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Alaska Oil and Gas Conservation Commission
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MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Jim Regg DATE: 07/18/2025
P. I. Supervisor
FROM: Kam StJohn SUBJECT: Site Clearance
Petroleum Inspector KRU 2P-441
ConocoPhillips Alaska LLC.
PTD 2020170; Sundry 324-586
07/15/2025: Went out to KRU 2P Pad for site clearance inspections and met with Roger
Mouser (CPAI). We went over the surface area of KRU 2P-441 which has been P&A and
buried. The area was clean of debris and had a settling mound for soil over the well
location. We verified the well-site with the pad location map and well conductor “as built”.
Marker plate and top of well are at 7 feet 7 inches below original tundra. Overall, the site
clearance was in good condition. The well site still had barriers around due to other work
going on in the area. Only follow up would be a full pad site clearance once CPAI has
completed all pad P&A work.
Attachments: Photo
9
9
James B. Regg Digitally signed by James B. Regg
Date: 2025.09.16 14:10:59 -08'00'
2025-0715_Location_Clear_KRU_2P-441_ksj
Page 2 of 2
Surface Abandonment Inspection – KRU 2P-441 (PTD 2020170)
Photo by AOGCC Inspector K. StJohn
7/15/2025
1a. Well Status:Oil SPLUG Other Abandoned Suspended
1b. Well Class:
20AAC 25.105 20AAC 25.110 Development Exploratory
GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test
2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry:
Aband.:
3. Address: 7. Date Spudded: 15. API Number:
4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number:
Surface:
Top of Productive Interval:17. Field / Pool(s):
GL: BF:
Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation:
4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number:
Surface: x- y- Zone- 4
TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD:
Total Depth: x- y- Zone- 4
5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD:
Submit electronic information per 20 AAC 25.050 N/A (ft MSL)
22. Logs Obtained:
N/A
23.
BOTTOM
16" B 110'
7.625" L-80 2378'
5.5" L-80 3890'
3.5" L-80 5793'
24. Open to production or injection? Yes No 25.
26.
Was hydraulic fracturing used during completion? Yes No
DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED
27.
Date First Production: Method of Operation (Flowing, gas lift, etc.):
Hours Tested: Production for Gas-MCF:
Test Period
Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr):
Press. 24-Hour Rate
4696'
SIZE DEPTH SET (MD)
7325'
30'
3795'
62.5#
29.7#
110'
30'
Sr Res EngSr Pet GeoSr Pet Eng
Oil-Bbl: Water-Bbl:
16.5 bbl 15.8 ppg PTA Cement
Surface-2345' 128.5 bbl 15.8 ppg Cement
Water-Bbl:
PRODUCTION TEST
N/A
Date of Test: Oil-Bbl:
Flow Tubing
2345-2647'
3846' (SW TOC)-4463'
ABANDONED
6950-6960' MD and 5520-5527' TVD (below cement plug)
Gas-Oil Ratio:Choke Size:
21 bbls 15.8 ppg Class G cement
Per 20 AAC 25.283 (i)(2) attach electronic information
4559' MD/ 3795' TVD
PACKER SET (MD/TVD)
42"
9.875"
422 sx AS I
31'300 sx AS IIIL, 135 sx LiteCrete
9.3#
31'
4559'
2594'31'
31'
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date perf'd or liner run):
15.5#
WT. PER
FT.GRADE
3/23/2002
CEMENTING RECORD
5865265
1360' MD/ 1353' TVD
SETTING DEPTH TVD
5864986
TOP HOLE SIZE AMOUNT
PULLED
442862
442881
TOP
SETTING DEPTH MD
suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log,
spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar
locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary.
N/A
BOTTOM
Kuparuk River Field/ Meltwater Oil Pool-
Abandoned
N/A
50-103-20407-00-00
KRU 2P-441
ADL0373112
989' FNL, 1719' FWL, Sec. 17, T8N, R7E, UM
382' FSL, 937' FWL, Sec. 17, T8N, R7E, UM
ALK4998
3/5/2002
7327' MD/ 5793' TVD
SURFACE/ SURFACE
P.O. Box 100360, Anchorage, AK 99510-0360
443679 5868890
660' FSL, 917' FWL, Sec. 17, T8N, R7E, UM
9. Ref Elevations: KB: 27'
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
ConocoPhillips Alaska, Inc.
WAG
Gas
1/19/2025 202-017/ 324-586
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
CASING, LINER AND CEMENTING RECORD
List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion,
(included above)6.75"
TUBING RECORD
47 bbl LiteCrete6.75"
4554' MD3-1/2"
CASING
Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment
By James Brooks at 8:15 am, Feb 18, 2025
Abandoned
1/19/2025
JSB
RBDMS JSB 022625
xGVTL 7/30/2025
DSR-4/7/25
Conventional Core(s): Yes No Sidewall Cores:
N/A
30.
MD TVD
Surface Surface
1360' 1353'
Top of Productive Interval
N/A
31. List of Attachments: Schematics, Summary of Operations, Photos
32. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Contact Name: Shane Germann
Digital Signature with Date:Contact Email: shane.germann@conocophillips.com
Contact Phone:(907) 263-4597
Senior RWO/CTD Engineer
General:
Item 1a:
Item 1b:
Item 4b:
Item 9:
Item 15:
Item 19:
Item 20:
Item 22:
Item 23:
Item 24:
Item 27:
Item 28:
Item 30:
Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and
other tests as required including, but not limited to: core analysis, paleontological report, production or well test results.
Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29.
Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool.
If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the
producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,
showing the data pertinent to such interval).
Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit
detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity,
permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology.
Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain).
Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical
laboratory information required by 20 AAC 25.071.
Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion,
suspension, or abandonment; or 90 days after log acquisition, whichever occurs first.
Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345),
and/or Easement (ADL 123456) number.
The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements
given in other spaces on this form and in any attachments.
The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic
diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from
a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071.
INSTRUCTIONS
Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core
analysis, paleontological report, production or well test results, per 20 AAC 25.070.
Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each
segregated pool is a completion.
TPI (Top of Producing Interval).
Authorized Name and
Authorized Title:
N/A - AbandonedFormation Name at TD:
If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if
needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired.
Yes No
Well tested? Yes No
28. CORE DATA
If Yes, list intervals and formations tested, briefly summarizing test results for
each. Attach separate pages if needed and submit detailed test info including
reports and Excel or ASCII tables per 20 AAC 25.071.
NAME
Permafrost - Top
Permafrost - Base
29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS
N/A- Abandoned
Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov
Digitally signed by Shane Germann
DN: O=ConocoPhillips, CN=Shane Germann, E=
shane.germann@conocophillips.com
Reason: I have reviewed this document
Location:
Date: 2025.02.14 11:49:39-09'00'
Foxit PDF Editor Version: 13.0.0
g g
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag: RKB 6,963.0 2P-441 6/21/2024 rogerba
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: P&Ad' 7 foot 7 inch below OG. Witnessed by AOGCC Sully Sullivan 2P-441 1/19/2025 mouser
Notes: General & Safety
Annotation End Date Last Mod By
NOTE: P&Ad' 7 foot 7 inch below OG. Witnessed by AOGCC Sully Sullivan 1/19/2025 mouser
NOTE: WAIVERED WELL: OA PRESSURE CHARGING FROM RESERVOIR 11/30/2004 pproven
Casing Strings
Csg Des OD (in) ID (in) Top (ftKB)
Set Depth
(ftKB)
Set Depth
(TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread
CONDUCTOR 16 15.06 41.0 120.0 120.0 62.60 WELDED
SURFACE 7 5/8 6.87 41.0 2,593.8 2,377.6 29.70 L-80 BTCMOD
PRODUCTION 5 1/2 4.95 2,647.0 4,696.0 3,890.2 15.50 L-80 BTCMOD
LINER 3 1/2 2.99 4,559.2 7,325.0 5,793.2 9.30 L-80 BTCMOD
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
30.8
Set Depth …
2,339.0
Set Depth …
2,196.0
String Max No…
3 1/2
Tubing Description
Tubing – Completion Upper
Wt (lb/ft)
9.30
Grade
L-80
Top Connection
EUE-M
ID (in)
2.99
Top (ftKB)
2,835.0
Set Depth …
4,553.8
Set Depth …
3,791.8
String Max No…
3 1/2
Tubing Description
Tubing – Completion Lower
Wt (lb/ft)
9.30
Grade
l-80
Top Connection
EUE-8rdMOD
ID (in)
2.99
Completion Details: excludes tubing, pup, space out, thread, RKB...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal
ID (in)
3,601.9 3,095.5 42.40 GAS LIFT 4.425 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900
4,429.1 3,704.9 45.21 GAS LIFT 4.425 CAMCO KBG-2-9 CAMCO KGB-2-9 2.900
4,478.9 3,739.9 45.78 SLEEVE-O 4.500 SLIDING SLEEVE w/DS PROFILE BAKER CMU 2.813
4,494.8 3,750.9 45.97 NIPPLE 4.550 CAMCO D NIPPLE CAMCO D 2.750
4,539.1 3,781.6 46.31 PBR 4.500 POLISHED PBR BAKER 3.000
4,553.1 3,791.3 46.29 ANCHOR 4.500 ANCHOR - TUBING SEAL DOWN BAKER K-22 3.000
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top (ftKB)
Top (TVD)
(ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in)
41.0 41.0 0.00 MARKER
PLATE
1/4" Plate x 30"(Dia) Marker
plate
1/19/2025 0.000
2,647.0 2,415.6 44.50 CUT MSC on rig 12/3/2024 4.950
2,650.0 2,417.8 44.52 CUT MSC on rig 12/3/2024 4.950
2,655.0 2,421.3 44.56 CIBP CIBP MID ELEMENT @
2655.5''. TOP @ 2655'. BTM
@ 3,041.25'. OAL = 1.25'
12/2/2024 0.000
2,835.0 2,548.4 45.48 CUT JET CUT @ 2835' RKB 10/17/2024 2.992
2,840.0 2,551.9 45.49 CUT JET CUT @ 2840' RKB 10/7/2024 2.992
4,460.0 3,726.7 45.57 TUBING
PUNCH
3FT OF 2" TUBING PUNCH,
4SPF, 0 DEGREE PHASE
(PUMP 20 BBL DIESEL
THROUGH AT 2 BPM AND
150 PSI)
9/27/2024 2.992
6,919.3 5,497.3 42.75 CIBP CIBP MID-ELEMENT AT 6920'
RKB, OAL = 1.37'
6/29/2024 0.000
Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal ID
(in)
4,559.2 3,795.5 46.29 PACKER 5.820 TIE-BACK SLEEVE ID 4.51",
Baker Liner Top Packer ID 3.91"
BAKER FA 3.910
4,574.4 3,806.0 46.27 SBR 4.250 POLISHED BORE RECEPTACLE BAKER 2.992
7,227.1 5,721.0 42.67 Plug Catcher 3.500 2.992
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
6,950.0 6,960.0 5,519.8 5,527.1 BERMUDA, 2P-
441
3/30/2002 6.0 IPERF 2.5" Gun, 2506 HJ RDX, 60
deg phase
Stimulation Intervals
Top (ftKB) Btm (ftKB)
Inter
val
Num
ber Type Subtype Start Date
Proppant
Designed (lb)
Proppant
Total (lb)
Vol Clean
Total (bbl)
Vol Slurry
Total (bbl)
6,950.0 6,960.0 1 FRAC 4/1/2002 0.0 0.00 0.00
6,950.0 6,960.0 1 RE-FRAC 5/19/2004 0.0 0.00 0.00
Cement Squeezes
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Des Com
Pump Start
Date
41.0 2,593.0 41.0 2,377.1 Cement
Casing
Pipe movement: ReciprocatingDrag down (lbs):
5000Drag up (lbs): 5000Time started reciprocating:
14:30Time stopped reciprocating: 17:30Annular flow
after cement job (Y/N): NCirculating BHT (F):
76Static BHT (F): 56Pressure before cementing
(psi): 700Hours circulated between stages: 2Bbls
cmt to surf: 1400 to surfaceReturns (pct): FullTime
cementing mixing started: 16:30
3/8/2002
6,848.0 6,919.3 5,444.5 5,497.3 Cement Plug DUMP BAILER CEMENT PLUG.
2P-441, 2/13/2025 1:12:14 PM
Vertical schematic (actual)
LINER; 4,559.2-7,325.0
FRAC; 6,950.0
RE-FRAC; 6,950.0
IPERF; 6,950.0-6,960.0
CIBP; 6,919.3
Cement Plug; 6,848.0 ftKB
PRODUCTION; 2,647.0-4,696.0
TUBING PUNCH; 4,460.0
GAS LIFT; 4,429.1
Cement Plug; 3,846.0 ftKB
GAS LIFT; 3,601.9
CUT; 2,840.0
CUT; 2,835.0
CIBP; 2,655.0
CUT; 2,650.0
CUT; 2,647.0
SURFACE; 41.0-2,593.8
Cement Plug; 2,345.0 ftKB
Cement Casing; 41.0 ftKB
CONDUCTOR; 41.0-120.0
MARKER PLATE; 41.0
Plug – Plug Back /
Abandonment Plug; 41.0 ftKB
KUP PROD
KB-Grd (ft)
35.10
RR Date
4/25/2002
Other Elev…
2P-441
...
TD
Act Btm (ftKB)
7,327.0
Well Attributes
Field Name
MELTWATER
Wellbore API/UWI
501032040700
Wellbore Status
PROD
Max Angle & MD
Incl (°)
48.60
MD (ftKB)
6,016.54
WELLNAME WELLBORE2P-441
Annotation
Last WO:
End DateH2S (ppm)
25
Date
12/6/2016
Comment
SSSV: NIPPLE
Cement Squeezes
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Des Com
Pump Start
Date
3,846.0 4,463.0 3,275.8 3,728.8 Cement Plug Cement Bal Plug - Pumped 21 Bbls of 15.8 PPG Cmt
& Displaced Cmt w/ 30 Bbls OF 9.8 PPG NaCl KWF.
9/28/2024
2,345.0 2,647.0 2,200.3 2,415.6 Cement Plug Pump 23.9 BBL of 10 PPG spacer @ 2.5 BPM 117
PSI
Load 4" Wiper Ball
Pump 16.5 Bbl of 15.8 PPG PTA Cmt @ 2.4 BPM
175 PSI
Load 4" Wiper Ball
Pump 4.3 Bbl of 10 PPG spacer @ 2.4 BPM 70 PSI
Pump 13.4 Bbl of 9.8 PPG Brine @ 2.7 BPM 110 PSI
Pump off line Well is Static pump Truck reading 0
PSI well is Balanced
Full returns through job. Cmt in place @ 14:58 Hrs.
12/4/2024
41.0 2,345.0 41.0 2,200.3 Plug – Plug
Back /
Abandonment
Plug
Pumped 128.5 bbls of 15.8# cement to surface.
Filled 3 1/2" Tubing and 7 5/8" Production Casing to
surface.
12/6/2024
2P-441, 2/13/2025 1:12:15 PM
Vertical schematic (actual)
LINER; 4,559.2-7,325.0
FRAC; 6,950.0
RE-FRAC; 6,950.0
IPERF; 6,950.0-6,960.0
CIBP; 6,919.3
Cement Plug; 6,848.0 ftKB
PRODUCTION; 2,647.0-4,696.0
TUBING PUNCH; 4,460.0
GAS LIFT; 4,429.1
Cement Plug; 3,846.0 ftKB
GAS LIFT; 3,601.9
CUT; 2,840.0
CUT; 2,835.0
CIBP; 2,655.0
CUT; 2,650.0
CUT; 2,647.0
SURFACE; 41.0-2,593.8
Cement Plug; 2,345.0 ftKB
Cement Casing; 41.0 ftKB
CONDUCTOR; 41.0-120.0
MARKER PLATE; 41.0
Plug – Plug Back /
Abandonment Plug; 41.0 ftKB
KUP PROD 2P-441
...
WELLNAME WELLBORE2P-441
Production Casing Cement:
37 bbls of 15.8# Class G Cement
Estimated TOC @ 3,052' KB
Liner Cement:
31.3 bbls of 15.8# Class G Cement
Calculated TOC @ 4,559.2' KB
2P-441 Well Final P&A Schematic
Conductor:
16" Conductor 120' KB
1
2
3
5
Production Casing:
5 ½" 15.5# L-80 BTCMOD
Set @ 4,696’ KB
Bermuda Peforations:
@ 6,950' – 6,960' KB (10')
Surface Casing:
7-5/8", 29.7#, L-80 BTCMOD
Set @ 2,593.8' KB (2377' TVD)
Production Tubing:
3.5" 9.3# L-80 EUE-8rdMOD
Set @ 4,553.8' KB
76 8
4
9
10
11
Liner:
3.5" 9.3# L-80 BTCMOD
Set @ 7,325’ KB
C80 @ 2690' KB C80 @ 2690' KB
Plug #1 – Reservoir
TOC ±6890' RKB
Plug #2 – Intermediate
TOC ±3460
BOC ±4460
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Plug #3 – Surface Shoe
TOC 2345' RKB (2200' TVD)
BOC @ ±2655' RKB
Plug #4 – Surface
TOC 23' RKB
BOC @ ±2345' RKB
DTTMSTART JOBTYP SUMMARYOPS
10/17/2024 CHANGE WELL
TYPE
RIH W/ 2.5" JET CUTTER, SET DOWN AT 500'. FROM 500' - 1700' HAD TO
HAND SPANG TOOLS EVERY COLLAR. AT 1700' TOOLS HUNG UP AND
OVER PULLED 600 LBS TO GET FREE. NO ISSUES FALLING AFTER.
