete.
GCW 05/11/23JLC 5/11/2023
5/11/2023
Brett W.
Huber, Sr.
Digitally signed by Brett W.
Huber, Sr.
Date: 2023.05.11 15:46:01
-08'00'
RBDMS JSB 051523
Well Prognosis
Well: A-10RD3
Date: 5/4/22
Well Name: A-10RD3 API Number: 50-733-20064-03-00
Current Status: Laying down BHA Leg: N/A
Estimated Start Date: 5/5/22 Rig: Monopod Rig 56
Reg. Approval Req’d? 403 Date Reg. Approval Rec’vd:
Regulatory Contact: Cody Dinger 777-8389 Permit to Drill Number: 223-011
First Call Engineer: Sean McLaughlin (907) 223-6784
Brief Well Summary – Drilled PB1 to 11,088’ when parted 4-1/2” drill pipe. The drillpipe and BHA was unable to
be fished. No nuclear sources were in the BHA. The well was sidetracked at 5115’ and drilled to current depth
of 9464’. Unfortunately, due to unfavorable wellbore conditions the decision has been made to stop drilling
activities. The coal at 6970’ MD is unpassable. There is potential future utility for the wellbore.
Notes Regarding Wellbore Condition –
x No significant hydrocarbon or freshwater zones have been encountered.
x Plugging program designed to segregate cased and uncased portions of the well bore.
x Current window depth – 5115’
x Current MASP with 5983’ TVD is 2109 psi
Rig 56 Procedure –
Work to be performed:
x POOH while removing nonrotating protectors and L/D BHA
x PU 9-5/8” cement retainer and RIH to ~5040’ and set.
x After setting retainer, set down 10 klbs to confirm set.
x Pump 37.7 bbls of 15.3 ppg cement below retainer. Expected bottom of cement will be 5400’.
x Lay in 7.3 bbls of 15.3 ppg cement above retainer. Expected TOC 4940’.
x Displace well to FIW with corrosion inhibitor
x Pressure test casing to 2500psi on chart for 30 mins
x POOH while L/D drill pipe
x PU 500’ kill string (tubing size TBD)
x Land hanger in wellhead.
x ND BOPE and NU tree and test
Attachments
1. Current Schematic
2. Proposed Schematic
(0.35 psi/ft) SFD
_____________________________________________________________________________________
Updated By: CJD 5/4/23
Current Schematic
Trading Bay Unit
Well: A-10RD3
PTD: 223-011
API: 50-733-20064-03-00
CASING DETAIL
Size Wt Grade Conn ID Top Btm
20”Conductor Pile Surface ~264’
13-3/8”61 K-55 BTC 12.515”Surface 1,095’
9-5/8”47 L-80 DWC/C 8.681” Surface
5,115’
(TOW)
JEWELRY DETAIL
No Depth
(MD)Item
1 5,115’TOW
_____________________________________________________________________________________
Updated By: CJD 5/4/23
Proposed Schematic
Trading Bay Unit
Well: A-10RD3
PTD: 223-011
API: 50-733-20064-03-00
Cement Detail
Item
Suspension
Proposed – Pump 37.7 bbls of 15.3 ppg cement below cmt retainer (bottom
of cement ~5,400’) Lay 7.3 bbls of 15.3 ppg cement above retainer (TOC @
~4,940’)
CASING DETAIL
Size Wt Grade Conn ID Top Btm
20”Conductor Pile Surface ~264’
13-3/8”61 K-55 BTC 12.515”Surface 1,095’
9-5/8”47 L-80 DWC/C 8.681” Surface
5,115’
(TOW)
Kill
String TBD TBD TBD TBD Surface ~500’
JEWELRY DETAIL
No Depth
(MD)Item
15,040’Cement Retainer
2 5,115’TOW
From:McLellan, Bryan J (OGC)
To:Sean McLaughlin
Cc:Cody Dinger; Roby, David S (OGC); Davies, Stephen F (OGC); Chmielowski, Jessie L C (OGC)
Subject:RE: [EXTERNAL] RE: A-10RD3 (223-011) Suspend well
Date:Friday, May 5, 2023 1:32:00 PM
Attachments:A-10RD3 10-403 Suspension Program.pdf
A-10RD3 Proposed Schematic 5-4-23.pdf
Sean,
Hilcorp has approval to proceed with pumping the cement suspension plug as outlined in the
attached procedure and diagram. Please follow up with a suspension Sundry within 3 days.
Regards
Bryan McLellan
Senior Petroleum Engineer
Alaska Oil & Gas Conservation Commission
Bryan.mclellan@alaska.gov
+1 (907) 250-9193
From: Sean McLaughlin <Sean.Mclaughlin@hilcorp.com>
Sent: Friday, May 5, 2023 1:22 PM
To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Cc: Cody Dinger <cdinger@hilcorp.com>
Subject: RE: [EXTERNAL] RE: A-10RD3 (223-011) Suspend well
There is a CIBP at 5145’ that was tested to 3500 psi. There may be some cement that falls on top
but likely no cement to be pumped by.
I have adjusted the cement retainer to be set 75’ above the window. Cody should have the Sundry
request sent over within the next hour.
Regards,
sean
From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Sent: Friday, May 5, 2023 12:21 PM
To: Sean McLaughlin <Sean.Mclaughlin@hilcorp.com>
Subject: RE: [EXTERNAL] RE: A-10RD3 (223-011) Suspend well
CAUTION: External sender. DO NOT open links or attachments from UNKNOWN
senders.
CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders.
Is it possible for the cement squeezed below the retainer to be displaced into either wellbore?
Whichever has the path of least resistance?
Bryan McLellan
Senior Petroleum Engineer
Alaska Oil & Gas Conservation Commission
Bryan.mclellan@alaska.gov
+1 (907) 250-9193
From: Sean McLaughlin <Sean.Mclaughlin@hilcorp.com>
Sent: Friday, May 5, 2023 12:18 PM
To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Subject: Re: [EXTERNAL] RE: A-10RD3 (223-011) Suspend well
There are currently no cement plugs in this wellbore.
Sean
On May 5, 2023, at 12:09 PM, McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
wrote:
Are there any cement plugs in this wellbore?
Bryan McLellan
Senior Petroleum Engineer
Alaska Oil & Gas Conservation Commission
Bryan.mclellan@alaska.gov
+1 (907) 250-9193
<image001.jpg>
From: Sean McLaughlin <Sean.Mclaughlin@hilcorp.com>
Sent: Friday, May 5, 2023 11:13 AM
CAUTION: External sender. DO NOT open links or attachments from UNKNOWN
senders.
CAUTION: External sender. DO NOT open links or attachments from UNKNOWN
senders.
To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Subject: RE: [EXTERNAL] RE: A-10RD3 (223-011) Suspend well
PB1 schematic attached. The cement crew should be heading to the platform this
afternoon.
sean
From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Sent: Friday, May 5, 2023 9:56 AM
To: Sean McLaughlin <Sean.Mclaughlin@hilcorp.com>
Subject: RE: [EXTERNAL] RE: A-10RD3 (223-011) Suspend well
Great, thanks. Steve is planning to look at it this morning. What is your timing?
Do you have a diagram of the first plugback as it was just prior to sidetracking?
Bryan McLellan
Senior Petroleum Engineer
Alaska Oil & Gas Conservation Commission
Bryan.mclellan@alaska.gov
+1 (907) 250-9193
<image001.jpg>
From: Sean McLaughlin <Sean.Mclaughlin@hilcorp.com>
Sent: Friday, May 5, 2023 9:52 AM
To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Subject: RE: [EXTERNAL] RE: A-10RD3 (223-011) Suspend well
Both data sets attached.
sean
From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Sent: Friday, May 5, 2023 9:33 AM
To: Sean McLaughlin <Sean.Mclaughlin@hilcorp.com>
Subject: [EXTERNAL] RE: A-10RD3 (223-011) Suspend well
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.
Sean,
Can you send over the open hole log data and gas sampling data?
Thanks
Bryan McLellan
Senior Petroleum Engineer
Alaska Oil & Gas Conservation Commission
Bryan.mclellan@alaska.gov
+1 (907) 250-9193
<image001.jpg>
From: Sean McLaughlin <Sean.Mclaughlin@hilcorp.com>
Sent: Thursday, May 4, 2023 4:55 PM
To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Subject: A-10RD3 (223-011) Suspend well
Bryan,
I’d like to ask for verbal approval to start suspension activities on A-10RD3. Supporting
documentation is attached. The signed Sundry should make it to you tomorrow.
Regards,
sean
Brief Well Summary – Drilled PB1 to 11,088’ when parted 4-1/2” drill pipe. The
drillpipe and BHA was unable to be fished. No nuclear sources were in the BHA. The
well was sidetracked at 5115’ and drilled to current depth of 9464’. Unfortunately,
due to unfavorable wellbore conditions the decision has been made to stop drilling
activities. The coal at 6970’ MD is unpassable. There is potential future utility for the
wellbore.
Notes Regarding Wellbore Condition –
1. No significant hydrocarbon or freshwater zones have been encountered.
2. Plugging program designed to segregate cased and uncased portions of the well
bore.
3. Current window depth – 5115’
4. Current MASP with 5983’ TVD is 2109 psi
Rig 56 Procedure –
Work to be performed:
1. POOH while removing nonrotating protectors and L/D BHA
2. PU 9-5/8” cement retainer and RIH to ~5095’ and set.
3. After setting retainer, set down 10 klbs to confirm set.
4. Pump 50 bbls of 15.3 ppg cement below retainer. Expected bottom of cement
will be 5645’.
5. Lay in 7.3 bbls of 15.3 ppg cement above retainer. Expected TOC 5045’.
6. Displace well to FIW with corrosion inhibitor
7. Pressure test casing to 2500psi on chart for 30 mins
8. POOH while L/D drill pipe
9. PU 500’ kill string (tubing size TBD)
10. Land hanger in wellhead.
11. ND BOPE and NU tree and test
Sean McLaughlin
Hilcorp Alaska, LLC
Drilling Engineer
Sean.McLaughlin@hilcorp.com
Cell: 907-223-6784
The information contained in this email message is confidential and may be legally privileged and is intended only for
the use of the individual or entity named above. If you are not an intended recipient or if you have received thismessage in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited.If you have received this email in error, please immediately notify us by return email or telephone if the sender's phonenumber is listed above, then promptly and permanently delete this message.
While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient toensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect itssystems or data. No responsibility is accepted by the company in this regard and the recipient should carry out suchvirus and other checks as it considers appropriate.
The information contained in this email message is confidential and may be legally privileged and is intended only for
the use of the individual or entity named above. If you are not an intended recipient or if you have received this
message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited.
If you have received this email in error, please immediately notify us by return email or telephone if the sender's phonenumber is listed above, then promptly and permanently delete this message.
While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient toensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect itssystems or data. No responsibility is accepted by the company in this regard and the recipient should carry out suchvirus and other checks as it considers appropriate.
The information contained in this email message is confidential and may be legally privileged and is intended only forthe use of the individual or entity named above. If you are not an intended recipient or if you have received thismessage in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited.
If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone
number is listed above, then promptly and permanently delete this message.
While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to
ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its
systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out suchvirus and other checks as it considers appropriate.
The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby
notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please
immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete
this message.
While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate.
The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message.
While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the
onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate.
_____________________________________________________________________________________
Updated By: CJD 5/5/23
PB1 Schematic
Trading Bay Unit
Well: A-10RD3
PTD: 223-011
API: 50-733-20064-03-70
CASING DETAIL
Size Wt Grade Conn ID Top Btm
20” Conductor Pile Surface ~264’
13-3/8” 61 K-55 BTC 12.515” Surface 1,095’
9-5/8” 47 L-80 DWC/C 8.681” Surface 5,421’
(TOW)
JEWELRY DETAIL
No Depth
(MD) Item
1 5,421’ TOW
2 5,829’ Fish – 44 Stands DP + Drilling BHA
CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders.
