Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout201-199STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
E�0
MAY 0 2 2019
WELL COMPLETION OR RECOMPLETION REPORT AN
ta. Well Status: Oil ❑ Gas❑ SPLUG ❑ Other E Abandoned 21 Suspended E
20MC 25.105 20AAC 25.110
GINJ E WINJ E WAGE] WDSPL ❑ No. of Completions:
ib. Well Class:
Development ❑ Exploratory El
Service E Stratigraphic Test ❑
2. Operator Name:
ConocoPhillips Alaska, Inc.
6. Date Comp., Susp., or
Abend.: 4/8/2019
14. Permit to Drill Number/ Sundry:
• 201-1991318-271
3. Address:
P.O. Box 100360 Anchorage, AK 99510-0360
7. Date Spudded:
1017/2001
15. API Number:
50-029-23044-00-00
4a. Location of Well (Governmental Section):
Surface: 1622' FNL, 898' FWL, Sec 12, T11N, R10E, UM •
Top of Productive Interval:
486' FSL, 1870' FWL, Sec 11, T11 N, R10E, UM
Total Depth:
90' FNL, 1761' FWL, Sec 14, T11N, R10E, UM
8. Date TD Reached:
10/1212001
16. Well Name and Number:
KRU 1C-125 '
9. Ref Elevations: KB:38
GL: BF:
17. Field / Pool(s):
Kuparuk River Field/West Sak Oil Pool -
10. Plug Back Depth MD/TVD:
7636/4092
18. Property Designation:
•ADL 25650, ADL 25649
4b. Location of Well (State Base Plane Coordinates, NAD 27):
Surface: x- 561906 • y- 5968614 Zone- 4 ,
TPI: x- 557627 y- 5965408 Zone- 4
Total Depth: x- 557523 y- 5964831 Zone- 4
11. Total Depth MDrrVD:
.772514142 •
19. DNR Approval Number:
ALK 468
12. SSSV Depth MD/TVD:
NIA
20. Thickness of Permafrost MD/TVD:
2238/1771
5. Directional or Inclination Survey: Yes E (attached) No
Submit electronic and printed information per 20 AAC 25.050
13. Water Depth, if Offshore:
N/A (ft MSL)
21. Re-drill/Lateral Top Window MD/TVD:
N/A
22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days
of completion, 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
23. CASING, LINER AND CEMENTING RECORD
WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT
CASING FT TOP BOTTOM TOP BOTTOM PULLED
16 62.5 H40 Surface 158 Surface 158 24 378 sx AS 1
5.5 15.5 L-80 Surface 6664 Surface 3588 7.875 600 sx AS III Lite, 430 ax Class G
3.5 9.3 L-80 6664 7700 3588 4128 7.875 tapered string -cemented above
24. Open to production or injection? Yes E No p
If Yes, list each interval open (MD/rVD of Top and Bottom; Perforation
Size and Number; Date Perfd):
PERFORATIONS PLUGGED BACK /l' baJO4
DATE
4442 20 ( 9
VERIFIED
�_-
25. TUBING RECORD
SIZE DEPTH SET (MD) PACKER SET (MD/IVD)
31/2 6662 N/A
26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
Was hydraulic fracturing used during completion? Yes ❑ No
Per 20 AAC 25.283 (i)(2) attach electronic and printed information hp�+2
DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED
7700'-6054' 20 bbis 15.8ppg, Class G
6014'-1030' tubin , 6014'-640' IA 105 bbis 15.8ppg, Class G
630' to Surface(tubing & IA) 125 bible 15.7ppg Permafrost cement
27. PRODUCTION TEST
Date First Production:
N/A
Method of Operation (Flowing, gas lift, etc.):
PLUGGED
Date of Test:
Hours Tested:
Production for
Test Period
Oil -Bbl:
Gas -MCF:
Water -Bbl:
Choke Size:
Gas -Oil Ratio:
Flow Tubing
Press.
Casino Press:
Calculated
24 -Hour Rate
Oil -Bbl:
Gas -MCF:
Water -Bbl:
Oil Gravity - API (corr):
Form 10-407 Revised 5/2017
VTL. 8/3119
/PA/7
CONTINUED ON PAGE 2 clpD{N$�a@✓MAY 0 2 2019
8A
Submi ORIGINIAL only 6
5'2,15-' /
28. CORE DATA Conventional Core(s): Yes ❑ No 21 • Sidewall Cores: Yes ❑ No ❑� '
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.
29. GEOLOGIC MARKERS (List all formations and markers encountered):
30. FORMATION TESTS
NAME
MD
TVD
Well tested? Yes ❑ No 0
If yes, list intervals and formations tested, briefly summarizing test results.
Permafrost - Top
Surface
Surface
Permafrost - Base
2238
1771
Attach separate pages to this form, if needed, and submit detailed test
Top of Productive Interval
NIA
N/A
information, including reports, per 20 AAC 25.071.
Formation @ TPI -
Formation at total de the
N/A
31. List of Attachments: Daily Operations Summary,•9EN00211maw Schematic r Ti Fj Kos
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis,
oaleontolooical report, ion or well test results
32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. `
Authorized Name: G. L. Alvord Contact Name: Jill Simek
Authorized Title: Alaska Drilling Manager Contact Email: JiII.SimekAco .o m
Authorized,, aa Contact Phone: 263-4131 S 1
Signature: e_U/-, Date: S•(r(tsiq
INSTRUCTIONS
General: 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.
Item 1 a: 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.
Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
Item 4b: TPI (Top of Producing Interval).
Item 9: 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.
Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
Item 19: 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.
Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29.
Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of
completion, suspension, or abandonment, whichever occurs first.
Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool.
Item 24: 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).
Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain).
Item 28: 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.
Item 30: 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.
Item 31: 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.
Form 10407 Revised 5/2017 Submit ORIGINAL Only
Well Service Daily Summary - No Costs
1C-125 Job: ABANDONMENT
Report Date: 3/11/2019
Rig: AES WELL INTEGRITY DHD
Job: ABANDONMENT
Actual Start Date
Entl Date
Objactwe
AFE I RFE I Maint.#
8/17/2018
4/9/2019
Expense Special
10410208
Rig: AES WELL INTEGRITY DHD
Rig Accept Data
RI9 RBleue Date
Rlg Supervlsar
Comment
3/111201906:00
3/11/20191200
RICHWINE.BRUCE.DHD Field Supervisor
-
Daily Operations
Report Start Dale
Report End Date
lGeneral Remarks
3/11/2019 06:00
3/111201912:00
Initial T/I = Si VacNac.
Final Tll = si 0/0.
Last 24hr Summary
(P&A): T CEMENT TOP JOB (COMPLETE), IA CEMENT TOP JOB (UNSUCCESSFUL).
Report Contacts
Supervisor
I This
I Company
MILLER, MATT, DHD Tech
DHD Tech
AES
HEMBREE, ANDREW.DHD Tech
DHD Tech
AES
Time Log
Stan Time
I EndTime
I Dur (hr)
Operation
06:00
07:30
1.50
Morning meeting, sync computer, job research, travel to Connex, p/u trailer & heater, p/u water for cement, travel to 1C-pad.
07:30
07:45
0.25
MIRU.
07:45
08:15
0.50
Heater not functioning, call 88, swapped w/ other heater on pad.
08:15
11:15
3.00
(P&A) : T Cement Top Job (Complete), IA Cement Top Job (Unsuccessful).
Inifial TA = si Va Wac. T TOC Q 28' w/ -8' of fluid. T LEL's = 0%, IA LEUs = 0%.
Verified 0 psi on IA, pulled IA companion nipple & du Z'90* & cement funnel, pulled IA flange from casing valve for flow
path.
Attempted to Cement IA, got - 1 gallon of cement (15.3 PPG Portland type Iq into IA & IA flange started plugging off
(aborted), cleaned up flange & nonnaled up IA.
Verified 0 psi on T, pulled tree cap.
Cemented T to -30" below SV w/ 15.3 PPG Portland type II cement. Normaled up T.
Final Till = si OA).
11:15
11:30
0.25
RDMO.
11:30
1200
1 0.50
Travel to 3F-pad.
Well Fluids
pima I To (bbl)
I Erom (bbp
rico-rew� ibbll mote
Discharges
Disch Type
Oil SM1eeni
Material
Note
Safety Incidents
Date I
Type
Subtype
Com
Page 1/1 ReportPrinted: 5/2012019
a e a
Well Service Daily Summary - No Costs
1C-125 Job: ABANDONMENT
Report Date: 3/19/2019
Rig: AES WELL INTEGRITY MISC
Job: ABANDONMENT
Actual Start Date
8/17/2018
Entl Date
=9/2019
a
Eic�ense Special
AFE I RFE / Malnt.#
10410208
Rig: AES WELL INTEGRITY MISC
Rig Accept Date
3/19/201906:00
Rig Release Date
3/19/201918001
Rlg Supervisor
WINTER, ROGER,WI Field Supervisor
Comment
Daily Operations
Report Start Data
3/19/2019 06:00
Report End Data
3/19/2019 18:00
General Remarks
Initial T/I = 010
Last 24hr Summary
P&A: CUT WELLHEAD OFF AND PREDRILL FOR 10'X 16' PIPE.
Report Contacts
Supervisor TPoe
Company
WINTER, ROGER,WI Field Supervisor
IWI Field Supervisor
JCPAI
Time Log
Start Tma
Entl Time
Dur
Operation
06:00
0630
1030
17:30
06:30
10:30
17:30
118:00
0.50
4.00
7.00
0.50
Travel from KOC to 1C -pad.
Remove snow from cellar- PJSM -cut and remove 2'9" of wellhead.
Remove snow around cut off well - mark ground and predrill for 10'X 16' pipe - pick up location and barricade around
cellar.
Travel from 1 C pad to KOC.
Well Fluids
GN1E To (DDI)
From (bbl)
Nan-recov (bbl)
Note
Discharges
DisU Type
Oil Sneen9 Matenal
Note
Safety Incidents
Date
Type
Subtype
Com
Page 111
Report Printed: 5/2012019
Well Service Daily Summary - No Costs
1C-125 Job: ABANDONMENT
Report Date: 312012019
Rig: AES WELL INTEGRITY MISC
Job: ABANDONMENT
Actual Start Date
8/17/2018
Entl Date
419/2019'--'------°' -
AFE I RFE / Malnt#
10410208
Rig: AES WELL INTEGRITY MISC
Rig Accept Date
3/20/201906:00
Rig Ralease Date
3120/201918:00
Rlg Supervisor
MOUSER. ROGER,WI Field Supervisor
Comment
-
Daity Operations
Report Start DateRepoli
320/2019 06:00
Entl Date
3202019 18:00
General Remarks
N/A
Last 24hr Summary
P&A PREP (IN PROGRESS) DRILLED 80 2"PILOT HOLES INTO THE GROUND.
Report Contacts
Supervisor TMeCompany
MOUSER, ROGER,WI Field Supervisor WI Field Supervisor
IGPAI
Time Log
Stan Lme
End Time
Dur (T
Operotlon
0600
06:30
17:30
06:30
17:30
18:00
0.50
11.00
0.50
Travel from KOC to 1C pad
P&A PREP (IN PROGRESS) DRILLED 80 2"PILOT HOLES INTO THE GROUND.
Stand plate located below frozen soil. Drilled 80 2" pilot holes into the ground for pipe install.
Return to in AM cut and remove stand plate proir to installation of 10'x16' shore pipe.
Travel 1C pad to KOC
Well Fluids
Flwd I To (bbp
I Fmm (*bp
Norvrecov (bbl)
Note
Discharges
Dlsch Type
OASheen'
Material
Note
Safety Incidents
Date I
Type Subtype Com
Page 111
Report Printed: 512012019
Well Service Daily Summary - No Costs
1C-125 Job: ABANDONMENT
Report Date: 3/21/2019
Rig: AES WELL INTEGRITY MISC
Job: ABANDONMENT
Actual Start Data
8/17/2018
End Data Objective
4/9/2019 Expense Special _
Rig: AES WELL INTEGRITY MISC
Rig Accept Date
3/21/2019 06:00
Daily Operations
Rig Release Date Rig Supervisor
3/212019 18:00 MOUSER. ROGER,WI Field Supervisor
Report Start DateReport
3/21/201906:00
End Date
321201918:00
General Remarks
N/A
Last 24hr Summary
P&A PREP (IN PROGRESS) CUT & REMOVED STAND PLATE, CONTINUED DRILLING 2"PILOT HOLES INTO THE GROUND,
Report Contacts
Supervisor
I Me
I Company
MOUSER, ROGER,WI Field Supervisor
jWl Field Supervisor
ICPAI
Time Log
Stan Time
End Tme
Dur(hr)
Operation
0600
06'.30
1730
06:30
17:30-
18:00
0.50
11.00
0.50
Travel from KOC to 1C pad
PJSM, P&A PREP (IN PROGRESS) CUT & REMOVED STAND PLATE, CONTINUED DRILLING 2"PILOT HOLES INTO
THEGROUND.
Cut and removed stand plate. continued to drill 2" pilot holes.
Begin assembly of vibratory hammer for 10'x16 shore pipe installation.
Return to in AM to begin shore pipe install.
Travel 1C pad to KOC
Well Fluids
Fluid Te (blot) From (bbl) Nonramv (w) Note
Discharges
Drsch Type
Oil Sheen9
tdalenal Note
Safety Incidents
Date
Type
subtype
Com
Page 1/1 Report Printed: 5/2012019
Well Service Daily Summary - No Costs
1C-125 Job: ABANDONMENT
Report Date: 3122/2019
Rig: AES WELL INTEGRITY MISC
Job: ABANDONMENT
Actual Start Date
8/17/2018
End Date
4/9/2019
Objective
Expense Special
AFE I RFE / Malnl.#
10410208
Rig: AES WELL INTEGRITY MISC
Rig Accept Date
3/22/2019 06:00
Rig Release Date
3/222019 18:00
Rig Supervisor
MOUSER, ROGER,WI Field Supervisor
Comment
Daily Operations
Report Start Date
3122/2019 06:00
Report End Date
322/2019 18:00
General Remarks
1 N/A
Last 24hr Summary
P&A PREP (IN PROGRESS) CONTINUED DRILLING 2"PILOT HOLES INTO THE GROUND.
Report Contacts
Supervisor
Tae
Campar
MOUSER, ROGER,WI Field Supervisor
WI Field Supervisor
JCPAI
Time Log
Time
Dur(hr)
Operation0.50
06:
17:
jFluids
11.00
0.50
Travel KOC to 1C pad
PJSM, P&A PREP (IN PROGRESS) CONTINUED DRILLING 2"PILOT HOLES INTO THE GROUND.
Continued to pre drill pilot holes for shoring installation.
Rigged down due to weather conditions detiomting
Return to in AM to begin post stomt dean up and shore pipe install.
Travel 1C pad to KOC.
We
F1uW To (bbl)
Front (loch
Nonremv (bbl)
Note
Discharges
Disch Type
Oil Sheen>
Material
Note
Safety Incidents
Oale
Type
Subtype
Com
Page 111
Report Printed: 5202019
Well Service Daily Summary - No Costs
1C-125 Job: ABANDONMENT
Report Date: 3123/2019
Rig: AES WELL INTEGRITY MISC
Job: ABANDONMENT
Actual Start Date
8/17/2018
End Date
4/9/2019
Objective
Expense Special
AFF- / RFE / MalnAX
10410208
Rig: AES WELL INTEGRITY MISC
Rig Accept Date
3/23/201906:00
Rig Release Date
3/231201918:00
Rig Supervisor
MOUSER.ROGER,WI Field Supervisor
comrpent
Daily Operations
Report Start Date
3/23/2019 06:00
Report Entl Date
3/23/2019 18:00
General Remarks
N/A
Last 24hr Summary
P&A PREP (IN PROGRESS) POST STORM CLEAN UP. ATTEMPTED REMOVING CELLAR BOX. NEEDED TO THAW CELLAR BOX FOR REMOVAL.
Report Contacts
Supenmor Title
Company
MOUSER, ROGER,WI Field Supervisor WI Field Supervisor
JCPAI
Time Log
Stan'rine
End Time
Dur lhr)
dperatlon
06:00
06:30
1230
17:30
06:30
12:30
17:30
18:00
0.50
6.00
5.00
0.50
Travel from KOC to 1C Pad
Snow removal post storm
P&A PREP ( POST STORM CLEAN UP) NES ASSISTED CLEARING SNOW FROM PAD. ATTEMPTED REMOVING
CELLAR BOX. NEEDED TO THAW CELLAR BOX FOR REMOVAL.
Cellar filled with water, contacted well support for removal of water.
Cellar box fabricated from 10'x10" was unable to be completely removed.
Covered exposed cellar area with tarp and applied heat for 3 hours, Removed 3/4 of the cellar.
Recovered cellar area and applied heat to thaw further overnight.
NES has personnel on location overnight to monitor equipment and work area.
Travel 1C Pad to KOC.
Well Fluids
Flultl
I To (bb[)
I From (bbl)
Norvremv (bbl)
Note
Discharges
Dlsoh Type
I Oil Sheen?
Metarlal I
Note
Safety Incidents
Date
Type
Subtype
ICom
Page 111 Report Printed: 512012019
Well Service Daily Summary - No Costs
1C-125 Job: ABANDONMENT
Report Date: 3/2412019
Rig: AES WELL INTEGRITY MISC
Job: ABANDONMENT
Actual Stan Date
End DateOb)ecUve
AFE 1 RFE / Malnt.#
8/17/2018
4/9/2019
Expense Special
10410208
Rig: AES WELL INTEGRITY MISC
Rig Accept Date
lg Release Date
Rlg Supervisor
comment
3/24/201906:00
IR
3/24/201918:00
MOUSER, ROGER.WI Field Supervisor
Daily Operations
Report Stan Date
I Report End Data
General Remarks
3/24/2019 06:00
3/24/2019 18:00
N/A
Last 24hr Summary
P&A PREP (IN PROGRESS). COMPLETED REMOVAL OF CELLAR BOX. BEGAN INSTALLATION OF 10'x16' SHORE PIPE. VIBRATED TO -5', TARGET
DEPTH OF 14'. (CAN BROKE AT THE END OF DAY. WILL RETURN IN AM TO ATTEMPT REPAIR.
Report Contacts
Supervisor
I Titlo
I Company
MOUSER, ROGER,WI Field Supervisor sW'
WI Field Supervisor
ICPAi
Time Log
stanrme I
Endnme
Du, (hr)
openflim
D6:00
06:30
0.50
Travel KOC to 1C-Pad
06:30
17'.30
11.00
P&A PREP (IN PROGRESS). COMPLETED REMOVAL OF CELLAR BOX. BEGAN INSTALLATION OF 10X16' SHORE
PIPE. VIBRATED TO -5', TARGET DEPTH OF 14'. (CAN BROKE AT THE END OF DAY. WILL RETURN IN AM TO
ATTEMPT REPAIR)
NES completed cellar box removal.
Marked reference points for shoring installation.
Set shoring in place, and rigged up vibratory hammer, adjusted the width to fit shoring,
Allowed hammer to warm up prior to attaching to shoring.
Vibrated -5 in 5 hours. Necessary to shut down twice to allow bearings to cool down in the hammer.
Noticed damage to CAN at end of the day.
Rigged down the hammer for the night and put heat on the shoring pipe.
Return in the AM to attempt repair to 10'x16' shoring
1730
18:00
0.50
Travel 1 C- Pad to KOC
Well Fluids
Fbid I To(W I From (bbl) fl. r oy(bW)I Nob
Discharges
Dlxh Type
Oil Sheen?I Material I Nob
Safety Incidents
Date I
Type
Subtype Com
Page 1/1 ReportPrinted: 5/20/2019
Well Service Daily Summary - No Costs
1C-125 Job: ABANDONMENT
Report Date: 3/2512019
Rig: AES WELL INTEGRITY MISC
Job: ABANDONMENT
Actual Start Date
8/17/2018
End Date
4/9/2019
Objective
Expense Special
AFE I RFE I Maint.9
10410208
Rig: AES WELL INTEGRITY MISC
Rig Accept Date
3/25/2019 06:00
Rig Release Date
3/25/2019 23:45
Rig Supervisor
MOUSER. ROGER,WI Field Supervisor
Oom
Daily Operations
Report Start Date
3/25/2019 06:00
Report End Date
3/2512019 2345
General Remarks
NIA
Last 24hr Summary
P&A PREP (IN PROGRESS) REPAIR PROCESS BEGAN, INSPECTION BY TUBOSCOPE FOR OTHER CRACKS IN PIPE MATERIAL. NES WELDER TO
WELD DAMAGED AREAS THROUGHOUT THE NIGHT. KAKIVIK TO FOLLOW UP WITH WELD INSPECTIONS FOLLOWING REPAIRS.
Report Contacts
Supervisor I TWO I Company
MOUSER, ROGER.WI Field Supervisor ;jWI Field Supervisor
CPAI
Time Log
Stan Time
End Time
Our(en
pparabpn
06:00
0630
1330
23:15
06:30
1330
23:15
23:45
0.50
7.00
9.75
0.50
Travel from KOC to 1 C Pad
WAIT on Tuboscope and NES WELDERS to obtain
P&A PREP (IN PROGRESS) REPAIR PROCESS BEGAN, INSPECTION BY the night shift FOR OTHER CRACKS IN
PIPE MATERIAL. NES WELDERS TO WELD DAMAGED AREAS THROUGHOUT THE NIGHT KAKIVIK TO FOLLOW UP
WITH WELD INSPECTIONS FOLLOWING REPAIRS.
Welders working throughout night to complete repairs.
Travel 1C-PAD to KOC
Well Fluids
Fluid To (bbp
From (bbp INonrecw
(bbl)
Nate
Discharges
Dish Type
Oil Sheen?
Material
Note
Safety Incidents
Data I
Type Subtype
Com
Page 1/1 Report Printed: 5/20/2019
Well Service Daily Summary - No Costs
1C-125 Job: ABANDONMENT
Report Date: 3126/2019
Rig: AES WELL INTEGRITY MISC
Job: ABANDONMENT
Actual Start Dad
End Date
Ob)BCOve
1 / Malnt.#
8/17/2018
4/9/2019
Expense Special
104AFE
2
10410208 _
Rig: AES WELL INTEGRITY MISC
Rig Accept Date
RIB Release Date
Rig Supervisor
COmm�nt _
3/26/2019 00:15
3/26/2019 22:15
MOUSER, ROGER WI Field Supervisor
Daily Operations
Report Start DadReport
End Dad
General Remarks
3/26/2019 00:15
3/26/2019 22:15
N/A
Last 24hr Summary
P&A PREP IN PROGRESS. NES WELDERS REPAIRNG SHORING CAN. NES QC VT (VISUAL TESTING),KAKIVIK PERFORMING MT NDE TESTING,
CONFERRED WITH CWG. DECISION MADE TO POSTPONE 1C-125 P&AAND DEMOBE EQUIPMENT FOR HIGHER PRIORITY 3G-19A P&A JOB. WILL
RETURN AFTER COMPLETION OF 3G-19A P&A.
Report Contacts
Supervisor Title Company
MOUSER, ROGER,WI Field Supervisor
IWI Field Supervisor
CPAI
Time Log
Stan Time
End Time
Dur (hr)
Operalion
00:15
00:45
0.50
Travel from KOC to -1C- pad.
0045
1445
14.00
P&A PREP IN PROGRESS. NES WELDERS REPAIRNG SHORING CAN. NES QC VT (VISUAL TESTING),KAKIVIK
PERFORMING MT NDE TESTING, CONFERRED WITH CWG. DECISION MADE TO POSTPONE 1C-125 P&A AND
DEMOBE EQUIPMENT FOR HIGHER PRIORITY 3G-19A P&A JOB. WILL RETURN AFTER COMPLETION OF 3G-19A
P&A.
NES welders working to finish up repair welds prior to demobing Shoring Can and equipment from 1C-125.
(Post inspections NES welders needed to reweld two locations)
Kakivik to repeat MT nde testing after rewelds are completed.
14:45
1115
7.00Rig
down equipment in progress to mobe to 3G-19
21:45
22:15
0.50
Travel from 1C-125 to KOC
Well Fluids
Fluid To (bb
Nonrecov (bbp Nota
Discharges
Diech Type
Oil Sheen'
te
Marial
Nota
Safety Incidents
Date
Type
I Subtype
I Com
Page 111 ReportPrinted: 5/20/2019
Well Service Daily Summary - No Costs
1C-125
Rig:
Job: ABANDONMENT
Report Date: 4/7/2019
AES WELL INTEGRITY MISC
Job: ABANDONMENT
Actual Start Date
8/17/2018
Entl Data S
419/2019
AFE / RFE / Malnt#
10410208
Rig: AES WELL INTEGRITY
MISC
Rig Accept Date
4/7/201906:00
Rig Release Date
4l7I201916:00
Rat Supervisor
WINTER.ROGER,WI Field Supervisor
Comment
Daily Operations
Report Start Date
4/7/2019 06:00
Repoli End Date
4/7/2019 16:00
General Remarks
N/A
Last 24hr Summary
PBA: EXCAVATE WITH TRIMMER TO 12'
Report Contacts
Supervisor
I TNe
I
Company
MOUSER, ROGER,WI Field Supervisor
IWI Field Supervisor
CPAI
Time Log
Start Time
I End Tlme
I Dur(hr)
Operation
0600
0630
17:30
0630
17:30
118:00
0.50
11.00
0.50
Travel from KIC to 1C pad.
Excavate with Ornmer down to 12'.
Travel from 1C pad to KIC.
Well Fluids
Fluitl
Ta (bbq
I Fmm rybq I
Nowecov (bbl)
Nate
Discharges
Disch Type
011 Sheen9 Matenal
Note
Safety Incidents
Date Type
Subtype
Com
Page 111
Report Printed: 5/2012019
Well Service Daily Summary - No Costs
1C-125 Job: ABANDONMENT
Report Date: 41812019
Rig: AES WELL INTEGRITY MISC
Job: ABANDONMENT
Actual Start Date
8/17/2018
End Date
4/9/2019
Objective
Expense Special
AFE / RFE I MainLg
10410208
Rig: AES WELL INTEGRITY MISC
Rig Accept Date
4/8/201906:00
Rig Release Date
418/201918:00
Rlg Supervisor
WINTER, ROGER.WI Field Supervisor
Comment
Daily Operations
Report Start DateReport
4/8/2019 06:00
End Date
4/8/2019 18:00
General Remarks
N/A
Last 24hr Summary
P&A: FINISH EXCAVATING TO 14' AND REMOVE 101"' (4'+ BELOW TUNDRA) OF WELL STUB (TOLAL WELL REMOVED = 13')
Report Contacts
Supervisor
Title
Company
MOUSER, ROGER,WI Field Supervisor
WI Field Supervisor
CPAI
Time Log
Stan Tme
End Lme
Durrr)
opet9dM1
06:00
06:30
1230
17:30
06:30
12:30
17:30
18:00
0.50
6.00
5.00
0.50
Travel from KIC to 1C pad.
Excavate to 14'- install 10'X 16' pipe - bury and compact around pipe.
lWeld plate across top of well stub to be all strings together, hook up crane and cut off 10'3"(4'+ below tundra) well stub,
prep well for marker plate, add 1 cup of cement to IA.
Travel from 1 C pad to KIC.
Well Fluids
Fluid
To (bbl) I From ICG)
Norvrecov (bbl)
Nole
Discharges
Ge& Type
I011 SCeen9 Matenal
Nab
Safety Incidents
Date
Type
subtype
I Com
Page 111 Report Printed: 512012019
Well Service Daily Summary - No Costs
1C-125 Job: ABANDONMENT
Report Date: 4/9/2019
Rig: AES WELL INTEGRITY MISC
Job: ABANDONMENT
Actual Start Date
8/17/2018
End Date
4/9/2019
Objective
Expense Special
AFE I RFE I Malnl#
10410208
Rig: AES WELL INTEGRITY MISC
Rig Accept Date
4/9/2019 06:00
Rig Release Data
4/920191900
Rig Supervisor
WINTER, ROGER.WI Field Supervisor
Comment
Daily Operations
Report Start Date
4/9/2019 06:00
Report EntlData
4/920191 9:00
General Remarks
N/A
Last 24hr Summary
P&A: STATEMAN WITNESS CEMENT & MARKER PLATE, WELD PLATE- BACK FILL & REMOVE 10'X 16' PIPE - P&A COMPLETE
Report Contacts
Supervisor
I Title
I Company
MOUSER, ROGER,WI Field Supervisor
WI Field Supervisor
ICPAI
Time Log
Stan Time
I End Time
Dur (hr)
Dperatbn
06:00
06:30
08:30
1030
1430
18:30
06:30
08:30
10:30
14:30
18:30
19:00
0.50
2.00
2.00
4.00
4.00
0.50
Travel from KIC to 1C pad.
Stateman Austin McLeod witness cement and P&A marker plate.
GBR welder Jose fitted and welded marker plate.
Back fill inside of pipe, RU hammer and vibirate 10'X 16' pipe out of the ground. RD hammer.
Set pipe at end of front well roll, RD & release equipment.
Travel from 1C to KIC.
Well Fluids
Ruitl I T. jibe Fmm(bbg I Norrewv(bbp
Note
Discharges
[),,ch Type
OII Sheen/
material I Note
Safety Incidents
Date
Type
Subtype
Com
Page 1/1 Report Printed: 5120/2019
Well Service Daily Summary - No Costs
6
1C-125 Job: ABANDONMENT
Report Date: 8/17/2018
Rig: HES SLICK LINE 759
Job: ABANDONMENT
Actual Start DateEna
Date
06jective
AFE / RFE / Malnt#
8/17/2018
4/9/2019
Experse Special
10410208
Rig: HES SLICK LINE 759
Rig Accept Date
Rlg Release Dale
Rig Supervisor mRm
8/17/201806:00
8/17/201814:00
FERGUSON, SID,Wells Supervisor AML -1111116
Daily Operations
Report Start Date
Report End Date
General Remarks
8/17/2018 06:00
8117/2018 14:00
INITIAL=250/0
FINAL=300/0
Last 24hr Summary
DRIFT w/ 2.25" BLR & PULL HEX PLUG @ 6697'RKB. LRS CONDUCTED 30BBL INJECTIVITY TEST. 1 BPM @ 950 PSI, 2 BPM @ 1475 PSI. READY FOR
CEMENT.
Report Contacts
Supervisor I Title
Compery
HERRON, ZANE,SI'ibklina Supervisor ._ Slickline Supervisor
HES
Time Log
sun r,re
Erd Time
Our (hr)
Opuauon
06:00
06:30
0.50
PU WELLFILE & CPU. CONFER w/ CWG REP. SYNC. CONTACT DSO. TRAVEL TO LOCATION. INSPECT ARFA
06:30
08:15
1.75
JSSM. JSA. RU .108" WIRE & 1.5" TS=RS,QC,5',QC,KJ,3',3',QC,KJ,5',QC,OJ,QC,KJ,LSS(34"). START TICKET @ 8:00.
08:15
09:30
1.25
PT w/ LRS TO 2500PSI. RIH w/ 5x2.25" DD BLR. DRIFT FREELY TO TAG HEX PLUG @ 6658'SLM(6697'RKB). POOH.
09:30
11:00
1.50
PT w/ LRS TO 2500PSI. RIH w/ 2.12" CENT,1.5" DOGLESS GS. SD @ 666USLM(6697'RKB). JAR DOWN 5 MINUTES.
POOH. GS SHEARED.
11:00
13:0-
2.00
PT w/ LRS TO 2500PSI. RIH w. 2.12" CENT,1.5" GS. FALLING SLOW. LATCH HEX PLUG @ 6660'SLM(6697'RKB). PT
TBG TO 700PSI. HIT 5 LIGHT SPANG LICKS. TBG FELL TO 350PSL HIT SPANG LICKS 10 MINUTES. POOH w/ HEX
PLUG.
13:00
14:00 -,.
1.00
RU LRS TO TREE CAP FOR INJECTIVITY TEST. END TICKET @ 14:00. ROMO. PJSM. CONTACT DSO, INSPECT
AREA.
Well Fluids
Fluid
To (bbi)
I From(bbl) I
Nor-recov(bbl) I Note
DIESEL
30.0
Discharges
Disch Type
Oil SM.,?
Material
Nate
Safety Incidents
Data I
Type
Subtype
Com
Page 1/1 Report Printed: 5/2012019
Well Service Daily Summary - No Costs
1C-125 Job: ABANDONMENT
Report Date: 9/1/2018
Rig: SLB CEMENT CMT
Job: ABANDONMENT
Actual Start Date
8/17/2018
End Dale
4/9/2019
Obpctive
Expense Special
AFE I RFE I Malnl.fl
10410208
Rig: SLB CEMENT CMT
Rig Accept Date
9/1/201806:00
Rlg Release Date
9/1/201813:00
Rig Supervisor
BESSETTE, PAUL.Wells Supervisor
Daily Operations
Report Start Date
9/1/201806:00
Report End Date
9/1/201813:00
lGeneral Remarks
INITIAL T/1=210/0
FINAL T8=700/0
Last 24hr Summary
PUMPED 20 BELS 15.8 CLASS G CEMENT FOR FIRST STAGE OF PBA, SQUEEZED 10 BELS THROUGH PERFS, TOC -6550 RKB, WELL IS FREEZE
PROTECTED WITH 22 BBLS DIESEL.
Report Contacts
Supervisor
Title,
Company
MURPHY, Pumping Supervisor "
Pumping Supervisor
SLB
Time Log
Stan Tme
End Time
I Dur(hd
crane.
06:00
08:00
0900
1100
08:00
09:00
11:00
13:00
2.00
1.00
2.00
2.00
Travel time from Deadhorse due to bad roads
MIRU, Hold safety meeting
pressure test to 3500 psi, Pump 10 bbls fAv ahead at 2.0 bpm, whp=1000, swap to cement, 8 bbls away, increase pump to
2.8 bpm, whp=645 psi, follow 20 bbls cement with f/w, launch foam ball, pump 35 bbls fAv followed by 22 bbls diesel,
pressure increase to 1050 when cement is at perf, squeeze 10 bbis, shut down, well holds 1050 steady, bleed down to 700,
trap on well.
Wash up all equipment, RDMO.
Well Fluids
Fluid
Ta (bbl)
From (bbl)
Norvrecav (bbl)
Note
Discharges
D,i Type
Oil Sneen9
Material
Nota
Safety Incidents
Date I
Type
Subtype Com
Page 1/1 Report Printed: 5/20/2019
A"
Well Service Daily Summary - No Costs
1C-125 Job: ABANDONMENT
Report Date: 9/4/2018
Rig: HES SLICK LINE 760
Job: ABANDONMENT
Actual Start DateEnd
Date APE / RFE I MaintA
8/17/2018
4/9/201911111�-10410208
Rig: HES SLICK LINE 760
Rig Accept Date
Rig Release Date Rlg Supervisor Comment
9/4/201806:00
9/41201813:00 CLAYTON, GREG,Wells Supervi
Daily Operations
Report Start Date
Report End -Date
General Remarks
9/4/201806:00
9/41201813:00
INITIAL T/1=010
FINAL TA=0/0
Last 24hr Summary
TAGGED TOP OF CEMENT @ 6054' RKB. ATTEMPT TO MIT -T TO 1500 PSI (FAIL). UNABLE TO ESTABLISH LLR @ 3000 PSI. ATTEMPT DDT (FAIL). TURN
OVER TO DHD FOR DIAGNOSTICS.
Report Contacts
supervisor I
Company
MORGAN, JOSHUA,Slickline Supervisor"' - Slickline Supervisor
HES
Time Log
Start Time
End Time
our(hD
Oparaban
06:00
06:45
0.75
PU WELL FILE & CPU. CONTACT DSO, TRAVEL TO LOC.
06:45
08:00
1.25
ARRIVE & INFECT LOC. PJSM, MIRU .108" WIRE, SWAP TO 1.5" RLR TS5', KJ, 51, KJ, 5', OJ, KJLSS (31' OAL) (START
-
TIME @ 08:00)
08:00
09:45
1.75
PT W/ GAS (1200) RIH W/2" DD-BLR, TOOLS FELL SLOWLY TO 6011' SLM, SD. JARRED DOWN TO 6016' SLM, 6054'
RKB. TOP OF CEMENT... POOH, OOH RECOVERED BAILER FULL OF CEMENT & FOAM BALL.
09:45
12:
2.25
LRS ATTEMPT TO MIT -T TO 1500 PSI.
PRE T/1=010 INITIAL TA=1550/0 15 MINS TA=1150/0 FAIL, .3 BBLS TO PRESSURE UP.
BUMP BACK UP .2 BBLS INITIAL TA=1500/0 15 MINS TA=1200/0 FAILED
BUMP BACK UP .2 BBLS INITIAL TA=1500/0 15 MINS TA=1200/0. CONFER WI CWG.
PRESSURE UP TO 3000. 4 BBLS INITIAL TA=3000/0 15 MINS T/1= 2500/0 FAILED. CONFER W/ CWG.