TAGGED PREVIOUS CUT AT 2840'. CUT TUBING AT 2835'. AFTER CUTTING
TOOLS UNABLE TO MOVE. OVER PULLED 1300 LBS BEFORE TOOLS
BECAME FREE. POOH WITH NO FURTHER ISSUES. RECOVERED ALL
TOOLS AT SURFACE AND FOUND A CENTRALIZER BLADE HAD BROKE
AND WAS FOLDED OVER. JOB COMPLETE, READY FOR RIG
12/1/2024 RECOMPLETION Demob off 2P-443 to 2P-441 Circ well w/ 9.8 Brine w/ No Issues N.D Tree and
N/U BOP
12/2/2024 RECOMPLETION L/D 3 1/2" tubing /RIH w/ 2 7/8" pac and Set CIBP POOH RIH & Cut 5 1/2" casing
12/3/2024 RECOMPLETION Cut 5 1/2" casing @ 2651' No pressure wrap around to OA. P/U 3' cut CSG @
2648'. No pressure wrap around to OA. POOH, L/D BHA #4, inspect cutter
blades - good wear pattern. Redressed MSC M/U BHA #5. RIH T/ 2490'. Locate
collar @ 2524'. Cut 5 1/2 CSG @ 2550'. 400 PSI wrap around to OA. Circ out
OA w/ 70 Bbls Deep clean pill followed by 100 Bbls 9.8# brine @ 3 BPM. 30 Min
no flow. M/U 6.5" LH Acme landing joint. BOLDS. Pull hanger to RF. L/D 5 1/2"
CSG to cut.
12/4/2024 RECOMPLETION RIH w/ BHA #5 _5 1/2" spear w/ jars & DC's. Engage 5 1/2" fish. Jar fish free.
Pull fish up inside surface casing shoe. Circ BU - no losses. POOH, L/D BHA #5
& 96.91' of 5 1/2" CSG fish. Process 3 1/2" EUE tubing string. RIH w/ 3 1/2" EUE
tubing T/ 2588'. Pump in hole T/ 2646'. PJSM w/ HES on pumping balance plug.
R/U HES and cement hose. Fill lines, PT T/ 2500 PSI. Batch up spacer &
cement. Cement wet @ 13:02 Hrs. HES pump 16 Bbls balance plug as per
program. POOH @ 30 FPM F/ 2646' T/ 1959', WOC.
12/5/2024 RECOMPLETION WOC. RIH, tag cement top @ 2345'. P/U T/ 2340'. PT cement plug 1500 psi f/
30 mins. Circ out green cement.
12/6/2024 RECOMPLETION P/U Hanger space out. Land hanger w/ BTM of string @ 2339'. RILDS. Jet BOP
stack. Open doors & clean out cement from ram cavities. Close doors. N/D BOP
N/U old adaptor spool & tree. PT hanger void T/ 5000 PSI for 10 MIn. R/U HES.
Pump 128.5 Bbls 15.8 PPG to surface. Est. 23 Bbls returned. Flush lines. R/D
HES. Secure cellar & tree. RDMO 2P-441.
12/17/2024 ACQUIRE DATA (P&A) T/IA DDT (COMPLETE), OA DDT (COMPLETE) TREE AND VALVES
REMOVED. REPLACED WITH BLINDS. CEMENT AT SURFACE ON ALL.
***NEXT STEP: CUT/REMOVE WELLHEAD & STEEL CELLAR***
12/18/2024 ACQUIRE DATA (P&A) PREP, CUT WINDOWS IN CONDUCTOR, CHIPPED OUT CEMENT IN
CONDUCTOR. (IN PROGRESS)
***NEXT STEP: CUT AND REMOVE WELLHEAD AND STEEL CELLAR.***
12/20/2024 ACQUIRE DATA (P&A) PREP- CUT & REMOVED 75" OF WELLHEAD, MEASURED FROM 8' OG
REFERENCE MARK. ADDITIONAL 69" IF WELL STUB NEEDS TO BE CUT TO
OBTAIN GREATER THAN 4' BELOW OG.
CUT REMOVED STEEL CELLAR.
BARRICADED OPEN HOLE, RETURN AFTER 3S-23 P&a.
NEXT STEPS: RETURN AFTER 3S-23 P&A, EXCAVATE TO 14' FOR SHORE
CAN INSTALLATION.
1/14/2025 ACQUIRE DATA (P&A) EXCAVATE TO 14' (IN PROGRESS @ ~5')
2P-441 Final Plug and Abandon
Summary of Operations
1/15/2025 ACQUIRE DATA (P&A) EXCAVATE TO 14' (IN PROGRESS @ ~8')
1/16/2025 ACQUIRE DATA (P&A) EXCAVATE TO 14' (IN PROGRESS @ ~13' 6")
***NEXT STEP: SET SHORE CAN, BACKFILL AROUND SHORE CAN PREP
FOR WELL STUB REMOVAL.***
NES excavated to ~13' 6" below pad grade
1/17/2025 ACQUIRE DATA (P&A) EXCAVATED TO 13' 6", SET SHORE CAN, BACKFILLED AROUND
SHORE CAN. PREPPED FOR WELL STUB REMOVAL. (IN PROGRESS )
***NEXT STEP: CUT AND REMOVE ADDITIONAL WELL STUB AND PREP
FOR MARKER PLATE WELDING.***
1/18/2025 ACQUIRE DATA (P&A) IN PROGRESS- CUT AND REMOVED ADDITIONAL112" (9' 4") OF WELL
STUB. COMBINED WITH ORIGINAL 75" OF WELLHEAD REMOVED,
ESTIMATED 91" OR 7' 7" BELOW OG.
PREPARED REMAINING WELL STUB FOR MARKER PLATE WELD.
***NEXT STEP: AOGCC SCHEDULED TO VERIFY TOC AND MARKER PLATE
INFORMATION . WELD MARKER PLATE, PULL SHORE CAN BACKFILL
EXCAVATION FOR FINAL SITE CLEARANCE.***
1/19/2025 ACQUIRE DATA (P&A) COMPLETE. AOGCC INSPECTOR SULLY SULLIVAN, WITNESSED
AND VERIFIED MARKER PLATE INFORMATION AND TOP OF CEMENT.
WELDED MARKER PLATE TO WELL STUB. TOP OF MARKER PLATE 7' 7"
BELOW ORIGINAL GROUND.
PULLED SHORE CAN, BEGAN BACKFILL OPERATIONS.
NEXT STEP : FINAL SITE CLEARANCE .
Page 1/5
2P-441
Report Printed: 2/13/2025
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/1/2024
00:00
12/1/2024
08:00
8.00 MIRU, MOVE MOB P Move rig off 443, clean up arond well,
prep for spotting over 441
0.0 0.0
12/1/2024
08:00
12/1/2024
09:30
1.50 MIRU, MOVE MOB P Spot T-mats, double stack mats and lay
herculite
0.0 0.0
12/1/2024
09:30
12/1/2024
11:00
1.50 MIRU, MOVE RURD P Spot rig over 441, level up and set down 0.0 0.0
12/1/2024
11:00
12/1/2024
14:00
3.00 MIRU, MOVE RURD P Save out rig prep to take on9.8# NaCl //
Rig Accepted 13:00
0.0 0.0
12/1/2024
14:00
12/1/2024
16:00
2.00 MIRU, MOVE RURD P Rig up to circulate well to 9.8# 0.0 0.0
12/1/2024
16:00
12/1/2024
18:00
2.00 MIRU, WELCTL DISP P PT lines 3000 psi / Displace well with 35
bbls Deep clean 9.8 & 105 bbls 9.8 #
brine Flow Check All good R/U to Set
BPV w/FMC
0.0 0.0
12/1/2024
18:00
12/1/2024
22:00
4.00 MIRU, WHDBOP NUND P N.D Tree Inspect hanger neck threads
and install FMC blanking plug Function
LDS N/U BOP
0.0
12/1/2024
22:00
12/2/2024
00:00
2.00 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE at
250/2500 PSI for 5 Min each, Tested
annular, UVBR's, w/ 2 7/8" & 5 ½”
donut test joints. Test blinds rams.
Choke valves #1 to #13, upper and
lower top drive well control valves. Test
3 1/2" IF FOSV and IBOP. Test 4 1/2"
FOSV. Test 2" rig floor Demco kill valve
MM #13. Test manual and HCR kill
valves & manual and HCR choke
valves. Test two ea 2 1/6" gate auxiliary
valves below LPR. Test hydraulic and
manual choke valves to 1500 PSI and
demonstrate bleed off. Perform
accumulator test. Initial pressure = 3000
PSI, after closure = 1750 PSI, 200 PSI
attained = 16 sec, full recovery attained
=95 sec. UVBR's = 4 sec Annular = 24
sec. Simulated blinds = 5 sec. HCR
choke & kill = 1 sec each. 4 back up
nitrogen bottles average = 2000 PSI.
Test gas detectors, PVT and flow show.
Witnessed waived by AOGCC Inspector
Brian Bixby @ 12-1-24 12:57 PM
12/2/2024
00:00
12/2/2024
03:00
3.00 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE at
250/2500 PSI for 5 Min each, Tested
annular, UVBR's, w/ 2 7/8" & 5 ½”
donut test joints. Test blinds rams.
Choke valves #1 to #13, upper and
lower top drive well control valves. Test
3 1/2" IF FOSV and IBOP. Test 4 1/2"
FOSV. Test 2" rig floor Demco kill valve
MM #13. Test manual and HCR kill
valves & manual and HCR choke
valves. Test two ea 2 1/6" gate auxiliary
valves below LPR. Test hydraulic and
manual choke valves to 1500 PSI and
demonstrate bleed off. Perform
accumulator test. Initial pressure = 3000
PSI, after closure = 1750 PSI, 200 PSI
attained = 16 sec, full recovery attained
=95 sec. UVBR's = 4 sec Annular = 24
sec. Simulated blinds = 5 sec. HCR
choke & kill = 1 sec each. 4 back up
nitrogen bottles average = 2000 PSI.
Test gas detectors, PVT and flow show.
Witnessed waived by AOGCC Inspector
Brian Bixby @ 12-1-24 12:57 PM
0.0 0.0
Rig: NORDIC 3
RIG RELEASE DATE 12/7/2024
Page 2/5
2P-441
Report Printed: 2/13/2025
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/2/2024
03:00
12/2/2024
04:00
1.00 COMPZN, RPCOMP THGR P R/D Test Equip Pull dart and bpv 0.0 0.0
12/2/2024
04:00
12/2/2024
05:00
1.00 COMPZN, RPCOMP TRIP P M/U landing jt BOLDS Pull hanger to
floor up wt 55K
0.0 2,835.0
12/2/2024
05:00
12/2/2024
06:00
1.00 COMPZN, RPCOMP CIRC P Circulate SxS 2,810.0 2,810.0
12/2/2024
06:00
12/2/2024
09:15
3.25 COMPZN, RPCOMP TRIP P L/D 3 1/2" TBG // Pull 88 full jts plus 1
cut jt
2,810.0 0.0
12/2/2024
09:15
12/2/2024
10:15
1.00 COMPZN, RPCOMP CLEN P Clean clear rig floor for picking up CIBP 0.0 0.0
12/2/2024
10:15
12/2/2024
10:30
0.25 COMPZN, RPCOMP BHAH P Make up CIBP BHA# 1 0.0 10.0
12/2/2024
10:30
12/2/2024
12:00
1.50 COMPZN, RPCOMP TRIP P TIH w/ CIBP T/ 2,655' 10.0 2,655.0
12/2/2024
12:00
12/2/2024
13:00
1.00 COMPZN, RPCOMP MPSP P Set plug @ 2,655' // Pump 3.25 bbls ball
on seat, pump 1500 psi tool shift 6K
WOB shift, let sit 2 min , pump 2033 psi
let sit 1 min pump and shear @ 2300psi
Blow down TD prep to trip.
2,655.0 2,655.0
12/2/2024
13:00
12/2/2024
14:30
1.50 COMPZN, RPCOMP TRIP P TOOH with setting tool 2,655.0 0.0
12/2/2024
14:30
12/2/2024
15:30
1.00 COMPZN, RPCOMP PRTS P Test CIBP 1000 psi 10 min // Rig down
test equipment and blow down lines
0.0 0.0
12/2/2024
15:30
12/2/2024
16:00
0.50 COMPZN, RPCOMP BHAH P Pick up BHA# 2 MSC 0.0 10.0
12/2/2024
16:00
12/2/2024
17:30
1.50 COMPZN, RPCOMP TRIP P TIH w/ MSC, tag CIBP @ 2655' P/U t/
2650'
10.0 2,655.0
12/2/2024
17:30
12/2/2024
22:00
4.50 COMPZN, RPCOMP PULL P Attemp to cut casing @ 2650' w/ free
Tq 1000 lb pump pres @ 2 bbls w/ 1000
psi RPM 90 Tq move up t/ 1300 20
mins All look good Attempt to pump up
OA Pres up t/ 550 psi No returns
Seems to be cut but no Ann
Communication POOH 4' Attempt to cut
@ 2646' Same indication as the first
cut . Discuss with engineers in town
Plan is POOH check MSC RIH and
attempt to cut @ 2590'
2,655.0
12/2/2024
22:00
12/2/2024
23:00
1.00 COMPZN, RPCOMP TRIP P POOH
12/2/2024
23:00
12/2/2024
23:30
0.50 COMPZN, RPCOMP BHAH P Redress YJOS MSC M/U BHA # 3 No
indication that the cutter was working
properly
12/2/2024
23:30
12/3/2024
00:00
0.50 COMPZN, RPCOMP P RIH t/ Attempt to cut @ first stage 2650''
12/3/2024
00:00
12/3/2024
01:30
1.50 COMPZN, RPCOMP TRIP P RIH t/ Attempt to cut @ first stage 2650'' 0.0 2,650.0
12/3/2024
01:30
12/3/2024
03:30
2.00 COMPZN, RPCOMP TRIP P Attempt to locate coller Not successful
POOH, L/D YJOS cutter
2,650.0 0.0
12/3/2024
03:30
12/3/2024
06:30
3.00 COMPZN, RPCOMP OTHR T Wait on new MSC from/deadhorse . 0.0 0.0
12/3/2024
06:30
12/3/2024
09:00
2.50 COMPZN, RPCOMP TRIP P M/U New Cutter BHA # 4 RIH. Locate
callar @ 2648' & 2607'.
0.0 2,648.0
12/3/2024
09:00
12/3/2024
10:30
1.50 COMPZN, RPCOMP CPBO P Tag CIBP @ 2655' P/U 4'. Cut 5 1/2"
CSG @ 2651'. Cutter responded will.
No pressure wrap around on OA. P/U 3'
Cut 5 1/2" CSG @ 2648'. Cuttrer
responded well. No pressure wrap
around to OA.
2,648.0 2,648.0
12/3/2024
10:30
12/3/2024
11:30
1.00 COMPZN, RPCOMP TRIP P POOH F/ 2648' T/ 11', PUW=55K. 2,648.0 11.0
12/3/2024
11:30
12/3/2024
12:00
0.50 COMPZN, RPCOMP BHAH P L/D BHA #4, inspect cutter blades.
Showed good wear pattern.
11.0 0.0
Rig: NORDIC 3
RIG RELEASE DATE 12/7/2024
Page 3/5
2P-441
Report Printed: 2/13/2025
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/3/2024
12:00
12/3/2024
12:30
0.50 COMPZN, RPCOMP BHAH P Redress MSC w/ new blades. RIH w/
BHA #5 5 1/2" MSC T/ 11'
0.0 11.0
12/3/2024
12:30
12/3/2024
14:00
1.50 COMPZN, RPCOMP TRIP P RIH w/ BHA #5 T/ 2490. Obtain
parameters. Pump @ 2.5 BPM, 533
PSI. RIH & locate collar @ 2524'. RIH
T/ 2550'.
11.0 2,550.0
12/3/2024
14:00
12/3/2024
14:30
0.50 COMPZN, RPCOMP CPBO P Cut 5 1/2" CSG @ 2550'. 3 BPM, 1200
PSI. 1.8K Tq. 400 PSI wrap around on
OA. P/U T/ 2548'
2,550.0 2,548.0
12/3/2024
14:30
12/3/2024
15:45
1.25 COMPZN, RPCOMP CIRC P Close UPR. Open OA, Circ 70 Bbls
Deep clean pill followed by 100 Blls 9.8#
bine out OA.
2,548.0 2,548.0
12/3/2024
15:45
12/3/2024
16:45
1.00 COMPZN, RPCOMP OWFF P OWFF, no flow at tank. Open UPR.
Suck out stack. OWFF from TBG & IA.