From:Sean McLaughlin
To:Davies, Stephen F (OGC)
Cc:McLellan, Bryan J (OGC)
Subject:RE: [EXTERNAL] RE: A-10RD3 (223-011) Suspend well
Date:Friday, May 5, 2023 1:25:02 PM
Thanks Steve, with respect to the other question I don’t know why the gas response was not
present. I do know that we circulated fist size chunks of coal up from that interval when we were
packed of and stuck there.
Regards,
sean
From: Davies, Stephen F (OGC) <steve.davies@alaska.gov>
Sent: Friday, May 5, 2023 12:35 PM
To: Sean McLaughlin <Sean.Mclaughlin@hilcorp.com>
Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Subject: RE: [EXTERNAL] RE: A-10RD3 (223-011) Suspend well
Hi Sean,
When I read your initial email to Bryan, I somehow transposed two digits and thought the well was
impassible below 9670’ MD rather than 6970’ MD, which renders my last question below irrelevant.
So, never mind.
Apologies,
Steve Davies
AOGCC
From: Davies, Stephen F (OGC)
Sent: Friday, May 5, 2023 10:32 AM
To: Sean McLaughlin <Sean.Mclaughlin@hilcorp.com>
Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Subject: RE: [EXTERNAL] RE: A-10RD3 (223-011) Suspend well
Sean,
The puzzling thing about that interval is that it has no associated gas spike. Any explanation? Were
cuttings samples examined?
Another question: How can Hilcorp be certain that the interval from 8100’ to 8155’ MD is not a gas-
charged 40-foot thick sand beneath a 10-foot thick coal seam?
CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders.
Thanks and stay safe,
Steve Davies
AOGCC
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas
Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or
privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an
unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake
in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov.
From: Sean McLaughlin <Sean.Mclaughlin@hilcorp.com>
Sent: Friday, May 5, 2023 10:28 AM
To: Davies, Stephen F (OGC) <steve.davies@alaska.gov>
Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Subject: RE: [EXTERNAL] RE: A-10RD3 (223-011) Suspend well
Steve,
That is a coal interval.
Regards,
sean
From: Davies, Stephen F (OGC) <steve.davies@alaska.gov>
Sent: Friday, May 5, 2023 10:25 AM
To: Sean McLaughlin <Sean.Mclaughlin@hilcorp.com>
Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Subject: FW: [EXTERNAL] RE: A-10RD3 (223-011) Suspend well
Sean,
I’m quickly reviewing the log and gas measurements, and I’m curious as to Hilcorp’s interpretation of
the interval that displays elevated resistivity between 6685’ and 6760’ MD.
From: Sean McLaughlin <Sean.Mclaughlin@hilcorp.com>
Sent: Friday, May 5, 2023 9:52 AM
To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Subject: RE: [EXTERNAL] RE: A-10RD3 (223-011) Suspend well
Both data sets attached.
sean
From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Sent: Friday, May 5, 2023 9:33 AM
CAUTION: This email originated from outside the State of Alaska mail system.
Do not click links or open attachments unless you recognize the sender and know
the content is safe.
CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders.
To: Sean McLaughlin <Sean.Mclaughlin@hilcorp.com>
Subject: [EXTERNAL] RE: A-10RD3 (223-011) Suspend well
Sean,
Can you send over the open hole log data and gas sampling data?
Thanks
Bryan McLellan
Senior Petroleum Engineer
Alaska Oil & Gas Conservation Commission
Bryan.mclellan@alaska.gov
+1 (907) 250-9193
From: Sean McLaughlin <Sean.Mclaughlin@hilcorp.com>
Sent: Thursday, May 4, 2023 4:55 PM
To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Subject: A-10RD3 (223-011) Suspend well
Bryan,
I’d like to ask for verbal approval to start suspension activities on A-10RD3. Supporting
documentation is attached. The signed Sundry should make it to you tomorrow.
Regards,
sean
Brief Well Summary – Drilled PB1 to 11,088’ when parted 4-1/2” drill pipe. The drillpipe and BHA
was unable to be fished. No nuclear sources were in the BHA. The well was sidetracked at 5115’
and drilled to current depth of 9464’. Unfortunately, due to unfavorable wellbore conditions the
decision has been made to stop drilling activities. The coal at 6970’ MD is unpassable. There is
potential future utility for the wellbore.
Notes Regarding Wellbore Condition –
No significant hydrocarbon or freshwater zones have been encountered.
Plugging program designed to segregate cased and uncased portions of the well bore.
Current window depth – 5115’
Current MASP with 5983’ TVD is 2109 psi
Rig 56 Procedure –
Work to be performed:
POOH while removing nonrotating protectors and L/D BHA
PU 9-5/8” cement retainer and RIH to ~5095’ and set.
After setting retainer, set down 10 klbs to confirm set.
Pump 50 bbls of 15.3 ppg cement below retainer. Expected bottom of cement will be 5645’.
Lay in 7.3 bbls of 15.3 ppg cement above retainer. Expected TOC 5045’.
Displace well to FIW with corrosion inhibitor
Pressure test casing to 2500psi on chart for 30 mins
POOH while L/D drill pipe
PU 500’ kill string (tubing size TBD)
Land hanger in wellhead.
ND BOPE and NU tree and test
Sean McLaughlin
Hilcorp Alaska, LLC
Drilling Engineer
Sean.McLaughlin@hilcorp.com
Cell: 907-223-6784
The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message.
While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the
onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility
is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate.
The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message.
While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate.
The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message.
While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the
onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility
is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate.
The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the
individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message.
While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate.
Well Prognosis
Well: A-10RD3
Date: 5/4/22
Well Name: A-10RD3 API Number: 50-733-20064-03-00
Current Status: Laying down BHA Leg: N/A
Estimated Start Date: 5/5/22 Rig: Monopod Rig 56
Reg. Approval Req’d? 403 Date Reg. Approval Rec’vd:
Regulatory Contact: Cody Dinger 777-8389 Permit to Drill Number: 223-011
First Call Engineer: Sean McLaughlin (907) 223-6784
Brief Well Summary – Drilled PB1 to 11,088’ when parted 4-1/2” drill pipe. The drillpipe and BHA was unable to
be fished. No nuclear sources were in the BHA. The well was sidetracked at 5115’ and drilled to current depth
of 9464’. Unfortunately, due to unfavorable wellbore conditions the decision has been made to stop drilling
activities. The coal at 6970’ MD is unpassable. There is potential future utility for the wellbore.
Notes Regarding Wellbore Condition –
• No significant hydrocarbon or freshwater zones have been encountered.
• Plugging program designed to segregate cased and uncased portions of the well bore.
• Current window depth – 5115’
• Current MASP with 5983’ TVD is 2109 psi
Rig 56 Procedure –
Work to be performed:
• POOH while removing nonrotating protectors and L/D BHA
• PU 9-5/8” cement retainer and RIH to ~5040’ and set.
• After setting retainer, set down 10 klbs to confirm set.
• Pump 37.7 bbls of 15.3 ppg cement below retainer. Expected bottom of cement will be 5400’.
• Lay in 7.3 bbls of 15.3 ppg cement above retainer. Expected TOC 4940’.
• Displace well to FIW with corrosion inhibitor
• Pressure test casing to 2500psi on chart for 30 mins
• POOH while L/D drill pipe
• PU 500’ kill string (tubing size TBD)
• Land hanger in wellhead.
• ND BOPE and NU tree and test
Attachments
1. Current Schematic
2. Proposed Schematic
_____________________________________________________________________________________
Updated By: CJD 5/4/23
Proposed Schematic
Trading Bay Unit
Well: A-10RD3
PTD: 223-011
API: 50-733-20064-03-00
Cement Detail
Item
Suspension
Proposed – Pump 37.7 bbls of 15.3 ppg cement below cmt retainer (bottom
of cement ~5,400’) Lay 7.3 bbls of 15.3 ppg cement above retainer (TOC @
~4,940’)
CASING DETAIL
Size Wt Grade Conn ID Top Btm
20” Conductor Pile Surface ~264’
13-3/8” 61 K-55 BTC 12.515” Surface 1,095’
9-5/8” 47 L-80 DWC/C 8.681” Surface 5,115’
(TOW)
Kill
String TBD TBD TBD TBD Surface ~500’
JEWELRY DETAIL
No Depth
(MD) Item
1 5,040’ Cement Retainer
2 5,115’ TOW
_____________________________________________________________________________________
Updated By: CJD 5/4/23
Current Schematic
Trading Bay Unit
Well: A-10RD3
PTD: 223-011
API: 50-733-20064-03-00
CASING DETAIL
Size Wt Grade Conn ID Top Btm
20” Conductor Pile Surface ~264’
13-3/8” 61 K-55 BTC 12.515” Surface 1,095’
9-5/8” 47 L-80 DWC/C 8.681” Surface 5,115’
(TOW)
JEWELRY DETAIL
No Depth
(MD) Item
1 5,115’ TOW
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
BOPE Test Report for:
Reviewed By:
P.I. Suprv
Comm ________TRADING BAY ST A-10RD3
JBR 04/17/2023
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:2
LEL sensor in pits F/P. During the low psi on the Blind ram test, all looked good other than 3 redundant tests with the 5" test
joint was tested. Additional failures were witnessed by the operator. I departed location due to weather incoming at 3pm on
3/18/23, operator ended testing 3/19/23.
Test Results
TEST DATA
Rig Rep:Hebert/NormanOperator:Hilcorp Alaska, LLC Operator Rep:Sunderland/Anderson
Rig Owner/Rig No.:Hilcorp 56 PTD#:2230110 DATE:3/18/2023
Type Operation:DRILL Annular:
250/3500Type Test:INIT
Valves:
250/5000
Rams:
250/5000
Test Pressures:Inspection No:bopAGE230322125455
Inspector Adam Earl
Inspector
Insp Source
Related Insp No:
INSIDE REEL VALVES:
Quantity P/F
(Valid for Coil Rigs Only)
Remarks:
Test Time 7.5
MASP:
3204
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 4 P
Inside BOP 2 P
FSV Misc 0 NA
16 PNo. Valves
2 PManual Chokes
1 PHydraulic Chokes
0 NACH Misc
Stripper 0 NA
Annular Preventer 1 13 5/8 P
#1 Rams 1 2 7/8 X 5 1/2 P
#2 Rams 1 Blinds NT
#3 Rams 1 2 7/8 X 5 1/2 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 3 1/8 P
Check Valve 0 NA
BOP Misc 0 NA
System Pressure P3025
Pressure After Closure P1325
200 PSI Attained P46
Full Pressure Attained P219
Blind Switch Covers:PAll Stations
Bottle precharge P
Nitgn Btls# &psi (avg)P6@2375
ACC Misc NA0
P PTrip Tank
P PPit Level Indicators
P PFlow Indicator
FP FPMeth Gas Detector
P PH2S Gas Detector
0 NAMS Misc
Inside Reel Valves 0 NA
Annular Preventer P11
#1 Rams P9
#2 Rams P9
#3 Rams P9
#4 Rams NA0
#5 Rams NA0
#6 Rams NA0
HCR Choke P2
HCR Kill P2
9
9
9
9
9999
9 9
9
9
departed location due to weather incoming at 3pm on
3/18/23, operator ended testing 3/19/23.