DRAW DOWN TEST BLED TBG TO 0 INITIAL T/1=010 15 MINS T/1=0/0 30 MINS T11=010, CONFER W/ CWG.
OPENED WELL TO BLED TRAILER CONTINUOUS FLOW OF DIESEL NO PRESSURE GAIN.
12:00
12:45
0.75
PJSM, RDMO. DSO NOTIFIED (END TIME @ 14:00)
12:45
13:00
0.25
TRAVEL OVER TO 1B-07
Well Fluids
Fluid To (bbq
From (bbd
Non rmcov (bbq
Nota
DIESEL
:A. B
Discharges
Decn Type
cil Sbee0
Mahrul
Nota
Safety Incidents
Date
Type
Subtype
com
Page 111 Report Printed: 5/20/2019
Well Service Daily Summary - No Costs
1C-125
Job: ABANDONMENT
Report Date: 9/512018
Rig:
AES WELL INTEGRITY DHD
Job: ABANDONMENT
Actual Stan Date
End Date
Objective
AFE / RFE / Malnt.#
8/17/2018
4/9/2019
Expense Special
10410208
Rig: AES WELL INTEGRITY DHD
Rig Accept Date
Rlg Release Date
Rig Supervisor
Comment
9/5/2018 09:00
9/5/2018 11:30
SUMRALL, SHELBY,DHD Tech
Dally Operations
Report Start Date
Report End Date
General Remarks
9/5/2018 09:00
9/5/2018 11:30
Initial TA = SI 818
Final T/I = SI 0/8
Last 24hr Summary
T-DDT (IN PROGRESS)
Report Contacts
Supervisor
M.
I
Company
HILLS, TOM.DHD Tech
DHD Tech
AES
WEIMER. PATRICK,DHD Tech
I DHD Tech
AES
Time Log
Stan Time
End Time
Dur (hr)
Operation
09:00
09:30
0.50
Drive drom 2G pad tot C pad
09:30
09:45
0.25
MIRU
09:45
11:15
1.50
T-DDT (IN PROGRESS)
Initial TA = SI 818, T FL @ NS, IA FL @ NS
Bled T to 0 psi in 3 sec (gas), left T on open bleed for 60 min
SI T for 60 min monitor.
15 min = 0.5/8 (+0.5 psi)
30 min = 1/8 (+0.5 psi)
45 min = 1/8
60 min = 1.5/8 (+0.5 psi)
Bled T to 0 psi
Final T/I = SI 0/8
11:15
11:30
1 0.25
1 RDMO
Well Fluids
Fluid Te (bbq From (bbp
Non-recov (bbp
Note
Discharges
Disch Type
I Oil Sheen?
I Matenal
Note
Safety Incidents
Data
I Type
I Subtype
Cam
Page 1/1
ReportPrinted: 512012019
Well Service Daily Summary - No Costs
1C-125
Job: ABANDONMENT
.
Report Date: 9/6/2018
Rig:
AES WELL INTEGRITY DHD
Job: ABANDONMENT
Actual Start Data
End DateOb
APE I RFE 1 Maint.#
8/17/2018
4/9/2019
Ecpen ial —
10410208
Rig: AES WELL INTEGRITY DHD
Rig Accept Date
Rig Release Date
Rig Supervisor
Comment
9/612018 06:00
916/201812:00
SUMRALL. SHELSY,DHD Tedi
Daily Operations
Report Stan Date
Report EndData
General Remarks
9/6/2018 06:00
9/6/2018 12:00
Initial Till = 1/8.
Final T/I = 010.
Last 24hr Summary
TBG & IA DDT (PASSED)
Report Contacts
Supervisor
Title
Campany
WEIMER, PATRICK,DHD Tech
DHD Tech
AES
HILLS, TOM, DHD Tech
DHD Tech
AES
Time Log
StariTime
EndTime
Dur(hr)
Operetim
06:00
06:30
0.50
Morning meeting, sync computer.
06:30
06:45
0.25
Contact DSO, MIRU.
06:45
11:15
4.50
TBG & IA DDT (PASSED)
TA=1/8. T FL( a� NS, IA FL @ NS.
Bled TBG to 0 psi in 3 seconds (gas), bled IA to 0 psi in 1 min (gas).
Leave TBG & IA on an open bleed for 60 min. No fluid present dunng open bleed.
Shut in TBG & IA, begin monitor period.
Starting TA = 0/0.
15 min TA = 0/0.
30 min TA = 0/0.
45 min T/I = 010.
IN
60 min TA = 0/0.
Final T/I = 0/0.
11:15
11:30
0.25
Contact DSO, RDMO.
11:30
12:00
0.50
Travel to KOC, Sync computer. Changeout w/ arriving crew.
Well Fluids
Fluid To(bbl)
I Fram(bbi)
Noo-repcv(bbl)
I Nota
Discharges
Disch Type
IOii SM1een9
Material
Note
Safety Incidents
Data
Type Subtype
Com
Page 1/1
Report Printed: 5/20/2019
Well Service Daily Summary - No Costs
4b
1C-125 Job: ABANDONMENT
Report Date: 9/2212018
Rig: HES DIGITAL SLICK LINE 764
Job: ABANDONMENT
Actual Start Date Entl Date Objeetive AFE I RFE / MaInLN
8/17/2018 4/9/2019 Expense Spe 10410208
Rig: HES DIGITAL SLICK LINE 764
Rig Accept Date Rig Release Date Rig Supervisor _ Comment
9/22/201806:00 9122/201818:00 BESSETTE, PAUL,Wells Supe.... _
Daily Operations
Report Start Date
Repart Entl Date
General Remarks
9/22/2018 06:00
9/22/2018 18:00
INITIAL= 0/0 FINAL= 200/25
Last 24hr Summary
STATE WITNESSED (JEFF JONES) TAG @ 6048' RKB & MITT TO 2000 (PASS). WORK 1.75" BAILER FROM 6053' TO 6108' RKB (RECOVER FOAM BALL
PIECES & HARD CEMENT). PUNCH HOLES FROM 6010'-6014' RKB WITH 2" x 4' TBG PUNCH, 4spf, 0" PHASING. PUMPED 6 BBLS @ 2bpm 750 TBG, 10
IA. JOB COMPLETE AND READY FOR CEMENT.
Report Contacts
Supervisor I Tee
CompenY
HES
WATKINS, KRIS,SiickOne Supervisor' Slickiine Supervisor
ESSICK, WADE,E-Line
Engineer E -Line Engineer
HES
Time Log
Stan Time I
End Time
I Dur(hr)
Operation
06:00
06:48
0.80
PU FILE I CPU, SYNC, ONTO LOCATION, CONTACT DSO, INSPECT AREA, JSSM.
0648
09:00
2.20
RU RELAY AND T' TS= RLR,5',5',5',RLR,LFTJ,PCH,PPU,CORE,CCL (32.68' OAL) (((START TICKET @ 9:00)))
09:00
10:54
1.90
PT W/ GAS TO 100. RIH WI 2.19" CENT, S-BLR, CORRELATE TO TBG DETAIL 10/16/01, CCL TO BTM- 5', TAG @ 6000'
SUM (6043' RKB) + 5'= 6005' SUM (6048' RKB), POOH.
10:54
11:24
0.50
BLEED OFF GAS CAP, RU LRS, PT TO 2500. INSTALL DHD CALIBRATED GAUGES ON TBG / IA.
11:24
12:54 . -,
1.50
MITT TO 2000 (STATE WITNESS JEFF JONES)
PRE TI1= 140/0. PSI UP wl 0.5 BBLS
START= 2000/0
15 MIN= 1910/0
30 MIN= 1880/0 **PASS** BLEED BACK 0.5 BBLS.
OOH w/ CEMENT IN BLR. STATE INS. WANTS ANOTHER SAMPLE. MU TOOLS, CHANGE 2" TS=
RLR,5',5',5',RLR,OJ,KJ,LSS (33.33' DAL).
12:54
14:36` ,..
1.70
PT W/ GAS TO 200. RIH W/ 2.19" CENT, 5'x 1.75" DD BLR (MULE / BALL) TO TAG @ 6010' SLM (6053' RKB), WORK
TOOLS DOWN TO 6065' SLM (6108' RKB), NOT MAKING ANY HOLE, POOH W/ FOAM BALL & HARD CEMENT. MU
TBG PUNCH.
1436
15:42
1.10
PT QTS TO 500. RIH W/2" x 4' TBG PUNCH, 4spf, 0° PHASING, CORRELATE TO TBG DETAIL 10/16101. PSI TBG TO
1150. SHOOT TBG PUNCH f/ 6010' TO 6014' RKB, CCL TO TOP SHOT- 12.3', CCL STOP DEPTH- 5997.71. AFTER
Y
SHOOTING TBGIIA= 150/40 PSI, POOH.
15:42
16:00
0.30
PUMP 6 BBL (PER CO REP) @ 28PM, 750 TBG, 10 IA. RD LRS.
16:00
17:18
1.30
(((END TICKET @ 16:00))) RDMO, FUSIBLE REMOVED, INSPECT AREA, PJSM, NOTIFY DSO OF WELL STATUS AND
DEPARTURE.
17:18
18:00
0.70
IDROP EQUIP @ KIC FOR MAINT. TRVL TO CAMP, DOWNLOAD, PAPERWORK.
Well Fluids
Fluid To (bbl) I From (W) Nprsrecov (DDI)
Nate
DIESEL
- 5j -. TBG
Discharges
Disrl, Type
Oil SheM9 Material NOW
Safety Incidents
Date I
Type
Subtype Com
Page 111 ReportPrinted: 5/20/2019
4h
Well Service Daily Summary - No Costs
1C-125 Job: ABANDONMENT
Report Date: 9/30/2018
Rig: SLB CEMENT CMT
Job: ABANDONMENT
Actual Start Date
8/17/2018
Entl Data
4/9/2019
Objective
Expense Special
AFE I RFE / Maint#
10410208
Rig: SLB CEMENT CMT
Rig Accept Date
9/30/201806:00
Rig Release Date
9/30201813:00
Rig Supemisor
BESSETTE, PAUL,Wells Supervi_
Comment
Daily Operations
Report Start Date
9/30/201806:00
Report End Date
9/30201813:00
General Remarks
INITIAL T/1=0/0
FINAL T/1=0
Last 24hr Summary
PUMPED 105 BELS 15.8 PPG CLASS -G CEMENT DOWN TUBING TAKING RETURNS UP I/A, FREEZE PROTECTED WITH 8 BBLS DIESEL. SLICKLINE TO
TAG IN 24HRS.
Report Contacts
Supervisor I Tab
Compam/
MURPHY.Pumping Supervisor Pumping Supervisor
SLB
Time Log
Stan Tme
I Endr..
Our (hr)
Operation
06:00
09:00
1000
09:00
10:00
13:00
3.00
1.00
3.00
MIRU, HOLD SAFETY MEETING, PRESSURE TEST TO 4500 PSI
ONLINE WITH CEMENT, 2 BPM WHP=360, INCREASE TO 4.8 BPM WHP=1050, 10 BBLS AWAY, STILL NO TRNTS TO
TANK, PRESSURE IS NOT INCREASING, CONTINUE PUMPING, NO RTNS TO TANKS, 150 PSI ON I/A, RELIZE
HARDLINE IS FROZE, DECREASE RATE TO 2.8 BPM, WHP=432, CONTINUE TO PUMP CEMENT, I/A RTNS GOING IN
CASING LEAK, I/A PRESSURE NEAR 0, PUMP CMT AWAY AS PLANNED, CHASE WITH 2 BBLS F/W AND 8 BBLS
DIESEL, WHP BLEED OFF QUICK WHEN SHUT DOWN, HOOK UP U -TUBE HOSE JUST IN CASE, NO FLOW.
RDMO
Well Fluids
Fluid I T. (boll
I From (bbl)
I Nor-recov(bbl) Nob
Discharges
Disch Type
011 Sheen?
Material
Nob
Safety Incidents
Date
Type
Subtype
Com
Page 1/1 Report Printed: 51202019
Well Service Daily Summary - No Costs
1C-126 Job: ABANDONMENT
Report Date: 10/2/2018
Rig: HES SLICK LINE 760
Job: ABANDONMENT
Actual Start Date
End Date
Objective
AFE / RFE / Malm.e
8/17/2018
4/9/2019
Expense Special
10410208
Rig: HES SLICK LINE 760
Rig Accept Date
Rig Release Date
Rig Supervisor
Comment
10/2/2018 06:00
10/2/201812:00
FERGUSON, SID,Wells Supervisor J_
IM11111111111ii=
Daily Operations
Report Start Date
Report End Date
General Remarks
10/2/2018 06:00
10/2/2018 12:00
INITIAL TA=0/50
FINAL TA=0/50
Last 24hr Summary
***PRE STATE WITNESSED—DRIFT W/ 2"x5' DD-BLR TAGGED TOP OF CEMENT @ 1030' RKB. RECOVED GOOD SAMPLE OF CEMENT. MIT-T 1500
PSI. READY FOR STATE WITNESS.
Report Contacts
Supervisor
Tilde I cempmry
ORGAN, JOSHUA,Siickline Supervisor "
SlickIme Supervisor IMES
Time Log
Stan Time
End Time
Der (hr)
Operate,
06:00
06:45
0.75
PU WELL FILE & CPU. CONTACT DSO, TRAVEL TO LOC.
06:45
08:15
1.50
ARRIVE & INSPECT LOC. PJSM, SIM-OPS W/ ZIEBEL, MIRU. A25" WIRE, 2.125" TS=5', KJ, 51, OJ, KJLSS (26' OAL)
(START TIME @ 08:00)
08:15
09:00
0.75
PT W/ LRS (2500) RIH W/ 2.48" CENT, 2" X 5' DD-BLR (MSFB) TAGGED @ 989' SLM, WORK DOWN TO 992' SLM 1030'
RKB... POOH, OOH RECOVED GOOD CEMENT SAMPLE. CONFER W/ CWG
09:00
10:15
1.25
LRS PREFORMED MIT-T TO 1500 PSI
PRE MIT-T TA=200/50 INTITIAL TA=1550/50 15 MIN T/I=1400/50 (FAIL)TOOK.15 BBLS TO PRESSURE UP
RESTART
PRE MIT-T TA=1400/50 INITIAL TA=1550/50 15 MIN TA=1500/50 30 MIN T/1=1490/50 (PASS)
GOT BACK .15 BBLS
BLED DOWN TO T11=0/50.
10:15
11:15-7
1.00
PJSM. RDMO, WORK AREA SECURE. NOTIFIED DSO (END TIME @ 12:00)
11:15
112:00
0.75
MOVE TO IG-13
Well Fluids
Fluid To (bbp
From(W)
Non-recov(bbl) Note
Discharges
NEW— mmw_—
Disch Type
OII Sheen?
makmal
Note
Safety Incidents
Date
Type
subtype
Com
Page 111 Report Printed: 5/20/2019
Well Service Daily Summary - No Costs
1C-125
Job: ABANDONMENT
Report Date: 10/7/2018
Rig: HES SLICK LINE 772
Job: ABANDONMENT
Actual Start Date
End DateObjective
AFE / RFE / Malnt
8/17/2018
4/9/2019
Expense Specf
10410208
Rig: HES SLICK LINE
772
Rig Accept Date
Rig Release Date
Rig Supervisor
Comment
10/7/201806:00
10!7/201812:00
FERGUSON, SID,Welis Supervisor
Daily Operations
Report Start Date
Report End Date
General Remarks
10/7/2018 06:00
1077/2018 12:00
INITIAL T/1= 142/50
FINAL TA= 142/50
Last 24hr Summary
TAG TOP OF CEMENT @ 990' RKB. PERFORM PASSING STATE WITNESS MITT TO 1500 PSI. READY FOR E -LINE.
Report Contacts
Supervisor Tilb
Company
GOMEZ, JONATHAN,Slickfine Operator Slickline Operator
IHES
Time Log
Start Time
Entl Time
our(no
Openukn
0600
06:30
0.50
PU WELL FILE CONFER w/ CAPI REP. TRVL TO 1L
06:30
07:00
0.50
•`• START TICKET @ 07:00 `•• RIG DOWN EQUIPMNET. TO TRVL TO 1C-125
07:00
07:300.50
TRVL TO 11-125
07:30
08:15
0.75
RU .108 WIRE 1.875" TS= RS,5',KJ,5',KJ,5',OJ,KJ,LSS (OAL=32' )
08:15
09:30
1.25
PT w7 LRS. RIH w/ 2" 5' DDB. WAIT ON STATE TESTER. TAG @ 990' SLM . TAP DOWN 10 TIMES. POOH. SIBO.
09:30
11:30;
-
2.00
PERFORM MITT TO 1500 PSI '* PASS
PRE MIT T11= 142/50
INITIAL TA= 1550/50
15 MIN T11= 14 9515 0
30 MIN T/1= 1490150
CLEAN AND INSPECT AREA. CONTACT DSO. NOTIFY OF WELL CONDITION AND DEPARTURE.
11:30
12:00
0.50
•`• END TICKET @ 12:00 •`• TRVL TO 1C-15
Well Fluids
FMid
T. (bbp Fmm (bbb Non,mwv (bbQ
Ndf
Discharges
Dlsch Type
Oil Sheen? Material
Note
Safety Incidents
Date
Type
I Subtype
Cam
Page 111
Report Printed: 5 /2 012 01 9
Well Service Daily Summary - No Costs
1C-125 Job: ABANDONMENT
Report Date: 10/10/2018
Rig: SLB ELECTRIC LINE 2320
Job: ABANDONMENT
Actual Start Date
End Dale
Objective
AFE I RFE / Malnt.#
8/17/2018
4/9/2019
Expense Special
10410208
Rig: SLB ELECTRIC LINE 2320
Rig Accept Date
Rig Release Date
Rig Supervisor -
10/10/2018 05:30
10/10/2018 20:15
1CONDIO, JOHN, Wells Supervisor -'
Daily Operations
Report Start Date
Report End Date
General Remarks
10/10/2018 05:30
10/10/2018 20:15
INITIAL: TA 0/0
FINAL: T8 0/50
Last 24hr Summary
RAN SCMT LOG, FOUND TOP OF CEMENT AT 640' IN IA. TAGGED TOC AT 1026' IN TUBING, PERFORATED TUBING AT 625'- 630' WITH 1.56" X 5'
TUBING PUNCH, 4 SPF, FIRED GUN WITH 1000 PSI ON TUBING, 5 PSI ON IA. TUBING WENT TO 0 PSI, IA INCREASED TO 20 PSI. LRS PUMPED 25
BBLS OF DIESEL AT 2
BPM, NO RETURNS TO SURFACE. CCL STOP DEPTH= 619.33', CORRELATE TO GR ON SPERRY LWD DUAL GR 13-FEB-2012
Report Contacts
Supervisor Title I Company
FERREIRA, TYRONE,E-line Eni I E-line Engineer ISLB
Time Log
Sian nme
End Time
Dur (hr)
opereaee
05:30
06:30
1.00
MEETING WITH WSL. DEPART KOC AND DRIVE TO 1C-125.
0630
09:00
2.50
SPOT SUPPORT EQUIPMENT, STACK PCE, BUILD HEAD, MAKE UP TOOL, PERFORM SURFACE CHECKS. STAB
AND PT.
09:00
12:00
3.00
SWAB OPEN. RIH WITH HEAD/EQF/PBMS/SCMT, DAL = 40', OAW = 240LBS, MAX OD = 1.688". TAGGED 1026' RKB.
PERFORM MAIN PASS FROM 1016'-SURFACE. PERFORM REPEAT PASS FROM 249'-SURFACE. POOH.
12:00
13:00
1.00
GET GUN READY.
13:00
14:00
1.00
RIH WITH 1.56"X5' TUBING PUNCHER 4SPF.
1400
16:00
2.00
WAITING ON WSLIINTEGRITY ENGINEER TO CONFIRM SHOOTING DEPTH.
16:00
18:00.
2.00
TROUBLESHOOT MAXWELL OPERATING SOFTWARE/TELEMETRY ISSUES.
CCL TO TOP SHOT = 5.67'. CCL TO BOTTOM SHOT = 10.67'. CCL TO BOTTOM = 14'. PERFORATED INTERVAL 625'-
630'. CCL STOP DEPTH = 619.33'. FIRED GUN WITH 1000 PSI ON THE TUBING. GUN FIRED WITH GOOD
INDICATION.
1800
18:30
0.50
LRS RU TO IA, PUMPED 25 BBLS OF DIESEL AT 2 BPM AT 280 PSI AGAINST CLOSED VALVE TO TANK. IA AT 140
PSI, WOULD NOT PRESSURE UP. UNABLE TO GET DIESEL TO SURFACE.
18:30
20:00
1.50
SWAB CLOSED. RIG DOWN.
20:00
20:15
0.25
1 DEPART 1C PAD AND DRIVE TO KOC.
Well Fluids
Fluid Tc (Wo
I Fmm(bbi)
Norvrecov(bbl) Nole
Discharges
Msch Type
Oil SM1eenO
Material
N&O
Safety Incidents
Date
Type
Subtype
Com
Page 111 ReportPrinted: 5/20/2019
Well Service Daily Summary - No Costs
1C-125 Job: ABANDONMENT
Report Date: 11/5/2018
Rig: SLB PUMPING MISC
Job: ABANDONMENT
Actual Start Date
End Date
Objective
AFE I RFE / Malnt.#
8/17/2018
4/9/2019
Expense Special
10410208
Rig: SLB PUMPING MISC
Rig Accept Date
Rig Release Dale
Rlg Supervisor
Comment
11/5/2018 08:00
11/5/2018 14:00
KENNEDY. CHRIS. Wells Supervisor
Daily Operations
Report Stan Date
Report End Date
General Remarks
11/5/2018 08:00
11/5/2018 14:00
INITIAL TH=O/0
FINAL T8=0/0
Last 24hr Summary
Performed final stage of fullbore cement P&A circulating 5 bbls Diesel, 5 bible FW, and 25 bbls of AS -1 cement down flog up IA. Verified good 15.7# cement at
surface prior to shutdown. In Progress.
Report Contacts
Supervisor
Tpb Comparry
COLE, DALE.Pump Supervisor
Pump Supervisor ISLB
Time Log
start Time
End T,me
Dur (hr)
opera .
0800
09:00
1.00
MIRU SLB CEMENTER&
09:00
09:51
0.85
CONDUCT PJSM. DISCUSS PLAN FORWARD.
09:51
10:00
0.15
PIT HARDLINE TO 500/3000 PSI.
10:00
10:09
0.15
ONLINE W/5 BBLS DIESEL @ 1.0 BPM DOWN TUBING, UP UI TAKING RTNS TO OT TANK. VERIFY -1:1 RTNS.
FOLLOW WITH 5 BBLS FW @ 1.0 BPM. WHTP=80 PSI, IA=O PSI.
10:09
10:24
0.25
BEGIN BATCHING 19 BBLS 15.7# AS -1 CEMENT.
10:24
10:30
0.10
ONLINE W/ 15.7# AS -1 CEMENT DOWN TUBING, UP IA TO OT @ 1.0 BPM, WHTP=50 PSI, IA=O PSI (PUSHING FLUID
W/ CHARGE PUMP ONLY).
10:30
10:45
0.25
10 BBLS CMT AWAY, APPEAR TO BE LOSING A BIT TO FORMATION.
10:45
11:00
0.25
19 BBLS CMT AWAY, SD AND BATCH 6 MORE BBLS CMT. WHTP=O, IA=O
1100
11:06
0.10
BACK ONLINE W/ CMT AT 1.0 BPM, WHTP=100 PSI, IA=O. 20 BBLS AWAY, CMT @ OT.
11:06
11:12
0.10
25 BBLS TOTAL CMT AWAY, PULL SAMPLE AT CHOKE AND SCALE. 15.7# ON THE NOSE.
11:12
14:00
2.80
FLUSH LINES. WASH UP EQUIPMENT, ROMO.
Well Fluids
Fluid I To (bbl)
From (bbg I Nonrecav (bbl)
Note
DIESEL
- 10.0
FRESH WATER
200.0
OTHER
25.0
Discharges
Disch Type
Oil Sheen9
Material
Note
Safety Incidents
Date
Type
Subtype
Com
Page 111 Report Printed: 5/2012019
Well Service Daily Summary - No Costs
1C-125 Job: ABANDONMENT
Report Date: 11/13/2018
Rig: AES WELL INTEGRITY DHD
Job: ABANDONMENT
Actual Start Date
End Date
Objective
AFE / RFE I Malm.#
8/17/2018
4/9/2019
Expense Special
10410208
Rig: AES WELL INTEGRITY DHD
Rig Accept Date
Rig Release Date
Rig Supervisor
Comment
11/13/2018 08:00
11/131201816:30
I SUMRALL. SHELBY.DHD Field Supervisor
Daily Operations
Report Start Date
Report End Dale
General Remarks
11/13/2018 08:00
11/132018 16:30
Initial T/I = siVac/Vac.
Final TA = si0/0.
Last 24hr Summary
DDT-T PASSED, DDT-IA PASSED, TOC-T Q 28', TOC-IA Q 36'.
Report Contacts
Supervisor I Teb
Company
MILLER, MATT.DHD Tech DHD Tech
AES
CAUDLE, BRANDON.DHD Tach DHD Tech
AES
Time Log
StartTme
End Tme
DurihQ
Operation
08:00
08:30
0.50
Travel from 1J-pad to lC-pad.
08:30
08:45
0.25
MIRU.
08:45
15:45
7.00
DDT-T Passed, DDT-IA Passed, TOC-T Q 28', TOC-IA @ 36.
Initial T/I = siVacA(ac. Flowline @ 2247 psi (no blind, triple blocked).
Stung into T PO w/ 10 psi, bled to 0 psi (gas/fluid) & held open for 15 min. Monitor for 15 min. T PO @ 0+ psi.
Stung into Gray lock Seal w/ 0 psi, held open for 15 min. Monitor for 15 min. Gray Lock @ 0 psi.
Bled T Vac to 0 psi in 10 sec, held open for 15 min.
Bled IA vac to 0 psi in 5 sec, held open for 15 min.
Starting TA = 0/0.
15 min TA = 010.
30 min TA = 0/0.
45 min TA = 0/0.
60 min TA = 0/0.
Strapped TOC-T @ 28'.
Removed IA flange, cleaned cement from IA casing valve. Pulled IA companion 2" nipple & VR plug (left VR plug out, re-
installed 2" nipple w/ alemite).
Strapped TOC-IA @ 36' (had sever difficulty getting anything to fall in IA, unable to get deeper then 36')
Final TA = si0/0.
15:45
16:00
0.25
RDMO.
16:00
16.30
0.50
Travel to 1Y-pad.
Well Fluids
Fluid
To (bbl)
From (bbl)
Noo-remy (bbl)
Note
Discharges
Dach Type
Oil Sneenp
Matenal
Note
Safety Incidents
Date
Type
Subtype
Com
Page 1/1 ReportPrinted: 5/20/2019
P&A WELL EVENTS SUMMARY
Date Well Event
4/8/2019 P&A: STATEMAN WITNESS CEMENT & MARKER PLATE, WELD PLATE - BACK FILL & REMOVE 10'X 16' PIPE - P&A COMPLETE
4/8/2019 P&A: FINISH EXCAVATING T014'AND REMOVE 10'3"'(4'+BELOW TUNDRA) OF WELL STUB(TOLAL WELL REMOVED= 13')
4/7/2019 P&A: EXCAVATE WITH TRIMMER T012'
P&A PREP IN PROGRESS. NES WELDERS REPAIRNG SHORING CAN. NES QC VT (VISUAL TESTING),KAKIVIK PERFORMING MT NDE
TESTING, CONFERRED WITH CWG. DECISION MADE TO POSTPONE 1C-125 P&A AND DEMOBE EQUIPMENT FOR HIGHER PRIORITY 3G-
3/26/2019 19A P&A JOB. WILL RETURN AFTER COMP
P&A PREP (IN PROGRESS) REPAIR PROCESS BEGAN, INSPECTION BY TUBOSCOPE FOR OTHER CRACKS IN PIPE MATERIAL. NES WELDER
3/25/2019 TO WELD DAMAGED AREAS THROUGHOUT THE NIGHT. KAKIVIK TO FOLLOW UP WITH WELD INSPECTIONS FOLLOWING REPAIRS.
P&A PREP (IN PROGRESS). COMPLETED REMOVAL OF CELLAR BOX. BEGAN INSTALLATION OF 10'x16' SHORE PIPE. VIBRATED TO—S',
3/24/2019 TARGET DEPTH OF 14'. (CAN BROKE AT THE END OF DAY. WILL RETURN IN AM TO ATTEMPT REPAIR.
P&A PREP (IN PROGRESS) POST STORM CLEANUP. ATTEMPTED REMOVING CELLAR BOX. NEEDED TO THAW CELLAR BOX FOR
3/23/2019 REMOVAL.
3/22/2019 P&A PREP (IN PROGRESS) CONTINUED DRILLING 2"PILOT HOLES INTO THE GROUND.
3/21/2019 P&A PREP (IN PROGRESS) CUT & REMOVED STAND PLATE, CONTINUED DRILLING 2"PILOT HOLES INTOTHE GROUND.
TO
3/20/2019 P&A PREP (IN PROGRESS)DRILLED 802"PILOT HOLES INTHE GROUND.
3/19/2019 P&A: CUT WELLHEAD OFF AND PREDRILL FOR 10' X 16' PIPE.
3/11/2019 (P&A): T CEMENTTOPJOB(COMPLETE), IA CEMENTTOP JOB (UNSUCCESSFUL).
11/13/2018 DDT -T PASSED, DDT -IA PASSED, TOC -T @ 28', TOC -IA @ 36'.
Performed final stage of fulibore cement P&A circulating 5 bbls Diesel, 5 bbls FW, and 25 bbls of A5-1 cement down tbg up IA.
11/5/2018 Verified good 15.7# cement at surface prior to shutdown. In Progress.
RAN SCMT LOG, FOUND TOP OF CEMENT AT 640' IN IA. TAGGED TOC AT 1026' IN TUBING. PERFORATED TUBING AT 625'- 630' WITH
1.56" X 5' TUBING PUNCH, 4 SPF, FIRED GUN WITH 1000 PSI ON TUBING, 5 PSI ON IA. TUBING WENT TOO PSI, IA INCREASED TO 20
10/10/2018 PSI. LRS PUM
10/7/2018 TAG TOP OF CEMENT @ 990' RKB. PERFORM PASSING STATE WITNESS MITT TO 1500 PSI. READY FOR E -LINE.
***PRE STATE WITNESSED* **DRIFT W/ 2"x5' OD-BLR TAGGED TOP OF CEMENT@1030' RKB. RECOVED GOOD SAMPLE OF CEMENT.
10/2/2018 MIT -T 1500 PSI. READY FOR STATE WITNESS.
PUMPED 105 BBLS 15.8 PPG CLASS -G CEMENT DOWN TUBING TAKING RETURNS UP I/A, FREEZE PROTECTED WITH 8 BBLS DIESEL.
9/30/2018 SUCKLINE TO TAG IN 24HRS.
STATE WITNESSED (JEFF JONES) TAG @ 6048' RKB & MITT TO 2000 (PASS). WORK 1.75" BAILER FROM 8053' TO 6108' RKB (RECOVER
FOAM BALL PIECES & HARD CEMENT). PUNCH HOLES FROM 6010'-6014' RKB WITH 2" x 4' TBG PUNCH, 4spf, 0" PHASING. PUMPED 6
9/22/2018 BBLS @ 2bpm 750 TBG
TBG & IA DDT (PASSED)
9/6/2018
9/5/2018 T-DDT(IN PROGRESS)
9/4/2018 TAGGED TOP OF CEMENT @ 6054' RKB. ATTEMPT TO MIT-TTO 1500 PSI (FAIL). UNABLE TO ESTABLISH LLR @ 3000 PSI. ATTEMPT DDT
9/1/2018 PUMPED 20 BBLS 15.8 CLASS G CEMENT FOR FIRST STAGE OF P&A, SQUEEZED 10 BELS THROUGH PERFS, TOC —6550 RKB, WELL IS
8/17/2018 DRIFTw/ 2.25" BUR & PULL HEX PLUG @ 6697'RKB. LRS CONDUCTED 30BBL INJECTIVITY TEST. 1 BPM @ 950 PSI, 2 BPM @ 1475 PSI.
SUNDRY NOTICE 10-407
ConocoPhillips Well 1C-125
Plug and Abandonment
April 12, 2019
ConocoPhillips Alaska, Inc. performed Plug and Abandonment operations on 1C-125,
commencing operations on August 17, 2018 and completing the Plug and Abandonment on April
10, 2019.
20 bbls of 15.8 Class "G" cement was pumped to place a plug from 7,700ft KB to 6,054ft KB.
Tubing was punched and 105 bbls of 15.8ppg Class "G" cement was placed in the tubing and
tubing x production annulus (IA). Cement was tagged at 1,030ft KB, and tubing punched for
circulation of the surface cement plug. 25bbls of 15.7 ppg Permafrost cement was then pumped
to place cement in the tubing and IA to bring cement to surface. The well was then excavated to
4 ft below original ground level, tree and wellhead removed, well capped, and excavation
backfilled.
Pictures below show cement to surface, marker plate installed, and final site condition after
backfill.
The field Well Service Report is attached.
----`'art
V
MEMORANDUM
State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Jim Regg Z" n 41jj I I`� DATE: 4/9/19
P. I. Supervisor '`�� 1
FROM: Austin McLeod SUBJECT: Surface Abandonment
Petroleum Inspector Kuparuk River Unit 1C-125
CPAI
PTD 201-199; Sundry 318-271
4/9/19: 1 traveled to KRU well 1C-125 to ensure all strings were cemented to surface
and the marker plate was proper, prior to CPAI welding the plate to the 16 -inch
conductor and burying the well. Once on location I met with Roger Winter to look over
the cut off well. Appearing to be approximately 5-6 feet below tundra grade, Roger
verified this, and informed me it was cut at least 4 feet below grade. All strings were
cemented to surface. I tested the integrity of the cement with several good licks with a
5 -foot bar. I did find a somewhat soft spot on the IA portion (3-1/2" x 5-1/2" annulus) and
was able make approximately 4 inches before I found good hard cement. This spot was
poured the previous day to completely top off the cement. Regardless, they refilled the
small void with cement. I found no other issues and informed them they could weld the
plate on and bury the well.
Attachments: Pictures
2019-0409_Surface_Abandon_KRU_1C-125_am.docx
Pagel of 3
Incomplete cement to
surface in tubing -casing
annulus
2019-0409_Surface_Abandon_KRU_1C-125_am.docx
Page 3 of 3
S
•
Wallace, Chris D (DOA)
From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com>
Sent: Tuesday, April 10, 2018 5:04 PM
To: Wallace, Chris D (DOA)
Cc: Senden, R.Tyler
Subject: KRU 1C-125 (PTD 201-199) Report of failed MITIA
Attachments: 1C-125.pdf'1C-125 90 day TIO trend 4-10-18.JPG
Chris,
. Thewell has been shut in and
KRU West Sak water injector 1C 125(PTD 201 199 failed a diagnostic MITIA toda e
) g Y
Slickline is currently prepping the well to be secured. Once the well has been secured further diagnostics will be
performed to determine the leak location. The well will remain shut in until a plan for corrective action or return to
injection has been developed at which time any necessary paperwork will be submitted. A 90 day TIO and wellbore
schematic are attached.
Please let us know if you disagree or have any questions with this plan.
Regards,
Jan Byrne/Kelly Lyons
Well Integrity Supervisor
ConocoPhillips Alaska, Inc.
Office phone: (907)659-7224 .., . ,�iptELLS TEAM
conocalphotps1
e
SEAN PARNELL, GOVERNOR
ALASKA OIL AND (;SAS 333 W. 7th AVENUE, SUITE 100
CONSERQATION COl►IMISSION ANCHORAGE, ALASKA 99501 -3539
PHONE (907) 279 -1433
FAX (907) 276 -7542
John W. Peirce
Wells Engineer'
ConocoPhillips Alaska, Inc.
PO Box 100360
Anchorage, AK 99510
Re: Kuparuk River Field, West Sak Oil Pool, 1 C -125
Sundry Number: 310 -384
Dear Mr. Peirce:
Enclosed is the approved Application for Sundry Approval relating to the above
referenced well. Please note the conditions of approval set out in the enclosed
form.
As provided in AS 31.05.080, within 20 days after written notice of this
decision, or such further time as the Commission grants for good cause shown,
a person affected by it may file with the Commission an application for
reconsideration. A request for reconsideration is considered timely if it is
received by 4:30 PM on the 23rd day following the date of this letter, or the
next working day if the 23rd day falls on a holiday or weekend.
Sincerer
Jo K. Nor an
sioner
DATED this d day of November, 2010.
Encl.