30 Min no flow.
2,548.0 2,548.0
12/3/2024
16:45
12/3/2024
18:45
2.00 COMPZN, RPCOMP TRIP P POOH L/D BHA 2,548.0 0.0
12/3/2024
18:45
12/3/2024
20:45
2.00 COMPZN, RPCOMP BHAH P R/U 5 1/2" landing Joint RIH M/U on
hanger P/U pulled free with no issue
P/U wt 70K L/D hanger Monitor well 15
mins OK
2,550.0 2,550.0
12/3/2024
20:45
12/3/2024
23:00
2.25 COMPZN, RPCOMP PULL P Cont L/D 5 1/2" casing Tot 59 joints and
26' cut jt
2,550.0 0.0
12/3/2024
23:00
12/4/2024
00:00
1.00 COMPZN, RPCOMP BHAH P R/D 5 1/2" Equip /M/U BHA #5 w/ spear 0.0 228.0
12/4/2024
00:00
12/4/2024
01:30
1.50 COMPZN, RPCOMP TRIP P RIH w/ 3 1/2" D.P and Tag up Fish @
2550'
228.0 2,550.0
12/4/2024
01:30
12/4/2024
02:30
1.00 COMPZN, RPCOMP FISH P Start Jarring fish w/ 75k over pulled free
@ 200K 27 hits
2,550.0 2,540.0
12/4/2024
02:30
12/4/2024
03:30
1.00 COMPZN, RPCOMP CIRC P POOH 1 Stand Circ B/U - no losses.
Inspect Derrick
2,540.0 2,440.0
12/4/2024
03:30
12/4/2024
05:00
1.50 COMPZN, RPCOMP TRIP P POOH and Rack Back 3 1/2" D.P 2,440.0 228.0
12/4/2024
05:00
12/4/2024
07:30
2.50 COMPZN, RPCOMP BHAH P L/D BHA #5 & 96.91' of 5 1/2" fish.
Clean cut
228.0 0.0
12/4/2024
07:30
12/4/2024
08:00
0.50 COMPZN, RPCOMP CLEN P Clean & clear RF & pipe shed. 0.0 0.0
12/4/2024
08:00
12/4/2024
08:30
0.50 COMPZN, RPCOMP RURD P R/U 3 1/2" tubing handling equipment. 0.0 0.0
12/4/2024
08:30
12/4/2024
11:30
3.00 COMPZN, RPCOMP PULD P RIH w/ old 3 1/2", 9.3#, L-80, EUE-M
TBG string T/ 2588'. PUW=51K,
SOW=51K.
0.0 2,588.0
12/4/2024
11:30
12/4/2024
11:45
0.25 COMPZN, RPCOMP WASH P Wash in hole w/ 3 1/2" EUE F/ 2588' T/
2646' @ 4 BPM, 140 PSI. B/D TD.
2,588.0 2,646.0
12/4/2024
11:45
12/4/2024
12:00
0.25 COMPZN, RPCOMP SFTY P PJSM w/ HES cement & rig crew on
pumping balance plug.
2,646.0 2,646.0
12/4/2024
12:00
12/4/2024
12:15
0.25 COMPZN, RPCOMP RURD P R/U HES, head pin & cement hose. 2,646.0 2,646.0
12/4/2024
12:15
12/4/2024
12:45
0.50 COMPZN, RPCOMP PRTS P HES flood lines w/ 5 Bbls 9.8# brine.
PT lines T/ 2500 PSI. Blow back lines
to cement unit.
2,646.0 2,646.0
12/4/2024
12:45
12/4/2024
13:45
1.00 COMPZN, RPCOMP CMNT P HES batch up spacer & 15.8 PPG
cement. Cement wet @ 13:02 Hrs.
2,646.0 2,646.0
Rig: NORDIC 3
RIG RELEASE DATE 12/7/2024
Page 4/5
2P-441
Report Printed: 2/13/2025
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/4/2024
13:45
12/4/2024
14:15
0.50 COMPZN, RPCOMP CMNT P HES pump 24 Bbls 10.0 PPG spacer @
2.5 BPM, 110 PSI. Shut down, close
UPR break hose, drop foam ball. R/U,
open UPR. HES pump 16 Bbls 15.8
PPG cement @ 2.4 BPM, 175 PSI.
Shut down, close UPR break hose, drop
foam ball. R/U, open UPR. HES pump
4 Bbls 10.0 PPG spacer @ 2.5 BPM, 65
PSI. Displace w/ 13.4 Bbls 9.8 PPG
brine @ 2.7 BPM, 110 PSI. Good
returns to surface through entire job.
Blow air through lines to cement unit.
2,646.0 2,646.0
12/4/2024
14:15
12/4/2024
15:00
0.75 COMPZN, RPCOMP TRIP P POOH, L/D single rack back 7 stands
TBG F/ 2646' T/ 1959'. PUW=51K.
Cement in place @ 14:58 Hrs.
2,646.0 1,959.0
12/4/2024
15:00
12/4/2024
15:30
0.50 COMPZN, RPCOMP CIRC P Circ out spacer & green cement @ 4
BPM, 145 PSI.
1,959.0 1,959.0
12/4/2024
15:30
12/5/2024
00:00
8.50 COMPZN, RPCOMP WOC P Wait on 500 PSI compressive strength
21:05 Hrs plus 3 Hrs safety factor.
1,959.0 1,959.0
12/5/2024
00:00
12/5/2024
20:00
20.00 COMPZN, RPCOMP WOC P Wait on 500 PSI compressive strength
21:05 Hrs plus 3 Hrs safety factor.
1,959.0 1,959.0
12/5/2024
20:00
12/5/2024
21:30
1.50 COMPZN, RPCOMP CIRC P Start wash Down F/ 1960' @ 2 bbls 100
psi Tag soft cement @ 2322' 4/6 K
Continue Down t/ wash down tag @
2345" W/10K down P/U 5' w/ AOGCC
witness tag By Sean Sullivan State Man
Discuss w/ Engineer All Good
1,959.0 2,340.0
12/5/2024
21:30
12/5/2024
23:30
2.00 COMPZN, RPCOMP OTHR P Shut down line up on tubing and pump
down tubing Close UPR hook up sensor
IA Test cement plug and casing 800 PSI
10 mins All good pump up to 1500 PSI
F/ 30 mins All good w/ State Man
2,340.0 2,340.0
12/5/2024
23:30
12/6/2024
00:00
0.50 COMPZN, RPCOMP CIRC P CBU @ 5 bbls 190 PSI Call FMC 2,340.0 2,344.0
12/6/2024
00:00
12/6/2024
01:30
1.50 COMPZN, RPCOMP THGR P M/U Hanger RIH and RILDS Run Tot 74
Jts 3 1/2" EUE set @ 2339' 6' off of
cement Plug. PUW=52K, SOW=52K.
2,344.0 2,339.0
12/6/2024
01:30
12/6/2024
07:00
5.50 COMPZN, WHDBOP WWWH P R/D Landing Jt P/U Johnny whacker
and Flush out BOP stack R/D Blow
Down Surf Equip Open up Doors on
stack clean out cement from ram
cavities.
2,339.0 2,339.0
12/6/2024
07:00
12/6/2024
08:30
1.50 COMPZN, WHDBOP NUND P N/D BOP. 2,339.0 2,339.0
12/6/2024
08:30
12/6/2024
10:00
1.50 COMPZN, WHDBOP NUND P N/U old adaptor spool & tree. 2,339.0 2,339.0
12/6/2024
10:00
12/6/2024
10:15
0.25 COMPZN, WHDBOP PRTS P PT hanger void T/ 5000 PSI for 10 Min. 2,339.0 2,339.0
12/6/2024
10:15
12/6/2024
11:30
1.25 COMPZN, WHDBOP RURD P R/U HES T/ tree. R/U return lines.
Distribute black water contamination pill.
2,339.0 2,339.0
12/6/2024
11:30
12/6/2024
12:00
0.50 COMPZN, WHDBOP SFTY P PJSM w/ HES & rig crew on pumping
cement to surface.
2,339.0 2,339.0
12/6/2024
12:00
12/6/2024
12:30
0.50 COMPZN, WHDBOP PRTS P Pump 4 Bbls fresh water w/ Surf wash
flood lines. PT cement hard line T/ 2500
PSI.
2,339.0 2,339.0
12/6/2024
12:30
12/6/2024
14:15
1.75 COMPZN, WHDBOP CMNT P Cement wet @ 13:09. Pump 16
additional Bbls fresh water w/ Surf wash
2 BPM, 230 PSI. Pump 128.5 Bbls
15.8# cement @ 2.6 BPM, 72 PSI.
Good 15.8 PPG returns to surface. 23
Bbls returned to surface. Cement in
place @ 14:13 Hrs. Close in wing, IA,
Swab & Master valves.
2,339.0 0.0
Rig: NORDIC 3
RIG RELEASE DATE 12/7/2024
Page 5/5
2P-441
Report Printed: 2/13/2025
Operations Summary (with Timelog Depths)
Job: RECOMPLETION
Time Log
Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)
12/6/2024
14:15
12/6/2024
18:00
3.75 COMPZN, WHDBOP RURD P Flush & B/D return lines & back to
cement van w/ black water pill. R/D
HES & cement plumbing in cellar. Suck
out & clean cuttings tank.
12/6/2024
18:00
12/7/2024
00:00
6.00 DEMOB, MOVE MOB P RDMO F/P2-441 T/ P2-438
Rig: NORDIC 3
RIG RELEASE DATE 12/7/2024
2025-0119_Surface_Abandon_KRU_2P-441_ss
Page 1 of 4
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Jim Regg DATE: 1-19-2025
P. I. Supervisor
FROM: Sully Sullivan SUBJECT: Surface Abandonment
Petroleum Inspector KRU 2P-441
ConocoPhillips Alaska Inc.
PTD 2020170; Sundry 324-586
1-19-2025: Travel out to Kuparuk River Unit 2P pad to witness top job and ID plate
installation for well 2P-441. Once on location I met with CPAI representative Roger
Mouser and received all appropriate documentation. I inspected the ID plate and took
measurements of the cut-off (see attachments). I inspected the cement for hardness
and made sure it was to surface. The ID plate was seal welded to the conductor with no
overlap. I inspected the weld and gave the okay to continue with program.
Attachments: Photos
9
9
9
9
James B. Regg Digitally signed by James B. Regg
Date: 2025.02.03 15:14:03 -09'00'
2025-0119_Surface_Abandon_KRU_2P-441_ss
Page 2 of 4
Surface Abandonment – KRU 2P-441 (PTD 2020170)
Photos by AOGCC Inspector S. Sullivan
1/19/2025
9
2025-0119_Surface_Abandon_KRU_2P-441_ss Page 3 of 4
2025-0119_Surface_Abandon_KRU_2P-441_ss
Page 4 of 4
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Jim Regg DATE:
P.I. Supervisor
SUBJECT:
FROM:
Petroleum Inspector
Section: 17 Township: 8N Range: 7E Meridian: Umiat
Drilling Rig: Nordic 3 Rig Elevation: 30.85 ft Total Depth: 7327 ft MD Lease No.: ADL0373112
Operator Rep: Suspend: P&A: X
Conductor: 16" O.D. Shoe@ 120 Feet Csg Cut@ Feet
Surface: 7 5/8" O.D. Shoe@ 2594 Feet Csg Cut@ 2650 Feet
Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet
Production: 5 1/2" O.D. Shoe@ 4696 Feet Csg Cut@ Feet
Liner: 3 1/2" O.D. Shoe@ 7325 Feet Csg Cut@ Feet
Tubing: 3 1/2" O.D. Tail@ 4554 Feet Tbg Cut@ Feet
Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified
Fullbore Bridge plug 2655 ft MD 2345 ft MD 9.8 ppg Drillpipe tag
Initial 15 min 30 min 45 min Result
Tubing
IA 800 1680 1600 1580
OA
Initial 15 min 30 min 45 min Result
Tubing
IA
OA
Remarks:
Attachments:
Ronnie Dalton
Casing/Tubing Data (depths are MD):
Plugging Data (depths are MD):
Traveled to KRU 2P-441 to witness tag and test of surface shoe cement plug. Tag @ 2345 ft MD (249 ft above the shoe) w/ 9K
lbs down weight. MIT was performed without issue.
December 6, 2024
Sully Sullivan
Well Bore Plug & Abandonment
KRU 2P-441
ConocoPhillips Alaska Inc.
PTD 2020170; Sundry 324-586
none
Test Data:
P
Casing Removal:
rev. 3-24-2022 2024-1206_Plug_Verification_KRU_2P-441_ss
ORIGINATED
TRANSMITTAL
DATE: 10/21/2024
ALASKA E-LINE SERVICES
TRANSMITTAL
#: 5127
42260 Kenai Spur Hwy
PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk River
PH: (907) 283-7374 FAX: (907) 283-7378
DELIVERABLE DESCRIPTION
TICKET # WELL # API #
LOG
DESCRIPTION
DATE OF
LOG
5127 2P-441 50103204070000 Tubing Cut Record 17-Oct-2024
RECIPIENTS
Conoco
DIGITAL FILES PRINTS CD'S
1 FTP Transfer 0 0 USPS
Attn: NSK-69
Richard.E.Elgarico@conocophillips.com 700 G Street
Anchorage, AK 99503
Received
By: Received By:
Signature Signature
AOGCC
DIGITAL FILES PRINTS CD'S
1 ShareFile 0 0 USPS
Attn: Natural Resources Technician II
abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision
aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501
Received
By: Received By:
Signature Signature
202-017
T39704
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2024.10.21 15:19:50
-08'00'
DNR
DIGITAL FILES PRINTS CD'S
1 SharePoint
Link 0 0 USPS
Attn: Natural Resource Tech II
DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501
Delivery Method: USPS
Received
By: Received By:
Signature Signature
Please return via e-mail a copy to both:
AR@ake-
line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com
1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown
Suspend Perforate Other Stimulate Pull Tubing Change Approved Program
Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other:
2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number:
Exploratory Development
3. Address:Stratigraphic Service
6. API Number:
7. If perforating:8. Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool?
Yes No
9. Property Designation (Lease Number): 10. Field:
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD):
7327'514'
Casing Collapse
Structural
Conductor
Surface
Intermediate
Production
Liner
Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft):
12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work:
Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service
14. Estimated Date for 15. Well Status after proposed work:
Commencing Operations: OIL WINJ WDSPL Suspended
16. Verbal Approval: Date: GAS WAG GSTOR SPLUG
AOGCC Representative: GINJ Op Shutdown Abandoned
Contact Name:
Contact Email:
Contact Phone:
Authorized Title:
Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number:
Plug Integrity BOP Test Mechanical Integrity Test Location Clearance
Other Conditions of Approval:
Post Initial Injection MIT Req'd? Yes No
APPROVED BY
Approved by: COMMISSIONER THE AOGCC Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
(907) 263-4597
Senior CTD/RWO Engineer
KRU 2P-441
5795' 3460' 2990' 3460', 6848', 6919'
N/A
Subsequent Form Required:
Suspension Expiration Date:
Will perfs require a spacing exception due to property boundaries?
Current Pools:
Plugs (MD):
17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval.
Authorized Name and
Digital Signature with Date:
Tubing Size:
Shane.Germann@conocophillips.com
AOGCC USE ONLY
Tubing Grade: Tubing MD (ft):
4559' MD and 3796' TVD
N/A
Shane Germann
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL0373112
202-017
P.O. Box 100360, Anchorage, AK 99510 50-103-20407-00-00
Kuparuk River Field Meltwater Oil Pool - Suspended
ConocoPhillips Alaska, Inc.
Length Size
Proposed Pools:
PRESENT WELL CONDITION SUMMARY
Meltwater Oil Pool -
Abandoned
TVD Burst
4554'
MD
110'
2378'
110'
2594'
3890'4696'
16"
7-5/8"
89'
2563'
6950-6960'
4666'
3-1/2"
5520-5527'
5-1/2"
Perforation Depth TVD (ft):
11/14/2024
7325'2766'
3-1/2"
5793'
Packer: Baker Liner Top Packer
SSSV: None
Perforation Depth MD (ft):
L-80
Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
MPSP (psi):
850 psi
By Grace Christianson at 8:51 am, Oct 09, 2024
Digitally signed by Shane Germann
DN: O=ConocoPhillips, CN=Shane Germann
, E=shane.germann@conocophillips.com
Reason: I am the author of this document
Location:
Date: 2024.10.09 07:42:34-08'00'
Foxit PDF Editor Version: 13.0.0
324-586
X
BOP test to 2500 psig
Annular preventer test to 2500 psig
See attached "Conditions of Approval"
X
VTL 11/27/2024
June 30, 2025
DSR-10/10/24
10-407
X
SFD 10/26/2024
X
*&:
Jessie L.
Chmielowski
Digitally signed by Jessie L. Chmielowski
Date: 2024.11.27 15:04:55 -09'00'11/27/24
RBDMS JSB 112924
KRU 2P-4ϰϭ
Abandonment Conditions of ƉƉƌŽǀĂů͗
ϭ͘ ǀĂriance is granted from 20 AAC 25.112(a)(1)(A) which requires a cement plug from 100'
below the base of the hydrocarbon-bearing strata.
ʹǤ A variance is granted under 20 AAC 25.112(i) to allow the alternate plug placement described as
the recovery of 50' of production casing below the surface casing shoe and a cement plug
placed across this open hole section and 150' into the surface casing. The plug must pass a
State Witnessed pressure test and tag according to 20 AAC 25.112(g).
͵Ǥ A variance to Order 196 is granted that will eliminate the requirement of logging the cement
placed across the hydrocarbon-bearing strata.
ͶǤ A failed pressure test of the surface casing shoe plug requires the submission of a new
sundry (10-403) to cover the rigless abandonment scope if planned. Completion of
workover operations under the original sundry will be complete and a 10-407 Well
Completion or Recompletion Report and Log must be filed with the Commission within 30
days following the completion of workover operations.
ͷǤ If surface abandonment operations are not initiated within 0 days after the successful
placement of the surface casing shoe plug (State witnessed pressure test and tag), a 10-407
Well Completion or Recompletion Report and Log must be filed with the Commission
within͵0 days after the completion of workover operations to date.