LEL sensor in pits F/P.Blind ram test,
NT
FP FP
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
Monty M. Myers
Drilling Manger
Hilcorp Alaska, LLC
3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Re: North Trading Bay Field, Trading Bay Undefined Gas Pool, TBU A-10RD3
Hilcorp Alaska, LLC
Permit to Drill Number: 223-011
Surface Location: 1602' FSL, 550' FEL, Sec 4, T9N, R13W, SM, AK
Bottomhole Location: 63' FSL, 171' FWL, Sec 26, T10N, R13W, SM, AK
Dear Mr. Myers:
Enclosed is the approved application for the permit to drill the above referenced well.
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:
Gas-measurement log (in units or ppm vs measured depth) or mud log recorded while drilling
from the window at about 5,500' MD to 7-inch casing point at about 14,800' MD is required to
demonstrate the absence of significant hydrocarbon reservoirs in the intermediate hole section.
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 0DUFK, 2023. 2
Brett W. Huber,
Sr.
Digitally signed by Brett W.
Huber, Sr.
Date: 2023.03.02 11:28:30 -09'00'
1a. Type of Work:1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for:
Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates
Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas
2. Operator Name:5. Bond: Blanket Single Well 11. Well Name and Number:
Bond No.
3. Address:6. Proposed Depth: 12. Field/Pool(s):
MD: 15,807' TVD: 9,101'
4a. Location of Well (Governmental Section):7. Property Designation:
Surface:
Top of Productive Horizon:8. DNR Approval Number: 13. Approximate Spud Date:
Total Depth: 9. Acres in Property: 14. Distance to Nearest Property:
4b. Location of Well (State Base Plane Coordinates - NAD 27):10. KB Elevation above MSL (ft): 101' 15. Distance to Nearest Well Open
Surface: x-218864 y- 2523116 Zone-4 N/A to Same Pool: N/A
16. Deviated wells:Kickoff depth: 5500 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035)
Maximum Hole Angle: 63 degrees Downhole: Surface:
Hole Casing Weight Grade Coupling Length MD TVD MD TVD
8-1/2" 7" 29# L-80 TXP 9,500' 5,300' 4,010' 14,800' 8,551'
6-1/8" 4-1/2" 13.5# L-80 TXP 1,207' 14,600' 8,415' 15,807' 9,101'
Tieback 4-1/2" 12.6# L-80 H533 14,600' Surface Surface 14,600' 8,415'
19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations)
Junk (measured):
N/A
TVD
264'
1,068'
4,258'
Hydraulic Fracture planned?Yes No
20. Attachments:Property Plat BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis
Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements
Contact Name:
Contact Email:
Contact Phone:
Date:
Permit to Drill API Number: Permit Approval
Number:Date:
Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales:
Samples req'd: Yes No Mud log req'd: Yes No
H2S measures: Yes No Directional svy req'd: Yes No
Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No
Post initial injection MIT req'd: Yes No
APPROVED BY
Approved by: COMMISSIONER THE COMMISSION Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
3/15/2023
2469' to nearest unit boundary
Sean Mcglaughlin
sean.mclaughlin@hilcorp.com
907-223-6784
N/A 264'
1,095'13-3/8"1200 sx
Drilling Manager
Monty Myers
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):Perforation Depth MD (ft):
1,095'
5,818'
Production
Liner
5,818'Intermediate
N/A
Conductor/Structural 20"264'
Authorized Title:
Authorized Signature:
Authorized Name:
11,276'6,852'
LengthCasing
Multiple (7,969')
Cement Volume MDSize
Plugs (measured):
(including stage data)
253 ft3
169 ft3
7,969'5,383'
Effect. Depth MD (ft):Effect. Depth TVD (ft):
10800
18. Casing Program:Top - Setting Depth - BottomSpecifications
4114
GL / BF Elevation above MSL (ft):
Total Depth MD (ft):Total Depth TVD (ft):
022224484
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
20 AAC 25.005
Tieback
3204
452' FNL, 56' FEL, Sec 34, T10N, R13W, SM, AK
63' FSL, 171' FWL, Sec 26, T10N, R13W, SM, AK
N/A
3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503
Hilcorp Alaska, LLC
1602' FSL, 550' FEL, Sec 4, T9N, R13W, SM, AK ADL 18731, 17597, 392195, 35431, 18776
TBU A-10RD3
North Trading Bay Unit
Trading Bay Undefined Gas Pool
Cement Quantity, c.f. or sacks
Commission Use Only
See cover letter for other
requirements.
N/A
1380 sx9-5/8"
s N
ype of W
L
l R
L
1b
S
Class:
os N s No
s N o
D s
s
s
D
84
o
well is p
G
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)
2.7.2023
By Samantha Carlisle at 2:08 pm, Feb 07, 2023
Digitally signed by Monty M Myers
DN: cn=Monty M Myers, c=US,
o=Hilcorp Alaska, LLC, ou=Technical
Services - AK Drilling,
email=mmyers@hilcorp.com
Reason: I am approving this document
Date: 2023.02.07 13:23:59 -09'00'
Monty M
Myers
X
DLB 02/09/2023
SFD 3/1/2023
X
50-733-20064-03-00
*
DSR-2/7/23
Initial BOP test to Rated Working Pressure.
Subsequent BOP tests to 3500 psi. 14 day BOP test frequency.
Significant Hydrocarbon zones across 7" liner must be covered by cement.
223-011
*
X
X
X
X
Gas-measurement log (in units or ppm vs MD) or mud log
recorded while drilling from window to 7-inch casing point is
required to demonstrate the absence of significant
hydrocarbon reservoirs in the intermediate hole section.
X*
BJM 3/1/23
JLC 3/2/2023
3/2/23
3/2/23Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr.
Date: 2023.03.02 11:28:44 -09'00'
A-10RD3 Drilling Program
Monopod
Sean McLaughlin
PTD Program
February 1, 2023
TBU A-10RD3
Drilling Program
For PTD
Contents
1. Well Summary...............................................................................................................................2
2. Management of Change Information............................................................................................3
3. Liner Program...............................................................................................................................4
4. Drill Pipe Information...................................................................................................................4
5. Internal Reporting Requirements.................................................................................................5
6. Current Wellbore Schematic.........................................................................................................6
7. Planned Wellbore Schematic.........................................................................................................7
8. Drilling Summary..........................................................................................................................8
9. Mandatory Regulatory Compliance / Notifications......................................................................9
10. BOP N/U and Test.......................................................................................................................11
11. Mud Program and Density Selection Criteria ............................................................................11
12. Decomplete / Set CIBP / Set Whipstock / Mill Window .............................................................13
13. Drill 8-1/2” Intermediate Hole Section........................................................................................14
14.Run 7” Intermediate Liner ..........................................................................................................16
15.Cement 7” Intermediate Casing ..................................................................................................22
16. Drill 6-1/8” Hole Section ..............................................................................................................25
17. Run 4-1/2” Production Liner.......................................................................................................26
18. Cement 4-1/2” Production Liner .................................................................................................29
19. Run Completion Assembly..........................................................................................................32
20. BOP Schematic............................................................................................................................33
21. Wellhead Schematic (proposed)..................................................................................................34
22. Anticipated Drilling Hazards (8-1/2” and 6-1/8” hole sections).................................................35
23. FIT Procedure..............................................................................................................................36
24. Choke Manifold Schematic .........................................................................................................37
25. Casing Design Information..........................................................................................................38
26. 8-1/2” Hole Section MASP...........................................................................................................39
27. 6-1/8” Hole Section MASP...........................................................................................................40
28. Plot (NAD 27) (Governmental Sections).....................................................................................41
29. Slot Diagram................................................................................................................................42
30. Directional Program (wp01) - Attached separately ...................................................................43
Page 2 PTD Program February 1, 2023
TBU A-10RD3
Drilling Program
For PTD
1. Well Summary
Well TBU A-10RD3
Drilling Rig Rig 56
Leg & Slot Designation Slot 31
Directional plan wp01
Pad & Old Well Designation Sidetrack of existing well A-10RD2 (PTD#222-002)
Planned Completion Type 4-1/2” Tubing with Gas Lift
Target Reservoir(s)Tyonek
Kick off point 5,500’ MD / 4106’ TVD
Planned Well TD, MD / TVD 15,807’ MD / 9,101’ TVD
PBTD, MD 15,717’ MD
AFE Number
AFE Days
AFE Drilling Amount
RKB –AMSL 101’
MSL to ML 66’’
Page 3 PTD Program February 1, 2023
TBU A-10RD3
Drilling Program
For PTD
2. Management of Change Information
Date: January 13, 2023
Subject: Changes to Approved Permit to Drill for TBU A-10RD3
File #: TBU A-10RD3 Drilling Program
Significant modifications to TBU A-10RD3 Drilling Program for PTD will be documented and approved below.
Changes to an approved PTD will be communicated and approved by the AOGCC prior to continuing forward
with work.
Sec Page Date Procedure Change Approved By
Approval:
Drilling Manager Date
Prepared:
Engineer Date
Page 4 PTD Program February 1, 2023
TBU A-10RD3
Drilling Program
For PTD
3. Liner Program
Hole
Section
OD (in)Wt (#/ft)Coupl OD ID (in)Drift (in)Grade Conn Top Bottom
8-1/2”7”29#7.75”6.172”*6.125”P-110 TXP 5300’14800’
6-1/8”4-1/2”13.5#5”3.908”3.795”L-80 TXP 14600’15807’
*7” casing will have 6.125” special drift
**Minimum of 100’ overlap required between casing strings
4. Drill Pipe Information
Hole
Section
OD (in)ID (in)TJ ID
(in)
TJ OD
(in)
Wt
(#/ft)
Grade Conn 80%
Burst
(psi)
80%
Collapse
(psi)
80%
Tension
(k-lbs)
All 5”4.276 3.25 6.625 19.5 S-135 NC50 15,638 10,029 560k
All 4-1/2”3.826 2.6875”5.25”16.6 S-135 CDS40 16,176 10,959 468k
* A tapered drill string will be run in both hole sections.
Page 5 PTD Program February 1, 2023
TBU A-10RD3
Drilling Program
For PTD
5. Internal Reporting Requirements
1. Fill out daily drilling report and cost report on Wellez.
x Report covers operations from 6am to 6am
x Click on one of the tabs at the top to save data entered. Clicking on one of the tabs to the left
of the data entry area will not save the data entered, and will navigate to another data entry tab.
x Ensure time entry adds up to 24 hours total.
x Try to capture any out-of-scope work as NPT. This helps later when aggregating end of well
reports.
2. Afternoon Updates
x Submit a short operations update each workday to KenaiCIODrilling@hilcorp.com
3. EHS Incident Reporting
x Notify EHS field coordinator.
i. Tyler Pruitt: C: (907) 513-9903
x Spills:
i. Keegan Fleming: C:907-350-9439
ii. Monty Myers: O: 907-777-8431 C: 907-538-1168
iii. Sean Mclaughlin
x Submit Hilcorp Incident report to contacts above within 24 hrs
4. Casing Tally
x Send final “As-Run” Casing tally to sean.mclaughlin@hilcorp.com and cdinger@hilcorp.com
5. Casing and Cmt report
x Send casing and cement report for each string of casing to sean.mclaughlin@hilcorp.com and
cdinger@hilcorp.com
Page 6 PTD Program February 1, 2023
TBU A-10RD3
Drilling Program
For PTD
6. Current Wellbore Schematic
Got 60 bbls cement back at surface.
-bjm
No cement behind 7" casing. Only 17 bbls cement were squeezed due to packoffs,
TOC on 7" in A-10RD was 11650' MD.
Lost all returns during primary 9-5/8" cement job.
2nd stage cement job pumped through 9-5/8" Cement stage tool at 3318'. Cemented w/ 267 bbls
cement and overdisplaced by 40 bbls when plug didn't bump (plug was stuck in cementing head).
