Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout190-097Suspended Well Inspection Review Report Reviewed By:
P.I. Suprv
Comm ________
JBR 09/22/2025
InspectNo:susKPS250809173907
Well Pressures (psi):
Date Inspected:8/9/2025
Inspector:Kam StJohn
If Verified, How?Other (specify in comments)
Suspension Date:6/5/2020
#320-168
Tubing:0
IA:0
OA:0
Operator:Hilcorp Alaska, LLC
Operator Rep:Steve Soroka
Date AOGCC Notified:8/4/2025
Type of Inspection:Subsequent
Well Name:MILNE PT UNIT J-03
Permit Number:1900970
Wellhead Condition
All the valves where in working order with working gauges on the tubing, IA & OA
Surrounding Surface Condition
Good condition, No debris or trash
Condition of Cellar
Good condition, no water in cellar and no visible sheen
Comments
Location verified by pad map
Supervisor Comments
Photos (3) attached
Suspension Approval:Sundry
Location Verified?
Offshore?
Fluid in Cellar?
Wellbore Diagram Avail?
Photos Taken?
VR Plug(s) Installed?
BPV Installed?
Monday, September 22, 2025
2025-0809_Suspend_MPU_J-03_photos_ksj
Page 1 of 2
Suspended Well Inspection – MPU J-03
PTD 1900970
AOGCC Inspection Rpt # sus250809173907
Photos by AOGCC Inspector K. StJohn
8/9/2025
2025-0809_Suspend_MPU_J-03_photos_ksj
Page 2 of 2
1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown
Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program
Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Inspect Well
Hilcorp Alaska 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 5,449 feet N/A feet
true vertical 4,229 feet N/A feet
Effective Depth measured 5,354 feet feet
true vertical 4,164 feet feet
Perforation depth Measured depth See Schematic feet
True Vertical depth See Schematic feet
Tubing (size, grade, measured and true vertical depth)3-1/2" 9.3# / L-80 / EUE 8rd 4,685' 3,702'
Packers and SSSV (type, measured and true vertical depth)N/A See Above N/A
12. Stimulation or cement squeeze summary: N/A
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure: N/A
13.
Prior to well operation:
Subsequent to operation:
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:Chad Helgeson
Contact Name:
Authorized Title:Operations Manager
Contact Email:
Contact Phone:
4,679', 4,981' &
5,189'
3,698', 3,908' &
4,051'
777-8333
2. Operator Name
115'
2,680'
Senior Engineer: Senior Res. Engineer:
Collapse
1,130psi
2,020psi
Burst
3,730psi
3,520psi
Production
measured
N/A
Casing
Conductor
Size
Junk
Length
Surface
13-3/8"
MILNE PT UNIT J-03
14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283)
Gas-Mcf Casing Pressure Tubing Pressure
N/A
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
N/A
Authorized Signature with date:
David Gorm
dgorm@hilcorp.com
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
190-097
50-029-22072-00-00
Plugs
ADL0025906
5. Permit to Drill Number:
MILNE POINT / SCHRADER BLUFF OIL
3800 Centerpoint Dr, Suite 1400
Anchorage, AK 99503
3. Address:
4. Well Class Before Work:
Representative Daily Average Production or Injection Data
WINJ WAG
Water-Bbl
MD
115'
measured
2,373'2,680'
TVD
115'
Oil-Bbl
measured
true vertical
Packer
Baker S3
9-5/8"
7,240psi 5,410psi5,434' 7" 5,434' 4,219'
PP
Form 10-404 Revised 3/2020 Submit Within 30 days of Operations
Chad A Helgeson
2020.10.07
16:19:37 -08'00'
By Samantha Carlisle at 11:25 am, Oct 09, 2020
DSR-10/12/2020 SFD 10/12/2020
RBDMS HEW 11/12/2020
MGR12OCT2020
Date Inspected:
Inspector: Operator:
Well Name: Oper. Rep:
PTD No.: Oper. Phone:
Location Verified? Oper. Email:
If Verified, How?
Onshore / Offshore:
Date AOGCC Notified:
Suspension Date: Type of Inspection:
Sundry No.: Wellbore Diagram Avail.?
Photos Taken?
Well Pressures (psi): Tubing 0
IA 0
OA 0
Condition of
Wellhead:
Comments:
Attachments:
Insp. Suprv
Comm
Follow Up Actions
Needed:
Hilcorp
190-097
Condition of
Surrounding Surface
Location:
04/17/20
320-168
REVIEWED BY:
Other (specify in comments)
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
Suspended Well Inspection Report
Brian Bixby
09/20/20
Yes
Jon ArendMPJ-03
(907)240-4383
Yes
Onshore
09/18/20
Subsequent
Good, Clean, No Leaks
Good, Clean
None
Location verifed by Pad map
WBS
Pictures
Area map
Yes
PLB 12/2014 MPJ-03 Suspended Well Inspection 9-20-20
_____________________________________________________________________________________
Revised By: TDF 7/7/2020
SCHEMATIC
Milne Point Unit
Well: MPU J-03
Last Completed: 4/11/2020
PTD: 190-097
TD =5,449’ (MD) / TD =4,229’(TVD)
Orig. KB Elev.: 70.2’/ Orig. GL Elev.: 35.2’
RKB-THF: 24.89’
7”
21
9-5/8 ”
1
TOC at
4,633’ SLM
5/31/2020
PBTD =5,354 (MD) / PBTD =4,164’(TVD)
RA Marker in 7”
@ 4,633’
12,13,14,15,16,17 &
18
2
11
N Sands
3
13-3/8”
19
5, 6,7,8,9&10
O Sands
20
2.25” DD Bailer
@ 5,132’ SLM
Recover sand
4
CASING DETAIL
Size Type Wt/ Grade/ Conn ID Top Btm BPF
13-3/8" Conductor 54.5 / K-55 / Welded 12.415” Surface 115' N/A
9-5/8” Surface 36 / K-55 / BTC 8.921” Surface 2,680’ 0.0773
7" Production 26 / L-80 / BTC 6.276” Surface 5,434' 0.0383
TUBING DETAIL
3-1/2” Tubing 9.3 / L-80 / EUE 8rd 2.992” Surface 4,685’ 0.0087
JEWELRY DETAIL
No Depth Item
1 25’ 4-1/2” Tubing Hanger w/ 3-1/2” pup below
2 2,507’ 3-1/2” GLM w/ 1.5” port –DGLV Set 4/14/2020
3 4,679’ 3-1/2” Seal Assembly (Stabbed into Packer sealbore) Btm @ 4,685’Min ID = 2.348”
4 4,679’ Otis VST Versa-Trieve Gravel Packer w/ 5” LCT Box Min ID = 3.250”
5 4,685’ Otis MCS Closing Sleeve 5” LCT Pin x 4-1/2” LCT Box
6 4,705’ Howard Smith Screen Blank 3-1/2”
7 4,803’ Howard Smith Screen – All Welded Stainless Steel Wire Wrapped 3-1/2”
8 4,968’ Otis O-Ring Sub 3-1/2”Min ID = 2.750”
9 4,969’ Howard Smith Screen- Tell Tale All Welded Stainless Steel Screen 3-1/2”
10 4,980’ Otis Str. Slot Seal Assembly for Lower VST Gravel Packer
11 4,981 Otis VST Versa-Trieve Gravel Packer w/ 5” LCT Box
12 4,987’ Otis MFS Flow Sub Assy. 5-1/2” LCT Pin x 5” LCT Pin
13 5,004’ Otis Adapter w/ Collet Receptacle 5” LCT Box
14 5,005’ Howard Smith Screen Blank 3-1/2”
15 5,032’ Howard Smith Screen – All Welded Stainless Steel Wire Wrapped 3-1/2”
16 5,177’ Otis O-Ring Sub 3-1/2”Min ID = 2.750”
17 5,178’ Howard Smith Screen- Tell Tale All Welded Stainless Steel Screen 3-1/2”
18 5,189’ Otis Str. Slot Seal Assembly
19 5,189’ Otis AWD Perma-Series Permanent Production Packer 7”
20 5,196’ Collet Guide – Bottom @ 5,196.43’Min ID = 2.980”
21 5,018’ 2.13” OD Baker inflatable cement retainer
OPEN HOLE / CEMENT DETAIL
13-3/8" Cmt w/ 485 sx of PF C in 30” Hole
9-5/8” Cmt w/ 1,087 sx PF E, 243 sx Class “G” in 12-1/4” Hole
7” Cmt w/ 285 sx Class “G” in 8-1/2” Hole
WELL INCLINATION DETAIL
KOP @ 500’ MD
Max Wellbore Angle = 50.5 deg @ 3,800’ MD
WELLHEAD
Tree 4-1/16” 5M MKM
Wellhead 11” 5M MKM
GENERAL WELL INFO
API: 50-029-22072-00-00
Drilled and Cased by EWS #4 – 12/29/1990
Gravel Pack and ESP Completion by EWS #4 – 5/25/1991
ESP Replacement by Nabors 4ES – 3/4/1995
ASR Pull ESP and Run Tubing – 4/11/2020
P&A by SLB CTU #6 – 6/5/2020
PERFORATION DETAIL
Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status
N Sands
4,822’ 4,828’ 3,798’ 3,802’ 6 5/20/1991 Open
4,852’ 4,887’ 3,819’ 3,843’ 35 5/21/1991 Open
4,897’ 4,908’ 3,850’ 3,858’ 11 5/20/1991 Open
4,927’ 4,960’ 3,871’ 3,894’ 33 5/20/1991 Open
O Sands 5,045’ 5,087’ 3,952’ 3,981’ 42 5/16/1991 Open
5,132’ 5,167’ 4,012’ 4,036’ 35 5/16/1991 Open
Perforation Data: 24 SPF with SLB 24 GM, 43C BH charges, 135° phasing shot E/L 12 SPF; TCP 12 SPF, surged w/
300 PSI U/B
ESP CABLE DETAIL
6-1/2 Flat Guards + 39 bands
289 Preformed Bands
1,189 Flat Bands
FRAC PACK SUMMARY
5,045’ to 5,147’: 10,535 lbs of 20/40 Sand
4,822’ to 4,960’: 9,515 lbs of 20/40 Sand
SFD 10/12/2020
Abandoned
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: _1 Service Stratigraphic Test
2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry:
3. Address:7.Date Spudded:15. API Number:
4a. Location of Well (Governmental Section): 8. Date TD Reached:16. W ell Name and Number:
Surface:
Top of Productive Interval:9. Ref Elevations: KB: 17. Field / Pool(s):
GL: 35.2 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-4 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD:
Total Depth: x- y- Zone-4
5.Directional or Inclination Survey: Yes (attached) No 13. W ater Depth, if Offshore:21. Re-drill/Lateral Top W indow MD/TVD:
Submit electronic information per 20 AAC 25.050 N/A (ft MSL)
22.Logs Obtained:
23.
BOTTOM
13-3/8" K-55 115'
9-5/8" K-55 2,373'
7" L-80 4,219'
24. Open to production or injection? Yes No 25.
26.
Was hydraulic fracturing used during completion? Yes No
DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED
27.
Date First Production: Method of Operation (Flowing, gas lift, etc.):
Hours Tested: Production for Gas-MCF:
Test Period
Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr):
Press. 24-Hour Rate
Sr Pet Eng
Oil-Bbl: Water-Bbl:
Choke Size:
10,535 lbs of 20/40 Sand
4,822 to 4,960
Sr Res EngSr Pet Geo
9,515 lbs of 20/40 Sand
Water-Bbl:
Flow Tubing
Date of Test: Oil-Bbl:
5,045 to 5,147
Per 20 AAC 25.283 (i)(2) attach electronic information
Gas-Oil Ratio:
36
115'
35' 5,434'
PRODUCTION TEST
suspension, or abandonment, 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 if necessary
N/A 1,800' MD / 1,723 TVD
N/A
26 35'
54.5
35'
CASING WT. PER
FT.GRADE TOP
551499.1525
551360.0635
TOP
SETTING DEPTH MD
35'
8-1/2"
N/A
N/A
35'N/A
5,354' MD / 4,164' TVD
5,449' MD / 4,229' TVD
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,
12-1/4"
485sx Permafrost C
551988.0424 6014944.653
5,249' FNL 3,838' FEL Section 28 T13N R10E UM
CEMENTING RECORD
6012424.787
SETTING DEPTH TVD
6011993.424
N/A
BOTTOM
CASING, LINER AND CEMENTING RECORD
2,733' FNL 3,331' FEL Section 28 T13N R10E UM
400' FNL 3,981 FEL Section 33 T13N R10E UM
12/23/1990 50-029-22072-00-00
12/26/1990 MILNE PT UNIT J-03
MILNE POINT / SCHRADER BLUFF OIL
70.2'
ADL0025906
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
Hilcorp Alaska LLC
WAG
Gas
190-097 / 320-168Aband.: 6/5/2020
3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503
285sx G
3-1/2"
SIZE DEPTH SET (MD) PACKER SET (MD/TVD)
4,685'
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date Perfd):
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
TUBING RECORD
4,679 / 3,698, 4,981 / 3,908 &
5,189 / 4,051
35' 2,680'
30"
HOLE SIZE AMOUNT
PULLED
1,087 sx Arcticset IV, 243sx G
Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment
Suspension Date
6/5/2020
HEW
RBDMS HEW 7/8/2020
xGDLB 07/08/2020
SFD 7/13/2020
DSR-7/8/2020MGR04FEB2021
Conventional Core(s): Yes No Sidewall Cores:
30.
MD TVD
1,800' 1,723
Top of Productive Interval
4,822' 3,798'
5,045' 3,952'
Kuparuk
31. List of Attachments:
Wellbore schematic and daily operation reports.
32. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Chad Helgeson Contact Name: Tom Fouts
Operations Manager Contact Email:tfouts@hilcorp.com
Authorized Contact Phone:907-777-8398
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:
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).
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.
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.
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.
This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram
with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical
reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted.
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, 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).
INSTRUCTIONS
Authorized Name:
Authorized Title:
Signature w/Date:
29.GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS
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, whichever occurs first.
Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
Formation at total depth:
Top of "O" Sand
Top of "N" Sand
If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form,
if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071.
Yes No
Well tested? Yes No
28. CORE DATA
If yes, list intervals and formations tested, briefly summarizing test results.
Attach separate pages to this form, if needed, and submit detailed test
information, including reports, per 20 AAC 25.071.
NAME
Permafrost - Top
Permafrost - Base
Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment
Chad A Helgeson
2020.07.08
15:00:17 -08'00'
SFD 7/13/2020
Schrader Bluff - O sand
_____________________________________________________________________________________
Revised By: TDF 7/7/2020
SCHEMATIC
Milne Point Unit
Well: MPU J-03
Last Completed: 4/11/2020
PTD: 190-097
TD =5,449’ (MD) / TD =4,229’(TVD)
Orig. KB Elev.: 70.2’/ Orig. GL Elev.: 35.2’
RKB-THF: 24.89’
7”
21
9-5/8”
1
TOC at
4,633’ SLM
5/31/2020
PBTD =5,354 (MD) / PBTD =4,164’(TVD)
RA Marker in 7”
@ 4,633’
12,13,14,15,16,17 &
18
2
11
N Sands
3
13-3/8”
19
5, 6,7,8,9&10
O Sands
20
2.25” DD Bailer
@ 5,132’ SLM
Recover sand
4
CASING DETAIL
Size Type Wt/ Grade/ Conn ID Top Btm BPF
13-3/8" Conductor 54.5 / K-55 / Welded 12.415” Surface 115' N/A
9-5/8” Surface 36 / K-55 / BTC 8.921” Surface 2,680’ 0.0773
7" Production 26 / L-80 / BTC 6.276” Surface 4,536' 0.0383
TUBING DETAIL
3-1/2” Tubing 9.3 / L-80 / EUE 8rd 2.992” Surface 4,685’ 0.0087
JEWELRY DETAIL
No Depth Item
1 25’ 4-1/2” Tubing Hanger w/ 3-1/2” pup below
2 2,507’ 3-1/2” GLM w/ 1.5” port –DGLV Set 4/14/2020
3 4,679’ 3-1/2” Seal Assembly (Stabbed into Packer sealbore) Btm @ 4,685’Min ID = 2.348”
4 4,679’ Otis VST Versa-Trieve Gravel Packer w/ 5” LCT Box Min ID = 3.250”
5 4,685’ Otis MCS Closing Sleeve 5” LCT Pin x 4-1/2” LCT Box
6 4,705’ Howard Smith Screen Blank 3-1/2”
7 4,803’ Howard Smith Screen – All Welded Stainless Steel Wire Wrapped 3-1/2”
8 4,968’ Otis O-Ring Sub 3-1/2”Min ID = 2.750”
9 4,969’ Howard Smith Screen- Tell Tale All Welded Stainless Steel Screen 3-1/2”
10 4,980’ Otis Str. Slot Seal Assembly for Lower VST Gravel Packer
11 4,981 Otis VST Versa-Trieve Gravel Packer w/ 5” LCT Box
12 4,987’ Otis MFS Flow Sub Assy. 5-1/2” LCT Pin x 5” LCT Pin
13 5,004’ Otis Adapter w/ Collet Receptacle 5” LCT Box
14 5,005’ Howard Smith Screen Blank 3-1/2”
15 5,032’ Howard Smith Screen – All Welded Stainless Steel Wire Wrapped 3-1/2”
16 5,177’ Otis O-Ring Sub 3-1/2”Min ID = 2.750”
17 5,178’ Howard Smith Screen- Tell Tale All Welded Stainless Steel Screen 3-1/2”
18 5,189’ Otis Str. Slot Seal Assembly
19 5,189’ Otis AWD Perma-Series Permanent Production Packer 7”
20 5,196’ Collet Guide – Bottom @ 5,196.43’Min ID = 2.980”
21 5,018’ 2.13” OD Baker inflatable cement retainer
OPEN HOLE / CEMENT DETAIL
13-3/8" Cmt w/ 485 sx of PF C in 30” Hole
9-5/8” Cmt w/ 1,087 sx PF E, 243 sx Class “G” in 12-1/4” Hole
7” Cmt w/ 285 sx Class “G” in 8-1/2” Hole
WELL INCLINATION DETAIL
KOP @ 500’ MD
Max Wellbore Angle = 50.5 deg @ 3,800’ MD
WELLHEAD
Tree 4-1/16” 5M MKM
Wellhead 11” 5M MKM
GENERAL WELL INFO
API: 50-029-22072-00-00
Drilled and Cased by EWS #4 – 12/29/1990
Gravel Pack and ESP Completion by EWS #4 – 5/25/1991
ESP Replacement by Nabors 4ES – 3/4/1995
ASR Pull ESP and Run Tubing – 4/11/2020
P&A by SLB CTU #6 – 6/5/2020
PERFORATION DETAIL
Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status
N Sands
4,822’ 4,828’ 3,798’ 3,802’ 6 5/20/1991 Open
4,852’ 4,887’ 3,819’ 3,843’ 35 5/21/1991 Open
4,897’ 4,908’ 3,850’ 3,858’ 11 5/20/1991 Open
4,927’ 4,960’ 3,871’ 3,894’ 33 5/20/1991 Open
O Sands 5,045’ 5,087’ 3,952’ 3,981’ 42 5/16/1991 Open
5,132’ 5,167’ 4,012’ 4,036’ 35 5/16/1991 Open
Perforation Data: 24 SPF with SLB 24 GM, 43C BH charges, 135° phasing shot E/L 12 SPF; TCP 12 SPF, surged w/
300 PSI U/B
ESP CABLE DETAIL
6-1/2 Flat Guards + 39 bands
289 Preformed Bands
1,189 Flat Bands
FRAC PACK SUMMARY
5,045’ to 5,147’: 10,535 lbs of 20/40 Sand
4,822’ to 4,960’: 9,515 lbs of 20/40 Sand
Well Name Rig API Number Well Permit Number Start Date End Date
MP J-03 CTU #6 50-029-22072-00-00 190-097 5/25/2020 6/5/2020
5/22/2020 - Friday
No operations to report.
5/20/2020 - Wednesday
Hilcorp Alaska, LLC
Weekly Operations Summary
No operations to report.
5/21/2020 - Thursday
No operations to report.
MU HAL memory GR/CCL tools inside 2.2" OD carrier with 2.21" DJN. PT to 300/3,500 psi. RIH and TAG at 5,132' ctmd. Clean
out to 5,216' ctmd. Log up to 4,600'. Flagged pipe at 5,000'. POOH. Tie log into SLB gravel pack log dated 23-May-91. Make
+7.5 ft depth correction. MU and RIH with 2.13" OD Baker inflatable cement retainer. At flag, correct depth to COE. Set
retainer at 5,018' between the N and O sands. Prove injectivity into each sand. HAL pump 19 bbls 13.0 ppg FineCem cement
lead / 5 bbls 15.8 ppg "G" cement down coil. Squeeze 8 bbls of FineCem into O sands. CTP increase from 886 psi to 1,885psi.
Unsting from retainer, lay in cement, and squeeze an estimated 7-8 bbl of FineCem into N Sands. Take squeeze pressure up
to 1,200psi. Contaminate and clean out leaving estimated TOC at 4,680' MD. POOH chasing returns. FP well from 2,800' with
60/40. Inflatable setting tool recovered. The inflatable retainer (9.43' long) left cemented in hole. Final T/I/O = 500/0/0.
RDMO.
No operations to report.
5/23/2020 - Saturday
MIRU SLB CTU #6 with 2" CT. Perform full BOP test to 300/ 4,200 psi. Good test. Record on 10-424. MU Baker MHA for
logging run tomorrow. Secure equipment for night. SDFN.
5/26/2020 - Tuesday
5/24/2020 - Sunday
No operations to report.
5/25/2020 - Monday
Well Name Rig API Number Well Permit Number Start Date End Date
MP J-03 CTU #6 50-029-22072-00-00 190-097 5/25/2020 6/5/2020
5/29/2020 - Friday
No operations to report.
5/27/2020 - Wednesday
Hilcorp Alaska, LLC
Weekly Operations Summary
No operations to report.
5/28/2020 - Thursday
No operations to report.
No operations to report.
No operations to report.
5/30/2020 - Saturday
No operations to report.
6/2/2020 - Tuesday
5/31/2020 - Sunday
(#1) Pre AOGCC MIT-T & IA to 1,500 psi (Pressure test equipment 250/2,500 psi) MIT-T to 1,500 psi (Failed). Pump 0.4 bbls
Dsl to reach test pressure. 1st 15 Min Tbg lost 67 psi. 2nd 15 Min Tbg lost 37 psi. 3rd 15 Min Tbg lost 28 psi. 4th 15 Min Tbg
lost 24 psi. Bleed Tbg down w/ 0.5 bbls Dsl returned. MIT-IA to 1,500 psi (Inconclusive) Pump 6 bbls Dsl down IA to reach
test pressure. 1st 15 Min IA lost 102 psi. 2nd 15 Min IA lost 41 psi. 3rd 15 Min IA lost 28 psi. Bleed IA down w/ 1 bbl Dsl
returned. (#2) MIT-T & IA to 1,500 psi (Pressure test equipment 250/2,500 psi) MIT-IA to 1,500 psi (PASSED). Pump 1 bbl Dsl
down IA to reach Test pressure. 1st 15 min IA lost 85 psi. 2nd 15 Min IA lost 32 psi. Bleed IA down w/ 1 bbl Dsl returned.
MIT-T to 1,500 psi (PASSED). Pump 0.3 bbls Dsl to reach test pressure. 1st 15 Min Tbg lost 70 psi. 2nd 15 Min Tbg lost 32 psi.
Bleed Tbg down w/ 0.2 bbls Dsl returned. RAN 2.00" CENT. & S. BAILER, TAG TOC @ 4,633' SLM. 1/2 Cup cured cement
recovered.
6/1/2020 - Monday
Well Name Rig API Number Well Permit Number Start Date End Date
MP J-03 CTU #6 50-029-22072-00-00 190-097 5/26/2020 6/5/2020
No operations to report.
No operations to report.
6/6/2020 - Saturday
No operations to report.
6/9/2020 - Tuesday
6/7/2020 - Sunday
No operations to report.
6/8/2020 - Monday
6/5/2020 - Friday
AOGCC witnessed (Bob Noble) pressure test TBG and IA. (Pressure test equipment 250/2500 psi) Pumped 0.33 bbls
down TBG for PT. Lost 56 psi 1st 15 min, lost 31 psi 2nd 15 min. Bleed back 0.33 bbls. Pumped 0.99 bbls down IA. Lost 105
psi 1st 15 min . Lost 29 psi 2nd 15 min. bled back 0.96 bbls. OPEN PERMIT W/PAD-OP, PT PCE 250L/2000H. DRIFT & TAG
WITH 3'x1-7/8" STEM, 2" CENT, SAMPLE BAILER TO 4636' SLM (recovered small amount of cement in ball bottom). STATE
REP (Bob Noble) WITNESSED TAG AND SAMPLE. RDMO, CLOSE PERMIT W/PAD-OP.
6/3/2020 - Wednesday
Hilcorp Alaska, LLC
Weekly Operations Summary
No operations to report.
6/4/2020 - Thursday
No operations to report.
Samuel Gebert Hilcorp Alaska, LLC
GeoTech Assistant 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: 907 777-8337
Fax: 907 777-8510
E-mail: sam.gebert@hilcorp.com
Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510
Received By: Date:
DATE: 11/03/2020
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
DATA TRANSMITTAL
MPU J-03 (PTD 190-097)
COIL FLAG 05/26/2020
Please include current contact information if different from above.
Received by the AOGCC 11/03/2020
Abby Bell 11/03/2020
PTD: 1900970
E-Set: 34180
Suspended Well Inspection Review RuD{rf
|nspectNo: susBD6200921141459
Date Inspected: 9/20/2020
Inspector: Brian Bixby Type ofInspection
VVeUName:
M|LNEPTUN|T]-08 '
Permit Number:
1900970 ' _
Suspension Approval:
Sundry - # 320'168 -
Suspension Date:
6/5/2020 ' �
Location Verified?
V
|fVerified, How?
�
other (specify incomments) '
Offshore?
F-1
Initial -
Date AOG[CNotified: 9/18/2020
Operator: Hi|cnrpAlaska, LLC -
Operator Rep: Jon Arend '
Wellbore Diagram Avai|7
Photos Taken?
�� []
Well Pressures (psi): Tubing� U ' Fluid in Cellar?
|A: 0 BPV|nstaUed7 [�
L�
0A: U VRP|uOs)Installed?
Wellhead Condition
All ofthe valves onthe appeared ingood working order with working gauges onthe Tubing, |Aand OA, There are noVR '
Plugs o/BPVinstalled.
Condition oiCellar
Good Condition. I did not observe and excessive water in cellar, trash or any sheen. '
Surrounding Surface Condition
Everything looked good. | did not see debris orsheen around the pad.
Comments
I verified the location using the pad map.
Supervisor Comments
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MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Jim Regg Ce j (�11Q31 z w
P.I. Supervisor
FROM: Bob Noble
Petroleum Inspector
DATE: June 5, 2020
SUBJECT: Well Bore Plug & Abandonment
MPU J-03 '
Hilcorp Alaska LLC
PTD 1900970; Sundry 320-168
Section:
28
Township:
13N
Range:
10E
Meridian: Umiat
5189 ft MD
4636 ft MD
Drilling Rig:
N/A
Rig Elevation:
N/A
Total Depth:
5449 ft MD
Lease No.: ADL 25906
Operator Rep:
Jim Fagnet
Suspend:
X
P&A:
Casing/Tubing Data (depths are MD):
Casing Removal:
Conductor:
13 3/8"
, O.D. Shoe@
2680
Feet
Csg Cut@
Feet
Surface:
9 5/8"
O.D. Shoe@
5434
Feet
Csg Cut@
Feet
Intermediate:
O.D. Shoe@
Feet
Csg Cut@
Feet
Production:
O.D. Shoe@
Feet
Csg Cut@
Feet
Liner:
O.D. Shoe@
Feet
Csg Cut@
Feet
Tubing:
2 7/8"
' O.D. Tail@
4603
Feet
Tbg Cut@
Feet
Plugging Data:
Test Data
Type Plug
Founded on
Depth Btm
Depth To MW Above
Verified
Tubing
Other -
5189 ft MD
4636 ft MD
Wireline tag
OA
0
0
0
Initial 15 min 30 min 45 min Result
Tubing 1
157 -1
175
180
IA
1721
1616
1587
P ✓
OA
0
0
0
Initial 15 min 3n min d5 min Reenlf
Tubing 1725 1669 1638
IA 106 111 112
P
OA
Remarks:
Cement set on packer to cover O and N sands. Plug tag with bailer. Hard flakes of cement came up in the bailer. MITIA and
MITT passed.