Ǥ Plugging of the surface of a well must meet the requirements of 20 AAC 25.112(d) and 20
AAC 25.120.
Ǥ AOGCC witness is required after the wellhead cutoff and prior to a top job.
Variances granted provide for at least equally effective plugging of the well and prevention of fluid
movement into sources of hydrocarbons or freshwater.
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Digitally signed by Shane Germann
DN: O=ConocoPhillips, CN=Shane
Germann, E=shane.germann@
conocophillips.com
Reason: I am the author of this
document
Location:
Date: 2024.10.09 07:42:59-08'00'
Foxit PDF Editor Version: 13.0.0
2P-441 Plug and Abandonment
Background & Objective
2P-441 was a producer that has been shut in since late 2021. It has no known tubing or IA integrity
issues. This well will be P&A’d as part of the 2P pad abandonment. 2P pad does not have any
facilities or surface line hookups, and the pad is slated to be used as storage for the Willow
development project in 2026. This well was suspended via reservoir cement plug and intermediate
cement plug. The objective of this procedure is to pump the surface casing shoe cement plug and
final abandonment cement plug with Nordic 3 and ultimately execute final abandonment.
Well Data
Meltwater Formation:
x Reservoir pressure 8/9/2020 = 906 psi @ 5400’ TVD
x MASP = 366 psi
C-80 Formation:
x OAP = 268 psi (1/5/22) (fluid packed with diesel)
x MASP = 850 psi
Anticipated intermediate plug TOC = 3460’ MD
Anticipated tubing cut depth = 2840’ MD
Surface Casing Plugs – Rig
Date: 9-26-2024
Prepared by: Shane Germann
Estimated Start Date: 11-14-2024
MIRU
1. MIRU on 2P-441.
2. Record shut-in pressures on the T & IA. If there is pressure, bleed oƯ IA and/or tubing
pressure and complete 30-minute NFT. Verify well is dead before proceeding.
3. ND Tree and NU BOPE. Test rams and annular to 250/2,500 PSI.
a. Will not set BPV due to two tested cement plugs below providing two barriers to
formation.
b. BOPE ConƱguration: Annular / Variable Bore Rams / Blind Rams / Pipe Rams
4. Circulate tubing and IA to brine.
Retrieve Tubing
5. MU landing joint and BOLDS.
6. Pull tubing from pre-rig cut to surface and LD.
Execute First Surface Casing Abandonment Plug
1. Set bridge plug in production casing 100’ below surface casing shoe
2. Cut production casing 50’ below surface casing shoe
3. Circulate OA to brine and complete 30-minute NFT.
a. Punch holes in production casing at the surface casing shoe if unable to achieve
circulation from production casing cut.
4. MU landing joint for production casing hanger and conƱrm casing is free from cut.
a. Contingency: If unable to pull production casing from original cut depth
i. Perform second cut inside surface casing shoe
ii. Pull casing down to upper cut and laydown
iii. PU DP and Ʊshing assembly
iv. TIH and engage cut stub of prod casing. Fish stub free.
v. Retrieve to surface. LD DP
5. Pump cement plug through the production casing cut. Utilize 14 BBL of cement, plus
excess, to target a Ʊnal TOC ±150’ TVD inside the surface casing shoe. Slightly under
displace cement and pull 5-1/2” casing slowly to above Ʊnal TOC - allowing cement to Ʊll
the space vacated by the casing displacement. Ensure base of 5-1/2” casing is between
150’ – 200’ TVD inside the surface casing shoe based on space out of a casing collar at the
Ʋoor. Circulate the base of the prod casing clear of any residual cement. See table below for
cement volume calculations.
a. Contingency: if unable to pull prod casing from original cut depth
i. TIH with tubing to above the casing shoe
ii. Pump cement plug across the shoe through the tubing. PU and circulate the
base of the tubing clear
b. A Variance is requested to 20 AAC 25.112 requiring cement 100’ below hydrocarbon
bearing zones. It is our intention to recover 50’ of production casing from the open
hole section.
c. A Variance is requested to Order 196 requiring the cement to be logged. It is not our
intention, nor recommendation for the integrity of the abandonment, to drill out the
cement plug once pumped.
6. WOC
7. Tag cement and PT to 1,500 PSI with state witness
a. Pressure up to FIT equivalent and hold for 10 min to ensure no leak oƯ prior to
increasing pressure to full 1,500 PSI for 30-min state witness
b. If PT fails, the well will be suspended with KWF and a kill string in preparation for o Ư-
rig remediation.
Production Casing Cement:
37 bbls of 15.8# Class G Cement
Estimated TOC @ 3,052' KB
Liner Cement:
31.3 bbls of 15.8# Class G Cement
Calculated TOC @ 4,559.2' KB
2P-441 Well Surface Shoe Cement Schematic
Conductor:
16" Conductor 120' KB
1
2
3
5
Production Casing:
5 ½" 15.5# L-80 BTCMOD
Set @ 4,696’ KB
Bermuda Peforations:
@ 6,950' – 6,960' KB (10')
Surface Casing:
7-5/8", 29.7#, L-80 BTCMOD
Set @ 2,593.8' KB (2377' TVD)
Production Tubing:
3.5" 9.3# L-80 EUE-8rdMOD
Set @ 4,553.8' KB
76 8
4
9
10
11
Liner:
3.5" 9.3# L-80 BTCMOD
Set @ 7,325’ KB
C80 @ 2690' KB C80 @ 2690' KB
Plug #1 – Reservoir
TOC ±6890' RKB
Plug #2 – Intermediate
TOC ±3460
BOC ±4460
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Plug #3 – Surface Shoe
TOC 2382' RKB (2227' TVD)
BOC @ ±2690' RKB
Base of 5-½” Casing
250'-300' MD Inside
Surface Shoe
Execute Final Abandonment Plug
8. Land workstring in casing hanger proƱle.
9. Circulate cement surface to surface until full cement returns observed on surface. See
table below for cement volumes.
RDMO
10. ND BOPE. NU dry hole tree.
a. Note: this step may be performed prior to pumping Ʊnal surface to surface
abandonment plug.
11. RDMO.
Cement Plug TOC BOC Section ID BBL/FT Volume Notes
Surface Shoe
2643 2693 Open Hole 6.75 0.03867 1.9 Displacement of Prod Casing
Stub Included in BBL/FT calc
2593 2643 Open Hole 6.75 0.04426 2.2
2382 2593 Surface Casing 6.87 0.04585 9.7
13.8 Total Volume of Plug
Surface Casing 23 2382 Surface Casing 6.87 0.04026 95.0 Displacement of Prod Casing
Included in BBL/FT calculation
Execute Final Abandonment
Surface Excavation
12. DHD to perform drawdown test on tubing, IA, and OA
13. Remove well house.
14. Bleed oƯ T/I/O to ensure all pressure is bled oƯ the system.
15. Remove tree in preparation for excavation and casing cut.
16. If shallow thaw conditions are found, have shoring box installed during the excavation
activity to prevent loose ground from falling into the excavation.
17. Cut oƯ wellhead and all casing strings at 4 feet below original ground level.
18. Perform top job if needed to ensure cement is at surface on all strings. AOGCC witness and
photo document required.
19. Send the casing head with stub to materials shop. Photo document.
20. Weld 1/4" thick cover plate (16" OD) over all casing strings with the following information
bead welded into the top. Photo document. AOGCC witness required.
a. ConocoPhillips
b. KRU 2P-441
c. PTD #: 202-017
d. API #: 50-103-20407-00-00
21. Remove cellar. Back Ʊll cellar with gravel/Ʊll as needed. Back Ʊll remaining hole to ground
level.
22. Obtain site clearance approval from AOGCC. RDMO.
23. Report the Ʊnal P&A has been completed to the AOGCC. Photo document Ʊnal location
condition after work is completed
Production Casing Cement:
37 bbls of 15.8# Class G Cement
Estimated TOC @ 3,052' KB
Liner Cement:
31.3 bbls of 15.8# Class G Cement
Calculated TOC @ 4,559.2' KB
2P-441 Well Final P&A Schematic
Conductor:
16" Conductor 120' KB
1
2
3
5
Production Casing:
5 ½" 15.5# L-80 BTCMOD
Set @ 4,696’ KB
Bermuda Peforations:
@ 6,950' – 6,960' KB (10')
Surface Casing:
7-5/8", 29.7#, L-80 BTCMOD
Set @ 2,593.8' KB (2377' TVD)
Production Tubing:
3.5" 9.3# L-80 EUE-8rdMOD
Set @ 4,553.8' KB
76 8
4
9
10
11
Liner:
3.5" 9.3# L-80 BTCMOD
Set @ 7,325’ KB
C80 @ 2690' KB C80 @ 2690' KB
Plug #1 – Reservoir
TOC ±6890' RKB
Plug #2 – Intermediate
TOC ±3460
BOC ±4460
/ƚĞŵĞƉƚŚͲƚŽƉƐ
;<Ϳ
ϭ &D,E' Z ϮϱΖ
Ϯ ^d/ZKEZ/' W>h' ϮϲϵϬΖ
ϯ < ZDh^>//E'^> s t^
WZK&/> ϰ͕ϰϳϴ͘ϴΖ
ϰ DKE/WW> ϰ͕ϰϵϰ͘ϴΖ
ϱ < ZWK>/^, WZ ϰ͕ϱϯϵ͘ϭΖ
ϲ < Z<ͲϮϮE,KZͲdh/E'^ >
KtE ϰ͕ϱϱϯ͘ϭΖ
ϳ < Zd/ Ͳ<^> s /ϰ͘ϱϭΗ͕< Z
>/E ZdKWW< Z/ϯ͘ϵϭΗ ϰ͕ϱϱϵ͘ϮΖ
ϴ < ZWK>/^, KZ Z Wd> ϰ͕ϱϳϰ͘ϰΖ
ϵ < Z,D>/E Z,E' Z ϰ͕ϱϳϵ͘ϰϬ
ϭϬ < ZϴϬͲϰϬ^ >KZ yd E^/KE ϳ͕ϰϰϲ͘ϱΖ
ϭϭ ZK^^Ks Zh^,/E' ϵ͕ϵϮϰ͘ϳΖ
Plug #3 – Surface Shoe
TOC 2382' RKB (2227' TVD)
BOC @ ±2690' RKB
Plug #4 – Surface
TOC 23' RKB
BOC @ ±2382' RKB
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag: RKB 6,963.0 2P-441 6/21/2024 rogerba
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Added tubing cut & Eline fish 2P-441 10/7/2024 jconne
Notes: General & Safety
Annotation End Date Last Mod By
NOTE: View Schematic w/ Alaska Schematic9.0 11/24/2010 ninam
NOTE: WAIVERED WELL: OA PRESSURE CHARGING FROM RESERVOIR 11/30/2004 WV5.3
Conversio
n
Casing Strings
Csg Des OD (in) ID (in) Top (ftKB)
Set Depth
(ftKB)
Set Depth
(TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread
CONDUCTOR 16 15.06 31.0 120.0 120.0 62.60 WELDED
SURFACE 7 5/8 6.87 30.9 2,593.8 2,377.6 29.70 L-80 BTCMOD
PRODUCTION 5 1/2 4.95 30.2 4,696.0 3,890.2 15.50 L-80 BTCMOD
LINER 3 1/2 2.99 4,559.2 7,325.0 5,793.2 9.30 L-80 BTCMOD
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
25.0
Set Depth …
4,553.8
Set Depth …
3,791.7
String Max No…
3 1/2
Tubing Description
TUBING
Wt (lb/ft)
9.30
Grade
l-80
Top Connection
EUE-8rdMOD
ID (in)
2.99
Completion Details: excludes tubing, pup, space out, thread, RKB...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal
ID (in)
25.0 25.0 0.00 HANGER 8.000 CT1A TUBING HANGER 3.500
514.8 514.8 0.48 NIPPLE 4.520 CAMCO DS NIPPLE CAMCO DS 2.875
2,082.7 1,998.7 35.03 GAS LIFT 4.425 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900
3,601.9 3,095.5 42.40 GAS LIFT 4.425 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900
4,429.0 3,704.9 45.21 GAS LIFT 4.425 CAMCO KBG-2-9 CAMCO KGB-2-9 2.900
4,478.8 3,739.8 45.78 SLEEVE-O 4.500 BAKER CMU SLIDING SLEEVE
w/DS PROFILE
BAKER CMU 2.813
4,494.8 3,750.9 45.97 NIPPLE 4.550 CAMCO D NIPPLE CAMCO D 2.750
4,539.1 3,781.6 46.31 PBR 4.500 BAKER POLISHED PBR BAKER 3.000
4,553.1 3,791.3 46.29 ANCHOR 4.500 BAKER K-22 ANCHOR - TUBING
SEAL DOWN
BAKER K-22 3.000
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top (ftKB)
Top (TVD)
(ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in)
514.8 514.8 0.48 FISH ELINE TOOL-STRING LIH
AFTER JET CUT. HEAD, (2X)
WEIGHT-BAR, CCL, SHOCK
MANDREL, & SPENT JET
CUTTER (OAL = 18.5'). 1"
F.N.
10/7/2024 0.000
2,840.0 2,551.9 45.49 CUT JET CUT @ 2840' RKB 10/7/2024 2.992
4,460.0 3,726.7 45.57 TUBING
PUNCH
3FT OF 2" TUBING PUNCH,
4SPF, 0 DEGREE PHASE
(PUMP 20 BBL DIESEL
THROUGH AT 2 BPM AND
150 PSI)
9/27/2024 2.992
6,919.3 5,497.3 42.75 CIBP CIBP MID-ELEMENT AT 6920'
RKB, OAL = 1.37'
6/29/2024 0.000
Mandrel Inserts : excludes pulled inserts
Top (ftKB)
Top (TVD)
(ftKB)
Top
Incl (°)
St
ati
on
No
/S Serv
Valve
Type
Latch
Type
OD
(in)
TRO Run
(psi) Run Date Com Make Model
Port
Size (in)
2,082.7 1,998.7 35.03 1 GAS LIFT Open 1 9/30/2024
3,601.9 3,095.5 42.40 2 GAS LIFT DMY INT 1 0.0 3/26/2002 0.000
4,429.0 3,704.9 45.21 3 GAS LIFT DMY INT 1 0.0 7/1/2024 0.000
Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal ID
(in)
4,559.2 3,795.5 46.29 PACKER 5.820 BAKER TIE-BACK SLEEVE ID
4.51", BAKER LINER TOP
PACKER ID 3.91"
BAKER FA 3.910
4,574.4 3,806.0 46.27 SBR 4.250 BAKER POLISHED BORE
RECEPTACLE
BAKER 2.992
7,227.1 5,721.0 42.67 Plug Catcher 3.500 2.992
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
6,950.0 6,960.0 5,519.8 5,527.1 BERMUDA, 2P-
441
3/30/2002 6.0 IPERF 2.5" Gun, 2506 HJ RDX, 60
deg phase
Stimulation Intervals
Top (ftKB) Btm (ftKB)
Inter
val
Num
ber Type Subtype Start Date
Proppant
Designed (lb)
Proppant
Total (lb)
Vol Clean
Total (bbl)
Vol Slurry
Total (bbl)
6,950.0 6,960.0 1 FRAC 4/1/2002 0.0 0.00 0.00
6,950.0 6,960.0 1 RE-FRAC 5/19/2004 0.0 0.00 0.00
Cement Squeezes
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Des Com
Pump Start
Date
6,848.0 6,919.3 5,444.5 5,497.3 Cement Plug DUMP BAILER CEMENT PLUG.
2P-441, 10/9/2024 7:08:05 AM
Vertical schematic (actual)
LINER; 4,559.2-7,325.0
RE-FRAC; 6,950.0
FRAC; 6,950.0
IPERF; 6,950.0-6,960.0
CIBP; 6,919.3
Cement Plug; 6,848.0 ftKB
PRODUCTION; 30.2-4,696.0
TUBING PUNCH; 4,460.0
GAS LIFT; 4,429.0
GAS LIFT; 3,601.9
Cement Plug; 3,460.0 ftKB
CUT; 2,840.0
SURFACE; 30.9-2,593.8
GAS LIFT; 2,082.7
FISH; 514.8
NIPPLE; 514.8
CONDUCTOR; 31.0-120.0
KUP PROD
KB-Grd (ft)
35.10
RR Date
4/25/2002
Other Elev…
2P-441
...
TD
Act Btm (ftKB)
7,327.0
Well Attributes
Field Name
MELTWATER
Wellbore API/UWI
501032040700
Wellbore Status
PROD
Max Angle & MD
Incl (°)
48.60
MD (ftKB)
6,016.54
WELLNAME WELLBORE2P-441
Annotation
Last WO:
End DateH2S (ppm)
25
Date
12/6/2016
Comment
SSSV: NIPPLE
Cement Squeezes
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Des Com
Pump Start
Date
3,460.0 4,463.0 2,990.3 3,728.8 Cement Plug Cement Bal Plug - PUMPED 21 BBLS OF 15.8 PPG
CEMENT & DISPLACED CEMENT w/ 30 BBLS OF
9.8 PPG NaCl KWF.
9/28/2024
2P-441, 10/9/2024 7:08:06 AM
Vertical schematic (actual)
LINER; 4,559.2-7,325.0
RE-FRAC; 6,950.0
FRAC; 6,950.0
IPERF; 6,950.0-6,960.0
CIBP; 6,919.3
Cement Plug; 6,848.0 ftKB
PRODUCTION; 30.2-4,696.0
TUBING PUNCH; 4,460.0
GAS LIFT; 4,429.0
GAS LIFT; 3,601.9
Cement Plug; 3,460.0 ftKB
CUT; 2,840.0
SURFACE; 30.9-2,593.8
GAS LIFT; 2,082.7
FISH; 514.8
NIPPLE; 514.8
CONDUCTOR; 31.0-120.0
KUP PROD 2P-441
...