Page 7 PTD Program February 1, 2023
TBU A-10RD3
Drilling Program
For PTD
7. Planned Wellbore Schematic
Planned TOC on 7" liner is 13800' md. - bjm
Page 8 PTD Program February 1, 2023
TBU A-10RD3
Drilling Program
For PTD
8. Drilling Summary
The parent well was a failed sidetrack attempt in 2022. Hole stability, ROP, and a short offshore drilling
season forced suspending the well. At 5,500’MD the parent wellbore will be sidetracked and an intermediate
section will be drilled to 14,800’towards the North Trading Bay Unit. After running a cementing 7” casing a
6.125” hole will be drilled to TD. A 4-1/2”prod liner will be run, cemented, and perforated based on data
obtained while drilling the interval.
The well will be completed with a 4-1/2”gas lift tie-back completion.
Operations are expected to commence approximately March 15, 2023.
All waste & mud generated during drilling and completion operations will be hauled to the Kenai Gas Field
G&I facility for disposal / beneficial reuse depending on test results.
A separate sundry notice will be submitted for re-entering a suspended well and running the
completion assembly.
General sequence of operations pertaining to this drilling operation:
Drilling Operations:
1. Test BOPE to 3500 psi
2.Pull 548’ of 4-1/2” IBT kill string
3. Set 9-5/8” CIBP at 5525’. Perform 3500 psi casing test.
4. Set 9-5/8” whipstock at 5500’ and 30 LOHS.
5. Swap well to 9.2 ppg mud
6. Mill window with 20’ of new formation.
7. Perform FIT to 13.7 ppg EMW
8. PU 6-3/4” Rotary Steerable assembly for 8.5” openhole.
9. Drill 8-1/2” intermediate hole to 14,800’ MD, performing short trips as needed
10.Install and test 7” casing rams, test to 3500 psi
11. RIH w/ 7”liner with TTDL (two trip drilling liner) system. Release liner, POOH
12. Install VBR rams, test to 3500 psi
13. RIH with drillpipe to cement liner in place. Circ wellbore clean.
14. Perform liner lap test to 3500 psi.
15. PU 4-3/4” Rotary Steerable assembly for 6.125” openhole.
16. Drill 6-1/8” production hole to 15,806’MD, performing short trips as needed
17. RIH w/ 4-1/2” liner. Set liner and cement. Circ wellbore clean.
18. Perform liner lap to 3500 psi.
19. Run 4-1/2”completion.
20. Land hanger and test tubing and IA to 3500 psi
21. ND BOPE, NU tree and test void
Perform FIT/LOT. -bjm
A separate sundry notice will be submitted for re-entering a suspended well a
This permit to drill is sufficient for re-entry of a suspended well to conduct drilling operatoins. Separate
Sundry not required for re-entering. - bjm
Page 9 PTD Program February 1, 2023
TBU A-10RD3
Drilling Program
For PTD
9. Mandatory Regulatory Compliance / Notifications
Regulatory Compliance
Ensure that drilling and completion operations comply with the below AOGCC regulations. If
additional clarity or guidance is required on how to comply with a specific regulation, do not hesitate to
contact the Anchorage Drilling Team.
x BOPs shall be tested at (2) week intervals during the drilling. Ensure to provide AOGCC 48 hrs
notice prior to testing BOPs.
x The BOP equipment will be tested to 250/3500 psi (annular 2500 psi). Confirm that these test
pressures match those specified on the APD.
o The highest reservoir pressure expected is 4114 psi at TD (9091' TVD). MASP is 3204 psi with
0.1psi/ft gas in the wellbore.
o A casing test to 3500 psi was conducted during the 2022 sidetrack. A 3500 psi casing test is
planned after setting a 9-5/8” CIBP.
x Minimum required Rated Working Pressure (RWP) the BOPE and wellhead must meet or exceed:
5000 psi. The tubing/casing spool pressure rating is 5k top and 3k bottom.
x If the BOP is used to shut in on the well in a well control situation, ALL BOP components utilized
for well control must be tested prior to the next trip into the wellbore. This pressure test will be
charted same as the 14 day BOP test.
x All AOGCC regulations within 20 AAC 25.033 “Primary well control for drilling: drilling fluid
program and drilling fluid system”
x All AOGCC regulations within 20 AAC 25.035 “Secondary well control for primary drilling and
completion: blowout prevention equipment and diverter requirements”
x Review all conditions of approval of the PTD on the 10-401 form. Ensure that the conditions of
approval are captured in shift handover notes until they are executed and complied with.
x Ensure AOGCC approved drilling permit is posted on the rig floor and in Co Man office.
Minimum required Rated Working Pressure (RWP) the BOPE and wellhead must meet or exceed:
5000 psi.
Page 10 PTD Program February 1, 2023
TBU A-10RD3
Drilling Program
For PTD
Summary of BOP Equipment and Test Requirements
Hole Section Equipment Test Pressure (psi)
8-1/2” and 6-1/8”
x 13-5/8” Shaffer 5M annular
x 13-5/8” 5M Shaffer SL Double gate
x Blind ram in bottom cavity
x Mud cross
x 13-5/8” 5M Shaffer SL single gate
x 3-1/16” 5M Choke Manifold
x Standpipe, floor valves, etc
Test: 250/3500
(Annular 2500 psi)
x Primary closing hydraulic pressure is provided by an electrically driven triplex pump. Secondary
back-up is an air pump, and tertiary emergency pressure is provided by bottled nitrogen.
Required AOGCC Notifications:
x Well control event (BOPs utilized to shut in the well to control influx of formation fluids).
x 48 hours notice prior to full BOPE test.
x Any other notifications required in APD conditions of approval.
Regulatory Contact Information:
AOGCC
Jim Regg / AOGCC Inspector / (O): 907-793-1236 / Email: jim.regg@alaska.gov
Bryan McLellan / Petroleum Engineer / (O): 907-793-1226 / (C): 907-250-9193 / Email: bryan.mclellan@alaska.gov
Mel Rixse / Petroleum Engineer / (O): 907-793-1231 / Email: melvin.rixse@alaska.gov
Primary Contact for Opportunity to witness: AOGCC.Inspectors@alaska.gov
Test/Inspection notification standardization format: http://doa.alaska.gov/ogc/forms/TestWitnessNotif.html
Notification / Emergency Phone: 907-793-1236 (During normal Business Hours)
Notification / Emergency Phone: 907-659-2714 (Outside normal Business Hours)
Page 11 PTD Program February 1, 2023
TBU A-10RD3
Drilling Program
For PTD
10. BOP N/U and Test
1. N/D Tree and adapter and install test dart (BPV installed as part of pre-rig work)
2. N/U to 13-5/8” 5M tubing spool
3. N/U 13-5/8” x 5M BOP as follows (top down):
x 13-5/8” x 5M Shaffer annular BOP.
x 13-5/8” Shaffer Type “SL” Double ram. (2-7/8” X 5” VBR in top cavity, blind ram in btm
cavity)
x 13-5/8” mud cross
x 13-5/8” Shaffer Type “SL” single ram. (2-7/8” X 5” VBR)
x N/U pitcher nipple, install flowline.
x Install (2) manual valves on kill side of mud cross. Manual valve used as inside or “master
valve”.
x Install (1) manual valve on choke side of mud cross. Install an HCR outside of the manual
valve.
4. Test BOPE
x Test BOP to 250/3500 psi for 5/5 min. Test annular to 250/2500 psi for 5/5 min.
x Ensure to leave “A” section side outlet valves open during BOP testing so pressure does not
build up beneath the BPV. Confirm the correct valves are opened.
x Test VBRs on 4-1/2” and 5” test joints (largest and smallest tubulars)
x Test Annular on 4-1/2” test joint (2500 psi)
x Ensure gas monitors are calibrated and tested in conjunction w/ BOPE.
5. Pull left hand test dart
6. Pull BPV
x Monitor well to ensure static
11. Mud Program and Density Selection Criteria
1. Mix 9.2 ppg OBM for 8-1/2” hole section.
2.6” liners are currently installed in mud pump #1 and pump #2. (FD-1600)
x The FD-1600 pumps are rated at 4665 psi with 6” liners and can each deliver 441 gpm at 100
spm.
x Pump range for drilling will be 380-550 gpm. This can be achieved with one or both pumps.
Page 12 PTD Program February 1, 2023
TBU A-10RD3
Drilling Program
For PTD
3. 8-1/2”Production hole mud program summary:
x Primary weighting material to be used for the hole section will be barite to minimize solids.
Ensure enough barite is on location to weight up the active system 1ppg above highest
anticipated MW in the event of a well control situation.
x Pason PVT will be used throughout the drilling and completion phase. Remote monitoring
stations will be available at the driller’s console, Co Man office, and Toolpusher office.
System Type: 9.2 ppg 80/20 Enviromul MOBM
Properties:
Section Mud
Weight Viscosity Plastic
Viscosity Yield Point pH HPHT
8-1/2”9.2-10.4 50-80 25-35 15-22 8.5-9.5 5.0
System Formulation: 80/20 Enviromul MOBM
Product Concentration
LVT
Water
INVERMUL NT
EZ MUL NT
GELTONE V
Lime
DURATONE HT
Calcium Chloride
BAROID 41
BARACARB 5
BARABLOK
BAROTROL PLUS
0.662 bbl
.172 bbl
4 ppb
4 ppb
6-10 ppb
7 ppb
2 ppb
21 ppb
9.0 ppg (as needed)
3-5 ppb
2 ppb
4 ppb
x No cuttings will be allowed to be overboarded. Use lubes as required.
x The use of good drilling practices to minimize excessive swab and surge pressure should be
employed to reduce the chances for losses and differential sticking. LCM (BARACARBs
Minimum EMW needed = 8.5 - 9.0 ppg DLB
Page 13 PTD Program February 1, 2023
TBU A-10RD3
Drilling Program
For PTD
5/25/50, STEELSEAL 50/100/400) and shale stabilizers (BAROTROL PLUS, SOLTEX)
should be maintained at elevated concentrations while drilling coals to help strengthen the
wellbore.
x Barolift (fibers)to be used for hole cleaning
x Maintain 10 ppb in background LCM
4. Program mud weights are generated by reviewing data from producing & shut in offset wells, estimated
BHP’s from formations capable of producing fluids or gas and formations which could require mud
weights for hole stabilization.
5. A guiding philosophy will be that it is less risky to weight up a lower weight mud than be overbalanced
and have the challenge to mitigate lost circulation while drilling ahead.
12. Decomplete / Set CIBP / Set Whipstock / Mill Window
x BOP Test interval for this section is 7 days -To comply with state regulations, record mud weights in and out
are recorded in WellEZ.
Operation Steps:
1.Recover 548’ of 4-1/2” IBT kill string.
2. Set wear bushing in wellhead. Ensure ID of wear bushing > 6-1/8”.
3. Set 9-5/8” CIBP at 5,525’(9-5/8” collar at TBD’)
4. Test casing to 3500 psi.
5. Make up the WIS 9-5/8” Mechanical set WIS Whipstock.
6. TIH with DP to the whipstock setting depth. Exercise caution when RIH / setting slips with whipstock
assembly
¾Fill the drill pipe a minimum of every 20 stands on the trip in the hole with the whipstock assembly.
¾Avoid sudden starts and stops while running the whipstock.
¾Recommend running in the hole at a maximum of 90-120 seconds per stand taking care not to spud or catch
the slips. Ensure running string is stationary prior to insertion of the slips and that slips are removed slowly
when releasing the work string to RIH. These precautions are required to avoid any weakening of the
whipstock shear mechanisms and / or to avoid part / preset on the packer.