Attachments: Photo (1)
rev. 11-28-18 2020-0605_Plug_Verification_M PU_J-03_bn
Plug Verification — MPU J-03 (PTD 1900970)
Plug Tag Cement Sample
Photo by AOGCC Inspector B. Noble
6/5/2020
li
2020-0605_PI ug_Verification_M PU_J-03_p hoto_bn. docx
Page 1 of 1
1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown
Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program
Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Pull ESP / Run Tieback
Development Exploratory
Stratigraphic Service 6. API Number:
7. Property Designation (Lease Number):8. Well Name and Number:
9. Logs (List logs and submit electronic and printed data per 20AAC25.071):10. Field/Pool(s):
11. Present Well Condition Summary:
Total Depth measured 5,449 feet 5,354 feet
true vertical 4,229 feet N/A feet
Effective Depth measured 5,214 feet feet
true vertical 4,068 feet feet
Perforation depth Measured depth See Schematic feet
True Vertical depth See Schematic feet
Tubing (size, grade, measured and true vertical depth)3-1/2" 9.3 / L-80 / EUE 8rd 4,685’ 3,702'
Packers and SSSV (type, measured and true vertical depth)Baker S-3 N/A See Above N/A
12. Stimulation or cement squeeze summary:N/A
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure:N/A
13.
Prior to well operation:
Subsequent to operation:
15. W ell Class after work:
Daily Report of Well Operations Exploratory Development Service Stratigraphic
Copies of Logs and Surveys Run 16. W ell Status after work:Oil Gas WDSPL
Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG
Sundry Number or N/A if C.O. Exempt:
Chad Helgeson
Contact Name:
Authorized Title:Operations Manager
Contact Email:
Contact Phone:
2
Water-Bbl
MD
115'
2,680'
5,434'
TVD
115'
3800 Centerpoint Dr, Suite 1400
Anchorage, AK 99503
3. Address:
4. Well Class Before Work:
23
Representative Daily Average Production or Injection Data
2243
MILNE PT UNIT J-03
Gas-Mcf
220
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
190-097
50-029-22072-00-00
Plugs
ADL0025906
5. Permit to Drill Number:
MILNE POINT / SCHRADER BLUFF OIL
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
320-130
0
Authorized Signature with date:
Authorized Name:
Stan Porhola
sporhola@hilcorp.com
N/A
measured
N/A
Casing
Conductor
Size
measured
true vertical
Packer
115'
2,680'
5,434'
Tubing Pressure
00
Oil-Bbl
200
Senior Engineer:Senior Res. Engineer:
Collapse
N/A
2,020psi
5,410psi
Burst
N/A
4,219'
Length
3,520psi
7,240psi
4,679, 4,981 &
5,189
3,698, 3,908 &
4,051
777-8412
14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283)
Casing Pressure
WINJ WAG
Hilcorp Alaska LLC
2. Operator Name
13-3/8"
9-5/8"
7"
2,373'Surface
Production
Junk measured
PL
G
Form 10-404 Revised 3/2020 Submit Within 30 days of Operations
Chad A Helgeson
2020.05.04
18:25:50 -05'00'
By Samantha Carlisle at 3:40 pm, May 04, 2020
RBDMS HEW 5/4/2020
DSR-5/4/2020gls 5/5/20
Pull Tubing Operations shutdown
OMMISSION
ERATIONS
Pull Tubing
OMMISSION
E SamanthaRATIONSRATIONS
Alter Casing Change Approved Program
er Susp Well Other:
ploratory
Service 6. API Number:
190-097
50 029 22072 00 00
5. Permit to Drill Number:
Pull ESP / Run Tieback
A
e
p
50-029-22072-00-00
gp
_____________________________________________________________________________________
Revised By: STP 4/14/2020
SCHEMATIC
Milne Point Unit
Well: MPU J-03
Last Completed: 4/11/2020
PTD: 190-097
TD =5,449’ (MD) / TD =4,229’(TVD)
Orig. KB Elev.: 70.2’/ Orig. GL Elev.: 35.2’
RKB-THF: 24.89’
7”
9-5/8 ”
1
PBTD =5,354 (MD) / PBTD =4,164’(TVD)
RA Marker in 7”
@ 4,633’
12,13,14,15,16,17 &
18
2
11
N Sands
3
13-3/8”
19
5, 6,7,8,9&10
O Sands
20
2.25” DD Bailer
@ 5,132’ SLM
Recover sand
4
CASING DETAIL
Size Type Wt/ Grade/ Conn ID Top Btm BPF
13-3/8" Conductor 54.5 / K-55 / Welded 12.415” Surface 115' N/A
9-5/8” Surface 36 / K-55 / BTC 8.921” Surface 2,680’ 0.0773
7" Production 26 / L-80 / BTC 6.276” Surface 4,536' 0.0383
TUBING DETAIL
3-1/2” Tubing 9.3 / L-80 / EUE 8rd 2.992” Surface 4,685’ 0.0087
JEWELRY DETAIL
No Depth Item
1 25’ 4-1/2” Tubing Hanger w/ 3-1/2” pup below
2 2,507’ 3-1/2” GLM w/ 1.5” port –DGLV Set 4/14/2020
2 4,679’ 3-1/2” Seal Assembly (Stabbed into Packer sealbore) Btm @ 4,685’Min ID = 2.348”
3 4,679’ Otis VST Versa-Trieve Gravel Packer w/ 5” LCT Box Min ID = 3.250”
4 4,685’ Otis MCS Closing Sleeve 5” LCT Pin x 4-1/2” LCT Box
5 4,705’ Howard Smith Screen Blank 3-1/2”
6 4,803’ Howard Smith Screen – All Welded Stainless Steel Wire Wrapped 3-1/2”
7 4,968’ Otis O-Ring Sub 3-1/2”Min ID = 2.750”
8 4,969’ Howard Smith Screen- Tell Tale All Welded Stainless Steel Screen 3-1/2”
9 4,980’ Otis Str. Slot Seal Assembly for Lower VST Gravel Packer
10 4,981 Otis VST Versa-Trieve Gravel Packer w/ 5” LCT Box
11 4,987’ Otis MFS Flow Sub Assy. 5-1/2” LCT Pin x 5” LCT Pin
12 5,004’ Otis Adapter w/ Collet Receptacle 5” LCT Box
13 5,005’ Howard Smith Screen Blank 3-1/2”
14 5,032’ Howard Smith Screen – All Welded Stainless Steel Wire Wrapped 3-1/2”
15 5,177’ Otis O-Ring Sub 3-1/2”Min ID = 2.750”
16 5,178’ Howard Smith Screen- Tell Tale All Welded Stainless Steel Screen 3-1/2”
17 5,189’ Otis Str. Slot Seal Assembly
18 5,189’ Otis AWD Perma-Series Permanent Production Packer 7”
19 5,196’ Collet Guide – Bottom @ 5,196.43’Min ID = 2.980”
OPEN HOLE / CEMENT DETAIL
13-3/8" Cmt w/ 485 sx of PF C in 30” Hole
9-5/8” Cmt w/ 1,087 sx PF E, 243 sx Class “G” in 12-1/4” Hole
7” Cmt w/ 285 sx Class “G” in 8-1/2” Hole
WELL INCLINATION DETAIL
KOP @ 500’ MD
Max Wellbore Angle = 50.5 deg @ 3,800’ MD
WELLHEAD
Tree 4-1/16” 5M MKM
Wellhead 11” 5M MKM
GENERAL WELL INFO
API: 50-029-22072-00-00
Drilled and Cased by EWS #4 – 12/29/1990
Gravel Pack and ESP Completion by EWS #4 – 5/25/1991
ESP Replacement by Nabors 4ES – 3/4/1995
ASR Pull ESP and Run Tubing – 4/11/2020
PERFORATION DETAIL
Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status
N Sands
4,822’ 4,828’ 3,798’ 3,802’ 6 5/20/1991 Open
4,852’ 4,887’ 3,819’ 3,843’ 35 5/21/1991 Open
4,897’ 4,908’ 3,850’ 3,858’ 11 5/20/1991 Open
4,927’ 4,960’ 3,871’ 3,894’ 33 5/20/1991 Open
O Sands 5,045’ 5,087’ 3,952’ 3,981’ 42 5/16/1991 Open
5,132’ 5,167’ 4,012’ 4,036’ 35 5/16/1991 Open
Perforation Data: 24 SPF with SLB 24 GM, 43C BH charges, 135° phasing shot E/L 12 SPF; TCP 12 SPF, surged w/
300 PSI U/B
ESP CABLE DETAIL
6-1/2 Flat Guards + 39 bands
289 Preformed Bands
1,189 Flat Bands
FRAC PACK SUMMARY
5,045’ to 5,147’: 10,535 lbs of 20/40 Sand
4,822’ to 4,960’: 9,515 lbs of 20/40 Sand
Well Name Rig API Number Well Permit Number Start Date End Date
MP J-03 ASR#1 50-029-22072-00-00 190-097 4/6/2020 4/11/2020
Move in and hook up support trailers. Rig up guy lines. Torque BOP bolts.
No operations to report.
4/4/2020 - Saturday
Begin to move in the ASR#1 rig. ND tree on J-03. All nuts and bolts removed at 0030 hrs. Had to use hacksaw on last one.
Grease tree flange, NU BOP (*Note, no caps on penetrator plugs but Wellhead and Baker Reps state plugs are good to 5k
psi.) Continue to NU BOP, remote for Hi-Torq wrench failed. Attempt to repair, cannot repair. Continue to torque with
hammer wrench by hand. Crane cannot make lift due to wind speed. Had to leave location at 0230 hrs due to having to go
get loader and move snow that has drifted in on access lanes and at pad entrances. Spot Mud Boat.
4/7/2020 - Tuesday
4/5/2020 - Sunday
No operations to report.
4/6/2020 - Monday
4/3/2020 - Friday
No operations to report.
4/1/2020 - Wednesday
Hilcorp Alaska, LLC
Weekly Operations Summary
No operations to report.
4/2/2020 - Thursday
No operations to report.
Well Name Rig API Number Well Permit Number Start Date End Date
MP J-03 ASR#1 50-029-22072-00-00 190-097 4/6/2020 4/11/2020
4/8/2020 - Wednesday
Hilcorp Alaska, LLC
Weekly Operations Summary
Morning Safety Meeting and Daily plan forward. Continue to MIRU, raised derrick , raised and installed tongs, installed flow
spool and flowline, moved in catwalk and Conex's. Started heat on 2-7/8" and 3-1/2" test joints, utilized well support grease
truck to grease all valves on choke/kill manifold and flow cross . Perform shell test and test held to 2,500psi for 5 minutes.
Bled-off and proceed with BOP testing. Start BOP testing- testing with 2-7/8" and 3-1/2" test mandrels, testing annular,
blinds, and 2-7/8" x 5" VBRs in pipe rams to 250psi low and 2,500psi high test. Test annular with 2-7/8" test mandrel, Pipe
rams with 2-7/8" and 3-1/2" test mandrels, test all choke, kill, and HCR valves to 250/2,500psi. Tested all LEL and Gas
alarms, Pit Level Alarms. Safety meeting with crew. Discuss status of BOP test and pressure on lines and initial entry into
well. Continue testing BOP from test 4 with 2-7/8" test joint in the 2-7/8" x 5" VBR pipe rams to 250psi low / 2,500psi high.
Tests 3 and 4 are good. Test 5 with 2-7/8" test joint had good low test. Pressure increased to 2,000psi, noticeable drop on
chart. Leaking at gland of LDS. Tighten, bring pressure up and leak at 2 other LDS. Call out Wellhead Rep, tighten. Good low
test but when brought up to high leaking off. No leaks in lines or wellhead, some bubbles above rams. Make several
attempts, bleeding off. Lift TJ and close Blinds. Conduct test against Blinds, had initial bleed. Pressure up 2 more times with
less bleed, on third attempt solid low and high test. Re-conduct test, good test. Replace 2-7/8" x 5" ram body. Left (Driver
side of rig) door closed easily and torqued with no issues. Right door closed and as crew was tightening bolt noticed that
hydraulic fluid was weeping / leaking. Function test and steady stream of hydraulic fluid is coming out of hinge. Lesson
Learned on F-116 was to open and close door many times to get "gasket to seal". Crew exercising door while discussing with
YJ rep. Cycle door 15 times, torque, pressure and it leaked badly. Unbolt, open and close numerous times (0psi on system),
close and torque, pressure again with less of a leak this time. Same iteration for a third time, very slight indication of fluid
upon initial open and close but did it again and had small leak. Crew squeezed one more squirt into the zert and go through
open and close cycle one more time to ensure no leak. Cycled door closure for fourth time. Brought up pressure, leaked at
hinge point again. Called Yellow Jacket BOP rep, stated that he is calling Lower 48 for possible troubleshooting but he
believes O-ring is not seated or damaged. Crew has verified that we have another 11" Double-Gate that we can swap out
(no ram bodies installed). Continue troubleshooting and preparing for swap-out.
Called Yellow Jacket BOP rep, stated that he is calling Lower 48 for possible troubleshooting but he
believes O-ring is not seated or damaged.
Start BOP testing- testing with 2-7/8" and 3-1/2" test mandrels,
Well Name Rig API Number Well Permit Number Start Date End Date
MP J-03 ASR#1 50-029-22072-00-00 190-097 4/6/2020 4/11/2020
Hilcorp Alaska, LLC
Weekly Operations Summary
4/10/2020 - Friday
Morning Safety meeting and daily plan forward. Discussed hazards of cutting bands, good communication with spooling
unit, and spooling ESP power cable and heat trace on same spool. Continue to POOH w/ 2-7/8" tubing, heat trace cable and
ESP power cable cutting bands and removing flat guards as coming out of hole, pumping double displacement of 8.4 ppg 1%
kcl brine. Well static, pipe and cable clean. Continue to POOH w/ 2-7/8" tubing, heat trace cable and ESP power cable
cutting bands and removing flat guards as coming out of hole, pumping double displacement of 8.4 ppg 1% kcl brine. Well
static, pipe and cable clean. End of Heat trace cable at joint 83. POOH w/ 2-7/8" tubing, and ESP power cable cutting bands
as coming out of hole, pumping double displacement of 8.4 ppg 1% kcl brine. Well static, pipe and cable clean. ESP Assembly
at surface at changeout time. Safety meeting with night crew. Discuss laying down motor and pump, landing and testing
completion. Swap out crews, inspect equipment and check fluids. Crew dressing out elevators, slips, preparing lift
equipment, strapping jewelry. Load in 3-1/2" tubing, strap. Pick up Otis Seal Assembly (Muleshoe, 3 each 3.25" molded seal
units, locator sub on pup). RIH with 3-1/2" 9.3# L-80 EUE tubing. Joint #40 in the well. Tubulars are full of ice and cannot
drift. Placing heat on both ends to thaw, load in more pipe and strap while allowing pipe to thaw. Mix 70 bbl corrosion
inhibitor pill. Continue to RIH with 3-1/2" 9.3# L-80 EUE tubing. Having to thaw and rabbit on the fly due to long ice plugs in
tubing. GLM with 2,000psi Shear Out Valve is placed at 2,500' md (follows Joint 68 RIH).
4/9/2020 - Thursday
Morning Safety Meeting, Daily Plan Forward. Discussed hazards of pressure testing and not getting complacent with
pressure. Function doors on double gate BOP for another cycle of fully opening and closing for 15 cycles. Close doors and
tighten bolts. Function BOP's and hinge seals holding. Function 4 more times open and closed and door hinge seals holding.
Hold a safety meeting in office with Mark Omalley. Continue moving forward with BOP test. High test with pie rams on 3-
1/2" test mandrel leaking off. Troubleshoot and determine hanger leaking. Swap 2-way check and attempt retest, test
continue to leak off. Break BOP at hanger and install Blanking sub over 2-way check, retighten BOP and re-test. Test
continues to leak off. Found two LDS screws leaking on this test. Wellhead group tighten and seal. Blow down stack and Mix
10 gallons of AquaGel and finely ground nut plug and dump on top of hanger. Re-attempt test number 4 with 3-1/2" test
mandrel. Test Pipe rams (2-7/8" x 5" VBR) , TIW, C5,C6,C9,K3, tested 250psi low and 2,500psi high for 5 minutes for good
test. Continue to going forward with test 5 of BOP test with 2-7/8" test mandrel. Safety meeting with crew to discuss past
events with BOP test and plan forward. Swap out crews. Check equipment, fluids while BOP test is being completed. BOP
testing completed at 1900 hrs. Use chains to position drilling riser to center of floor. Pull Test Plug, then pull BPV Dart and
BPV. No pressure on well. Circulate 50 bbls down tubing, staging up from 2 bpm to 4-1/2 bpm, 5000psi. Well on vacuum. RU
Landing Jt, back out landing screws. Pull hanger, 40k to overpull to release, 34k PUW picking up through stack. Prep ESP and
Heat Trace cables for pulling back over sheave into spooler. Lay Down hanger and first 5 joints in order to get a wrap onto
spooler. Shorthanded on crew, stab TIW onto stump and Operator / Co Rep monitor well while remainder of crew eats
lunch. Fill backside with 8.4+ ppg 1% KCL, returns after 30 bbls. POH with 2-7/8" tubing while spooling Heat Trace and ESP
Cable. Joint 22 laid down as of 0300 hrs. Filling with 5 bbls of 8.4+ ppg 1% KCL each hour. POH with 2-7/8" tubing while
spooling Heat Trace and ESP Cable. Joint 36 laid down as of 0430 hrs. Filling with 5 bbls of 8.4+ ppg 1% KCL each hour.
4/11/2020 - Saturday
Pull hanger, 40k to overpull to release,
Continue to POOH w/ 2-7/8" tubing, heat trace cable and ESP power cable
Well on vacuum.
RIH with 3-1/2" 9.3# L-80 EUE tubing.
r. Pull Test Plug, then pull BPV Dart a
Well Name Rig API Number Well Permit Number Start Date End Date
MP J-03 ASR#1 50-029-22072-00-00 190-097 4/6/2020 4/11/2020
Hilcorp Alaska, LLC
Weekly Operations Summary
No operations to report.
Morning Safety Meeting, Discussed hazards of handling frozen pipe, always know location of rabbit and pumping sequnece
for pumping packer fluid. Continue to RIH w/ 3.5" 9.3# EUE tubing w/ seal assembly . Pumping double diplacement of source
water every 15 joints. Well static. Continue to RIH w/ 3.5" 9.3# EUE tubing w/ seal assembly. Tag seals @ 20.83' in on joint
143.and mark pipe, close annular and attempt low pressure test to determine if seal holding - seals leaking off. Work seal
assembly and finally get seals to break through something and fall into packer seal bore. Set down on seals w/ 3-4K down.
Pressure test casing to 500psi and seals holding solid, strip up on tubing 4.3' and pressure drop off immediately. Crews eat
lunch and pump 75bbls 2% barra-corr packer fluid and follow with 55 bbls source water. Shut down pumping and allow
wwell to settle out, well on vac. Lay down joint 143 and pick up 2' pup joint and space out hanger to land. Pulled 20.83' from
joint 143. Add in ASR KB = 17.2' + 2' pup joint +2'hanger pup =0.73' on hanger = 21.93' for required spaceout. Mobilize pups
to floor. Strap pups - will take 2 each 10' and 1 each 8' pup and drop out joint 141, MU joint 142 to pups and hanger for final
landing. Safety Meeting with night crew, discuss landing out completion and following pressure testing. Day crew has landed
out completion with 2k difference in slackoff weight. PUW averaging 35k before landing, SOW averaging 24k down. Swap
out crews. Conduct MIT of casing by tubing string. Slowly bring up test pressure to 1,600psi (well on vacuum, had to be
careful due to Shear Out Valve differential pressure of 2,000psi and hydrostatic combined with test pressure could shear
valve prematurely). Lock in pressure at just over 1,600psi. Bled 800psi in first 15 minutes, 300psi in second 15 minutes for
good test. Pressure up, shear at 1,810psi. Break circulation, returns. Open up to well. Install BPV, well J-03 secure as of 2030
on 4/11/2020. Follow on activities will be to RDMO of J-03, mobilize rig equipment to A-pad for maintenance. Clear location
of support equipment so crane can move in for picks. De-pressurize BOP, disconnect all hoses, ND BOP. Lower Sheave,
lower Derrick. Conduct picks of tongs, floor equipment, Rig Floor with crane and lower. Pick BOP with crane. NU Dry Hole
Tree, pressure test.
No operations to report.
4/14/2020 - Tuesday
4/12/2020 - Sunday
No operations to report.
4/13/2020 - Monday
MIT casing to 1600 psi
Conduct MIT of casing by tubing string. Slowly bring up test pressure to 1,600psi
Continue to RIH w/ 3.5" 9.3# EUE tubing w/ seal assembly. Tag seals @ 20.83' in on joint
143.and mark pipe, close annular and attempt low pressure test to determine if seal holding -
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: Coil Cement Plugback
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/Pool(s):
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD):
5,449'N/A
Casing Collapse
Structural N/A
Conductor 2,020psi
Surface 5,410psi
Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft):
12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work:
Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service
14. Estimated Date for 15. Well Status after proposed work:
Commencing Operations:OIL WINJ WDSPL Suspended
16. Verbal Approval:Date:GAS WAG GSTOR SPLUG
Commission Representative: GINJ Op Shutdown Abandoned
Chad Helgeson Contact Name: Stan Porhola
Operations Manager Contact Email:
Contact Phone: 777-8412
Date:4/3/2020
Conditions of approval: Notify Commission 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 COMMISSION Date:
Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng
sporhola@hilcorp.com
COMMISSION USE ONLY
Authorized Name:
Perforation Depth TVD (ft): Tubing Size:
PRESENT WELL CONDITION SUMMARY
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL0025906
Tubing Grade:Tubing MD (ft):
190-097
Anchorage Alaska 99503 50-029-22072-00-00
Hilcorp Alaska LLC
Length Size
3800 Centerpoint Dr, Suite 1400
C.O. 477.05
MILNE PT UNIT J-03
6.5 / L-80 / EUE 8rd
TVD Burst
4,603'
MD
N/A
7,240psi
2,373'
4,219'
2,680'
5,434'
115'115'
Perforation Depth MD (ft):
See Schematic
4,679(MD)/ 3,698(TVD), 4,981(MD)/ 3,908(TVD) & 5,189(MD)/ 4,051(TVD) and N/A
115'13-3/8"
9-5/8"
7"
Authorized Title:
17. I hereby certify that the foregoing is true and the procedure approved herein will not
be deviated from without prior written approval.
Authorized Signature:
4/17/2020
2-7/8"
(2) Otis Versa-trieve & Otis AWD Perm. Pkrs and N/A
See Schematic
MILNE POINT / SCHRADER BLUFF OIL
4,229' 5,214' 4,068' 1,082 5,354'
2,680'
5,434'
3,520psi
No
No
Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval.
Chad A Helgeson
cn=Chad A Helgeson, c=US,
o=Hilcorp Alaska LLC, ou=ANS
Operations Manager,
email=chelgeson@hilcorp.com
2020.04.13 11:29:09 -05'00'
By Samantha Carlisle at 7:56 am, Apr 16, 2020
320-168
DLB 04/16/20
+ Suspended well inspection required within 1 yr per 20 AAC 25.110(e)
10-407 X
gls 4/16/20
DSR-4/16/2020
4/17/2020
Well Prognosis
Well: MPU J-03
Date: 04/09/2020
Well Name:MPU J-03 API Number:50-029-22072-00-00
Current Status:Oil Well [SI ESP]Pad:Milne Point J-Pad
Estimated Start Date:April18th, 2020 Rig:Coil Tubing
Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd:
Regulatory Contact:Tom Fouts Permit to Drill Number:190-097
First Call Engineer:Stan Porhola (907) 777-8412 (O) (907) 331-8228 (M)
Second Call Engineer:Wyatt Rivard (907) 777-8547 (O) (509) 670-8001 (M)
AFE Number:2051449 Job Type:Coil Plugback
Current Bottom Hole Pressure: 1,439 psi @ 3,571’ TVD (SBHP 3/03/95/ EMW = 7.75 ppg)
Maximum Expected BHP:1,439 psi @ 3,571’ TVD (EMW = 7.75 ppg)
MPSP:1,082 psi (0.1 psi/ft gas gradient)
Brief Well Summary
The Milne Point J-03 well was drilled as a Schrader Bluff development well in December 1990 using Nabors 27.
The EWS #4 workover rig ran the initial gravel pack completion in May 1991. The most recent workover was in
March 1995 using Nabors 4ES to replace the ESP. The ESP was just shutdown after 25 years to allow the ASR rig
to pull the ESP and run a tieback string for coil tubing.
Notes Regarding Wellbore Condition
Casing last tested to 1,500 psi down to 5,355’ (Float Collar) on 12/28/1990.
Tubing Hanger is a WKM “TDF-CS-1” w/ 2.5” Cameron H BPV profile w/ ½” NPT port plugged.
Top Packer is an OTIS “VST” Versa-Trieve Gravel Pack Packer w/ 3.25” ID (6.26’ Long) @ 4,679’ MD.
Hole angle at top of Gravel Pack @ 4,679’ MD is 45°.
12 Gauge Screens are 3-1/2” 9.2# base pipe Wire Wrapped Screens (166’ Upper and 145’ Lower).
Last fill tag at 5,214’ WLM on 3/03/1995.
Objective:
The purpose of this work is to abandon the Schrader NA/NB/NC/NE/OA/OB perf intervals prior to drilling future
wells on Milne Point I-pad due to close approach risks and to help prevent potential MBE’s.
Future Wellbore Utility Options to be Reviewed:
1.) Rotary sidetrack into the Ugnu or Schrader Bluff sands.
2.) Coil tubing sidetrack into the Ugnu or Schrader Bluff sands.
3.) Conversion to a water source well in either the Prince Creek or Ugnu sands.
Coil Tubing Procedure:
1. MIRU Coiled Tubing Unit w/ 2.0” coil and spot ancillary equipment.
2. Fill source tank w/ produced water.
3. Pressure test BOPE to 3,500 psi Hi 250 Low, 10 min Hi, 5 min Low each test.
a. Each subsequent test of the lubricator will be to 3,500 psi Hi 250 Low to confirm no leaks.
b. No AOGCC notification required.
c. Record BOPE test results on 10-424 form.
ASR 1 tested MIT-IA on 4/11/20
The purpose of this work is to abandon the Schrader NA/NB/NC/NE/OA/OB perf intervals prior to d
r 25 years t
1600 psi
drilling future
wells on Milne Point I-pad due to close approach risks and to help prevent potential MBE’s.
Future Wellbore
NOTE:
CT BOPE test
Well Prognosis
Well: MPU J-03
Date: 04/09/2020
d. If within the standard 7 day test BOPE test period for Milne Point, a full body test and function test
of the rams is sufficient to meet weekly BOPE test requirement.
4. RIH w/ CCL memory logging carrier and 2.0” jet-swirl nozzle to 5,189’ MD (bottom packer depth). Wash
down as needed.
a. Min ID = 2.750”.
b. Last tag at 5,214’ WLM on 3/03/1995.
c. Use CCL log to confirm jewelry depths to correlate to coil tubing measured (CTM) depths.
5. Paint a flag at 5,189’ MD and log OOH.
6. Log up to 4,600’ and continue to POOH.
7. LD CCL memory logging carrier.
8. MU ball drop cementing nozzle and RIH to 5,189’ MD or previous tag depth.
9. Begin to mix cement. Once blend is up 15.8ppg, pump ±40 bbls of cement down the coil tubing.
a. Use freshwater spacers as needed around the cement.
b. Coil capacity est ±40 bbl (14,500’ of 2.0” 0.156” wall).
c. Bullhead fluids into the formation ahead of cement.
10. Allow ~0.5bbl of cement around the cementing nozzle and lay the rest of the cement in at 1:1 up to
5,000’ MD.
a. Lay in approximately ±2.5bbls of cement.