WELLNAME WELLBORE2P-441
ϮWͲϰϰϭϱ ƐƚŝŵĂƚĞĚ WdKΛϯϬϱϮ͛Z<^^ŚŽĞΛϮϱϵϯ͛Z</WΛϮϲϵϯ͛Z<^^ŚŽĞĐĞŵĞŶƚƉůƵŐdKΛϮϯϴϮ͛Z<WƵƚΛϮϲϰϯ͛Z<ϴϬdŽƉ ΛϮϲϵϬ͛Z<ϴϬĂƐĞΛϰϬϭϬ͛Z<
1a. Well Status:Oil SPLUG Other Abandoned Suspended
1b. Well Class:
20AAC 25.105 20AAC 25.110 Development Exploratory
GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test
2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry:
Aband.:
3. Address: 7. Date Spudded: 15. API Number:
4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number:
Surface:
Top of Productive Interval:17. Field / Pool(s):
GL: BF:
Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation:
4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number:
Surface: x- y- Zone- 4
TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD:
Total Depth: x- y- Zone- 4
5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD:
Submit electronic information per 20 AAC 25.050 N/A (ft MSL)
22. Logs Obtained:
N/A
23.
BOTTOM
16" B 110'
7.625" L-80 2378'
5.5" L-80 3890'
3.5" L-80 5793'
24. Open to production or injection? Yes No 25.
26.
Was hydraulic fracturing used during completion? Yes No
DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED
27.
Date First Production: Method of Operation (Flowing, gas lift, etc.):
Hours Tested: Production for Gas-MCF:
Test Period
Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr):
Press. 24-Hour Rate
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
CASING, LINER AND CEMENTING RECORD
List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion,
(included above)6.75"
TUBING RECORD
47 bbl LiteCrete6.75"
4554' MD3-1/2"
CASING
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
ConocoPhillips Alaska, Inc.
WAG
Gas
10/7/2024 202-017/ 324-522
50-103-20407-00-00
KRU 2P-441
ADL0373112
989' FNL, 1719' FWL, Sec. 17, T8N, R7E, UM
382' FSL, 937' FWL, Sec. 17, T8N, R7E, UM
ALK4998
3/5/2002
7327' MD/ 5793' TVD
3846' MD / 3276' TVD
P.O. Box 100360, Anchorage, AK 99510-0360
443679 5868890
660' FSL, 917' FWL, Sec. 17, T8N, R7E, UM
9. Ref Elevations: KB: 27'
WT. PER
FT.GRADE
3/23/2002
CEMENTING RECORD
5865265
1360' MD/ 1353' TVD
SETTING DEPTH TVD
5864986
TOP HOLE SIZE AMOUNT
PULLED
442862
442881
TOP
SETTING DEPTH MD
suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log,
spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar
locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary.
N/A
BOTTOM
Kuparuk River Field/ Meltwater Oil Pool-
Suspended
N/A
4559' MD/ 3795' TVD
PACKER SET (MD/TVD)
42"
9.875"
422 sx AS I
31'300 sx AS IIIL, 135 sx LiteCrete
9.3#
31'
4559'
2594'31'
31'
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date perf'd or liner run):
15.5#
3846' (SW TOC)-4460' 21 bbls 15.8 ppg Class G cement
Water-Bbl:
PRODUCTION TEST
N/A
Date of Test: Oil-Bbl:
Flow Tubing
SUSPENDED
6950-6960' MD and 5520-5527' TVD (below cement plug)
Gas-Oil Ratio:Choke Size:
Per 20 AAC 25.283 (i)(2) attach electronic information
Sr Res EngSr Pet GeoSr Pet Eng
Oil-Bbl: Water-Bbl:
4696'
SIZE DEPTH SET (MD)
7325'
30'
3795'
62.5#
29.7#
110'
30'
Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment
By James Brooks at 2:40 pm, Oct 10, 2024
Suspended
107/2024
JSB
RBDMS JSB 101724
xGDSR-11/22/24
Conventional Core(s): Yes No Sidewall Cores:
N/A
30.
MD TVD
Surface Surface
1360' 1353'
Top of Productive Interval
N/A
31. List of Attachments: Schematics, Summary of Operations
32. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Contact Name: Katherine O'Connor
Digital Signature with Date:Contact Email: katherine.oconnor@conocophillips.com
Contact Phone:(907) 263-3718
Senior Well Interventions Engineer
General:
Item 1a:
Item 1b:
Item 4b:
Item 9:
Item 15:
Item 19:
Item 20:
Item 22:
Item 23:
Item 24:
Item 27:
Item 28:
Item 30:
Item 31:
Formation Name at TD:
If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if
needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired.
Yes No
Well tested? Yes No
28. CORE DATA
If Yes, list intervals and formations tested, briefly summarizing test results for
each. Attach separate pages if needed and submit detailed test info including
reports and Excel or ASCII tables per 20 AAC 25.071.
NAME
Permafrost - Top
Permafrost - Base
29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS
N/A- Suspended
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core
analysis, paleontological report, production or well test results, per 20 AAC 25.070.
Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each
segregated pool is a completion.
TPI (Top of Producing Interval).
Authorized Name and
Authorized Title:
N/A - Suspended
Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and
other tests as required including, but not limited to: core analysis, paleontological report, production or well test results.
Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29.
Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool.
If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the
producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,
showing the data pertinent to such interval).
Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit
detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity,
permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology.
Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain).
Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical
laboratory information required by 20 AAC 25.071.
Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion,
suspension, or abandonment; or 90 days after log acquisition, whichever occurs first.
Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345),
and/or Easement (ADL 123456) number.
The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements
given in other spaces on this form and in any attachments.
The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic
diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from
a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071.
INSTRUCTIONS
Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov
Digitally signed by Katherine O'ConnorDN: CN=Katherine O'Connor, O=ConocoPhillips, OU=Wells Group, E=katherine.oconnor@conocophillips.com, C=US
Reason: I am the author of this document
Location:
Date: 2024.10.10 09:31:36-08'00'
Foxit PDF Editor Version: 13.0.0
Katherine
O'Connor
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag: RKB 6,963.0 2P-441 6/21/2024 rogerba
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Pulled E-Line toolstring fish out 2P-441 10/8/2024 rogerba
Notes: General & Safety
Annotation End Date Last Mod By
NOTE: View Schematic w/ Alaska Schematic9.0 11/24/2010 ninam
NOTE: WAIVERED WELL: OA PRESSURE CHARGING FROM RESERVOIR 11/30/2004 WV5.3
Conversio
n
Casing Strings
Csg Des OD (in) ID (in) Top (ftKB)
Set Depth
(ftKB)
Set Depth
(TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread
CONDUCTOR 16 15.06 31.0 120.0 120.0 62.60 WELDED
SURFACE 7 5/8 6.87 30.9 2,593.8 2,377.6 29.70 L-80 BTCMOD
PRODUCTION 5 1/2 4.95 30.2 4,696.0 3,890.2 15.50 L-80 BTCMOD
LINER 3 1/2 2.99 4,559.2 7,325.0 5,793.2 9.30 L-80 BTCMOD
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
25.0
Set Depth …
4,553.8
Set Depth …
3,791.7
String Max No…
3 1/2
Tubing Description
TUBING
Wt (lb/ft)
9.30
Grade
l-80
Top Connection
EUE-8rdMOD
ID (in)
2.99
Completion Details: excludes tubing, pup, space out, thread, RKB...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal
ID (in)
25.0 25.0 0.00 HANGER 8.000 CT1A TUBING HANGER 3.500
514.8 514.8 0.48 NIPPLE 4.520 CAMCO DS NIPPLE CAMCO DS 2.875
2,082.7 1,998.7 35.03 GAS LIFT 4.425 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900
3,601.9 3,095.5 42.40 GAS LIFT 4.425 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900
4,429.0 3,704.9 45.21 GAS LIFT 4.425 CAMCO KBG-2-9 CAMCO KGB-2-9 2.900
4,478.8 3,739.8 45.78 SLEEVE-O 4.500 BAKER CMU SLIDING SLEEVE
w/DS PROFILE
BAKER CMU 2.813
4,494.8 3,750.9 45.97 NIPPLE 4.550 CAMCO D NIPPLE CAMCO D 2.750
4,539.1 3,781.6 46.31 PBR 4.500 BAKER POLISHED PBR BAKER 3.000
4,553.1 3,791.3 46.29 ANCHOR 4.500 BAKER K-22 ANCHOR - TUBING
SEAL DOWN
BAKER K-22 3.000
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top (ftKB)
Top (TVD)
(ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in)
2,840.0 2,551.9 45.49 CUT JET CUT @ 2840' RKB 10/7/2024 2.992
4,460.0 3,726.7 45.57 TUBING
PUNCH
3FT OF 2" TUBING PUNCH,
4SPF, 0 DEGREE PHASE
(PUMP 20 BBL DIESEL
THROUGH AT 2 BPM AND
150 PSI)
9/27/2024 2.992
6,919.3 5,497.3 42.75 CIBP CIBP MID-ELEMENT AT 6920'
RKB, OAL = 1.37'
6/29/2024 0.000
Mandrel Inserts : excludes pulled inserts
Top (ftKB)
Top (TVD)
(ftKB)
Top
Incl (°)
St
ati
on
No
/S Serv
Valve
Type
Latch
Type
OD
(in)
TRO Run
(psi) Run Date Com Make Model
Port
Size (in)
2,082.7 1,998.7 35.03 1 GAS LIFT Open 1 9/30/2024
3,601.9 3,095.5 42.40 2 GAS LIFT DMY INT 1 0.0 3/26/2002 0.000
4,429.0 3,704.9 45.21 3 GAS LIFT DMY INT 1 0.0 7/1/2024 0.000
Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal ID
(in)
4,559.2 3,795.5 46.29 PACKER 5.820 BAKER TIE-BACK SLEEVE ID
4.51", BAKER LINER TOP
PACKER ID 3.91"
BAKER FA 3.910
4,574.4 3,806.0 46.27 SBR 4.250 BAKER POLISHED BORE
RECEPTACLE
BAKER 2.992
7,227.1 5,721.0 42.67 Plug Catcher 3.500 2.992
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
6,950.0 6,960.0 5,519.8 5,527.1 BERMUDA, 2P-
441
3/30/2002 6.0 IPERF 2.5" Gun, 2506 HJ RDX, 60
deg phase
Stimulation Intervals
Top (ftKB) Btm (ftKB)
Inter
val
Num
ber Type Subtype Start Date
Proppant
Designed (lb)
Proppant
Total (lb)
Vol Clean
Total (bbl)
Vol Slurry
Total (bbl)
6,950.0 6,960.0 1 FRAC 4/1/2002 0.0 0.00 0.00
6,950.0 6,960.0 1 RE-FRAC 5/19/2004 0.0 0.00 0.00
Cement Squeezes
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Des Com
Pump Start
Date
6,848.0 6,919.3 5,444.5 5,497.3 Cement Plug DUMP BAILER CEMENT PLUG.
3,846.0 4,463.0 3,275.8 3,728.8 Cement Plug Cement Bal Plug - PUMPED 21 BBLS OF 15.8 PPG
CEMENT & DISPLACED CEMENT w/ 30 BBLS OF
9.8 PPG NaCl KWF.
9/28/2024
2P-441, 10/9/2024 2:18:50 PM
Vertical schematic (actual)
LINER; 4,559.2-7,325.0
IPERF; 6,950.0-6,960.0
FRAC; 6,950.0
RE-FRAC; 6,950.0
CIBP; 6,919.3
Cement Plug; 6,848.0 ftKB
PRODUCTION; 30.2-4,696.0
TUBING PUNCH; 4,460.0
GAS LIFT; 4,429.0
Cement Plug; 3,846.0 ftKB
GAS LIFT; 3,601.9
CUT; 2,840.0
SURFACE; 30.9-2,593.8
GAS LIFT; 2,082.7
NIPPLE; 514.8
CONDUCTOR; 31.0-120.0
KUP PROD
KB-Grd (ft)
35.10
RR Date
4/25/2002
Other Elev…
2P-441
...
TD
Act Btm (ftKB)
7,327.0
Well Attributes
Field Name
MELTWATER
Wellbore API/UWI
501032040700
Wellbore Status
PROD
Max Angle & MD
Incl (°)
48.60
MD (ftKB)
6,016.54
WELLNAME WELLBORE2P-441
Annotation
Last WO:
End DateH2S (ppm)
25
Date
12/6/2016
Comment
SSSV: NIPPLE
DTTMSTART JOBTYP SUMMARYOPS
9/27/2024 CHANGE
WELL TYPE
SHOT 2" TUBING PUNCHER FROM 4460'-4463'
LOG CORRELATED TO TUBING TALLY DATED 26-MAR-2002
CCL OFFSET=7.3', CCL STOP DEPTH=4452.7'
LRS CIRCULATED 20 BBLS DIESEL T X IA AT 2 BPM, 1000 PSI TO CONFIRM
GOOD CIRCULATION, U-TUBE TO ENSURE FREEZE PROTECT
9/28/2024 CHANGE
WELL TYPE
INTERMEDIATE CEMENT BALANCE PLUG.
LOAD TBG & IA WITH 9.8 PPG NaCl KWF. PUMPED 21 BBLS OF 15.8 PPG
CEMENT & DISPLACED CEMENT w/ 30 BBLS OF 9.8 PPG NaCl KWF. PLACING
TOC IN TBG & IA @ ~3460' MD. WAIT ~48 HRS & WILL BE READY FOR SL PULL
VALVE & FREEZE PROTECT. IN PROGRESS
9/30/2024 CHANGE
WELL TYPE
TAG TOC @ 3846' SLM. PULL DV FROM ST#1 @ 2082' RKB, LEAVING POCKET
OPEN. CIRCULATE 43 BBLS DIESEL FREEZE PROTECT T x IA, PERFORM
PASSING CMIT-TxIA TO 1800 PSI. READY FOR SW TAG/TEST.
10/5/2024 CHANGE
WELL TYPE
STATE WITNESS ( SULLEY ) TAG TOC 3846' SLM, GOOD SAMPLE. PERFORM
1500 PSI CMIT W/ PASSING RESULTS. READY FOR E-LINE.
10/7/2024 CHANGE
WELL TYPE
CUT TUBING AT 2840' RKB WITH 2.5" JET CUTTER
LOG CORRELATED TO TUBING TALLY DATED 3/26/2002
PULLED TOOLS OUT OF ROPE-SOCKET WHEN ATTEMPTING TO WORK
THROUGH NIPPLE @ 514'8' RKB (FISH LIH: 1.0" F.N., AOL = 18.5'). WELL LEFT
S/I
10/8/2024 CHANGE
WELL TYPE
FISHED E-LINE TOOLSTRING @ 497' RKB. READY FOR RIG
2P-441 Intermediate Suspend
Summary of Operations
ORIGINATED
TRANSMITTAL
DATE: 10/9/2024
ALASKA E-LINE SERVICES
TRANSMITTAL
#: 5106
42260 Kenai Spur Hwy
PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk River
PH: (907) 283-7374 FAX: (907) 283-7378
DELIVERABLE DESCRIPTION
TICKET # WELL # API #
LOG
DESCRIPTION
DATE OF
LOG
5106 2P-441 501032040700 Tubing Cut Record 7-Oct-2024
RECIPIENTS
ConocoPhillips Alaska, Inc.
DIGITAL FILES PRINTS CD'S
1 0 0 0 USPS
0
0 0
0
Received
By: Received By:
Signature Signature
AOGCC
DIGITAL FILES PRINTS CD'S
1 ShareFile 0 0 USPS
Attn: Natural Resources Technician II
abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision
aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501
Received
By: Received By:
Signature Signature
202-017
T39648
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2024.10.09 12:56:14 -08'00'
DNR
DIGITAL FILES PRINTS CD'S
1 SharePoint
Link 0 0 USPS
Attn: Natural Resource Tech II
DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501
Delivery Method: USPS
Received
By: Received By:
Signature Signature
Please return via e-mail a copy to both:
AR@ake-
line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com
ORIGINATED
TRANSMITTAL
DATE: 10/9/2024
ALASKA E-LINE SERVICES
TRANSMITTAL
#: 5085
42260 Kenai Spur Hwy
PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk River
PH: (907) 283-7374 FAX: (907) 283-7378
DELIVERABLE DESCRIPTION
TICKET # WELL # API #
LOG
DESCRIPTION
DATE OF
LOG
5085 2P-441 50103204070000 Tubing Puncher Record 27-Sep-2024
RECIPIENTS
ConocoPhillips Alaska, Inc.