7. Orient whipstock as directed by the directional driller. The directional plan specifies 30 deg LOHS.
8. Set the top of the whipstock at ~5,500’ MD
x Ensure 9.2 ppg mud in/out prior to milling window
x 9-5/8” collar at xxxx’
Note that 50 ppm H2S was encountered upon initial circulation in A-10RD2 on 4/6/22. -bjm
Page 14 PTD Program February 1, 2023
TBU A-10RD3
Drilling Program
For PTD
9. Mill window plus 20’-50’ of new hole (DO NOT EXCEED 50’ OF NEW HOLE BEFORE RUNNING
THE PLANNED FIT/LOT).
¾Use ditch magnets to collect the metal shavings. Clean regularly.
¾Ensure any personnel working around metal shavings wear proper PPE, including goggles, face shield and
Kevlar gloves.
¾Work the upper mill through the window to confirm the window milling is complete and circulate well clean
(circulate a minimum of 1-1/2 bottoms up). Pump a high-vis super sweep to remove metal shavings and
make every effort to remove all of the super sweep pill from the mud system as it is circulated to surface.
10. Pull starter mill into casing above top of whipstock, flow check the well for 10 minutes and conduct a
FIT to 13.7 ppg.
¾Assuming the kick zone is at TD, a FIT of 13.7 ppg EMW gives an infinite Kick Tolerance with 9.2 ppg mud
weight. Send FIT chart to Drilling Engineer.
¾The parent well 9-5/8” shoe passed a 13.7 ppg FIT
11. POOH and LD milling assembly
¾Once out of the hole, inspect mill gauge and record.
¾Flow check well for 10 minutes to confirm no flow:
¾Before pulling off bottom.
¾Before pulling the BHA through the BOPE.
12. Flush the stack/lines to remove metal debris that may have settled out in these areas. Ensure BOP
equipment is operable.
13. Drill 8-1/2” Intermediate Hole Section
x BOP Test interval for this section is 14 days –AOGCC approval is required after second BOPE test for 14
day frequency. To comply with state regulations, record mud weights in and out and ensure BOPE function test
are recorded in WellEZ before the 7 day deadline.
1. PU 4,550’(less BHA length) of 4-1/2” CDS40 and 950’ of 5” NC50 drill pipe for start of drilling.
x Non-rotating protectors will be run on the 5” DP. Splitting this hole section into shorter runs
can provide more adequate NRP coverage from start to end of each run.
Page 15 PTD Program February 1, 2023
TBU A-10RD3
Drilling Program
For PTD
x The first 950’ of 5” will have 1 NRP per joint. Continue to run 1 NRP per joint for first 2000’
of 5” run.
x For next 3450’ of 5” run 2 NRP’s per joint. Drill to ~10050’ MD
x POOH to 4-1/2”DP and add ~4,550’ of 4-1/2” DP to reach 14,600. Keep same 5” NRP
configuration (2000’ of 1/jt then 3450’ of 2/jt).
2. P/U 6-3/4” Sperry Sun motor drilling assy w/ GR/Res only for the intermediate section
3. Ensure BHA Components have been inspected previously.
4. Drift & caliper all components before M/U. Visually verify no debris inside components that
cannot be drifted.
5. Ensure TF offset is measured accurately and entered correctly into the MWD software.
6. Have DD run hydraulics models to ensure optimum TFA. Plan to pump at 400-550 gpm.
7. Production section will be drilled with Rotary Steerable tools. Must keep up with 3 deg/100 DLS in
the turn and drop sections of the wellbore.
8. Primary bit will be the Baker Hughes Kymera 8-1/2” KM524. Ensure to have a backup PDC bit
available on location.
9. TIH to window. Shallow test MWD on trip in.
10. TIH through window ensure MWD service rep on rig floor during this operation.
11. Circulate well with 9.2 ppg OBM to warm up mud until good 9.2 ppg in and out.
12.Drill approx. 20’ rat hole to accommodate the drilling assembly. Ream shoe as needed to assure
there is little or no drag. After reaming, shut off pumps and rotary (if hole conditions allow) and
pass through shoe checking for drag.
13. Circulate Bottoms Up until MW in = MW out.
14. Drill 8-1/2” hole to 14,800’ It is acceptable to let the MW drift up while drilling the Tyonek.
x Pump sweeps and maintain mud rheology to ensure effective hole cleaning.
x Utilize Inlet experience to drill through coal seams efficiently. Try to avoid sliding through
coal seams. Work through coal seams once drilled.
x Keep swab and surge pressures low when tripping.
x See attached mud program for hole cleaning and LCM strategies.
x Ensure solids control equipment functioning properly and utilized to keep LGS to a
minimum without excessive dilution.
x Adjust MW as necessary to maintain hole stability.
x Ensure mud engineer set up to perform HTHP fluid loss.
Page 16 PTD Program February 1, 2023
TBU A-10RD3
Drilling Program
For PTD
x Maintain API fluid loss < 6.
x Take MWD surveys every stand drilled.
x Minimize backreaming when working tight hole
15. At TD pump a sweep and a marker to be used as a fluid caliper to determine annulus volume for
cement calculations. CBU, and pull a wiper trip back to the window.
16. TOH with drilling assembly, handle BHA as appropriate.
14. Run 7” Intermediate Liner
1.Install 7”Rams in upper cavity. Test to 3500 psi
2. R/U Baker liner running equipment.
x Ensure DP crossover on rig floor and M/U to FOSV.
x R/U fill up line to fill liner while running.
x Ensure all liner has been drifted and tally verified prior to running.
x Be sure to count the total # of joints before running.
x Keep hole covered while R/U running equipment.
x Record OD’s, ID’s, lengths, S/N’s of all components w/ vendor & model info.
3. P/U 8.25” Reamer shoe, 7” casing, quick connect and setting sleeve
x Centralizers will be run, 1 per joint
x Fill liner while running using fill up line on rig floor.
x Use “API Modified” thread compound. Dope pin end only w/ paint brush.
x Utilize a collar clamp until weight is sufficient to keep slips set properly.
x Ensure to run enough liner to provide at least 100’ overlap inside 9-5/8” casing. Ensure
hanger/pkr will not be set in a 9-5/8” connection.
4. Circulate 1-1/2 casing volume at 9-5/8” window prior to going into open hole. Stage pumps up
slowly and monitor for losses.
5. Obtain up and down weights of the liner before entering open hole. Record rotating torque at 10, 20,
& 30 rpm.
6. Continue to fill the string every 10 joints while running casing in open hole. Do not stop to fill
casing.
7. Run inner string consisting of 6-1/8” bit, 4-1/2” DP, HRD-E setting tool, and pack off
x 4000’ of casing will be stationary in open hole while picking up the inner string
Page 17 PTD Program February 1, 2023
TBU A-10RD3
Drilling Program
For PTD
8. Circulate 1-1/2 OH volume after MU of inner string to condition to mud. Stage pumps up slowly
and monitor for losses.
9. Obtain up and down weights. Record rotating torque at 10, 20, & 30 rpm.
10. RIH w/ casing on DP no faster than 1 min / stand. Watch displacement carefully and avoid surging
the hole. Slow down running speed if necessary.
11. M/U top drive and fill pipe while lowering string every 10 stands.
12. Set slowly in and pull slowly out of slips.
13. RIH with 5” DP. This casing/inner string configuration is designed to wash, ream, or drill the casing
to TD.
x Limit running torque to the MUT of the 5” DP –26,000 ft-lbs
x PUW with the 7” casing and DP is expected to be ~500klbf. 80% of the derrick rating is
600klbf.
14. At TD drop ball to release the running tool per BOT.
15.LD 5” x 4-1/2” DP
Page 18 PTD Program February 1, 2023
TBU A-10RD3
Drilling Program
For PTD
Page 19 PTD Program February 1, 2023
TBU A-10RD3
Drilling Program
For PTD
Page 20 PTD Program February 1, 2023
TBU A-10RD3
Drilling Program
For PTD
Page 21 PTD Program February 1, 2023
TBU A-10RD3
Drilling Program
For PTD
Page 22 PTD Program February 1, 2023
TBU A-10RD3
Drilling Program
For PTD
15. Cement 7” Intermediate Casing
1. Hold a pre-job safety meeting over the upcoming cmt operations.
2. Install 2-7/8 x 5” VBRs in upper cavity. Test to 3500 psi
3. M/U Baker cement retainer and 4-1/2” DP followed by the seal assembly, ZXP LTP, and running tools.
x Space out cement retainer to be in middle of first full joint above the reamer shoe
4. RIH keeping pressure below 2500 psi to avoid potential set of the LTP. Stab seal assembly then set liner
hanger and release via the delayed opening ball seat.
5. Set the cement retainer with right hand rotation per BOT.
6. Pump 15 bbls 12.5 ppg spacer.
7. Test surface cmt lines to 4500 psi.
8. Pump remaining 10 bbls 12.5 ppg spacer.
9. Mix and pump 45 bbls of 15.3 ppg EasyBLOK per below recipe with XX lbs/bbl of loss circulation
fiber. Ensure cmt is pumped at designed weight. Job is designed to pump 50% OH excess but if
wellbore conditions dictate otherwise decrease or increase excess volumes as necessary. Cement volume
is designed to bring cement to 13,800’ TMD (1000’ of OH).
10. Displacement fluid will be CLEAN drilling mud (No clean out run planned). Ensure displacement
calculation considers 4-1/2” or 5” DP. Underdisplace cement by 10 bbls to ensure good quality cement
at the retainer and shoe before pulling the cement stinger from the retainer.
Cement Estimates for TOC at 13,800’ (1000’ of OH cement)
8-1/2”OH x 7” Casing:(14,800’ –13,800’) x 0.226 x 1.5 =34 bbls
Shoe Track:20’ x 0.0371 =0.7 bbls
Under displaced volume:10 bbls
Total Volume (bbls):45 bbls
Total Volume (ft3):45 bbls x 5.615 ft3/bbl =253 ft3
Total Volume (sx):253 ft3 / 1.34 ft3/sk =189 sx
Verified cement calcs. -bjm
Page 23 PTD Program February 1, 2023
TBU A-10RD3
Drilling Program
For PTD
Slurry Information:
System EasyBLOK
Density 15.3 lb/gal
Yield 1.34 ft3/sk
Mixed Water 5.879 gal/sk
Mixed Fluid 5.879 gal/sk
Expected Thickening 70 Bc at 05:00 hr:mn
API Fluid Loss <25 mL in 30.0 min at 155degF / 1000 psi
Additives
Code Description Concentration
G
D046
D202
D400
D154
Cement
Anti Foam
Dispersant
Gas Control Agent
Extender
94 lb/sk
0.2% BWOC
1.5% BWOC
0.8% BWOC
8.0% BWOC
11. Circulate out excess cement at maximum rate.
12. Pressure up to 4200 psi to release the running tool (HRD-E) from the liner
13. Bleed pressure to zero to check retainer integrity
14. P/U, verify setting tool is released, and expose setting dogs on top of tieback sleeve
15. Rotate slowly and slack off 50k downhole to set ZXPN.
16. Pressure up drill pipe to 500 psi and pick up to remove the RS packoff bushing from the RS nipple.
Bump up pressure as req’d to maintain 500 psi DP pressure while moving pipe until the pressure drops
rapidly, indicating pack-off is above the sealing area (ensure that 500 psi will be enough to overcome
hydrostatic differential at liner top).
17. Immediately with the loss of pressure and before DP reaches zero, initiate circulation while picking up
to position the bottom of the stinger inside the tieback sleeve. Increase pump rate to wellbore clean up
rate until the sleeve area is thoroughly cleaned.
Page 24 PTD Program February 1, 2023
TBU A-10RD3
Drilling Program
For PTD
18. Pick up to the high-rate circulation point above the tieback extension, mark the pipe for reciprocation, do
not re-tag the liner top, and circulate the well clean.
19. Watch for cement returns and record the estimated volume. Rotate & circulate to clear cmt from DP.
20. POOH, LDDP. Verify the liner top packer received the required setting force by inspecting the rotating
dog sub.