11. Attempt to squeeze away ±12bbls of cement. Do not exceed 500 psi above circulating pressure.
a. Squeezing cement into O-sand gravel pack and perfs.
b. Top of O-sand 12-gauge screens at 5,032’ MD.
c. Maintain pipe movement at ±50’ while pumping cement.
12. Lay cement in at 1:1 up from 5,000’ MD to 4,700’.
a. Lay in approximately ±2.5bbls of cement.
13. Attempt to squeeze away ±18bbls of cement. Do not exceed 500 psi above circulating pressure.
a. Squeezing cement into N-sand gravel pack and perfs.
b. Top of N-sand 12-gauge screens at 4,803’ MD.
14. PU to safety depth at ±4,500’ MD and attempt to squeeze away or lay in remaining ±5bbls of cement.
a. Do not exceed 500 psi above circulating pressure.
15. Swap to contaminate and RIH to cleanout from ±4,685’ MD to surface.
a. Use ±40 bbl of N-Vis for contamination.
16. POOH and circulate coil tubing clean as needed.
17. Wait on cement to gain 1,500psi compressive strength.
a. Wait on cement time estimated at 16-18 hours.
18. RIH w/ nozzle BHA and tag top of cement at estimated ±4,685’ MD.
19. Pressure test cement plug to 1,500psi for 30 min charted.
20. POOH and circulate coil tubing clean as needed.
a. Freeze protect well on way out of hole.
21.Contingency: If failed pressure test of the cement plug.
a. Re-squeeze cement down into gravel pack as needed.
22. POOH. LD nozzle BHA.
23. RD CT unit.
Attachments:
1. As-built Schematic
2. Proposed Schematic
3. Coil Tubing BOPE Schematic
MIT-T
against cmt
plug
Also test IA to 1500 psi for 30 min/chart. gls
RIH w/ nozzle BHA and tag top of cement at estimated ±4,685’ MD.
Pressure test cement plug to 1,500psi for 30 min charted.
_____________________________________________________________________________________
Revised By: STP 4/03/2020
SCHEMATIC (Post-Rig)
Milne Point Unit
Well: MPU J-03
Last Completed: Proposed
PTD: 190-097
Fill Tagged
@ 5,214’ WLM
3/03/1995
TD =5,449’ (MD) / TD =4,229’(TVD)
Orig. KB Elev.: 70.2’/ Orig. GL Elev.: 35.2’
Orig. Rig: EWS 4
7”
9-5/8 ”
1
PBTD =5,354 (MD) / PBTD =4,164’(TVD)
RA Marker in 7”
@ 4,633’
11,12,13,14,15,16 &
17
3
10
N Sands
19
2
13-3/8”
18
4, 5, 6,7,8 & 9
O Sands
CASING DETAIL
Size Type Wt/ Grade/ Conn ID Top Btm BPF
13-3/8" Conductor 54.5 / K-55 / Welded 12.415” Surface 115' N/A
9-5/8” Surface 36 / K-55 / BTC 8.921” Surface 2,680’ 0.0773
7" Production 26 / L-80 / BTC 6.276” Surface 4,536' 0.0383
TUBING DETAIL
3-1/2” Tubing 9.3 / L-80 / EUE 8rd 2.992” Surface 4,679’ 0.0087
JEWELRY DETAIL
No Depth Item
1 35’ 3-1/2” Tubing Hanger
2 4,674’ 3-1/2” Seal Assembly (Stabbed into Packer sealbore)
3 4,679’ Otis VST Versa-Trieve Gravel Packer w/ 5” LCT Box
4 4,685’ Otis MCS Closing Sleeve 5” LCT Pin x 4-1/2” LCT Box
5 4,705’ Howard Smith Screen Blank 3-1/2”
6 4,803’ Howard Smith Screen – All Welded Stainless Steel Wire Wrapped 3-1/2”
7 4,968’ Otis O-Ring Sub 3-1/2”
8 4,969’ Howard Smith Screen- Tell Tale All Welded Stainless Steel Screen 3-1/2”
9 4,980’ Otis Str. Slot Seal Assembly for Lower VST Gravel Packer
10 4,981 Otis VST Versa-Trieve Gravel Packer w/ 5” LCT Box
11 4,987’ Otis MFS Flow Sub Assy. 5-1/2” LCT Pin x 5” LCT Pin
12 5,004’ Otis Adapter w/ Collet Receptacle 5” LCT Box
13 5,005’ Howard Smith Screen Blank 3-1/2”
14 5,032’ Howard Smith Screen – All Welded Stainless Steel Wire Wrapped 3-1/2”
15 5,177’ Otis O-Ring Sub 3-1/2”
16 5,178’ Howard Smith Screen- Tell Tale All Welded Stainless Steel Screen 3-1/2”
17 5,189’ Otis Str. Slot Seal Assembly
18 5,189’ Otis AWD Perma-Series Permanent Production Packer 7”
19 5,196’ Collet Guide –Bottom @ 5,196.43’
OPEN HOLE / CEMENT DETAIL
13-3/8" Cmt w/ 485 sx of PF C in 30” Hole
9-5/8” Cmt w/ 1,087 sx PF E, 243 sx Class “G” in 12-1/4” Hole
7” Cmt w/ 285 sx Class “G” in 8-1/2” Hole
WELL INCLINATION DETAIL
KOP @ 500’ MD
Max Wellbore Angle = 50.5 deg @ 3,800’ MD
WELLHEAD
Tree 2-9/16” 5M MKM
Wellhead 11” 5M MKM
Actuator 2-9/19 5M Baker CAC
GENERAL WELL INFO
API: 50-029-22072-00-00
Drilled and Cased by EWS #4 – 12/29/1990
Gravel Pack and ESP Completion by EWS #4 – 5/25/1991
ESP Replacement by Nabors 4ES – 3/4/1995
PERFORATION DETAIL
Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status
N Sands
4,822’ 4,828’ 3,798’ 3,802’ 6 5/20/1991 Open
4,852’ 4,887’ 3,819’ 3,843’ 35 5/21/1991 Open
4,897’ 4,908’ 3,850’ 3,858’ 11 5/20/1991 Open
4,927’ 4,960’ 3,871’ 3,894’ 33 5/20/1991 Open
O Sands 5,045’ 5,087’ 3,952’ 3,981’ 42 5/16/1991 Open
5,132’ 5,167’ 4,012’ 4,036’ 35 5/16/1991 Open
Perforation Data: 24 SPF with SLB 24 GM, 43C BH charges, 135° phasing shot E/L 12 SPF; TCP 12 SPF, surged w/
300 PSI U/B
ESP CABLE DETAIL
6-1/2 Flat Guards + 39 bands
289 Preformed Bands
1,189 Flat Bands
FRAC PACK SUMMARY
5,045’ to 5,147’: 10,535 lbs of 20/40 Sand
4,822’ to 4,960’: 9,515 lbs of 20/40 Sand
GLM with
DV at
2500 ft.
_____________________________________________________________________________________
Revised By: STP 4/09/2020
PROPOSED (Post-Rig)
Milne Point Unit
Well: MPU J-03
Last Completed: Proposed
PTD: 190-097
TD =5,449’ (MD) / TD =4,229’(TVD)
Orig. KB Elev.: 70.2’/ Orig. GL Elev.: 35.2’
Orig. Rig: EWS 4
7”
9-5/8 ”
1
PBTD =5,354 (MD) / PBTD =4,164’(TVD)
RA Marker in 7”
@ 4,633’
11,12,13,14,15,16 &
17
3
10
N Sands
19
2
13-3/8”
18
4, 5, 6,7,8 & 9
O Sands
Planned TOC
@ 4,685’
Fill Tagged
@ 5,214’ WLM
3/03/1995
CASING DETAIL
Size Type Wt/ Grade/ Conn ID Top Btm BPF
13-3/8" Conductor 54.5 / K-55 / Welded 12.415” Surface 115' N/A
9-5/8” Surface 36 / K-55 / BTC 8.921” Surface 2,680’ 0.0773
7" Production 26 / L-80 / BTC 6.276” Surface 4,536' 0.0383
TUBING DETAIL
3-1/2” Tubing 9.3 / L-80 / EUE 8rd 2.992” Surface 4,679’ 0.0087
JEWELRY DETAIL
No Depth Item
1 35’ 3-1/2” Tubing Hanger
2 4,674’ 3-1/2” Seal Assembly (Stabbed into Packer sealbore) – Btm @ 4,679’
3 4,679’ Otis VST Versa-Trieve Gravel Packer w/ 5” LCT Box
4 4,685’ Otis MCS Closing Sleeve 5” LCT Pin x 4-1/2” LCT Box
5 4,705’ Howard Smith Screen Blank 3-1/2”
6 4,803’ Howard Smith Screen – All Welded Stainless Steel Wire Wrapped 3-1/2”
7 4,968’ Otis O-Ring Sub 3-1/2”
8 4,969’ Howard Smith Screen- Tell Tale All Welded Stainless Steel Screen 3-1/2”
9 4,980’ Otis Str. Slot Seal Assembly for Lower VST Gravel Packer
10 4,981 Otis VST Versa-Trieve Gravel Packer w/ 5” LCT Box
11 4,987’ Otis MFS Flow Sub Assy. 5-1/2” LCT Pin x 5” LCT Pin
12 5,004’ Otis Adapter w/ Collet Receptacle 5” LCT Box
13 5,005’ Howard Smith Screen Blank 3-1/2”
14 5,032’ Howard Smith Screen – All Welded Stainless Steel Wire Wrapped 3-1/2”
15 5,177’ Otis O-Ring Sub 3-1/2”
16 5,178’ Howard Smith Screen- Tell Tale All Welded Stainless Steel Screen 3-1/2”
17 5,189’ Otis Str. Slot Seal Assembly
18 5,189’ Otis AWD Perma-Series Permanent Production Packer 7”
19 5,196’ Collet Guide –Bottom @ 5,196.43’
OPEN HOLE / CEMENT DETAIL
13-3/8" Cmt w/ 485 sx of PF C in 30” Hole
9-5/8” Cmt w/ 1,087 sx PF E, 243 sx Class “G” in 12-1/4” Hole
7” Cmt w/ 285 sx Class “G” in 8-1/2” Hole
WELL INCLINATION DETAIL
KOP @ 500’ MD
Max Wellbore Angle = 50.5 deg @ 3,800’ MD
WELLHEAD
Tree 2-9/16” 5M MKM
Wellhead 11” 5M MKM
Actuator 2-9/19 5M Baker CAC
GENERAL WELL INFO
API: 50-029-22072-00-00
Drilled and Cased by EWS #4 – 12/29/1990
Gravel Pack and ESP Completion by EWS #4 – 5/25/1991
ESP Replacement by Nabors 4ES – 3/4/1995
PERFORATION DETAIL
Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status
N Sands
4,822’ 4,828’ 3,798’ 3,802’ 6 5/20/1991 Open
4,852’ 4,887’ 3,819’ 3,843’ 35 5/21/1991 Open
4,897’ 4,908’ 3,850’ 3,858’ 11 5/20/1991 Open
4,927’ 4,960’ 3,871’ 3,894’ 33 5/20/1991 Open
O Sands 5,045’ 5,087’ 3,952’ 3,981’ 42 5/16/1991 Open
5,132’ 5,167’ 4,012’ 4,036’ 35 5/16/1991 Open
Perforation Data: 24 SPF with SLB 24 GM, 43C BH charges, 135° phasing shot E/L 12 SPF; TCP 12 SPF, surged w/
300 PSI U/B
ESP CABLE DETAIL
6-1/2 Flat Guards + 39 bands
289 Preformed Bands
1,189 Flat Bands
FRAC PACK SUMMARY
5,045’ to 5,147’: 10,535 lbs of 20/40 Sand
4,822’ to 4,960’: 9,515 lbs of 20/40 Sand
MIT-IA and
MIT-T to 1500 psi
MILNE POINT UNIT
MPU J-03
4/03/2020
COIL BOPE
MPU J-03
13 X9 X7X3½
Valve, Swab, WKM-M,
3 1/8 5M FE
Valve, Upper Master, Baker,
3 1/8 5M FE, w/ Hydraulic
Valve, Lower Master, WKM-M,
3 1/8 5M FE
Blind/Shear Blind/Shear
Lubricator to injection
head
4 1/16 10M
Slip Slip
Blind/Shear Blind/Shear
Pipe Pipe
Manual Gate
2 1/8 5M
2.00" Single Stripper
Crossover spool
4 1/16 10M X 4 1/16 5M
Manual Gate
2 1/8 5M
Tubing Adapter, 3 1/8 5M
Pump-In Sub
4 1/16 5M 1502 Union
Crossover spool
4 1/16 5M X 3 1/8 5M
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: Pull ESP / Run Tieback
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/Pool(s):
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD):
5,449'N/A
Casing Collapse
Structural N/A
Conductor 2,020psi
Surface 5,410psi
Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft):
12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work:
Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service
14.Estimated Date for 15.Well Status after proposed work:
Commencing Operations:OIL WINJ WDSPL Suspended
16. Verbal Approval:Date:GAS WAG GSTOR SPLUG
Commission Representative: GINJ Op Shutdown Abandoned
Chad Helgeson Contact Name: Stan Porhola
Operations Manager Contact Email:
Contact Phone: 777-8412
Date: 3/24/2020
Conditions of approval: Notify Commission 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 COMMISSION Date:
Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng
sporhola@hilcorp.com
COMMISSION USE ONLY
Authorized Name:
Perforation Depth TVD (ft): Tubing Size:
PRESENT WELL CONDITION SUMMARY
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL0025906
Tubing Grade:Tubing MD (ft):
190-097
Anchorage Alaska 99503 50-029-22072-00-00
Hilcorp Alaska LLC
Length Size
3800 Centerpoint Dr, Suite 1400
C.O. 477.05
MILNE PT UNIT J-03
6.5 / L-80 / EUE 8rd
TVD Burst
4,603'
MD
N/A
7,240psi
2,373'
4,219'
2,680'
5,434'
115'115'
Perforation Depth MD (ft):
See Schematic
4,679(MD)/ 3,698(TVD), 4,981(MD)/ 3,908(TVD) & 5,189(MD)/ 4,051(TVD) and N/A
115'13-3/8"
9-5/8"
7"
2,680'
5,434'
3,520psi
Authorized Title:
17.I hereby certify that the foregoing is true and the procedure approved herein will not
be deviated from without prior written approval.
Authorized Signature:
4/1/2020
2-7/8"
(2) Otis Versa-trieve & Otis AWD Perm. Pkrs and N/A
See Schematic
MILNE POINT / SCHRADER BLUFF OIL
4,229'5,214'4,068'1,082 5,354'
Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval.
Digitally signed by Chad
Helgeson
DN: cn=Chad Helgeson,
ou=Users
Date: 2020.03.25 06:14:16 -08'00'
Chad
Helgeson
By Samantha Carlisle at 7:58 am, Mar 25, 2020
320-130
10-404
gls 3/25/20 DLB 03/25/20
X
* 2500 psi BOP test
DSR-3/25/2020
X
tubing
3/26/2020
Well Prognosis
Well: MPU J-03
Date: 03/24/2020
Well Name:MPU J-03 API Number:50-029-22072-00-00
Current Status:Oil Well [Active ESP]Pad:Milne Point J-Pad
Estimated Start Date:April 1
st, 2020 Rig:ASR
Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd:
Regulatory Contact:Tom Fouts Permit to Drill Number:190-097
First Call Engineer:Stan Porhola (907) 777-8412 (O) (907) 331-8228 (M)
Second Call Engineer:Wyatt Rivard (907) 777-8547 (O) (509) 670-8001 (M)
AFE Number:205XXXX Job Type:Pull ESP
Current Bottom Hole Pressure: 1,439 psi @ 3,571’ TVD (SBHP 3/03/95/ EMW = 7.75 ppg)
Maximum Expected BHP:1,439 psi @ 3,571’ TVD (EMW = 7.75 ppg)
MPSP:1,082 psi (0.1 psi/ft gas gradient)
Brief Well Summary
The Milne Point J-03 well was drilled as a Schrader Bluff development well in December 1990 using Nabors 27.
The EWS #4 workover rig ran the initial gravel pack completion in May 1991. The most recent workover was in
March 1995 using Nabors 4ES to replace the ESP. The ESP is currently still active after 25 years.
Notes Regarding Wellbore Condition
x Casing last tested to 1,500 psi down to 5,355’ (Float Collar) on 12/28/1990.
x Tubing Hanger is a WKM “TDF-CS-1” w/ 2.5” Cameron H BPV profile w/ ½” NPT port plugged.
x Top Packer is an OTIS “VST” Versa-Trieve Gravel Pack Packer w/ 3.25” ID (6.26’ Long) @ 4,679’ MD.
x Hole angle at top of Gravel Pack @ 4,679’ MD is 45°.
x 12 Gauge Screens are 3-1/2” 9.2# base pipe Wire Wrapped Screens (166’ Upper and 145’ Lower).
Objective:
The purpose of this work is to pull the ESP with the ASR rig and abandon/isolate both Schrader intervals (N and
O sands) with cement. The Schrader NA/NB/NC/NE/OA/OB perf intervals needs to be abandoned prior to drilling
future wells on Milne Point I-pad due to close approach risks and to help prevent potential MBE’s.
Future Wellbore Utility Options to be Reviewed:
1.) Rotary sidetrack into the Ugnu or Schrader Bluff sands.
2.) Coil tubing sidetrack into the Ugnu or Schrader Bluff sands.
3.) Conversion to a water source well in either the Prince Creek or Ugnu sands.
Pre-Rig Procedure:
1. MIRU Slickline unit.
a. MU tubing punch and punch hole in 2-7/8” tubing above ESP @ 4,565’ MD. POOH.
b. RD Slickline Unit.
2. RU LRS and PT lines to 3,000 psi.
3. Circulate at least one wellbore volume down to tubing punched holes at +/- 4,500’ MD (120 bbl) with
8.3 ppg produced water and 1 drum of Baraklean (for tubing cleaning) down tubing, taking returns up
the casing to the 500 bbl returns tank.
The ESP is currently still active after 25 years.
The purpose of this work is to pull the ESP with the ASR rig and abandon/isolate both Schrader intervals (N and
O sands) with cement. The Schrader NA/NB/NC/NE/OA/OB perf intervals needs to be abandoned prior to drilling
future wells on Milne Point I-pad due to close approach risks and to help prevent potential MBE’s.
Well Prognosis
Well: MPU J-03
Date: 03/24/2020
4. Clear and level pad area in front of well. Spot rig mats and containment.
5. RD well house and flowlines. Clear and level area around well.
6. Confirm well is dead. Freeze protect tubing/casing as needed with 60/40 MeOH.
7. RD Little Red Services.
8. RU crane. Set BPV. ND Tree. NU BOPE. RD Crane.
9. NU BOPE house. Spot mud boat.
Brief RWO Procedure:
10. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment and lines to returns tank.
11. Check for pressure and if 0 psi, pull BPV. If needed, bleed off any residual pressure off tubing and
casing. If needed, kill well w/8.3 ppg produced water prior to pulling BPV. Pump +/- 70 bbl down the
casing.
12. Set BPV Plug (converting BPV to TWC).
13. Test BOPE to 250 psi Low/ 2,500 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve
and test for 5-min). Record accumulator pre-charge pressures and chart tests.
a. Notify AOGCC 24 hours in advance of BOP test.
b. Perform Test per ASR #1 BOP Test Procedure dated 11/03/2015.
c. Confirm test pressures per the Sundry Conditions of approval.
d. Test VBR ram on 2-7/8” and 3-1/2” test joints.
e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test.
14.Contingency: If BOPE test fails
a. Notify Operations Engineer (Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr. Jim Regg (AOGCC) via
email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to
send an inspector to witness test.
b. With stack out of the test path, test choke manifold per standard procedure
c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the
surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere
at surface.)
d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record
the pumping rate and pressure.
e. Once the BOP ram and annular tests are completed, test the remainder of the system following the
normal test procedure (floor valves, gas detection, etc.)
f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile /
penetrator wouldn’t hold pressure and rolling test was performed on BOP Equipment and list
items, pressures and rates.
15. Bleed any pressure off casing to returns tank. Pull BPV plug and BPV. Kill well w/8.3 ppg produced
water as needed.
16. Rig up spoolers for ESP #4 round cable and Raychem Heat Trace (unknown OD) to 2,265’ MD.
a. Baker Hughes representative should be onsite for ESP pull.
17. RU spoolers and MU landing joint or spear and PU on the tubing hanger.
a. The PU/SO weights during the 1995 Nabors 4ES ESP RWO are unknown (estimate 27k UWT).
18. Recover the tubing hanger.
Test BOPE to 250 psi Low/ 2,500 psi High, annular to 250 psi Low/ 2,500 psi High
Well Prognosis
Well: MPU J-03
Date: 03/24/2020
Contingency (If a rolling test was conducted): MU new hanger or test plug to the completion
tubing. Re-land hanger (or test plug) in tubing head. Test BOPE per standard procedure.
a. Evaluate pulled tubing hanger for possible thread damage. If any damage is found, contact well
head specialist for possible replacement. Plan to re-use this hanger on this well.
19. POOH and lay down the 2-7/8” tubing. Lay down ESP.
a. Note any sand or scale inside or on the outside of the ESP on the morning report.
b. Look for over-torqued connections from previous tubing runs.
c. The well completion currently has:
i. 2,265’ of Ray Chem heat trace
ii. 1,149 Flat Bands on heat trace
iii. 4,600’ of ESP cable #4 round
iv. 349 Flat Guards (6’ Long)
v. 22 Flat Guards (3’ Long)
vi. 3 Flat Guards (4’ Long)
vii. 289 Preformed Bands
viii. 40 Flat Bands
ix. 6-1/2 Flat Guards
20. PU 3-1/2” seal assembly for Otis VST packer sealbore.
21. RIH w/ 3-1/2” EUE used tubing to +/- 4,679’ MD.
22. Tag packer, PU above sealbore to be able to circulate.
23. Pump corrosion inhibited brine (±70bbls 1% KCl + CI) and freeze protect fluid down the IA (±55bbls
freeze protect) to 2,100’ MD.
24. Tag no-go, PU 2’-3’ and space out to land.
a. Seal assembly is 5’ long w/ 2 set of bullet seals.
b. Otis VST tieback sealbore is 5’ long w/ 3.25” ID.
25. Land tubing hanger. RILDS. Note PU (Pick Up) and SO (Slack Off) weights on tally.
26. Bleed tubing to 0 psi.
27. Pressure test IA to 1,500 psi for 30 min and chart.
a. Notify OE in town if casing does not test.
28. Freeze protect tubing (Tbg ±20bbls freeze protect) for upcoming coil tubing operations.
29. Lay down landing joint. Set BPV.
Post-Rig Procedure:
30. Begin RD of ASR. RD BOPE house.
31. RU crane. ND BOPE.
32. NU used 3-1/8” 5,000# dry hole tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi
high. Pull BPV.
33. RD crane. Move to next well location. Move 500 bbl returns tank and rig mats to next well location.
34. Pull BPV.
35. RD crane. Move returns tank and rig mats to next well location.
36. Replace casing gauge(s) if removed.
37. Turn well over to production team.
ssure test IA to 1,500 psi for 30 min and chart.
Lay down ESP.
MIT
Casing
Well Prognosis
Well: MPU J-03
Date: 03/24/2020
38. Well is ready for coil tubing cement plugging. A separate sundry will be submitted to abandon the
reservoir in this well using coil tubing.
Attachments:
1. As-built Schematic
2. Proposed Schematic
3. BOPE Schematic
4. Blank RWO Sundry Change Form
Well is ready for coil tubing cement plugging. A eparate sundry will be submitted to abandon the se
reservoir in this well using coil tubing.
Note: CTU will abandon perforation intervals in separate sundry.