DIGITAL FILES PRINTS CD'S
1 0 0 0 USPS
0
0 0
0
Received
By: Received By:
Signature Signature
AOGCC
DIGITAL FILES PRINTS CD'S
1 ShareFile 0 0 USPS
Attn: Natural Resources Technician II
abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision
aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501
Received
By: Received By:
Signature Signature
202-017
T39643
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2024.10.09 12:44:56 -08'00'
DNR
DIGITAL FILES PRINTS CD'S
1 SharePoint
Link 0 0 USPS
Attn: Natural Resource Tech II
DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501
Delivery Method: USPS
Received
By: Received By:
Signature Signature
Please return via e-mail a copy to both:
AR@ake-
line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Jim Regg DATE:
P.I. Supervisor
SUBJECT:
FROM:
Petroleum Inspector
Section: 17 Township: 8N Range: 7E Meridian: Umiat
Drilling Rig: N/A Rig Elevation: N/A Total Depth: 7,327 ft MD Lease No.: ADL0373112
Operator Rep: Suspend: X P&A:
Conductor: 16" O.D. Shoe@ 120 Feet Csg Cut@ Feet
Surface: 7 5/8" O.D. Shoe@ 2594 Feet Csg Cut@ Feet
Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet
Production: 5 1/2" O.D. Shoe@ 4696 Feet Csg Cut@ Feet
Liner: 3 1/2" O.D. Shoe@ 7325 Feet Csg Cut@ Feet
Tubing: 3 1/2" O.D. Tail@ 4,554 Feet Tbg Cut@ Feet
Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified
Fullbore Balanced 4,460 ft 3,046 ft 9.8 ppg Wireline tag
Initial 15 min 30 min 45 min Result
Tubing 1765 1705 1695
IA 1755 1710 1695
OA 331 309 296
Initial 15 min 30 min 45 min Result
Tubing
IA
OA
Remarks:
Attachments:
Sid Ferguson
Casing/Tubing Data (depths are MD):
Plugging Data (depths are MD):
Traveled to KRU 2P pad for plug tag and MIT-TxIA combo test of the intermediate balanced plug on 2P-441. Wire line tool was
28 ft long with 150lbs of weight bar and a flap bailer on the end. Initial tag was made at 3,046 ft MD and beat down several times
fir final tag at 3,046ft MD. The bailer returned a good cement sample. 0.5 bbl in and 0.5 bbl out during the MIT.
October 5, 2024
Sully Sullivan
Well Bore Plug & Abandonment
KRU 2P-441
ConocoPhillips Alaska LLC
PTD 2020170; Sundry 324-522
none
Test Data:
P
Casing Removal:
rev. 3-24-2022 2024-1005_Plug_Verification_KRU_2P-441_ss
9
9
9
99
9
9
9
9
9
9
9
9
9
99 9
9
9 9 9
9 9 9
9 9
9
9
James B. Regg Digitally signed by James B. Regg
Date: 2024.11.18 16:04:04 -09'00'
Operations shutdownRepair WellFracture StimulatePlug PerforationsAbandon1. Type of Request:
Change Approved ProgramPull TubingOther StimulatePerforateSuspend
Alter Casing Other: Suspend- Intermediate PlugPerforate New Pool Re-enter Susp WellPlug for Redrill
5. Permit to Drill Number:4. Current Well Class:2. Operator Name:
DevelopmentExploratory
3. Address:ServiceStratigraphic 6. API Number:
8. Well Name and Number:7. If perforating:
What Regulation or Conservation Order governs well spacing in this pool?
NoYes
10. Field:9. Property Designation (Lease Number):
11.
Junk (MD):Effective Depth TVD:Effective Depth MD:Total Depth TVD (ft):Total Depth MD (ft):
None7327'
CollapseCasing
Structural
Conductor
Surface
Intermediate
Production
Liner
Packers and SSSV MD (ft) and TVD (ft):Packers and SSSV Type:
13. Well Class after proposed work:12. Attachments: Proposal Summary Wellbore schematic
ServiceDevelopmentExploratory StratigraphicDetailed Operations Program BOP Sketch
15. Well Status after proposed work:14. Estimated Date for
WDSPLOIL WINJCommencing Operations:Suspended
SPLUGGSTORWAGGASDate:16. Verbal Approval:
AOGCC Representative: GINJ AbandonedOp Shutdown
Contact Name:
Contact Email:
Contact Phone:
Authorized Title:
Sundry Number:Conditions of approval: Notify AOGCC so that a representative may witness
Location ClearancePlug Integrity BOP Test Mechanical Integrity Test
Other Conditions of Approval:
Post Initial Injection MIT Req'd? NoYes
APPROVED BY
Date:THE AOGCCCOMMISSIONERApproved by:
Sr Res EngSr Pet GeoSr Pet EngComm.Comm.
(907) 263-3718
Well Interventions Engineer
KRU 2P-441
6848', 6919'366 psi6919'6848'5795'
N/A
Subsequent Form Required:
Suspension Expiration Date:
Will perfs require a spacing exception due to property boundaries?
Current Pools:
Plugs (MD):MPSP (psi):
17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval.
Authorized Name and
Digital Signature with Date:
Tubing Size:
katherine.oconnor@conocophillips.com
AOGCC USE ONLY
Tubing MD (ft):Tubing Grade:
4559' MD and 3796' TVD
N/A
Katherine O'Connor
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL0373112
202-017
P.O. Box 100360, Anchorage, AK 99510 50-103-20407-00-00
Kuparuk River Field Meltwater Oil Pool - Suspended
ConocoPhillips Alaska, Inc.
SizeLength
Proposed Pools:
PRESENT WELL CONDITION SUMMARY
Meltwater Oil Pool -
Suspended
BurstTVD
4554'
MD
110'
2378'
110'
2594'
3890'4696'
16"
7-5/8"
89'
2563'
6950-6960'
4666'
3-1/2"
5520-5527'
5-1/2"
Perforation Depth TVD (ft):
7325'2766'
3-1/2"
5793'
Packer: Baker Liner Top Packer
SSSV: None
Perforation Depth MD (ft):
L-80
Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
09/20/2024
By Grace Christianson at 12:30 pm, Sep 11, 2024
Digitally signed by Katherine O'Connor
DN: CN=Katherine O'Connor, O=
ConocoPhillips, OU=Wells Group, E=
katherine.oconnor@conocophillips.com, C=US
Reason: I am the author of this document
Location:
Date: 2024.09.11 07:08:43-08'00'
Foxit PDF Editor Version: 13.0.0
Katherine
O'Connor
June 30, 2025
A.Dewhurst 11SEP24
0
VTL 9/19/2024
10-407X
DSR-9/13/24
X
*&:
Jessie L.
Chmielowski
Digitally signed by Jessie L.
Chmielowski
Date: 2024.09.23 08:38:45 -08'00'09/23/24
RBDMS JSB 092324
2P-441 Suspension - Intermediate
Date: 9/5/24
Prepared by: Katherine O’Connor (214-684-7400)
Background & Objecve
2P-441 was a producer shut-in in late 2021. It has no known tubing or IA integrity issues. This well is
ultimately slated to be P&Ad as part of the 2P pad abandonment. 2P pad does not have any facilities or
surface line hookups, and the pad is slated to be used as storage for Willow development project in 2026.
This well will be suspended in 2023, and it is currently planned to be fully abandoned in 2024.
Well Data
Reservoir pressure 8/09/2020 = 906 psi at 5400’ TVD = 0.168 psi/ft
Last TD tag 6950’ KB in 2020 with BHP gauges in 2016.
Tubing leak found during suspension. LLR = 0.073 gpm @ 1700 psi.
Suspended with passing witnessed CMIT-TxIA to 1500 psi on 8/9/24
This will be a 1000 ft plug to give more breathing room for TOC & tubing cut
Procedure
Wireline & Pumping
1. Punch tubing at ±4460’ RKB
2. Pump the following schedule taking returns up the IA:
a. ±30 bbls surfactant wash
b.±100 bbls 9.8 brine
c. ±21 bbls cement
d. ±30 bbls 9.8 brine displacement
3. This should leave TOC in tubing and IA hydrostatically balanced with cement top at 3460’ MD
1. RIH and tag TOC and perform CMIT-TxIA to 1500 psi (AOGCC Witnessed)
Eline/Relay
4. Cut tubing at ±2840’ RKB
Top Bottom Size ID bbls/ft ft volume ft/bbl notes
3-1/2" tubing 0 4460 3.5" 9.3# 2.99" 0.0087 4460 38.7 115.1 from punch depth
3-1/2" x 5-1/2" Annulus 0 4460 3.5" 9.3# x 5.5" 15.5# 4.95" x 3.5" 0.0119 4460 53.1 84.0 from punch depth
Tubing Cement 3460 4460 3.5" 9.3# 2.99" 0.0087 1000 8.7 115.1
Annular Cement 3460 4460 3.5" 9.3# x 5.5" 15.5# 4.95" x 3.5" 0.0119 1000 11.9 84.0
Liner Cement:
31.3 bbls of 15.8# Class G Cement
Calculated TOC @ 4,559.2' KB
2P-441 Well Suspension Schematic
Conductor:
16" Conductor 120' KB
Production Casing Cement:
37 bbls of 15.8# Class G Cement
Calculated TOC @ 2,209' KB
1
2
3
5
Production Casing:
5 ½" 15.5# L-80 BTCMOD
Set @ 4,696’ KB
Bermuda Peforations:
@ 6,950' – 6,960' KB (10')
Surface Casing:
7-5/8", 29.7#, L-80 BTCMOD
Set @ 2,593.8' KB
Production Tubing:
3.5" 9.3# L-80 EUE-8rdMOD
Set @ 4,553.8' KB
7
Item Depth - tops
(KB)
1 CT1A TUBING HANGER 25'
2 CAMCO DS NIPPLE 514.8'
3 BAKER CMU SLIDING SLEEVE W DS
PROFILE 4,478.8'
4 CAMCO D NIPPLE 4,494.8'
5 BAKER POLISHED PBR 4,539.1'
6 BAKER K-22 ANCHOR - TUBING SEAL
DOWN 4,553.1'
7 BAKER TIE-BACK SLEEVE ID 4.51",
BAKER LINER TOP PACKER ID 3.91"4,559.2'
8 BAKER POLISHED BORE RECEPTACLE 4,574.4'
9 BAKER HMC LINER HANGER 4,579.40
10 BAKER 80-40 SEAL BORE EXTENSION 7,446.5'
11 CROSSOVER BUSHING 9,924.7'
6
8
4
9
10
11
Liner:
3.5" 9.3# L-80 BTCMOD
Set @ 7,325’ KB
C80 @ 2690' KB C80 @ 2690' KB
Plug #1 – Reservoir
TOC ±6848' RKB
Plug #2 – Intermediate
TOC ±3460
BOC ±4460
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag: RKB 6,963.0 2P-441 6/21/2024 rogerba
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Set DMY in Stn#1 2P-441 8/30/2024 fergusp
Notes: General & Safety
Annotation End Date Last Mod By
NOTE: View Schematic w/ Alaska Schematic9.0 11/24/2010 ninam
NOTE: WAIVERED WELL: OA PRESSURE CHARGING FROM RESERVOIR 11/30/2004 WV5.3
Conversio
n
Casing Strings
Csg Des OD (in) ID (in) Top (ftKB)
Set Depth
(ftKB)
Set Depth
(TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread
CONDUCTOR 16 15.06 31.0 120.0 120.0 62.60 WELDED
SURFACE 7 5/8 6.87 30.9 2,593.8 2,377.6 29.70 L-80 BTCMOD
PRODUCTION 5 1/2 4.95 30.2 4,696.0 3,890.2 15.50 L-80 BTCMOD
LINER 3 1/2 2.99 4,559.2 7,325.0 5,793.2 9.30 L-80 BTCMOD
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
25.0
Set Depth …
4,553.8
Set Depth …
3,791.7
String Max No…
3 1/2
Tubing Description
TUBING
Wt (lb/ft)
9.30
Grade
l-80
Top Connection
EUE-8rdMOD
ID (in)
2.99
Completion Details: excludes tubing, pup, space out, thread, RKB...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal
ID (in)
25.0 25.0 0.00 HANGER 8.000 CT1A TUBING HANGER 3.500
514.8 514.8 0.48 NIPPLE 4.520 CAMCO DS NIPPLE CAMCO DS 2.875
2,082.7 1,998.7 35.03 GAS LIFT 4.425 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900
3,601.9 3,095.5 42.40 GAS LIFT 4.425 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900
4,429.0 3,704.9 45.21 GAS LIFT 4.425 CAMCO KBG-2-9 CAMCO KGB-2-9 2.900
4,478.8 3,739.8 45.78 SLEEVE-O 4.500 BAKER CMU SLIDING SLEEVE
w/DS PROFILE
BAKER CMU 2.813
4,494.8 3,750.9 45.97 NIPPLE 4.550 CAMCO D NIPPLE CAMCO D 2.750
4,539.1 3,781.6 46.31 PBR 4.500 BAKER POLISHED PBR BAKER 3.000
4,553.1 3,791.3 46.29 ANCHOR 4.500 BAKER K-22 ANCHOR - TUBING
SEAL DOWN
BAKER K-22 3.000
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top (ftKB)
Top (TVD)
(ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in)
6,919.3 5,497.3 42.75 CIBP CIBP MID-ELEMENT AT 6920'
RKB, OAL = 1.37'
6/29/2024 0.000
Mandrel Inserts : excludes pulled inserts
Top (ftKB)
Top (TVD)
(ftKB)
Top
Incl (°)
St
ati
on
No
/S Serv
Valve
Type
Latch
Type
OD
(in)
TRO Run
(psi) Run Date Com Make Model
Port
Size (in)
2,082.7 1,998.7 35.03 1 GAS LIFT DMY INT 1 0.0 8/30/2024 0.000
3,601.9 3,095.5 42.40 2 GAS LIFT DMY INT 1 0.0 3/26/2002 0.000
4,429.0 3,704.9 45.21 3 GAS LIFT DMY INT 1 0.0 7/1/2024 0.000
Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal ID
(in)
4,559.2 3,795.5 46.29 PACKER 5.820 BAKER TIE-BACK SLEEVE ID
4.51", BAKER LINER TOP
PACKER ID 3.91"
BAKER FA 3.910
4,574.4 3,806.0 46.27 SBR 4.250 BAKER POLISHED BORE
RECEPTACLE
BAKER 2.992
7,227.1 5,721.0 42.67 Plug Catcher 3.500 2.992
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
6,950.0 6,960.0 5,519.8 5,527.1 BERMUDA, 2P-
441
3/30/2002 6.0 IPERF 2.5" Gun, 2506 HJ RDX, 60
deg phase
Stimulation Intervals
Top (ftKB) Btm (ftKB)
Inter
val
Num
ber Type Subtype Start Date
Proppant
Designed (lb)
Proppant
Total (lb)
Vol Clean
Total (bbl)
Vol Slurry
Total (bbl)
6,950.0 6,960.0 1 FRAC 4/1/2002 0.0 0.00 0.00
6,950.0 6,960.0 1 RE-FRAC 5/19/2004 0.0 0.00 0.00
Cement Squeezes
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Des Com
Pump Start
Date
6,848.0 6,919.3 5,444.5 5,497.3 Cement Plug DUMP BAILER CEMENT PLUG.
2P-441, 9/10/2024 5:41:57 PM
Vertical schematic (actual)
LINER; 4,559.2-7,325.0
FRAC; 6,950.0
IPERF; 6,950.0-6,960.0
RE-FRAC; 6,950.0
CIBP; 6,919.3
Cement Plug; 6,848.0 ftKB
PRODUCTION; 30.2-4,696.0
FLOAT SHOE; 4,694.6-4,696.0
FLOAT COLLAR; 4,609.5-
4,610.8
ANCHOR; 4,553.1
PBR; 4,539.1
NIPPLE; 4,494.8
SLEEVE-O; 4,478.8
GAS LIFT; 4,429.0
GAS LIFT; 3,601.9
SURFACE; 30.9-2,593.8
FLOAT SHOE; 2,592.3-2,593.8
FLOAT COLLAR; 2,506.3-
2,507.6
GAS LIFT; 2,082.7
PORT COLLAR; 1,033.9-
1,036.3
NIPPLE; 514.8
CONDUCTOR; 31.0-120.0
HANGER; 30.9-33.4
HANGER; 30.2-33.1
HANGER; 25.0
KUP PROD
KB-Grd (ft)
35.10
RR Date
4/25/2002
Other Elev…
2P-441
...
TD
Act Btm (ftKB)
7,327.0
Well Attributes
Field Name
MELTWATER
Wellbore API/UWI
501032040700
Wellbore Status
PROD
Max Angle & MD
Incl (°)
48.60
MD (ftKB)
6,016.54
WELLNAME WELLBORE2P-441
Annotation
Last WO:
End DateH2S (ppm)
25
Date
12/6/2016
Comment
SSSV: NIPPLE
1
Christianson, Grace K (OGC)
From:O'Connor, Katherine <Katherine.OConnor@conocophillips.com>
Sent:Friday, September 13, 2024 1:59 PM
To:Loepp, Victoria T (OGC)
Subject:RE: [EXTERNAL]KRU 2P-441(PTD 202-017, 324-522) Intermediate Plug
The witnessed tag was on 7/12/24 but their Įrst pressure test failed. They did an MIT-T and that's when they found the
tubing leak. So they rigged down, pulled a valve so we could do a combo, and came back with an inspector on 8/9/24.
That's when the referenced CMIT-TxIA witnessed test passed.
Not sure which date is correct to put on the form but can change it if needed.
-----Original Message-----
From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>
Sent: Friday, September 13, 2024 1:53 PM
To: O'Connor, Katherine <Katherine.OConnor@conocophillips.com>
Subject: RE: [EXTERNAL]KRU 2P-441(PTD 202-017, 324-522) Intermediate Plug
The SW tag was on 7/12/2024 according to the 10-407. Both a SW tag and PT are required.