Backup release from liner hanger:
x If the HRD-E tool still does not release hydraulically, left-hand (counterclockwise) torque will have to
be applied to the tool. This torque acts to shear brass screws. Bleed off pump pressure and ensure that
the tool is in the neutral position. Apply left-hand torque as required to shear screws.
x NOTE: Some hole conditions may require movement of the drillpipe to “work” the torque down to the
setting tool.
x After screws have sheared, the top sub and body of the setting tool will turn 1/4 turn. Then proceed
slacking off set-down weight to shear second set of shear screws. The top sub will drop 1-3/4 inches. At
this point, the bottom sub no longer supports the collet fingers. Pick straight up with workstring to
release collet from the profile.
Ensure to report the following on Wellez:
x Pre flush type, volume (bbls) & weight (ppg)
x Cement slurry type, lead or tail, volume & weight
x Pump rate while mixing, bpm, note any shutdown during mixing operations with a duration
x Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight & type
of displacing fluid
x Note if liner is reciprocated or rotated during the job
x Calculated volume of displacement , actual displacement volume, whether plug bumped & bump
pressure, do floats hold
x Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating
pressure
x Note if pre flush or cement returns at surface & volume
x Note time cement in place
x Note calculated top of cement
x Add any comments which would describe the success or problems during the cement job
Note: Send Csg & cmt report + “As-Run” liner tally to sean.mclaughlin@hilcorp.com
Page 25 PTD Program February 1, 2023
TBU A-10RD3
Drilling Program
For PTD
16. Drill 6-1/8” Hole Section
x BOP Test interval for this section is 14 days –AOGCC approval is required after second BOPE test for 14
day frequency. To comply with state regulations, record mud weights in and out and ensure BOPE function test
are recorded in WellEZ before the 7 day deadline.
1.Test Shoe, Liner and Liner lap to 3500 psi.
2. PU 11,000’of 4-1/2” CDS40 and 950’ of 5” NC50 drill pipe for start of drilling.
x The first 950’ of 5” will have 1 NRP per joint.
x For next 3950’ of 5” run 2 NRP’s per joint. Ensure 5” DP does not enter the 7” TOL (5,300’).
3. P/U 4-3/4” Sperry Sun motor drilling assy w/ triple combo tools (DEN, POR, RES).
4. Drift & caliper all components before M/U. Visually verify no debris inside components that
cannot be drifted.
5. Ensure TF offset is measured accurately and entered correctly into the MWD software.
6. Have DD run hydraulics models to ensure optimum TFA. Plan to pump at 150 - 300 gpm.
7. Production section will be drilled with rotary steerable tools. Must keep up with 3 deg/100 DLS in
the drop sections of the wellbore.
8. Primary bit will be the Baker Hughes Kymera 6-1/8” KM323. Ensure to have a backup PDC bit
available on location.
9. TIH to the cement retainer.
10. Circulate well with 9.2 ppg OBM to warm up mud until good 9.2 ppg in and out.
11. Mill Cement Retainer, shoe track, plus 20’-50’of new hole.
¾Use ditch magnets to collect the metal shavings. Clean regularly.
¾Ensure any personnel working around metal shavings wear proper PPE, including goggles, face shield
and Kevlar gloves.
12. Pull bit into casing, flow check the well for 10 minutes and conduct a FIT to 13.7 ppg.
¾Assuming the kick zone is at TD, a FIT of 13.7 ppg EMW gives an infinite Kick Tolerance volume
with 9.2 ppg mud weight.
13. Drill 6-1/8” hole to TD.
x Pump sweeps and maintain mud rheology to ensure effective hole cleaning.
Page 26 PTD Program February 1, 2023
TBU A-10RD3
Drilling Program
For PTD
x Utilize Inlet experience to drill through coal seams efficiently. Try to avoid sliding through
coal seams. Work through coal seams once drilled.
x Keep swab and surge pressures low when tripping.
x See attached mud program for hole cleaning and LCM strategies.
x Ensure solids control equipment functioning properly and utilized to keep LGS to a
minimum without excessive dilution.
x Adjust MW as necessary to maintain hole stability.
x Ensure mud engineer set up to perform HTHP fluid loss.
x Maintain API fluid loss < 6.
x Take MWD surveys every stand drilled.
x Minimize backreaming when working tight hole
14. At TD pump a sweep and a marker to be used as a fluid caliper to determine annulus volume for
cement calculations. CBU, and pull a wiper trip back to the window.
15. TOH with drilling assembly, handle BHA as appropriate.
17. Run 4-1/2” Production Liner
1. R/U Baker 4-1/2” liner running equipment.
x TBD if running on 4-1/2” or 4-1/2”x5” tapered drill string
x Ensure DP crossover on rig floor and M/U to FOSV.
x R/U fill up line to fill liner while running.
x Ensure all liner has been drifted and tally verified prior to running.
x Be sure to count the total # of joints before running.
x Keep hole covered while R/U running equipment.
x Record OD’s, ID’s, lengths, S/N’s of all components w/ vendor & model info.
2. P/U shoe joint, visually verify no debris inside joint.
3. Continue M/U & thread locking shorty shoe track assy consisting of:
x (1) Shoe joint w/ shoe bucked on & threadlocked (coupling also thread locked).
x (1) Joint with float collar bucked on pin end & threadlocked (coupling also thread locked).
x (1) Landing collar.
x Centralizers will be run on 4-1/2” liner, 1 per joint
x Ensure proper operation of float shoe & FC.
4. Continue running 4-1/2” production liner to TD
x Short joint run every 500’
x Fill liner while running using fill up line on rig floor.
Page 27 PTD Program February 1, 2023
TBU A-10RD3
Drilling Program
For PTD
x Use “API Modified” thread compound. Dope pin end only w/ paint brush.
x Utilize a collar clamp until weight is sufficient to keep slips set properly.
5. Ensure to run enough liner to provide at least 100’ overlap inside 7” casing. Ensure hanger/pkr will
not be set in a 7” connection.
6. Before picking up Baker ZXP liner hanger / packer assy, count the # of joints on the pipe deck to
make sure it coincides with the pipe tally.
7.M/U Baker ZXP liner top packer. Fill liner tieback sleeve with “XANPLEX”, ensure mixture is
thin enough to travel past the HRD tool and down to the packoff. Wait 30 min for mixture to set up.
8. RIH one stand and circulate a minimum of one liner volume. Note weight of liner.
9. RIH w/ liner on DP no faster than 1 min / stand once liner hanger in in the 7”. Watch displacement
carefully and avoid surging the hole. Slow down running speed if necessary.
10. M/U top drive and fill pipe while lowering string every 10 stands.
11. Set slowly in and pull slowly out of slips.
12. Circulate 1-1/2 drill pipe and liner volume at 7” window prior to going into open hole. Stage pumps
up slowly and monitor for losses.
13. Obtain up and down weights of the liner before entering open hole. Record rotating torque at 10,
20, & 30 rpm.
14. Continue to fill the string every 10 joints while running liner in open hole. Do not stop to fill
casing.
15. P/U the cmt stand and tag bottom with the liner shoe. P/U 2’ off bottom. Note slack-off and pick-
up weights. Record rotating torque values at 10, 20, & 30 rpm.
16. Stage pump rates up slowly to circulating rate without exceeding 60% of the liner hanger setting
pressure. Circ and condition mud with the liner on bottom. Reduce the low-end rheology of the
drilling fluid by adding water and thinners.
17. Reciprocate & rotate string if hole conditions allow. Circ until hole and mud is in good condition
for cementing.
Page 28 PTD Program February 1, 2023
TBU A-10RD3
Drilling Program
For PTD
Page 29 PTD Program February 1, 2023
TBU A-10RD3
Drilling Program
For PTD
18. Cement 4-1/2” Production Liner
1. Hold a pre-job safety meeting over the upcoming cmt operations.
2. Attempt to reciprocate the casing during cmt operations until hole gets sticky.
3. Pump 15 bbls 12.5 ppg spacer.
4. Test surface cmt lines to 4500 psi.
5. Pump remaining 10 bbls 12.5 ppg spacer.
6. Mix and pump 30 bbls of 15.3 ppg EasyBLOK per below recipe with XX lbs/bbl of loss circulation
fiber. Ensure cmt is pumped at designed weight. Job is designed to pump 50% OH excess but if
wellbore conditions dictate otherwise decrease or increase excess volumes as necessary. Cement
volume is designed to bring cement to 14,600’ TMD (TOL).
7. Displacement fluid will be CLEAN drilling mud (No clean out run planned). Ensure displacement
calculation considers 4-1/2” or 5” DP.
Cement Estimates
7” 29#x 4.5” Liner:(14,800’ –14,600’) x 0.01748 =3.5 bbls
6-1/8”OH x 4.5” Liner:(15,807’ –14,800’) x 0.01677 x 1.5 =25.3 bbls
Shoe Track:60’ x 0.0152 =0.9 bbls
Total Volume (bbls):3.5 + 25.3 + 0.9 =30 bbls
Total Volume (ft3):30 bbls x 5.615 ft3/bbl =169 ft3
Total Volume (sx):169 ft3 / 1.34 ft3/sk =226 sx
d p
Verified cement calcs. -bjm
126 sx -bjm
Page 30 PTD Program February 1, 2023
TBU A-10RD3
Drilling Program
For PTD
Slurry Information:
System EasyBLOK
Density 15.3 lb/gal
Yield 1.34 ft3/sk
Mixed Water 5.879 gal/sk
Mixed Fluid 5.879 gal/sk
Expected Thickening 70 Bc at 05:00 hr:mn
API Fluid Loss <25 mL in 30.0 min at 155degF / 1000 psi
Additives
Code Description Concentration
G
D046
D202
D400
D154
Cement
Anti Foam
Dispersant
Gas Control Agent
Extender
94 lb/sk
0.2% BWOC
1.5% BWOC
0.8% BWOC
8.0% BWOC
8. Drop DP dart and displace with 9.2 ppg OBM.
9. Pump cement at max rate of 5 bbl/min. Reduce pump rate to 3 bpm prior to latching DP dart into
liner wiper plug. Note plug departure from liner hanger running tool and resume pumping at full
displacement rate. Displacement volume can be re-zeroed at this point
10. If elevated displacement pressures are encountered, position liner at setting depth and cease
reciprocation. Monitor returns & pressure closely while circulating. Notify Drilling Foreman
immediately of any changes. Reduce pump rate as required to avoid packoff.
11. Bump the plug and pressure up to up as required by Baker procedure to set the liner hanger (15%
above nominal setting pressure. Hold pressure for 3-5 minutes.
12. Slack off total liner weight plus 30k to confirm hanger is set.
13. Do not overdisplace by more than 1 bbls. Shoe track volume is 0.9 bbls.
14. Pressure up to 4200 psi to release the running tool (HRD-E) from the liner
15. Bleed pressure to zero to check float equipment.
Page 31 PTD Program February 1, 2023
TBU A-10RD3
Drilling Program
For PTD
16. P/U, verify setting tool is released, and expose setting dogs on top of tieback sleeve
17. Rotate slowly and slack off 50k downhole to set ZXPN.
18. Pressure up drill pipe to 500 psi and pick up to remove the RS packoff bushing from the RS nipple.
Bump up pressure as req’d to maintain 500 psi DP pressure while moving pipe until the pressure
drops rapidly, indicating pack-off is above the sealing area (ensure that 500 psi will be enough to
overcome hydrostatic differential at liner top).
19. Immediately with the loss of pressure and before DP reaches zero, initiate circulation while picking
up to position the bottom of the stinger inside the tieback sleeve. Increase pump rate to wellbore
clean up rate until the sleeve area is thoroughly cleaned.