STATE OF ALASKA U
ALASOIL AND GAS CONSERVATION COMMA 1+ ,16
• APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
1. Type of Request: Abandon "` Rug for Redrill Perforate New Pool r Repair w ell r Change Approved Program
Suspend r Rug Perforations Perforate r Pull Tubing Time Extension
Operational Shutdown Re -enter Susp. Well r Stimulate r" After casing
Other: Wax Job �"
2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number:
ConocoPhillips Alaska, Inc. Development Exploratory 201 -199
3. Address: 6. API Number:
Stratgraphic �"` Service ;r ,
P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 23044 - 00
7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number:
where ownership or landownership changes:
Spacing Exception Required? Yes No 1C -125 -
9. Property Designation (Lease Number): 10. Field / Pool(s):
ADL 25650,'25649 ' I Kuparuk River Field /West Sak Oil Pool
11. PRESENT WELL CONDITION SUMMARY
Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured):
7725 • 4142 7636' 4092' 7703'
Casing Length Size MD TVD Burst Collapse
CONDUCTOR 120 16 158' 158'
SURFACE 6626 5.5 6664' 3585'
PRODUCTION 1036 3.5 7700' 4128'
Perforation Depth MD ( 6742' - 6800', 6858' - 6904', Perforation Depth ND (ft): 3628' - 3657', 3686- 3708', Tubing Size: Tubing Grade: Tubing MD (ft):
954'- 6970', 6990'- 7000', 7042'- 7058', 7078'- 7138', 8 3733'- 3740', 3750'- 3755', 3776'- 3783', 3793' - 3823', 3.5 L -80 6661
7204' -7248' MD and 3858' -3880 Packers and SSSV MD (ft) and TVD (ft)
Packers and SSSV Type: no packer
no SSSV
12. Attachments: Description Summary of Proposal jv 13. Well Class after proposed work:
Detailed Operations Program r BOP Sketch Exploratory r Development Service
14. Estimated Date for Commencing Operations: 15. Well Status after proposed work:
11/29/2010 Oil r Gas �` WDSPL F Suspended r
16. Verbal Approval: Date: WINJ W • GINJ r' WAG F Abandoned J
Commission Representative: GSTOR SPLUG
17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John W. Peirce @ 265 -6471
Printed Name John W. Peirce Title: Wells Engineer ,J
Signature w Phone: 265 -6471 Date
Commission nl
Sundry Number:511) -5N
Conditions of approval: Notify Commission so that a representative may witness
Plug Integrity r" BOPTest r" Mechanical Integrity Test Location Clearance r1M
i !k
Other:
�_' ( ��qq 01 g� 0 �..qq
Subsequent Form Required:
jdw ! ll
a pail Cal Gat O�i�s!(tlt�iabJi 10
Astchomp
APPROVED BY
A roved by: MMISSIONER THE COMMISSION Date:
Form 10 -403 Re ./d Submit in Duplicate
ORIGINAL. , j���
'_
I C -125
Wax Squeeze of Matrix Bypass Event B
Proposal / Objective:
1C -125 is a deviated cased, cemented, and perforated injector completed in 2001 as a 3.5"
monbore in West Sak A, B, and D sands. An MBE initially occurred 12/26/04 in the B sand with
breakthrough to 1C -104 producer. In 2005, a patch was set across the B sand perfs to isolate
the MBE, but the MBE reappeared in 2007. A 12/1/07 IPROF sh owed the MBE ta kin g all PWI
a t 6990 - 7000' RKB in the upper A4 interval.
- —_ = --
The A4 MBE may be in communication with the initial B sand MBE behind casing. The patch
across the B sand MBE was pulled, and a composite plug was set 2/12/08 at 6988' RKB to
isolate lower A4, A3, and A2 perfs. On 3/18/08, a cement retainer was set at 6840' RKB
between the D and B sand perfs, and 16 bbls of cement was pumped through the retainer to
squeeze the A4 and B sands. Subsequent coil milling removed wellbore cement, the retainer
and the composite plug. A 615108 1PRnF chows the A4 at 6990 - 7000' RKB s taking all PWI�
It is proposed 1 C -125 be squeezed to wax fill the MBE path to 1 C -104. A total of 10 to 15 bbls
of wax will be pumped down coil tubing to squeeze off all of the perforation intervals. Following
a successful wax squeeze, 1C-125 will be reperforated in the D sand and lower A sands.
Reperforating of the A4 or B sands will depend on post- squeeze evaluation results.
Procedure:
Active -Coil
1) RIH with Active -Coil and park the nozzle at the A4 perfs at 6990' RKB. Perform a thermal
test by circulating 180 ° F Seawater down coil tubing and up the coil x tubing annulus at 0.5, 1.0,
and 1.5 bpm to record real -time BHT vs. time over an 8 hour period. If thermal testing indicates
it is possible to achieve a BHT of at least 115 ° F within 8 hours of circulation, POOH with CT and
plan to perform a wax squeeze the following day (per step #2 below), else terminate plans to
pump a wax squeeze.
2) RIH with Active -Coil and park wax nozzle at MBE at 6990' RKB. Circulate 180 °F Seawater
until real -time BHT exceeds 115 ° F while melting 10 - 15 bbls of low melting point wax with wax
hardener additive to 180 ° F in the wax heating tank. Pump all of the molten wax down CT at 1.5
bpm while taking returns up the CT x tubing annulus until the wax plug has been displaced to
the nozzle with 180F seawater, then shut -in backside of coil and bullhead the wax slug into the
MBE at maximum rates attainable below fracture gradient. As soon as the last barrel of wax
exits the nozzle, shut down all pumping and hold pressure. Monitor temperature cool down at
MBE. POOH with CT. RD.
3) Wait 5 - 7 days for wax in MBE to harden and cure.
4) Pressure test 1C -125 wax job to determine if wax plug has sealed the MBE. If PT looks good, ✓
decision plans to run an injection profile log and /or reperforate zones.
_ K UP 0 1 C-1 25
ributes Max Angle & MD _TD
Conoc oPhilfip5 t _ - _ -
{n4 Wellbore APVUWI Field Name Well Status Inc/ ( (ftK6) Act B (ftKB)
500292304400 WEST SAK (INJECTING 69.78 I MD 2,28602 7725.0
C e t H25 (ppm) Dab Annotation (End Date KB - Grd (ft) Rig Release Dale
-- Well conng 1c - i 239na orn 23920 PM �m= SSSV NONE 0 6/18(2006 LastWO: 4564 10/16/2001
Schematic Actual A obtion (Depth (ftKB) End Date Annotation Last Mod By End Data
Last Tag: SLM L 7,196 0 7!7/2009 Rev Reason: Remove Plug /Packer Imosbor 911
Casing Strip s
String OD String ID Set Depth Set Depth (TVD) String Wt String
Ca sina D escryrtion (i n) (in) ^...- ,TOp (ftKB) (ftKB) (ftKB) _ (IbstR) Grade String Top Third
_ CONDUCTOR - 16 15.062 - 380 - 158.0 158.0 68.00
PRODUCTION 51/2 __ !.9 � 501 0.0 6,664.0 3,585.3 15.50 L-80 BTCM
- �_
,.' LINER 31/2 Z_ 6,664.0 7,700.0 4,128 2 9.30 L-80 EUESrdMod - -
CONDUCTOR, _ 1-
158 } Tubing Strings
String OD String ID Set Depth Set Depth (TVD) String Wt String
( Tubing Description (in) (in) Top(ftK B) (ftKB) (ftKB) '.b..) G.de strip Top Thm
TUBING 3 112 2 992 00 6,661 0 3,583.6 9.30 L-8o EUE8rdMod
GASLIFT.- ther In Hole (All Jewelry: Tubing Run & Retrievable, Fish, etc.)
6,567
Top Depth:
TVD) I Top Inc/
T (ftKB (ftKB) ( "1 Description Comment Run Dab ID (In)
6,567 3,541.9 63.01 GAS LIFT CAMCO /KBG- 2- 9 /1/DMYANTII1 Comment: STA 1 10116/2001 k4.00O
6,610 3,561.8 62.05 NIPPLE CAMCO 2.81 "'DS' NIPPLE W/NO GO PROFILE 10/1612001
NIPPLE,6,619 - - - - -- -� -� --
-- - - - - -- 6,648 3,576.1 56.44 SEAL BAKER 8040 GBH - SEAL ASSEMBLY W/LOCATOR 10/16(2001
SUB
6,653 3,579.0 56.56 SBE BAKER SSE 10/16/2001 6,863 3,69 6028 MARKER JNT 10!16/2001 87 SEAL, 6,646- _ 7,703 4,129.9 55.47 FISH ROLLER .25" X 2 6" ROLLER WHEEL LOST IN HOLE 11/25/2001
-- - PUSHED TO BOTTOM BY SUCKUNE
shot
Top (M) Stm(TVD) Dens
T RKB Btm ftK6 /ft( 1ftK61 Zone Dab (sh.° Commerd
SBE, 6,853 6,742 6,780 3,627.5 3,646.8 WS D, 1C-125 1212812001 4.0 IPERF 2.5" HSD SH Chg, 60 deg ph
-- 6,780 6,800 3,646.8 3,657.1 WS D, 10-125 12/19/2001 4.0 IPERF 2.5" HSD BH Chg, 60 deg ph
6,858 6,904 3,685.4 3,708.3 WS B, 1C -125 12/14/2001 4.0 IPERF 2S" HSD BH Chg, 60 deg ph
6,954 6,970 3j 3,740.4 WSA4, 1C -125 12/14/2001 4.0 IPERF 2.5" HSD SH Chg, 60 deg ph
6,990 7,000 - 3,750.1 3,754.9 WS A4, 1C -125 12/1212001 4.0 IPERF 2.5" HSD BH Chg, 60 deg ph
PRODUCTION, 7,042 - 7,058 - 3,775.7 3,783.3 WS A3, 1C -125 12/12/2001 4.0 IPERF 2.5" HSD BH Chg, 60 deg ph
6,664
7,078 7,138 3,792.9 3,822.7 WS A3, 1C -125 11124/2001 4.0 IPERF 2.5" HSD BH Chg, 60 deg ph
7,204 7,248 3,857.5 3,880 -1 WS A2, 1C -125 1123/2001 4 0 IPERF 2.5" HSD BH Chg, 60 deg ph
IPERF,_ -__ Notes: General & Safety
6,742 - 6,780 I
End Date I}+ Annotaton
11/252001 _ .25 "" X26 ROLLER WHEEL LOST IN HOLE PUSHED TO BOTTOM BY SLICKLINE
IPERF, ....
6,780.6,800
MARKER JNT, _
6,863
IPERF, 4 7
6,858-6,904 �J
IPERF, A4,
6,954 -6,970
IPERF, _ J r q
6,990 -7,000
IPERF,, _ R
7,042 -7,058
IPERF, A 3
7.078 -7,138
PE / .
],204 -],248 {{{���
LINER, 7,700
FISH, 7,703 -�
TD, 7,725
MEMORANDUM •
To: Jim Regg ~
P.I. Supervisor ~~~~ ~ ~~ (~ ~
FROM: John Crisp
Petroleum Inspector
State of Alaska •
Alaska Oil and Gas Conservation Commission
DATE: Tuesday, June 08, 2010
SUBJECT: Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA INC
1 C-125
KUPARUK RIV U WSAK 1C-125
Src: Inspector
NON-CONFIDENTIAL
Reviewed By:
~~
P.I. Suprv~
Comm
Well Name: KUPARUK RIV U WSAK 1C-125 API Well Number: 50-029-23044-00-00 Inspector Name: John Crisp
Insp Num: mitJCr100523173619 Permit Number: 201-199-0 Inspection Date: 5/21/2010
Rel Insp Num:
Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
1C-125 i '~ 3581 ~ IA
Well Type Inj. N ~ TVD ~
P.T.D 2011990 iTypeTest SPT ,Test psi ls~o ~I OA 0 __
_
__ 2220 2160 2150
_
~ Tllbin
Interval aYRTST p~F P g 1280 ~
~ 1300 1300 1300
_ __
_~
Notes: 2,1 bbls pumped for test. Monobore injector. No problems witnessed.
M r
Tuesday, June 08, 2010 Page 1 of ]
• STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
~~:..
s~~ ~ o zoos
REPORT OF SUNDRY WELL OPERATA$)i~ ~ Cr= ~ ~la~~. Cui~?s;~i,~il~~
1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations Q Stimulate ^ O ' ~'~~;~'~~~~
Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^
Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^
2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number:
COnocoPhilllps Alaska, InC. Development ^ Exploratory ^ 201-199 /
3. Address: Stratigraphic ^ Service ~ 6. API Number: ,
P. O. Box 100360, Anchorage, Alaska 99510 50-029-23044-00
7. KB Elevation (ft): 9. Well Name and Number:
RKB 38' 1 C-125
8. Property Designation: 10. Field/Pool(s):
ADL 25650~8~ 25649 Kuparuk River Field /West Sak Oil Pool
11. Present Well Condition Summary:
Total Depth measured 7725' feet
true vertical 4142' feet Plugs (measured) 6988'
Effective Depth measured 7636' feet Junk (measured) 7700', 7703'
true vertical 4092' feet
Casing Length Size MD TVD Burst Collapse
Structural
CONDUCTOR 120' 16" 158' ' 158'
SURFACE 6626' 5-1/2" 6664' r,~ ~D~ ~'~~ ~' ;
~ ~~~~
PRODUCTION 1036' 3-1/2" 7700' 4128'
Perforation depth: Measured depth: 6742'-6800', 6858'-6904', 6954'-6970', 6990'-7000', 7042'-7058', 7078'-7138', 7204'-7248'
true vertical depth: 3627'-3657', 3685'-3708', 3733'-3740', 3750'-3755', 3776'-3783', 3793'-3823', 3858'-3880'
Tubing (size, grade, and measured depth) 3-1/2" , L-80, 6661' MD.
Packers &SSSV (type Zk measured depth) HES E z pk ssao' ~{~ S~ ~ ~ ~U~O~,~
no SSSV
12. Stimulation or cement squeeze summary:
Intervals treated (measured) attempted water shut-off of '8' sand matrix by-pass event, treatment was not successful. see attached summary
Treatment descriptions including volumes used and final pressure :
13. Representative Daily Average Production or Injeption Data
Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure
Prior to well operation 368
Subsequent to operation Shut-in --
14. Attachments 15. Well Class after work:
Copies of Logs and Surveys run - Exploratory ^ Development ^ Service 0 '
Daily Report of Well Operations _X 16. Well Status after work:
Oil^ Gas^ WAG^ GINJ^ WINJ Q WDSPL^
17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt:
none
contact Randy Kanady @ 263-4126
Printed Name ndy Kanady Title Drilling Engineer
~~
Signature Phone: 263-4126 ~_ ~ `~
Date
Pre ared b Sharon All u Drake 263-4612
U
Form 10-404 Revised 04/2006
~ y'~~.aB
Submit Origina Or~y~~D~
• 1C-125 Well Events Summary •
DATE SUMMARY
12/1/07 WELL INJECTING AT 800 BWPD, 50 PSI, 145 DEGF. ALL FLUID SEEN EXITING CASING
HROUGH PERFS AT 6990'-7000'. SHUT IN WELL AND CHECKED FOR CROSS FLOW.
FROM UP DOWN OVERLAY IT APPEARED THAT FLUID WAS MOVING FROM A2/A3
SANDS INTO PERFS AT 6990'-7000_'. WELL LEFT SHUT IN LRS TO FP W/ 25 BBL 60/40
MEOH, 5 BBL MEOH FL.
12/27/07 TAGGED TD @ 7515' SLM. OBTAINED SBHPS W/ DUEL PANEX GAUGES @ 6954' RKB
(1666 PSI) AND 6760' RKB (1623 PSI) PULLED ECLIPSE PACKER W/ STINGER
ASSEMBLY @ 6851' RKB. PULLED SLICK STICK RECEPTICLE, SPACER PIPE, AND
SNAP LATCH ASSEMBLY @ 6881' RKB. (( IN PROGRESS ))
12/28/07 FISHED ELEMENT FROM UPPER ECLIPSE PACKER. PULLED LOWER ECLIPSE
PACKER @ 6909' RKB. OBTAINED SBHPS W/ DUEL PANEX GAUGES @ 6851' RKB
(1646 PSI @ 75 DEG F) AND 6657' RKB (1605 PSI @ 73 DEG F) DRIFTED DOWN TO
7500' SLM W/ 2.80 CENT.
2/11/08 BRUSHED AND FLUSHED TUBING THOROUGHLY FROM 6800' TO 7000' SLM. RUN 12'
x 2.75" DRIFT TO 7200' SLM. READY FOR E/L SET RETAINER.
2/12/08 SET HES 3-1/2" FASDRILL BRIDGE PLUG AT 6988.1', PLUG BECAME STUCK DURING
CORRELATION PASS AND HAD TO SET IT TO COME FREE, SET HES 3-1/2" EZ DRILL
SVB S UEEZE PA KER AT 6840'
3/16/08 Attempt Thermatek treatment. Unable to sting into cement retainer @ 6827 CTMD. Will
restart in A.M. with different BHA.
3/17/08 Thermatek MBE project. Confirmed stinger entry in retainer, Experiencing communication
through perfs or cement retainer. Will return in A.M. to continue diagnostic stages.
3/18/08 PUMPED TWO 20 BBL HALLIBURTON K-MAX GEL PILLS TO CONFIRM MBE SIZE AT 8.5
BBLS. MIX AND PUMPED TOTAL OF 16 BBLS THERMATEK 15 BBLS BELOW RETAINER
ONE BBL ABOVE @ 1 BPM WHP 240 PSI CP 3900 PSI WITH 1C-104 PRODUCER SHUT
IN. SHUT DOWN PUMP AND DISENGAGE CEMENT RETAINER. FREEZE PROTECT
WELL WITH DIESEL TO 2000'MD WHILE POOH. NOTIFIED DSO OF WELL STATUS.
3/28/08 MU AND RIH WITH A 2.80" FIVE BLADE MILL AND MILL FROM 6447' CTMD TO 6535'
CTMD.POOH TO CHECK MILL AND FOUND HEAVY WEAR MARKS ON SIDE OF
MILL.SEEN VERY LITTLE WEAR ON BOTTOM OF MILL.RIH WITH 2.75" MILL AND TAG
@ 6320' CTMD AND WAS UNABLE REACH LAST TAG DEPTH.POOH TO REGROUP AND
RESTOCK FLUIDS.JOB INCOMPLETE.
3/29/08 RIH WITH VENTURI BASKET AND CLEAN DOWN TO HARD TAG @ 6535' CTMD,
RECIPROCATE ACROSS HARD TAG AND POOH.FOUND 1/2 GALLON OF FILL FROM
CEMENT JOB.MU AND RIH WITH A 2.25" NOZZLE AND~LEAN DOWN TO 6540' CTMD.
WITH A 20 bbl GEL SPILL AND CHASE TO SURACE, SEEN VERY LITTLE FILL MIXED
WITH GEL @ MI SKID.RIG BACK COIL FOR SLICKLINE TO DRIFT AND TAG.
3/29/08 CTU SUPPORT: RIH WITH 2.62" LIB TO 6542' SLM. COMPLETE.
4/4/08 SPOTTED 10 BBLS OF 15% HCL FROM 6535' CTMD TO 5385' CTMD IN ATTEMPT TO
SOFTEN OF REMOVE THERMATEK BRIDGE AT GLM ABLE TO PUSH 5 BBLS OF 15%
AWAY LEAVING TOP OF ACID AT 5960' MD WITH 2.5 BBLS BEHIND PIPE, WELL LEFT
SHUT IN AND FREEZE PROTECTED WITH DIESEL FROM 5900' TO SURFACE, RETURN
IN THE AM. (( IN PROGRES ))
4/5/08 AFTER 20HR SOAK TIME OF 15% ACID, MADE NOZZLE RUN IN ATTEMPT TO FCO
PAST GLM AT 6545' CTMD UNABLE TO JET THRU GLM WITH 2.5" NOZZLE, SWAPED
BHA OUT TO 1 11/16" JET BLASTER WITH 2.7" GAUGE RING WITH 3 DOWN JETS AND
1 SIDE JET, UNABLE TO BLAST THRU GLM AFTER 2 HRH„ POOH RETURN IN THE AM
FOR RESTART. WELL LEFT SHUT IN AND FREZZE PROTECTED WITH DIESEL TO
2000'MD.
4/6/08 MADE MILLING RUN WITH 2.8" BEAR CLAW MILL ABLE TO WORK THRU GLM DOWN
TO 6690' CTMD, TRIPPED FOR BIT AND WAS ABLE TO MILL DOWN TO 6788' CTMD,
TOTAL FOOTAGE MADE 244', RETURN IN THE AM FOR RESTART WITH MORE
AGRESSIVE MILL. WELL LEFT SHUT IN AND FREEZE PROTECTED TO 2000' WITH
DIESEL
1C-125 Well Events Summary
4/7/08 MILLED DOWN TO EZSV AND PARTLY THRU EZSV BEFORE LOSING ROPS (6812'
CTMD), MILL LOOKED GOOD AT SURFACE, CUT COIL AND CHANGE PACKOFFS,
WELL LEFT SHUT IN AND FREEZE PROTECTED, RETURN IN THE AM FOR RESTART
4/8/08 UNABLE TO WORK THRU PLUG, USED 2.75" 5 BLADED COWBOY MILL ON FIRST RUN,
2.80" CARBIDE CRAYOLA FOR SECOND RUN, WELL LEFT SHUT IN AND FREEZE
PROTECTED TO 2500' WITH DIESEL, TURN OVER TO SLICKLINE TO INVESTIGATE
4/9/08 RUM LIB TO 6804' SLM, IMPRESSION OF EZSV_. ***END JOB***
4/10/08 DUMP BAIL 2.0 GALLONS CEMENT na 6804' SLM, JOB COMPLETE.
4/12/08 ABLE TO MILL DOWN TO 6854' CTMD, LOST ALL ROPS AT THIS DEPTH, THIS IS
WHERE WFT PACKER WAS SET FOR PATCH, IF LINER WAS DAMAGED FROM
PACKER THIS MILL WOULD EXIT LINER, RETURN IN THE AM WITH BEARCLAW MILL,
IN PROGRESS )
4/13/08 MADE TWO MILLING RUNS TO 6856' CTMD, FIRST RUN WITH 2.80" BEAR CLAW,
SECOND RUN WITH 2.7" CARBIDE CRAYOLA MILL, UNABLE TO MAKE ANY
PROGRESS WITH EITHER MILLING ASSEMBLY, TURN OVER TO SLICKLINE FOR LIB
RUN, WELL LEFT SHUT IN AND FREEZE PROTECTED
4/16/08 RAN 2.79" LIB TO 6826' SLM, SHOWS 2.7" RING OF POSSIBLE CEMENT TOP. RAN 2.5"
BAILER 10' LOWER TO 6836' SLM, SMALL PIECES OF METAL RECOVERED. RAN 2.23"
LIB TO 6828' SLM, JUNK.
4/22/08 LATE START DUE TO HIGH WIND SPEEDS. RIH WITH BAKER 2.3" CARBIDE GUIDE
VENTURI BASKET, MOTOR, JARS, MHA (26.25'). INITAL TAG @ 6834' RKB, INCREASE
PUMP RATE TO 1.5 BPM, RIH DOWN TO 6836 RKB. POOH 40', RIH AND MADE IT
DOWN TO 6860' RKB. SLIGHT PRESSURE SPIKES WHILE RIH, P/U WEIGHT CLEAN.
POOH 400' TO DISCUSS POSSIBLE CLEARANCE & OBSTRUCTIONS, RIH AND
PRESSURE INCREASED IMMEDIATELY, POOH TO INSPECT BHA. FOUND LARGE
CHUNKS OF METAL AND SMALL FILLING OF CEMENT IN BASKET. JUNK BASKET WAS
NOT PACKED OFF & ABOUT 1/2 FULL. STAND BACK FOR NIGHT AND PREPARE FOR
MILL RUN IN AM.
4/23/08 RIH WITH BAKER 2.25" MHA, JARS, EXTREME, & 2.74" 3 BLADE MEDIUM CARBIDE BIT.
DRY TAGGED (~ 6875' RKB. P/U & INCREASE PUMP RATE 1.5 BPM PUMPING 1.5# BIO
TO MI SKID. MOTOR WORK~a~ 6874'. MILL DOWN TO 6874.7' WITH MULITPLE STALLS.
FASTER ROP FROM 74.7 DOWN TO 6876.3' RKB. NOT DRILLING OFF, POOH INSPECT
BIT, ALL 12 CUTTERS WORN DOWM ALONG WITH CARBIDES. OUTSIDE GAUGE
LOOKED GOOD. RIH WITH 2.63" VENTURI TAGGED Cc~ 6876.7', INCREASED TO 1.5
BPM, SLOWLY MADE IT DOWN TO 6878.6' RKB. POOH FREEZE PROTECTING CT,
FOUND LARGE 1" x 2 "THREADED SLEEVE WITH 1/4" x 2" SLIP. LOOKS LIKE MAY BE
TOP TENSION SLEEVE ON THE EZ DRILL PCKR. SET UP FOR MILLING RUN IN AM.
4/24/08 P/U BAKER 2.75" 3 BLADE PARANA MILL, 2.13" XTREME, DC,JARS, MHA. RIH & TAG Cc~
6878' RKB, START MILLING PUMPING 1.5# BIO @ 1.5 BPM RECIRC. TO MI SKID.
MILLED CEMENT DOWN TO 6920' RAN INTO SLUDGE, FLUIDS CLEARED UP @ 6950'.
_ GOOD CEMENT MILLING DOWN TO 6991' RKB FOUND COMP. PLUG. SWITCH TO
SSW, REMOVE BIO FROM WELL, MILLED OFF (a7 6992'. PUSHED DOWN TO 7011'
MILLED OUT, RIH WITH CT TO 7300' -BOTTOM OF PERFS. POOH BACKREAMING TO
6400'. POOH FREEZE PROTECT, GUAGE BIT AT SURFACE 2.70". JOB COMPLETE.
6/4/08 DRIFT TBG W/ 10' OF 2.25", TAGGED @ 7262' SLM (SAMPLE OBTAINED). JOB
COMPLETE.
6/5/08 RAN INJECTION PROFILE LOG. RESULTS: A-4 FROM 6990-7000' TAKING NEARLY
100% OF THE INJECTION. D, B, AND A-3 TAKING SOME FLUID BASED -2
TAKING SOME FLUID BASED ON STOP COUNTS. GAS CAP PRESENT FROM
SURFACE TO 6990' WHILE RIH. CROSSFLOW PRESENT FROM WS "D" TO A-4 (6990-
7000') WITH WELL SHUT IN. SMALL AMOUNT OF CROSSFLOW FROM A-4 (6954-6970')
TO A-4 6990-7000' BASED ON STOP COUNTS. FLUID LEVEL AT 6570' WHILE POOH.
WELL LEFT SHUT IN, LRS TO FP TO FOLLOW.
' `
C
Philli -_ _ ~JP 1C-125
~
;
onoco
ps
A(~,:~1~-_ WallGOre APIIUWI ~
(Field Name Well Status
M:i.trnum lncllrutbn (') Total Depth (flKB)
500292304400 jWEST SAK INJ ~I 6 9.78 7,700.0
Comment IN2S (ppm) Data Annotation IEnd Dale
~ 'KB-Grd (fl) Rig Release Date
.ienc, t~ -;C-~25. si9~2o0a i:3p;ps PM -. -... I ~ 45.64 I 10/16/2UU7
Sdiematlc-ACNaI ~~Annotation
Depth (kKB) Entl Date jMnotation End Data
(
Last lag. 12620 16/4/2008 'Rev Reason~lAG
» ' I
6/9/2008
ng Des pCOn OD (in) ~ ID (in) Top (RKB( S t Depth (k K6) Set Dep th (TVD1 (kKB) Wt (Ib Ik) Gratl I Top Thrbed
Conductor
~ ~ 16 15.062 0 U 1S8 0 1S4 i) F8 00
omdunor
~Sudace 5 12~ A.000 0 0 6,664 U t S8S S 1 S SO L 80 BTCM -
Praducnon 3 1l2 2.992 6,664 0 7,100.0 4.128.2 `.f.30 L-AO EUE8rdMDd
rr
Tubing Description
OD (in( ID (in) Top (kK8) Set Depth (flKB) Sat Dept
h (TVD) (kK8) Wt (
ICs/k) Gradei , _.. Top Thfeed
GAS UFF' -- TUBING
6.567 .,:, 31/2 2992 O0 6,6610 3,583.6 9.30 L-80 EUESrdMOd
~..
-
' Top (kK8) Descrip
tion - r Comment _-_.-_.-- - i
Run Data ID
6,56ZO,GAS LIFT CAMCO/KBG-2-9/1/DMY/INT!//Comment: 10/16/2001 2.9
_ 6,610.OI NIP CAMCO NIPPLE WITH NO GO PROFILE (10/76/2001 2.8
NIP, 6sto-- 6.648.O~SEAL BAKER 80-00 GBH-22 SEAL ASSEMBLY W/LOCATOR SUB 10/16/2001 2.9
- 'I 6,663.0'SBE BAKER SBE 10/16!2001 4.0
1 6,840.O~PACKER HES EZ RIL SVB SQUEEZE PACKER set 2/12/2008 '2/12/2008 _
6,863.0 j Marker Joint 10/ 16/2001 2.9
6,988.Oi PLUG HES FASDRILL BRIDGE PLUG set 2/1212008 2/12/2008 _
SE~~ - _ 7,700.0 Fish ROLLER .25" X 2.6" ROLLER WHEEL LOST IN HOLE PUSHED TO BOTTOM 11/23/2001
6'~ BY SLICKLINE
7,703.0 Fish ROLLER .25" X 2.6" ROLLER WHEEL LOST IN HOLE PUSHED TO BOTTOM 1125!2001
BY SLICKLINE
SBE. - - ~
• I • SMt Caku...
I
6.853
- ToP (TVD) Bim (ND) Dens Shot
Top (RKB) i Btrn (flKB) (RKB) (RKB) Type Zone (shot... Total Date Comment
6,742.0 6,780.0 3,627.5 3,646.8 IPERF 4.0 152 12282001 ~; 2.5` HSD BH Chg, 60 deg ph
6,780.0 6,800.0 3,646.8 3 657.1 IPERF 4.0 80 12/19/2001 '125" HSD BH Chg, 60 deg ph
6,858.01 6,904.0 3,685.4'7 3,708.3 IPERF ~ 4.0 1841~12l14/2001 72.5' HSD BH Chg, 60 deg ph
6,954.0 6,970.0 3.732.61 3.740.4 IPERF ~ 4.0 64 i 12/14/2001 ~ 2.5" HSD BH Chg, 60 deg ph
7
'
I I
~ 5
8
~ ~
o 0 3
~ 6 0
~
~
204 0
7 24
.O
.71z
a
. 1 3 88
3,857.
IPERF
.0 1
11/2312 Ol .5" HSD BH Chg 6
deg ph
~
2
12/282001
]806,800
12119/2001
Marker
JtiM, ---
6,863
.8586.901. __
tvtuzo9t~ _
.9516.970.
12na1200t /
PLUG.
6.988 f
1
.990.7,000,
1?/1?/2001
,012-7,058.
-- -
12/12/2001
,0787,138,
t Inazom
/-
,201-7,2x8.
11/23/2001 -_
Pmducdon
TD,1.700 `
Fish. 1.700. -- J
Fish, 7,703
~'
i
______.. ____-- - 06/10/08
..--~!
i
~i~~#i~~
Schlumberger -DCS
2525 Gambell Street, Suite 400
Anchorage, AK 99503-2838
ATTN: Beth
~~1~NNEE~ JUN ~ 2008
Well Job #
Log Description
i(";
NO. 4741
Company: Alaska Oil & Gas Cons Comm
Attn: Christine Mahnken
333 West 7th Ave, Suite 100
Anchorage, AK 99501
Field: Kuparuk ~ ~ t !,
6
Date BL Color CD
2W-13
3J-17
2M-08
16-10
1A-20
1G-13 11970689
11970690
11996642
11994672
11994673
11994674 GLS/PROD PROFILE -
GLS/PROD PROFILE /~ - v
PROD PROFILE/DEFT / / C/
PROD PROFILE/DEFT G
PROD PROFILE/DEFT -
PROD PROFILE/DEFT 3 ^ J(o~C~/~ 05/27/08
05/28/08
06/03/08
05/31/08
06/01/08
06/02/08 1
1
1
1
1
1 1
1
1
1
1
1
1A-03 11994673 PROD PROFILE/DEFT - / ~cr~y 06/04/08 1 1
2W
17 .
- 11996644 PROD PROFILE/DEFT ,-i /
~~ 06/05/08 1 1
~ 1C-125 ~
1C-127 11994677 INJECTION PROFILE -I- y ~~~~ 06/05/08 1 1
1 F-09 11994675 INJECTION PROFILE U _ L ~~y ~ 06/03/08 1 1
11994671 PROD PROFILE/DEFT -/ ®~~~ 05/30/08 1 1
iC-27 11994679 SBHP SURVEY ~~ ®~/ 06/07/08 1 1
•
Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you.
12/20/07
Schlumberger -DCS
2525 Gambell Street, Suite 400
Anchorage, AK 99503-2838
ATTN: Beth
NO. 4532
Company: Alaska Oil & Gas Cons Comm
Attn: Christine Mahnken
333 West 7th Ave, Suite 100
Anchorage, AK 99501
Field: Kuparuk
Well Job #
Log Description
Date BL Color CD
1J-105 11837540 INJECTION PROFILE c'a'1'~-(~'~- 11/20/07 1
1A-06 11837542 _
RST WFL '8'~ -~(~ i 11I22I07 1
10-05 11837537 LDL ~ - `~( 11117107 1
16-12 11970607 INJECTION PROFILE "i' 12/04/07 1
2N-327 11996582 OILPHASE SAMPLER Q~- (0 12/15/07 1
1D-132 11994588 SBHP SURVEY ~' 12/17/07 1
3H-10B 11996580 PATCH EVALUATION '= 12/13/07 1
3N-02A 11970609 LDL '~ - 12/05/07 1
1C-125 11964553 INJECTION PROFILE - 12/01/07 1
2M-15 NIA PRODUCTION PROFILE 1 ~ - 12/10/07 1
2M-11 N/A PRODUCTION PROFILE ~q ~ I 12/08/07 1
3A-03B 11970604 SCMT °=}- / 12/01/07 1
2T-217A 11978431 SCMT - 12/15/07 1
2L-330 11837544 FULLBORE MICRO SCANNER 11/27/07 1
2L-330 11837544 SONIC SCANNER 11/27/07 1
J
Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you.
.,-."".-..,;;...
Sc~lullbepger
RECE'VED
..., JUL 2- '1 2007
SJGAN~EU
NO. 4332
07/12/07
Schlumberger -DCS
2525 Gambell Street, Suite 400
Anchorage, AK 99503-2838
ATTN: Beth
JUL 2 5 2007
Alaska on &, Gas Cons. Commission
Anchorage
Company:
Alaska Oil & Gas Cons Comm
Attn: Christine Mahnken
333 West 7th Ave, Suite 100
Anchorage, AK 99501
u:rc- eå ( - ¡O¡<i
Field:
Kuparuk
Well
Log Description
CD
Date
BL
Color
Job#
1C-125 (REDO) N/A MEM INJECTION PROFILE 05/05/07 1
1 E-31 11629042 GLS 07/09/07 1
1 R-20 11839632 LDL 07/06/07 1
3F-19A 11839634 PRODUCTION PROFILE 07/08/07 1
2L-309 11839633 GLS 07/07/07 1
1J-122 11629039 USIT 07/05/07 1
2N-342 11629036 FMI 07/04/07 1
"Î Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you.
.
.
.
.
~
ConocoPhillips
Alaska
RECEIVED
.JUL 1 0 Z007
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
Alaska Oil & Gas Cons. Commission
Anchorage
July 6,2007
Mr. Tom Maunder
Alaska Oil & Gas Commission
333 West ih Avenue, Suite 100
Anchorage, AK. 99501
~~ JUL 1 J 2007
\~\~4
:)..0
Dear Mr. Maunder:
Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Some of
these wells were found to have a void in the conductor by surface casing annulus. The voids that
were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The
remaining volume of annular void subsequently was filled with a corrosion inhibiter engineered
to prevent water from entering the annular space. As per previous agreement with the AOGCC,
this letter and spreadsheet serves as notification that the treatments took place and meets the
requirements of form 10-404, Report of Sundry Operations.
Please M.J. Loveland at 907-659-7043, if you have any questions.
ConocoPhillips Well Integrity Project Supervisor
.
.
ConocoPhillips Alaska Inc.
Suñace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off
Corrosion
Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/
Well Name PTD# cement pumped cement date inhibitor sealant date
ft bbls ft aal
1C-125 201-199 11" na na 4.8 6/912007
1 C-170 203-078 23" na na 14.5 6/9/2007
1C-174 203-027 28" na na 9 6/912007
1C-178 203-041 40" na na 16 619/2007
1C-184 203-089 24" na na 10.4 6/9/2007
Kuparuk Field
June 9,2007
06/08/07
Schlullbergel'
-,..",,,~...,,-,",~ .