gls 3/25/20
_____________________________________________________________________________________
Revised By: TDF 1/17/2018
SCHEMATIC
Milne Point Unit
Well: MPU J-03
Last Completed: 3/4/1995
PTD: 190-097
TD =5,449’(MD) / TD =4,229’(TVD)
Orig. KB Elev.: 70.2’/ Orig. GL Elev.: 35.2’
Orig. Rig: EWS 4
7”
Raychem
Heat Trace
to 2,265’ MD
Banded
every 2’
9-5/8 ”
1
3
PBTD =5,354 (MD) / PBTD =4,164’(TVD)
RA Marker in 7”
@ 4,633’
13,14,15,16,17,18 &
19
5
12
N Sands
21
4
2
13-3/8 ”
20
6, 7, 8, 9, 10 & 11
O Sands
CASING DETAIL
Size Type Wt/ Grade/ Conn ID Top Btm BPF
13-3/8" Conductor 54.5 / K-55 / Welded 12.415” Surface 115' N/A
9-5/8” Surface 36 / K-55 / BTC 8.921” Surface 2,680’ 0.0773
7" Production 26 / L-80 / BTC 6.276” Surface 4,536' 0.0383
TUBING DETAIL
2-7/8” Tubing 6.5 / L-80 / EUE 8rd 2.441” Surface 4,250’ 0.0058
JEWELRY DETAIL
No Depth Item
1 4,565’ Pump: FC650 184 Stage - FPLTARC
2 4,580’ Seal Section: GSTDBHL
3 4,593’ Motor: KMEI 65HP/ 1,250V/ 30A
4 4,601’ Sensor: PHD – 21AD1566 –Bottom @ 4,603’
5 4,679’ Otis VST Versa-Trieve Gravel Packer w/ 5” LCT Box
6 4,685’ Otis MCS Closing Sleeve 5” LCT Pin x 4-1/2” LCT Box
7 4,705’ Howard Smith Screen Blank 3-1/2”
8 4,803’ Howard Smith Screen – All Welded Stainless Steel Wire Wrapped 3-1/2”
9 4,968’ Otis O-Ring Sub 3-1/2”
10 4,969’ Howard Smith Screen- Tell Tale All Welded Stainless Steel Screen 3-1/2”
11 4,980’ Otis Str. Slot Seal Assembly for Lower VST Gravel Packer
12 4,981 Otis VST Versa-Trieve Gravel Packer w/ 5” LCT Box
13 4,987’ Otis MFS Flow Sub Assy. 5-1/2” LCT Pin x 5” LCT Pin
14 5,004’ Otis Adapter w/ Collet Receptacle 5” LCT Box
15 5,005’ Howard Smith Screen Blank 3-1/2”
16 5,032’ Howard Smith Screen – All Welded Stainless Steel Wire Wrapped 3-1/2”
17 5,177’ Otis O-Ring Sub 3-1/2”
18 5,178’ Howard Smith Screen- Tell Tale All Welded Stainless Steel Screen 3-1/2”
19 5,189’ Otis Str. Slot Seal Assembly
20 5,189’ Otis AWD Perma-Series Permanent Production Packer 7”
21 5,196’ Collet Guide –Bottom @ 5,196.43’
OPEN HOLE / CEMENT DETAIL
13-3/8" Cmt w/ 485 sx of PF C in 30” Hole
9-5/8” Cmt w/ 1,087 sx PF E, 243 sx Class “G” in 12-1/4” Hole
7” Cmt w/ 285 sx Class “G” in 8-1/2” Hole
WELL INCLINATION DETAIL
KOP @ 500’ MD
Max Wellbore Angle = 50.5 deg @ 3,800’ MD
WELLHEAD
Tree 2-9/16” 5M MKM
Wellhead 11” 5M MKM
Actuator 2-9/19 5M Baker CAC
GENERAL WELL INFO
API: 50-029-22072-00-00
Drilled and Cased by EWS #4 – 12/29/1990
Gravel Pack and ESP Completion by EWS #4 – 5/25/1991
ESP Replacement by Nabors 4ES – 3/4/1995
PERFORATION DETAIL
Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status
N Sands
4,822’ 4,828’ 3,798’ 3,802’ 6 5/20/1991 Open
4,852’ 4,887’ 3,819’ 3,843’ 35 5/21/1991 Open
4,897’ 4,908’ 3,850’ 3,858’ 11 5/20/1991 Open
4,927’ 4,960’ 3,871’ 3,894’ 33 5/20/1991 Open
O Sands 5,045’ 5,087’ 3,952’ 3,981’ 42 5/16/1991 Open
5,132’ 5,167’ 4,012’ 4,036’ 35 5/16/1991 Open
Perforation Data: 24 SPF with SLB 24 GM, 43C BH charges, 135° phasing shot E/L 12 SPF; TCP 12 SPF, surged w/
300 PSI U/B
ESP CABLE DETAIL
6-1/2 Flat Guards + 39 bands
289 Preformed Bands
1,189 Flat Bands
FRAC PACK SUMMARY
5,045’ to 5,147’: 10,535 lbs of 20/40 Sand
4,822’ to 4,960’: 9,515 lbs of 20/40 Sand
_____________________________________________________________________________________
Revised By: STP 3/24/2020
PROPOSED
Milne Point Unit
Well: MPU J-03
Last Completed: Proposed
PTD: 190-097
TD =5,449’(MD) / TD =4,229’(TVD)
Orig. KB Elev.: 70.2’/ Orig. GL Elev.: 35.2’
Orig. Rig: EWS 4
7”
9-5/8 ”
1
PBTD =5,354 (MD) / PBTD =4,164’(TVD)
RA Marker in 7”
@ 4,633’
11,12,13,14,15,16 &
17
3
10
N Sands
19
2
13-3/8 ”
18
4, 5, 6,7,8 & 9
O Sands
CASING DETAIL
Size Type Wt/ Grade/ Conn ID Top Btm BPF
13-3/8" Conductor 54.5 / K-55 / Welded 12.415” Surface 115' N/A
9-5/8” Surface 36 / K-55 / BTC 8.921” Surface 2,680’ 0.0773
7" Production 26 / L-80 / BTC 6.276” Surface 4,536' 0.0383
TUBING DETAIL
3-1/2” Tubing 9.3 / L-80 / EUE 8rd 2.992” Surface 4,679’ 0.0087
JEWELRY DETAIL
No Depth Item
1 35’ 3-1/2” Tubing Hanger
2 4,674’ 3-1/2” Seal Assembly (Stabbed into Packer sealbore)
3 4,679’ Otis VST Versa-Trieve Gravel Packer w/ 5” LCT Box
4 4,685’ Otis MCS Closing Sleeve 5” LCT Pin x 4-1/2” LCT Box
5 4,705’ Howard Smith Screen Blank 3-1/2”
6 4,803’ Howard Smith Screen – All Welded Stainless Steel Wire Wrapped 3-1/2”
7 4,968’ Otis O-Ring Sub 3-1/2”
8 4,969’ Howard Smith Screen- Tell Tale All Welded Stainless Steel Screen 3-1/2”
9 4,980’ Otis Str. Slot Seal Assembly for Lower VST Gravel Packer
10 4,981 Otis VST Versa-Trieve Gravel Packer w/ 5” LCT Box
11 4,987’ Otis MFS Flow Sub Assy. 5-1/2” LCT Pin x 5” LCT Pin
12 5,004’ Otis Adapter w/ Collet Receptacle 5” LCT Box
13 5,005’ Howard Smith Screen Blank 3-1/2”
14 5,032’ Howard Smith Screen – All Welded Stainless Steel Wire Wrapped 3-1/2”
15 5,177’ Otis O-Ring Sub 3-1/2”
16 5,178’ Howard Smith Screen- Tell Tale All Welded Stainless Steel Screen 3-1/2”
17 5,189’ Otis Str. Slot Seal Assembly
18 5,189’ Otis AWD Perma-Series Permanent Production Packer 7”
19 5,196’ Collet Guide –Bottom @ 5,196.43’
OPEN HOLE / CEMENT DETAIL
13-3/8" Cmt w/ 485 sx of PF C in 30” Hole
9-5/8” Cmt w/ 1,087 sx PF E, 243 sx Class “G” in 12-1/4” Hole
7” Cmt w/ 285 sx Class “G” in 8-1/2” Hole
WELL INCLINATION DETAIL
KOP @ 500’ MD
Max Wellbore Angle = 50.5 deg @ 3,800’ MD
WELLHEAD
Tree 2-9/16” 5M MKM
Wellhead 11” 5M MKM
Actuator 2-9/19 5M Baker CAC
GENERAL WELL INFO
API: 50-029-22072-00-00
Drilled and Cased by EWS #4 – 12/29/1990
Gravel Pack and ESP Completion by EWS #4 – 5/25/1991
ESP Replacement by Nabors 4ES – 3/4/1995
PERFORATION DETAIL
Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status
N Sands
4,822’ 4,828’ 3,798’ 3,802’ 6 5/20/1991 Open
4,852’ 4,887’ 3,819’ 3,843’ 35 5/21/1991 Open
4,897’ 4,908’ 3,850’ 3,858’ 11 5/20/1991 Open
4,927’ 4,960’ 3,871’ 3,894’ 33 5/20/1991 Open
O Sands 5,045’ 5,087’ 3,952’ 3,981’ 42 5/16/1991 Open
5,132’ 5,167’ 4,012’ 4,036’ 35 5/16/1991 Open
Perforation Data: 24 SPF with SLB 24 GM, 43C BH charges, 135° phasing shot E/L 12 SPF; TCP 12 SPF, surged w/
300 PSI U/B
ESP CABLE DETAIL
6-1/2 Flat Guards + 39 bands
289 Preformed Bands
1,189 Flat Bands
FRAC PACK SUMMARY
5,045’ to 5,147’: 10,535 lbs of 20/40 Sand
4,822’ to 4,960’: 9,515 lbs of 20/40 Sand
To be
Plugged
Milne Point
ASR Rig 1 BOPE
2020
Updated 1/09/2020
11” BOPE
4.48'
4.54'
2.00'
INTEGRATED
4.30'INTEGRATED
11" - 5000
2-7/8" x 5" VBR
Blind11'͛- 5000
DSA, 11 5M X 7 1/16 5M (If Needed)
2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves
HCRManualManualManual
Stripping Head
Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Rig Work Over Sundry ProcedureDate: March 24, 2020Subject: Changes to Approved Sundry Procedure for Well MP J-03Sundry #: xxx-xxxAny modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.Step Page Date Procedure ChangeHAK PreparedBy (Initials)HAKApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date
"..-. .~
"'ELL HISTORY FILE COVER PAGE
XHVZS
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Please insure that it remains as the first page in this file.
~ ~ Well History File #
Digital Data Added to LaserFiche File
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-
[I DVD's - # [I Yes D No
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[I Diskettes - # IJ Yes I] No
-
Oversized Material Added to LaserFiche File
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-
I] Mud Logs # - 0 Yes 0 No
IJ Other # 0 Yes 0 No
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General Notes or Comments about this file.
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contact the Alaska Oil & Gas Conservation Commission to request copies.
Please call Robin Deason at (907) 793-1225 if you have any questions or infom1ation
requests regarding this file.
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
1. Operations performed: Operation shutdown Stimulate__ Plugging__
Pull tubing x Alter casing ~ Repair well x
Perforate__
Other.
2. Name of Operator
BP Exploration (Alaska) Inc.
3. Address
P. 0. Box 196612, Anchorage, Alaska 99519-6612
4. Location of well at surface
2732' SNL, 3331' WEL, SEC. 28, T13N, RIOE
5. Type of Well:
Development
Exploratory
Stratigraphic
Service
6. Datum elevation (DF or KB)
KBE = 70
7. Unit or Property name
Milne Point Unit
8. Well number
MPJ-03
At top of productive interval
5249' SNL, 3838' WEL, SEC. 28, T13N, RIOE
At effective depth
At total depth
400' SNL, 3981' WEL, SEC. 33, T13N, RIOE
9. Permit number/approval number
90-97/94-190
10. APl number
50- 029-22072
11. Field/Pool
Schrader Bluff
feet
12. Present well condition summary
Total depth: measured
true vertical
Effective depth: measured
true vertical
Casing Length
Structural
Conductor 80'
Surface 2645'
Intermediate
Production 5399'
Liner
Perforation depth:
5449
4158
5354
4093
Size
feet
feet
feet
feet
Plugs (measured)
Junk (measured)
Cemented Measured depth True vertical depth
13-3/8"
9-5/8"
485 sx PF "C" 115' 115'
lO87 sx AS IV/243 sx "G" 2680' 2359'
7" 285 sx Class "G" 5434' 4218'
measured 4822'-4828', 4852'-4887', 4897'-4908', 4927'-4960', 5045'-5087', 5132'-5167'
true vertical 3797'-3801', 3818'-3842', 3849'-3857', 3870'-3893', 3951'-3980', 4011'-4035'
Tubing (size, grade, and measured depth) 2-7/8", L-80 tubing w/Centrilift ESP to 4603' MD
Packers and SSSV (type and measured depth) Gravel pack screen assemby w/Otis "VST" versa-trieve packer @ 4679' MD & Otis
"AWD" packer @ 5189' MD (Raychem heat trace wa~r~te~(~ ~2~ I~)
13. Stimulation or cement squeeze summary
Intervals treated (measured)
Treatment description including volumes used and final pressure
I~ L~.L I v
APR -4 1995
Alaska 0il & Gas Cons. Commission
Anch0ra,
14.
Prior to well operation
Subsequent to operation
Representative Daily Average Production or Injection Data
OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure
Tubing Pressure
15. Attachments 16. Status of well classification as:
Copies of Logs and Surveys run __
Daily Report or/Well Operations x Oil x Gas Suspended
17. I hereby ce, i;tf',f/y t,b,at th,.,e foregoing is true and correct to the best of my knowledge.
Signed ~~-~ (/'~~_.4~
Form 10-404 I~v 06/15~88
Service
Title Dr/I//nE En~lineer Supervisor
Date /~/~
SUBMIT IN DUPLI~CATE ~_.,,~?
BP/AAI SHARED SERVICE
DAILY OPERATIONo
PAGE: 1
WELL: MP J-3
BOROUGH: NORTH SLOPE
UNIT: UNKNOWN
FIELD: UNKNOWN
LEASE:
API: 50-
PERMIT:
APPROVAL:
ACCEPT: 02/28/95 07:00
SPUD:
RELEASE:
OPERATION:
DRLG RIG: NABORS 4ES
WO/C RIG: NABORS 4ES
03/01/95 (1)
TD: 5434
PB: 5434
03/02/95 (2)
TD: 5434
PB: 5354
03/03/95 (3)
TD: 5434
PB: 5354
03/04/95 (4)
TD: 5434
PB: 5354
03/05/95 (5)
TD: 5434
PB: 5354
PULL BPV F/TREE
MW: 0.0
MOVE RIG F/L-17 T/J-3 & RU./SPO? OVER WELL. RU MUD, PIT
EXT. & HEAT SOURCE H20. 'RIG LINES T/COMP TREE & TIGER TANK.
TEST'LINES. RU LUBRICATOR & PULL BPV.
SETTING STORM PKR MW: 0.0
BLEED.GAS F/ ANN AND PUMP 8.3 PPG. HEATED SOURCE WATER AT
140 DEG DOWN TBG GAS AND CRUDE RETURNS TO TIGER TANK.
MONITOR. TBG AND ANNULAR. SEAWATER TREATED AND FILTER MIX
AND PUMP 40 BBL XANVIS PILL W/ LITHIUM BREAKER. CIRC DOWN
TBG TO TIGER TANK. DIVERT CLEAN SOURCE WATER TO GAS BUSTER
AND CONTINUE CIRC TO REMOVE GAS INFLUX. NIPPLE DOWN TREE
AND ADAPTER FLANGE. NIPPLE UP BOPS AND CHANGE RAMS TO 2
7/8". TEST BOPS. RIG UP LUB MADE FOR OFFSET HGRS AND PULL
TWC AND RIG DOWN SAME. PICK UP LANDING JT BACK OUT RILDS
AND PULL AND LAY DOWN HGR. PULL 1 STAND TBG AND INSTALL
BAKER PKR AND SET 90' RT.
RIH W/ ESP ASSY MW: 0.0
NIPPLE DOWN BOP'S AND CHANGE OUT ALIGNMENT PIN IN TBG
SPOOL. N/U BOPS AND SET TEST PLUG. RIH AND RETRIEVE AND
LAY DOWN STORM PKR. CIRC BOTTOMS UP. CIRC. POH W/ ESP
ASSY RIG UP CAMCO AND RIH TO 5214'. RIG UP EQUIPMENT TO
RUN ~SP COMPLETION ASSY. RIH W/ ESP COMP ASSY. RE-TORQUE
ALL TBG BREAKS DUE TO FINDING TBG LOOSE ON TOH. RIG UP
RAYCHEM HEAT TRACE RUNNING EQUIP. RIH W/ COMPLETION ASSY.
N/D BOP AND N/U TREE MW: 0.0
RIH W/ ESP COMPLETION ASSY. RAN TOTAL OF 144 JTS 2 7/8"
6.5# L-80 8RD EUE TBG. HEAT TRACE TAPE USED 349 (6') + 22
(3') + 3 (4') FLAT GUARDS + 1149 FLAT BANDS. ESP CABLE
USED 289 PREFORMED BANDS + 40 FLAT BANDS + 6 1/2" FLAT
GUARDS. MAKE UP SPACE PUPS AND HANGER AND HOOK HEAT TRACE
TAPE AND BANDS. MAKE ESP LINE HANGER SPLICE AND CK. LAND
TBG RILDS AND LAY DN LANDING JT. SET BPV. NIPPLE DN BOPS.
RELEASE RIG MW: 0.0
NIPPLE UP TREE AND TEST. PICK PU LUB AND PULL TWC. FREEZE
PROTECT ANNULUS W/ DIESEL AND TBG W/ MECH. SET BPV. RIG
DOWN CELLAR LINES AND SECURE TREE. RELEASE RIG @ 1300 HRS
ON 03/04/95.
R F..C£ V F-.D
APR -4 1995.
Oil & Gas Cons. Commissior~
Anchom '
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMI~,51ON
APPLICATION FOR SUNDRY APPROVALS
1. Type of Request:
2. Name' of Operator
Abandon __ Suspend ~ Operation Shutdown ~ Re-enter suspended well~
Alter casing ~ Repair well x Plugging __ Time extension __ Stimulate x
Change approved program __ Pull tubing x Variance Perforate Other __
BP Exploration (Alaska) inc.
3. Address
P. O. Box 196612, Anchorage, Alaska 99519-6612
5. Type of Well: 6.
Development c
Exploratory __
Stratigraphic __
Service
Datum elevation (DF or KB)
KBE-- 70 feet
7. Unit or Property name
Milne Point Unit
4. Location of well at surface
2732' SNL, 3331' WEL, SEC. 28, T13N, RIOE R E C E IV E D
At top of productive interval
5249'SNL, 3838'WEL, SEC. 28, T13N, RIOE JUL- 8 1994
At effective depth 10.
Alaska 0il & Gas Cons, C0mmissl0n
8. Well number
MPJ-03
9. Permit number
9O-97
APl number
50- 029-22O72
At total depth Anchorage
400' SNL, 3981' WEL, SEC. 33, T13N, RIOE
12. Present well condition summary
Total depth: measured 5449 feet Plugs (measured)
true vertical 4158 feet
Effective depth: measured 5354 feet Junk (measured)
true vertical 4093 feet
11. Field/Pool
Schrader Bluff
Casing Length
Structural
Conductor 80'
Surface 2645'
Intermediate
Production 5399'
Liner
Perforation depth:
Size Cemented Measured depth True vertical depth
13-3/8" 485 sx PF "C" 115' 115'
9-5/8" lO87 sx AS IV/243 sx "G" 2680' 2359'
7" 285 SX Class "G" 5434' 4218'
measured 4822'-4828', 4852'-4887', 4897'-4908', 4927'-4960', 5045'-5087', 5132'-5167'
true vertical 3797'-3801', 3818'-3842', 3849'-3857', 3870'-3893', 3951'-3980', 4011'-4035'
Tubing (size, grade, and measured depth) 2-7/8", L-80 tubing to 4637' MD
Packers and SSSV (type and measured depth) Otis "VST" versa-trieve packer @ 4679' MD; Reda DN-800 ESP @ 4590' MD
13. Attachments Description summary of proposal × Detailed operations program ~ BOP sketch
14. Estimated date for commencing operation
8/18/94
,,,
16. If proposal was verbally approved
Name of approver
Date approved
15. Status of well classification as:
Oil x Gas
Suspended __
Service
7. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Signed ,/~",.~ ( L~'~ /"~r~~ Title Drilling Engineer Supervisor
~" ..... FOR COMMISSION USE ONLY
Conditions of apprOVal: Notify Commission so representative may witness
Plug integrity BOP Test~ Location clearance ~
Mechanical Integrity Test~ Subsequent form required 10-
Date
J Approval No~ ,~//,__ ~ a
Approved by order of the Commission
Form 10-403 Rev 06/15/88
ORIGINAL SIGNED BY
Commissioner
Approved Copy
Returned
Date 7 //' (-/ ,/' p c/
SUBMIT IN TRIPLICATE
Milne Point J-03 RWO and HCI Stimulation
Ob!ective:
The objective of this work is to pull a failed electrical submersible pump from the
well, perform an acid stimulation and flowback with Nabors 4ES workover rig,
then recomplete with a new ESP. The work is expected to begin 8/18/94.
Work Outline:
.
Pre-dg: Perforate tubing immediately above ESP at +/- 4570. Circulate
crude from well with Milne source water. Freeze protect with diesel.
Install BPV.
,
MIRU Nabors 4ES wokover rig. Pull existing 2 7/8" tubing and ESP
assembly.
.
Check PBTD with slickline (a fill cleanout may be performed if excessive
fill covers lower perfs).
.
Run seal assembly and jet pump on workstring. Sting into packer at
4679 MD.
.
Pump nitrified HCI acid stimulation. Flow back well via jet pump and
workstring.
6. Pull workstring and lay down seal assembly and jet pump.
,
Recomplete well with new ESP and heat trace on 2 7/8", 6.5#, L-80
tubing.
8. RDMO Nabors 4ES. Place well on production.
RECEIVED
JUL - 8 1994
Oit & Gas Cons. Commission
Anchorage
DBR, 3:47 PM, June 22, 1994
NOTES:
1. ALL DEPTHS MEASURED
KDB-SL - 70.2'
2. MAX. ANGLE - 50'2g' @ ,3800'
3. K.O.P. = 500'
4. SLANT HOLE: YES
5. TREE TYPE: WKM 2 9/16", 5000#
W/ 2 7/8" 8rd TREETOP CONNECTION
6. MIN ID = 1.g9" @ 4589'
7. COMPLETION FLUID: 8.5 PPG NaCl W/ 14%
METHANOL
8. STIMULATION: FRAC PACK (5045'-5147')
PUMPED 10,535# OF 20/40 MESH GRAVEL
FRAC PACK (4822'-4960')
PUMPED 9,515# OF 20/40 MESH GRAVEL
9. ESP ASSEMBLY: REDA DN-800 PUMP WITH 191
STAGES, 75 HP, 1345V/35A MOTOR W/SHROUD,
KGS GAS SEPARATOR, BSBSL PROTECTOR, PSI
UNIT
N SAND PERFORATION DATA
MD TVD
DEPTH: 4822'-4828':o 3797'-5801'
4852'-4887'~5 3818'-3842'
4897'-4908'
4927'-4960' ~ 3870'-3893'~
DENSITY: 24 SPF, 24 GM
0 SAND PI~RFORATION DATA
DEPTH:
DENSITY:
WELL No. J-3
COMPLETION SKETCH
MILNE POINT UNIT (P)
MD TVD
5045'-5087' ~,~ 5951 '- 3980'
51,32'-5167' ~5 4011'-4055'
7" CASING @ 5454'
JUL "8 1994
Oil & Gas Cons. Commission
APl No.: 50-029-22072
PERMIT No.' 90-97
COMPLETED: 5/26/91
LAST WORKOVER: N/A
_
J~
WKM 2 7/8" TUBING HANGER W/ "H"
PROFILE BPV
144 JTS. 2 7/8", 6.5#, L-80, 8rd EUE TUBING
ESP CABLE - No. 2 REDA BLACK
4589' "XO" 2.875" x 2.375" (1.995" I.D.)
4590' TOP OF ESP
f, : , .-:. .z ~"T.'-.Z~ v..',-
4638' BOTTOM OF ESP
4679' OTIS "VST" VERSA-TRIEVE PACKER
(3.25" ID)
4705' H-S 5 1/2" BLANK PIPE (98')
4805' H-S, ,3.5", 12 ga SCREEN (166', 2.99"
FRAC PACK (N-SANDS) 20/40 MESH GRAVEL
4968' OTIS O-RING SEAL SUB (2.75" ID)
4969' H-S, .3 1/2" 12 9a TELL TALE SCREEN
(11', 2.99" ID)
4981' OTIS "VST" VERSA-TRIEVE PACKER
(3.88" ID)
5004' OTIS ADAPTER W/ COLLET RECEPTACLE
(2.99" ID)
5005' H-S 3 1/2" BLANK PIPE (27')
5032' H-S, .3.5", 12 ga SCREEN (145' 2.99" ID)
FRAC PACK (O-SANDS) 20/40 MESH GRAVEL
5177' OTIS O-RING SUB (2.75" ID)
5178'
5189'
5196'
5354'
H-S, 3.5", 12 ga TELL TALE SCREEN
(11', 2.99" ID)
OTIS "AWD" PACKER (4.0" ID)
COLLET GUIDE (2.98" ID)
PBTD
CONOCO INC.
ANCHORAGE DIVISION
APPROVED BY: BGA
DRAFTED BY: CFP
DATE: 7/29/92
C. AI') FII Fr WC..(I.I~
,~,~noco Inc.
Anchorage Division
To Larry Grant
Alaska Oil & Gas Conservation Commission
3001 Porcupine Drive
Anchorage, Alaska 99501-3192
(907) 279-1433
[] Under Separate Cover
Enclosed
· _~cord of Shipment of
Confidential Information
Date
From Steve Davies
Conoco Inc.
3201 C Street, Suite 200
June 10, 1993
Anchorage, Alaska 99503
(907) 564-7640
Via Petroleum Couriers
Subject
Quantity Contents
1 I~0[ ~[E-7 Final Drilling & Completion Report
0~\'~ ~..~-7 Core Analysis Report
1 ~_,-IIE~7 Sidewall Descriptions
~01"~'1 .~.-2 Final Drilling Report
C~1,-_~,~ ,-~1-3 Final Drilling Report
~1~ l"&~"l ~H~l-4 Final Drilling Report
(~rl~:~O~'!-I Final Drilling Report
¢~t31~--'~ I ~/rI-2 Final Drilling Report
.~ ~I-3 Final Drilling Report
-- _~1-3 No Whole Core or Sidewall Cores taken as noted on completion report.
~::~ 1~ ~-~1-4 Final Drilling Report
1 ~._-4A Core Analysis Report
1 ,.3~J-1 Final Drilling Report
c~1~5~-1 Core Analysis Report
I .~-1 Core Description Report
~1.,~/,~ ~-2 Final Drilling Report R E C E I V E D
~'1 '",~ 'J'-2 Completion History
~)1~"7 -. ~ Final Drilling Report JUNI I 7993
o~,~.~ d~-4 Final Drilling Report
orL-c7 Final Drilling & Completion Report
[-8 Final Drilling & Completion Report
1 ~I-E;9 Final Drilling & Completion Report
0/~) f/OI~ Core Description Report
Core Analysis Report
~Jaska Oil & Gas Cons. Commission
Anchorage
¢ Signed By
Transmittal Approved By ~ Date
Instructions: Please ack le~ige rec~ raptly by signing and returning second copy.
Received By Date
Remarks
· June 1
Transmittal Copy Only To
L,onoco Inc.
Anchorage Division
h=cord of Shipment of
Confidential Information
T° Larry Grant
Alaska Oil & Gas Conservation Commission
3001 Porcupine Drive
Anchorage, Alaska ~ 99501-3192
(907) 279-1433
[] Under Separate Cover
Enclosed
Date
From Steve Davies
Conoco Inc.
3201 C Street, Suite 200
M~y 5, 19~)3
Anchorage, AlaSka 99503
(907) 564-7640
Via Petroleum Couriers
Subject
Milne Point Well Log Magnetic Tapes I-2, I-3~ I-4~ I-4A~ J-l~ J-3~ J-4~ L-7r L-8~ L-9
Quantity
Contents
1 each
I-2 Magnetic Tape. ~)EDIT, APl #50-029-22066, Log Date: 03-NOV-90, Ref #74175.
I-3 Magnetic Tape. O.H.EDIT, APl #50-029-22067, Log Date: 12-NOV-90, Ref #74203.
!-4 Magnetic Tape. O.H.EDIT, APl #50-029-22068, Log Date: 19-Nov-90, Ref #74208.
1-48/Magnetic Tape.
J-1 Magnetic Tape.
J-3 Magnetic Tape.
J-4 Magnetic Tape.
L-7 Magnetic Tape.
L-8 Magnetic Tape.
~L-9 Magnetic Tape.
O.H.EDIT, APl #50-029-22068, Log Date: 29-Nov-90, Ref #74229.
Open Hole,APl #50-029-22070, Log Date: !3-Dec-90, Atlas Wireline & LIS listing,cji%'
O.H.EDIT, APl #50-029-22072, Log Date: 27-Dec-91, Ref #74271 & US Iisting:,~'/
O.H.EDIT, APl #50-029-22073, Log Date: 03-Jan-91, Ref #74276 & LIS Iisting.¢~0..¢~
O.H.EDIT, APl #50-029-22028, Log Date: 14-Feb-91, Ref #74350.
Open Hole,APl #50-029-22074, Log Date: 17-Apr-91, Ref #74527 & LIS Iisting. C~O~il3O
O.H.EDIT, APl #50-029-22075, Log Date: 28-Mar-91, Ref #74467.
RECEIVED
M~,Y 0 5 199~
~Jaska Oil & Gas Cons. Commission
Anchorage
**LIS listings not availabe for I-2, I-3, I-4, I-4A, L-7 & L-9. Verbal notification provided to H. Oakland. Waiver
granted via phone conversation May 5, 1993.
(~~~~~~ ~ ~,~ Signed By
Transmittal Approved By "'~ Date
Instructions: Please ackno~el~dge~.~f~omptly by signing and returning second copy,
Received By Date
May 5, 1993
Remarks
Transmittal Copy Only To
Suite
March 27, 1992
Mr. Blair Wondzell
Alaska Oil & Gas Conservation Commission
3001 Porcupine Dr.
Anchorage, Alaska 99501
Dear Blair Wondzell,
Please find attached the ce$ing and cementing reports for ,.I.-~and several other
Schrader Bluff wells. Unfortunately, the foreman that completed the form did not indicate
that there were full returns durir]g the ~,-~ne~t job. However, I contacted Ute foreman, Joe
Polya, that did the cement job and he informed me that it was an oversight on his part.
We have never had a problem with loss circulation on the 7" jobs on Schra~r Bluff wells
primarily due to the fact that we do not bring cement high enough in the wells to exceed
the fracture gradient. Additionally, I contacted the foreman opposite Mr. Polya and he
confirmed that loss returns on this cra~ing string if~ the Schrader Bluff wells is not a
problem. I have attached other casing/cementing reports from Schrader Bluff wells to
provide you with additional support.
Allow me to apologize for the delay in providing you with this information and if
there is an'ythi~g I can do in the future do not hesitate to call (G64-7609).
Be~t Regards,
Steve Bolt
Division Drilling Superintendent
RECEIVED
MAR 2 ? 1992
Alaska Uil & Gas Cons. Commission
Anchorage
FROM CONOCO
FuZZ Re~urns:~-~ NO] Cement Returns to Surface: (Ye$,~.. . .....
..,(].Bm) Final tandin{ ~eishc :___~> <lbs)
supervisor.-- ,~~~ .........
"-~' STATE OF ALASKA
ALASKA ,.,,L AND GAS CONSERVATION C MISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
1. Status of Well Classification of Service Well
OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] ....