20. Pick up to the high-rate circulation point above the tieback extension, mark the pipe for
reciprocation, do not re-tag the liner top, and circulate the well clean.
21. Watch for cement returns and record the estimated volume. Rotate & circulate to clear cmt from
DP.
22. POOH, LDDP. Verify the liner top packer received the required setting force by inspecting the
rotating dog sub.
Backup release from liner hanger:
x If the HRD-E tool still does not release hydraulically, left-hand (counterclockwise) torque will have to
be applied to the tool. This torque acts to shear brass screws. Bleed off pump pressure and ensure that
the tool is in the neutral position. Apply left-hand torque as required to shear screws.
x NOTE: Some hole conditions may require movement of the drillpipe to “work” the torque down to the
setting tool.
x After screws have sheared, the top sub and body of the setting tool will turn 1/4 turn. Then proceed
slacking off set-down weight to shear second set of shear screws. The top sub will drop 1-3/4 inches. At
this point, the bottom sub no longer supports the collet fingers. Pick straight up with workstring to
release collet from the profile.
Ensure to report the following on Wellez:
x Pre flush type, volume (bbls) & weight (ppg)
x Cement slurry type, lead or tail, volume & weight
x Pump rate while mixing, bpm, note any shutdown during mixing operations with a duration
Page 32 PTD Program February 1, 2023
TBU A-10RD3
Drilling Program
For PTD
x Pump rate while displacing, note whether displacement by pump truck or mud pumps, weight & type
of displacing fluid
x Note if liner is reciprocated or rotated during the job
x Calculated volume of displacement , actual displacement volume, whether plug bumped & bump
pressure, do floats hold
x Percent mud returns during job, if intermittent note timing during pumping of job. Final circulating
pressure
x Note if pre flush or cement returns at surface & volume
x Note time cement in place
x Note calculated top of cement
x Add any comments which would describe the success or problems during the cement job
Note: Send Csg & cmt report + “As-Run” liner tally to sean.mclaughlin@hilcorp.com
19. Run Completion Assembly
1.A dedicated run to clean out and displace the OBM out of the 1100’ of 4-1/2” liner is not planned.
Coiled tubing will make a CO run prior to perforating.
2. Run 4-1/2” tubing completion assembly to above the liner top
x Tubing will be 4-1/2” L-80 12.6# H533
x SSSV to be placed at 500’
x CIM to be placed at 2000’
x GLM will be run.
3. Swap the well over to FIW
x Circulate a hi-vis pill followed by a soap train per Baroid
x Circulate FIW until clean-up is satisfactory.
x Leave FIW in the annulus.
4. Space out and land seal bore in tie back sleeve. RILDs.
5. Test IA and tubing to 3500 psi. Charted 30 min test
6. Install BPV in wellhead.
7. ND BOPE, NU tree, test void
8. Rig Down
Page 33 PTD Program February 1, 2023
TBU A-10RD3
Drilling Program
For PTD
20. BOP Schematic
Page 34 PTD Program February 1, 2023
TBU A-10RD3
Drilling Program
For PTD
21. Wellhead Schematic (proposed)
Page 35 PTD Program February 1, 2023
TBU A-10RD3
Drilling Program
For PTD
22. Anticipated Drilling Hazards (8-1/2” and 6-1/8” hole sections)
Lost Circulation:
Ensure 500 lbs of medium/coarse fibrous material, 500 lbs SteelSeal (Angular, dual-composition
carbon-based material), & 500 lbs different sizes of Calcium Carbonate are available on location to mix
LCM pills at moderate product concentrations.
Hole Cleaning:
Maintain rheology w/ viscofier as necessary. Sweep hole w/ 20 hi-vis pill or Barolift fiber pill as
necessary. Optimize solids control equipment to maintain density and minimize sand content. Maintain
programmed mud specs. Planned wiper trips every 1000’.
Coal Drilling:
The following lessons were learned from extensive experience drilling coal seams in Cook Inlet. The
need for good planning and drilling practices is also emphasized as a key component for success.
x Keep the drill pipe in tension to prevent a whipping effect which can disturb coal sections.
x Use asphalt-type additives to further stabilize coal seams.
x Increase fluid density as required to control running coals.
x Emphasize good hole cleaning through hydraulics, ROP and system rheology.
x Minimize swab and surge pressures
x Minimize back reaming through coals when possible
H2S:
H2S is not present in this hole section.
Reservoir Pressure:
No abnormal temperatures or pressures are present in this hole section.
Close Approach:
Spurr TS-06 will have 30’ separation at 12,670’ MD. The intersection would occur at 7,828’ MD in the
offset well and above the reservoir abandonment plug. TS-06 is filled with 8.5 ppg ppg FIW and the
casing was last tested to 1,500 psi on 08/04/1992.
H2S:
H2S is not present in this hole section.DLB
Close Approach:pp
Spurr TS-06 will have 30’ separation at 12,670’ MD. The intersection would occur at 7,828’ MD in thepp, ,
offset well and above the reservoir abandonment plug. TS-06 is filled with 8.5 ppg ppg FIW and thep
casing was last tested to 1,500 psi on 08/04/1992.
H2S was encountered when drilling TBU A-10RD2 during initial
well entry and circulation. -bjm
Page 36 PTD Program February 1, 2023
TBU A-10RD3
Drilling Program
For PTD
23. FIT Procedure
Formation Integrity Test (FIT) and
Leak-Off Test (LOT) Procedures
Procedure for FIT:
1. Drill 20' of new formation below the casing shoe (this does not include rat hole below the shoe).
2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe.
3. Close the blowout preventer (ram or annular).
4. Pump down the drill stem at 1/4 to 1/2 bpm.
5. On a graph plot the fluid pumped (volume or strokes) vs. drill pipe pressure until appropriate surface
pressure is achieved for FIT at shoe. Add casing pressure test data to graph if recent and available.
6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes.
Record time vs. pressure in 1-minute intervals.
7. Bleed the pressure off and record the fluid volume recovered.
The pre-determined surface pressure for each formation integrity test is based on achieving an EMW at
least 1.0 ppg higher than the estimated reservoir pressure, and allowing for an appropriate amount of kick
tolerance in case well control measures are required.
Where required, the LOT is performed in the same fashion as the formation integrity test. Instead of
stopping at a pre-determined point, surface pressure is increased until the formation begins to take fluid;
at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure
monitored as with an FIT.
Page 37 PTD Program February 1, 2023
TBU A-10RD3
Drilling Program
For PTD
24. Choke Manifold Schematic
Page 38 PTD Program February 1, 2023
TBU A-10RD3
Drilling Program
For PTD
25. Casing Design Information
Page 39 PTD Program February 1, 2023
TBU A-10RD3
Drilling Program
For PTD
26. 8-1/2” Hole Section MASP
Page 40 PTD Program February 1, 2023
TBU A-10RD3
Drilling Program
For PTD
27. 6-1/8” Hole Section MASP
Page 41 PTD Program February 1, 2023
TBU A-10RD3
Drilling Program
For PTD
28. Plot (NAD 27) (Governmental Sections)
Page 42 PTD Program February 1, 2023
TBU A-10RD3
Drilling Program
For PTD
29. Slot Diagram
Page 43 PTD Program February 1, 2023
TBU A-10RD3
Drilling Program
For PTD
30. Directional Program (wp01) - Attached separately
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22503000375045005250600067507500825090009750True Vertical Depth (1500 usft/in)0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 9750 10500 11250 12000 12750 13500 14250Vertical Section at 33.66° (1500 usft/in)TBU A-10RD32500300035004000450050005500600065006950TBS A-10RD PB125003000350040004500500055006000650070007500800085009000950010000105001100011500120001250012786TBU A-10RD2 PB125003000350040004500500055006000650070007500800085009000950010000105001100011276TBU A-10RD2250030003500400045005000550060006500700075008000850090009500100001050011000115001200012500130001350014000145001500015500TBS A-10RD9 5/8" TOW4 1/2" Casing25003000350040004500500055006000650070007500800085009000950010000105001100011500120001250013000135001400014500150001550015807TBU A-10RD3 wp01KOP: 12.75º/100' : 5500' MD, 4105.91'TVD : 30° LT TFEnd Dir : 5517' MD, 4113.7' TVDStart Dir 3º/100' : 5537' MD, 4122.56'TVDEnd Dir : 6729.17' MD, 4687.58' TVDStart Dir 3º/100' : 15075.35' MD, 8641'TVDTotal Depth : 15806.9' MD, 9101' TVDHilcorp Alaska, LLCCalculation Method:Minimum CurvatureError System:ISCWSAScan Method: Closest Approach 3DError Surface: Ellipsoid SeparationWarning Method: Error RatioWELL DETAILS: Plan: TBU A-10Water Depth: 62.00+N/-S +E/-W Northing EastingLatitudeLongitude0.00 0.002523116.280 218864.51560° 53' 48.5593 N 151° 34' 43.6365 WSURVEY PROGRAMDate: 2022-11-16T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool25.00 900.00 A-10 SDI Keeper Gyro (TBS A-10) 3_Gyro-CT-KPR_Pipe957.00 1106.00 A-10 MSS (TBS A-10) 3_CB-Film-MSS1182.00 5500.00 A-10RD PB1 MWD OnTrak+Sag (TBS A-10RD PB1)3_MWD+IFR1+MS+Sag5500.00 5900.00 TBU A-10RD3 wp01 (Plan: TBU A-10RD3) 3_MWD_Interp Azi+Sag5900.00 15806.90 TBU A-10RD3 wp01 (Plan: TBU A-10RD3) 3_MWD+IFR1+MS+SagFORMATION TOP DETAILSNo formation data is availableREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: TBU A-10, True NorthVertical (TVD) Reference:WELL @ 101.00usft (Original Well Elev)Measured Depth Reference:WELL @ 101.00usft (Original Well Elev)Calculation Method: Minimum CurvatureProject:Trading Bay - McArthur River FieldSite:MonopodWell:Plan: TBU A-10Wellbore:Plan: TBU A-10RD3Design:TBU A-10RD3 wp01CASING DETAILSTVD TVDSS MD Size Name4105.91 4004.91 5500.00 9-5/8 9 5/8" TOW9101.00 9000.00 15806.90 4-1/2 4 1/2" CasingSECTION DETAILSSecMD Inc Azi TVD +N/-S +E/-W Dleg TFace VSectTargetAnnotation1 5500.00 61.81 65.34 4105.91 1026.90 2074.64 0.00 0.002004.67 KOP: 12.75º/100' : 5500' MD, 4105.91'TVD : 30° LT TF2 5517.00 63.69 64.13 4113.70 1033.35 2088.30 12.75 -30.002017.62 End Dir : 5517' MD, 4113.7' TVD3 5537.00 63.69 64.13 4122.56 1041.17 2104.43 0.00 0.002033.07 Start Dir 3º/100' : 5537' MD, 4122.56'TVD4 6729.17 61.73 23.76 4687.58 1778.93 2820.11 3.00 -102.573043.82 End Dir : 6729.17' MD, 4687.58' TVD5 15075.35 61.73 23.76 8641.00 8506.46 5781.42 0.00 0.0010284.71 TBU A-10RD3 Start Dir 3º/100' : 15075.35' MD, 8641'TVD615806.90 39.78 23.76 9101.00 9021.82 6008.27 3.00 180.0010839.40 Total Depth : 15806.9' MD, 9101' TVD