-----Original Message-----
From: O'Connor, Katherine <Katherine.OConnor@conocophillips.com>
Sent: Friday, September 13, 2024 1:47 PM
To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>
Cc: Roby, David S (OGC) <dave.roby@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Subject: RE: [EXTERNAL]KRU 2P-441(PTD 202-017, 324-522) Intermediate Plug
CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open a Ʃachments
unless you recognize the sender and know the content is safe.
Hi Victoria,
MPSP is a mistake, it is zero. Likely a follow over from the original sundry. And the SW test was on 8/9/24 and passed to
1500 psi, it is in the well notes secƟon of my procedure. Let me know if you need further detail, though.
Thanks!
Katherine
Katherine O'Connor
CPF2 IntervenƟons Engineer
907-263-3718 (O)
214-684-7400 (C)
-----Original Message-----
From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>
Sent: Friday, September 13, 2024 1:38 PM
To: O'Connor, Katherine <Katherine.OConnor@conocophillips.com>
2
Cc: Roby, David S (OGC) <dave.roby@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>
Subject: [EXTERNAL]KRU 2P-441(PTD 202-017, 324-522) Intermediate Plug
CAUTION:This email originated from outside of the organizaƟon. Do not click links or open aƩachments unless you
recognize the sender and know the content is safe.
Katherine,
Please include the date and result of the state witnessed tag. Why is the MPSP 366 psig and not 0 psig?
Victoria
Victoria Loepp
Senior Petroleum Engineer
Alaska Oil & Gas ConservaƟon Commission
Work: (907)793-1247
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Jim Regg DATE:
P.I. Supervisor
SUBJECT:
FROM:
Petroleum Inspector
Section: 17 Township: 8N Range: 7E Meridian: Umiat
Drilling Rig: N/A Rig Elevation: N/A Total Depth: 7,327 ft MD Lease No.: ADL0373112
Operator Rep: Suspend: X P&A:
Conductor: 16" O.D. Shoe@ 120 Feet Csg Cut@ Feet
Surface: 7-5/8" O.D. Shoe@ 2,594 Feet Csg Cut@ Feet
Intermediate: N/A O.D. Shoe@ N/A Feet Csg Cut@ Feet
Production: 5-1/2" O.D. Shoe@ 4,696 Feet Csg Cut@ Feet
Liner: 3-1/2" O.D. Shoe@ 7325 Feet Csg Cut@ Feet
Tubing: 3-1/2" O.D. Tail@ 4,554 Feet Tbg Cut@ Feet
Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified
Tubing Bridge plug 6,919 ft 6,830 ft 9.6 ppg KWF Wireline tag
Initial 15 min 30 min 45 min Result
Tubing 1750 1410
IA 200 350
OA 253 262
Initial 15 min 30 min 45 min Result
Tubing 1750 1620 1540 1470
IA 420 500 550 610
OA 265 267 267 267
Remarks:
Attachments:
Traveled to KRU 2P pad for multiple P&A's. This is the initial witnessed Tag and MIT-T of the 1st cmt plug for 2P-441. Upon
arival I met with Conoco rep Sid Ferguson, Little Red Services (LRS) operators and wireline crew to go over the plan for the
day. They began with a wireline tag with bailer and 150 lbs weight bar. A solid tag was made at 6,830 ft MD and returned a cmt
sample that was grey in color and sample was semi hard and crumbly. E-line rigged down and started rigging up on the next
well while LRS rigged up for the MIT-T. MIT was performed with immediate losses, failing after 12 min. A second MIT was
performed that indicated losses to the IA. MIT run out to 45 min for data collection (also a Fail). Data was recorded and we
moved to the next well.
July 12, 2024
Sully Sullivan
Well Bore Plug & Abandonment
KRU 2P-441
ConocoPhillips Alaska Inc.
PTD #2020170; Sundry 323-548
none
Test Data:
F
Casing Removal:
Sid Ferguson
F
Casing/Tubing Data (depths are MD):
Plugging Data (depths are MD):
rev. 3-24-2022 2024-0712_Plug_Verification_KRU_2P-441_ss
9
9
9 9 9 9
99
9
9
9
9
9
9
9 9 9
99
9
9 9 9 9
9 9
9 9
9
9
9
9
ygg
MIT was performed with immediate losses
gg
second MIT wasgg
performed that indicated losses to the IA
g
also a Fail
James B. Regg Digitally signed by James B. Regg
Date: 2024.08.21 11:02:37 -08'00'
1a. Well Status:Oil SPLUG Other Abandoned Suspended
1b. Well Class:
20AAC 25.105 20AAC 25.110 Development Exploratory
GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test
2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry:
Aband.:
3. Address: 7. Date Spudded: 15. API Number:
4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number:
Surface:
Top of Productive Interval:17. Field / Pool(s):
GL: BF:
Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation:
4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number:
Surface: x- y- Zone- 4
TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD:
Total Depth: x- y- Zone- 4
5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD:
Submit electronic information per 20 AAC 25.050 N/A (ft MSL)
22. Logs Obtained:
N/A
23.
BOTTOM
16" B 110'
7.625" L-80 2378'
5.5" L-80 3890'
3.5" L-80 5793'
24. Open to production or injection? Yes No 25.
26.
Was hydraulic fracturing used during completion? Yes No
DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED
27.
Date First Production: Method of Operation (Flowing, gas lift, etc.):
Hours Tested: Production for Gas-MCF:
Test Period
Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr):
Press. 24-Hour Rate
4696'
SIZE DEPTH SET (MD)
7325'
30'
3795'
62.5#
29.7#
110'
30'
Sr Res EngSr Pet GeoSr Pet Eng
Oil-Bbl: Water-Bbl:
5432' (SW TOC)-5499' ~0.26 bbls 15.8 ppg Class G cement
Water-Bbl:
PRODUCTION TEST
N/A
Date of Test: Oil-Bbl:
Flow Tubing
SUSPENDED
6950-6960' MD and 5520-5527' TVD (below cement plug)
Gas-Oil Ratio:Choke Size:
Per 20 AAC 25.283 (i)(2) attach electronic information
4559' MD/ 3795' TVD
PACKER SET (MD/TVD)
42"
9.875"
422 sx AS I
31'300 sx AS IIIL, 135 sx LiteCrete
9.3#
31'
4559'
2594'31'
31'
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date perf'd or liner run):
15.5#
WT. PER
FT.GRADE
3/23/2002
CEMENTING RECORD
5865265
1360' MD/ 1353' TVD
SETTING DEPTH TVD
5864986
TOP HOLE SIZE AMOUNT
PULLED
442862
442881
TOP
SETTING DEPTH MD
suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log,
spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar
locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary.
N/A
BOTTOM
Kuparuk River Field/ Meltwater Oil Pool-
Suspended
N/A
50-103-20407-00-00
KRU 2P-441
ADL0373112
989' FNL, 1719' FWL, Sec. 17, T8N, R7E, UM
382' FSL, 937' FWL, Sec. 17, T8N, R7E, UM
ALK4998
3/5/2002
7327' MD/ 5793' TVD
5432' MD / 5237' TVD
P.O. Box 100360, Anchorage, AK 99510-0360
443679 5868890
660' FSL, 917' FWL, Sec. 17, T8N, R7E, UM
9. Ref Elevations: KB: 27'
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
ConocoPhillips Alaska, Inc.
WAG
Gas
7/12/2024 202-017/ 323-548
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
CASING, LINER AND CEMENTING RECORD
List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion,
(included above)6.75"
TUBING RECORD
47 bbl LiteCrete6.75"
4554' MD3-1/2"
CASING
Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment
By James Brooks at 9:19 am, Aug 14, 2024
Suspended
7/12/2024
JSB
RBDMS JSB 081624
xGDSR-8/27/24
Conventional Core(s): Yes No Sidewall Cores:
N/A
30.
MD TVD
Surface Surface
1360' 1353'
Top of Productive Interval
N/A
31. List of Attachments: Schematics, Summary of Operations
32. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Contact Name: Katherine O'Connor
Digital Signature with Date:Contact Email: katherine.oconnor@conocophillips.com
Contact Phone:(907) 263-3718
Senior Well Interventions Engineer
General:
Item 1a:
Item 1b:
Item 4b:
Item 9:
Item 15:
Item 19:
Item 20:
Item 22:
Item 23:
Item 24:
Item 27:
Item 28:
Item 30:
Item 31:
N/A - Suspended
Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and
other tests as required including, but not limited to: core analysis, paleontological report, production or well test results.
Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29.
Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool.
If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the
producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,
showing the data pertinent to such interval).
Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit
detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity,
permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology.
Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain).
Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical
laboratory information required by 20 AAC 25.071.
Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion,
suspension, or abandonment; or 90 days after log acquisition, whichever occurs first.
Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345),
and/or Easement (ADL 123456) number.
The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements
given in other spaces on this form and in any attachments.
The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic
diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from
a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071.
INSTRUCTIONS
Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core
analysis, paleontological report, production or well test results, per 20 AAC 25.070.
Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each
segregated pool is a completion.
TPI (Top of Producing Interval).
Authorized Name and
Authorized Title:
Formation Name at TD:
If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if
needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired.
Yes No
Well tested? Yes No
28. CORE DATA
If Yes, list intervals and formations tested, briefly summarizing test results for
each. Attach separate pages if needed and submit detailed test info including
reports and Excel or ASCII tables per 20 AAC 25.071.
NAME
Permafrost - Top
Permafrost - Base
29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS
N/A- Suspended
Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov
Digitally signed by Katherine O'Connor
DN: CN=Katherine O'Connor, O=ConocoPhillips, OU=
Wells Group, E=katherine.oconnor@
conocophillips.com, C=US
Reason: I am the author of this document
Location:
Date: 2024.08.13 14:53:00-08'00'Foxit PDF Editor Version: 13.0.0
Katherine
O'Connor
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag: RKB 6,963.0 2P-441 6/21/2024 rogerba
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Noted DB Cement 2P-441 7/2/2024 fergusp
Notes: General & Safety
Annotation End Date Last Mod By
NOTE: View Schematic w/ Alaska Schematic9.0 11/24/2010 ninam
NOTE: WAIVERED WELL: OA PRESSURE CHARGING FROM RESERVOIR 11/30/2004 WV5.3
Conversio
n
Casing Strings
Csg Des OD (in) ID (in) Top (ftKB)
Set Depth
(ftKB)
Set Depth
(TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread
CONDUCTOR 16 15.06 31.0 120.0 120.0 62.60 WELDED
SURFACE 7 5/8 6.87 30.9 2,593.8 2,377.6 29.70 L-80 BTCMOD
PRODUCTION 5 1/2 4.95 30.2 4,696.0 3,890.2 15.50 L-80 BTCMOD
LINER 3 1/2 2.99 4,559.2 7,325.0 5,793.2 9.30 L-80 BTCMOD
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
25.0
Set Depth …
4,553.8
Set Depth …
3,791.7
String Max No…
3 1/2
Tubing Description
TUBING
Wt (lb/ft)
9.30
Grade
l-80
Top Connection
EUE-8rdMOD
ID (in)
2.99
Completion Details: excludes tubing, pup, space out, thread, RKB...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal
ID (in)
25.0 25.0 0.00 HANGER 8.000 CT1A TUBING HANGER 3.500
514.8 514.8 0.48 NIPPLE 4.520 CAMCO DS NIPPLE CAMCO DS 2.875
2,082.7 1,998.7 35.03 GAS LIFT 4.425 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900
3,601.9 3,095.5 42.40 GAS LIFT 4.425 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900
4,429.0 3,704.9 45.21 GAS LIFT 4.425 CAMCO KBG-2-9 CAMCO KGB-2-9 2.900
4,478.8 3,739.8 45.78 SLEEVE-O 4.500 BAKER CMU SLIDING SLEEVE
w/DS PROFILE
BAKER CMU 2.813
4,494.8 3,750.9 45.97 NIPPLE 4.550 CAMCO D NIPPLE CAMCO D 2.750
4,539.1 3,781.6 46.31 PBR 4.500 BAKER POLISHED PBR BAKER 3.000
4,553.1 3,791.3 46.29 ANCHOR 4.500 BAKER K-22 ANCHOR - TUBING
SEAL DOWN
BAKER K-22 3.000
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top (ftKB)
Top (TVD)
(ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in)
6,919.3 5,497.3 42.75 CIBP CIBP MID-ELEMENT AT 6920'
RKB, OAL = 1.37'
6/29/2024 0.000
Mandrel Inserts : excludes pulled inserts
Top (ftKB)
Top (TVD)
(ftKB)
Top
Incl (°)
St
ati
on
No
/S Serv
Valve
Type
Latch
Type
OD
(in)
TRO Run
(psi) Run Date Com Make Model
Port
Size (in)
2,082.7 1,998.7 35.03 1 GAS LIFT DMY INT 1 0.0 10/18/2002 0.000
3,601.9 3,095.5 42.40 2 GAS LIFT DMY INT 1 0.0 3/26/2002 0.000
4,429.0 3,704.9 45.21 3 GAS LIFT DMY INT 1 0.0 7/1/2024 0.000
Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°) Item Des
OD
Nominal
(in)Com Make Model
Nominal ID
(in)
4,559.2 3,795.5 46.29 PACKER 5.820 BAKER TIE-BACK SLEEVE ID
4.51", BAKER LINER TOP
PACKER ID 3.91"
BAKER FA 3.910
4,574.4 3,806.0 46.27 SBR 4.250 BAKER POLISHED BORE
RECEPTACLE
BAKER 2.992
7,227.1 5,721.0 42.67 Plug Catcher 3.500 2.992
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
6,950.0 6,960.0 5,519.8 5,527.1 BERMUDA, 2P-
441
3/30/2002 6.0 IPERF 2.5" Gun, 2506 HJ RDX, 60
deg phase
Stimulation Intervals
Top (ftKB) Btm (ftKB)
Inter
val
Num
ber Type Subtype Start Date
Proppant
Designed (lb)
Proppant
Total (lb)
Vol Clean
Total (bbl)
Vol Slurry
Total (bbl)
6,950.0 6,960.0 1 FRAC 4/1/2002 0.0 0.00 0.00
6,950.0 6,960.0 1 RE-FRAC 5/19/2004 0.0 0.00 0.00
Cement Squeezes
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Des Com
Pump Start
Date
6,848.0 6,919.3 5,444.5 5,497.3 Cement Plug DUMP BAILER CEMENT PLUG.
2P-441, 7/16/2024 4:41:37 PM
Vertical schematic (actual)
LINER; 4,559.2-7,325.0
IPERF; 6,950.0-6,960.0
FRAC; 6,950.0
RE-FRAC; 6,950.0
CIBP; 6,919.3
Cement Plug; 6,848.0 ftKB
PRODUCTION; 30.2-4,696.0
GAS LIFT; 4,429.0
GAS LIFT; 3,601.9
SURFACE; 30.9-2,593.8
GAS LIFT; 2,082.7
NIPPLE; 514.8
CONDUCTOR; 31.0-120.0
KUP PROD
KB-Grd (ft)
35.10
RR Date
4/25/2002
Other Elev…
2P-441
...
TD
Act Btm (ftKB)
7,327.0
Well Attributes
Field Name
MELTWATER
Wellbore API/UWI
501032040700
Wellbore Status
PROD
Max Angle & MD
Incl (°)
48.60
MD (ftKB)
6,016.54
WELLNAME WELLBORE2P-441
Annotation
Last WO:
End DateH2S (ppm)
25
Date
12/6/2016
Comment
SSSV: NIPPLE
DTTMSTART JOBTYP SUMMARYOPS
6/21/2024 CHANGE
WELL TYPE
ATTEMPTED CMIT TXIA FAILED, APPEARS PLUG IS NO LONGER HOLDING.
WILL PERFORM CMIT TXIA ONCE CIBP IS SET. PULLED 2.75" CA-2 PLUG
FROM 4494' RKB, DRIFTED TBG W/ 2.69" DMY CIBP DRIFT TO 6963' RKB, NO
TIGHT SPOTS OR WEIGHT SWINGS ENCOUNTERED. WELL READY FOR E-
LINE. IN PROGRESS.
6/29/2024 CHANGE
WELL TYPE
LOAD IA W/ 40 BBLS CISW AND 24 BBLS DIESEL, LOAD TUBING W/ 50 BBLS
CISW AND 18 BBLS DIESEL. SET CIBP MID-ELEMENT AT 6920'. PUMP AN
ADDITIONAL 80 BBLS DIESEL TO PRESSURE UP TO 1500 PSI FOR CMIT-TXIA
(PASS).
JOB COMPLETE, READY FOR SL
6/30/2024 CHANGE
WELL TYPE
DRIFT & TAG CIBP @ 6919' RKB, LDFN. JOB IN PROGRESS
7/1/2024 CHANGE
WELL TYPE
SET 1'' BTM INT DMY VLV IN ST#3 @ 4429' RKB. PERFORM PASSING MIT-T TO
1500 PSI. DUMP BAIL CEMENT ON TOP OF CIBP @ 6919' RKB. JOB IN
PROGRESS.
7/2/2024 CHANGE
WELL TYPE
DUMP BAIL CEMENT ON TOP OF CIBP @ 6919' RKB. READY FOR SW TOC
TAG & TEST IN 72 HOURS.
7/12/2024 CHANGE
WELL TYPE
STATE WITNESS (SEAN SULLIVAN) TAG TOC @ 6848' RKB. MIT-T TO 1500
PSI FAILED. NEED PLAN FORWARD.