Schlumberger -DCS
2525 Gambell Street. Suite 400
Anchorage. AK 99503-2838
ATTN: Beth
NO. 4286
1 1 20m Sc;;ANNED JUN 142007
Company: Alaska Oil & Gas Cons Comm
Attn: Christine Mahnken
333 West 7th Ave, Suite 100
Anchorage, AK 99501
Field: Kuparuk ~v .
U .J- Q.. eo I - /c¡cr :.
'. - ""~~...
Job# Log Description Date BL Color CD
Well
2L-321 11629010 MULTI-FINGER CASING INSPECTION 05/12/07 1
2C-16 11629008 PPROF/LDL 05/10/07 1
2G-11 11638863 PRODUCTION PROFILE 05/05/07 1
1C-125 N/A MEM INJECTION PROFILE 05/05/07 1
2D-13 11638861 PRODUCTION PROFILE 05/03/07 1
2D-08 11638862 PRODUCTION PROFILE 05/04/07 1
2G-09 11638864 PRODUCTION PROFILE 05/06/07 1
2N-349A 11629004 RST/ WFL 05/04/07 1
3H-19 11638867 PRODUCTION PROFILE 05/09/07 1
1Q-10 11628771 MEM PRODUCTION PROFILE 05/03/07 1
1 E-11 11629012 INJECTION PROFILE 05/14/07 1
2L-321 11665439 USIT OS/25/07 1
2V-OBA 11629013 PM IT 05/15/07 1
1J-160 11632704 PRODUCTION PROFILE 03/19/07 1
1H-07 11665436 SBHP SURVEY OS/20/07 1
2F-11 11665434 PRODUCTION PROFILE 05/19/07 1
2X-07 11665433 INJECTION PROFILE 05/18/07 1
1B-01 11665432 PRODUCTION PROFILE 05/17/07 1
2X-01 11637338 INJECTION PROFILE 05/15/07 1
2Z-29 11665438 PRODUCTION PROFILE OS/22/07 1
1 H-22 11637339 INJECTION PROFILE 05/16/07 1
1Y-11 11632708 INJECTION PROFILE OS/23/07 1
1G-03 11637336 INJECTION PROFILE 05/14/07 1
1A-23 11665443 MEM PRODUCTION PROFILE OS/29/07 1
1 F-08 11665435 SBHP SURVEY OS/20/07 1
1J-170 11632709 INJECTION PROFILE OS/24/07 1
10-109 N/A INJECTION PROFILE 05/13/07 1
2M-24 11665440 SBHP SURVEY OS/28/07 1
Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you.
.
MEMORANDUM
e
State of Alaska
e
Alaska Oil and Gas Conservation Commission
TO:
Jim Regg
P.I. Supervisor
Rtt(t[ ':5/-Z:S!oev
DATE: Monday, May 22,2006
SUBJECT: Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA INC
lC-125
KUPARUK RIV U WSAK lC-125
.\ / ~qq
ðP
FROM:
Jeff Jones
Petroleum Inspector
Src: Inspector
Reviewed By:
P.I. Suprv ~13~
Comm
NON-CONFIDENTIAL
Well Name: KUPARUK RIV U WSAK IC-125 API Well Number 50-029-23044-00-00
Insp Num: mitJJ060508182344 Permit Number: 201-199-0
Rei Insp Num
Inspector Name: Jeff Jones
Inspection Date: 5/8/2006
Packer
Depth
3583
Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
Well i lC-12~IType Inj. i W
~j 2011990 ITypeTest I SPT
Interval 4YRTST P/F
TVD
Test psi
P
~
I IA i 200
I
i OA !
, -1-------
Tubing: 928
1725
1720
1720
1500
!
--
929
929
930
Notes .7 bbls diesel pumped. 1 well house inspected; no exceptions noted. Monobore injector.
lit-;.
Monday, May 22, 2006
Page 1 of 1
TUSING
(0-6661,
OD:3.500,
ID:2.992)
SURFACE
(0·6664,
OD:5.500,
Wt:15.50)
NIP
(6610-6611,
OD:4.520)
SEAL
(6648-6649,
OD:4.000)
SSE
(6653-6654,
OD:5.000)
Perf
(6742-6780)
Perf
(6780-6800)
Marker Joint
(6863-6864,
OD:4.500)
PATCH
(6851-6920,
OD:2.800)
'RODUCTION
(6664-7700,
OD:3.500,
Wt:9.30)
Perf
(6954-6970)
Perf
(6990-7000 )
Perf
(7042-7058)
Perf
(7078-7138)
Perf
(7204-7248)
e
e
ConocoPhillips Alaska, Inc.
1 C-125
API: 500292304400
SSSV Type: None
Well T e: INJ
Orig 10/16/2001
Com letion:
Last W/O:
Annular Fluid:
Ref Lo Date:
TD: 7725 ftKB
Max Hole 70 deg @ 2286
An Ie:
To
o
o
6664
Bottom
158
6664
7700
Zone Status Ft SPF
WSD 38 4
6780 - 6800 3647 - 3657 WSD 20 4
6858 - 6904 3686 - 3708 WSB 46 4
6954 - 6970 3733 - 3740 WSA4 16 4
6990 - 7000 3750 - 3755 WSA4 10 4
7042 - 7058 3775 - 3783 WSA3 16 4
7078 - 7138 3793 - 3823 WSA3 60 4
7204 - 7248 3857 - 3880 WSA2 44 4
KRU
1 C-125
Rev Reason: Post FCO tag, Set
Patch assembl
Last U date: 3/21/2005
TVD
158
3588
4128
Wt Grade Thread
68.00
15.50 L-80 BTCM
9.30 L-80 EUE8rdMod
Thread
EUE8rdMod
Comment
2.5" HSD BH Chg, 60 deg
h
2.5" HSD BH Chg, 60 deg
h
2.5" HSD BH Chg, 60 deg
h
2.5" HSD BH Chg, 60 deg
h
2.5" HSD BH Chg, 60 deg
h
2.5" HSD BH Chg, 60 deg
h
2.5" HSD BH Chg, 60 deg
h
2.5" HSD BH Chg, 60 deg
h
Vlv
Cmnt
Descri tion
CAMCO NIPPLE WITH NO GO PROFILE
BAKER 80-40 GBH-22 SEAL ASSEMBLY W/LOCATOR SUB
BAKER SBE
SET WEATHERFORD PATCH LOWER PACKER WITH TOP AT 6910'
3/7/2005
SET 3 1/2" LOWER ECLIPSE STRADDLE SPACER 29 1/2" OAL AND
UPPER ECLIPSE PACKER ON ETD 30.7" 6851' RKB 3/15/2005
.
6863 3688 Marker
Joint
ID
2.812
2.999
4.000
1.812
2.992
General Notes
Date Note
1/23/200 .25" X 2.6" ROLLER WHEEL LOST IN HOLE
1/25/200 .25" X 2.6" ROLLER WHEEL LOST IN HOLE PUSHED TO BOTTOM BY SLlCKLlNE
e
e
MICROFILMED
07/25/06
DO NOT PLACE
ANY NEW MATERIAL
UNDER THIS PAGE
F:\LaserFiclte\CvrPgs _ Inserts\Microfilm _ Marker. doc
)
)
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
Mechanical Integrity Test
5Et- ø. 11 0-5"
Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us
OPERA TOR:
FIELD I UNIT I PAD:
DATE:
OPERATOR REP:
AOGCC REP:
ConoeoPhillips Alaska Inc.
West Sak / KRU/ 1 C-125
07/30/05
Rogers - AES
Waived by John Crisp
l'~'\'!("'i'
~Øf::':~"":~r' if'
o
F
o
P
o
P
Well
P.T.D.
Notes:
Well
P.T.D.
Notes:
Test Details:
SCANNED !)!UG () IH 2.0D5
TYPE INJ Codes
F = Fresh Water Inj
G = Gas Inj
S = Salt Water Inj
N = Not Injecting
TYPE TEST Codes
M = Annulus Monitoring
P = Standard Pressure Test
R = Internal Radioactive Tracer Survey
A = Temperature Anomaly Survey
D = Differential Temperature Test
INTERVAL Codes
I = Initial Test
4 = Four Year Cycle
V = Required by Variance
T = Test during Workover
o = Other (describe in notes)
MIT Report Form
Revised: 06/19/02
2005-0730 _MIT _KRU _1 C-125_MITIA.xls
ßl-25 4-
'3'}- í10
LC"~ ¡GO
/91 - D~"I~'
)'5/- () ')14
/9ð-0t1
/7_'1(_ 117
:7'Þ
átJ I ~ (1'/
02/04/05
Schlumberger
NO. 3329
Schlumberger -DCS
2525 Gambell Street, Suite 400
Anchorage, AK 99503-2838
A TTN: Beth
SCANNED JUN 1 i 2005
Company: Alaska Oil & Gas Cons Comm
Attn: Helen Warman
333 West 7th Ave, Suite 100
Anchorage, AK 99501
Field: Kuparuk
Well
Job#
Log Description
Date
BL
Color
CD
'-'
3S-15 10922486 INJECTION TEST 11/06/04 1
1G-13 10922529 RST WFL 01/28/05 1
3H-108 10942827 PRODUCTION PROFILE/DEFT 01/17/05 1
1 L-24 10942834 RST WFL 01/26/05 1
1A-01 10922530 RST WFL 01/29/05 1
1 L-12 10922532 LEAK DETECTION 01/31/05 1
1C-125 10942833 INJECTION PROFILE 01/25/05 1
_/
~ /// ///1/ _/ ~
SIG~n' "1/ ~/Ú-~~ //(/C;;Ù<4~_~ DATE: ~;2{;:~~--¡;_r.;-
/// / /'
Please sign and return l¿ copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you.
(»..v
DATA SUBMITTAL COMPLIANCE REPORT
11/25/2003
).. v¡
S(l~ 7 ~~ Jt\kJ)
API No. 50-029-23044-00-00
CONOCOPHILLIPS ALASKA INC
Operator
KUPARUK RIV U WSAK 1C-125
Well Name/No.
2011990
Permit to Dri
1WINJ
Current Status
Completion Status
,-
11/23/2001
Completion Date
,-
4142
TVD
----
7725
MD
REQUIRED INFORMATION
~v~
-----=--~---=--=-- -{~~- -----= --=--~--=--
Well Data Maint
(data taken from Logs Portion of Master
Directional Survey
No
Samples
No
Mud Log
DATA INFORMATION
Types Electric or Other Logs Run:
Well Log Information:
-
Electr
Dataset
Number
10646
Log/
Data
Type
Comments
Digital Data: Rate of
Penetration, Dual Gamma
Ray, Electromagnetic
Wave Resistivity
Received
3/4/2002
10/1/2002
10/1/2002
10/1/2002
10/1/2002
11/1/2002
OH
CH
Open
Case
Case
Case
Case
Case
Interval
Start Stop
- -
116 7668
6890 7214
6890 7214
6890 7214
6890 7214
116 7725
Run
No
1
1
1
1
1
1
Log
Media
Blu
Blu
Blu
Blu
Log
Scale
5
5
5
5
,,{o '()~
Name
11261
Digital
Med/Frmt
D
I
i
~
~
frOg
i
! Q".og-
-1~
\...J..J' V"
~-
Sample
Set
Number
Interval
Stop
Well Cores/Samples Information:
Comments
Received
Sent
Start
Name
ADDITIONAL INFORMATION
Well Cored? Y ^it>
0N
(0N
Daily History Received?
Formation Tops
y,'t~----
-¥-,' 14
Chips Received?
---
" bM's
u1 f,.. IJ vv~
N'" 1-- ,..:...
1N'"" ^' ~~ \.
Analysis
Received?
Comments:
c''ß~
~~
DATA SUBMITTAL COMPLIANCE REPORT
11/25/2003
Permit to Dri 2011990 Well Name/No. KUPARUK RIV U WSAK 1C-125 Operator CONOCOPHILLlPS ALASKA INC API No. 50-029-23044-00-00
MD 7725 TVD 4142 Completion Date 11/23/2001 Completion Status 1WINJ Current Status 1WINJ UIC Y
Compliance Reviewed By: Date: ~~-~~
~
aD -I Cj 9
J I ~ (ç I
WELL LOG TRANSMfITAL
To: State of Alaska
Alaska Oil and Gas Conservation COmtn.
Attn.: Lisa Weepie
333 West 7th Avenue, Suite 100
J\nchorage,Alaska 99501
October 31, 2002
RE: MWD Formation Evaluation Logs: 1C-125,
AK-l\1N1-11165
The technical data listed below is being submitted herewith. Please address any problems or concerns
to the attention of
Rob Kalish, Speny-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518
lC-125:
Digital Log Images:
50-029-23044-00
1 CD Rom
/
~~
RECEIVED
NOV 01 2002
Alaska 01) & Ga~ C:Jn,~. Conh11iøiQn
Anchom~~
'"
WELL LOG TRANSMfIT AL
To: State of Alaska
Alaska Oil and Gas ConselVation Co.
Attn.: Lisa Weepie
333 West 7th Avenue, Suite 100
J\nchorage,Alaska 99501
February 26, 2002
RE: MWD Formation Evaluation Logs lC-125,
AK-MM-ll165
1 LDWG formatted Disc with verification listing.
API#: 50-029-23044-00
c30J-J'1~
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL
LETTER TO THE ATTENTION OF:
Sperry-Sun Drilling Service
Attn: Jim Galvin
6900 Arctic Blvd.
Anchorage, Alaska 99518
Sign& ~f( f2'-^-J
Date:
RECEIVED
f· ~ ~. n :j f' 0!\Q1l
.~:'_\:'.r~ L' L.~. LiJ t...
Alaska Oil &. Gas Cons, Commission
Anchorage
01/29/02
NO. 1759
Company: Alaska Oil & Gas Cons Comm
AUn: Lisa Weepie
333 West 7th Ave, Suite 100
Anchorage, AK 99501
Field: Kuparuk
BL Sepia CD Color
Division
Scblum~el'øer
Schlumberger Technology Corporation, by and through is Geoquest
3940 Arctic Blvd, Suite 300
Anchorage, AK 99503-5711
ATTN: Sherrie
"~j,"
Date
1 C-121 INJECTION PROFILE 01/20/02 1 1
1 C-125 PRESSURE STATION PBMS 12/28/01 1 1
1 L-14 INJECTION PROFILE 01/22/02 1 1
1 Y -26A PRODUCTION PROFILE WIDEFT 01/20/02 1 1
1 Y-32 PRODUCTION PROFILE WIDEFT 01/09/02 1 1
3M-19 PRODUCTION PROFILE 01/21/02 1 1
3N-19 22030 SCMT 01/12/02 1
-
---- '1\ Ii ¡-..,.
... ....
,.-.. "L! V L.LI
Log Description
Job#
Wel
dO}-O~O
dù)- ,qq
(~_O 10
I ~-1f(P
I ¥-oQ3
1 <:[7--0 t.pt./
61ol-;l ;;¿5
SIGNED DATE: FEB 0 1 2002
Alaska Oil & Gas Cons. Commisstur
Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. Anchorage
RECEIVED
SIGNED: ,J DATE:
JAN 2 5 2002
Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank Y1lalk80i1&GasCons.~
AnchoIage
.'<.-~
1 C-125 dO 1- CfLj PRESSURE STATION PBMS 12/28/01 1 1
1 D-137 . ~ri)--()t( , INJECTION PROFILE 01/04/02 1 1
1D-138 :).oD-OL í ;? INJECTION PROFILE 01/05/02 1 1
1 Q-21 ¡q F) - J :. '3 PRESS-TEMP STATIONS PBMS 12/29/01 1 1
1Y-15A ¡q )(' - J )(¡ (" PRODUCTION PROFILE 01/02/02 1 1
1Y-15A GAS LIFT SURVEY 01/02/02 1 1
2K-28 ~DI- Jf54 STATIC BOTTOM HOLE PRESS SURVEY 12/16/01 1 1
3A-03A ;JOb-ICJ J LEAK DETECTION LOG 01/08/02 1 1
30-03 /~-OJ5 PRODUCTION PROFILE WIDEFT 12/31/01 1 1
30-03 PROD PROF FIELD DEFT PRESENTATION 12/31/01 1 1
30-03 GAS LIFT SURVEY 12/31/01 1 1
-~
Sc___epgøP
Schlumberger Technology Corporation, by and through is Geoquest Division
3940 Arctic Blvd, Suite 300
Anchorage, AK 99503-5711
ATTN: Sherrie
Well Job# Log Description
Date
BL
Sepia
Field
Company:
1736
NO.
CD
Kuparuk
Alaska Oil & Gas Cons Comm
Attn: Lisa Weepie
333 West 7th Ave, Suite 100
Anchorage, AK 99501
Color
01/
7/02
~'
~
PHilliPS Alaska, Inc.
A Subsidiary of PHILLIPS PETROLEUM COMPANY
Post Office Box 100360
Anchorage, Alaska 9951 Q-0360
C. Mallary
Phone (907) 265-6434
Fax: (907) 265-6224
January 9, 2002
Commissioner Cammy Oechsli Taylor
State of Alaska
Alaska Oil & Gas Conservation Commission
333 West ih Avenue Suite 100
Anchorage, Alaska 99501
Subject: Completion Report for 1C-125 (201-199)
Dear Commissioner:
Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the West
Sak well1C-125.
If you have any questions regarding this matter, please contact Steve McKeever at 265-6826.
Sincerely,
Œ~'
C. Mallary
Drilling Engineering Supervisor
PAl Drilling
CM/skad
lYS'c~
çlV~
J/fA¡ 0 I...~
'a,crG 9 2002
4 Cis CO(}.
. "ChOta '~Conz .
,YJe rtJ/$Sio"
O,RJGI~tAL_
(' STATE OF ALASKA (I
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
1. Status of well Classification of Service Well
Oil D Gas D Suspended D Abandoned D Service 0 Water Injector
2. Name of Operator 7. Permit Number
Phillips Alaska, Inc. 201-1991
3. Address 8. API Number
P. O. Box 100360, Anchorage, AK 99510-0360 50-029-23044-00
4. Location of well at surface .. .,.,_ . r -~ .", -- 9. Unit or Lease Name
1622' FNL, 898' FWL, Sec. 12, T11 N, R10E, UM t ;... . .... '(ASP: 561906, 5968614) œ: Kuparuk River Unit
I .h. . . l.OC<\ hoNi'
At Top Producing Interval ~ '""7 - :' 10. Well Number
...L~.2~QL.:
486' FSL, 1870' FWL, Sec. 11, T11N, R10E, UM .\1£:' :::,: (A~P: 557627, 5965408) 1C-125
At Total Depth ' . ._Þ!/ ..-....-.~ ': .' ."'" 11. Field and Pool
90' FNL, 1761' FWL, Sec. 14, T11N, R10E, UM ,-" ,,- "'(ASP: 557523, 5964831) ~~~ ~..:~ West Sak Oil Pool
5. Elevation in feet (indicate KB. DF, etc.) 6. Lease Designation and Serial No. Kuparuk River Field
RKB 38' MD ADL 25650 & 25649 ALK 468
12. Date Spudded 13. Date T.D. Reached 14. Da~ Or Aband. 15. Water Depth, if offshore 16. No. of Completions
October 7, 2001 October 12, 2001 ' ¿..., ,. 001 tb N/A feet MSL 1
17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost
7725' MD 14142' TVD 7636' MD 1 4092' TVD YES 0 No D N/A feet MD 2238'
22. Type Electric or Other Logs Run
GR/Res, CBL
23. CASING, LINER AND CEMENTING RECORD
SETTING DEPTH MD
CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED
16" 62.5# H-40 Surface 158' 24" 378 sx AS 1
5.5" x 15.5# L-80 Surface 6664' 7.875" 600 sx AS III Lite, 430 sx Class G
3.5" 9.3# L-80 6664' 7700' 7.875" tapered string - cemented above
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)
3.5" 6662' NJA
7204' -7248' MD 3857' - 3880' TVD 4 spf
7078' - 7138' MD 3793' - 3823' TVD 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
7042' - 7058' MD 3775' - 3783' TVD 4 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED
6990' - 7000' MD 3750' - 3755' TVD 4 spf N/A
6954' - 6970' MD 3733' - 3741' TVD 4 spf
6858' - 6904' MD 3686' - 3708' TVD 4 spf
6742' - 6780' MD 3628' - 3647' TVD 4 spf
27. PRODUCTION TEST
Date First Production Method of Operation (Flowing, gas lift, etc.)
Injector
Date of Test Hours Tested Production for OIL-BBL GAS-MCF W A TER-BBL CHOKE SIZE GAS-OIL RATIO
Test Period>
Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF W A TER-BBL OIL GRAVITY - API (corr)
24-Hour Rate>
28. CORE DATA
Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips.
RECEIVED
N/A
Jl.\N 0 9 ZOOz
Alaska Oil & Gas G008. Commissm~
.Anchorage
Form 10-407 Rev. 7-1-80
CONTINUED ON REVERSE SIDE
Submit in duplicate
n [< i (J\' ~.'I ¡Ill RBDMS BFL
'-' í \ i \.:. ~ ~\Jf~\
~ AI ~ ~~,
JAN I 0 2002
G{
29.
GEOLOGIC MARKER~
30.
1
FORMATION TESTS
MEAS.DEPTH
TRUE VERT. DEPTH
Include interval tested, pressure data, all fluids recovered and gravity.
GOR, and time of each phase.
NAME
West Sak D
West Sak A3
West Sak Base
6739'
7030'
7564'
3626'
3769'
4051'
Annulus left open - freeze protected with diesel.
31. LIST OF ATTACHMENTS
Summary of Daily Operations, Directional Survey
32. I hereby certify that the following is true and correct to the best of my knowledge.
Signed CLn1A i£A/V/ / T~e
C. Mal/ary A
(/
Questions? Call Steve McKeever 265-6826
Drillinc Encineerinc Sucervisor
Dale 9 ~-t1 () Z
Prepared by Sharon AI/sup-Drake
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 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 cementing and the location
of the cementing tool.
Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection,
Shut-in, Other-explain.
Item 28: If no cores taken, indicate "none".
RECEI
'D
OR\Glf\jt\l~
JAN (} 0 ?f'r,')
Aiaska OU & G-:,
AnaS¡' COlrlfiIISS (j/;
: , uC lOrage
Form 10-407
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(PHILLIPS J
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~
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PHilliPS ALASKA INC.
Operations Summary Report
Legal Well Name: 1 C-125
Common Well Name: 1 C-125
Event Name: ROT - DRILLING
Contractor Name: Nabors
Rig Name: Nabors 245
Date From - To Hours Code Sub Phase
Code
10/6/2001 17:00 - 17:30 0.50 MOVE SFTY MOBMIR
17:30 - 18:30 1.00 MOVE MOVE MOBMIR
18:30 - 19:30 1.00 MOVE RURD MOBMIR
19:30 - 23:00 3.50 WELCTL NUND PROD
23:00 - 00:00 1.00 DRILL SFTY PROD
10nl2001 00:00 - 01 :30 1.50 DRILL SFTY PROD
01 :30 - 02:30 1.00 WELCTL NUND PROD
02:30 - 06:00 3.50 DRILL PULD PROD
06:00 - 08:00 2.00 DRILL PULD PROD
08:00 - 10:00 2.00 DRILL PULD PROD
10:00 - 11 :00 1.00 DRILL SFTY PROD
11 :00 - 13:00 2.00 DRILL DEQT PROD
13:00 - 14:30 1.50 DRILL DRLG PROD
14:30 - 15:00 0.50 DRILL SURV PROD
15:00 - 00:00 9.00 DRILL DRLG PROD
10/8/2001 00:00 - 00:00 24.00 DRILL DRLG PROD
10/9/2001
00:00 - 11 :00 11.00 DRILL DRLG PROD
11 :00 - 13:00 2.00 DRILL CIRC PROD
13:00 - 17:00 4.00 DRILL TRIP PROD
17:00 - 18:00 1.00 DRILL TRIP PROD
18:00 - 19:00 1.00 RIGMNT RSRV PROD
19:00 - 21 :00 2.00 DRILL TRIP PROD
21 :00 - 21 :30 0.50 DRILL OTHR PROD
21 :30 - 00:00 2.50 DRILL TRIP PROD
00:00 - 03:30 3.50 DRILL TRIP PROD
03:30 - 04:00 0.50 DRILL CIRC PROD
04:00 - 12:00 8.00 DRILL DRLG PROD
12:00 - 00:00 12.00 DRILL DRLG PROD
00:00 - 03:30 3.50 DRILL DRLG PROD
03:30 - 05:00 1.50 DRILL CIRC PROD
05:00 - 05:30 0.50 DRILL CIRC PROD
05:30 - 10:30 5.00 DRILL TRIP PROD
10:30 - 12:00 1.50 DRILL TRIP PROD
12:00 - 12:30 0.50 RIGMNT RSRV PROD
12:30 - 13:00 0.50 DRILL TRIP PROD
13:00 - 17:00 4.00 DRILL TRIP PROD
17:00 - 19:00 2.00 DRILL REAM PROD
19:00 - 20:30 1.50 DRILL CIRC PROD
20:30 - 00:00 3.50 DRILL DRLG PROD
10/10/2001
10/11/2001
Page 1 of 3
Spud Date: 10/11/2001
End:
Group:
Start: 10/6/2001
Rig Release: 10/16/2001
Rig Number: 245
Description of Operations
Pre-job meeting before rig move
Move rig from 1C-131 to 1C-125
Rig accepted. Mate up drilling module & utility module. Prep diverter.
NU diverter stack. Skid floor 3 in. away from pipe shed
Pre-spud meeting with both crews and PAl personnel.
Pre-spud meeting with both crews and PAl personnel.
NU Diverter stack.
PU 36 stds DP and 9 jts HWDP. Stand back in derrick.
PU landing joint and fluted hanger. Drift hanger through diverter stack.
Land hanger on landing ring. Function test diverter stack. Lay down
landing joint and hanger.
PU BHA #1 and MU 7-7/8" bit. Orient motor and MWD.
Load MWD data - Shallow gas diverter drill.
Surface test stack and associated equipment. Surface test MWD.
Drill ahead f/158' to 283'
Gyro survey.
Drill ahead f/283' to 926' MD (909' TVD).
AST =3.75
ART =4.00
Drilling from 926' to 3476' MD, 2234' TVD
AST = 6.75
ART = 11 .5
Directional drill 7 7/8" surface hole from 3476' to 4517' (1041') (TVD
2676').
Ream tight hole f/4477' to 4517'. Survey. Back ream. Circulate and
condition fl trip. Monitor well.
POOH. Tight @ 2950'. Ream out of hole.
Monitor hole @ BHA. Change bit and BHA.
Service rig and top drive.
Download MWD. Change pulsar sub. Program tools.
Surface test MWD. OK.
RIH wI bit # 2. Tight hole @ 2414'. Work, wash and ream to 2824'.
Continue to wash & ream to bottom wI bit # 2 to 4517'.
CBU while rotating and recip pipe @ 100 RPM.
Directional drill 7 7/8" hole from 4517' to 5376' (TVD=3005'). ART =
5.25 hrs. AST = .25 hrs.
Directional drill 7 7/8" hole from 5376' to 6418' (TVD= 3475') ART
= 3.5 hrs. AST =5.25 hrs.
Irect. drill 7-7/8" hole f/6418' to 6612' (194') (TVD=3562') ART= .25
hrs AST =2 hrs
CBU for trip. Need more turn than it appears to be acheiving.
Monitor wee I. PJSM. Pump dry job.
POOH for increase in motor bend. Blow down top drive. POOH. Tight
hole @ 647'. Continue out of hole.
Change bit, change bend of mtr f/1.15 deg to 1.83 deg. Download
Sperry MWD and program tools.
Service rig and top drive.
Surface test MWD. OK.
RIH wI bit # 3.
Ream 1100' to bottom.
Recip and circulate bottoms up prior to drilling.
Directional drill 7 7/8" surface hole f/6612' to 6760' (148') (TVD=3635')
ART = 1.2 hrs. AST = 2.0 hrs.
-
Printed: 10/25/2001 12:02:15 PM
(
~ ... ~
(PHILLIPS ~
~
~
((
PHilliPS ALASKA INC.
Operations Summary Report
Legal Well Name: 1 C-125
Common Well Name: 1 C-125
Event Name: ROT - DRILLING
Contractor Name: Nabors
Rig Name: Nabors 245
Date From - To Hours Code Sub Phase
Code
10/12/2001 00:00 - 13:30 13.50 DRILL DRLG PROD
13:30 - 15:00 1.50 DRILL CIRC PROD
15:00 - 19:30 4.50 DRILL TRIP PROD
19:30 - 21 :30 2.00 DRILL TRIP PROD
21 :30 - 23:30 2.00 CMPLTN PULD PROD
23:30 - 00:00 0.50 DRILL OTHR PROD
10/13/2001 00:00 - 05:00 5.00 DRILL TRIP PROD
05:00 - 08:30 3.50 DRILL CIRC PROD
08:30 - 14:00 5.50 DRILL TRIP PROD
14:00 - 23:00 9.00 RIGMNT RGRP PROD
23:00 - 00:00 1.00 DRILL TRIP PROD
10/14/2001 00:00 - 01 :00 1.00 RIGMNT RSRV PROD
01 :00 - 06:00 5.00 DRILL TRIP PROD
06:00 - 08:30 2.50 DRILL CIRC PROD
08:30 - 14:30 6.00 DRILL TRIP PROD
14:30 - 15:30 1.00 CASE RURD PROD
15:30 - 16:00 0.50 CASE RUNC PROD
16:00 - 17:00 1.00 RIGMNT RGRP PROD
17:00 - 18:00 1.00 CASE RUNC PROD
18:00 - 19:00 1.00 CASE RURD PROD
19:00 - 20:30 1.50 CASE RUNC PROD
20:30 - 22:00 1.50 CASE RUNC PROD
22:00 - 00:00 2.00 CASE RUNC PROD
10/15/2001 00:00 - 03:00 3.00 CASE RUNC PROD
03:00 - 03:30 0.50 CASE RUNC PROD
03:30 - 04:00 0.50 CASE RUNC PROD
04:00 - 04:30 0.50 CASE RURD PROD
04:30 - 09:00 4.50 CEMEN"' CIRC PROD
09:00 - 11 :00 2.00 CEMEN"' PUMP PROD
11 :00 - 12:00 1.00 CEMEN"' DISP PROD
12:00 - 13:00 1.00 CEMEN" RURD PROD
13:00 - 13:30 0.50 CEMEN"' OTHR PROD
13:30 - 16:00 2.50 WELCTL NUND PROD
16:00 - 17:00 1.00 WELCTL NUND PROD
17:00 - 20:30 3.50 WELCTL NUND PROD
20:30 - 23:00 2.50 WELCTL BOPE PROD
Page 2 of 3
Spud Date: 10/11/2001
End:
Group:
Start: 10/6/2001
Rig Release: 10/16/2001
Rig Number: 245
Description of Operations
Directional drill 7 7/8" hole fl 6760' to 7725' (965') (TVD= 4143) AST=
2.1 hrs. ART = 7.9 hrs
Circulate and condition mud and hole prior to POOH fl Hole Opener.
POOH fl 7 7/8" hole opener.
Download Sperry tools, UD BHA.
PJSM. RU GBR to stand back 33 joints (11 stands) 3 1/2" EUE tubing
in derrick.
MU 77/8" hole opener assembly.
TIH w/7 7/8" hole opener to TD @ 7725'. Fill pipe every 25 stands.
Circulate and condition mud and hole fl 3 1/2" x 5 1/2" casing.
PJSM, monitor well, pump dy job. POOH, monitor well @ HWDP,
continue to POOH. UD BHA.
Flange connection on hydraulic motor failed on pipe handling machine.
Evaluate and troubleshoot. Plan for repairs.
PJSM. MU 7 7/8" hole opener BHA.
Continue repairs on Pipe Handling machine while service rig and top
drive.
RIH w/7 7/8" hole opener assembly. Fill pipe @ 2500' and 6200'.
Circulate and condition mud and hole for casing.
POOH. UD BHA. Clean up rig floor.
Rig up to run 3 1/2" casing. PJSM on casing procedure.
Run 31/2" casing.
Repair service loop on pipe handling machine.
Continue to run 3 1/2" casing. Total of 32 joints and 2- 10' pups.
Rig up 51/2" casing tools.
Run 5 1/2" casing, knot in hole @ 1650' shoe depth = X-O @ 614'. Had
14 joints of 5 1/2" in hole + 8' in on joint # 15.
Circulate wI Franks fillup tool and work pipe through tight spot in hole.
Continue to run 5 1/2" casing into hole. 65 in hole @ midnight. PU wt
115 k. SO wt 90 k. Depth approx 3730'.
Continue to run 31/2" x 51/2" casing. With casing shoe @ 7301' &
Tam port collar @ 614', again hit knot in hole. 146 joints of 51/2" in
hole + 26'.
Work pipe and circulate @ 7301' shoe depth, Tam port collar @ 614'.
Work through knot with 6.77" OD Tam port collar.
Continue to run 31/2" x 51/2" casing to 7655'.155 joints of 51/2" in
hole.
Rig down Frank's fillup tool. Rig down spiders
PU Hanger and landing joint. Run in hole, MU cement head. Circ casing
while reciprocating 15'. Circulate 13937 strokes(1403 bbls).
PJSM. Cement per program.
Drop Weatherford plugs as one. Displace cement with 3% KCL 9.2ppg.
CIP @ 1140 hrs. Bump plug wI 2500 psi @ calculated strokes.. Bleed
off. Check floats. OK.
RID cement equipment and casing tools. Clear floor.
Wash cement out of diverter stack.
PJSM. N/D Diverter stack.
PJSM. NU Vetco gray tubing spool. Test to 5000 psi.
NU BOPE.
RU to test BOPE. Witness of test waived by AOGCC inspector John
Crisp.Test annular @ 250 and 1500 PSI. Test top and bottom pipe
rams, HCR, KILL and Choke valves, floor safety valve,choke valves
1,2,3 to 250 and 2500 psi.
Printed: 10/25/2001 12:02:15 PM
.... .-... ......
(PHILLiPS,! PHilliPS ALASKA INC. Page 3 of 3
IUi Operations Summary Report
Legal Well Name: 1 C-125
Common Well Name: 1 C-125 Spud Date: 10/11/2001
Event Name: ROT - DRILLING Start: 10/6/2001 End:
Contractor Name: Nabors Rig Release: 10/16/2001 Group:
Rig Name: Nabors 245 Rig Number: 245
Date From - To Hours Code Sub Phase Description of Operations
Code
10/15/2001 23:00 - 23:30 0.50 WELCTL BOPE PROD RID test equipment. Blow down lines.
23:30 - 00:00 0.50 CMPL TN RURD PROD Rig up to run 31/2" completion string.
10/16/2001 00:00 - 00:30 0.50 CMPL TN SFTY PROD PJSM for running 31/2" completion string.
00:30 - 07:30 7.00 CMPL TN RUNT PROD MU Baker seal assembly" joint tubing, Camco DS nipple, joint, Camco
GLM, run total of 211 joints tubing.
07:30 - 09:30 2.00 CMPL TN RUNT PROD Circ slow coming down wI joint # 211. PU joint # 212-circ slow coming
down. Pressure increase @ SBE. Bleed pressure. Locate. UD joint
212, 211, 210. Install 2.33' pup, mu jt 210, hngr, landing joint.
09:30 - 10:00 0.50 CMPL TN CIRC PROD Reverse circ 102 bbl brine @ 4.6 bpm & 1200 psi.
10:00 - 10:30 0.50 CMPL TN FRZP PROD Reverse circ 68 bbls diesel @ 2.5 bpm, 400-600 psi.
10:30 - 11 :00 0.50 CMPL TN FRZP PROD RU to IOU tube" diesel fl5 1/2" x 31/2" annulus to 3 1/2" tubing. Initial
pressure 236 psi. 16 PSI @ 100 hrs.
11 :00 - 12:00 1.00 CMPL TN OTHR PROD Open annular. Pump out stack. Land tubing. Run in lockdown screws
on tubing hanger. Test tubing @ 500 psi. fl 15 min. OK.
12:00 - 12:30 0.50 CMPL TN OTHR PROD Test annulus @ 500 psi. fl 15 min. OK. Blow down lines.
12:30 - 13:00 0.50 WELCTL OTHR PROD UD landing joint. Install BPV.
13:00 - 15:00 2.00 WELCTL NUND PROD PJSM. NID 13 5/8" BOPE.
15:00 - 18:00 3.00 WELCTL NUND PROD Install tree. Test lower flange to 5000 psi. Test tree to 5000 psi on chart
fl 15 min. OK.
18:00 - 19:00 1.00 WELCTL NUND PROD Remove 16" knife valve from diverter setup in cellar for next well.
19:00 - 20:00 1.00 RIGMNT RSRV PROD Service rig and top Drive. PJSM wI Toolpusher.
20:00 - 22:00 2.00 RIGMNT RURD PROD Sip and cut 110' drilling line. PJSM wi Toolpusher.