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9000
9450
South(-)/North(+) (900 usft/in)1350 1800 2250 2700 3150 3600 4050 4500 4950 5400 5850 6300 6750 7200 7650
West(-)/East(+) (900 usft/in)
TBU A-10RD3
4500 4750500052505500575060006250650067506950TBS A
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10000
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TBU A-10RD2 PB1
4500 4750500052505500575060006250650067507000725075007750800082508
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1125011276 TBU A-10RD2
4500 4750500052505500575060006250650067507000725075007750800082508500875090009250950097501000010250105001075011000112501150011750120001225
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-10RD9 5/8" TOW
4 1/2" Casing
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TBU A-10R
D
3 wp01
KOP: 12.75º/100' : 5500' MD, 4105.91'TVD : 30° LT TF
End Dir : 5517' MD, 4113.7' TVD
Start Dir 3º/100' : 5537' MD, 4122.56'TVD
End Dir : 6729.17' MD, 4687.58' TVD
Start Dir 3º/100' : 15075.35' MD, 8641'TVD
Total Depth : 15806.9' MD, 9101' TVD
CASING DETAILS
TVD TVDSS MD Size Name
4105.91 4004.91 5500.00 9-5/8 9 5/8" TOW
9101.00 9000.00 15806.90 4-1/2 4 1/2" Casing
Project: Trading Bay - McArthur River Field
Site: Monopod
Well: Plan: TBU A-10
Wellbore: Plan: TBU A-10RD3
Plan: TBU A-10RD3 wp01
WELL DETAILS: Plan: TBU A-10
Water Depth: 62.00
+N/-S +E/-W Northing Easting Latitude Longitude
0.00 0.00 2523116.280 218864.515 60° 53' 48.5593 N 151° 34' 43.6365 W
REFERENCE INFORMATION
Co-ordinate (N/E) Reference:Well Plan: TBU A-10, True NorthVertical (TVD) Reference:WELL @ 101.00usft (Original Well Elev)
Measured Depth Reference:WELL @ 101.00usft (Original Well Elev)
Calculation Method:Minimum Curvature
667
1333
2000
2667
3333
4000
4667
5333
6000
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10000
South(-)/North(+) (1000 usft/in)2000 2667 3333 4000 4667 5333 6000 6667 7333 8000 8667
West(-)/East(+) (1000 usft/in)
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Azimuths to True North
Magnetic North: 15.11°
Magnetic Field
Strength: 54911.5nT
Dip Angle: 73.61°
Date: 2/20/2023
Model: BGGM2022
T M
Project: Trading Bay - McArthur River Field
Site: Monopod
Well: Plan: TBU A-10
Wellbore: Plan: TBU A-10RD3
Plan: TBU A-10RD3 wp01
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0.001.503.004.50Separation Factor6000 6600 7200 7800 8400 9000 9600 10200 10800 11400 12000 12600 13200 13800 14400 15000 15600 16200Measured DepthTS-06S-2RDS-08S-02S-02DPNTBS A-10RD PB1TBU A-10RD2 PB1TBS A-10RDTS-01S-05TS-03RDTS-08S-09PB1S-09Trading Bay State #1No-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.WELL DETAILS:Plan: TBU A-10 NAD 1927 (NADCON CONUS)Alaska Zone 04Water Depth: 62.00+N/-S +E/-W Northing EastingLatitudeLongitude0.000.002523116.280218864.51560° 53' 48.5593 N151° 34' 43.6365 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: TBU A-10, True NorthVertical (TVD) Reference:WELL @ 101.00usft (Original Well Elev)Measured Depth Reference:WELL @ 101.00usft (Original Well Elev)Calculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2022-11-16T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool25.00 900.00 A-10 SDI Keeper Gyro (TBS A-10) 3_Gyro-CT-KPR_Pipe957.00 1106.00 A-10 MSS (TBS A-10) 3_CB-Film-MSS1182.00 5500.00 A-10RD PB1 MWD OnTrak+Sag (TBS A-10RD PB1) 3_MWD+IFR1+MS+Sag5500.00 5900.00 TBU A-10RD3 wp01 (Plan: TBU A-10RD3) 3_MWD_Interp Azi+Sag5900.00 15806.90 TBU A-10RD3 wp01 (Plan: TBU A-10RD3) 3_MWD+IFR1+MS+Sag0.0035.0070.00105.00140.00175.00Centre to Centre Separation (60.00 usft/in)6000 6600 7200 7800 8400 9000 9600 10200 10800 11400 12000 12600 13200 13800 14400 15000 15600 16200Measured DepthNO GLOBAL FILTER: Using user defined selection & filtering criteria5500.00 To 15806.90Project: Trading Bay - McArthur River FieldSite: MonopodWell: Plan: TBU A-10Wellbore: Plan: TBU A-10RD3Plan: TBU A-10RD3 wp01CASING DETAILSTVD TVDSS MD Size Name4105.91 4004.91 5500.00 9-5/8 9 5/8" TOW9101.00 9000.00 15806.90 4-1/2 4 1/2" Casing
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.
TBU A-10RD3
Trading Bay Undefined Gas Pool
X
223-011
Gas-measurement log (in units or ppm vs measured depth) or mud log
recorded while drilling from the window at about 5,500' MD to 7-inch casing
point at about 14,800' MD is required to demonstrate the absence of
significant hydrocarbon reservoirs in the intermediate hole section.
SFD 3/1/2023
North Trading Bay Unit
X
X
CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders.
CAUTION: This email originated from outside the State of Alaska mail system. Do not
click links or open attachments unless you recognize the sender and know the content
is safe.
From:Sean McLaughlin
To:McLellan, Bryan J (OGC)
Subject:RE: [EXTERNAL] TBU A-10RD3 PTD questions
Date:Friday, February 17, 2023 4:04:07 PM
Attachments:SPR-06 Schematic 2017-11-10.pdf
Bryan,
The PTD number for TS-06 is 168-090. The reservoir has a P&A plug and the collision risk is above
the plug in the 9-5/8” casing around 7820’. I don’t see a significant well control concern. I do have
an open hole whipstock on standby in case there is an intersection. We may try to steer the well to
the east a bit but the torque model does not allow for any additional bending.
The rig on Monopod is Rig 56.
I agree 126 is the correct number of sxs.
Regards,
sean
From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>
Sent: Friday, February 17, 2023 3:06 PM
To: Sean McLaughlin <Sean.Mclaughlin@hilcorp.com>
Subject: [EXTERNAL] TBU A-10RD3 PTD questions
Sean,
A couple questions about the PTD application for this well
1. What is the PTD number for Spurr TS-06, the close approach well. Is that well currently
P&A’d? Any collision concerns?
2. What’s the name of the rig?
3. I think the number of sacks on the 4-1/2” liner cement job is incorrect. I get 126 sx instead of
226.
Bryan McLellan
Senior Petroleum Engineer
Alaska Oil & Gas Conservation Commission
333 W 7th Ave
Anchorage, AK 99501
Bryan.mclellan@alaska.gov
+1 (907) 250-9193
_____________________________________________________________________________________
Updated By: JLL 11/10/17
SCHEMATIC
North Trading Bay Field
Well: SPR-06
Last Completed: 09/20/1983
PTD: 168-090
API: 50-733-20153-00
PBTD: 10,430’ TD: 10,530’
9-5/8”
RKB to Mudline: 165’ RKB to MLLW: 98’
1
3
4
5
6
7
Stage collar @
2,946’
13-3/8”
36”
2
9,891’–9,893’
TBG & CSG
filled with
Inhibited 8.5
ppg FIW
TOC @
9,560’
CTM
Circulation
holes in Tbg
9,488’-9,490’
9,908’–9,909’
XN
CASING DETAIL
Size Wt Grade Conn ID Top Btm
36” Surf ~300’
13-3/8” 54.5# J-55 Butt 12.615” Surf 1,350’
9-5/8” 43.5# & 47#N-80 &
S-95 Butt 8.755”
8.681”Surf 10,498’
TUBING DETAIL
2-7/8” 6.5# N-80 OSS-HT 2.441” Surf 10,199’
PERFORATION DETAIL
Zone Top
(MD)
Btm
(MD)
Top
(TVD)
Btm
(TVD)FT Date Status
G-Zone 10,008' 10,074' 9,587' 9,652' 66' Isolated
G-Zone 10,110' 10,146' 9,688' 9,723' 36' Isolated
G-Zone 10,158' 10,182' 9,735' 9,759' 24' Isolated
Hemlock 10,203' 10,235' 9,779' 9,811' 32' Isolated
Hemlock 10,250' 10,345' 9,826' 9,920' 95' Isolated
Hemlock 10,360' 10,375' 9,935' 9,950' 15' Isolated
JEWELRY DETAIL
No Depth
(MD)
Depth
(TVD)ID Item
1
2,363’ 2,285’ Camco 2-7/8” KBM GLM #1
4,412’ 4,218’ Camco 2-7/8” KBM GLM #2
5,430’ 5,192’ Camco 2-7/8” KBM GLM #3
6,717’ 6,439’ Camco 2-7/8” KBM GLM #4
7,421’ 7,117’ Camco 2-7/8” KBM GLM #5 – Dummy
8,013’ 7,676’ Camco 2-7/8” KBM GLM #6
8,479’ 8,117’ Camco 2-7/8” KBM GLM #7 - Dummy
8,949’ 8,567’ Camco 2-7/8” KBM GLM #8
9,446’ 9,040’ Camco 2-7/8” KBM GLM #9
2 9,854’ 9,436’ Camco 2-7/8” KBM GLM #10 - Orifice
3 9,895’ 9,476’ Baker Hydraulic Packer
4 10,130’
9,707’ Otis XA SSD Sleeve (Records indicate sleeve is
open)
5 10,182’ 9,759’ XN Nipple
6 10,191’ 9,768’ Baker Permanent Packer
7 10,199’ 9,775’ EOT
Notes:
Fill @ 10,318 CTM 8/3/92
WELL PERMIT CHECKLISTCompanyHilcorp Alaska, LLCWell Name:TRADING BAY ST A-10RD3Initial Class/TypeDEV / 1-GASGeoArea820Unit12070On/Off ShoreOffProgramDEVField & PoolWell bore segAnnular DisposalPTD#:2230110TRADING BAY, UNDEFINED GAS - 800500NA1 Permit fee attachedYes2 Lease number appropriateYes3 Unique well name and numberNo Trading Bay Undefined Gas Pool4 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 partyYes10 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) (ForNA15 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)NA Sidetrack18 Conductor string providedYes19 Surface casing protects all known USDWsNA20 CMT vol adequate to circulate on conductor & surf csgNo Intermediate TOC is 1000' above casing shoe, which meets regulation.21 CMT vol adequate to tie-in long string to surf csgYes All known hydrocarbon zones will be covered. Mud logs will confirm.22 CMT will cover all known productive horizonsYes23 Casing designs adequate for C, T, B & permafrostYes24 Adequate tankage or reserve pitYes This well was suspended last summer due to drilling hole problems.25 If a re-drill, has a 10-403 for abandonment been approvedNo Close approach to a P&A'd well, intersection point above abandonment plug in P&A'd well.26 Adequate wellbore separation proposedNA27 If diverter required, does it meet regulationsYes28 Drilling fluid program schematic & equip list adequateYes29 BOPEs, do they meet regulationYes BOP rated to 5000 psi, MPSP = 3204, (BOP test to 3500 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 shutdownYes H2S was detected during initial circulation of previous sidetrack. Alarms will be in place.33 Is presence of H2S gas probableNA34 Mechanical condition of wells within AOR verified (For service well only)Yes H2S is not present in 8-1/2" & 6-1/8" hole sections.35 Permit can be issued w/o hydrogen sulfide measuresYes36 Data presented on potential overpressure zonesNA37 Seismic analysis of shallow gas zonesNo Well-established drilling platform.38 Seabed condition survey (if off-shore)NA39 Contact name/phone for weekly progress reports [exploratory only]ApprDLBDate2/8/2023ApprBJMDate3/1/2023ApprDLBDate2/8/2023AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDateJLC 3/2/2023