2. Name of Operator 7. Permit Number
Conoco Inc ?T~':- ...... ~ ~,~:r 90--97
'3. Address il VE:.;i~ti~O ~ 8. APl Number
3201 'C' Street, Suite 200, Anchorage, Alaska 9950,3.,..,,~i 5o-029-22072
4. Location of well at surface : ;. 9. Unit or Lease Name
2733' FNL 3331' FEL Section 28 T13N R10E ~ Milne Point: Unit .,
At Top Producing Interval ~ U(}~.~}~L~ 10. Well Number
5249' FNL 3838' FEL Section 28 T13N R10E UM ~.~:.~m~
At Total Depth ~ ~ ~ 1 ~. Field and Pool
400' FNL 3981' FEL Section 33 T13N R10E UM ·
~ 'q~'~- ~ Kuparuk River Field
5. Elevation in feet {indicate KB, DF, etc.) 8. Lease Designation and o r~e~.~,~.~ ~
70~ RKB A_D~ 25906
1~. Date Spudded iS. Date T.D. Reached ~4. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore I 18. No. o~ Completions
12-23-90 12-26-90 5-26-90I NA feetMSLI 2
17. Total Depth {MD-I-TVD} l~.Plug Back Depth {MD~TVD) 19. Directional Survey ~0. Depth where SSSV set I ~l' Thickness of Permafrost
5449/4158 5354/A093 YESI~ NO[] NA fee~MDI ± 1800
~. Type Electric or Other Logs Run
AMS, NGT, CNL, LDT, DIL
23. CASING, LINER AND CEMENTING RECORD
-
SETTING DEPTH MD
CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED
13 3/8 54.5 K55 35 115 30 485sx PermaFrost C N/A
9 5/8 36 K55 35 2680 12 1/4 1087sx ArcticSet IV N/A
243sx G
7 26 L80 35 5434 8 1/2 285sx G N/A
24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD
interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD)
"N" Sand 12 JSPF/24 GM 2 7/8 4637 NONE
4822-4828 MD 3797-3801 TVD
4852-4887 MD 3818-3842 TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
4897-4908 MD 3849.3857 TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED
4927-4960 MD 3870-3892 TVD
"0" Sand 12 JSPF/24 GM
5045-5087 MD 3951-3980 TVD
5132-5167 MD 40t1-40~5 TVD
27. PRODUCTION TEST
Date First Production I Method of Operation (Flowing, gas lift, etc.)
I
Subme r s ib le
Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER~BBL CHOKE SIZE GAS-OIL RATIO
TEST PERIOD I~
·
Flow Tubing Casing Pressure CALCULATED~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr)
Press· 24-HOUR RATE ~'
28. CORE DATA
Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips.
NONE RECEIVED
OCT 8 ,991
Alaska .0il & Gas Cons. Commission
Anchorage
Form 10-407 Submit in duplicate
Rev. 7-1-80 CONTINUED ON REVERSE SIDE
29. 30.
GEOLOGIC MARKERS FORMATION TESTS
_
NAME Include interval tested, pressure data, all fluids recovered and gravity,
MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase.
Top of "N" Sand 4822 RKB 3797 RKB NONE
Top of "O" Sand 5045 RKB 3951 RKB
31. LIST OF ATTACHMENTS
Gyro Survey, Plat
32. I hereby certify that the foregoing is true and correct to the best of my knowledge
Signed ,~¢.)~ /~J~~. _~"~--~J T itle,~~f Foreman Date /O --' ~ O "-~/
INSTRUCTIONS
General: This form is designed for submitting a complete and correct well completion report and log on
all types of lands and leases in Alaska.
Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt
water disposal, water supply for injection, observation, injection for in-situ combustion.
Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements
given in other spaces on this form and in any attachments.
Item 16 and 24: If this well is completed for separate production from more than one interval (multiple
completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported
in item 27. Submit a separate form for each additional interval to be separately produced, showing the
data pertinent to such interval.
Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.).
Item 23' Attached supplemental records for this well should show the details of any multiple stage cement-
ing and the location of the cementing tool,
Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In-
jection, Gas Injection, Shut-in, Other-explain.
Item 28: If no cores taken, indicate "none".
Form 10-407
-,%
_ /
PROPOSED
MON d--i NORTH
6,015,.]13.Z5
551,531
1700.00
E 850.00
',~ J PAD
', J-1 ·
"x .,,~ j-2·
\ J-4. ·
=ROPOSED PROPOSED
~-2 sOUTH EXPANSION
8,0~ 4,507.26
551,884.66
820.00
850.00
" I
Y= 6,014,84-2.62
X= 552,201.70
POL #15
¥: 6,014,6.4-1.12
×= 552,289.96
>IOTES:
·
·
2.
J PAD
~ . ,~'¢¢YD'YI~ BAY
~LNE PONT ~ '~
ACCESS ~ ~ . . ~ ~ PRUDHO=
%~ /t~
'AILNE P'- ',"ICINITY MAP
MILES
STATE PLANE COORDINATES .ARE ZONE 4.
ALL GEODETIC POSITIONS ARE BASED ON
N.A.D. 1927.
OFFSETS TO SECTION LINES ARE COMPUTED
BASED ON PROTRACTED VALUES OF THE
SECTION CORNER POSITIONS.
LEGEND
· EXISTING WELL
O PROPOSED WELL
AS-BUILT
WELL DATA
LOCATED WITHIN SECTION 28
T. 13 N., R. 10 E., UMIAT MERIDIAN, ALASKA
WENoL. L PLANT A.S.P. ZONE 4. LATITUDE SEC. LINE
COORDS COORDS LONGITUDE OFFSETS
N 1300.07 Y 6,015,055.19 70' 2_.7' 06.742'" ] 2622' FNL
d-1 E 1119.80 X 551,939.18 14.9' 54-' 34..364." 3378' FEL
I
N 12,39.64 Y 6,015,000.11 70' 2.7' 06.199" 2677' FNL
J-2 E 1120.¢7 X 551,964..03 14-9' 34-' 33.64.6" 3354/ EL
J-3 N 1179.81 Y 6,014.,945.05 70' ?.7' 05.656' 273`3' FNL
E 1119.81 X 551,987.4.3 1¢9' 34' 32..970" 3531' FEL
N 1119.59 Y 6,014.,889.82 70' 27' 05.111' 2788' FNL
J-4 E 1119.62 X 552,011.4.2 14.9' 34.' 32.276" 3307' F-EL
SuRvEyoR'S
CERTIFICATE
?. Robert
I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED
AND LICENSED TO PRACTICE LAND SURVEYING IN THE
STATE OF ALASKA, AND THAT THIS PLAT REPRESENTS
A LOCATION SURVEY MADE BY ME OR UNDER MY DIR-
ECT SUPERVISION,AND THAT ALL DIMENSIONS AND
OTHER DETAILS ARE CORRECT.
,,
SURVEYED FOR:
(conoco)
- ATE: 4--20-gl
DRAWN: STOLL
CHECKED: HERRIN¢
AS-BUlL T 'EI_L CONDUCTORS
,JOB NO.: 90059
SCALE: 1"= SO0' -- 'd-/~
d-4
DWG 90059-12-A-t-77
iii
~ ¢¢ '.. Sl~EPHEN STOLL .-'~ ~
Conoco Inc.
Milne Point Well No J-3
Completion History
Milne Point J No. 3 - DRILL & EQUIP. API No.: 50-029-22072
Location: Milne Point Field - SCHRADER BLUFF POOL
AFE Number: 10-61-1253 Approved: 08/15/90, Rev. 01/11/91
AFE Amount: $1,741,000 gross Cost to Date: $1,776,187 gross
Operator: Conoco
Chevron
OXY
0.5942340
0.3764866
0.0292794
Objectives:
Schrader Bluff Pool
Spud Date: 12/23/90
Compl Rig Accepted: 05/13/91
Rig: EWS 4
Rig Release Date:
Compl Rig Released:
12/28/90
05/26/91
Planned
Drilling Days: 12
Completion Days: 14
Actual Planned Actual
6 Depth: 5,356' MD 5,356' MD
14
Test Summary:
Type Interval Shows
Current Operations:
05/14/91: Move rig from J-2 to J-3. Work on berms for break up chemical
stock and slop tank/filter van. NU BOPE. Rig on contract to
J-3 @ 0800 hrs on 05/13/91.
05/15/91: Pull hanger. Change rubbers on test plug and run same. Test
BOPE. Had called AOGCC @ 9 am on 5/13/91, AOGCC did not
witness test. Tally pipe & MU bit and casing scraper. TIH
w/ bit - csg scraper, 4 DCs, 2-7/8" tbg. Tag ice @ 520'. Circ
through. TIH w/ bit - tag up @ 5324'. Reverse out diesel &
9.2 brine w/ 8.5 filtered brine (193 bbls). Hookup to Arctic
Pac - Slop tank full. Unable to open valve - pressure locked.
Wait on bleeder tool & open valve. Dispose of slop tank down
7" x 9-5/8".
05/16/91: RU & Rev out 31 addl bbls (225 total of 196 hole vol). Pump 22
bbl dirt magnet pill, 12 bbl brine, 22 bbl dirt magnet pill and
190 bbls brine (Note: reversing). Pump pill to slop tank. Rev
circ and filter well one hole vol. POOH w/ 165 jts tbg while
pumping'96 bbls down 7" x 9-5/8" annulus (combined w/ 281 on 14
May = 377 bbls). Fill w/ 45 bbls diesel. Break down otis seal
assby. RU SWS. Run GR-JB to 5335'. Run GCT. Run GR-CCL w/
sump PKR - correlate to open hole log, pull strip and set sump
PKR @ 5189' not 5187' due to csg collar. Perf w/ 12 SPF/24 gm:
Run #1 5145'-5167' Fluid at surface, all shots fired
Run ~2 5132'-5147'
Run #3 5067'-5087'
Run #4 5047'-5067'
Run #5 5045'-5047'
Conoco Inc.
Milne Point
Well No. J-3
Page 2
RD SWS. PU Otis seal assby portion of TCP assby.
05/17/91: PU remainder of TCP assby. TIH w/ 40 stds tbg. Work on hook.
TIH w/ 17 stds. Set Champ III. Close Fas-Fil. Space out in
AWD, RU flowhead and lines. Set PKR & drop bar - guns fired
@ 11:16, 24 gm charges, 12 JSPF, 5167'-5132' & 5087-5045'.
Flow well 1 hour - weak blow at surface. Shear APRM-2 and
rev out 22 bbls brine and 3 bbls oil. POOH w/ TCP assby. Work
on #1 hydraulic motor. POOH. LD TCP assby/ PU Mod. seal assby
and 3 junk baskets. TIH w/ wash assby. Filter brine and RU
kelly to circulate.
05/18/91: Circ. POOH. Clean 3.junk baskets (top & bottom junk baskets
1/2 full - middle JB full). PU GP Assbly. TIH w/TBG. R/U
Dowell - Schlumberger.
Test lines to 5000. Drop ball. W.O. Ball to seat. Set Pkr &
test backside. Pickle TBG. Rev out 47 BBLS. Set tool in SQZ
position, establish rate and pump GP slurry. No screen out.
Rev out 81 BBLS and rec 30 BBLS 2% KCL WTR, 15 BBLS 8ppg
slurry~. ~0.BBLS Gel H20 & 15 BBLS Brine. RP P/S. Pull 1 std
and work stack pipe @ middle of second std - came free. Pull
10 std. POOH. Ported shifting sub washed out between shifting
sleeve and port. PU 3 JTS 1-1/4 & 5 JTS 2-3/8 and TIH w/159
JTS 2-7/8 - No fill tagged. Rev out 2 TBG vols (60 BBL) no
gravel rtns. POOH. LD 1-1/4 & 2-3/8. PU Washpipe.
05/Z0/9~: Space out & check seal assby. RU hardline to manifold. Test
lines and establish rates. Pump 17 BBL 10 ppgp slurry, screen
out w/1 BBL through tool. Rev out 12B 10ppg slurry. Rev out
35 BBLS brine to pits. Wait to test GP. Press test on GP.
Instant bleed off. GP w/14B 10ppg. 1/2 BBL through tool.
Screen out. Rev out 83 BBLS. POOH & L/D RNG Assbly. Run TDT.
Showed good log. Perf as follows: (all 12 JSPF/24 EM 43C JS).
Gun run - 1 Mis Run. Gun Run 2 - PF/4947-60. 13'. Gun Run 3 -
PF/4927 - 47. 20'. Gun Run 4 - PF/4907-8, 4897-4907,4822-28.
05/21/91: Perf No. 5 PF/ 4872'-87'. No. 6 PF/ 4852'-72'. Run GR-CCL
1-11/16" dummy run. RD loggers. Begin PU & tally TCP for "N"
sand. PU seal assby. TIH. Set PKR-pump 24 bbl diesel down
tbg. Unset PKR & TIH w/ 6 stds. Space out, set PKR, and check
backside to 500 psi. RU loggers. Run 1-11/16 GR-CCL - TCP in
correct position. RD. Drop bar & fire guns, flow to surface.
Open APRM-2 w/ csg press. Rev out w/ 97 bbls - well dead.
POOH.
05/22/91: POOH and LD TCP BHA. PU 7 jts 1-1/4 CSH/XO/ 1 jt 2-3/8
WFJ/XO/PUP/XO/3 JBs/XO/2-7/8" tbg. Pass through "0" sand GP
screens. Tbg plugged off after reversing 28 bbls. POOH
6 stds. Tbg unplugged - rev out 61 bbls. POOH. PU mod seal .
assby/PUP/XO/3 JBs/XO/2-7/8" tbg and TIH. Tag PKR @ 4982' and
insert seal assby to no-go. PU above PKR and work pipe between
PKR and bottom of "N" perfs @ 4960'. PU 3 stds (above N perfs)
and circulate & filter 2 hole volumes (350 bbls).
Conoco Inc.
Milne Point
Well No. J-3
Paqe 3
05/23/91: Fin reversing 350 bbls. POOH w/ 79 stds tbg - 3 JBs & seal
assby. Test BOpE. Replace seals on seal assby. PU screens,
PKR, WP and seal assby. TIH to 4982'. Drop ball. Test lines
to 5000 psi and set PKR. Pressure up and disengage R/T. Test
ann to 1000 psi. PU to "R" position and shift X-Weldmont
sleeve. Pickle tbg. Pump GP as follows: 25 bbl gel pad,
10 bbl 2 ppg, 27 bbl 2/8 ramp, 35 bbl 8 ppg slurry. Screen out
w/ 4.2 bbl. Disp @ 5000 psi. Repress to 3000 psi - bled off
slower. 22.8 bbl 8 ppg above tool, 7 bbl 8 ppg in ann, and
5.2 bbl 8 ppg in formation at screen out. Wait 4 hrs for
pressure test.
05/Z4/91: Test "N" sand gravel pack; @ 1 bpm - 568 psi, @ 2.2 bpm -
1500 psi. Pump 2nd gravel pack as follows: 10 bbls pad,
11 bbls 12 ppg slurry, 5 bbl post pad, 10 bbl KCL. Shift to
upper circ position. Screened .out w/ 16.5 bbl flush pumped.
Est 5.5 bbls slurry below tool. Wait. to test pack. Test pack
- OK. R/D Dowell Schlumberger. POOH. R/U Schlumberger. Run
gravel pack log. R/D Schlumberger. L/D DCs, 6 stds tbg. Pull
wear bushing. P/U shroud~ ESP & service. R/U cable shieves.
RIH w/ ESP.
05/Z5/9~: RIH w/ ESP on 2-7/8" tbg. M/U tbg hgr. Land hanger. Test
hanger seals to 5000 psi. OK. N/D BOPs. N/U tree. Test to
3000 psi. OK. Freeze protect w/ 60 bbls down 7" x 2-7/8" and
11 bbls down 2-7/8" tbg. Set BPV. Clean pits.
Finish cleaning pits. R/D derrick. Change out guide wires,
re-align derrick board. Drain lines in mud pumps, lines.
Fabricate new mud pump, kill lines to comply with AOGCC rules.
Install new lines.
05/Z7/9~: R/D. Move rig to B-19. Operations concluded, last day on
report. Rig released @ 1000 hrs 05/26/91.
Conoco Inc.
MILNE POINT WELL NO. J-2
Completion History
Milne Point J No. 2 - DRILL & EOUIP. API No.: 50-029-22071
Location: Milne Point Field - SCHRADER BLUFF POOL
AFE Number: 10-61-1252 Approved: 08/15/90, Revised 01/11/91
AFE Amount: $1,881,000 gross Cost to Date: $1,851,993 gross
Operator: Conoco
Chevron
OXY
0.5942340
0.3764866
0.0292794
Objectives:
Schrader Bluff Pool
Spud Date: 12/16/90
Compl Rig Accepted: 04/28/91
Rig: EWS 4
Rig Release Date:
Compl Rig Released:
12/22/90
Drilling Days: 7
Completion Days: 14
Planned Actual Planned Actual
8' Depth: 6,019' MD 6,094' MD
15
04/29/91: Accept rig on AFE 1252 @ 0900 hrs, 04/28/91. Move rig to J-2.
R/U. N/D tree. N/U BOPs.
04/30/91: N/U BOPs. Test plug failed. POOH. Change "O" ring seals.
Test pipe, blind rams, choke manifold to 3000 psi. Test
annular to 1500 psi. P/U 6-1/8" bit, scraper, 4 DCs. Go in
hole picking up DP. Tag ice @ 527'. Circ thru bridge. TIH
w/ bit & scraper.
05/01/91: RIH w/ bit & scraper. Tag bottom @ 6094' (27E RKB). R/U to
rev circ. Could not pump thru 7" csg valve. Move line from
7" csg valve to drlg spool on BOP stack. Pump 20 bbl dirt
magnet pill, 20 bbl H20, 20 bbl dirt magnet pill. Reverse circ
pills followed by filtered 8.5 ppg brine. Displace hole. Circ
1 hole vol (205 bbls) & filter. POOH. R/U Schlumberger. RIH
w/ gauge ring, junk basket & tag @ 6092'. POOH. Run GCT. M/U
sump PKR. RIH w/ PKR to 5920'. Attempt to set. No indication
setting tool fired. RIH to 5945'. Packer did not set. POOH.
05/02/91: Finish POOH w/ sump PKR. Found that secondary firing mechanism
on Baker setting tool did not work. Re-dress firing head.
TIH. Set sump PKR @ 5920'. POOH. R/U lubricator. Test
lubricator/casing to 500 psi. OK. M/U gun run #1.
RIH w/ GR, CCL, Gun. Perf "0" sand w/ 12 SPF, 24 gm charges:
5880'-5900' (20') Fluid level stayed same
5865'-5880' (15')
5801'-5803' ( 2')
5803'-5823' (20')
5781'-5801' (20') Fluid level at surface
05/02/91 (Continued):
RIH w/ 3-3/8" dummy run thru sump PKR to 5941'. Gun went thru
w/ no problem. POOH. R/D Schlumberger. P/U Baker seal assby,
collet locator, Schlum guns, Halco Champ III PKR, safety jt,
jars, APR-M2 valve. RIH w/ TCP assby on 4" drill pipe. Tag
sump PKR @ 5920'. Attempt to work thru sump PKR w/ seal assby.
Got 2-3 seals in sump PKR when assby failed to go any deeper.
Pulled 110 K#s (30 K overpull) to get seals out of PR.
Determined that assby was hydraulically locked. Plan: POOH
w/ TCP assby, drill hole in XO below guns for pressure
equalization.
05/03/91: Set Champ PKR @ 5667'. Pressure up to 2000 psi on backside to
open APR-M2. Reverse circ brine. POOH w/ TCP assby. M/U
re-dressed APR-M2 valve. Add ported XO below guns. M/U TCP
assby & TIH. Fill pipe w/ brine every 10 stds. Leave top
1200' dry. Tag sump PKR @ 5920'. Space out to put guns on
depth. Set Champ PKR. R/U surface lines, choke manifold.
Press test surface lines to 2500 psi. Test backside to
500 psi. OK. Drop bar. Guns fired @ 1650 hrs. Open well.
Kept well open until 1845 hrs - no flow to surface. Press up
.on annulus to 2000 psi to open APR-M2. Reverse circ 90 bbls
brine (1-1/2 times DP vol). Got back traces of oil off bottom.
Unseat Champ PKR. Attempt to run seals thru sump PKR -
unsuccessful. Had to unstick assby several times. R/D surface
lines, choke manifold. POOH w/ TCP assby.
05/04/9~: Finish POOH w/ TCP assby. L/D assby. M/U rounded guide on 8'
2-7/8" PUP jt. P/U 3 junk baskets & TIH. Tag sump PKR
@ 5920'. Circ bottoms up. Reciprocate thru sump PKR. Pump
130 bbls total. Lost ~ 40 bbls. POOH. L/D baskets, guide &
PUP jt. Recovered cups of gun debris. P/U gravel pack assby:
seal assby, GP screens, wash pipe, GP PKR. RIH w/ gravel pack
assby on 4" drill pipe.
05/05/9~: R/U surface lines. Prime pumps. Test surface lines to
60 psi/5000 psi. Drop 1.312" ball & pump down w/ 5 bbls. Set
gravel pack PKR w/ 1500 psi on DP. Pressure up to 2800 psi to
release running tool. P/U to reverse circ position. Press up
to 2800 psi - ball blew out of seat. Locate & mark tool
positions. Test annulus to 1500 psi. OK. Pump neutralizer to
slop tank (14.5 bbls). P/U to reverse circ position. Pump
10 bbl gel, 520 gal acid/super pickle. Pump down DP to within
1 bbl of GP PKR. Reverse circ pickle into slop tank.
Establish injection rates:
S/O to squeeze position;
Lower circ position;
1 bpm @ 505 psi
1 bpm-82 psi, 2 bpm-180 ps~,
3 bpm-320 psi
Conoco Inc.
Milne Point
Well No. J-2
PAGE 4
05/07/91: Wait on Ported XO from Otis. Work on following rig projects
while waiting:
a) Install new kill line system as per AOGCC request. System
is 85% complete. Will finish on next rig move.
b) Test kill, choke system, BOPs to 3000 psi, annular BOP to
1500 psi.
05/08/91: M/U wash pipe, seal assby (w/ ported XO), setting tool. RIH on
drill pipe. Tag gravel pack PKR @ 5725'. Space out seal
assby. Press test annulus to 500 psi. OK. R/U to circ in
upper circ position. Circ @ 1 bpm. Pump 10 bbl gel pill
followed by 12 bbl acid/super pickle. Displace acid to setting
tool then reverse out. With setting tool in upper circ
position, obtain circ rates of 1 bpm @ 200 psi, 2 bpm @
250 psi. Pump gravel pack as follows: 40 bbl prepad (pump 20 bbl in csg)
20 bbl slurry 2-10 ppg ramp, 20-40 mesh, 3700 #'s
10 bbl postpad
Pump pack away at 3 bpm - 800 psi. When slurry hit screen,
pressure increased to 2300 psi. Press drifted to 1200 psi.
P/U to reverse position & reverse out. Shift tool to upper
circ position. Test pack to 1750 psi. POOH. L/D otis setting
tool, seal assby, wash pipe.
05/09/91: R/U E/L. M/U guns. TIH. Perforate the following intervals at
12 SPF (4 runs): 5675'-5705', 5645'-5655', 5608'-5625',
5568'-5600'. M/U 3-3/8" dummy gun. RIH & go thru gravel pack
PKR @ 5725'. Go to 5745'. OK. POOH. P/U TCP assby. RIH
w/ TCP assby on 4" drill pipe. Tag GP PKR @ 5725'. Space out.
Set Champ III PKR. Press test surface lines to 3500 psi. OK.
Press up on annulus to 600 psi. Press up on drill pipe to
2500 psi (300 psi underbalance in DP). Guns fired @ 2137 hrs.
Perf. Interval "N" Sand SPF
5568-5600 (32') 12
5608-5625 (17') 12
5645-5655 (10') 12
5675-5705 (30') 12
Flow well for 1 hr. Well flowed back 6 bbls diesel. Press up
on annulus to 2000 psi to open APR-M2 valve. Reverse circ
diesel/crude oil out of drill pipe.
05/10/91: Finish reverse circ. Unseat Champ PKR. Pull seal assby out of
GP PKR. Attempt to sting back in seals. Could not get thru.
Pulling 100 K ~'s to get out of seal bore. POOH L/D drill
pipe, TCP assby. P/U muleshoe & 3 junk baskets. RIH picking
up 2-7/8" tubing to 5401'. R/U to circ pill.
Conoco Inc.
Milne Point
Well No. J-2
PAGE 5
05/11/91: Clean out pill tank. Mix 25 bbl Hi Vis pill. Pump pill and
displace same to EOT. PU 9 jts of tbg to tag PKR. Tag PKR &
CBU. W/O slickline. RU slickline & TIH - wouldn't pass junk
baskets. RU & begin pumping down 7" x 9-5/8" ann. POOH w/
junk baskets. LD same. PU seal assby & TIH. RU slickline &
fin pumping 7" x 9-5/8" annulus. Total pumped: 129 bbls slop
+ 44 bbls diesel. TIH & tag @ 5981' (Bottom perf @ 5900').
POOH & RD slickline.
05/12/9X: RD slickline. POOH w/ tbg & LD seal assby. PU screens and PKR
assby (T/ PKR @ 5371.28'). RIH w/ tbg & space out. RU Halco
manifold & floor piping. Test lines 500/3500 psi. Set PKR and
shift tool. Pickle tbg w/ 10 bbl gel, 12 bbl acid, 19 bbl
brine. Rev out same. Inj test as follows:
I. SQZ 1 bpm @ 640
II. LC 1 bpm @ 260*, 2 bpm @ 430, 3 bpm @ 700
III. UC 1 bpm @ 290, 2 bpm @ 470, 3 bpm @ 700
IV. Rev 1 bpm @ 200, 3 bpm @ 800
* Note: Bled press off in SQZ position and began pumping in
LC position - pressure spiked to 640 before settling to 260.
Reverse well getting fine perf debris over shaker. Gravel pack
well pumping 23 bbls @ 2#/B in SQZ mode, 1.5 bbls @ 8 ppb in
LC, 10 bbls @ 8 ppb in UC - leaving 3.5 bbls in tbg. 1800 psi
screen out. Rev out 900# gravel f/ well. Restress pack to
1800 psi twice. OK. RD Halco. POOH.
05/X3/91: Fin. POOH & LD Otis equipment. RU SWS. Run TDT-P from
5940'-5150'. 2 Additional TDT-P runs were made after swabbing
pack with a WID tool. RD SWS. LD 5 stds. PU Reda pump &
shroud (PSI in latched mode). RIH w/ 166 jts 2-7/8" 6.5# N-80
EU tubing & set pump @ 5281'. (Bottom of pump @ 5324' , T/GP
@ 5371'). (PSI reads 67.9 °F & 1683 psi). Meanwhile pumped
270 bbls slop down 9-5/8" x 7" annulus & freeze protect.
(Note: installed cable w/ 357 bands). MU tbg hgr & landing jt.
Measure cable, cut and splice to B/W penetrator. Land tbg hgr.
Install BPV & ND BOPE.
05/X4/91: Fin ND BOPE. Install 2-way check. Test tree to 3000 psi - OK.
Pull check. Pump 70 bbls diesel down backside. Install BPV &
pump 10 bbls down tbg. Rig down & clean pits - Final test on
Reda - OK. Released rig @ 0800 on 05/13/91. Move to J-3.
Operations concluded.
Conoco Inc.
Milne Point Well No J-3
Completion History
Milne Point J No. 3 - DRILL & EQUIP. API No.: 50-029-22072
Location: Milne Point Field SCHRADER BLUFF POOL
AFE Number: 10-61-1253 Approved: 08/15/90, Rev. 01/11/91
AFE Amount: $1,741,000 gross Cost to Date: $1,776,187 gross
Operator: Conoco
Chevron
OXY
0.5942340
0.3764866
0.0292794
Objectives:
Schrader Bluff Pool
Spud Date: 12/23/90
Compl Rig Accepted: 05/13/91
Rig: EWS 4
Rig Release Date:
Compl Rig Released:
12/28/90
05/26/91
Planned
Drilling Days: 12
Completion Days: 14
Actual Planned Actual
6 Depth: 5,356' MD 5,356' MD
14
Test Summary:
Type Interval Shows
Current Operations:
05/14/91: Move rig from J-2 to J-3. Work on berms for break up chemical
stock and slop tank/filter van. NU BOPE. Rig on contract to
J-3 @ 0800 hrs on 05/13/91.
05/15/91: Pull hanger. Change rubbers on test plug and run same. Test
BOPE. Had called AOGCC @ 9 am on 5/13/91, AOGCC did not
witness test. Tally pipe & MU bit and casing scraper. TIH
w/ bit - csg scraper, 4 DCs, 2-7/8" tbg. Tag ice @ 520'. Circ
through. TIH w/ bit - tag up @ 5324'. Reverse out diesel &
9.2 brine w/ 8.5 filtered brine (193 bbls). Hookup to Arctic
Pac - Slop tank full. Unable to open valve - pressure locked.