22:00 - 22:01 0.02 MOVE MOVE PROD Rig released fl move 240' away from CPM to we1l1c-109 ml.
('
(
Printed: 10/25/2001 12:02:15 PM
Date
11/04/01
11/05/01
11/22/01
11/23/01
11/24/01
11/25/01
11/26/01
12/12/01
12/14/01
12/16/01
12/19/01
12/20/01
12/21/01
12/28/01
(I·
1 C-125 Event History
f
Comment
DRIFTED TBG & TAGGED W/ 2.735" @ 7588' RKB. [TAG]
OBTAINED CEMENT BOND LOG W/ SCMT-BB, TAGGED TD @ 7577', LOG PRESSURE PASS TO TO
ABOVE LINER TOP & FOUND GOOD CEMENT. LOG SAME WITH NO WHP AND FOUND GOOD CEMENT
FROM LINER TOP TO 6745', FAIR FROM 6745'-6830', GOOD FROM 6830'-7010', AND FAIR FROM 7010
DRIFTED TBG W/ 23' OF 2.60" DUMMY GUN'S & TAGGED 7557' WLM [LEAK DETECT-PATCH, TAG]
PERFORATED A2 SAND INTERVAL 7204' -7248' W/ 2.5" HSD 4 SPF BH & 60 DEG PHASING. [PERF]
PERFORATED A3 SAND INTERVAL 7078' -7138' W/2.5" HSD 4 SPF BH CHGS 60 DEG PHASING IN 3
RUNS. ON 4TH RUN UNABLE TO DESCEND PAST 2230', SUSPECT ICING. DISPLACE WELLBORE W/ 65
BBLS OF HOT DIESEL. JOB IN PROGRESS. [PERF]
DRIFTTBG W/2.80" GAUGE RING + 3" BRAIDED LINE BRUSH, TAGGED FILL @ 7510' WLM COMPLETE.
[TAG]
INCOMPLETE OPERATION - RIGGED DOWN TO GO TO ALPINE RIG JOB [PERF]
INTERVALS SHOT: 7042-7058 FT MD / 6990-7000 FT MD. 3RD RIH WAS A MISRUN. NO DIFFICULTIES
ON RIH OR POOH EXCEPT A LITTLE OVERPULL AT THE NIPPLE AT 6611 FT MD AFTER SHOOTING.
RAN ROLLER IN UPPER 1/3 OF TOOL AND A ROLLER STEM AT BOTTOM. [PERF]
PERFORATED 6954-6970 AND 6858-6904 FT MD WITH 2506 POWERFLOW CHARGES AT 4 SPF. 2ND
GUN GOT STUCK IN THE HOLE AFTER SHOOTING - PULLED OUT OF WEAK POINT. TOOLSTRING
WILL BE FISHED. TOTAL LENGHT = 37.7 FT X 2.6" MAX OD. TOOL TOP AT APPROX 6624 FT. [PERF]
FISHED E-LlNE PERF GUNS @ 6608' WLM. ALL TOOLS RETRIEVED [FISH]
RIG UP SHOOT 58 FT OF 3.5 POWERJETS @ 4 SPF- TOTAL OF 232 SHOTS PERF INTERVAL 6742 TO
6800 --GUN TWO STUCK IN WELL LINE PARTED TRYING TO WORK GUN LOOSE
*CONTINUATION FROM 12/19 REPORT* FINISH STRIPPING LINE FROM WELL-
FISHED LIVE E-LlNE PERF GUNS F/ 2645' WLM. FULL RECOVERY, DRIFT TBG W/ 2.805" GAUGE RING
TO 6510' RKB, TAGGED FILL W/ 2.75" GAUGE RING @ NO PROBLEMS COMPLETE [FISH]
PERFORATE 6742-80' (38', FINAL OF TOT 250' PERFORATED) WITH 2.5" HSC 4 SPF, 60 DEG PHASED,
POWERFLOW CHARGES. SBHP OF 1705 PSI @ 6900 FT. PUMPED 20 BBL METH FREEZE PROTECT.
Page 1 of 1
117/2002
~
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:;\. 0' - I B3
.:l 0 , - I c¡q
Ø\Oi ..~
.;) 0 I - ~..¡.
Alaska Oil & Gas COns. CommiSSiOt
Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you'Anchorage
1 F-16A SBHP SURVEY 11/30/01 1 1
2T -39 SBHP SURVEY 12/04/01 1 1
1 C-125 21501 SCMT 11/05/01 1
1F-16A 21502 USIT 11/12/01 1
2K-28 21503 SCMT 11120/01 1
.
~ECEIVt::D
DATE:
-~~
SCbllll_.pgBP
Schlumberger Technology Corporation, by and through is Geoquest Division
3940 Arctic Blvd, Suite 300
Anchorage, AK 99503-5711
ATTN: Sherrie
Well Job# Log Description Date
BL
Sepia
Field:
Company:
CD
Kuparuk
Alaska Oil & Gas Cons Comm
Attn: Lisa Weepie
333 West 7th Ave, Suite 100
Anchorage, AK 99501
Color
NO.
1692
2/13/01
\
I{
07-Nov-01
AOGCC
333 W. 7th Ave. Suite 100
Anchorage, AK 99501
Definitive
Re: Distribution of Survey Data for Well 1 C-125
~DJ-)94
Dear Dear Sir/Madam:
Enclosed are two survey hard copies and 1 disk
Tie-on Survey:
Window / Kickoff Survey
Projected Survey:
0.00' MD
'MD
(if applicable)
7,725.00' MD
Please call me at 273-3545 if you have any questions or concerns.
Regards,
William T. Allen
Survey Manager
Attachment(s)
RECEIVED
NOV 1 J 2001
Alaska Oil & Gas CO"\,, .
Þ\... I.. ns. L-ommassion
I'w, tCltorage
DEFINiTiVE
~
Kuparuk River Unit
North Slope, Alaska
Kuparuk 1C, Slot 1C-125
1C-125
Job No. AKMM11165, Surveyed: 12 October, 2001
SURVEY REPORT
7 November, 2001
~
Survey Ref: svy9647
Your Ref: API 500292304400
Surface Coordinates: 5968613.75 N, 561905.78 E (70019'29.2213" N, 149029' 52.8817" W)
Surface Coordinates relative to Project H Reference: 968613.75 N, 61905.78 E (Grid)
Surface Coordinates relative to Stucture Referance: 95.13 N, 465.50 W (True)
Kelly Bushing: 101.45ft above Mean Sea Level
5pa~(lY-5UI!
DAnlCLING 5 E R vn:::es
A Halliburton Company
DEF\N\T\\!E ·
Sperry-Sun Drilling Services
Survey Report for 1C-125
Your Ref: AP/500292304400
Job No. AKMM11165, Surveyed: 12 October,
North Slope, Alaska
Kuparuk 1C
2001
Vertical
Section
Dogleg
Rate
(0/100ft)
Global Coordinates
Northings Eastings
(ft) (ft)
Local Coordinates
Northings Eastings
(ft) (ft)
Vertical
Depth
(ft)
Sub-Sea
Depth
(ft)
Kuparuk River Unit
Measured
Depth
(ft)
_..
Comment
MWD Magnetic
0.00
0.05
0.27
1.60
6.23
0.429
0.772
0.868
3.695
561905.78 E
561906.49 E
561906.79 E
561906.54 E
561903.32 E
5968613.75 N
5968612.85 N
5968612.17 N
5968610.42 N
5968607.06 N
0.00 E
0.71 E
0.99 E
0.73 E
2.51 W
0.00 N
0.908
1.59 S
3.338
6.678
0.00
175.00
228.68
319.66
411.64
-1 01.45
73.55
127.23
218.21
310.19
Azim.
0.000
142.000
170.030
199.940
231 .580
Incl
0.000
0.750
0.880
1 .420
4.530
0.00
175.00
228.69
319.69
411.80
16.24
31.30
53.15
79.84
08.07
3.548
3.915
5.794
1.848
2.220
561895.24 E
561882.26 E
561863.10 E
561839.25 E
561813.23 E
5968601.10 N
5968593.1 0 N
5968581.85 N
5968568.64 N
5968555.58 N
10.64 W
23.69 W
42.94 W
66.90 W
93.03 W
12.56 8
20.45 S
31.55 S
44.56 S
57.41 S
504.53
595.18
684.55
772.69
858.32
403.08
493.73
583.1 0
671.24
756.87
235.510
241.140
239.300
243.530
244.090
7.820
11 .300
16.620
17.780
19.780
505.24
597.18
689.31
781.57
872.02
140.19
180.22
225.87
275.95
328.63
4.513
5.370
2.770
2.190
2.572
561784.67 E
561750.80 E
561712.84 E
561671.43 E
561628.10 E
5968539.51 N
5968517.48 N
5968491.60 N
5968462.94 N
5968432.52 N
121.72 W
155.77 W
193.94 W
235.59 W
279.16 W
73.24 8
94.99 S
120.55 S
148.87 S
178.948
941 .50
1025.35
1106.63
1187.85
1266.18
840.05
923.90
1005.18
1 086.40
1164.73
238.550
236.500
235.900
235.690
235.110
23.270
28.190
30.760
32.850
35.260
961.44
1054.54
1147.92
1243.49
1338.04
386.19
449.81
518.93
592.20
669.05
5.195
5.419
3.587
5.881
2.893
561581.42 E
561529:18 E
561470.88 E
561409.29 E
561345.57 E
5968398.50 N
5968361.66 N
5968323.42 N
5968282.64 N
5968238.85 N
326.13 W
378.66 W
437.28 W
499,20 W
563.28 W
212.578
248.98 S
286.73 S
327.008
370.27 8
1340.97
1410.83
1476.94
1536.89
1590.98
1239.52
1309.38
1375.49
1435.44
1489.53
233.750
236.670
237.730
236.260
235.690
40.100
44.840
48.200
53.680
56.370
1432.57
1527.29
1623.39
1718.56
1812.93
~
749.76
833.55
919.95
007.84
096.40
6.135
2.179
4.542
1.250
1.535
561279.35 E
561210.85 E
561140.23 E
561069.17 E
560997.50 E
5968192.05 N
5968143.19 N
5968092.77 N
5968040.58 N
5967988.09 N
629.89 W
698.79 W
769.83 W
841.31 W
913.41 W
416.51 S
464.81 S
514.65 S
566.24 S
618.15 S
1639.24
1681.89
1720.01
1754.40
1787.86
1537.79
1580.44
1618.56
1652.95
1686.41
234.790
235.150
234.750
233.610
234.890
62.110
64.140
68.430
68.950
69.780
1907.33
2001.67
2096.47
2191.10
2286.04
DrillQuest 2.00.09.003
1184.15
1270.14
1356.87
1441.76
1530.31
3.011
1 .438
0.368
1.578
0.883
560925.33 E
560853.37 E
560779.91 E
560707.07 E
560630.47 E
5967937.41 N
5967889.17 N
5967841.54 N
5967796.01 N
5967749.24 N
986.00 W
1058.35 W
1132.20 W
1205.41 W
1282.40 W
Page 2 of 5
668.22 S
715.878
762.89 S
807.82 S
853.96 S
1822.71
1859.03
1895.32
1931.11
1969.54
1721.26
1757.58
1793.87
1829.66
1868.09
235.920
237.340
237.690
239.240
238.890
67.090
67.420
67.550
67.220
66.420
7 November, 2001 - 13:10
2380.87
2474.81
2569.58
2662.64
2760.27
·
Sperry-Sun Drilling Services
Survey Report for 1 C-125
Your Ref: API 500292304400
Job No. AKMM11165, Surveyed: 12 October, 2001
North Slope, Alaska
Kuparuk 1 C
Vertical
Section
Dog leg
Rate
(o/100ft)
Global Coordinates
Northings Eastings
(ft) (ft)
Coordinates
Eastings
(ft)
Loca
Northings
(ft)
Vertical
Depth
(ft)
Sub-Sea
Depth
(ft)
Kuparuk River Unit
Incl
Measured
Depth
(ft)
r~
Comment
1617.63
1702.04
1788.64
1875.91
1962.23
2.346
1.084
0.527
2.044
1.782
560556.31 E
560485.60 E
560412.85 E
560338.46 E
560264.35 E
5967701.53 N
5967654.27 N
5967606.03 N
5967558.64 N
5967512.40 N
1356.94 W
1428.05 W
1501.20 W
1575.97 W
1650.46 W
901.05 8
947.738
995.37 8
042.148
087.778
2007.42
2042.54
2078.17
2114.11
2150.47
1905.97
1941 .09
1976.72
2012.66
2049.02
Azim.
236.550
236.880
236.970
238.980
238.030
67.090
68.040
67.550
68.120
66.680
2856.25
2948.27
3042.56
3137.80
3232.42
2048.48
2134.52
2219.68
2303.64
2387.68
2.700
1.635
2.739
0.935
1.142
560192.17 E
560120.97 E
560050.23 E
559981.28 E
559913.20 E
5967464.02 N
5967414.83 N
5967366.46 N
5967317.85 N
5967268.10 N
1723.04 W
1794.64 W
1865.77 W
1935.13 W
2003.61 W
1135.558
1184.158
1231.948
1279.97 8
1329.178
2187.76
2225.72
2266.63
2309.24
2352.43
2086.31
2124.27
2165.18
2207.79
2250.98
235.260
236.41 0
235.790
234.800
233.820
66.880
65.750
63.210
63.200
62.560
3326.99
3421.49
3516.46
3610.97
3705.71
2471.41
2555.86
2640.96
2726.19
2814.99
0.283
2.045
0.191
3.442
2.339
559845.72 E
559777.25 E
559707.95 E
559639.05 E
559566.63 E
5967218.14 N
5967168.22 N
5967118.27 N
5967067.66 N
5967015.66 N
2071.50 W
2140.38 W
2210.10 W
2279.41 W
2352.26 W
1378.57 8
1427.938
1477.30 8
1527.338
1578.748
2396.14
2438.62
2479.56
2517.60
2553.86
2294.69
2337.17
2378.11
2416.15
2452.41
234.090
234.660
234.730
233.630
235.950
62.440
64.310
64.480
67.540
68.210
3800.37
3895.16
3989.89
4083.47
4179.73
2901.20
2989.38
3076.01
3156.09
3244.50
3.100
0.738
1.704
1.534
3.423
559493.62 E
559417;49 E
559343.65 E
559276.72 E
559201.81 E
5966968.32 N
5966921 .55 N
5966874.53 N
5966829.50 N
5966780.99 N
2425.66 W
2502.16 W
2576.39 W
2643.69 W
2718.99 W
1625.478
1671.61 8
1718.038
1762.50 S
1810.398
2588.73
2624.02
2657.36
2687.29
2720.88
2487.28
2522.57
2555.91
2585.84
2619.43
239.080
238.730
237.240
235.850
239.250
68.130
68.760
69.540
69.750
69.020
4273.48
4369.54
4463.22
4549.26
4644.63
.~
3332.34
3419.23
3505.01
3589.54
3675.47
2.765
2.898
1.637
2.271
1.518
559127.02 E
559052.97 E
558979.28 E
558908.04 E
558836.98 E
5966733.21 N
5966686.01 N
5966640.12 N
5966593.28 N
5966544.11 N
2794.18 W
2868.61 W
2942.68 W
3014.31 W
3085.77 W
1857.55 8
1904.148
1949.428
1995.678
2044.26 8
2755.60
2791.30
2827.39
2864.55
2904.15
2654.15
2689.85
2725.94
2763.10
2802.70
236.540
239.390
237.730
236.560
235.010
68.260
67.500
67.360
65.540
65.230
4739.94
4834.74
4928.76
5021.77
5116.83
DrillQuest 2.00.09.003
3761.92
3845.97
3930.36
4014.05
4097.94
0.659
2.833
1.618
1.706
1 .462
558766.07 E
558695.53 E
558623.96 E
558552.82 E
558481.41 E
5966493.95 N
5966447.05 N
5966400.82 N
5966355.15 N
5966309.51 N
3157.09 W
3228.02 W
~ 3299.96 W
~371.48 W
3443.27 W
Page 3 of 5
2093.83 8
2140.15 8
2185.788
2230.868
2275.91 8
2944.71
2985.00
3026.51
3068.80
3111.45
2843.26
2883.55
2925.06
2967.35
3010.00
235.390
238.320
236.900
238.660
237.110
64.700
64.450
63.600
63.250
63.330
7 November, 2001- 13:10
5212.69
5306.50
5401.28
5495.81
5590.69
.
Sperry-Sun Drilling Services
Survey Report for 1C-125
Your Ref: API 500292304400
Job No. AKMM11165, Surveyed: 12 October, 2001
North Slope, Alaska
Kuparuk 1 C
Vertical
Section
Dogleg
Rate
(0/100ft)
Global Coordinates
Northings Eastings
(ft) (ft)
Local Coordinates
Northings Eastings
. (ft) (ft)
Vertical
Depth
(ft)
Sub-Sea
Depth
(ft)
Azim.
Unit
Incl
Kuparuk River
Measured
Depth
(ft)
-'<.
Comment
4183.05
4266.33
4349.26
4430.08
4517.23
0.268
2.408
0.730
3.976
0.933
558409.66 E
558338.21 E
558266.19 E
558198.18 E
558126.90 E
5966262.38 N
5966217.70 N
5966174.23 N
5966129.32 N
5966078.54 N
3515.40 W
3587.22 W
3659.60 W
3727.96 W
3799.67 W
2322.45 S
2366.54 S
2409.41 S
2453.76 S
2503.95 S
3154.78
3198.23
3241.89
3283.34
3326.41
3053.33
3096.78
3140.44
3181.89
3224.96
237.240
239.670
239.050
235.020
235.000
63.100
62.360
62.780
63.340
64.250
5686.85
5781.67
5876.45
5967.89
6065.44
4602.31
4687.95
4774.53
4859.09
4943.96
2.417
3.671
2.555
1.910
2.021
558058.49 E
557992.68 E
557929.34 E
557869.62 E
557811.58 E
5966027.57 N
5965972.75 N
5965913.64 N
5965853.40 N
5965790.77 N
3868.49 W
3934.75 W
3998.58 W
4058.79 W
4117.35 W
2554.35 S
2608.62 S
2667.21 S
2726.96 S
2789.11 S
3366.96
3406.74
3446.96
3487.35
3529.19
3265.51
3305.29
3345.51
3385.90
3427.74
232.580
228.780
226.120
224.320
222.260
64.910
65.290
64.920
64.160
63.640
6159.90
6254.35
6349.88
6443.83
6538.93
5025.22
5100.44
5174.54
5248.94
5320.26
9.640
6.413
3.002
3.848
3.380
557761.66 E
557722.77 E
557688.33 E
557656.98 E
557631.12 E
5965724.22 N
5965654.16 N
5965580.65 N
5965503.09 N
5965423.90 N
4167.82 W
4207.28 W
4242.33 W
4274.32 W
4300.83 W
2855.25 S
2924.98 S
2998.21 S
3075.51 S
3154.48 S
3572.49
3618.96
3666.92
3714.07
3760.22
3471.04
3517.51
3565.47
3612.62
3658.77
212.340
206.580
204.600
200.360
96.770
61.540
58.300
60.560
60.670
61.380
6632.81
6725.48
6819.78
6915.82
7011.07
5388.10
5452.37
5515.34
5576.38
5636.48
4.328
1.856
1.783
0.824
1.851
557610.93 E
557594;93 E
557580.98 E
557568.72 E
557555.66 E
5965343.45 N
5965263.63 N
5965183.40 N
5965104.19 N
5965027.33 N
4321.68 W
4338.34 W
4352.95 W
4365;87 W
4379.56 W
3234.75 S
3314.45 S
3394.55 S
3473.66 S
3550.41 S
3806.81
3855.27
3905.74
3956.67
4007.53
3705.36
3753.82
3804.29
3855.22
3906.08
192.320
191.290
189.380
189.160
191.080
60.000
58.480
57.950
57.190
56.570
7106.22
7200.97
7296.77
7391.74
7484.83
~
5698.74
5743.84
5789.29
1.042
1.249
0.000
557541.51 E
557532.06 E
557522.96 E
5964948.42 N
5964890.34 N
5964831.33 N
4394.36 W
4404.29 W
4413.88 W
3629.20 S
3687.20 S
3746.14 S
4061.14
4101.31
4142.40
3959.69
3999.86
4040.95
90.190
89.240'
89.240
55.890
55.470
55.470
7581.27
7652.52
7725.00
Projected Survey
FWL.
All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North.
Vertical depths are relative to RKB = 101.45' MSL. Northings and Eastings are relative to 1622' FNL & 898'
Magnetic Declination at Surface is 26.1 or (06-0ct-01
The Dogleg Severity is in Degrees per 100 feet (US)
Vertical Section is from 1622' FNL & 898' FWL and calculated along an
Azimuth of 229.680° (True)
Based upon Minimum Curvature type calculations, at a Measured Depth of 7725.00ft.
The Bottom Hole Displacement is 5789.29ft.. in the Direction of 229.678° (True)..
DrillQuest 2.00.09.003
Page 4 of 5
7 November, 2001 - 13:10
..
.
Sperry-Sun Drilling Services
Survey Report for 1C-125
Your Ref: API 50029230440
Job No. AKMM11165, Surveyed: 120
o
ctober,
-~
North Slope, Alaska
Kuparuk 1 C
2001
Comment
Projected Survey
Kuparuk River Unit
Comments
Measured Station Coordinates
Depth TVD Northings Eastings
(ft) (ft) (ft) (ft)
7725.00 4142.40 3746.14 S 4413.88 W
Survey tool program for 1 C-125
To
Measured Vertical
Depth Depth
(ft) (ft)
Fro m
Measured Vertical
Depth Depth
(ft) (ft)
,c
DrillQuest 2.00.09.003
Page 5 of 5
Survey Tool Description
MWD Magnetic
4142.40
7725.00
0.00
7 November, 2001-13:10
0.00
(,
~V~1rΠ(ffi~ fA\~~~[K(~
ALASIiA OIL AND GAS
CONSERVATION COMMISSION
/
/
/
/
I
/
TONY KNOWLES, GOVERNOR
333 W. -¡n< AVENUE, SUITE 100
ANCHORAGE, ALASKA 99501-3539
PHONE (907) 279-1433
FAX (907) 276-7542
Chuck Mallary
Drilling Engineering Supervisor
Phillips Alaska, Inc.
PO Box 100360
Anchorage AK 99510
Re: Kuparuk River Unit lC-125
Phillips Alaska, Inc.
Permit No: 201-199
Sur. Loc. 1622' FNL, 898, FWL, Sec. 12, TIIN, RI0E, UM
Btmhole Loc. 128' FNL, 1804' FWL, Sec. 14, TIIN, RI0E, UM
Dear Mr. Mallary:
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.
Annular disposal has not been requested as part of the Permit to Drill application for Kuparuk River Unit
lC-125. Please note that any disposal of fluids generated from this drilling operation which are pumped
down the surface/production casing annulus of a well approved for annular disposal on KRU 1 C must
comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does
not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space
of a single well or to use that well for disposal purposes for a period longer than one year.
The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the
mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC
25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the
BOPE test performed before drilling below the surface casing shoe, must be given so that a representative
of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum
field inspector on the North Slope pager at 659-3607.
Sincerely,
Û-~~'>:1J
Cammy Oechsli Taylor
Chair
, BY ORDER OF THE COMMISSION
DATED this 5th day of October, 2001
jj c/Enclosures
cc: Department ofFish & Game, Habitat Section w/o encl.
Department of Environmental Conservation w/o encl.
PHILLC 'S Alaska, Inc.
A Subsidiary of PHILLIPS PETROLEUM COMPANY
,{
,
Post Office Box 100360
Anchorage, Alaska 99510-0360
Chuck Mallary
Phone (907) 265-6434
Fax: (907) 265-1535
Email: anallar@ppco.com
October 2, 2001
Commissioner Cammy Oechsli Taylor
Alaska Oil and Gas Conservation Commission
333 West ih Avenue
Suite 100
Anchorage, Alaska 99501
(907) 279-1433
Re: Application for Permit to Drill, West Sak Injector lC-125
Dear Commissioner Taylor:
Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore service well, #lC-125, an injector well
to provide pressure support for West Sak production.
Please find attached for the review of the Commission Form 10-401 and the information required by 20
Ace 25.005.
If you have any questions or require any further information, please contact Steve McKeever at 265-
6826.
Sincerely,
ŒfL
Chuck Mallary
GKA Drilling Engineering Supervisor
RECEIVED
OCT 0 3 2001
Alaska Oil & Gas Cons. Commission
Anchorage
('
(" -J.. ~\I:. ,I C \
\ ó'''' \ oJ\!
STATE OF ALASKA \0
ALASKA OIL AND GAS CONSERVATION COMMISSION
17.)#;ID(1
/~
PERMIT TO DRILL
20 AAC 25.005
1 a. Type of work:
Re-entry
2. Name of Operator
Phillips Alaska, Inc.
3. Address
P.O. Box 100360 Anchorage, AK 99510-0361
4. Location of well at surface
1622' FNL, 898' FWL, Sec. 12, T11 N, R10E, UM
At top of productive interval
655' FSL, 1973' FWL, Sec. 11, T11 N, R10E, UM
At total depth j'l lib
128' FNL, 1804' FWL, Sec. , T11 N, R10E, UM
12. Distance to nearest property line 13. Distance to nearest well
128' @ TD feet 1C-123 @ 25 feet
16. To be completed for deviated wells
Kickoff depth: 250 MD
18. Casing program
size
1b. Type of well.
Service 0
Exploratory Stratigraphic Test
Development Gas 0 Single Zone rn))
5. Datum elevation (DF or KB)
RKB = 102 feet AMSL
6. Property Designation oZSc.1'i ~
ADL 25650 ALK 46S
7. Unit or property Name
Kuparuk River Unit
8. Well number
1 C-125
9. Approximate spud date
October 5,2001
14. Number of acres in property
25 0
feet
Hole Casin
24" 16"
7.875" 5.5"
7.875" 3.5"
Development Oil
Multiple Zone 0
10. Field and Pool
Kuparuk River Field
West Sak Oil Pool
11. Type Bond (see 20 AAe 25.0251)
Statewide
Number
#59-52-180
Amount
$200,000
15. Proposed depth (MD and TVD)
7709' MD/4114' TVD
fi$
e 20 AAC 25.035 (e)(2))
At total depth (TVD)
Maximum hole angle
66°
Bottom
TVD
158'
3600'
4114'
TVD
41.2'
41.2'
3600'
MD
158'
6681'
7709'
19. To be completed for Redrill, Re-entry, and Deepen Operations.
Present well condition summary
Total Depth:
Plugs (measured)
measured
true vertical
feet
feet
Effective Depth:
Junk (measured)
measured
true vertical
feet
feet
Casing
Conductor
Surface
o
Length
Size Cemented
Measured depth
Perforation depth:
measured
true vertical
20. Attachments
Title: Drilling Engineering SupeNisor
Permit Number
;2D -
Commission Use Onl
AP mber ; I,. / Approval date
50- t)"Z-C¡' Z3D,Lf -OD
DYes 6l No
f8) No
o 3M; 0 5M;
True Vertical depth
RECEIVED
OCT 0:3 2001
Alaska Oil & Gas Cons. Commission
Anchorage
Conditions of approval Samples required
Hydrogen sulfide measures 0 Yes
Required working pressure for BOPE 0 2M;
Other:
Mud log required
Directional survey required
o 10M;D
See cover letter
for other requirements
o Yes iii' No
œ' Yes 0 No
~dS(XJ~\ß~~~~
by order of
the commission
Commissioner
Form 10-401 Rev. 12/1/85·
Submit in triplicate
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'3.tion for Permit to Drill, Well 1 C-125
Revision No.O
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Permit It - West Sak Well #1 C-125
Application for Permit to Drill Document
MoximizE
Well VgllI,I~
Table of Contents
1. Well Name.. .......... ................................ ........... ... ................ .... .................. ..... ............2
Requirements of 20 AAC 25.005 (f).............................. .......................................................................... 2
2. Location Sum mary .......... ............................... ..................... ................. .... ................2
Requirements of 20 AAC 25.oo5(c)(2) ................. .................................................................................. 2
Requirements of 20 AAC 25. o50(b)................................. ....................................................................... 3
3. Blowout Prevention Equipment Information .........................................................3
Requirements of 20 AAC 25. o05( c)(3) ................ .................................................................... ............... 3
4. Dri II i ng Hazards Information.... .............. ........ ............ .............................................3
Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 3
5. Procedure for Conducting Formation Integrity Tests ........................................... 3
Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 3
6. Casi ng and Cementi ng Program .............................................................................4
Requirements of 20 AAC 25.oo5(c)(6) .............................................................................. ......... ..... ....... 4
7. Diverter System Information ................ ........................ ...........................................4
Requirements of 20 AAC 25.oo5(c)(7) ...................................................................................................4
8. Dri II i ng FI u id Program ....................... ..... ........ ................................................. ........5
Requirements of 20 AAC 25. o05( c)(B) .................................................... ...............................................5
9. Abnormally Pressured Formation Information ...................................................... 5
Requirements of 20 AAC 25.005 (c)(9) . ................................................................................................. 5
1 O. Seism ic Analysis .......................................................... ....... ............ ............. ............5
Requirements of 20 AAC 25.005 (c)(1 0) ................................................................................................ 5
11. Seabed Condition Analysis .....................................................................................5
Requirements of 20 AAC 25.005 (c)(11) ........................ .......................................................... ..............5
12. Evidence of Bond i ng.......................... ...... ................................................................ 6
Requirements of 20 AAC 25.005 (c)(12) ........ .............. .......................................................................... 6
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13. Proposed Dri Iii ng Program ................. ..................................................................... 6
Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 6
14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 7
Requirements of 20 AAC 25.005 (c)(14) .. .................................................................... ........... ........ .......7
15. Attachments .... ............ ......... ...................... ...... ................. ... ......... ........................... 7
Attachment 1 Directional Plan....................................................................................... .................... ..... 7
Attachment 2 Drilling Hazards Summary........... ............... ...................................... .......... .............. ....... 7
Attachment 3 Cement Loads and CemCADE Summary. ...................................................................... 7
Attachment 4 Well Schematic. .............................................................. ................................................. 7
1. Well Name
Requirements of 20 AAC 25.005 (f)
Each well must be Identified by a unique name de:,ignated by the operator and a unique API number ass7'gned by the commission
under 20 MC 25.040(b). For a well with multiple well branches/ ea(.77 branch must 5imilady be Identified by a unique name and API
number by adding a suffix to the name designated for the well by the oper<'ltor and to the number assigned to the well by the
commission.
The well for which this Application is submitted will be designated as lC-125.
2. Location Summary
Requirements of 20 AAC 25.005(c)(2)
An application for a Permit to Drill must be accompanied by each of the following items/ except ('Or an item already on file with the
commission and identified in the application:
(2) a plat identifying the property and the property's owners and 51wwing
(A)the coordinates of'the proposed location of'the well at the surfaC6~ at the top of eacl7 objective f'ormation and at total depth
referenæd to governmental section línes.
(8) the coordinates of the proposed location of'the well at the sur(;.x:e/ ref'erenced to the state plane coordinate system for thi"
state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration;
(C) the proposed depth ot'the well at the top of each opjective f'ormation and at total depth;
Location at Surface
NGS Coordinates
Northings: 5,968,613.75
11622' FNL, 898' FWL, Section 12, TllN, Rl0E, UM
I RKB Elevation I
Eastings: 561,905.78 I Pad Elevation I
102.0' AMSL
60.8' AMSL
Location at Top of
Productive Interval
West Sak "D" Sand
NGS Coordinates
Northings: 5,965,578
655' FSL, 1973' FWL, Section 11, TllN, Rl0E, UM
Eastings: 557,728
6781
3600
3498
Location at Total De th
NGS Coordinates
Northings: 5,964,794 Eastings: 557,566
128' FNL 1804' FWL Section 13 TllN Rl0E UM
Measured De th RKB: 7709
Total Vertical De th RKB: 4114
Total Vertical De th 55: 4012
and
1C-125 PERMIT IT. DOC
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(D) other information required by 20 MC 2S.050(b)/·
Requirements of 20 AAC 25.050(b)
If a well is to be intentionally deviate~ the application for a Permit to Dr/II (Form 10-401) must
(1) include a plat, drawn to a suitable scale/ showing tl7e path of the proposed wellbore/ including all adjacent wellbores wIthin 200
feet of any portion of the proposed well;
Please see Attachment 1: Directional Plan and Anti-Collision Report
and
(2) for all wells within 200 feet of the proposed wellbore
(A) list the names of the operators of tlJOse well~ to the extent tl7at those names are known or discoverable in public records".
and show that each named operator has been furnished a copy of the application by certified mail· or
(B) state that the applicant is tile only affected owner.
The Applicant is the only affected owner.
3. Blowout Prevention Equipment Information
Requirements of 20 AAC 25.005(c)(3)
An application for a Pelmlt to Onll must be accompanied by each ol the lollowing Items¡ exæpt for an item already on tìle with the
commission and identified in the application:
(3) a diagram and descliption of the blowout prevention equipment (BOPE) as required by 20 AAC 2S.03~ 20 AAC 25.03~ or 20
AAC 25.037, as applicable;
Please see "Diagram and Description of the Blowout Prevention Equipment for Nabors Rig 245e", placed
on file with the Commission with the Application for Permit to Drill for welllC-133, dated April 26th, 2001.
4. Drilling Hazards Information
Requirements of 20 AAC 25.005 (c)(4)
An application for a Permit to Olill mU5"t be accompanied by each of the following items~ except for an item already on fìle with the
commission and identified in the application:
(4) information on dtilling hazard5~ including
(A) the maximum downhole pressure that may be encountered; LTiteria used to determine i~ and maximum potential swfåæ
pressure based on a methane gradienç'
The expected reservoir pressures in the West Sak sands in the lC pad area vary from 0.43 to 0.46 psi/ft,
or 8.2 to 8.8 ppg EMW (equivalent mud weight). These are pressures obtained from actual well test data
from the nearby WS1-0l well.
The maximum potential surface pressue (MPSP) based on the above maximum pressure gradient, a
methane gradient (0.11) and the vertical depth of the expected base of the West Sak formation is 1429
psi, calculated thusly:
MPSP =(4084 ft)(0.46 - 0.11 psi/ft)
=1429 psi
(8) data on potential gas zones",
The well bore is not expected to penetrate any gas zones.
and
(C) data concerning potential caU$es of hole problems such as abnol7nally geo-pres'!iured strata, lost circulation Z0f7e5~ and zones
thatlJave a propensity for differential stic*ing;
Please see Attachment 2: lC-125 Drilling Hazards Summary.
5. Procedure for Conducting Formation Integrity Tests
Requirements of 20 AAC 25.005 (c)(5)
An application for a Permit to Olill must b(7 accompanied by each ot'the following item.~ except for an item already on tìle with the
commi..'ision and identified in the application:
(5) a description of the procedure f'Or conducting formation integrity testSr as required under 20 MC 25:030(f)/
1 C-125 PERMIT IT. DOC
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As the well will be completed with a single casing string that will not be drilled out, no formation integrity
tests are planned. In the unlikely event that it does become necessary to drill out a casing string with
blowout prevention equipment installed, a formation integrity test will be performed in accordance with
the LOT / FIT procedure, that Phillips Alaska has on file with the Commission.
6. Casing and Cementing Program
Requirements of 20 MC 25.005(c)(6)
An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the
commission and identified in the application:
(6) a complete proposed casing and cementing program as required by 20 MC 25.030" and a description of any slotted linet; pre-
petforated linet; or screen to be installed,:
Casing and Cementing Program
Hole Top Btm
CsgfTbg Size Weight Length MDfTVD MDfTVD
00 (in) (in) (Ib/ft) Grade Connection (ft) (ft) (ft) Cement Proqram
16 24 62.5 H-40 Welded 117 41/41 158 / 158 Cemented to
surface with
225 cf
ArcticSet 1
5-1/2 7-7/8 15.5 L-80 BTC,AB 6640 41/41 6681 / 3600 Cemented to
Modified Surface with
3-1/2 7-7/8 9.3 L-80 EUE 8rd, 1028 6681 / 3600 7709/4114 600 sx ASLite
AB Lead, 430 sx
Modified Class G Tail
See also Attachment 3: Cement Loads and CemCADE Summary.
7. Diverter System Information
Requirements of 20 AAC 25.005(c)(7)
An applicatìo{l for a Permit to Drill must be accompanied by each of the fbllowing items" excr:.pt for an Item already on tHe wit/¡ the
commL<;sion and Identified in the application:
(7) a diagram and description olthe dìverter system as requ/Ì'ed by 20 AAC 25.03.~ unless tl7ìs requirement is waived by the
COmmis.,70n under 20AAC 25,035'(17)(2)/
Please see "Diagram And Description of the Diverter System For Nabors Rig 245e", placed on file with
the Commission with the Application for Permit to Drill for weIl1C-133, dated April 26th, 2001.
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8. Drilling Fluid Program
Requirements of 20 AAC 25.005(c)(B)
An application for a PermIt to Drill must be accompanied by each of tl7e following Items, except for an item already on file with the
commission and Identified in the application:
(8) a drilling fluid program/ including a diagram and description of the drilling fluid system/ as required by 20 AAC 25.033;
Drilling will be done with a bentonite slurry having the following properties over the listed intervals:
Spud to Base of Permafrost Base of Permafros to Total Depth
Initial Value Final Value Initial Value Final Value
Density (ppg) 8.5 9.2-9.4 9.2-9.4* 9.2-9.4*
Funnel Viscosity 150-200 150-200 150 75
(seconds)
Yield Point 30-60 30-60 20-40 18- 30
(cP)
Plastic Viscostiy 8-15 11-22 15-30 15-30
(lb/100 sf)
10 second Gel 10-30 10-25 10-25 10-25
Strength (lb/100 sf)
10 minute Gel 25-55 25-55 20-40 20-40
Strength (lb/100 sf)
pH 8-9 8-9 8-9 8-9
API Filtrate(cc) 8-15 6 5-6 5-6
Solids (%) 5-8 5-8 5-8 6-11
*9.8 ppg if hydrates are encountered
Please see "Diagram of Mud System, Nabors Rig 245e", placed on file with the Commission with the
Application for Permit to Drill for welllC-133, dated April 26th, 2001.
This drilling fluid system of Nabors Rig 245e consists of: (3) Continental Emsco FB-1600 Mud Pumps,
Steel Mud pits with 1100 barrel capacity, Pill Pit, Trip Tank, (3) Derrick Flo-line Shale Shakers (rated at
600 gpm), Brandt Model SRS-2 Desander, Derrick Model 58S Mud Cleaner, (2) Alpha-Laval Model 418-\(f:"
5 Centrifuges, Degassers, PVT System with visual and audio alarms, Trip Tank, Flow Sensor, and Fluid
Agitators.
Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033.
9. Abnormally Pressured Formation Information
Requirements of 20 AAC 25.005 (c)(9)
An application for a PermIt to On/I must be accompanied by each of the following Itern.~ except for an item already on fIle with the
comml$sion and identified in the application:
(9) for an exploratory or strat~qraphic test well, a tabulatlÓn settin.q out the depths of predic:ted abnormally geo-pressured strata as
required by 2(} AAC 2S.033(f}/
Not applicable: Application is not for an exploratory or stratigraphic test well.
10. Seismic Analysis
Requirements of 20 AAC 25.005 (c)(10)
An application for a Pel7mt to Olill must be accompanied by each of the following Item~; except for an item already on fIle with the
C'Ommission and identified in the applk....ation:
(10) for an exploratory or stratigraphic test well, a seismic retraction or reflection analysis as required by 20 MC 2.'i.061(a)/
Not applicable: Application is not for an exploratory or stratigraphic test well.
11. Seabed Condition Analysis
Requirements of 20 AAC 25.005 (c)(11)
An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file wIth the
commiS!;;ïÓn and identified in the applic.:¡tion:
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(11) for a well drilled from an offs/70re platform/ mobJle bottom-founded structufe/ jack-up rig/ or floating drilling vessel, an analysis
of seabed conditions as required by 20 AAC 25. 061 (bJ/
Not applicable: Application is not for an offshore well.
12. Evidence of Bonding
Requirements of 20 MC 25.005 (c)(12)
An application for a Permit to Drill mllst be accompanied by each of the following items.. except for an item already on file with the
commission and Identified in the application:
(12) evidence showing that the requirements of 20 MC 25.025 {Bonding}have been me~'
Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission.
13. Proposed Drilling Program
Requirements of 20 AAC 25.005 (c)(13)
An application for a PermIt to Drill must be accompanied by each of the following items.. except for an item already on file with the
commission and identified in the application:
The proposed drilling program is listed below. Please refer as well to Attachment 4/ Well Schematic.
1. Excavate cellar, install cellar box, set and cement 16" conductor. Weld landing ring on conductor.
2. MIRU Nabors Rig 245e. Install diverter and function test same.
3. Spud and directionally drill 7-7/S" hole to desired targets through West Sak interval. Run MWD/LWD
logging tools in drill string as required for directional monitoring and formation data gathering.
4. Circulate and condition hole to run casing.
5. Run and cement 5-1/2" 15.5# L-SO BTCM x 3-1/2" 9.3# L-SO EUE Srd tapered casing string to
surface. Displace cement with 9.0 ppg brine and perform stage job or top job if required.
Note: 5-1/2" Port Collar to be installed @ +/- 1/000' TVD.
6. Nipple down diverter and install wellhead. Nipple up 3-ram 5/000 psi BOP stack and pressure test
annular to 1500 psi and pipe rams and inside choke and kill line valves to 2500 psi.
7. PU and RIH with 3-1/2" tubing to just above seal bore extension and displace well to clean seawater.
S. Sting into seal bore extension and space out.
9. Unsting seal assembly, and freeze protect well with diesel.
10. Sting back into seal bore extension and land tubing.
11. Using diesel, pressure test tubing and casing x tubing annulus to 500 psi for 10 minutes.
12. Install back pressure valve.
13. Nipple down BOP stack. Install production tree and pressure test same.
14. Secure well and release Nabors Rig 245e.
Post Rig Work:
1. Pull back pressure valve.
2. Rig up and pressure test tubing and tubing annulus to 3/000 psi for 30 minutes, recording test on
chart.
3. Rig up wireline and make a drift run to PBTD. Clean out as necessary.
4. Rig up and run SCMT Bond log at 1000 psi tubing pressure.
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5. Rig up and perforate well for injection.
14. Discussion of Mud and Cuttings Disposal and Annular Disposal
Requirements of 20 AAC 25.005 (c)(14)
An application for a Permit to Drill mustc be accompanied by eacl7 of the following Items, except for an Item already on file witl7 the
commission and identified in the application:
(14) a general description of how tl7e operator plans to dispose of drilling mud and cuttings and a statement of whether the
operator intends to request authorization under 20 MC 25.080 for an annular disposal operation in the well./
Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids
into a permitted annulus on lC pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings
generated will be either stored temporarily on site or hauled to the Prudhoe Bay Field for temporary
storage and eventual processing for injection down an approved disposal well.
Phillips Alaska does not intend to request authorization for the use of this well for annular disposal
operations.
15. Attachments
Attachment 1 Directional Plan and Anti-Collision Report(12 pages)
Attachment 2 Drilling Hazards Summary (1 page)
Attachment 3 Cement Loads and CemCADE Summary (1 page)
Attachment 4 Well Schematic (1 page)
1 C-125 PERMIT IT. DOC
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Reference is True North
Current Well Properties
Plan: 1 C-125
Phillips Alaska, nc.
North Slope, Alaska
Kuparuk River Unit
1 -125 ( p01)
Well:
Horizontal Coordinates:
Ref. Global Coordinates:
Ref. Stucture Referance :
Ref. Geographical Coordinates
5968613.75 N, 561905.78 E
95.13 N, 465.50 W
700 19' 29.2213" N, 149029' 52.8817" W
(1622' FNL & 898' FWL, Sec 12·T11N-R10E)
1 02,OOft above Mean Sea Level
True North
Feel (US)
RKB Elevation
North Reference
Units:
o
--"
sper'r'y-sul1
D A tL,~.!!L,G S EiJ3V lC;J¡~
A HaltJblH"OOIl Comp.;¡ny
IC- ¡ 25 (H'c,\'t Sill. ,1.1 TtH'í(efj;
75' Uadius Circle r(¡; 7078.70tt Mf), 37')I).tlfJµ 1TfJ
.IU{¡.5N'S & 4276.71' IV o/Sln
rs/, &. 1899' FWL See 1 ¡ - TllN - UltJF
TVD
1683.381
@ 3.0000/100ft : 250.00ft MD, 250.00ft TVD
750.00ft MD, 744.31ft TVD
2028.08ft MD.
Rate @ 4.00/100f
End Dir, Start Sail @ 66.123°
Dir
Increase in Dir
Begin
çj:ß .00
800
600
2400
.c
ã.
<1>
o
(ij
(.)
t
<1>
>
Begin Dir @ 4.00/100ft: 6039.32ft MD.
5-1/2" x 3-1/2" Casing X-O
.....
~........ 1r:fJo;;/'/
~,
~O,r:fJ
~
6681.00ft MD
Total Depth: nOB.70ft MD, 4114.00ft TVD
28' FNL & 1804' FWL, See 14 - T11N - R10E)
6400
5600
4800
4000
2400
600
800
o
3200
4000
Phillips Alaska, nc. SPSI'I'Y--S;UI1
North Slope, Alaska D RÎL L I N G s;ï~R \!-!.Ç;_ 'ª.~
'~~y':>;-~?'*y..¡....,!-:~~~....-.,,:~V""""___--=.. __ __ _...,
Kuparuk River Unit 1\ tial~¡bl,rt(l11 COffl'jJ'.any
1 C-125 (wp01 )
-4800 -4000 -3200 -2400 600
-5600 ---L- ---L- L
I I I ---------. .."_h_
E&'r ,62~
@3 0
0 - -- --- .--.--..... .---. .
._u_n"',_,_, _n. __.____________ ..._ _....____.....___ .... ......_._...._. .__ ___._.__.___.___ .
Increase in Dir Rate @ 4.00/100ft
~=-
End Dir, Start Sail @ 66.123° : 2028.08ft MD, 1683.38ft
-800
-800 -
-1600
-1600 - (J)
(J) Q)
c
Q) :c
c
:c t
t 0
0 '/,'6 Z
Z ;Y 1£t?OO
Begin Dir @ 4.00/100ft : 6039.32ft MD, 3307.02ft T Reference is True North
!-{oo -2400
-2400 Current Well Properties ~"
5-112" x 3-112' Cas;ngX-O' > Well: Plan: 1 C-125
6681.00ft MD, 3600.16ft ~ Horizontal Coordinates:
Ref. Global Coordinates : 5968613.75 N, 561905.78 E
ú'sCV Ref. Stucture Referance : 95.13 N. 465.50 W
Ref. Geographical Coordinates: 70' 19' 29.2213" N, 149029' 52.8817" W
'00 (1622' FNL & 898' FWL, Sec 12-T11N-R10E)
RKB Elevation: 1 02.oolt above Mean Sea Level
North Reference True North -3200
-3200 Units: Feet(US)
'----
~OO
" Õ
" 0
'-~ !" --.--...--... ---------....-----... CJ)
5-1/2' X 3-1/2' Casirg 1C-125 (West 5ak rlJ T(lJ~~{;tJ: II
¡ 75' Radius Circle 0;' 7lì78]Oft AID. 37(J9J)(ìft TH £.
7708.701\ MD U
4114.00ft TVD 32./6.58' S & ·1276.71' W of SHL .S
{./w' FSL &. 189.'J' FilL, See 11 - TIIN - RWm åi
-4000 <õ
Total Depth: 7708.70ft MD, 4114.00ft TVD u
-4000 28' FNL & 1804' FWL, See 14 - T11N - R10E) (fJ
¡- ¡- I J -r T
I ¡-
-4000 -3200 -2400 600 -800 0
-5600 -4800
Scale: 1 inch = 800ft Eastings
DrillQuest 2.00.09.003
~--
Kuparuk River Unit
North Slope, '1.
Kuparuk 1 C, Sid'
Plan: 1C-1 C-
Re .
OSAL REPORT
25 September, 2001
I~""-
Proposal Ref: pr09635
Your Ref: per Prelim Plan version #O.A
Surface Coordinates: 5968613.75 N, 561905.78 E (70019' 29.2213" N, 149029' 52.8817" W)
Surface Coordinates relative to Project H Reference: 968613.75 N, 61905.78 E (Grid)
Surface Coordinates relative to Stucture Referance: 95.13 N, 465.50 W (True)
Kelly Bushing: 102.000 above Mean Sea Level
C)
:x:~
-"0-
{;
---
-.".-
~
:t'
r=-~
Sperry-Sun Drilling Services
Proposal Report for Plan: 1C-125 -1C-125 (wp01)
Your Ref: per Prelim Plan version #O.A
Revised: 25 September, 2001
North Slope, Alaska
Kuparuk 1 C
Comment
Vertical
Section
Dogleg
Rate
(0/100ft)
FV
SHL: X = 561905.78' E & Y =
5968613.75' N (1622' FNL & 898'
Sec 12-T11 N-R10E)
~--"--
Surface Conductor
0.00
0.00
0.00
0.00
0.00
0.000
0.000
0.000
0.000
Local Coordinates
Northings Eastings
(ft) (ft)
Vertical
Depth
(ft)
Sub-Sea
Depth
(ft)
Kuparuk River Unit
Measured
Depth
(ft)
0.00 E
0.00 N
0.00
100.00
120.00
200.00
250.00
-102.00
-2.00
18.00
98.00
148.00
Azim.
0.000
0.000
0.000
0.000
0.000
Incl
0.000
0.000
0.000
0.000
0.000
0.00
100.00
120.00
200.00
250.00
250.00ft
Begin Dir @ 3.0000/100f
MD, 250.00ft TVD
0.65
5.87
16.30
31.90
52.63
3.000
3.000
3.000
3.000
3.000
561905.24 E
561900.90 E
561892.24 E
561879.28 E
561862.06 E
5968613.38 N
5968610.45 N
5968604.60 N
5968595.84 N
5968584.20 N
299.99
236.420
236.420
236.420
236.420
236.420
1.500
4.500
7.500
1 0.500
13.500
300.00
400.00
500.00
600.00
700.00
Increase in Dir Rate @ 4.00/100f
750.00tt MD, 744.31ft TVD
64.91
78.66
111.12
150.09
195.36
3.000
4.000
4.000
4.000
4.000
561851.86 E
561840.44 E
561813.47 E
561781.10 E
561743.49 E
N
5968569.59 N
5968551 .37 N
5968529.50 N
5968504.09 N
5968577.31
54.22 W
65.70 W
92.82 W
125.37 W
163.19W
35.99 S
43.62 S
61.62 S
83.22 S
108.32 S
.90
.93
.02
5.000
17.000
21.000
25.000
29.000
750.00
800.00
900.00
1000.00
1100.00
-
246.72
303.92
366.68
434.69
507.62
4.000
4.000
4.000
4.000
4.000
561700.82 E
561653.30 E
561601.16 E
561544.66 E
561484.06 E
5968475.27 N
5968443.17 N
5968407.95 N
5968369.79 N
5968328.86 N
206.09 W
253.88 W
306.31 W
363.12 W
424.06 W
136.79 S
168.49 S
203.28 S
240.97 S
281.40 S
1153.71
1235.61
1313.31
1386.43
1454.62
1051.71
1133.61
1211.31
1284.43
1352.62
236.434
236.436
236.437
236.438
236.439
33.000
37.000
41 .000
45.000
49.000
200.00
300.00
400.00
1500.00
1600.00
End Dirt Start Sail @ 66.1230 :
2028.08ft MD, 1683.38ft TVD
DrillQuest 2.00.09.003
585.12
666.80
752.28
841 .13
866.63
4.000
4.000
4.000
4.000
4.000
561419.67 E
561351.80 E
561280.78 E
561206.95 E
561185.77 E
5968285.38 N
5968239.54 N
5968191.58 N
5968141.72 N
5968127.42 N
488.80 W
557.05 W
628.46 W
702.70 W
724.00 W
Page2of7
324.35 S
369.63 S
417.00 S
466.24 S
480.38 S
1517.54
1574.88
1626.38
1671.77
1683.38
1415.54
1472.88
1524.38
1569.77
1581.38
236.440
236.440
236.441
236.442
236.442
C>
:::t:J
-.r~_~
~:>
~-_o.-
--~
~
~:.25 September, 2001- 9:31
~'
53.000
57.000
61.000
65.000
66.123
700.00
800.00
1900.00
2000.00
2028.08
·".
. ". ..... ..' .'
Sperry-Sun Drilling Services
Proposal Report for Plan: 1C-125 - 1C-125 (wp01)
Your Ref: per Prelim Plan version #O.A
Revised: 25 September, 2001
North Slope, Alaska
Kuparuk 1 C
Comment
Vertical
Section
Dogleg
Rate
(0/100ft)
Global Coordinates
Northings Eas~ings
(ft) (ft)
Local Coordinates
Northings Eastings
(ft) (ft)
Base Permafrost
932.23
1023.43
1 061.80
1114.64
1205.84
0.000
0.000
0.000
0.000
0.000
561131.27 E
561055.48 E
561023.61 E
560979.70 E
560903.92 E
778.80
855.00
887.06
931 .20
516.738
567.288
588.54 8
617.83 8
668.378
---
1297.05
1388.25
1479.46
1570.66
1661.87
0.000
0.000
0.000
0,000
0.000
560828.14 E
560752.36 E
560676.58 E
560600.80 E
560525.02 E
5967885.91 N
5967834.74 N
5967783.57 N
5967732.39 N
5967681.22 N
753.07
1844.28
1935.48
2026.69
2117.89
0.000
0.000
0.000
0.000
0.000
560449.24 E
560373.46 E
560297.67 E
560221.89 E
560146.11 E
5967630.04 N
5967578.87 N
5967527.69 N
5967476.52 N
5967425.34 N
w
w
w
w
w
1464.61
1540.81
1617.01
1693.21
1769.41
.668
1022.21 8
1072.75 8
1123.30 8
1173.85 8
Top K-15
2154.62
2209.10
2300.30
2391.51
2482.72
0.000
0.000
0.000
0.000
0.000
560115.59 E
560070.33 E
559994.55 E
559918.77 E
559842.99 E
5967404.73 N
5967374.17 N
5967322.99 N
5967271 .82 N
5967220.64 N
1800.10 W
1845.61 W
1921.81 W
1998.01 W
2074.21 W
1194.21 8
1224.408
1274.958
1325.498
1376.04 S
-~.
DrillQuest 2.00.09.003
2573.92
2665.13
2756.33
2847.54
2938.74
3029.95
3121.15
3212.36
3303.56
3394.77
0.000
0.000
0.000
0.000
0.000
559767.21 E
559691.43 E
559615.65 E
559539.86 E
559464.08 E
5967169.47 N
5967118.30 N
5967067.12 N
5967015.95 N
5966964.77 N
2150.41 W
2226.61 W
2302.82 W
2379.02 W
2455.22 W
1426.59 8
1477.14 S
1527.688
1578.23 8
1628.78 8
0.000
0.000
0.000
0.000
0.000
559388.30 E
559312.52 E
559236.74 E
559160.96 E
559085.18 E
5966913.60 N
5966862.42 N
5966811.25 N
5966760.07 N
5966708.90 N
2531.42 W
2607.62 W
2683.82 W
2760.02 W
2836.22 W
Page 3 of7
1679.33 S
1729.87 S
1780.42 S
1830.97 S
1881.528
Vertical
Depth
(ft)
1712.50
1752.97
1770.00
1793.45
1833.93
1874.40
1914.88
1955.36
1995.84
2036.31
2255.00
2279.18
2319.65
2360.13
2400.61
2441.08
2481.56
2522.04
2562.52
2602.99
2643.47
2683.95
2724.42
2764.90
2805.38
Sub-Sea
Azim. Depth
(ft)
236.442 1610.50
236.442 1650.97
236.442 1668.00
236.442 1691.45
236.442 1731.93
236.442 1772.40
236.442 1812.88
236.442 1853.36
236.442 1893.84
236.442 1934.31
236.442 1974.79
236.442 2015.27
236.442 205§.~~
236.442 20g~122
236.442 ~Î 36iiiJJ
2:36.442 4iJ53.00
236.442 2177.18
236;444 2217.65
236:442 2258.13
236.442 2298.61
236.442 2339.08
236.442 2379.56
236.442 2420.04
236.442 2460.52
236.442 2500.99
236.442 2541.47
236.442 2581.95
236.442 2622.42
236.442 2662.90
236.442 2703.38
Kuparuk River Unit
Measured
Depth Incl
(ft)
2100.00 66.123
2200.00 66.123
2242.07 66.123
2300.00 66.123
2400.00 66.123
2500.00 66.123
2600.00 66.123
2700.00 66.123
2800.00 66.123
2900.00 66.123
3000.00 66.123
3100.00 66.123
3200.00 66.123
3300.00 66.123
3400.00 66.123
3440.27 66.123
3500.00 66.123
3600.00 66.123
3700.00 66.123
3800.00 66.123
3900.00 66.123
4000.00 66.123
4100.00 66.123
4200.00 66.123
4300.00 66.123
4400.00 66.123
<:) 4500.00 66.123
4600.00 66.123
=0 4700.00 66.123
- 4800.00 66.123
~
----
~
f'25 September, 2001 - 9:31
...<:..
,~ , .
Sperry-Sun Drilling Services
Proposal Report for Plan: 1C-125 -1C-125 (wp01)
Your Ref: per Prelim Plan version #O.A
Revised: 25 September, 2001
North Slope, Alaska
Kuparuk 1 C
Comment
Vertical
Section
Dogleg
Rate
(0/100ft)
Global Coordinates
Northings Eastil1gs
(ft)( ft)
.-,
3485,97
3577.18
3668,38
3759.59
3850.79
0.000
0.000
0.000
0.000
0.000
59009.40 E
58933.62 E
58857.84 E
558782.05 E
558706.27 E
Top Ugnu C
3942.00
4015.81
4033.20
4124.41
4215.62
0.000
0.000
0.000
0.000
0.000
558630.49 E
558569.16 E
558554.71 E
558478.93 E
558403.15 E
Local Coordinates
Northings Eastings
(ft) (ft)
Vertical
Depth
(ft)
Sub-Sea
Depth
(ft)
Kuparuk River Unit
Measured
Depth
(ft)
2912.42 W
2988.62 W
3064.82 W
3141.02 W
32 ·W
1932.06 S
1982.61 S
2033.16 S
2083.71 S
2134.26 S
2845.86
2886.33
2926.81
2967.29
3007.77
2743.86
2784.33
2824.81
2865.29
2905.77
Azim.
236.442
236.442
236.442
236.442
236.442
Incl
66.123
66.123
66.123
66.123
66.123
4900.00
5000.00
5100.00
5200.00
5300.00
5966401.85 N
5966360.44 N
5966350.68 N
5966299.50 N
5966248.33 N
3048.24
3081.00
3088.72
3129.20
3169.67
2946.24
2979.00
2986.72
3027.20
3067.67
236.442
236.442
236.442
236.442
236.442
66.123
66.123
66.123
66.123
66.123
5400.00
5480.93
5500.00
5600.00
5700.00
4306.82
4398.03
4489.23
4525.09
0.000
0.000
0.000
0.000
558327.37 E
558251 .59 E
558175.81 E
558146.01 E
5966197.15 N
5966145.98 N
5966094.80 N
5966074.68 N
3598.23 W
3674.43 W
3750.63 W
3780.59 W
2386.99 S
2437.54 S
2488.09 S
2507.96 S
M
6039.32f
OOf
Begin Dir @ 4.0°/
3307.02ft TVD
Top Ugnu B
Top Ugnu A
4554.08
4580.34
4670.77
4683.93
4760.04
4847.73
4.000
4.000
4.000
4.000
4.000
4.000
558122.13 E
558100.86 E
558030.25 E
558020.31 E
557964.65 E
557904.39 E
5966058.16 N
5966042.73 N
5965986.23 N
5965977.57 N
5965925.22 N
5965859.97 N
3804.60 W
3826.00 W
3897.08 W
3907.08 W
3963.17 W
4023.97 W
2524.29 S
2539.55 S
2595.46 S
2604.04 S
2655.93 S
2720.67 S
66.123
66.123
66.123
66.123
5800.00
5900.00
6000.00
6039.32
3331.96
3374.60
3381.00
3418.99
3464.90
65.715
65.355
64.183
64.022
63.136
62.222
6071.13
6100.00
6200.00
6214.66
6300.00
6400.00
--
K-13 Shale
4933.41
4975.11
5016.65
5082.02
4.000
4.000
4.000
4.000
557849.77 E
557824.80 E
557801.04 E
557766.06 E
5965790.82 N
5965755.10 N
5965718.09 N
5965656.81 N
4079.16 W
4104.43 W
4128.49 W
4163.98 W
2789.38 S
2824.89 S
2861.70 S
2922.69 S
3512.12
3536.00
3560.41
3600.16
3410.12
3434.00
3458.41
3498.16
216.544
214.309
212.033
208.343
61 .448
61.118
60.822
60.426
6500.00
6549.70
6600.00
6681.00
6681.001
Casing X-O
TVD
5-1/2" x 3-1/2'
MD,3600.16f
Top West Sak D
C
DrillQuest 2.00.09.003
B
5097.06
5160.16
5174.25
5215.48
5247.83
5254.42
4.000
4.000
4.000
4.000
4.000
4.000
557758.45 E
557728.44 E
557722.19 E
557704.91 E
557692.46 E
557690.05 E
5965642.15 N
5965578.19 N
5965563.35 N
5965518.61 N
5965482.09 N
5965474.48 N
W
Page 4 of7
4171.71
4202.24 W
4208.61 W
4226.26 W
4239.01 W
4241.48 W
2937.29 S
3000.99 S
3015.78 S
3060.38 S
3096.79 S
3104.38 S
3609.54
3650.00
3659.28
3687.00
3709.37
3714.00
3507.54
3548.00
3557.28
3585.00
3607.37
3612.00
207.473
203.733
202.877
200.321
198.259
197.833
60.348
2001 - 9:31
60.079
60.032
59.925
59.876
59.870
6700.00
c::>
:x::J
---
ø
--
:ë:::
~
r---- September,
6781 .42
6800.00
6855.40
6900.00
6909.23
."",
'. ". ..0. .
Sperry-Sun Drilling Services
Proposal Report for Plan: 1C-125 -1C-125 (wp01)
Your Ref: per Prelim Plan version #O.A
Revised: 25 September, 2001
North Slope, Alaska
Kuparuk 1 C
Comment
Vertical
Section
Dogleg
Rate
(0/100ft)
Global Coordinates
Northings Ea!i!ÍI.,gs
(ft)(ft)
Local Coordinates
Northings Eastings
(ft) (ft)
Vertical
Depth
(ft)
Sub-Sea
Depth
(ft)
Kuparuk River Unit
Measured
Depth
(ft)
A4
5304.49
5317.44
5369.22
4.000
4.000
4.000
557673.27 E
557669.39 E
557656.00 E
4258.75 W
4262.76 W
4276.71 W
3163.93 S
3179.93 S
3246.58 S
3750.00
3759.57
3799.00
3648.00
3657.57
3697.00
Azim.
94.516
93.635
90.000
Incl
59.868
59.882
60.000
6980.93
7000.00
7078.70
3799.00ft TV[
-
5.00
Target: 7078.70t
A3 Target
1C-125 (West Sak A3 Targl:..
Radius., Current Target
MD,
A2
5382.86
5446.89
5463.99
5510.93
5574.96
5607.42
5638.99
0.000
0.000
0.000
0.000
0.000
0.000
0.000
557652.95 E
557638.61 E
557634.79 E
557624.28 E
557609.94 E
557602.68 E
557595.61 E
N
N
5965205.60 N
5965142.99 N
5965057.58 N
5965014.28 N
5964972.17 N
3809.65
3859.65
3873.00
3909.65
3707.65
3757.65
3771
90.000
90.000
190.000
190.000
190.000
190.000
190.000
60.000
60.000
60.000
60.000
60.000
60.000
60.000
7100.00
7200.00
7226.70
7300.00
7400.00
7450.70
7500.00
MD, 4114.001
A1
Base West Sak
7708.70t
Total Depth
TVD
5-1/2"
5703.03
5734.21
5767.06
5772.63
0.000
0.000
0.000
0.000
557581.28 E
557574.29 E
557566.94 E
557565.69 E
5964886.77 N
5964845.17 N
5964801.36 N
5964793.93 N
4355.10 W
4362.43 W
4370.14 W
4371.45 W
3691.18 S
3732.71 S
3776.47 S
3783.89 S
60.000
60.000
60.000
60.000
7600.00
7648.70
7700.00
7708.70
Casing
X 3-1/2'
~"
FWL.
All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North.
Vertical depths are relative to RKB = 102' MSL. Northings and Eastings are relative to 1622' FNL & 898'
Magnetic Declination at Surface is 26.1170 (25-Sep-01)
The Dogleg Severity is in Degrees per 100 feet (US).
Vertical Section is from 1622' FNL & 898' FWL and calculated along an Azimuth of 232.3200 (True)
Based upon Minimum Curvature type calculations, at a Measured Depth of 7708.70ft.
The Bottom Hole Displacement is 5781.64ft., in the Direction ot 229.1210 (True).
DrillQuest 2.00.09.003
Page 50f7
C
::t:J
----
c-:>
-----
~5 September, 2001 - 9:31
~
r--
Sperry-Sun Drilling Services
Proposal Report for Plan: 1C-125 -1C-125 (wp01)
Your Ref: per Prelim Plan version #O.A
Revised: 25 September, 2001
North Slope, Alaska
Kuparuk 1 C
-"
2-T11 N-R1 OE)
FWL, Sec
nates
Eastings
(ft)
on Coord
Northings
(ft)
Stat
TVD
(ft)
Kuparuk River Unit
Comments
Measured
Depth
(ft)
Comment
SHL: X = 561905.78' E & Y_..$ N
Begin Dir @ 3.0 Oft: 2 liD, 250.00ft TVD
Increase in Di .00/1O,o.00ft MD, 744.31ft TVD
~nd Di 1.23° : 2028.08ft MD, 1683.38ft TVD
ßegin 6039.32ft MD, 3307.02ft TVD
0.00 E
0.00 E
54.22 W
724.00 W
3780.59 W
0.00 N
0.00 N
35.99 S
480.38 S
2507.96 S
0.00
250.00
744.31
1683.38
3307.02
0.00
250.00
750.00
2028.08
6039.32
5-1/2", Casing X-O : 6681.00ft MD, 3600.16ft TVD
Targsg; 7078.70ft MD, 3799.00ft TVD
Total Depth: 7708.70ft MD, 4114.00ft TVD
Formation Name
n
P 0
o n
a
r
Pen e
Sub-Sea
Depth
(ft)
2922.69 S
3246.58 S
3783.89 S
3600.16
3799.00
4114.00
Formati on Plan
(Below Well Orig'
Sub-Sea Dip
(ft) Deg.
6681.00
7078.70
7708.70
Formation Tops
Eastings
(ft)
Northings
(ft)
-
Base Permafrost
Top K-15
Top Ugnu C
Top Ugnu B
Top Ugnu A
887.06 W
1800.10 W
3355.09 W
3804.60 W
3907.08 W
588.54 S
1194.21 S
2225.71 S
2524.29 S
2604.04 S
1668.00
2153.00
2979.00
3218.00
3279.00
1770.00
2255.00
3081.00
3320.00
3381.00
2242.07
3440.27
5480.93
6071.13
6214.66
O.
0.472
0.472
0.472
0.472
0.000
0.000
0.000
0.000
0.000
1668.00
2153.00
2979.00
3218.00
3279.00
K-13 Shale
Top West Sak D
C
B
A4
4104.43 W
4202.24 W
4226.26 W
4241.48 W
4258.75 W
2824.89 S
3000.99 S
3060.38 S
3104.38 S
3163.93 S
3434.00
3548.00
3585.00
3612.00
3648.00
3536.00
3650.00
3687.00
3714.00
3750.00
6549.70
6781.42
6855.40
6909.23
6980.93
0.472
0.472
0.472
0.473
0.472
0.000
0.000
0.000
0.000
0.000
3434.00
3548.00
3585.00
3612.00
3648.00
DrillQuest 2.00.09.003
Page 6 of 7
<::)
:::c
---
Ç)
--
~
~ 25 September, 2001 - 9:31
r---
Sperry-Sun Drilling Services
Proposal Report for Plan: 1C-125 - 1C-125 (wp01)
Your Ref: per Prelim Plan version #O.A
Revised: 25 September, 2001
North Slope, Alaska
Kuparuk 1 C
Eastings
(ft)
n
P 0
o n
Northings
(ft)
a
Pen e
Sub-Sea
Depth
(ft)
o f i Ie
Vertical
Depth
(ft)
P
Measured
Depth
(ft)
Kuparuk River Unit
Formati on Plane
(Below Well Origin)
Sub-Sea Dip Dip Dir.
(ft) Deg. Deg.
Formation Tops (Continued)
4Zitth71 W A3 T,
4298J9}'l,·W A2
4332.65W A 1
4362.43 W Base West
arget
3799.00
3873.00
3985.00
4084.00
7078.70
7226.70
7450.70
7648.70
0.472
0.472
0.472
0.472
0.000
0.000
0.000
0.000
3697.00
3771.00
3883.00
3982.00
Sak
asing Detai
Casing details
From
Measured Vertical
Depth Depth
(ft) (ft)
Surface Conductor
5-1/2" x 3-1/2" Casing
<SUlͪ,ce>
<Surfàce>
<Surface>
<Surface>
.-..
Target
Type
Current Target
Target
Shape
Circle
Entry Coordinates
Northings Eastings
(ft) (ft)
Target
TVD
(ft)
Targets associated with this wellpath
4276.71 W
557656.00 E
49° 31' 57.6691" W
3246.58 S
5965332.00 N
700 18' 57.2764" N
3799.00
3697.00
Mean Sea LeveVGlobal Coordinates:
Geographical Coordinates:
Target Radius:
Target
Name
C-125 (West Sak A3 Target
75.00ft
a
::t::J
~
C,
---,
-......
C:.-
::t:' 25 September, 2001 - 9:31
~-
(wp01 )
1 C-125
V.S.
(ft)
DLS
(°/1 OOft)
X
(ft)
y
(ft)
EIW
(ft)
N/S
(ft)
ps Alaska, Inc.
TVD
(ft)
SSTVD
(ft)
ill i
Azim.
(De9)
Ph
Inc
(De9)
MD
(ft)
,'-"'-
Comment
SHL
Surface Conductor
D"'n;n Dir
Inci in DLS
End )tart Sai
5-1/2" X 3-1/2" (X-D)
Top \¡Vest Sak 0
C
B
A4
Target (A3)
(,2
Ai
West
Base Permafrost
Top K-'15
Top Ugnu C
Begin Dir
Top Ugnu ß
Top Ugnu A
K-13 Shale
LJ....~" I
0.00
0.00
0.00
64.91
866.63
1 Oß1.80
2154.63
4015.81
4525.09
4554.08
4683,93
4975.11
5082.02
5160.16
5215.48
5254,42
5304.49
5369.22
5463,99
5607,42
5734,21
5772.63
0.00
0.00
0.00
3.00
4.00
0.00
0.00
0.00
0.00
4.00
4.00
4.00
4.00
4.00
4,00
4.00
4,00
4.00
0,00
0.00
0.00
0.00
561905.78 E
561905.78 E
561905,78 E
561851.86 E
561185.77 E
561023,61 E
560115.59 E
558569,16 E
558146.01 E
558122,13 E
558020.31 E
557824,80 E
557766.06 E
557728.44 E
557704.91 E
557690.05 E
557673.27 E
557656.00 E
557634.79 E
557602,68 E
557574.30 E
557565,69 E
5968613.75 N
5968613.75 N
5968613.75 N
5968577.31 N
5968127.42 N
596801 Ï,91 N
5967404,73 N
5966360.44 N
5966074.68 N
5966058.16 N
5965977.57 N
5965755,10 N
5965656.81 N
5965578.19 N
5965518,61 N
5965474.48 N
5965414.80 N
5965332.00 N
5965205.60 N
5965014.28 N
5964845.17 N
5964793.93 N
0.00 E
0.00 E
0.00 E
54.22 W
724.00 W
887.06 \Iv
1800.10 VV
3355.09 VV
W
\/'1
VV
'N
W
'N
4226.26 VV
4241.48 VV
A ..,;; n, "7 c: Vv
W
Vv
\N
\/V
W
3780.59
3804.60
3907.08
4104.43
4163.98
4202.24
'-t<:::"J~; I...)
4276.71
4332.65
4362.43
4371 .45
0.00 N
0.00 N
0.00 N
35.99 S
480.38 S
588.54 S
1194.21 S
2225.71 S
2507.96 S
2524.29 S
2604.04 S
2824.89 S
2922.69 S
3000.99 S
3060,38 S
3104.38 S
3163.93 S
3246.58 S
3372.80 S
3563.85 S
3732.71 S
3783.89 S
0.00
120.00
250.00
744.31
1683.38
1770.00
2255,00
3081.00
3307.02
3320.00
3381,00
3536.00
3600.16
3650.00
3687.00
3714.00
3750.00
3799.00
3873.00
3985.00
4084.00
4114.00
-102.00
18.00
148.00
642.31
1581.38
1668.00
2153.00
2979.00
3205,02
3218.00
3279.00
3434.00
3498.16
3548.00
3585.00
3612.00
3648.00
3697.00
3771.00
3883.00
3982.00
4012.00
0.00
0.00
0.00
236.42
236.44
236.44
236.44
236.44
236.44
235.12
229.06
214.31
208.34
203.73
200.32
197.83
194.52
190.00
190.00
190.00
190.00
190.00
0.00
0.00
0.00
15.00
66.12
66,12
66.12
66,12
66.12
65.72
64.02
61,12
60.43
60.08
59.93
59.87
59.87
60.00
60.00
60.00
60.00
60.00
0.00
120.00
250.00
750.00
2028.08
2242.07
3440,27
5480.93
6039.32
6071.13
6214.66
6549.70
6681.00
6781.42
6855.40
6909.23
6980.93
1018.70
7226.70
7450.70
7648.70
7708.70
Base Sak
Total Depth
~
:::J:J
--
ta)
----
<:
~
.--
I
nH,U'A.'ò
1'hlIit.\ t\LL·J¡,."1m:
I~....'TIV
Kup.w.J.;.