Wait on bleeder tool & open valve. Dispose of slop tank down
7" x 9-5/8".
05/16/91: RU & Rev out 31 addl bbls (225 total of 196 hole vol). Pump 22
bbl dirt magnet pill, 12 bbl brine, 22 bbl dirt magnet pill and
190 bbls brine (Note: reversing). Pump pill to slop tank. Rev
circ and filter well one hole vol. POOH w/ 165 its tbg while
pumping 96 bbls down 7" x 9-5/8" annulus (combined w/ 281 on 14
May = 377 bbls). Fill w/ 45 bbls diesel. Break down Otis seal
assby. RU SWS. Run GR-JB to 5335'. Run GCT. Run GR-CCL w/
sump PKR - correlate to open hole log, pull strip and set sump
PKR @ 5189' not 5187' due to csg collar. Perf w/ 12 SPF/24 gm:
Run #1 5145'-5167' Fluid at surface, all shots fired
Run #2 5132'-5147'
Run #3 5067'-5087'
Run #4 5047'-5067'
Run #5 5045'-5047'
Conoco Inc.
Milne Point
Well No. J-3
Page 2
RD SWS. PU Otis seal assby portion of TCP assby.
05/~7/91: PU remainder of TCP assby. TIH w/ 40 stds tbg. Work on hook.
TIH w/ 17 stds. Set Champ III. Close Fas-Fil. Space out in
AWD, RU flowhead and lines. Set PKR & drop bar - guns fired
@ 11:16, 24 gm charges, 12 JSPF, 5167'-5132' & 5087-5045'.
Flow well 1 hour - weak blow at surface. Shear APRM-2 and
rev out 22 bbls brine and 3 bbls oil. POOH w/ TCP assby. Work
on ~1 hydraulic motor. POOH. LD TCP assby/ PU Mod. seal assby
and 3 junk baskets. TIH w/ wash assby. Filter brine and RU
kelly to circulate.
05/lS/9~: Circ. POOH. Clean 3'junk baskets (top & bottom junk baskets
1/2 full - middle JB full). PU GP Assbly. TIH w/TBG. R/U
Dowell - Schlumberger.
05/~9/9~: Test lines to 5000. Drop ball.' W.O. Ball to seat. Set Pkr &
test backside. Pickle TBG.. Rev out 47 BBLS. Set tool in SQZ
position, establish rate and pump GP slurry. No screen out.
Rev out 81 BBLS and rec 30 BBLS 2% KCL WTR, 15 BBLS 8ppg
slurry. 20 BBLS Gel HzO & 15 BBLS Brine. RP P/S. Pull 1 std
and work stack pipe @ middle of second std - came free. Pull
10 std. POOH. Ported shifting sub washed out between shifting
sleeve and port. PU 3 JTS 1-1/4 & 5 JTS 2-3/8 and TIH w/159
JTS 2-7/8 - No fill tagged. Rev out 2 TBG vols (60 BBL) no
gravel rtns. POOH. LD 1-1/4 & 2-3/8. PU Washpipe.
05/Z0/9~: Space out & check seal assby. RU hardline to manifold. Test
lines and establish rates. Pump 17 BBL 10 ppgp slurry, screen
out w/1 BBL through tool. Rev out 12B 10ppg slurry. Rev out
35 BBLS brine to pits. Wait to test GP. Press test on GP.
Instant bleed off. GP w/14B 10ppg. 1/2 BBL through tool.
Screen out. Rev out 83 BBLS. POOH & L/D RNG Assbly. Run TDT.
Showed good log. Perf as follows: (all 12 JSPF/24 EM 43C JS).
Gun run - 1 Mis Run. Gun Run 2 - PF/4947-60. 13'. Gun Run 3 -
PF/4927 - 47. 20'. Gun Run 4 - PF/4907-8, 4897-4907,4822-28.
05/2~/9~: Perf No. 5 PF/ 4872'-87'. No. 6 PF/ 4852'-72'. Run GR-CCL
1-11/16" dummy run. RD loggers. Begin PU & tally TCP for "N"
sand. PU seal assby. TIH. Set PKR-pump 24 bbl diesel down
tbg. Unset PKR & TIH w/ 6 stds. Space out, set PKR, and check
backside to 500 psi. RU loggers. Run 1-11/16 GR-CCL - TCP in
correct position. RD. Drop bar & fire guns, flow to surface.
Open APRM-2 w/ csg press. Rev out w/ 97 bbls - well dead.
POOH.
05/2Z/9~: POOH and LD TCP BHA. PU 7 jts 1-1/4 CSH/XO/ 1 jt 2-3/8
WFJ/XO/PUP/XO/3 JBs/XO/2-7/8" tbg. Pass through "O" sand GP
screens. Tbg plugged off after reversing 28 bbls. POOH
6 stds. Tbg unplugged - rev out 61 bbls. POOH. PU mod seal
assby/PUP/XO/3 JBs/XO/2-7/8" tbg and TIH. Tag PKR @ 4982' and
insert seal assby to no-go. PU above PER and work pipe between
PKR and bottom of "N" perfs @ 4960'. PU 3 stds (above N perfs)
and circulate & filter 2 hole volumes (350 bbls).
Conoco Inc.
Milne Point
Well No. J-3
Paqe 3
05/23/91: Fin reversing 350 bbls. POOH w/ 79 stds tbg - 3 JBs & seal
assby. Test BOPE. Replace seals on seal assby. PU screens,
PKR, WP and seal assby. TIH to 4982'. Drop ball. Test lines
to 5000 psi and set PKR. Pressure up and disengage R/T. Test
ann to 1000 psi. PU to "R" position and shift X-Weldmont
sleeve. Pickle tbg. Pump GP as follows: 25 bbl gel pad,
10 bbl 2 ppg, 27 bbl 2/8 ramp, 35 bbl 8 ppg slurry. Screen out
w/ 4.2 bbl. Disp @ 5000 psi. Repress to 3000 psi - bled off
slower. 22.8 bbl 8 ppg above tool, 7 bbl 8 ppg in ann, and
5.2 bbl 8 ppg in formation at screen out. Wait 4 hrs for
pressure test.
05/24/91: Test "N" sand gravel pack; @ 1 bpm - 568 psi, @ 2.2 bpm -
1500 psi. Pump 2nd gravel pack as follows: 10 bbls pad,
11 bbls 12 ppg slurry, 5 bbl post pad, 10 bbl KCL. Shift to
upper circ position. Screened out w/ 16.5 bbl flush pumped.
Est 5.5 bbls slurry-below tool. Wait to test pack. Test pack
- OK. R/D Dowell Schlumberger. POOH. R/U Schlumberger. Run
gravel pack log. R/D Schlumberger. L/D DCs, 6 stds tbg. Pull
wear bushing. P/U shroud, ESP & service. R/U cable shieves.
RIH w/ ESP.
05/25/91: RIH w/ ESP on 2-7/8" tbg. M/U tbg hgr. Land hanger. Test
hanger seals to 5000 psi. OK. N/D BOPs. N/U tree. Test to
3000 psi. OK. Freeze protect w/ 60 bbls down 7" x 2-7/8" and
11 bbls down 2-7/8" tbg. Set BPV. Clean pits.
05/26/91: Finish cleaning pits. R/D derrick. Change out guide wires,
re-align derrick board. Drain lines in mud pumps, lines.
Fabricate new mud pump, kill lines to comply with AOGCC rules.
Install new lines.
05/27/91: R/D. Move rig to B-19. Operations concluded, last day on
report. Rig released @ 1000 hrs 05/26/91.
MILNE POINT UNIT
J-3
FINAL DRILLING REPORT
OPERATOR: CONOCO
WELL: MPU J-3
FIELD: KUPARUK
PTD?eJ325 MD
CASING: 13-3/8" @ 105
9 5/8" @ 2680'
7" @ 5434
CURRENT TD: 5449
PROGRESS: 0
DATE:
12-23-90:
12-24-90:
12-25-90:
12-26-90:
12-27-90:
12-28-90:
12-29-90:
Description of Operations:
MIRU. PU rig @ 2100 HRS 12-22-90. NU Diverter system.
Mix mud. MU 12 1/4" bit & Steerable Assy, Spud well @ 0300 hrs 12-23-90, Drill f/
105 to 1266, Short trip. Drill to 1474.
Drill 1474 to 2700. Short trip. C & C. POOH. Run 4 arm caliper on E/L, RU to run csg,
Ran 66 jts 9 5/8" csg, 36#, K-55, Butt. Circ & recip. Cmt w/100 BBL wtr spacer, 358
BBL 12.3 PPG Artic Set IV cmt, and 51 BBL 15.8 PPG G cmt. Disp cmt. Land csg. FS
@ 2680. FC @ 2600. Bump plug. ND Diverter. Install Speed Head. NU Bop's. Test
same. MU 8 1/2" bit & Steerable BHA. RIH. Test csg to 1500 psi. Drill out cmt & float
equip. Drill 2700 to 2710. C & C. Run FIT to 12.8 PPG EMW.
Drill 2710 to 3873. Short trip. Drill to 4948. Short trip. Drill to 5449. C & C.
Short trip. C & C. POOH, RU E/L. Run AMS-NGT-CNL-LDT-DIL. RIH w/bit, C & C.
POOH. LD DP & BHA.
RU & run 131 jts, 7", 26#, L-80, Butt csg. FS @ 5434. FC @ 5354. Circ & recip csg.
Cmt w/58 BBL G cmt @ 15.8 PPG. Disp w/brine & 20 BBL diesel. Land csg. Bump
plug. ND BOP. Install packoff. Test same. NU tree. Clean mud pits. Released rig @
1930 hrs 12-28-90 to J-4. Operations suspended pending arrival of completion rig.
RIG RECEIVED: 12-22-90
SPUD DATE: 12-23-90
RIG: NABORS 27 DAYS: 6 / 12 FOREMAN: Mountjoy DATE: 12-31-90
SUB - S URFA CE
DIRECTIONAL
SURVEY
~-~ UIDANCE
~ ONTINUOUS
I~ OOL
RECEIVED
OOT 2 8 ~991
~¢;~ ~Ojl .& Gas Cor~s. ~omrnissi~m
·
~, ~nchorage
Company CONOCO INC.
Well Name MPU J-3 (2732' FNL, 3331' FELr SEC 28r TWN 13N, RNG 10E)
Field/Location SCHRADER BLUFF, NORTH SLOPEt ALASKA
Job7~~fse~ence No. !ld lC R 0 F ILH E D
_/ O/.~ -/ /GO .... Computed "~
Logged
By'
Date.,
JOHNSON DEE~
* SCHLUMBERGER
GCT DIRECTIONAL SURVEY
CUSTOMER LISTING
FOR
CONOCO INC.
MILNE POINT UNIT d-3
SCHRADER BLUFF
NORTH SLOPE, ALASKA
SURVEY DATE: 15-MAY-1991
ENGINEER: SCHWARTZ
METHODS OF COMPUTATION
TOOL LOCATION:
INTERPOLATION:
VERTICAL SECTION:
TANGENTIAL-
LINEAR
HORIZ. DIST.
Averaged deviation and azimuth
PROJECTED ONTO A TARGi~T AZIMUTH OF
SOUTH
1 2 DEG
13 MI N WEST
COMPUTATION DATE: 29-MAY-91
PAGE I
CONOCO INC.
MILNE POINT UNIT J-3
SCHRADER BLUFF
NORTH SLOPE, ALASKA
DATE OF SURVEY: 15-MAY-1991
KELLY BUSHING ELEVATION: 70.20 FT
ENGINEER: SCHWARTZ
INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH
TRUE SUB-SEA COURSE
MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH
DEPTH DEPTH DEPTH DEG MIN DEG MIN
VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE
SECTION SEVERITY NORTH/5OUTH EAST/WEST DIST. AZIMUTH
FEET DEG/IO0 FEET FEET FEET DEG MIN
0 O0
100 O0
200 O0
3OO O0
400 O0
500 O0
600 O0
700 O0
800 O0
900 O0
0.00 -70.20
100.00
200 O0
300 O0
399 99
499 97
599 85
699 44
798 70
897 59
0 0 N 0 0 E
29.80 0 10 S 11 21 E
129.80 0 15 5 36 0 W
229.80 0 24 S 18 19 W
329.79 0 37 S 14 31 W
429.77 1 51 S 7 19 W
529.65 3 56 S 2 21 E
629.24 6 12 S 7 34 E
728.50 7 47 S 5 16 E
827.39 9 27 S 0 55 E
0 O0
0 27
0 6O
1 19
1 97
3 99
8.74
17.25
28.71
43.03
0.00
0.00
0.17
0 42
081
1 37
2 59
1 80
1 75
1 65
0.00 N
0.29 S
0.61 5
1.14 5
1 .91 $
3.89 S
8.73 S
17.64 5
29,68 5
44.49 S
0 O0 E
0 08 E
0 02W
0 32 W
0 47 W
0 85 W
095W
0 05 W
1 42 E
2 14 E
0 O0 N 0 0 E
0
0
1
1
3
8
17
29
44
30 S 15 19 E
61 S 1 27 W
19 S 15 49 W
97 S 13 48 W
99 S 12 22 W
79 S 6 13 W
64 S 0 9 W
71 5 2 44 E
54 S 2 45 E
1000 O0
1100
1200
1300
1400
1500
1600
1700
1800
1900
995.77 925.57 12 43
O0 1092.61 1022.41 15 45
O0 1188.09 1117.89 18 59
O0 1281.08 1210.88 23 53
O0 1371.62 1301 42 25 52
O0 1461.12 1390 92 27 14
O0 1549.36 1479 16 29 12
O0 1635.70 1565 50 30 36
O0 1722.37 1652 17 29 19
O0 1808.19 1737 99 32 15
5 0 24 E
S 2 29 W
S 4 41 W
S 6 39 W
S 7 17 W
S 7 13 W
S 6 7 W
S 5 25 W
S 6 9 W
5 7 49 W
61.45
85.88
115.23
151.69
193.95
238.39
285.22
335.30
384.87
435.96
4.63
2.60
4.50
3.97
0.77
1 .66
3.86
1 .05
1.11
1 .86
63.40
88.28
117.89
154.38
196.53
240.76
287.46
337.67
387.28
438.20
2.41 E 63.45 S 2 11 E
1.88 E 88.30 S 1 13 E
0.02 W 117.89 S 0 1 W
3.79 W 154.43 S 1 24 W
8.88 W 196.73 S 2 35 W
14.59 W 241.20 S 3 28 W
20.17 W 288.17 S 4 1 W
24.98 W 338.59 S 4 14 W
30.03 W 388.45 5 4 26 W
36.30 W 439.70 S 4 44 W
2000 O0 1891.36 1821 16 35 43
2100
2200
2300
2400
2500
2600
2700
2800
2900
O0 1970.57 1900i
O0 2045.03 1974
O0 2116.63 2046
O0 2187.71 2117
O0 2255.42 2185
O0 2320.68 2250
O0 2385.05 2314
O0 2448.97 2378
O0 2513.52 2443
37 39 47
83 43 3O
43 44 28
51 45 32
22 48 54
48 49 37
85 5O 13
77 50 11
32 49 19
S 8 43 w
5 8 54 w
S 8 50 W
$ 9 9 W
S 9 35 W
S 10 17 W
5 10 33 W
S 11 42 W
491 32
552 21
618 81
688 49
758 74
832 25
907 98
984 48
S 12 45 W 1061.39
S 13 51 W 1137.75
4.19
5.82
2.78
081
3 56
0 98
0 84
1 9O
0 84
1 53
493.12 S 44.25 W 495.11 S 5 8 W
553.37 5 53.72 W 555.98 S 5 33 W
619.31 S 63.94 W 622.60 S 5 54 W
688.26 S 74.79 W 692 31 S 6 12 W
757.66 S 86.25 W 762 55 S 6 30 W
830.12 S 98.91 W 835 99 S 6 48 W
904.63 S 112.64 W 911 62 S 7 6 W
979.76 5 127.17 W 987 98 S 7 24 W
1054.91 S 143.56 W 1064 63 S 7 45 W
1129.25 S 161.03 W 1140 67 S 8 7 W
3000.00 2579.41 2509.21 48 16
3100.00 2645.96 2575,76 48 33
3200.00 2712.10 2641.90 48 18
3300,00 2778.98 2708.78 47 56
3400.00 2846.08 2775.88 47 52
3500.00 2912.22 2842.02 49 21
3600.00 2976.91 2906.71 49 59
3700.00 3040.97 2970.77 50 13
3800.00 3104.86 3034.66 50 29
3900.00 3168.46 3098.26 50 14
S 15 15 W 1212.90
5 13 59 w 1287.47
S 13 59 W 1362.44
S 14 51 W 1436 73
S 15 7 W 1510 78
S 12 38 W 1585 73
S 12 43 W 1661 99
S 14 18 W 1738 76
S 15 21 W 1815 59
S 15 25 W 1892 65
0 85
2 26
2 05
021
0 90
1 81
1 29
1 53
071
1 21
1202.06 5 179.93 W 1215 45 S 8 31 W
1274.20 $ 199.09 W 1289
1347,09 $ 216.73 W 1364
1419.05 S 235.41 W 1438
1490.67 S 254.61 W 1512
1563.42 S 272.76 W 1587
1637.89 S 289.19 W 1663
1712.57 S 307.05 W 1739
1786.88 S 326.94 W 1816
1861.29 S 347.41 W 1893
66 S 8 53 W
41 S 9 8 W
44 S 9 25 W
25 S 9 42 W
O4 S 9 54 W
22 S 10 1 w
88 S 10 10 W
54 S 10 22 W
43 S 10 34 W
COMPUTATION DATE: 29-MAY-91
PAGE 2
CONOCO INC.
MILNE POINT UNIT J-3
SCHRADER BLUFF
NORTH SLOPE, ALASKA
DATE OF SURVEY: 15-MAY-1991
KELLY BUSHING ELEVATION: 70.20 FT
ENGINEER: SCHWARTZ
INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH
TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE
MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH
DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN
4000 O0 3232.72 3162.52 49 52 S 14 50 W 1969,15
4100
4200
4300
4400
4500
4600
4700
4800
4900
O0 3297.38 3227.18 49 46 S 12 2 W 2045.42
O0 3362.60 3292.40 48 5 S 11 58 W 2121.22
O0 3431 47 3361.27 45 35 S 12 7 W 2193.70
O0 3501 54 3431.34 45 26 S 12 38 W 2265.05
O0 3571 70 3501.50 45 25 S 13 1 W 2336.30
O0 3642 13 3571.93 45 17 S 14 4 W 2407.28
O0 3712 22 3642.02 45 44 S 15 55 W 2478.52
O0 3781 75 3711.55 45 57 S 17 17 W 2550.17
O0 3851 15 3780.95 46 10 S 17 56 W 2621.85
2.54 1935.19 S 367 63 W 1969 80 S 10 45 W
0.86 2009.47 S 384
4.39 2083.62 S 400
0.34 2154.52 S 415
0.39 2224.21 S 431
0.53 2293.69 S 446
1.55 2362.75 S 463
1.35 2431.62 S 481
0.69 2500.48 S 502
0,50 2569.11 S 524
95 W 2046
69 W 2121
78 W 2194
05 W 2265
85 W 2336
32 W 2407
85 W 2478
42 W 2550
17 W 2622
01 S 10 51W
79 S 10 53 W
27 S 10 55 W
60 S 10 58 W
81 S 11 1 W
74 S 11 6 W
90 S 11 13 W
46 S 11 22 W
04 S 11 32 W
5000.00 3920.36 3850.16 46 18 S 18 13 W 2693.65
5100.00 3989.34 3919.14 46 26 S 18 35 W 2765.63
5200.00 4057.98 3987.78 46 52 S 18 33 W 2837.90
5300,00 4126.30 4056.10 46 56 S 18 30 W 2910.48
5400.00 4194.46 4124.26 47 2 S 18 28 W 2983,23
5448.00 4227.18 4156.98 47 2 S 18 28 W 3018.15
0.41 2637.72 S 546 58 W 2693 75 S 11 42 W
0.14 2706.42 S 569 44 W 2765 68 S 11 53 W
0.36 2775.35 S 592 60 W 2837 92 S 12 3 W
3.63 2844.59 S 615 80 W 2910 48 S 12 13 W
0.00 2914.01 S 638 96 W 2983 24 S 12 22 W
0.00 2947.33 S 650 07 W 3018 17 S 12 26 W
CONOCO INC.
MILNE POINT UNIT J-3
SCHRADER BLUFF
NORTH SLOPE, ALASKA
COMPUTATION DATE: 29-MAY-91 PAGE 3
DATE OF SURVEY: 15-MA¥-1991
KELLY BUSHING ELEVATION: 70,20 FT
ENGINEER: SCHWARTZ
INTERPOLATED VALUES FOR EVEN 1000 FEET OF M[[ASURED DEPTH
TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE
MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH
DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN
0.00 0.00 -70.20 0 0 N 0 0 E 0 O0
1000.00 995.77 925.57 12 43 S 0 24 E 61 45
2000.00 1891.36 1821.16 35 43 S 8 43 W 491 32
3000.00 2579.41 2509.21 48 16 S 15 15 W 1212 90
4000.00 3232.72 3162.52 49 52 S 14 50 W 1969 15
5000.00 3920.36 3850.16 46 18 S 18 13 W 2693 65
5446.00 4227.18 4156.98 47 2 S 18 28 W 3018 15
0 O0 0.00 N 0.00 E 0 O0 N 0 0 E
4 63 63.40 S 2.41 E 63 45 S 2 11 E
4 19 493.12 S 44.25 W 495 11 S 5 8 W
0 85 1202.06 S 179.93 W 1215 45 S 8 31 W
2 54 1935.19 S 367.63 W 1969 80 S 10 45 W
0 41 2637.72 S 546.58 W 2693 75 S 11 42 W
0.00 2947.33 S 650.07 W 3018 17 S 12 26 W
COMPUTATION DATE: 29-MAY-91
PAGE 4
CONOCO INC.
MILNE POINT UNIT J-3
SCHRADER BLUFF
NORTH SLOPE, ALASKA
DATE OF SURVEY: 15-MAY-1991
KELLY BUSHING ELEVATION: 70.20 FT
ENGINEER: SCHWARTZ
INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH
TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES MORIZ. DEPARTURE
MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH
DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN
0 O0
70
170
270
370
470
570
670
771
872
0.00 -70.20 0 0 N 0 0 E 0,00
20 70.20 0,00 0 10 S 16 41 E 0.19
20 170.20 100.00 0 12 S 28 54 W 0.49
20 270.20 200.00 0 24 S 27 23 W 0,98
20 370.20 300.00 0 30 S 10 52 W 1.68
22 470.20 400.00 1 23 S 9 52 W 3.14
29 570.20 500.00 3 10 S 0 44 E 6.94
60 670.20 600.00 5 34 S 6 36 E 34.39
25 770.20 700.00 7 21 S 6 39 E 25.11
26 870.20 800.00 8 55 S 1 25 E 38.71
0 O0
0 18
0 13
001
0 24
I 88
2 45
2 39
1 21
2 15
0.00 N
0.21 S
0.51 S
0.95 S
1 63 S
3 05 S
6 89 S
14 64 S
25 92 S
40 06 S
0.00 E 0.00 N 0 0 E
0.06 E 0.21 S 15 57 E
0.05 E 0.52 S 5 33 E
0.24 W 0.98 S 14 13 W
0.41 W 1.68 S 14 0 W
0.73 W 3.14 S 13 28 W
1.00 w 6.96 S 8 15 W
0.43 w 14,64 S 1 40 W
1.03 E 25.94 S 2 16 E
2.05 E 40. 11 S 2 56 E
973.84 970.20 900.00 11 40 S 0 54 E 56.07
1076.75 1070.20 1000.00 15 6 S 1 48 W 79.81
1181.12 1170.20 1100.00 18 12 S 4 15 W 109.27
1288.08 1270.20 1200.00 23 27 S 6 37 W 146.85
1398.43 1370.20 1300.00 25 51 S 7 16 W 193.28
1510.22 1470.20 1400.00 27 24 S 7 9 W 243.05
1624.02 1570.20 1500.00 29 57 S 5 38 W 297.08
1739.96 1670.20 1600.00 30 1 5 5 48 W 355.34
1855.36 1770.20 1700.00 31 1 5 7 5 W 412.61
1974.20 1870.20 1800.00 34 34 S 8 27 W 476.59
4 O5
2 74
3 97
4 49
0 78
1 49
312
2 O5
3 99
4 69
57.88 S 2.35 E 57.93 S 2 19 E
82.11 5 2.11 E 82.14 S 1 28 E
111.90 S 0.44 E 111.90 S 0 14 E
149.55 S 3.22 W 149.59 S 1 14 W
195.85 5 8.80 W 196.05 5 2 34 W
245.40 S 15.18 W 245.87 S 3 32 W
299.34 S 21.36 W 300.10 S 4 5 W
357.74 5 26.94 W 358.76 S 4 18 W
414.97 S 33.26 W 416.30 S 4 35 W
478.53 5 42.06 W 480.37 S 5 1 W
2099.52 1970.20 1900.00 39 45 S 8 54 W 551,90
2234.92 2070.20 2000.00 44 19 S 8 53 W 642.96
2375.12 2170:20 2100.00 44 49 S 9 28 W 741.09
2522 53 2270.20 2200.00 49 4 S 10 23 W 849 25
2676 83 2370.20 2300.00 50 6 S 11 16 W 966 70
2833 08 2470.20 2400.00 49 57 S 13 2 W 1086 75
2986 14 2570.20 2500.00 48 23 S 15 5 W 1202 56
3136 68 2670.20 2600.00 48 43 S 13 24 W 1314 98
3286 90 2770.20 2700.00 47 56 S t4 49 W 1427 01
3436 10 2870.20 2800.00 48 19 S 14 36 W 1537 62
581
1
2
0
1
1
1
0
0
2
553.07 S 53 68 W 555.67 S 5 33 W
88 643.22 S 67 66 W 646.77 S 6 0 W
15 740 23 S 83 32 W 744 90 S 6 25 W
60 846 85 S 101 97 W 852 97 S 6 52 W
59 962 33 S 123 67 W 970 24 S 7 19 W
07 1079 63 S 149 21 W 1089 89 S 7 52 W
41 1192 05 S 177 23 W 1205 15 S 8 27 W
95 1300 94 S 205.60 W 1317 09 S 8 59 W
24 1409.65 S 232.92 W 1428 76 S 9 23 W
60 1516.63 S 261,50 W 1539 01 S 9 47 W
3589.55 2970 20 2900 O0 49 55 S 12 34 W 1653.98
3745.68 3070
3902.72 3170
4057.97 3270
4211.27 3370
4355.31 3470
4497.86 3570
4639.97 3670
4783.38 3770
4927,50 3870
20 3000
20 3100
20 3200
20 3300
20 3400
20 3500
20 3600
20 3700
20 3800
O0 50 14 S 15 2 W 1773.83
O0 50 13 S 15 25 W 1894.74
O0 49 39 S 12 46 W 2013.36
O0 47 35 S 11 58 W 2129.54
O0 45 31 S 12 23 W 2233.19
O0 45 26 S 13 0 W 2334.78
O0 45 28 S 14 55 W 2435.70
O0 45 59 S 17 8 W 2538.26
O0 46 10 S 18 4 W 2641.58
1 25 1630.08 S 287.41 W 1655.23 S 10 0 W
03 1746.53 S 315.96 W 1774.87 S 10 15 W
13 1863.30 S 347.97 W 1895.51 S 10 35 W
38 1978.15 S 378.08 W 2013 96 S 10 49 W
36 2091.76 S 402 42 W 2130 11 S 10 53 W
52 2193.11 S 424 15 W 2233 74 S 10 57 W
49 2292.21 S 446 50 W 2335 29 S 11 1 W
64 2390.29 S 470 43 W 2436 14 S 11 8 W
85 2489.06 S 498 89 W 2538 56 S 11 20 W
24 2587.97 S 530 29 W 2641.75 S 11 35 W
COMPUTATION DATE: 29-MAY-91
PAGE 5
CONOCO INC.