Tool
CB-GYRO-S
MWI>
SURVEY PROGRAM
Depth Fm Deplh To Slm'e)'lPlan
41.20 900.00 PJanneJ: IC-I25 (\\pOl) VI
900.00 7709.19 Planœd: IC-I25 (»pOl) VI
.<\1'\'TI-COLLISION SETTINGS
50.00
ïï09.19
Plan: IC-12S
SIoI
NJA
L:mgitude
49";:g52.8.S2W
Lllitude
70" 19'29.22IN
WElL Dh'T AIlS
Nor1hing Ea.-ain
5968613. 561905.
+FJ-W
-trð 54
+N/-
95_1
~
},l/I
V~'lh'f1
tuÜ'
Interval:
To:
Reference:
Interpolation Method:1l.-ID
Depth Range From: 41.20
Maximum Range: 5000.00
Draft PI a 11 (wpOl)
-
SECTION DnAII$
Soc MD In<: Aó TV ) +Ni-S +E/W PI... TFJ<' V,<.i¡;,; T
4UO 0.00 0.00 . 1.21) IJ.W (UXI O.U(I 0.00 n.on
250.l'O 0.00 O.l~) ¿IO.CO n.m 0.'" n.oo 0.1"1 O.I.()
750.00 15.00 2Yd2 7·14..11 ..15.'!') ·~1.2::! I.I) ) 1.l('..I2 (...1.5."
2(2)1.15 (Id3 236.45 I 6X.1.4 I ·4XO. JX ·72-1,0-' -100 00.1 S(,I1\7
fIJWHJ M.lJ 2.16.45 W)Ó.I}J ·2507.l}.1 <'7XI,11 f),OO O(V) '>00.10
7079.19 (,0.00 190.00 379'J.lXI :t24r..(,2 ..1:!77.:tZ ·HX) ·IOX,tfl .~~~.¡(t)
7709.19 ÓO.OO 191).00 4114.00 -:<7K.!.9.! ..nnw, O.IX) o.m 7X2.1.1
S~h:¡
rrHUlIVI
----
-EGEND
I C-04 (I C-04). Major Risk
IC-OS (IC-05). Major Risk
IC-IO (IC-IO). Major Risk
I C-I 02 (I C-I 02 'B' Lateral). Maj.
I C-102 (I C-102 'I)' Lalcral). Maj
I C-III (I C-III ), Major Risk
I C- J 17 (I C-117), Major Risk
IC-119 (IC-119), Major Risk
I C-121 (I C-121). Major Risk
I C-12:! (I C-(23). Major Risk
I C-I27 (I C-(27). Major Risk
I C-131 (I C-131), Major Risk
I C-13 ( I C-D). Major Risk
I C-I3:! (I C-D3). Major Risk
I C-16 (I C-16), Major R)à...,
IC-18(IC-18),Majorl .
1D-112(1D-IJ2).Maje t>.
IC-125
I C-125 (wpO
Ofl:n
~i"Ï·W
~,\
liTl"I"Spkm lI.;CWS/\
SCIII "kdn& r,;I"d)ß..L., ;,;,'f1h
liT"r stñ......: I~ÜI + (·....it:
Wmif~ ~1.-I'p\ ; ~1I1-.c (1."...."'"
ToMD
100
200
300
400
500
600
700
900
] 100
1300
1800
2.~00
2800
3800
4800
5800
6800
7800
-
-
COIOI
-
From
o
100
200
300
400
500
600
700
900
1100
1300
1800
2300
2800
3800
4800
5S00
6800
90
wp01
o
270
Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [15ft/in]
Travelling Cylinder
IC-l25I1C-I25)
Dato: 9125.'2001
Oal!:-:
D-atc:
Date:
~-
:",,,, -..;.;.:::: b ("pOl) (Plarc
~ì"gcdal~
'hæ--=:
:o\';,,~
'PPro~~::---
Company:
Field:
Reference Site:
Reference Well:
Reference Wellpath:
Phillips Alaska Inc.
Kuparuk River Unit
Kuparuk 1 C Pad
Plan: 1 C-125
1 C-125
(
Sperry-SUD
Anticollision Report
(
Date: 9/25/2001
Time: 09:08:26
Page:
Co-ordinate(NE) Reference:
Vertical (TVD) Reference:
Well: Plan: 1C-125, True North
1 C-125 wi N245E @ 102' 102.0
Db: Oracle
Principal Plan & PLANNED PROGRAM
ISCWSA Ellipse
Trav Cylinder North
Ellipse + Casing
GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference
Interpolation Method: MD Interval: 50.00 ft
Depth Range: 41.20 to 7709.19 ft
Maximum Radius: 5000.00 ft
Survey Program for Definitive Wellpath
Date: 9/25/2001 Validated: No
Planned From To Survey
ft ft
41.20 900.00
41.20 7709.19
Casing Points
Planned: 1 C-125 (wp01) V1
Planned: 1C-125 (wp01) V1
Diameter
in
13.375
5.500
Hole Size
in
Name
Reference:
Error Model:
Scan Method:
Error Surface:
Version: 2
Toolcode
Tool Name
CB-GYRO-SS
MWD
Camera based gyro single shots
MW D - Standard
17.500
7.875
Summary
<::~.___m_.___m______ Offset Wellpath nm_________mm__>
Site Well Wellpath
Kuparuk 1 C Pad
Kuparuk 1 C Pad
Kuparuk 1 C Pad
Kuparuk 1 C Pad
Kuparuk 1 C Pad
Kuparuk 1 C Pad
Kuparuk 1 C Pad
Kuparuk 1 C Pad
Kuparuk 1 C Pad
Kuparuk 1 C Pad
Kuparuk 1 C Pad
Kuparuk 1 C Pad
Kuparuk 1 C Pad
Kuparuk 1 C Pad
Kuparuk 1 C Pad
Kuparuk 1 C Pad
Kuparuk 1 D Pad
1 C-04
1 C-05
1 C-1 0
1 C-1 02
1 C-1 02
1 C-111
1 C-117
1 C-119
1C-121
1 C-123
1 C-127
1 C-131
1 C-13
1 C-133
1 C-16
1 C-18
1 D-112
Plan: 1C-125,1C-125,1C
1 C-04 V1
1 C-05 V1
1C-10 V1
1 C-1 02 'B' Lateral VO
1 C-1 02 'D' Lateral V2
1C-111 VO
1C-117 V1
1C-119 VO
1C-121 V1
1C-123 V5
1C-127 V5
1C-131 V1 Plan: 1C-131
1C-13 VO
1C-133 V6
1C-16 VO
1C-18 VO
1 D-112 V2
Reference Offset Ctr-Ctr No-Go Allowable
MD 1\10 Distance Area Deviation Warning
ft ft ft ft ft
6200.04 6200.00 0.38 410.77 -306.73 FAIL: Major Risk
250.00 250.00 195.54 5.19 190.35 Pass: Major Risk
296.36 300.00 188.39 5.50 182.89 Pass: Major Risk
1222.35 1250.00 120.24 33.64 90.50 Pass: Major Risk
680.82 650.00 358.50 12.39 346.25 Pass: Major Risk
5892.81 10450.00 589.30 377.65 305.91 Pass: Major Risk
826.74 800.00 217.37 17.40 200.48 Pass: Major Risk
752.76 750.00 116.45 13.28 103.16 Pass: Major Risk
655.99 650.00 84.00 11.78 72.28 Pass: Major Risk
852.32 850.00 52.17 17.42 34.80 Pass: Major Risk
650.48 650.00 25.55 11.81 13.83 Pass: Major Risk
498.56 500.00 29.94 8.63 21.36 Pass: Major Risk
788.19 800.00 95.89 16.50 79.81 Pass: Major Risk
297.05 300.00 228.97 5.47 223.52 Pass: Major Risk
396.06 400.00 119.91 6.79 113.16 Pass: Major Risk
200.00 200.00 212.22 4.68 207.54 Pass: Major Risk
295.86 300.00 182.05 5.43 176.63 Pass: Major Risk
Out of range
ORIGINÅL
( (
lC-125 Drilling Hazards Summa~
(Please see well plan and attachments for detailed discussions of these risks.)
7-7/8" Open Hole / 5-1/2" x 3-1/2" Casing Interval
Hazard
Broach of Conductor
Risk Level Miti ation Strate
Low Monitor cellar continuously during interval,
reduced flow rates until BHA is below
conductor.
Low Control drill, Reduced pump rates, Reduced
drilling fluid temperatures, Additions of
d ri Itreat.
Moderate Maintain planned mud parameters,
Increase mud weight, use weighted
swee s run ravel isolation strin .
Low Diverter drills, increased mud weight.
Gas Hydrates
Running Sands and
Gravels
Abnormal Reservoir
Pressure
Lost circulation
Hole swabbing on trips
Low Reduced um rates mud rheolo LCM
Moderate Trip speeds, Proper hole filling, pumping
out
This Summary to be Posted in the rig doghouse, in
accordance with instructions of the AOGCC.
10-125 Drilling Hazards Summary
prepared by steORrG I N A l
Schlumberger
Preliminary Job Design based on limited input data. For estimate purposes only.
Rig: Nabors 245E
Location: West Sak
Client: Phillips Alaska, Inc.
Revision Date: 9/26/01
Prepared by: Kevin Tanner
Location: Anchorage, AK
Phone: (907) 265-6205
Mobile: (907) 230-6628
email: ktanner@slb.com
Volume Calculations and Cement Systems
(Volumes are based on 250% excess in the permafrost and 35% excess below the
permafrost. Top of tail slurry is designed to be 500' above the crossover.
Lead Slurrv (minimum pump time 240 min.)
ARCTICSET* Lite @ 10.7 ppg, Class G + 50%0124,9% (BWOW) 044, 0.6%D46,
30%053, 1.5%S1, 0.5% 065, 1.5%079 - 4.44 fe/sk
< TOC at Surface
A"evious Csg.
< 16", 62.6# casing
at 120' rvD
< Base of Permaf rost at
2,242' rvD (1 ,770' 1V D)
< 51/2",15.5# casing
in 7 7/8" OH
Top of Tail
< at 6,189' rvD
< X-over at 6,689' rvD
< Top of A3rrarget
at 6,781' rvD
< 31/2",9.3# casing
in 7 7/8" OH
TO at 7,709' rvD
(4,114' 1VD)
Mark of Schlumberger
50 bbls x 5.6146 fe/bbl (cement to surface) =
1.1034 fe/ft x (120') x 1.00 (no excess) =
0.1733 fe/ft x (2242' - 120') x 3.50 (250% excess) =
0.1733 fe/ft x (6189' - 2242') x 1.35 (35% excess) =
280.7 fe + 132.4 fe + 1287.1 fe+ 923.4 fe =
2623.6 fe 14.44 ft3/sk =
Round up to 600 sks
280.7 fe
132.4 fe
1287.1 fe
923.4 fe
2623.6 fe
590.9 sks
Have 160 sks of additional Lead on location for Top Out stage, if necessary.
Tail Slurrv (minimum pump time 150 min.)
Class G + 2.0 gps 0600G, 0.2 gps 047, 0.3% M117, 0.45% 065 -1.16 ft3/sk
0.1733 fe/ft x (6689' - 6189') x 1.35 (35% excess) = 117.0 ft3
0.2714 fe/ft x (7709' - 6689') x 1.35 (35% excess) = 373.7 ft3
0.0488 ft3/ft x 90' (Shoe Joint) = 4.4 fe
117.0 ft3 + 373.7 fe + 4.4 fe = 495.1 fe
495.1 fel 1.16 fe/sk = 426.8 sks
Round up to 430 sks
BHST = 88°F (BHST calculated using a gradient of 2.4°F/1 00 ft. below the permafrost)
PUMP SCHEDULE
Stage
Pump Rate
(bpm)
Stage
Volume
Cumulative
Stage Time Time
(min)
(bb ) (min>
CW 100 5 60 12.0 12.0
Drop Bottom Plug 3.0 15.0
MudPUSH*XL 5 50 10.0 25.0
Lead Slurry 5 474 94.8 119.8
Tail Slurry 5 89 17.8 137.6
Drop Top Plug 3.0 140.6
Displacement 5 147 29.4 170.0
Bump Plug 2.5 20 8.0 178.0
MUD REMOVAL
Recommended Mud Properties: 9.8 ppg, Pv ::::: 15-20, T y ::::: 15-20. As thin and light as
possible to aid in mud removal during cementing.
Spacer Properties: 10.5 ppg MudPUSH* XL, Pv::::: 17-20, T y::::: 20-25
Centralizers: Recommend 1 per joint across zones of interest for proper cement
placement.
ORIGINAL
Well # 1 C...,~ ~5, AFE # 0206
West Sak f".~nobore Injector
Planned Completion Schematic,
Sheet 1 of 1
~HILLIPS Alaska, Inc.
A Subsidiary of PHILLIPS PETROLEUM COMPANY
16" Conductor
@ +1- 158' MD
Tubing Hanger:
(475-0525) 3-1/2" Vetco-Gray w/ 3-1/2"
pup (EUE 8rd, AB Mod pin) down x
3.725" MCA box up
Casing Hanger:
(492-1810) 5-1/2" Vetco-Gray w/5-1/
2" pup (BTCM pin) down x 7.790"
MCA box up
Landing Ring:
(492-9750) Vetco-Gray, 16"
Weld on Bottom x 13-5/8" Male
Overshot Top
Christmas Tree:
(475-0605) Vetco-Gray, API 5K 7-1/
16" Flange Bottom x API 5K 3-1/8"
Valves, with Otis 5-3/4" 5K Tree Top
Tubing Head:
(475-0515) Vetco-Gray, 10-
3/4" Gray Quick Connect
Bottom x API5K 7-1/16"
Flange Top
Port Collar @ 1,000' MD:
(491-9350) TAM 5-1/2" BTC
Box x Pin
Gas Lift Mandrel:
(477-4825) 3-1/2" x 1" Camco 'KBG-2-9' wi dummy valve
(474-7315), IBT special clearance box up x IBT special
clearance box down, with 6-foot tubing handling pups (XO to
EUE 8rd) installed on top and bottom.
(1) Joint Tubing
Landing Nipple: (461-6545) 3-1/2" Camco 'OS' wi 2.81211 No-Go
Profile.
(1) Joint Tubing
Locator Seal Assembly: (461-3435) 3-1/2" Baker GBH-22 '80-
40' wi 12' of Seals and Locator, 3-1/2" x 6' L-80 Handling Pup
(455-3185) installed on top. EUE 8rd AB Mod Box up.
Production Tubing:
(423-1660) 3-1/2" 9.3# L
EUE 8rd, AB Modified.
Production Casing
(467-0750) 5-1/2" 15.5# L-80
BTCM
XO I SBE to surface
Set XO I SBE +1- 100' above
top Perforation
~ Casing Bore Receptacle Assembly(461-3470) @ +1- 6,681' MD,
3,600' TVD:
[Baker 5-1/2" XO I Handling Pup, BTC x BTC
Baker XO Coupling wi locator shoulder, BTC x SBE
Baker 5" 00 x 4" ID Seal Bore Extension 12'
Baker XO, SBE x 3-1/2" EUE 8rd
Production Casing
(423-1660) 3-1/2" 9.3# L-80 EUE
8RD-Mod
TD to XO I SBE
(x) Joints Tubing, from Landing Sleeve to Seal Bore Extension
TD 7-7/8" Hole
7,708' MD, 4,114' TVD
Landing Sleeve: 3-1/2" Weatherford, installed in top of joint #3.
(1) Joint Tubing (468-0725) Joint with Collar Thread Locked
Float Collar: (500-1580) 3-1/2" Halliburton Super Seal II,
wi 3-1/2" EUE 8rd Box x Pin.
(2) Joints Tubing
Float Shoe: (500-1585) 3-1/2" Halliburton Super Seal II, wi
3-1/2" EUE 8rd Box Up.
American Expressœ Cash Advance Draft 166
DATE ~ 3.2et>{ R')-4n/ln?1
(
~~YD:~ ~~E Sf-f;!¿j~td /tð~~_ J $I/OCi.OO~
----- OM.. _ ~ 4-. ~ _ DOLLARS
Issued by Integrated Payment System. Inc.
Englewood. Colorado
Payable at Norwest Bank of Grand Junction. Downtown, NA
Grand Junction. Colorado
PERIOD ENDING
IC-/~~
I: * 0 2 * 0 0 .... 0 0 I: j 5 III 0 * 7 5000 5 j bill 0 * b b
CHECK 1
ST ANDARD LETTER
DEVELOPMENT
DEVELOPMENT
RED RILL
EXPLORATION
INJECTION WELL
/
INJECTION WELL
RED RILL
( (
TRANS:MITAL LETTER CHECK LIST
CIRCLE APPROPRIATE LE'ITER/PARAGRAPHS TO
BE INCLUDED IN TRANSMUTTAL LETTER
I e.- /2.S
WELL NAME j¿/2 l'{
(If api number last two (2)
digits are between 60-69)
PILOT HOLE (PH)
ANNULAR SPOSAL
NO
ANNULAR DISPOSAL
<-J YES
ANNULAR DISPOSAL
THIS WELL
DISPOSAL INTO OTHER
ANNULUS /
è{] YES +
SP ACING EXCEPTION
Templates are located m drive\jody\templates
"CLUE"
The permit is for a new wellbore segment of existing well
--' Permit No, API No.
Production should continue to be reported as a function of
the original API number stated above.
In accordance with 20 AAC 25.005(f), all records, data and
logs acquired for the pilot hole must be clearly
differentiated in both name (name on permit plus PH)
and API number (50 -70/80) from
records, data and logs acquired for well (name on permit).
Annular disposal has not been requested. . .
Annular Disposal of drilling wastes will not be approved. . .
Annular Disposal of drilling wastes will not be approved. . .
Please note that an disposal of fluids generated. . .
Enclosed is the approved application for permit to drill the
above referenced well. The. permit is approved, subject to
full compliance with 20 AAC 25.055. Approval to periorate
and produce is contingent upon issuance of a conservation
order approving a spacing exception.
(Companv Name) will assume the liability of any protest to
the spacing exception that may occur.
ADMINISTRA TION
, 'if...
COMPANY ) WELL NAME Ie. ·/2_
INIT CLASS ~e..y v/C'£ / uJ/NJ
1. Permit fee attached. . . . . . . . . . . del, ... " . . . ~ . . .
2. Lease number appropriate:~ .5.ri:.~. ,'). .'! -(7,:,,: -I (,-: '10. I. .
3. Unique well name and number. .. . . . . . . . . . . . . . . .
4. Well located in a defined pool.. . . . . . . . . . . . . . . . .
5. Well located proper distance from drilling unit boundary. N
6. Well located proper distance from other wells.. . N
7. Sufficient acreage available' in drilling unit.. . . . . . . . N.
8. If deviated, is wellbóre plat induded.. . . . . . . . . . . N
9. Operator only affected party.. . . . . . . . . . . . . . . . . . N
10. Operator has appropriate bond in force. . . . . . . . . . N
11. Permit can be issued without conservation order. . . . . . . . N
AP R DA v: 12. Permit can·be issued without administrative approval.. . . . N
:Þ ~( 13. Can permit be approved before 15-day wait.. . . . . . . . . . Y N
14. Conductor string provided .. . . . . . . . . . . . . . . . . . ~ N~
15. Surface casing protects all known USDWs. . . . . . .
16. CMT vol adequate to circulate on conductor & surf csg. .
1178' CcMMTT v~111 adequatlel kto ,tie-in lod0ngcts~ngh t~ surf esg. . ., . . .. ,~y --N.N ~"\ ~~ ~ ~ <'\ ~~
. WI cover a nown pr u lYe onzons. . . . . . . . . .
19. Casing designs adequate for C, T, B & permafrost. . . . . . . ' N ~ \
20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . ' N ~~'\ "~ ~~ .: ~~~~\~ .
21. If a re-drill, has a 10-403 for abandonment been approved. . . ~ ~ ~ ~. ,~\ _ t"(",, ~.... :nr-. ~\ r. ~ ......~
22. Adequate well bore separation proposed.. . . . . . . . . . . . _.~~ _~,--- ::::::. _ ~ ~ m~, _ ~ ''-J _I~~~!..'~
23. If diverter required, does it meet regulations . . . . . . . . . .
24. Drilling ,fluid program schematic & equip list adequate. . ~ . . N
25. BOPEs, do they meet regulation. . . . . . ''':''~7'\. . . . . N ~
26. BOPE press rating appropriate; test to ~ psig. N \--\~~ ~c:.... \- Q. \ '-\~--\ ~ \ '
27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N , -
28. Work will occur without operation shutdown. . . . . . . . . . . Â
29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y \tV
30. Penni! can be issued w/o hydrogen sulfide measures. . . . .. .~. N
31. Data presented on potential overpressure zones . . . . . . .
32. Seismic analysis of shallow gas zones. . . . . . . . . . ~. . N
APPR DA Tç / 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . Y N
~ì.> 10· ~,O 34. Contact name/phone for weekly progress reports [explora ry only] Y N
~NNULAR DISPOSAL35. With proper cementing records, this plan. þ...\) ~\- ~o->i,\ \Q. "" ~~,\c; ~ \ \, ~(\\~ ~,~ ~~,\~~\~~~ \,
(A) will contain waste in a suitable receiving zone; . . . . . . . Y N
(8) will not contaminate freshwater; or cause drilling waste. " Y N
to surface; .
(C) will not impair mechanical integrity pf the well used for disposal; Y N
(0) will not damage producing formation or impair recovery from a Y N
pool; and
E will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N
GEOLOGY: ENGINEERING:· UIC/Annular COMMISSION:
W~. '8~s
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WELL PERMIT CHECKLIST
FIELD & POOL
PROGRAM: exp
GEOLAREA
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N
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well bore seg
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ann. disposal para req
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GEOLOGY
tF;<r~c.k:.d ~e.rvôi r ;pJ"~5'-'re.. ~ 8, L Þ g, ß r~éJ é;7)¿J (~, '1,,5 -fò Ó, ¥c:Ç~¿/f-t)
APPR
DATE
~Þ8~
Comments/Instructions:
/ .
to/c'4/ol
c:\msoffice\wordian\diana\checklist (rev. 11/01/100)
f
Well History File
APPENDIX
Information of detailed nature that is not
particularly germane to the Well Permitting Process
but is part of the history file. .
To improve the readability of the Well History file and to
simplify finding information, information of this
nature is accumulated at the end of the file under APPENDIX.
No special' effort has been made to chronologically
organize this category of information.
( (
Memory Multi-Finger Caliper
Log Results Summary
¡.,
Company:
Log Date:
Log No. :
Run No.:
Pipe 1 Desc.:
Pipe1 Use:
Inspection Type:
CONOCOPHILLlPS ALASKA, INC.
August 1, 2005
6516
1
3.5" 9.3Ib. L-80
Tubing
Well: 1C-125
Field: Kuparuk
State: Alaska
API No.: 50-029-23044-00
Top Log IntvI1.: Surface
Bot. Log IntvI1.: 6,672 Ft. (MD)
Corrosive & Mechanical Damage Inspection
COMMENTS:
This caliper data is tied into the Nipple @ 6,610' (Driller's Depth).
This log was run to assess the condition of the 3.5" tubing with respect to corrosive and mechanical
damages. The 3.5" tubing appears to be in good to fair condition with respect to corrosive damage, with a
maximum wall penetration of 34% in pup joint 208.3 (6,577'). The damage appears in the forms of isolated
pitting, general corrosion, and lines of pits. No significant areas of cross-sectional wall loss or I.D.
restrictions are recorded throughout the tubing logged.
Cross-sectional drawings of the most significant events recorded are included in this report. The distribution
of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report.
MAXIMUM RECORDED WAll PENETRATIONS:
Isolated Pitting
Isolated Pitting
Isolated Pitting
Isolated Pitting
Isolated Pitting
( 34%)
( 33%)
( 32%)
( 32%)
( 30%)
208.3 @
55 @
58 @
198 @
206 @
6,577 Ft. (MD)
1,731 Ft. (MD)
1,853 Ft. (MD)
6,244 Ft. (MD)
6,479 Ft. (MD)
Jt.
Jt.
Jt.
Jt.
Jt.
MAXIMUM RECORDED CROSS-SECTIONAL METAL lOSS:
No significant areas of cross-sectional wall loss (> 8%) are recorded.
MAXIMUM RECORDED ID RESTRICTIONS:
No significant I.D. restrictions are recorded.
SCANNE.D l~UG 2 6 2.005
I Field Engineer: N.Kesseru Analyst: M. Tahtouh Witness: C. Fitzpatrick I
ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497
Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com
Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314
~ :J-.6) - ¡q ct
,-
~
clï3s"
Well:
Field:
Company:
Country:
1 C-125
Kuparuk
CONOCOPHILLlPS ALASKA, INC.
USA
Tubing:
Weight
9.3 f
Grade & Thread
L-80
Nom.OD
3.5 ins
Penetration and Metal Loss (% wall)
_ penetration body
250
200
150
100
50
~ metal loss body
o 0 to
1%
1 to
10%
1 0 to 20 to 40 to ove r
20% 40% 85% 85%
o
o
Damage Configuration ( body)
150
100
50
o
isolated general line ring hole / poss
pitting corrosion corrosion corrosion ible hole
o
{
PDS Report Overview
Body Region Analysis
Survey Date:
Tool Type:
Tool Size:
No. of Fingers:
Analyst:
Nom.lD
2.992 ins
Nom. Upset
3.5 ins
August 1, 2005
MFC 24 No. 00387
1.69
24
M. Tahtouh
Upper len.
1.2 ins
Lower len.
1.2 ins
Damage Profile (% wall)
_ penetration body
o
o
GLM 1
Bottom of Survey = 210.3
Analysis Overview page 2
~ metal loss body
50
100
49
99
149
199
( (
PDSKEPORT JOINT TABULATION SHEET
Pipe:
Body Wall:
Upset Wall:
NominaII.D.:
3.5 in 9.3 ppf L-80
0.254 in
0.254 in
2.992 in
Well:
Field:
Company:
Country:
Survey Date:
1 C-l 25
Kuparuk
CONOCOPHILLlPS ALASKA, INC.
USA
August 1, 2005
Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile
No. (Ft.) Upset Body % Loss 1.0. Comments (% wall)
(Ins.) (Ins.) % (Ins.) 0 50 100
.1 26 0 0.04 16 5 2.92 PUP Shallow corrosion. Lt. Deoosits. r'"
1 30 0 0.03 12 2 2.92 ·
1.1 62 0 0.03 12 4 2.91 !II
2 64 0 0.03 12 1 2.92 ·
3 96 0 0.04 15 2 2.92 Shallow oittim~. ..
4 127 0 0.04 18 5 2.91 Shallow corrosion. Lt. Deoosits. r·
5 159 0 0.02 9 2 2.93 II
6 190 0 0.03 12 1 2.92 Shallow pitting. ·
7 222 0 0.03 11 2 2.91 ~
8 253 0 0.02 8 2 2.94 ·
9 285 0 0.03 10 2 2.92 ~
10 316 0 0.03 12 2 2.89 ·
11 347 0 0.03 11 2 2.88 ·
12 379 0 0.03 12 2 2.92 ·
13 410 0 0.03 12 2 2.92 ~
14 441 0 0.03 13 3 2.88 Shallow j2itting. ·
15 473 0 0.03 13 4 2.86 Shallow pitting. Lt. Deoosits. ~
16 504 0 0.03 13 2 2.89 Shallow pitting. ·
17 536 0 0.03 11 2 2.88 ·
18 567 0 0.03 10 4 2.86 ..
19 598 0 0.02 9 2 2.88 ·
20 628 0 0.03 12 4 2.88 ..
21 660 0 0.03 13 2 2.89 Shallow pitting. ·
22 691 0 0.03 11 2 2.91 ·
23 723 0 0.03 12 '1 2.88 ·
24 754 0 0.04 14 2 2.89 Shallow J:>itti ng. "II
25 786 0 0.03 13 2 2.91 Shallow corrosion. III
26 817 0 0.04 14 1 2.93 Shallow corrosion. 11I1
27 849 0 0.03 11 2 2.91 III
28 880 0 0.04 15 3 2.92 Shallow pitting. ..'"
29 912 0 0.04 15 1 2.87 Shallow pitting. ~'"
30 943 0 0.02 7 2 2.89 II
31 975 0 0.04 14 2 2.88 Shallow pitting. ..
32 1006 0 0.02 9 2 2.87 ..
33 1037 0 0.04 15 2 2.92 Shallow pitting. ..
34 1069 0 0.05 21 3 2.94 I so lated J:titti m~:. ...
35 1100 0 0.03 11 2 2.92 II
36 1132 0 0.05 21 2 2.93 Isolated-º-itting. II !II
37 1163 0 0.03 12 2 2.92 Shallow -ºÎtting. II
38 1195 0 0.03 12 2 2.93 ·
39 1226 0 0.03 13 2 2.92 Shallow pitting. .~
40 1258 0 0.03 12 3 2.87 Lt. Deposits. pi
41 1289 0 0.03 11 2 2.91 II
42 1320 0 0.04 17 3 2.92 Shallow pitting. ..~
43 1352 0 0.03 12 2 2.88 Lt. Deposits. ·
44 1383 0 0.03 13 2 2.93 Shallow pitting. ·
45 1415 0 0.03 13 3 2.92 Shallow pitting. ·
46 1446 0 0.03 10 2 2.93 ·
47 1478 0 0.03 13 4 2.94 Shallow J~itting. ·
48 1509 0 0.03 11 8 2.89 I
. Penetration Body
~~: Metal Loss Body
Page 1
( r,f
~ ,
PDS KEPORT JOINT TABULATION SHEET
Pipe:
Body Wall:
Upset Wall:
NominaII.D.:
3.5 in 9.3 ppf L-80
0.254 in
0.254 in
2.992 in
Well:
Field:
Company:
Country:
Survey Date:
1 C-l 25
Kuparuk
CONOCOPHILLlPS ALASKA, INC.
USA
August 1, 2005
Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile
No. (Ft.) Upset Body % Loss I.D. Comments (% wall)
(Ins. ) (Ins.) % (Ins.) 0 50 100
49 1541 0 0.03 13 .:2 2.91 Shallow pitting. ·
50 1572 0 0.04 16 4 2.88 Shallow pitting. ..
51 1604 0 0.03 10 3 2.89 ·
52 1635 0 0.03 12 4 2.89 ""
53 1667 0 . 0.03 13 3 2.89 Shallow pitting. ·
54 1698 0 0.04 15 4 2.87 Shallow oitting. !III
55 1730 0 0.08 33 5 2.85 Isolated oittim:!:. ....
56 1761 0 0.07 28 4 2.85 Line of oits. !II..
57 1792 0 0.04 16 6 2.87 Shallow pitting. ...
58 1824 0 0.08 32 4 2.88 Isolated pitting. ...
59 1855 0 0.05 20 4 2.89 Isolated pitting. ..
60 1886 0 0.06 24 4 2.85 Isolated pitting. ""..
61 1918 0 0.05 20 4 2.87 Line shallow corrosion. "".
62 1949 0 0.06 23 5 2.80 Line of pits. Lt. Deposits. II.
63 1981 0 0.04 17 7 2.82 Shallow pitting. Lt. Deposits. II
64 2012 0 0.03 13 3 2.84 Shallow oitting.
65 2044 0 0.05 19 4 2.88 Shallow oitting. ..
66 2075 0 0.04 15 4 2.84 Shallow oitting. ·
67 2107 0 0.05 19 5 2.80 Shallow úitting. ...
68 2138 0.03 0.03 13 5 2.75 Shallow oitting. Lt. Deposits. II
69 2170 0 0.03 12 5 2.84 Lt. Deposits.
70 2201 0 0.03 12 4 2.81 ·
71 2232 0 0.05 21 5 2.81 Line of pits. ..
72 2264 0 0.04 16 6 2.84 Line shallow corrosion. III
73 2295 0 0.05 19 4 2.84 Shallow pitting. .,.
74 2327 0 0.06 24 7 2.82 Isoalted pitting. ~~
75 2358 0 0.04 16 6 2.83 Shallow oitting. II
76 2389 0 0.05 19 6 2.87 Shallow oitting. Lt. Deposits. II
77 2421 0 0.05 20 5 2.81 Shallow oitting. ~
78 2452 0 0.05 20 6 2.81 Line shallow corrosion. Lt. Deoosits. ..~
79 2484 0 0.06 22 7 2.83 Line of pits. " III
80 2515 0 0.04 18 4 2.84 Shallow pitting. . II
81 2547 0 0.04 17 5 2.81 Shallow pitting. ·
82 2578 0 0.04 16 4 2.79 Shallow pitting. ·
83 2610 0 0.03 13 6 2.83 Shallow pitting. Lt. Deposits.
84 2641 0 0.04 16 6 2.86 Shallow pitting. Lt. Deposits. ·
85 2673 0 0.05 18 5 2.82 Shallow pitting. Lt. Deposits. ..
86 2704 0 0.04 18 5 2.79 Line shallow corrosion. Lt. Deoosits. III
87 2735 0 0.05 19 5 2.81 Line shallow corrosion. Lt. Deoosits. ·
88 2767 0 0.05 20 5 2.77 Shallow oitting. Lt. Deposits. ..
89 2796 0 0.03 11 5 2.80
90 2828 0 0.03 13 4 2.80 Line shallow corrosion.
91 2859 0 0.05 20 5 2.80 Isolated pitting. Lt. Deposits. ..
92 2891 0 0.05 18 5 2.78 Shallow pitting. Lt. Deposits. ..
93 2922 0 0.04 15 5 2.78 Shallow pitting. Lt. Deposits. I
94 2954 0 0.04 17 5 2.84 Shallow pitting. ..
95 2985 0 0.04 18 6 2.84 Shallow pitting. I.
96 3016 0 0.04 17 5 2.81 Line of shallow pits. Lt. Deposits. ·
97 3048 0 0.04 17 6 2.81 Shallow pitting. Lt. Deposits. ,.
98 3079 0 0.04 15 6 2.80 Shallow oitting. p.
I Penetration Body
p~,!,',
I!r'i: Metal Loss Body
Page 2
t (
PD~\KEPORT JOINT TABULATION ~HEET
Pipe:
Body Wall:
Upset Wall:
N ominaII.D.:
3.5 in 9.3 ppf L-80
0.254 in
0.254 in
2.992 in
Well:
Field:
Company:
Country:
Survey Date:
1 C-125
Kuparuk
CONOCOPHILLlPS ALASKA, INC.
USA
August 1, 2005
Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile
No. (Ft.) Upset Body % Loss I.D. Comments (% wall)
(Ins.) (Ins.) % (Ins.) 0 50 100
99 3111 0.03 0.03 13 6 2.82 Shallow pitting. Lt. Deposits.
100 3142 0 0.04 14 6 2.81 Shallow pitting.
101 3172 0 0.04 17 5 2.82 Shallow pitting. ·
102 3203 0 0.04 16 6 2.78 Shallow oitting. Lt. Deoosits. I
103 3235 0 0.04 16 4 2.78 Line shallow corrosion. Lt. Deoosits. I
104 3266 0 0.03 11 8 2.82
105 3298 0 0.04 14 4 2.89 Shallow oitting. ..
106 3329 0 0.06 24 4 2.80 Isolated oitting. ..
107 3361 0 0.04 15 5 2.81 Shallow pitting. Lt. Deposits. I
108 3392 0 0.03 13 6 2.84 Shallow oitting.
109 3423 0 0.03 12 6 2.86
110 3454 0 0.04 17 6 2.85 Shallow pitting. ·
111 3486 0 0.04 17 6 2.82 Shallow pitting. ·
112 3517 0 0.05 20 6 2.80 Shallow pitting. Lt. Deposits. ·
113 3549 0 0.04 16 6 2.82 Shallow pitting. I
114 3580 0 0.03 11 6 2.84
115 3612 0 0.04 14 6 2.87 Shallow oitting. ·
116 3643 0 0.05 20 5 2.80 Isolated oitting. Lt. Deoosits. ·
117 3674 0 0.05 20 5 2.81 Shallow pitting. Lt. Deoosits. ·
118 3706 0 0.04 16 5 2.83 Shallow pitting. ·
119 3737 0 0.03 13 6 2.86 Shallow pitting. Lt. Deposits.