NILNE POINT UNIT J-3
SCHRADER BLUFF
NORTH SLOPE, ALASKA
DATE OF SURVEY: 15-MAY-1991
KELLY BUSHING ELEVATION: 70.20 FT
ENGINEER: SCHWARTZ
INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH
TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE
MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH
DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN
5072.23 3970.20 3900.00 46 25 S 18 31 W 2745.64
5217.89 4070.20 4000.00 46 55 S 18 31 W 2850.89
5364.40 4170.20 4100.00 47 2 S 18 28 W 2957.34
5448.00 4227.18 4156.98 47 2 S 18 28 W 3018.15
0.26 2687.35 S 563.05 W 2745.70 S 11 50 W
0.34 2787.74 S 596.75 W 2850,90 S 12 5 W
0.00 2889.30 S 630.71 W 2957.34 S 12 19 W
0.00 2947.33 S 650.07 W 3018.17 S 12 26 W
CONOCO INC.
NILNE POINT UNIT J-3
SCHRADER BLUFF
NORTH SLOPE, ALASKA
MARKER
GCT LAST READING
TD
COMPUTATION DATE: 29-MAY-91 PAGE
DATE OF SURVEY: 15-MAY-1991
KELLY BUSHING ELEVATION: 70.20 FT
ENGINEER: SCHWARTZ
INTERPOLATED VALUES FOR CHOSEN HORIZONS
SURFACE LOCATION = 2732' FNL & 3331' FEL, 5EC28 T13N RIOE
MEASURED DEPTH TVD RECTANGULAR COORDINATE5
BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST
5302.79 4128.21 4058.01 2846.53 5 616.44 W
5448.00 4227.18 4156.98 2947.33 S 650.07 W
CONOCO INC.
MILNE POINT UNIT J-3
SCHRADER BLUFF
NORTH SLOPE, ALASKA
MARKER
TD
COMPUTATION DATE: 29-MAY-91 PAGE 7
DATE OF SURVEY: 15-MAY-1991
KELLY BUSHING ELEVATION: 70.20 FT
ENGINEER: SCHWARTZ
~*~**~**~** STRATIGRAPHIC SUMMARY ~****~'*****
SURFACE LOCATION = 2732' FNL & 3331' FEL, SEC28 T13N R10E
MEASURED DEPTH TVD RECTANGULAR COORDINATES
BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST
5448.00 4227.18 4156.98 2947.33 S 650.07 W
FINAL WELL LOCATION AT TD:
TRUE SUB-SEA
MEASURED VERTICAL VERTICAL
DEPTH DEPTH DEPTH
HORIZONTAL DEPARTURE
DISTANCE AZIMUTH
FEET DEG MIN
5448.00 4227.18 4156.98 3018.17 S 12 26 W
SCHLUMBEROER
O I RECT I ONAL SURVEY
COMPANY cONuCu iNC,
WELL MILNE POINT UNIT d-3
FIELD
SCHRADER BLUFF
COUNTRY USA
RUN ONE
DATE LOOOEO iS - MAY - 9i
REFERENCE 94S8S
WELL: MPU J-3
(2732' FNL, 3331' FEL, SEC 28, T13N, R10E)
HORIZONTAL PROJECTION
~TH ] 000
SOO
-1000
-ISO0
-2000
-2500
SOUTH -3000
-2OOO
WEST
REF 74S8S SCALE = I/S00 IN/FT
::.., ....... ....... ......,...?,..,...,..., ..... .... ....... .......
..* .**.**j*---4 *.-q* - --4,-*-*-*~*.**~* ....... 4.-4...4-*--i*-*-~**-4 .-4--4--q* ....... ~--.4 .*-* --4- ...... *..* .:**-4-4~-
=_.. ::. ________q~:~::,::i::;:;:-~::'--b+--HL~--i-'H ....... i-+-!"+"H-'i--H ......____.____H"H"'!"H"H'"'"t"'t'"f"'":":'t"'t"'t'"t"'t ....... t'"t---t-.~"'t'-'t'-'t'-'t'"t ....... ?'"t"'t"-?!'"i'"t'":"'~ ....... FFt-LI'
........................... "'!'T'!"T' i'TT'T"~ ..... ?TTTT'T'T'T"! ....... i"T'T'"FC'FF;'"! ....... f"?."'7 !'"i"'?C'i
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192.
PROJECTION ON VERTICAL PLANE 19~. - 12. $CALEO IN VERTICAL OEPTHS HORIZ SCALE = l/1000 IN/FT
AOGCC GEOLOGICAL MATERIALS INVENTORY LIST
- WELL NAME
COMPLETION DATE ~ !~. c~t CO. CONTACT
........ CheCkoff ,riist'da{a ~s it is ,reCeiV'~d.*list ~e~'~i~,ed dpte fro' 4~7. if not re.quire, d list as ~1~"
,401"I ~"lo.~q,'~ "dri'iiing hi~t°. ~ """0~"91¢1 weii'tcstS' I~o;~ de;'criptlOd~
cored intc~als core analysis ~ ........ d~ ditch inte~als digital data
-'~'~ ,' - , . .,,, ................... ................... ,,,, ,, , ,, ,~ ~
_.,]llJ J _ _ I . II .llJl IJlll II I III II , II I I I I I t
. I[ III II i i iiiii I III I I Ilin II I II I II II IIIII
. .,~,,~ ..... ~ ............... i n I II I I I III II
....... LOG TYP~ I~Ui~' INTERVALS SCALE
NO. ,(to the nearest f°oq pnchl100'l_
i i i i I iiiiu i iii ii II I I II
.~
~ . _ II I I I i ii i i L
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SCHLUMBERGER WELL SERVICES
A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION
HOUSTON. TEXAS 77251-2175
~ REP~Y TO
MAY 2 9 1991 ~HLU~;~ W~LL B;~
Pouch 340069
Prudhoe Bay, ~ 99734-0069
A~Cn: Bernie/Shelley
CONOCO, Inc.
3201 "C" Street, Suite 200
Anchoraie, AK 99503
Attention: Van Llneberger
Gentlemen:
Compony CONOCO, Inc.
Well Milne Point Unit J-3
Field Mllne point/SchradEr B],,ff ___County North Slope State Alaska
on:
Additionol prints ore being sent to:
I .BL nrints
CONOCO, Inc.
600 North Dairy Ashford
Houston, TX 77079
ArCh: George Lamb - OF 2018 ?ER
I BL prints, I I~F Sepia
CONOCO, Inc.
1000 South Pine
Ponca City, OK 74603
Attn: Glenn Welch 7360RDW
1BL orints, I RF Sepia
OXY U'S.A., Inc.
6 Desta Drive
Midland, TX 79710
Attn: John Carrol
*(915/685-5898)
I BL prints, I ILF Sepia
Chevron U.S.A.
11111 South Wtlcrest
Hosuton, TX 77099
Art. n: Priscilla MacLeroy
*(713/561-3652)
A.],a~S~'~i'& Gas Co~servatio~'~,.
/'~Commlsslon . ",,, ....
/ o%u ln. \.
( /
Johm Boyle ~/ ._
The film is returned to GON~O.
Ponca City.
We appreciote the privilege of serving you.
prints
prints
Very truly yours,
SCHLUMBERGER WELL SERVICES
Raymond N. Dickes
DISTRICT MANAGER
SW$--t32T-F
SCHLUMBERGER WELL SERVICES
A DIVISION OF' SCHLUMBrRG£R TECHNOLOGY CORPO~ATK)N
I'K)USTON. TEXAS 77251-2175
K.EAM REPLY TO
M~ ~ 2 ~, /t~.,.. ICHLUMBERGER WELL 8ERV1CE8
Pouch 340069
co o o.
3201 "C" Street~ Suite 200
Anchorage~ AK... 99503
Attention: Van Ltneberl~er -?v/'~,/~; ~,
Gentlemen: GeT, Run 1, 5/15/91
£nclo~ed ore .2 BLorin~s o{ the ...Comp Rec,...Ru.n 1~. 5/.15/91 on:
Compony CONO¢O~ Inc:
Well - Milne Point Uni~. J-~ ..
Field Milne Point /Schrader Bluff Counl¥ North Slope Store. Alaska
Additionol prints ore being sent to:
I BL nrints
c0NOC6, Znc.
600 North Dairy Ashford
Houston, TX 77079
Attn: George Lamb - OF 2018 PER
I BL prints, I RF Sepia
CONOCO, Inc.
_.1000 Sou~h Pine
Ponca City. OK 74603,
Attn: Glenn Welch 7360RDW
I BL nrints, I RF Sepia
OXY U~S.A., Inc.
6 Desta Drive
Hidland, TX 79710
Attn: John Carrol
*(915/685-5898)
I BL prints, I 1~ Sepia
Chevron U.S.A.
11111 South Wllcrest
Hosuton, TX 77099
Atgn: Priscilla MacLeroy
*(7L3/561-3652)
BL nrints, I RF Sepia.
A~k~ .0tl & Gas Conser~_tion
Commission\ -
..~001 .Porcupine Drive /'
~mchora~e. Ail 99501
The fi~m ~s returned
Ponca Ci~.
We oppreciote the privilege of serving you.
. prints
prints
prints
Received by;
Very truly yours,
SCHLUMBERGER WELL SERVICES
Raymond N. Dickes
DISTRICT MANAGER
SWS-- ! 32T-F
SCHLUMBERGER WELL SERVICES
A DIVISION OF SCHLUMBERGER T~CHNOLOOY CORPORATION
~ST~. ~S 77251-2175
~OUCh 3400~9
~ud~oe BaT, ~ 99734-00~9
Attn: Bernie/Shelley
CONOCO, Inc.
3201 "C" Street, Suite 200
Anchorage, AK 99503
Attention: Van Llneberzer
Gentlemen: Gravel Pack Log, Run 1, 5/19/91
Enclosed ore 2 BLorints of the , Perf Re,~, Run 2, 5/lg/gl
Company GONOCO~ Inc: '
Well Milne POSDt Unit ,1-3
Field Milne Point/Schrader Bluff County Nor.~h Slop~ Stote,
Additionol prints ore being sent to:
Alaska ..
,l BL nrints
CONOC6, Inc.
600 North Dairy Ashford
Houston, TX 77079
Attn: George Lamb - OF 2018 PER
I BL prints, I RF Sepia
CONOCO, Inc.
1000 South Pine
Ponca City, OK. 74603
Attn: Glenn Welch 736ORDW
on:
I BL nrints, I P,F Sepia
OXY U:S.A., Inc.
6 Desta Drive
Midland, TX 79710
Attn: John Carrol
*(915/685-5898)
I BL prints, I ~ Sepia
Chevron U.S.A.
11111 South Wtlcrest
Hosuton, TX 77099
Attn: Priscilla MacLeroy
*(713/561-3652)
I BL prints, 1 RF Sepia
Alaska Oil & Gag cOnserVation _
/Commission / ·
3bol Porcupine Drive /
A~_chorage, AK 99501 /
The film is returned to CONOCO,
~e~OqOWPonca City.
O1SelmmoO.suooseS llOmtel
t66t 8Z X¥ t- --
We
oppreciote the privilege of serving you.
CI]AI]3]
. prints
prints
prints
Received by;
4 . _,.
'Date:
Very truly yours,
SCHLUMBERGER WELL SERVICES
Raymond N. Dlckes
DISTRICT MANAGER
SWS--- ! 327.F
SCHLUMBERGER WELL SERVICES
A DIVISION OF ~K~HLUHBER~ER TECHNOLOGY CORPO~ATIO~
HOUSTON. TEXAS 77251-21 '/'5
MAY 2 2 tggl K:HLUUBE~ER W~LL SERVICE8
Pouch 3~0069
?rudhoe Bay, .AK. 9973~-0069
Attn: Berate/Shelley
CONOCO, [nc.
3201 "C" Street, Suite 200
Anchorage, AK 99503
Attention: Van Ltneberger
.~Gentlemen:
,,.0~ ~ Enclosed are 2 BLorintsofthe, T. CP Gun Correlation Rec, Run 2, 5/20./91
00 CONOCO, Inc'.
Compony
on:
Well Milne Point Unit
Field Milne Potn,t~Schrader Bluff County North Slope State., Alaska
Additionol
prints
ore
being
sent
°~O/s9tll~O0 effe. lOun,..t. BL nrints, I RF Sepia
I BL nrints
CONOCO, Znc. 'gUo0; 0NOC6, Znc. .
-- "l~~£h, P/ne
~~--~h~-0-or~- ~l ~ ~ ,.~onca C~ty. OK 7~603
HO'~st0n, TX 77079 ' ' :'
--~ ....
Attn: George Lamb - OF 2018 PE~ ~. ~tn: Glenn ~elch 7360RD~
I ~ prints, I ~ Sepfa ..... ~rints
OX~ U.S.~., 1~c.
6 DesCa ~glve
~dla~d, T.X 79~0
ACC~: 3oh~ Caggol
*(~/~8~-~8~8)
I BL prints, 1 KF Sepia
Chevron U.S.A.
11111 South Wllcrest
Hosuton, TX 77099
AtCn: Priscilla MacLeroy
*(713/561-3652~ ......
I BL Prints, 1RF Sepia~
A~.aSka 011 & Gas Conser~vatton
/Commission.
~O01Porcuolne Drive
[ choras', ..99 m/
prints
prints
The film is returned to CONOCO,
Ponca City.
Received by: _
~l. .- Al_ -
We oppreciote the privilege of serving you.
Very truly yours,
SCHLUMBERGER WELL SERVICES
$W$-- 1327-F
Raymond N. Dtckes
DISTRICT MANAGER
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
1. Type of Request: Abandon Suspend Operation shutdown__ Re-enter suspended well
Alter casing __ Repair well __ Plugging w Time extention __ Stimulate X
Change approved program Pull tubing Variance Perforate X Other .. X..
Name of Operator
Conoco Inc.
Address
3201 C Street, Suite 200 Anchorage, AK 99503
Location of well at surface
2732' FNL, 3331' FEL, Sec. 28, T13N, R10E, U.M.
At top of productive interval
4900' FNL, 3800' FEL, Sec. 28, T13N, R10E, U.M.
At effective depth
5. Type of Well:
Development
Exploratory
Stratigraphic
NSB AK
NSB AK
At total depth
313' FNL, 3950' FEL, Sec. 33, T13N, R10E, U.M. NSB AK
6. Datum elevation (DF or KB)
KB 35 AG L
7. unit or Property name
Milne Point Unit
8. Well number
J-3
9. Permit number
90 -97
10. APl number
50-029-22072
11. Field/Pool /~pt~,~t~ I[v~' '
SCHRADER BLUFF
feet
12. Present well condition summary
Total depth: measured 5449 feet
true vertical 4250 feet
Effective depth: measured feet
true vertical feet
Casing Length Size
Structural
Conductor 115' 13-3/8"
Surface 2715' 9-5/8"
Intermediate
Production 5469' 7"
Liner
Perforation Depth: measured
true vertical
Tubing (size, grade, and measured depth)
Packers and SSSV (type and measured depth)
Plugs (measured)
Junk (measured)
Cemented Measured depth True vertical depth
Surface 80' 80'
Surface 2680' 2385'
T.O.C. @ 3500' 5434' 4239'
13. Attachments
Description summary of proposal X
Detailed operations program
BOP sketch
14. Estimated date for commencing operation
April, 1991
16. ff proposal was verbally approved
Name of approver
Date approved
15. Status of well classification as:
Oil X Gas
Suspended
Service
17. I hereby certify~that ~regoing is true and correct to the best of my knowledge.
Sicjne~-,"~~~~n Lineberge~ Title Sr. Production Engineer
OR COMMISSION USE ONLY
Conditions of approval: Notify Commission so representative may witness
Plug integrity ~ BOP Test Location clearance
Mechanical Integrity Test ~ Subsequent form required 10-
Approved by order of the Commission
ORIGINAL SIGNED BY
LONNIE C. ,gM1TH
Date ~'~/z-~/c~ (
Form 10-403 Rev 06/15/88
SUBMIT IN TRIPLICATE
MILNE POINT UNIT J-3 WELL
PROPOSED COMPLETION PROCEDURE - SUMMARY
4/4/91 - CVL
NOTE:
Hold frequent on site safety/environmental meetings
prior to all potentially hazardous tasks.
1. MIRU on J-3 well. Test BOP's.
2. GIH w/ bit and scraper to PBTD. Reverse circulate well clean.
3. RU electric line. Run Gyro survey (if necessary). Set gravel
pack sump packer below the proposed "0" sand perf's.
·
Correlate with open hole logs and perforate "O" sands at 12-24
SPF over 5045'-87' and 5132'-67' utilizing electric line or
tubing conveyed perforating (TCP). If TCP is used, apply 300
psi underbalance and allow well to flow for approximately 20
bbls. Kill well and POOH. RD electric line.
5. PU gravel pack assembly and GIH. RU gravel pack
pumps/blenders and test surface lines. Set gravel pack
packer.
6. Pickle workstring. Establish injection profile. Pump gravel
pack. Stress test gravel pack and POOH.
·
Perforate "N" sands at 12-24 SPF over 4822'-28', 4852'-87',
4897'-908', and 4927'-60' utilizing electric line or tubing
conveyed perforating (TCP). If TCP is used, apply 300 psi
underbalance and allow well to flow for approximately 20 bbls.
Kill well and POOH.
·
PU gravel pack assembly and GIH.
pumps/blenders and test surface lines.
packer.
RU gravel pack
Set gravel pack
9. Pickle workstring. Establish injection profile. Pump gravel
pack. Stress test gravel pack and POOH.
10. PU and run electric submersible pump (ESP) on tubing. Freeze
protect. ND BOP's and NU tree.
11.
Leave well shut in until surface equipment installation is
complete.
Sr. Prod. Engineer
STATE OF ALASKA [ '~ ~' ~''-'
ALASKA oIL AND GAS CONSERVATION COMMISSION'
APPLICATIOH FOP, SD#DRY APPROVALS
1. Type of Request: Abandon Suspend m
Alter casing m Repair well
Change approved program
Operation shutdown X Re-enter suspended well
Plugging m Time extention m Stimulate __
Pull tubing __ Variance __ Perforate m Other
Name of Operator
Conoco Inc.
Address
3201 C Street, Suite 200 Anchorage, AK 99503
Location of well at surface
2732' FNL, 3331' FEL, Sec. 28, T13N, R10E, U.M.
At top of productive interval
4900' FNL, 3800' FEL, Sec. 28, T13N, R10E, U.M.
At effective depth
5. Type of Well:
Development
Exploratory
Stratigraphic
Service
NSB AK
NSB AK
At total depth
313' FNL, 3950' FEL, Sec. 33, T13N, R10E, U.M. NSB AK
6. Datum elevation (DF or KB)
KB 35 AGL
7. Unit or Property name
Milne Point Unit
8. Well number
J-3
9. Permit number
90 -97
10. APl number
50-029-22072
11. Field/Pool
SCHRADER BLUFF
feet
12. Present well condition summary
Total depth: measured 5449 feet
true vertical 4250 feet
Effective depth: measured feet
true vertical feet
Casing
Structural
Conductor
Surface
Intermediate
Production
Liner
Perforation Depth:
measured
Length Size
115'
2715'
5469'
true vertical
Tubing (size, grade, and measured depth)
Packers and SSSV (type and measured depth)
13-3/8"
9-5/8"
11
Plugs (measured)
Junk (measured)
Cemented Measured depth True vertical depth
Surface 80' 80'
Surface 2680' 2385'
T.O.C.@3500' 5434'
4239'
RECEIVED
FEB 1 4 199t
Alaska Oil & Gas Cons. C0mmiSs'i0a
Anchorage
13. Attachments Description summary of proposal __ Detailed operations program
Shutdown Operations with Rig 27E Pending Completion with EWS 4
BOP sketch
14. Estimated date for commencing operation
October 1991
16. If proposal was verbally approved
Name of approver
Date approved
15. Status of well classification as:
Oil X Gas Suspended ~
Service
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Signed J/~S ~ R.S. Rossberg Title Sr. Drilling Engineer
FOR COMMISSION USE ONLY
Conditions of approval: Not Commission so representative may witness
Plug integrity BOP Test Location clearance
Mechanical Integrity Test __
Approved by order of the Commission
Su"~bsequent form required lO-m
i ONNIF C SMITH ~mmissioner Date
Form 10-403 Rev 06/15/88
SUBMIT IN TRIPLICATE
SCHLUMBERGER WELL SERVICES
A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION
HOUSTON, TEXAS 77251-2175
CONOCO, Inc.
3201 "C'" Street, Suite 200
Anchorage, AK 99503
Attention: Van Lineberger
~EAI~ REPLY TO
SCHLUMBERGER WELL SERVICES?ouch 340069
?rudhoe Bay, AK 99734-0069
Attn: Bernie/Shelley
Gentlemen: DIT-E/NGT/Raw Data/Porosity/Cyberlook,
Enclosed ore2 RL prints of the .Run 2, !2/27/90
Compony CONOCO, Inc.
Well Milne Point Unit J-3
on:
Field Milne Poi nt/Schrader Bluff
Additionol prints ore being sent to:
1 BL prints
CONOCO, Inc.
600 North Dairy Ashford
Houston, TX 77079
A~tn: George Lamb -. OF 2018 PER
County North SIope
~tote.. Alaska
_l_BL_prints, 1RF Sepia
_CONOCO. ThC
1000 South Pine
Ponca City, OK 74603
Attn: Glenn Welch 7360RDW
1BL prints, 1RF Sepia
OXY U.S.A., Inc.
..6 D~ta P_~iv_e ....................
Midland, T.X .79..710
..Att~: John Carrol .
*(915/685-5600)
_l_B_L_prints, 1RF Sepia
Chevron U.S.A.
~11111 South Wilcre~t_
H~tnn; Tpwa~ 77~qq
Attn: Priscilla MacLeroy
J'713/561-3652
~RF Sepia
//Alaska Oil &Gas. C.o~servatib~
/-COmmissi°n "~
/ _3oo1' ?orcup e riVe
[ Anchorage, ,6i<. 99501
X,,. Attn: Boyle
The film is returned to Conoco,
Log Library.
We appreciote the privilege of serving you.
prints
prints
prints
D IZr- i: !\/i:D
I\ ~ M,, L I 1/ L
jAN 8 i99i
Alaska 0il & Gas Cons. Commission
Anchorage
_Received by:
Da/te:
Very truly yours,
SCHLUMBERGER WELL SERVICES
David M. Saalwaechter
DI$TR~CT MANAGER
SwS-- ! 327.F
SCHLUMBERGER WELL SERVICES
A DIVISION OF .~CHLUMBEIRGER TECHNOLOGY CORPORATION
HOUSTON, TEXAS 7725 t-Z ! 7~
CONOCO, Inc.
3201 "C" Street, Suite 200
Anchorage, AK 99503
Attention: Van J~ineberg, er
~ REPLY TO
SCHLUMBERGER WELL ~ICES?ouch 340069
?rudhoe Bay, AK 99734-0069
Attn: Bernie/Shelley
Gentlemen:
Enclosed ore_2_BL_prints of the
Company CONOCO, Inc.
Well Milne Point Unit 3-3
BGT, Run 1, 12/24/90
on:
Field ... Milne Point /Schrader Bluff
Additional prints are being sent to:
1 BL prints
CONOCO. Inc..
600 North Dairy Ashford
Houston, TX 77079
.._Attn: George Lsmb - OF 2018 PER...
County. Nnrth Slope .
State . Alaska__
~rints, 1 RF Sepia
CONOCO: Tn¢__
1000 South Pine
Ponca City, OK 74603
Attn; Glenn Welch 7360RDW
1BL prints, 1RF Sepia
OXY U.S,A., Inc.
_fL_D~ Drive
..Midland, TX 79~i10
Attn: John Carro]
*(915/685-5600)
_L~rints, 1RF Sepia
Chevron U.S.A.
,.11111 South Wj]crmmt_
_Hou~tnn; T~w~ 77~qq
Agtn: Priscilla MacLeroy
.~713/561-3652_
//Alaska 0tl & Gas
ConservationX~
/. co'mmissiOn
~3001 Porcupine Drive
~.'mnchorage, AK 99501
~.~Attn: John Boyle
prints
prints
prints
RECEIVED
DEC ,5 1 1990
The film is returned to Conoco,
Log Library.
We appreciate the privilege of serving you.
ReceJved by:
,1
Date:
Very truly yours,
SCHLUMBERGER WELL SERVICES
,David M, Saalwaechter
DISTRICT MANAGER
SWS-- ! 327-F
TO:
THRU:
FROM:
MEMORANuUM
Stale of Alaska
ALASKA OIL ~AND GAS CONSERVATION COMMISSION
Lonnie C. Smit~~?~ DATE: December 26, 1990
Commissioner
FILE NO: JT. LG. 1226.12
TELEPHONE NO:
SUBJECT:
Diverter Inspection
Conoco MPU well J-3
Kuparuk Rv Field
Louis R rzmaldl
.G'
Petroleum Inspector
~~rday 12/22/90: I performed a diverter inspection on Nabor's 27-E
preparing to ~1 well #J-3 for Conoco Milne Point. The rig and
diverter looked fine with the exception of the alternate leg of the
vent line did not extend far enough from the rig and the diverter
spool did not have enough bolts holding it to the conductor flange.
I informed the Conoco rep., Joe Polya, who remedied these.
In summary: Nabor's 27-E and it's diverter system appear to be in
good shape for drilling Conoco I~PU J-3.
02-00lA (Rev. 6/89)
20/ll/MEMO1.PM3
October 8, 1990
Telecopy.'
(907)276-7542
R. $. Rossberg
Sr. Drilling Engineer
Conoco Inc.
3201 C Street, Suite 200
Anchorage,. Alaska 99503
Re: Miine Point Unit No. J-3 Revised
Conoco Inc.
Permit No. 90-97
Sur. Loc. 2732'Fhq~, 3331'FEL, Sec. 28, T13N, R10E, UM.
Btmhole Loc. 313'FNL, 3950'FEL, Sec. 33, T13N, RIOE, UM.
Dear Mr. Rossberg:~
Enclosed is the approved revised application for permit to drill
the above referenced well.
The provisions of the cover letter, dated July 27, 1990,
accompanying the original approved permit are in effect for this
revision.
Lonnie C. ~~h
Co~issioner
Alaska Oil and Gas Conservation Co~ission
BY O~ER OF THE COMMISSION
dlf
Enclosure
cc: Department of Fish & Game, Habitat Section w/o encl.
Department of Environmental Conservation w/o encl.
Conoco Inc.
Suite 200
3201 C Street
Anchorage, Al( 99503
(907) 564-7600
August 13, 1990
C. V. Chatterton
Chairman
Alaska Oil and Gas Conservation Commission
3001 Porcupine Drive
Anchorage, Alaska 99501-1433
RE' Milne Point Unit Wells H-3, I-4, J-3 Permit to Drill Revisions
Dear Mr. Chatterton'
A change in bottom hole location from the original permitted location is
requested for the subject wells. Attached are revised permit applications and
directional drilling plans indicating the revised locations.
Very truly Yours,
Sr. Drilling Engineer
cc' MPS, DLM, SLD
RSR/sa
........ STATE OF ALASKA
ALASKA _ .~_ AND GAS CONSERVATION CON, ,~ISSION
PERMIT TO DRILL
20 AAC 25.005
,,
la. Type of work Drill E~ Redrill F-i lb. lyDe o! well. Exploratory [-: Stratigraphic Test [] Development Oil
Re-Entry [] DeepenE't. Serv,ce -' DeveloDement Gas L'] Single Zone E] Multiple Zone
2. Name of Operator i 51~a,~ ~(~ation (DF or KB) 10. Field andPoo,
CONOCO INC feet KUPARUK RIVER
3. Address i6. Property Designation
POUCH 340045, PRUDHOE BAY ALASKA 99734~. APL-25906 FIELD
4. Location of well at surtace 7. Unit or prooerty Name 11. lype'
2732' FNL, 3331' FEL, SEC. 28, T13N, R10E MILNE POINT UNIT BLANKET
At top of productive interval U M., NSB, AK 8. Weil nu~_~r Number
4900' FNL, 3800' FEL, SEC. 28, T13N, RiOE 8086-15-54
At tota, dept, APOr° ' na'el=Od '-Z, Amount
313' FNL, 3950' FEL, SEC. 33, T13N, R10E November $200,000
12. Distance to nearest 13. Distance to nearest well 14. Numoer o~ acres ~n pr°pert~ 15. Proposed depth~oao~Tvol
property line
4967 feet 60' F/J-2 @ 500' feet 2560 5325'MD, 4185'TV]~et
16. To be completed for deviated wells ~. ~ 17. Antic~0ateO pressure ~,# ;m ,~c =s0=5
Kickoff depth 500 feet Maximum hole angle74'5,~ ~ ...... su~,,=, 1900 2000
18. Casing program Sett~n~ Depth
size $0ecifications Too Bottom Quantity of cement
Hole Casing Weight Graoe Coupling ~ngth MD IVD MD IVD (include stage data)
30" 13-3/8 48# H-~40 WELD 80' ~35' 35' 115 115' ~4~5 SKS PE~FROST
12-1/4 9-5/8 36# J-55 BTRS 2925' 35' 35' 2960 2500' +658 SKS PE~FROST
~CTI( G~E ' ~ +261 SKS C~SS G
8.5 7 26# L-80 BTRS 53'25' 35' 35' 5360 4185' + 40 SKS PE~FROST
.s s CnASS
19. lo be complete~ for Redrill, Re-en[ry, and Deepen Operations. DOWNSQUEEZE
Present well condition summary +273 SKS PE~FROST
Total Oe0t~: measured feet Plugs (measured) --
+ 60 BBLS ~CTIC PAC]
true vertical feet _
Effective depth: measured feet Junk (measured)
true vertical feet
Casing Length Size Cemented Measured depth True Vertical depth
Structural
Intermediate
Production AUG 1 5 ]990
Liner
Perforation depth: measured A~as~(a0jl.& Gas ~ ,,",.. ' ~ '
true vertical ' ~cJ]ora~
20. Attachments Filing fee -- Property pl~.~' BOP Sketc~ ~ DiverterSketch ~,' Drilling program ~
Drilling fluid program ' , Timevs depth plot ~ Refraction analysis ~ Seabed report ~ 20 AAC 25.050 requirements
21. I hereby certify, that the foregoing is true and correct to the best of my knowledge
~~/ Title SR. DRILLING ENGINEER Date~~i
Signed ~ ~ ~ CommissionUseOnly
Perm. NumberIAm number I Approv~ ¢~t~ 7 ~ See cover letter
, - 9 p ! ! . / 90, for other requirements
Conditions of approval Samples required ~ Yes ~ No Mud log requ~e~ ~ Yes ~ No
Hydrogen sulfide measures ~ Yes ~No Directional su~ey required ~ Yes ~ No
Required working pressure for BOP6o ~2M; O~.M; ~ 5M; ~ 10M; ~ 15M
Other: ~/ ~ ~ l P
Approved by ~'/~ (~ /~ Commissioner the commission Date /~,~
Form 10-401 Rev. 12-1-85
L.
Submit in triplicate
-41 -
CONOCO
Structure · Pad J Well' 5
Field · Milne Point Unit Location · North Slope, Alaska~
reoted by : jones
te plotted : 06--Aug--g0
ot Reference is 3.
inotes ere in feet referees slot
ue V~icol ~ths ore referee wellh~.]
------ ~STMAN ~RISTENSEN ---
S 12 Deg 12 Min .W
2218' (To Torge()
<= West
~,~,,-,,T,~,,=,,,,,,
ISec. 26. TI3N. R. IO[. UMJ ..
.
~ I RKB Elevation: 35'
Tm%'.5~8269
[ ~ ~outh 2168
[ 1.00 West 469
lz.aa
Is. os
\
2000 -1860 Tmd-432g Dep-569
9 5/8 csg Pt Tvd=2500 Tm<1=2925 D~p=12~8 ~ 131~' mL. 30~o, m-I
~ 33. mN. R,~ej
V. TARGE-'T / M SANDS Tvd---3486 Tmd=4329 Oep--2218
N So.dB T~=3707 Trod=4644.
0 ~ Tvd--~885 Tmd-4~g8 Oep-2623
TO / 7 Liner Tvd-4185 Tmd-§325 Oep-Zg27
AVERAGE ANGLE
45 Deg 2_4 Mtn
col 200.00 Vertical Section on 192.21 azimuth wlth reference 0.00 N, 0.00
-
.
.
.
.
.
.
·
.2-Joe
·
-2ese
July 27, 1990
Telecopy:
(907)276-7542
David L. Mountj oy
Sr. Drilling Foreman
Conoco Inc.
3201 C Street, Suite 200
Anchorage, Alaska 99503
Re: ~%ltlne Point Unit No. J-3
Conoco Inc.
Pe~it No. 90-97
Sur. Loc. 2732'FNL, 3331'FEL, Sec. 28, T13N, R10E, I~.
Btmhole Loc. 5193'F~, 3317'FEL, Sec. 28, TI3N, R10E, UM.
Dear Mr. Mountjoy:
Enclosed is the approved application for permit to drill the
above referenced well.
The permit to drill does not exempt you from obtaining additional
permits required by law from other governmental agencies, and
does not authorize conducting drilling operations until all other
required permitting determinations are made.
The Commission will advise you of those BOPE tests that it wishes
to witness.
Veryr~ly yo~,~ ........ ~
Commis sioner"~-of ...... .~
Alaska Oil and Gas Conservation Commission
BY ORDER OF ~tE CO}:~ISSION
dlf
Enclosure
cc~ Department of Fish & Game, Habitat Section w/o encl.
Department of Environmental Conservation w/o encl.
---- STATE OF ALASKA
ALASK/- JlLAND GAS CONSERVATION ( MMISSION
PERMIT TO DRILL
la. Type of work Drill ~
Re-Entry __
2. Name of Operator
CONOCO 1'NC.
3. Address
Pouch 340045. Prudhoe Bev. AK 99734
4. Location of well at surface
2732' FNL, 3331' FEL, SEC. 28, T13N, R10E
At top of productive interval U.M,, NSB, AK
4620' FNL, 3320' FEL, SEC. 28, T13N, R10E
At total depth
5193' FNL, 3317' FEL, SEC.28, T13N, R10E
12. Distance to nearest / 13. Distance to nearest well
property line
1963 feet 60'F/J-2 @ 500' feet
16. To be completed for deviated wells
Kickoff depth 500 feet Maximum hole angleJ9,50
18. Casing program
size
Hole Casing
Weight
48#
TIC GE
26#
8,5
q
7
20 AAC 25.005
Redrill lb. Type of well. Exploratory ~ Strat~graph~c Test ,_ eve opment O~1
DeepenEI Service -- Developement Gas ~_ Single Zone~' Multip!e Zone.:~ ~,~¢
5. Datum' Elevation (DF or KB) 110. Field a'i~d F~'0'i ...........
19. To be completed for Redri
Present well condition summary
Total depth: measured
true vertical
Specifications
Grade I Coupling
w_~nl .U. EL_n
L-801 BTRS
I
I, Re-entry, and Deepen O
Effective depth:
KB 35 AGL
6. Property Designation
ADL-25906
7. Unit or property Name
M~LNE POINT UNIT
8. Well number
J-3
feet
9. Approximate spud date
NOVEMBER 17, 1990
14. Number of acres in property'
KUPARUK RIVER
2560
FIELD
11. Type Bond ~soo 2o AAC 25.0251
BLANKET
Number
8086-15-54
Amount
$200,000 _
15. Proposed depth~MD and TVD~
5011 'M.D, 4185'TVD~eet
2000
17. Anticipated pressure (see 20 AAC 25.035
Maximum surface 1900 ps'g At total.depth ¢TVD)
Setting Depth
MD
35'
35'
measured
true vertical
Length
80'
~7q7'
4976'
Top Bottom
TVD[ MDJ TVD
I ';ir.,, J !lr-,, I 11~'
Quantity of cement
J <include ~t.a. ge data)
+485 SKS PERMAFROST r
~658 SKS PER_H~FR0$T ___
+261 SKS CLASS G
(~'40 SKS PERMAFROST E
) J ,, j_+37,.7 S,KS. C.LASS G
3erations.
feet Plugs (measuredl DOWNSQUEEZE
feet +273 SKS PERMAFROST C
+60 8BLS ARCTIC PACK
feet Junk (measured) -
feet
Casing
Structural
Conductor
Surface
I nte rmediate
Production
Liner
Perforation depth:
Length Size Cemented Measured depth True Vertical depth
measured ' ~ ~C[10fr~8
true vertical PIT SKETCH X
20. Attachments Filing fee~ Property plat~ BOP Sketch~ Diverter Sketch X; Drilling program
Drilling fluid program~ Time vs depth plot ~ Refraction analysis ~ Seabed report -- 20AAC25.050 requiremonts
21. I hereby certify that the foregoing is true and correct to the best of my knowledge
Signed ~"//'~~'~"/~¢';;'~a'~uommissionTitle useSR DRILLIN6 FOREMAN pat
........ 'C)nlv -
Permit Number J APl number J Approval date J See cover ,ottor
.'~'c)- ¢~ 50--o-~ ?- z~.o~'..~_,. 07/27/90 for other requirements
"'Conditions of approval Samples required [Z Yes ~ No Mud Icg required 2~ Yes ,~ No
Hydrogen sulfide measures ~ Yes ~ No Directional survey required ~Yes * No
Required working p..~.C..~s.u.r.P.~for B~2M; ~3 3M; i~3 5M; ~ 10M; ~ 15M
_. by order of
Approve~ _~ Commissioner, the commission
Form 10-401 Rev. 12-1-85
submi't id trlpFica[e'
SUPPLEMENTAL DATA SHEET
APPLICATION FOR PERMIT TO DRILL
CONOCO MILNE POINT UNIT J-3
Conoco Inc.
P. O. Box 340045
Prudhoe Bay, Alaska 99734
I. Casing and Cementing Program
ae
The 13-3/8" conductor will be set at ±80' below the
surface, then cemented to the surface with ±485 sacks of
Permafrost Type "C".
Be
The 9-5/8" surface casing will be cemented with ±658
sacks of Permafrost "E" cement followed by ±261 sacks of
Class "G" Cement. A top job will be done if cement is
not circulated to the surface.
Ce
The 7" production casing will be cemented in two stages.
The first stage will consist of ±40 sacks of Permafrost
"E" cement pumped around the casing shoe followed by ±377
sacks of Class "G" cement. The secondary cement job will
consist of ±273 sacks of Permafrost "C" cement followed
by ±60 barrels of Arctic Pack pumped down the 7"x 9-5/8"
annulus.
II. Drilling Fluid Program
ae
0' - 2832' 9.0 ppg freshwater spud mud.
B. 2832' - 4107' 9.2 ppg low solids non-dispersed.
C. 4107' - TD 9.4 low solids non-dispersed.
III. Drilling Program
Conoco Inc. proposes drilling the subject well as a production
well in the Kuparuk River Field (Upper Cretaceous-West Sac).
The mud system will be low solids, non-dispersed with a mud
weight in surface hole of 9.0 ppg. Mud weight at TD will be
9.4 ppg. A 20", 2000 psi diverter will be installed on the 13-
3/8" conductor for drilling surface hole. A 13-3/8", 5000 psi
RSRRA BOPE stack will be used on the surface casing. Pressure
tests will be performed as per State Regulations. BOP's,
choke manifold, upper and lower kelly safety valves will be
tested to 500 psig and 5000 psig, the Hydril to 350 psig and
3500 psig. Casing will be pressure tested to 1500 psig.
Maximum downhole pressure is based on initial reservoir
pressure. Maximum surface pressure is based on an unexpanded
gas bubble, temperature taken into account. The closest
wellbore is J-~ with a closure of 60 feet at a depth of 500'.
The well will not be completed or tested at this time.
ae
Drill a 30" conductor hole to ±80' and set 13-3/8"
conductor.
Be
Drill a 12-1/4" surface hole to ±2500' TVD 2832' MD and
set 9-5/8" casing.
Ce
Drill a 8-1/2" production hole to ±4185' TVD to 5011' MD
and set 7" casing.
TVD MD FORMATION BIT MUD WT YD PV VIS FL
0 0 Gravel 1-1-4 9.0 32 20 90 15
500 500 Sand/Clay 1-1-4 9.0 25 20 65 15
3236 3784 "K" Sand 1-1-4 9.2 25 15 35 10
3486 4107 "M" Sand 1-1-4 9.4 25 15 35 10
3707 4393 "N" Sand 1-1-4 9.4 25 12 35 05
3885 4623 "O" Sand 1-1-4 9.4 25 12 35 05
4185 5011 TD 1-1-4 9.4 25 12 35 05
*The proposed depth is an estimate only. If the actual depth
exceeds the permit depth by over 300 feet TVD, a Sundry Notice will
be submitted.
I II I ~ II I III
NOTES: ~N~ PONT UNIT
1. ,STATE PLANE COORDINATES ARE ZONE 4
- LOCATION IN
b ~ SEC. 28, T13N, R1OE UMIAT MERIDIAN
o
~LL FROM ~ST L~ ~OM NOR~ L~
' "J'l ~378'
, ~-- ~ ~2 3354' 26.'
~ ~::,~~ J-, ~ 3331' ~732'
~ - · _ ~ J-4 3307' 2787'
' ~4--~' ~<;~o '~ ~ ~ S~TE PLANE COORDINATES-ZONE 4
290'~:
.
~t J-~': 6,O14,890.3~' 55~Olt60'
>
J
~EO~ETI~
PO~ITION~
N~D
1~27
~, 1_ 170' __ 80' _ _40'_~
~-~ -~, ~ 20'1 - ~, W~Li NORm LA~E ~ST LONG~E
· ~ ~1 70* 27'06.7426' 149' 34'34,358'
~; ~:: .::. ~ :.:~~' ~J-2 27'06,2005' 149' 34'33,66~
- 70-
I.,...::/_'...:..:_..,.~J-3 70'27'O~.6~83' 149'34'32.g~7'
~4 70' 27'O~.1163' 149' 34'32.27~
TYPICAL SECTION ~
NO 8CALE~
'1 fill I II I I I I I I I
I
Rober
1~' D'~wNDATE JAN.jsp., l~gO ~O~
~ ~ ~ ~ CHEWED DL~
~ ~ -~ ~ F~LD
~ ~ ~ ~CALE 1'=2OO' ~OB NO. 87033
II
~~LOC ~ '
),
T 13 N R 9 E T 13 N R 10 E T 13 N R 1 1 E MILNE POIN~
,.., ,t t ,,,tLr ,,.,, ut --3 ~' ": " T A (~) Danotae tract fl
¢ Co.o o, ®
~ Unit Boundary
~'~D~743~68 A~ _
~-255~
2533
~C
~.o. 0 ~ o~ ~r ~ .~"' ~ ..... ce.aco ~f ~ co.o~o ,,~ --~o.oCo~ ~**~
'~ :CHEVRON
18 17 . 16 15
15
23 24 lO 20 21 22 2 21 22
ADL-47439 ADL-3158,
ADL-25516
~-25514 2550 AC ADL-25515 2~4 AC ~2eo AC 1280 AC ADL-4743Z 2560 AC
*OL-31Se4. ADL-47438 25 ¢~C 1280 AC ,1280 ACI
30 20 2a 2~ 26 - 25 30 20 EXl
31
, 38 38 31 32 MIIoo 0
A~-25517 ~ 5
2235AC 20 ADL-25~ 256OAC ADL-25518 2560 AC ADL-28231 2555 AC
UNIT
numb®re
35,744 &oral
0/84
IBIT A
)INT UNIT AREA
Maridlln,Xlask I
I 2
~ , " ·
Scale
CHEY,
SOHIO
CONOCO INC,- NAISOP, S RIG
13-5/8" 56888 BOP SYSTEM
F:tll Line
13-5/8'
13-548' ~t
A~ 13-5/9'
A~ 13-5/8' 5M x 11' ~M
API 11' 5H
F low Line
Annubr Preventer
Ram
Choke Line: 3" 5000~ Manual
& 3" HCR VALVE
Kit[ Line: Two 3" 500015 Manual
VaLves
Ram
Tubing Spool
w/ 2"-5000~ Side Outlets
Casing Spool
w/ 3"-5000~t Side Outlets
9-5/8" Suni:ace Casing
13-3/8" Conductor' Casing
Gate VaLve
Oa~e
t, BOP STACK SIZE RATING MEETS AP] RP53 & SPEC 6A FOR CLASS 5H
2, BOPE TO BE OPERATED EACH TRIP AND TESTED WEEKLY,
3, BOP HYDRAULIC CONTROL SYSTEM TO INCLUDE (5) STATION CONTROL
MANIFOLD LOCATED REMOTE WITH 160 GALLON ACCUMULATOR, RESERVOIR
UN]T, & AUXILIARY ENERGY SOURCE FOR SYSTEM ACT]VAT]ON,
~-, H]N]HUH ONE SET BLIND RAHS & TWO SETS APPROPRIATE PIPE RAHS,
5, CHOKE & KILL HAN]FOLDS SHOWN SEPARATELY TO HEET AP] RP 53
CLASS 5H REQU]REHENTS,
KiLL MANIFOLD
FROM REMOTE HIGH
PRESSURE PUMP
NOTE:
I. HYDraULIC CC:NTROL SYST£N1 FOR 80P STACK ~ CHO~
UA~iFOLD TO INCLUDE (5) STATI~ CCN/ROL ~ANIFO~
L~AIED REVOTELY W/TH )~0 PSI ACCUUULATOR &
160 G~. RESE~IR 8 ~UX. E~ERGY SOURCE. (5)
STA. ~NIROL WANIFO~ PLUS V~RIAB~ CHOKE
~HT~L TO BE ~CATED ON RiG FLOOR.
~ KiLL a CHO~ ~ANIFOLDS m MEET AH RP53 ~.
5W s~s.
3. KILL ~ANIF~O 51ZE- RATING ~'- 5000
4. CHOKE WANIFO~ SIZE - RATING ~"- 5~0
J.~P
FROW ML
RF~h(OTE PRESSURE G~GE SENSOR
DRILLING SPOOL
~ HYDRAULIC CONTROLLED
_~RI~OTE OPIATED
REMOTE PRESSURE GAGE SENSOR
ADJUSTABLE
CHOKE
ADJUSTABLE
CHOKE
CHOKE
WANIFOLD
i VARIABLE
CHOKE
CONSOL
TO SHALE
-----iimi,
SHAKER
BLEED LINE TO ATWOSPHERIC
TO PIT I~UD/GAS SEPARATOR
CHOKE 8 KILL MANIFOLDS FOR 9s/8'~ 8 7" OD CASING BOP STACK
BOP I, ANIFOLD LAYOUT- CONOCO, INC.
:
ri
CONOCO, INC.
tdlLNE POINT UNIT
DIV£RTER STACK FOR 13 3/8' CONDUCTOR
: -
_
DIV[IT[R OUICK CON,ItT ASS[alLY
SAV[R 'SUB
1. ~e hydraulic control syst~ will ~ in a~pda~e ~i'th ~I
specifications a~ ~ requirements.
e. The HCR valve will open ~en the preventer closes. A single '
10" ~elief line will pun off of the drilling s~ol HCR valve
and will have a ta~-geted d~nstream tee fop downwind
dive.ion. Valves on ~th sides of the t~ will be full
opening a~ linked [ogether [o enabl~ one to al~ays be open
a~ the other to ~ closed.
E:::.-'
F~OM SALAMANCE~S
PUMP
HGLE FI~.L ~tJ/~S
HOLE I, ILL
TANK I
C~NTq~;UGE
DUM;~
MUD CLEANER PUIdP$
:
MIX CHz-~GE CH^RGE
I,~U:,:P 2 FUt,'P IPUMP
~ GATE VALVE
~.(~ ~uo Gu~
~:~-,,~ PSv
:,
[~"-- (~AIN ARCTIC
r~J SUCTION VALVE
SUC~ON OR DISCHARGE
C NgVALV~)
J
I NA.BORS DRiLLLNG LI,%~TED
L,~ J'tl SKU ALBERTA
j~moxc R~G
12r;~ EBL kl~O SrST~M
'~ FLOW SHEET
J~ ~ELSEN ~NOUS~m~
J ~. EO~O.m..
J ~... :. ,.ON~(~
TIME ESTIMATE J-3
Am
C.
E,
F.
G.
H.
I.
Rig up
Drill Surface Hole
Run Casing and Cement
Drill Out and Test
Drill Production Hole
Log Open Hole
Condition, POOH, L. DP.
Run Production Casing
Cement Production Casing
Move Rig
Hours
10
48
36
8
100.8
36
20
16
10
10
Days
0.42
2
1.5
0.33
4.2
1.5
0.83
0.67
0.42
0.42
Cum. days
0.42
2.42
3.92
4.25
8.45
9.95
10.78
11.35
11.77
12.19
TOTALS 294.8 12.19 12.19
MILNE POINT ;JNIT. WELL
-1
-2
-3
-4
-5
-6
-7
-8
-9
10
11
Rate vs. Depth
,
0.00 2.00 4.00 6.00 8.00 10.00 12.00 14.00 16.00 18.00
RIG DAYS
CONOCO. ! n
Pad J, Well No'
FII Ine Point Unit,
Rev I'eed Propoeal
North Slope. Alael~'e
0
1000
2000
3000
4000
5000
RKB ELEYAT[ON ~
KOP TVD=500 TMD=500 DEP=O
3
9
15 BUILD 3
PER 100 FT
21
27
3~39-- EOB TVD=1711 TMD=1811
DEP=4~3
AVERAGE ANGLE
39 DEG 21 iii N
9 5/8' CSG PT TVD=2500 THD=2832 DEP=1080
K SNDS TVD=3236.THD=3784 DEP=1683
TARGET / M SNDS TVD=3486 THD=4107 DEP=1888
N SNDS TVD=3707 THD=4393 DEP=2069
0 SNDS TVD=3885 THD=4623 DEP=2215
TD / 7' LINER
TVD=4185 THD=5011 DEP=2461
I
1000 2000
VERTICAL SECTION
I
3000
HOF~ ZONTAL PROJECT I ON
SCALE 1 IN. = 1000 FEET
CONOCO. !no,
Pad d, Nell No'
MI Ine Point Unit.
Revised Proposal
North Slope, Alaeke
1000
SURFACE LOCATION,
2732' FNL, 3331' FEL
SEC. 28. T13N. RIOE
1000
2000
3000
4000
2000 1000
I
WEST-EAST
0
I
1000
I
2000
I
SURFACE
TARGET / M SNDS
TVD=3486
TMD=410Z
DEP-1888
SOUTH 1888
EAST il
TD LOCATION,
5193' FNL, 331Z' FEL
SEC. 28. T13N. RIOE
TARGET LOCATION,
4620' FNL, 3320' FEL
SEC. 28. TI3N. RIOE
S O0 DE G
1888' (TO
20 MINE
TARGET)
2550
26O0
2650 _
2700 _
275 _
2800 _
2850 _
2900 _
2950 .
3500 ;3450 :3400 :3350 :3000
I , ,I I
I
I
I
I
~' 1900
17oo
500
:3500 :3450 :3400
-"°'~00
'~500
~ ?00
!
900 ,~
,~oo
'"',900
1100
300
3:350
3250
I
;t200
I
I
I
-.tjoo I
_ 255L
_ 260¢
I
I
[ _ 270(.
I
_ 275r
I
I
I
I
I I !
3:300 3250 3200
_ 280C
_ 285C
_ 290C
_ 2950
CHECK LIST FOR NEW WELL PERMITS
iT_tM APPROVE DATE
...
(f :~ru 8) ....
(8)
(10 and i3) 12..
13.
(4) Casg'
(14 thru 22)
(23 thru 28)
Company
Is the perm.i= fee attached ..........................................
Lease & Well No. YES NO
2. !s well to' be located in a defined pool .............................
3. Is well located proper distance from property line ..................
4. Is we!! located proper distance from other wells ........ ~ ...........
5. Is sufficient undedicated acreage available in this pool ............
6. Is well to be deviated and is we!!bore pla= included ................
7. Is operator :he only affected par:y ..................... . ............
8. Can permi= be approved before fifteen-day wait ......................
Does operator have a bond i= force .................................. ~
is a conservation order needed ...................................... ~-
Is a6m~nistrative approval needed ...................................
is :he lease number appropriate ..................................... Z --
Does :he we!! have a unique name and number .........................
14.
15.
16.
i7.
18.
19.
20.
21.
22.
23.
24.
25.
26.
27.
28.
!s cdnductor string provided ........................................ ,~z ......
Will surface casing protect all zones reasonably ex?ected to
serve as an underground source of drinking wa=er .....................
~ ,
Is enough cemen: used :o circulate on conductor and surface .........
Will cement tie in surface and intermediate or produc:ion s~rings ... ,//~, .........
Will cement cover all known productive horizons .....................
Will al! casing give adequate safety in collapse, tension and burs=..
Is nb.is well to be kicked off from an ez_isting we!!bore .............
Is old we!Ibore abandommen~ procedure included on 10-403 ............
, .,,, .,.
!s ad q llbore para=ion propos d '
e uate we se e ..... . .... ..................
Is a diveruer system required .......................................
Is the drilling fluid program schematic and lis: of equipment adequate
Are necessary diagr~ and descriptions of diver~ar and BOPE at~ached. ,¢~ .....
Does BOPE have sufficien~ pressure rating -Tes= :o ~o~ psig .. ~. ----
Does :he choke manifold comply w/AP1 RP-53 (May 84) .................. ,W,~',,,
Is :he presence of H2S gas probable .............................
(6) OTEER ~.~C ~
...... (29 =hru 31)
(6)
Geo lo g7: En ~.in~erimg:
rev: 01/30/89
6.011.
For
30.
31.
32.
exploratory and S=rauigraphic wellsr
Are data presen=ed on po=an=iai ore=pressure zones? .................
Are seismic analysis data presented on shallow gas zones ............
If am offshore loc., are survey results of seabed condi=ions presented
Additional requirements .............................................
,,,
INITIAL GEO. UNIT I ON/OFF
POOL CLASS STATUS AREA NO. SNORE
.,, ,.
, .
/ ,-'
CEECK LEST FOR NEW WELL PERMITS Company_ ~"~'5/~,,-' ~-3 Lease & Well No. /~9~ g 3-~ ' /~/~
(1> Fee /~.;0/__., , ?,//p 1. Is the permit fee at=ached .......................................... ~ ..----
(2 thru 8)
(8)
(3) Admin t~/Oc-' Z~,5 9.
(9 thru i35 10.
~3.
(14 thru 22)
(23 thru 28)
14.
15.
2. Is well to' be located in a defined pool ............................. ~__
3. Is well located proper distance from property line ..................
4. Is well located proper distance from other wells ....................
5. Is sufficient undedicated acreage available in this pool ............
6. Is weil to be deviated and is we!!bore plat included ................
7. Is operator the only affected party .................................
16.
17.
18.
19.
20.
21.
22.
Can permit be approved before fifteen-day wait .....................
23.
24.
25.
26.
27.
28.
Does operator have a bond in force ..................................
Is a conservation order needed ......................................
Is administrative approval needed ...................................
Is the lease number appropriate .....................................
Does the well have a unique name and number
!s cdnductor string provided ........................................
Wi!! surface casing protect all zones reasonably expected to
serve as an underground source of drinking water .....................
Is enough cement used to circulate on conductor and surface .........
Will cement tie in surface and intermediate or production strings ...
Will cement cover ail known productive horizons .....................
Will all casing give adequate safety in collapse, tension and burst..
Is this well to be kicked off from an existing we!lbore .............
Is old we!lbore abandonment procedure included on 10-403 ............
Is adequate wellbore separation proposed ............................
Is a diverter system required .......................................
Is the drilling fluid program schematic and list of equipment adequate,Z~f.
Are necessary diagrams and descriptions of diver=er and BOPE attached.
Does BOPE have sufficient pressure rating - Test to ~OCD psig ..
Does the choke manifold comply w/API RP-53 (May 84) ..................
Is the presence of H2S gas probable ............................. ~...
(6) OTHER
· (29 :hru' 31)
Geology: Engineering:
,,. DWa LCS
.,
rev: 01/30/89
6.011.
·
For
29.
30.
31.
32.
exploratory and Stratigraphic wells:
Are data presented on potential overpressure zones? .................
Are seismic analysis data presented on shailow gas zones ............
If an offshore loc., are survey results of seabed conditions presented
Additional requirements .............................................
INITIAL GEO. UNIT I ON/OFF
POOL CLASS STATUS AREA NO. SHORE
, , ~
Additional Remarks: '