120 3769 0 0.04 14 6 2.88 Shallow pitting. ·
121 3800 0 0.06 24 5 2.89 Isolated piting. ·
122 3832 0 0.04 16 5 2.87 Shallow pitting. ·
123 3863 0 0.04 15 4 2.83 Shallow pitting. Lt. Deposits. ·
124 3894 0 0.04 15 5 2.81 Shallow pitting. I.
125 3926 0 0.04 16 5 2.73 Shallow oitting. Lt. Deposits. I.
126 3957 0 0.05 20 4 2.76 Isolated oitting. III.
127 3989 0 0.03 13 4 2.81 Shallow oitting. Lt. Deoosits. III
128 4020 0 0.03 13 5 2.86 Shallow oitting.
129 4051 0 0.04 15 4 2.87 Shallow pitting. I
130 4083 0 0.02 9 5 2.85
131 4114 0 0.03 10 6 2.88
132 4146 0 0.03 12 6 2.88
133 4178 0 0.04 14 5 2.88 Shallow pitting. ·
134 4209 0 0.03 13 4 2.82 Shallow pitting.
135 4240 0.03 0.03 12 6 2.77 Lt. Deposits. pitting.
136 4272 0 0.03 10 3 2.76 Lt. Deposits.
137 4303 0 0.04 17 5 2.77 Shallow corrosion. Lt. Deposits. ·
138 4335 0 0.03 13 5 2.77 Shallow oitting.
139 4366 0 0.06 23 5 2.79 Line of oits. Lt. Deoosits. ..
140 4398 0.03 0.05 21 4 2.81 Line of oits. Lt. Deoosits. ..
141 4429 0 0.04 16 6 2.82 Shallow pitting. Lt. Deposits. !III
142 4460 0 0.04 14 5 2.78 Shallow pitting. Lt. Deposits. !II
143 4492 0 0.04 17 5 2.75 Shallow pitting. Lt. Deposits. ..
144 4523 0 0.04 17 5 2.81 Shallow pitting. ..
145 4554 0 0.04 15 5 2.77 Shallow pitting. Lt. Deposits. ..
146 4586 0 0.03 11 6 2.77 Lt. Deposits. !II
147 4617 0 0.04 18 6 2.74 Line shallow corrosion. II.
148 4649 0.02 0.05 20 6 2.77 Shallow oitting. Lt. Deposits. II.
I Penetration Body
[I Metal Loss Body
Page 3
! 1
( ,
PDSKEPORT JOINT TABULATION sHEET
Pipe:
Body Wall:
Upset Wall:
NominaII.D.:
3.5 in 9.3 ppf L-80
0.254 in
0.254 in
2.992 in
Well:
Field:
Company:
Country:
Survey Date:
1 C-l 25
Kuparuk
CON OCOPH I LLI PS ALASKA, IN C.
USA
August 1, 2005
Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile
No. (Ft.) Upset Body 0/0 Loss I.D. Comments (% wall)
(Ins.) (Ins.) % (Ins.) 0 50 100
149 4680 0 0.04 15 5 2.83 Shallow oittim~:. . II
150 4711 0 0.03 12 5 2.79 Lt. Deoosits. II
151 4743 0 0.04 15 5 2.76 Shallow corrosion. Lt. Deoosits. . II
152 4775 0 0.05 18 7 2.85 Line shallow corrosion. Lt. Deoosits. III
153 4806 0 0.04 17 6 2.84 Shallow oitting. 1111I
154 4837 0 0.04 17 5 2.78 Line shallow corrosion. Lt. Deposits. . II
155 4868 0 0.05 19 5 2.82 Shallow pitting. Lt. Deposits. "' III
156 4900 0 0.04 14 5 2.78 Shallow pitting. Lt. Deposits. ""~
157 4931 0 0.04 16 6 2.79 Shallow pitting. II
158 4961 0 0.03 10 5 2.74 Lt. Deposits. II
159 4993 0 0.04 17 5 2.77 Shallow pitting. Lt. Deposits. "".
160 5024 0 0.03 13 6 2.73 Line shallow corrosion. Lt. Deoosits.
161 5055 0 0.04 15 7 2.78 Shallow oitting. Lt. Deoosits.
162 5087 0 0.03 10 5 2.80 Lt. Deoosits.
163 5118 0 0.03 12 7 2.85 Shallow oitting. Lt. Deoosits.
164 5150 0 0.04 15 6 2.82 Shallow oitting.
165 5181 0 0.04 16 5 2.81 Shallow pitting. Lt. Deposits. ·
166 5213 0 0.04 15 7 2.86 Shallow pitting.
167 5244 0 0.03 13 6 2.78 Shallow pitting. Lt. Deposits.
168 5276 0.03 0.03 12 6 2.78 Lt. Deposits.
169 5307 0.03 0.04 14 6 2.79 Shallow pitting.
170 5338 0 0.05 20 5 2.82 Shallow pitting. ·
171 5369 0 0.04 17 5 2.84 Shallow pitting. ·
172 5400 0 0.04 15 5 2.84 Shallow oitting. Lt. Deposits.
173 5432 0 0.03 12 6 2.75 Lt. Deoosits.
174 5463 0 0.02 9 5 2.77 Lt. Deoosits.
175 5495 0 0.03 10 6 2.77 Lt. Deoosits.
176 5526 0 0.05 20 6 2.80 Shallow oitting. Lt. Deoosits. ·
177 5558 0 0.03 10 5 2.79
178 5589 0 0.03 13 5 2.78 Shallow pitting. Lt. Deoosits.
179 5621 0.04 0.03 13 6 2.77 Shallow pitting. Lt. Deposits.
180 5652 0 0.02 9 5 2.89
181 5683 0 0.03 12 5 2.85
182 5714 0 0.02 9 5 2.84
183 5746 0 0.04 16 6 2.85 Shallow oitting. ·
184 5777 0 0.04 14 6 2.83 Shallow oitting.
185 5808 0 0.04 17 4 2.81 Shallow oitting. ·
186 5840 0 0.03 12 5 2.76 Lt. Deoosits.
187 5871 0.02 0.04 17 5 2.79 Shallow pitting. Lt. Deoosits. ·
188 5903 0 0.04 15 5 2.85 Shallow pitting. Lt. Deoosits. ·
189 5934 0 0.04 17 4 2.85 Shallow pitting. ·
190 5966 0 0.03 13 6 2.89 Shallow pitting.
191 5997 0 0.04 16 6 2.85 Shallow pitting. Lt. Deposits. ·
192 6028 0 0.05 20 6 2.79 Isolated pitting. ·
193 6060 0 0.04 16 5 2.82 Shallow pitting. Lt. Deposits. ·
194 6091 0 0.03 11 6 2.86
195 6123 0 0.03 10 5 2.86
196 6154 0 0.04 15 5 2.84 Line shallow corrosion. Lt. Deoosits. ·
197 6186 0 0.04 16 6 2.85 Line of shallow oits. ·
198 6217 0 0.08 32 6 2.83 Isolated oitting. ..
I Penetration Body
\',11',1,
,!\~tì Metal Loss Body
Page 4
~ (
PDSKEPORT JOINT TABULATION SHEET
Pipe:
Body Wall:
Upset Wall:
NominaII.D.:
3.5 in 9.3 ppf L-80
0.254 in
0.254 in
2.992 in
Well:
Field:
Company:
Country:
Survey Date:
1 C-125
Kuparuk
CONOCOPHILLlPS ALASKA, INC.
USA
August 1, 2005
Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile
No. (Ft.) Upset Body % Loss I.D. Comments (% wall)
(Ins.) (Ins.) % (Ins.) 0 50 100
199 6248 0 0.03 10 5 2.80 .
200 6280 0 0.05 19 5 2.81 Shallow pitting. Lt. Deposits. II.
201 6311 0 0.03 12 7 2.83
202 6343 0 0.03 13 6 2.80 Shallow oittim!:.
203 6373 0.09 0.03 13 7 2.74 Shallow oitting. Lt. Deoosits.
204 6404 0 0.04 18 6 2.76 Shallow oitting. Lt. Deoosits. ·
205 6435 0 0.05 20 7 2.83 Shallow oitting. ·
206 6467 0 0.08 30 6 2.85 Isolated pitting. ..
207 6498 0 0.04 15 5 2.78 Shallow pitting. Lt. Deposits. ·
208 6530 0 0.03 11 5 2.78 Lt. Deposits.
208.1 6561 0 0.05 20 9 2.81 PUP Shallow pitting. -
208.2 6566 0 0 0 0 N/A GLM (Latch @ 4:30)
208.3 6573 0 0.09 34 7 2.85 PUP Isolated pitting. Lt. Deposits. --
209 6579 0 0.02 7 7 2.83 I
209.1 6610 0 0 0 0 2.81 Nioole
210 6611 0 0.03 11 6 2.81 r
210.1 6641 0 0 0 0 3.00 SEAL
210.2 6647 0 0.00 1 6 2.89 PUP II
210.3 6659 0 0 0 0 N/A SBE
. Penetration Body
1'¡;,::1 Metal Loss Body
Page 5
clr3_ >6
.' . II'
PDS Report Cross Sections
Well:
Field:
Company:
Country:
Tubin :
1 C-125
Kuparuk
CONOCOPHILLlPS ALASKA, INC.
USA
3.5 ins 9.3 f L-80
Survey Date:
Tool Type:
Tool Size:
No. of Fingers:
Anal st:
August 1, 2005
MFC 24 No. 00387
1.69
24
M. Tahtouh
Cross Section for Joint 208.3 at depth 6577.2 ft
Tool speed = 49
Nominal 10 = 2.992
Nominal 00 = 3.500
Remaining wall area = 99 %
Too! deviation = 69 0
~-"-..
Finger 8 Penetration = 0.086 ins
Isolated Pitting
0.09 ins = 34% Wall Penetration
HIGH SIDE = UP
Cross Sections page 1
Jrl
"'n:n_- :····...tS
il'
PDS Report Cross Sections
Well:
Field:
Company:
Country:
Tubing:
1 C-125
Kuparuk
CONOCOPHILLlPS ALASKA, INC.
USA
3.5 ins 9.3 ppf L-80
Survey Date:
Tool Type:
Tool Size:
No. of Fingers:
Analyst:
August 1, 2005
MFC 24 No. 00387
1.69
24
M. Tahtouh
Cross Section for Joint 55 at depth 1731.08 ft
Tool speed = 52
Nominal 10 = 2.992
Nominal 00 = 3.500
Remaining wall area = 97 %
Tool deviation = 540
Finger 6 Penetration = 0.084 ins
Isolated Pitting
0.08 ins = 33% Wall Penetration
HIGH SIDE = UP
Cross Sections page 2
.., ('
.' ,~:- ConocoPhillips Alaska, Inc.
f
KRU
1 C-125
1 C-125
API: 500292304400 Well TVDe: INJ Anale (â) TS: dea@
TUBING SSSV Type: None Orig 10/16/2001 Angle @ TD: 55 deg @ 7725
(0-6661, Completion:
OD:3.500,
10:2,992) Annular Fluid: Last W/O: Rev Reason: Post FCO tag. Set
Patch assemblv
SURFACE 1.-. Reference Loa: Ref Loa Date: Last UDdate: 3/21/2005
(0-6664, Last Tao: 7535 TD: 7725 ftKB
OD:5,500,
Wt15.50) Last Tag Date: 3/2/2005 Max Hole 70 deg @ 2286
Anole:
Casing String - ALL STRINGS
DescriDtion Size TOD Bottom TVD Wt Grade Thread
CONDUCTOR 16.000 0 158 158 68.00
SURFACE 5.500 0 6664 3588 15.50 L-80 BTCM
NIP I PRODUCTION 3.500 6664 7700 4128 9.30 L-80 EUE8rdMod
(6610-6611 , III Tubing String - TUBING
00:4,520) Size I TOD I Bottom I TVD I Wt r Grade I Thread
3.500 I 0 I 6661 I 3587 I 9.30 I L-80 I EUE8rdMod
Perforations Summary
Interval TVD Zone Status Ft SPF Date TVDe Comment
6742 - 6780 3627 - 3647 WSD 38 4 2/28/2001 IPERF 2.5" HSD BH Chg. 60 deg
Dh
6780 - 6800 3647 - 3657 WSD 20 4 2/19/2001 IPERF 2.5" HSD BH Chg. 60 deg
SEAL Dh
(6648-6649, 6858 - 6904 3686 - 3708 WSB 46 4 2/14/2001 IPERF 2.5" HSD BH Ch9. 60 deg
OD:4.000) IDh
6954 - 6970 3733 - 3740 WSA4 16 4 2/14/2001 IPERF 2.5" HSD BH Chg. 60 deg
IDh
6990 - 7000 3750 - 3755 WSA4 10 4 2/12/2001 IPERF 2.5" HSD BH Chg. 60 deg
IDh
SBE 7042 - 7058 3775 - .3783 WSA3 16 4 2/12/2001 IPERF 2.5" HSD BH Chg. 60 deg
(6653-6654, IDh
00:5.000) 7078 - 7138 3793 - 3823 WSA3 60 4 1/24/2001 IPERF 2.5" HSD BH Chg. 60 deg
Ich
Pert .-- 1---. 7204 - 7248 3857 - 3880 WSA2 44 4 1/23/2001 IPERF 2.5" HSD BH Chg. 60 deg
(6742-6780)
.--- ---. Dh
- ~ Gas Lift MandrelsNalves
Pert --- St I MD I TVD I ~~~ Man Type I VMfr I V Type I V OD I Latch I Port I TRO I Date I Vlv
(6780-6800) ---
-- ~- Run Cmnt
- ~ 1 I 65671 35421 CAMCO KBG-2-9 I I DMY I 1.0 lINT I 0.000 I 0 m 0/16/2001
Marker Joint - .-- ~ Other pluas eauip.. etc.) - JEWELRY
(6863-6864,
00:4.500) -.--- 1----- Depth TVD Type Descriction ID
--- --..-. 6610 3562 NIP CAMCO NIPPLE WITH NO GO PROFILE 2.812
PATCH
(6851-6920, --- I--- 6648 3580 SEAL BAKER 80-40 GBH-22 SEAL ASSEMBLY W/LOCATOR SUB 2.999
00:2.800) ---~ --- 6653 3583 SBE BAKER SBE 4.000
. . 6851 3682 PATCH SET WEATHERFORD PATCH LOWER PACKER WITH TOP AT 6910' 1.812
3n /2005
SET 31/2" LOWER ECLIPSE STRADDLE SPACER 291/2" OAL AND
UPPER ECLIPSE PACKER ON ETD 30.7" (â) 6851' RKB 3/15/2005
=>RODUCTION 6863 3688 Marker 2.992
(6664-7700, Joint
OD:3.500, General Notes
Wt:9.30)
Date I Note
--- - 1/23/2001.25" X 2.6" ROLLER WHEEL LOST IN HOLE
Pert - f---- 1/25/2001.25" X 2.6" ROLLER WHEEL LOST IN HOLE PUSHED TO BOTTOM BY SLlCKLlNE
(6954-6970)
---- f----
..----- ----.---
Pert ---- -
(6990-7000)
- I----
-- ~._.
Pert ---
(7042-7058) --
-- I----
- f----
Pert ---- 1----
(7078-7138)
-- I--
--- ---
Pert --- I----
(7204-7248)
--.- .--
..III ...
Spe·r.::-y-Sun Dri 11 in,} Se;"vi
LIS Scan Utili~~'
~~R.evi3ion: 3 ::
LisLib $Revision: 4 $
~ed Feb 13 16:23:47 2002
R.eel Header
Service name. ..... .......LISTPE
Da t e. . . . . . . . . . . . . . . . . . . . . () 2/ (::: i 1':;
Ol:i,;¡in. . . . . . . . . . . . . . . . . . . STS
Reel Name................ UN¡'~NOv-;¡N
Continuation Number. .....01
Previous Reel Name...... .UNKNOV-m
Comments. ... ....... ......STS LIS Writing Library. Scientific Technical Services
Tape Header
Service name....... ......LI8TPE
Da t e. . . . . . . . . . . . . . . . . . . . . 02/ 02/1 3
Origin. . . . . . . . . . . . . . . . . . . STS
Tape Name................UNKNOWN
Continuation Number......Ol
Previous Tape Name.... ...UNKNOWN
Comments.................STS LIS WrLting Library. Scientific Technical Services
Physical EOF
Comment. Record
'rAPE HEADER
Kuparuk River Unit
MWD/MAD LOGS
if
WELL NAME:
API NUMBER:
OPERATOR:
LOGGING COMPANY:
TAPE CREATION O1\TE:
#
,JOB DATA
1C-125
::100292304400
PHILLIPS Alaska, Inc.
Sperry Sun
I3-FEB-02
JOB NUMBER:
LOGGING ENGINEER:
OPERATOR WITNESS:
MWD RUN 1
AK-MM-l1l6~)
S. HUrBAN
D. PRESNELL
MWD RUN 3
AK-MM-l1l65
A.. WEAVER
D. ¡NESTER
MWD RUN 2
AK-MM-11165
A. WEAVER
D. 1A1ESTER
#
SURFACE LOCATION
SECTION:
TOWNSHIP:
RANGE:
FNL:
FSL:
FKl,:
FWL:
ELEVATION (FT FROM MSl., 0)
KELLY BUSHINl~:
DERRICK FLOOR:
GROUND LEVEL:
12
IIN
10E
1622
898
.00
101.45
60.80
If
WELL CASING RECORD
1ST STRING
2ND STRING
3RD STRING
PRODUCTION STRING
OPEN HOLE CASING DRILLERS
BIT SIZE (IN) SIZE (IN) DEPTH (FT)
16.000 158.0
#
REMARKS:
1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE
STATED.
2. MWD RUNS 1 - :3 ARE DIRECTIONAL ¡rUTH DUAl., GAM'MA RAY
(DGR) UTILIZING GEIGER
HUELLER TUBE DETECTORS l-\ND ELECTROMAGNETIC WAVE
dOJ- Iqg
\
j
\
RESISTIVITY PHASE 4
; ElrJR 4 ) .
- .
~mD DATA IS PDC PER THE GKA GEOSIENCE GROUP (E-MAIL
fROM D. SCHWARTZ
OF FHILL::FS Al.;'.SK.=\, INC. DATED Ol/C,4/C<::::I.
.'\LL rl1'JD LOG HE..'\DER D}:,TA RETMNS THE ORIGINAL
DRILLER'S DEPTH REFERENCES.
1. MWD RUNS 1. - 3 REPRESENT WELL 1.C-1.25 WITH
API # 50-029-23044-00. THIS WELL REACHED A TOTAL
DF, PTH OF
7725' MD, 41.42' TVD.
SROP SMOOTHED r~ATE OF PENETRATION
SGRC SJv¡OOTHED GAMMA RAY COHBINED
SEXP SHOOTHED PHASE SHIFT DERIVED RESISTIVITY
EXTRA SHALLOW SPACING )
SESP = SHOOTHED PHASE SHIFT DERIVED RESISTIVITY
SHALLOW SPACING )
SEHP = SHOOTHED PHASE SHIFT DERIVED RESISTIVITY
MEDIUH SPACING )
SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY
DEEP SPACING )
SFXE = SHOOTHED FORMATION EXPOSURE TIME
$
File Header
Service name.............STSLIB.OOl
Service Sub Level Name...
Version Number... ........1.0.0
Date of Generation.......02/02/13
Haximum Physical Record. .65535
File Type................ LO
Previous File Name.......STSLIB.OOO
Comment Record
FILE HEADER
FILE NUMBER:
EDITED Jl1ERGED MWD
Depth shifted
DEPTH INCREMENT:
if
FILE SUMMARY
PBU TOOL CODE
GR
RPD
RPH
RPS
RPX
ROP
FET
$
and clipped curves; all bit runs merged.
.5000
START DEP'TH
116.5
148.0
148.0
148.0
148.0
158.5
158.5
STOP DEPTH
7668.5
'7675.5
7675.'5
7675.5
7675.5
77.25.0
7675.5
II
BASELINE CURVE FOR SHIFTS:
CURVE SHIFT DATA (MEASURED DEP'I'H)
---------EQUIVAl,EWl' UNSHIFTED DEPTH ---------
BASELINE DEPTH
$
if
HERGED DATA SOURCE
PBU TOOL CODE
HWD
HWD
MWD
$
BIT RUN NO
1
2
3
MERGE TOP
116.5
4475.5
6556.0
MERGE BASE
4517 . 0
6612.0
'7725.0
#
REMARJ<S :
MERGED MAIN PASS.
$
if
Data Format Specification Record
Data Record Type.................. 0
Data Specification Block Type.....O
Logging Direction.................Down
Optical 10 depth uni~s.......... .fee:
Data Refer nee Point..............~nde ne,j
fl.-ame Spac ]ì<J..................... 60 .
!~a:': fra~es per rel:c,r~....... ......~nde ~:e,2
."'.Ö sent val u e . . . . . . . . . . . . . . . . . . . . . . - 9 9 9
:Jepth Uni ts.......................
:Jatum Specification Block sub-type...O
Name Servie,e Order Units Si::e Nsarn Rep Code Offset
DEPT FT 1 68 0
ROP HIIJD fT/H 1 62- 4
(:;R I'-TItìJD .Z\FI 1 68 2,
RPX HltìJD OHMM 1 68 12
RPS MWD OHMM 1 68 16
RPM ¡V¡WD OHMM 1 68 20
RPD MWD OHMM 1 68 24
fET MWD HR 1 68 28
Chanr;el
1.
5
6
7
8
First Last
Name Service Unit Min Max Mean N:ë;am Reading Readi rJl;¡
DEPT FT 116.5 7725 3920.75 152lCJ 1 J 6.5 772C,
ROP MWD FT/H 2 . E~ 8 2680.24 177.421 15134 158.5 7725
GR MWD API 11. '7 9 13[3.84 73.7483 IS105 116.5 7668.5
RPX MWD OHMM 0.18 2000 48.0476 15056 148 7675.5
RPS MWD OHMM 0.15 2000 60.2623 15056 148 7675.5
RP¡V¡ MWD OHMM 0.47 2000 89.2[326 15056 148 7675.5
RPD MWD OHMM 0.52 2000 139.9'7l E1056 148 7675.5
FET MWD HR 0.12 18.88 0.675421 15035 158.5 7675.5
First Reading For Entire File..........116.5
Last Reading For Entire File...........7725
File Trailer
Service name.............STSLIB.OOl
Service Sub Level Name...
Version Number. ..........1.0.0
Date of Generation.......02/02/13
Maximum Physical Record..65535
File Type................ LO
Next File Name...........STSLIB.002
Physical EOF
File Header
Service name... ..........STSLIB.002
Service Sub Level Name...
Version Number...........1.0.0
Date of Generation.......02/02/13
Maximum Physical Record..65535
File Type................ LO
Previous File Name.... ...STSLIB.OOl
Comment Record
FILE. HEADER
FILE NUMBER:
RAW MWD
Curves and log
BIT RUN NUMBER:
DEPTH INCREMENT:
#
FILE SUMMARY
VENDOR TOOL CODE
GR
RPD
RPM
RPS
RPX
ROP
FET
2
header data for each bit run in separate files.
1
. ~)OOO
START DEPTH
116.5
148.0
148.0
148.0
148.0
158.5
158.5
STOP DEPTH
4475.0
4482.0
4482.0
4482.0
4482.0
4517 . 0
4482.0
.~
:.,C:C; !-iE}l.DER DAT.ZI.
J.;TE LOGGED:
:3 0 FT1'P,R::
SURFACE SOFn~p..RE VERSION:
DOv.,'NHOLE SOFTìt>JARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME):
TD DRILLER (FT):
TOP LOG INTERVAL (E'T):
BOTTOM LOG INTER~~L (E'T):
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
JvIINIMUJv1 ,Zl.NGLE:
!'-i~>:IMUM ANGLE:
TOOL STRING (TOr TO
VENDOR TOOL CODE
DGR
EWR4
$
BOTTOM)
TOOL TYPE
DUAL GAMMA RAY
ELECTROMAG. RESIS.
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT):
fl
BOREHOLE CONDITIONS
MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S):
MUD PH:
MUD CHLORIDES (PPM):
FLUID LOSS (C3):
RESISTIVITY (O]-IMM) l\T TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING 'I'ERMPERA'I'URE:
MUD FILTRATE AT M'l':
MUD CAKE AT M'I':
NEU'I'RON TOOL
MATRIX:
MATRIX DENSI'T'Y:
HOLE COI~REC'I'ION (IN):
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
REMARKS:
$
#
Data Format Specification Record
Data Record Type.................. 0
Data Specification Block Type.....O
Logging Direction.................Down
Optical log depth units.._........Feet
Data Reference Point..............Undefined
Frame Spacing. ..... ...............60 .1IN
Max frames per record.............Undefined
Absent value..................... .-999
Depth Units.......................
Datum Specification Block sub-type...O
it
09-0CT-Ol
Insi te ~~.. 1='15..
(')6.37
!"íernory
4517.1)
.. t'
69.. ~)
TOOL NUMBER
PB02207GRV4
PB02207GRV4
7.875
Water Based
9.20
120.0
9.5
200
7.0
4.800
3.826
3.100
2.900
60.0
77.0
60.0
60.0
Name Service Order Units Siz.e Nsam Rep Code Offset Channel
DEPT F'I' 4 1 68 0 1
ROP MWDOIO FT /I~I <1 1 68 4 -
GR MWD010 API 4 1 68 8 3
RPX MWDOlO OHMM <1 1 68 12
RPS MWD010 Ol-lMM 4 1 68 16 5
RPM MWD010 OHMM 4 1 68 20 6
RPD MWD010 OHMM <1 1 68 24 7
FET MWD010 HR 4 1 68 28 8
First Last
\alTle Ser\tice Unit Hin Ma:z ¡"lean Nsanl Readin,;] R(::,adin,;]
JEr:-'T FT 116.5 4517 2316.75 8802 116.5 451
?OP Ì"n^TD010 FT/H f,S 2680. 24 1 --;, .75:2 871t~ 158. 5 451
~ . ''<
:ÒK ;V¡I'JD010 .ìl.PI 11. 79 131 9] )"2. 16<1 8H8 11 6. 5 4n
1\1":': J'!\'JD() 1 I) OH~'1M O. 18 2000 -/ ::¡.. 6996 8669 1:1t: ~ ~ E:
~PS HI/JOCI10 OHHH O. 15 2000 '0; 0180 8669 U8 ·H
RPM ]v ¡'-JDO 10 o H HI"! O. 47 ~'OC)\) 147 :)41 t:Ó69 148 '-14::
RPD HI'mCI10 OHl'lH O. 5~ 20(.10 234 f:5 ::;669 142: 44 t'
FET ¡·1~·mo 1 [) HE O. L~ 1 65 U. 3692:"72 :::64:": 1S2: 5 . ,'':'
"-1"1<...'
First Reading For Entire File..........116.5
Last Reading For Entire Fi.le_... _...,. _ 4517
Fi Ie T l-ailer
Service name._.._....._..STSLIR.002
Service Sub Level Name...
Version Number...........l.O.O
Date of Generation..... ..02/02/13
Maximum Physical Record. .65535
File Type........... '" ..LO
Next File Name.... ...... .STSLIB.003
Physical SOF
File Header
Service name........ .....8TSLIB.003
Service Sub Level Name...
Version Number.. ..... ....1.0.0
Date of Generation.......02/02/13
Maximum Physical Record..65535
File Type................LO
Previous File Name.... ...STSLIB.002
Comment Record
FILE HEADER
FI LE NUMBE.f':
RAW MWD
Curves and log header data
BIT RUN NUMBER:
DEPTH INCREMSNT:
#
FILE SUHMARY
VENDOR TOOL CODE
GR
FET
RPD
RPM
RPS
RPX
ROP
3
for each bit run in separate files.
'~)
.5000
START DEPTH
44'75.5
4482.5
4482.5
4482.EJ
4482.5
4482.5
4517 . 5
STOP DEPTH
6555.5
6562.5
6562.5
6562.5
6::)62.5
6562.5
6612.0
c'
'?
Ii
LOG HE.ADER DATA
DATE LOGGED:
SOFTWARE
SURfJ-\CE SOfTWARE VERSION:
DOWNHOLE SOFTW1-\RE VERSION:
DATA TYPE (MEMORY OR REAL-TIME):
TO DRILLER (FT):
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT):
BIT ROTATING SPEED (RPH):
HOLE INCLINATION (DEG
MINH1UM ANGLE:
M.AXIHUM ANGLE:
1l-OCT-01
Insite 4.05.)=)
66.37
Memory
6612.0
62.4
69.8
#
TOOL STRING (TOP TO
VE,NDOR TOOL CODE
DGR
E.WR4
$
BOTTOM)
TOOL TYPE
DUAL GAMIvIA RAY
ELECTROMJ\G. RESIS.
TOOL NUHBER
PB02207GRV4
PB02207GRV4
ê:OREHOLE ¡\ND G\SING DAT.'\
OPEN HOLE SIT SIZE (IN):
JRIL~ER'S CASING DEPTH rFT):
7.875
SORE~OLE CON~ITIONS
HUD TYPE:
MUD DENSITY (LS/G):
MUD VISCOSITY (S):
HUD PH:
MUD CHLORIDES (PPM):
FLUID LOSS (C3):
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
HUD }\T MEASURED TEMPERFIT1..JRE (1'-1T):
MUD AT MAX CIRCULATING TERMPERATURE:
tvlUD FILTR,"'.TE AT !'-1T:
HUD CAKE AT HT:
¡,'Jater E:aseÖ
9.. 3\~"
85. íJ
9.5
200
5.2
.5(10
.874
.300
.000
NEUTRON TOOL
MATRIX:
MATRIX DE.NSITY:
HOLE CORRECTION (IN):
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
REMARKS:
$
#
Data Format Specification Record
Data Record Type..................O
Data Specj.fì.cat:Lon Blod:. Type..... 0
Logging Direction.................Down
Optical log depth units... ....... .Feet
Data Reference Point..............Undefined
Frame Spacing....... ..............60 .1.IN
Max frames per record.............Undefined
Absent value..................... .-999
Depth Unj.ts.......................
Datum Specification Block sub-type...O
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1.
ROP MWD020 FT/H 4 1 68 4 ,..,
¿
GR MWD020 API 4 1. 6f3 8 3
RPX MWD020 OHH¡V¡ 4 1 68 12 4
RPS HWD020 OHHH 4 1. 6i3 16 5
R PH MWD020 OHI'1H 4 1. 68 20 6
RPD MWD020 OHMM 4 1 68 24 7
FET MírifD020 HR 4 1 68 28 8
FLr s t Last
Name Service Unit Min ¡VIa x Hean Nsarn Reading Reading
DEPT FT 4475.5 6612 5543.75 4274 4475.5 6612
EOI? MWD020 FT/H 7.'71 2161.35 203.57 4190 4517 . 5 6612
GR HWD020 API 26.24 L?1.12 68.9947 4 lEi 1 44'7!:).5 655::). ~')
RPX tvlWD020 OHHM 4.75 46.34 9.97372 4161 4482.5 6562.5
RPS HWD020 OI-IHM 4.36 40.63 9.87666 4161 4482.5 6562.5
RPH MWD020 OH.MM .95 40.88 9.98645 4161 4482.5 6562.5
RPD HWD020 OHjv ]'v! 4.25 42.4 10.6193 4161 44~32.5 6562.5
FET HWD020 HR 0.16 18 0.838524 4161 4482.5 6562.5
First Reading For Entire File... .......4475.5
Last Reading For Entire File...........6612
File Trailer
Service name.............STSLIB.003
Service Sub Level Name...
Version Number.... .......1.0.0
Date of Generation...... .02/02/13
Maximum Physical Record..65535
::'11 e '!,O:.=,e................ LO
~ext File Name...... .....STSLIB.004
p:",VS i .::;:¡J SOF
Fi Ie Headel-
Service name. ............STSLIB.
Service Sub Level Name...
·v'ersion Number.......... .1.0.0
Date of Generation...... .02/02/13
Maximum Physical Record..65535
Fi 1 e Type................ LO
Previous File Name.......STSLIB.003
Cc,rnrnent Record
F'I LE HEADER
FILE NUMBER:
RAW MWD
Curves and log
BIT RUN NUMBER:
DEPTH INCREMENT:
#
FILE SUMMARY
VENDOR TOOL CODE
GR
RPD
RPM
RP8
RPX
FET
ROP
$
header data Eor each bit run in separate files.
3
. ::)000
START DEPTH
6556.0
6563.0
6563.0
6563.0
6563.0
6563.0
6612.5
STOP DEPTH
7668.5
7675.5
7675.5
7675.5
7675.5
7675.5
7725.0
Ji
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
SURFACE 80E''I'WARE VERSION:
DOWNHOLE SOF1:WJ.\RE VERSION:
DATA TYPE (MEMORY OR REAL-TIME) :
TO DRILJÆR (F'I'):
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (r'r):
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
MINIMUM ANGLE:
MAXIMUM ANGLE:
#
TOOL STRING (TOP TO
VENDOR TOOL CODE
DGR
EWR4
$
BOTTOM)
TOOL TYPE:
DUAL C;AMMJ\ Rl\Y
ELECTROMAG. RES IS.
#
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (F'T):
BOREHOLE CONDITIONS
MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (8):
MUD PH:
MUD CHLORIDES (PPM):
FLUID LOSS (C3):
RESISTIVITY (OHMM) A'r TEMPE.RATURE. (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TERMPERJ.\TURE:
MUD E'ILTRA.'rE AT MT:
MUD CAKE AT MT:
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
12-0CT-Ol
Insite 4.05.5
66.37
Jv!ernory
7725.0
55.5
61.5
TOOL, NUMBER
PB02207C3RV4
PB02207GRV4
7.875
Water
9.30
85.0
9.5
200
5.2
Based
3.250
2.677
3_600
2.250
68.0
84.0
68.0
68.0
!-JOLt: C02RSCTl (11'4 ;:; 1':: :
7001. ST,'\NDOFF i J:ì';:
SWR FREQUSI~CY ~~=:
S;E:HP,RKS:
~
Data Format Specification Record
Data Rece,rd Type................. .1:'
Data Sr,ecificatior, 8L:·c}: T'11='e..... CI
Logging Direction............... ..Down
Optical log depth units. ..... .....Feet
Data Reference Point.... ..... .....Undefined
Frame Spacing..................... 60 .1IN
Max frames per record.............Undefined
Absent value.............. _...... .-999
Depth Units.... _ . . . . . . . . . . . _ _ _ . . . .
Datum Specification Block sub-type...O
Name Service Order UniU, Size Nsam Rep Code Offset Channel
DE. PT F'T 4 1 68 0 1
ROP MWDO.30 FT/H 4 1 68 4 "
L
GR MWDO.30 API 4 1 68 8 .3
RPX HWDO.30 OHHH 4 1 68 12 4
RPS MWD030 OHMM 4 1 6B 16 5
RPM HWD030 OHHH 4 1 68 20 6
RPD HWDO.30 OHMH 4 1 68 24 7
FET H\~lD030 HR 4 1 68 28 8
FLrst Last
Name Service Unit Hin Hax Hean Nsam Reading Reading
DEPT FT 6556 7725 7140.5 2339 6556 7725
ROP MWD030 FT/H 5.52 :')55.4 138.649 2226 6612.5 7725
GR HWDO.30 API 43.09 138.e4 Be.e3e4 2226 65~,)6 7668.5
RPX HTÑD030 OHHM 2.31 238.tJ3 11.529 2226 6563 7675.5
RPS HWDO.30 OJ-fMM 2_37 162.77 11.3008 2226 6563 7675.5
RPM HWD030 OH.Ml'1 2.37 126.1 11. 4035 2226 6563 7675.5
.RPD HWD030 OHMH 2. ~)n 130.el .1.2.2673 2226 6b63 7675.5
FET MWD030 HR O. ¿:1 18.88 1.55759 2226 6563 7675.5
First Reading For Entire File__._.___..6556
Last Reading For Entire File...........7725
File Trailer
Service name.............STSLIB.004
Service Sub Level Name...
Version Number.......... .1.0.0
Date of Generation.......02/02/13
Maximum Physical Record..65535
File Type............... .IJO
Next File Name...........STSLIB.005
Physical EOE"
Tape Traile.r
Service name..... .... ... .LISTPE
Da t e. . . . . . . . . . . . . . . . . . . . . 02/ 02/13
Origin. . . . . . . . . . . . . . . . . . . STS
Tape Name................UNKNOWN
Continuation Number..... .01
Next Tape Name...........UNKNOWN
Comments. ................ST3 LI3 Wri.ting Library. Scientific Technical Services
Reel Trailer
Service name.............LISTPE
Date. . . . . . . . . . . . . . . . . . . . .02/02/13
Origin. . . . . . . . . . . . . . . . . . . S'I'S
Reel Name................UNKNOWN
~o~~inuation Number.... ..01
:1ext Reel Na.me........... UNKNOWN
:ommen~s.................STS LIS Writinq Libra.ry. Scientific Technical Services
Physi=-al EOt'
¡>hysical EOF
E.nd Of LIS File