7/28/2024 CHANGE
WELL TYPE
SET SLIPSTOP CATCHER @ 2207' RKB, PULL DMY VLV IN ST#1 @ 2082' RKB,
PULL SLIPSTOP CATCHER @ 2207' RKB, OBTAIN PASSING CMIT TxIA TO 1700
PSI, RDMO.
8/9/2024 CHANGE
WELL TYPE
STATE WITNESSED (AUSTIN McLEOD )CMIT PASSED @ 1500 PSI. READY
FOR NEXT P&A STEPS.
2P-441 Suspend
Summary of Operations
ORIGINATED
TRANSMITTAL
DATE: 7/1/2024
ALASKA E-LINE SERVICES
TRANSMITTAL
#: 4901
42260 Kenai Spur Hwy
PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk
PH: (907) 283-7374 FAX: (907) 283-7378
DELIVERABLE DESCRIPTION
TICKET # WELL # API #
LOG
DESCRIPTION
DATE OF
LOG
4901 2P-441 50103204070000 Plug Setting Record 29-Jun-2024
RECIPIENTS
Conoco
DIGITAL FILES PRINTS CD'S
1 FTP Transfer 0 0 USPS
Attn: NSK-69
tom.osterkamp@conocophillips.com 700 G Street
Anchorage, AK 99503
Received
By: Received By:
Signature Signature
AOGCC
DIGITAL FILES PRINTS CD'S
1 SharePoint
Link 0 0 USPS
Attn: Natural Resources Technician II
abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision
333 W. 7th Ave, Suite 100 - Anchorage, AK 99501
Received
By: Received By:
Signature Signature
202-017
T39098
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2024.07.01 11:43:09 -08'00'
DNR
DIGITAL FILES PRINTS CD'S
1 SharePoint
Link 0 0 USPS
Attn: Natural Resource Tech II
DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501
Delivery Method: USPS
Received
By: Received By:
Signature Signature
Please return via e-mail a copy to both:
AR@ake-
line.com tom.osterkamp@conocophillips.com
1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown
Suspend Perforate Other Stimulate Pull Tubing Change Approved Program
Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________
2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number:
Exploratory Development
3. Address:Stratigraphic Service
6. API Number:
7. If perforating:8. Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool?
Yes No
9. Property Designation (Lease Number): 10. Field:
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD):
7327'None
Casing Collapse
Structural
Conductor
Surface
Intermediate
Production
Liner
Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft):
12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work:
Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service
14. Estimated Date for 15. Well Status after proposed work:
Commencing Operations: OIL WINJ WDSPL Suspended
16. Verbal Approval: Date: GAS WAG GSTOR SPLUG
AOGCC Representative: GINJ Op Shutdown Abandoned
Contact Name:
Contact Email:
Contact Phone:
Authorized Title:
Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number:
Plug Integrity BOP Test Mechanical Integrity Test Location Clearance
Other Conditions of Approval:
Post Initial Injection MIT Req'd? Yes No
APPROVED BY
Approved by: COMMISSIONER THE AOGCC Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
(907) 263-3718
Well Interventions Engineer
KRU 2P-441
5795' 4495' 3751' 366 psi 4495'
N/A
Subsequent Form Required:
Suspension Expiration Date:
Will perfs require a spacing exception due to property boundaries?
Current Pools:
MPSP (psi): Plugs (MD):
17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval.
Authorized Name and
Digital Signature with Date:
Tubing Size:
katherine.oconnor@conocophillips.com
AOGCC USE ONLY
Tubing Grade: Tubing MD (ft):
4559' MD and 3796' TVD
N/A
Katherine O'Connor
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL0373112
202-017
P.O. Box 100360, Anchorage, AK 99510 50-103-20407-00-00
Kuparuk River Field Meltwater Oil Pool
ConocoPhillips Alaska, Inc.
Length Size
Proposed Pools:
PRESENT WELL CONDITION SUMMARY
Meltwater Oil Pool -
Suspended
TVD Burst
4554'
MD
120'
2378'
120'
2594'
3890'4696'
16"
7-5/8"
89'
2563'
6950-6960'
4666'
3-1/2"
5520-5527'
5-1/2"
Perforation Depth TVD (ft):
11/20/2023
4559'2766'
3-1/2"
7325'
Packer: Baker Liner Top Packer
SSSV: None
Perforation Depth MD (ft):
L-80
Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
By Grace Christianson at 9:15 am, Oct 05, 2023
Digitally signed by Katherine O'Connor
DN: CN=Katherine O'Connor, O=ConocoPhillips, OU
=Wells Group, E=katherine.oconnor@
conocophillips.com, C=US
Reason: I am the author of this document
Location:
Date: 2023.10.04 10:56:37-08'00'
Foxit PDF Editor Version: 12.1.2
Katherine
O'Connor
323-548
VTL 11/14/2023
*110' MD on initial Well Completion Report filed 4/19/2002 SFD
SFD 10/6/2023
*
DSR-10/5/23
7325'
December 31, 2024
X
*
5793'
10-407X
SFD
*&:JLC 11/15/2023
Brett W. Huber,
Sr.
Digitally signed by Brett W.
Huber, Sr.
Date: 2023.11.15 14:29:17 -09'00'11/15/23
RBDMS JSB 111623
2P-441 Suspension
Date Wrien: 9-21-23
Execuon Date: Nov 20, 2023
Prepared by: Katherine O’Connor (214-684-7400)
Background & Objecve
2P-441 was a producer shut-in in late 2021. It has no known tubing or IA integrity issues. This well is
ultimately slated to be P&Ad as part of the 2P pad abandonment. 2P pad does not have any facilities or
surface line hookups, and the pad is slated to be used as storage for Willow development project in 2026.
This well will be suspended in 2023, and it is currently planned to be fully abandoned in 2024.
Well Data
Reservoir pressure 8/09/2020 = 906 psi at 5400’ TVD
MASP = 366 psi
Last TD tag 6950’ KB in 2020 with BHP gauges in 2016.
Well has history of parrafin
Procedure
Wireline & Pumping
1. Drift with dummy CIBP to TD. If unable to get within 50’ of perforations, contact Katherine
O’Connor
2. Fluid pack tubing with KWF and freeze protect
3. Set CIBP @ ±6,920’ RKB (must be set within 50’ of the top of perforations).
4. Perform MIT-T to 1500 psi, record results
5. Dump bail at least 30’ of cement on top of CIBP
6. Allow 72 hours for cement to harden, notify AOGCC at least 24 hours in advance
7. RIH and tag TOC, approx. 6,890’ RKB (MUST BE AOGCC WITNESSED)
8. RU LRS as necessary. Perform pressure test to 1500 psi (MUST BE AOGCC WITNESSED)
9. Perform DDT and record results
DHD
1. Schedule wellsite inspection within 12 months of suspension approval
* 110' MD on initial Well Completion
Report filed 4/19/2002 SFD
**
Liner Cement:
31.3 bbls of 15.8# Class G Cement
Calculated TOC @ 4,559.2' KB
2P-441 Well Schematic
Conductor:
16" Conductor 120' KB
Production Casing Cement:
37 bbls of 15.8# Class G Cement
Calculated TOC @ 2,209' KB
1
2
3
5
Production Casing:
5 ½" 15.5# L-80 BTCMOD
Set @ 4,696’ KB
Bermuda Peforations:
@ 6,950' – 6,960' KB (10')
Surface Casing:
7-5/8", 29.7#, L-80 BTCMOD
Set @ 2,593.8' KB
Production Tubing:
3.5" 9.3# L-80 EUE-8rdMOD
Set @ 4,553.8' KB
7
Item Depth - tops
(KB)
1 CT1A TUBING HANGER 25'
2 CAMCO DS NIPPLE 514.8'
3 BAKER CMU SLIDING SLEEVE W DS
PROFILE 4,478.8'
4 CAMCO D NIPPLE 4,494.8'
5 BAKER POLISHED PBR 4,539.1'
6 BAKER K-22 ANCHOR - TUBING SEAL
DOWN 4,553.1'
7 BAKER TIE-BACK SLEEVE ID 4.51",
BAKER LINER TOP PACKER ID 3.91"4,559.2'
8 BAKER POLISHED BORE RECEPTACLE 4,574.4'
9 BAKER HMC LINER HANGER 4,579.40
10 BAKER 80-40 SEAL BORE EXTENSION 7,446.5'
11 CROSSOVER BUSHING 9,924.7'
6
8
4
9
10
11
Liner:
3.5" 9.3# L-80 BTCMOD
Set @ 7,325’ KB
C80 @ 2690' KB C80 @ 2690' KB
Liner Cement:
31.3 bbls of 15.8# Class G Cement
Calculated TOC @ 4,559.2' KB
2P-441 Well Suspension Schematic
Conductor:
16" Conductor 120' KB
Production Casing Cement:
37 bbls of 15.8# Class G Cement
Calculated TOC @ 2,209' KB
1
2
3
5
Production Casing:
5 ½" 15.5# L-80 BTCMOD
Set @ 4,696’ KB
Bermuda Peforations:
@ 6,950' – 6,960' KB (10')
Surface Casing:
7-5/8", 29.7#, L-80 BTCMOD
Set @ 2,593.8' KB
Production Tubing:
3.5" 9.3# L-80 EUE-8rdMOD
Set @ 4,553.8' KB
7
Item Depth - tops
(KB)
1 CT1A TUBING HANGER 25'
2 CAMCO DS NIPPLE 514.8'
3 BAKER CMU SLIDING SLEEVE W DS
PROFILE 4,478.8'
4 CAMCO D NIPPLE 4,494.8'
5 BAKER POLISHED PBR 4,539.1'
6 BAKER K-22 ANCHOR - TUBING SEAL
DOWN 4,553.1'
7 BAKER TIE-BACK SLEEVE ID 4.51",
BAKER LINER TOP PACKER ID 3.91"4,559.2'
8 BAKER POLISHED BORE RECEPTACLE 4,574.4'
9 BAKER HMC LINER HANGER 4,579.40
10 BAKER 80-40 SEAL BORE EXTENSION 7,446.5'
11 CROSSOVER BUSHING 9,924.7'
6
8
4
9
10
11
Liner:
3.5" 9.3# L-80 BTCMOD
Set @ 7,325’ KB
C80 @ 2690' KB C80 @ 2690' KB
Plug #1 – Reservoir
TOC ±6890' RKB
STATE OF ALASKA � V � y V
A OIL AND GAS CONSERVATION COMM.55ION "t
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool ri Repair w ell r Change Approved Rogram r
Suspend r Plug Perforations r Perforate \ tll�.ubing r Time Extension r
Operational Shutdown Re -enter Sus Well 1 �
p r p. r Stimulate r YJ4 casing r Other.Cement Shoe p
2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number:
ConocoPhillips Alaska, Inc. Development rj . Exploratory r 202 -017 '
3. Address: 6. API Number:
Stratigraphic r Service r
P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20407 -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 r No r \\Y -441
9. Property Designation (Lease Number
P Y 9 ( Number): 10. Field / Pool(s):
ADL0373112 • Kuparuk River F • = ater Oil Pool
11. PRESENT WELL CONDITION SUMM
Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs ( easur =.): Junk (measured):
7327 ' 5795
Casing Length Size MD ° D Burst Collapse
CONDUCTOR 89 16 120' .1k, ,,' 120' A 1640 630
SURFACE 2563 10.625 2594' , 237 ' IF 6890 4790
PRODUCTION 4666 8.5 4696' ` •,' 7000 4990
LINER 2766 5.82 73 5' ` : 5 '3' 10160 10540
C k /
I
Perforation Depth MD (ft): Perforation Depth TVD (ft): ubing Size: Tubing Grade: Tubing MD (ft):
6950 -6960 5520-5527 3.5 L -80 4539
Packers and SSSV Type: Pa '€ d SSSV and TVD (ft)
PACKER = BAKER K -22 ANCHOR P : MD = 4553, = 3791 RECEIVED
SSSV = CAMCO "DS" NIPPLE • ,. , MD 15, t I = 515 #w rr is 0
12. Attachments: Description Summary of Roposal sq 1 1 : r proposed work: r Development p' - Ser AU u 1 7 2012
1 vice r
Detailed Operations Program r BOP Sk -tch f � w 0GCC
14. Estimated Date for Commencing Operations: . 15. We .tatus :fter proposed work:
9/15/2012 .\ Oil r Gas r WDSPL r Suspended r
16. Verbal Approval: Date: r GINJ r WAG r Abandoned r
Commission Representative: GSTOR r SPLUG r
17. I hereby certify that the foregoing is true and corre , to e be- . y knowledge. Contact: Martin Walters
Printed Name Martin Waite- 1 Title: Well Integrity Supervisor
t
Signature 77,,v6.-
� 7,," bC)4 . Phone: 659 -7043 Date: 08/15/12 417
Commission Use Only
Sundry Number: 3/2-38
Conditions of approval: Notify Commi .ion so that a representative may witness
Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r
Other: l: ���1
. :y„ � x 1+0 4-: ' ': % 1 ' I- ,r 4 t ,-' L L
Subsequent Form Required:
APPROVED BY
Approved by: - COMMISSIONER THE COMMISSION Date: '' ,
Form 10 -403 Revised 1/2010 R 1 G j N e L Submit in Duplicate ,
�J F ll ub'
,
• • •
• •
Conoco Phillips
Alaska
P.O. BOX 100360
ANCHORAGE, ALASKA 99510 -0360 AUG 1 ? 2012
1Z
CC
August 15, 2012
Commissioner Dan Seamount
Alaska Oil and Gas Conservation Commission
333 West 7 Avenue, Suite 100
Anchorage, AK 99501
Dear Commissioner Seamount:
Enclosed please find the 10 -403 Application for Sundry Approvals for ConocoPhillips
Alaska, Inc. well 2P-441, PTD 202 -017 surface casing cement shoe.
Please call MJ Loveland or me at 659 -7043 if you have any questions.
Sincerely,
tat 2&<-.:
Martin Walters
ConocoPhillips
Well Integrity Projects Supervisor
Enclosures
• 0
ConocoPhillips Alaska, Inc.
Kuparuk Well 2P -441 (PTD 202 -017)
SUNDRY NOTICE 10 -403 REQUEST
08/15/12
The purpose of this Sundry Notice is to notify the AOGCC of ConocoPhillips Alaska, Inc., intent
to pump a cement shoe in the surface casing of Meltwater well 2P -441 (202 -017). A surface
casing cement shoe was not pumped at the time of original completion in 2002. The cement
shoe is required to isolate the surface casing by production casing annulus (OA), from downhole
formations above the producing zone.
With approval, the OA cement shoe will require the following general steps:
1. Pump cement designed for at minimum —1000' linear shoe in the OA.
2. Displace cement with freeze protection fluids
3. Wait 48 hrs on cement
4. MITOA to 1800 psi.
5. Submit 10 -404 to AOGCC.
NSK Problem Well Supervisor 8/15/2012
• .-, KUP • 2P -441
ConocoPhillip5 Well Attributes Max Angle & MD TD
/ a`ika Inc ti' Wellbore API/UWI Field Name Well Status Inc! ( °) MD (606) Act Btm (ftKB)
co,.. , „, 501032040700 MELTWATER PROD _ 48.60 6,016.54 7,327.0
Comment H2S (ppm) Date Annotation End Date KB (R) Rig Release Date
"' SSSV: NIPPLE 30 10/28/2011 Last WO: 35.10 4/25/2002
Well Confiq: - 2P341, 1 /20:42 '.05 AM
schematic - 131 Actual 12 7 Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date
Last Tag: SLM 6,946.0 8/8/2011 Rev Reason: WELL REVIEW osborl 1/31/2012
Casing Strings
Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd
HANGER. 25 f e"' CONDUCTOR 16 15.062 31.0 120.0 120.0 62.60 WELDED
Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd
SURFACE 75/8 6.875 30.9 2,593.8 2,377.4 29.70 L BTCMOD
Casing Description String 0... String ID ... Top OMB) Set Depth (t.. Set Depth (TVD) ... String Wt.. String ... String Top Thrd
4 PRODUCTION 51/2 4.950 30.2 4,696.0 3,891.5 15.50 L BTCMOD
Casing Description String 0... String ID ... Top (MB) Set Depth (f... Set Depth (TVD) .. String Wt... String ... String Top Thrd
LINER 3 1/2 2.992 4,559.2 7,325.0 5,793.2 9.30 L -80 BTCMOD
Liner Details
Top Depth
(TVD) Top Inc! Nomi...
I t Top (RKB) (RKB) ( °) Item Description Comment ID (In)
4,559.2 3,795.5 46.30 PACKER BAKER TIE - BACK SLEEVE ID 4.51 ", BAKER LINER TOP PACKER ID 3.910
CONDUCTOR, _� 3'91
31 - 120 4,574.4 3,806.0 46.28 SBR BAKER POLISHED BORE RECEPTACLE 2.992
4,579.4 3,809.5 46.27 HANGER BAKER HMC LINER HANGER 2.910
NIPPLE, 515 -- 7,227.1 5,721.0 42.45 Plug Catcher 2.992
Tubing Strings
Tubing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd
TUBING 31/2 I 2.992 I Str
25.0 I 4,553.8 3,791.8 I 9.3 I I -80 EUE- 8rdMOD
Completion Details
Top Depth Nomi...
(TVD) Top Ind
Top (MB) (RKB) (1 Item Description Comment ID (in)
IIIP 25.0 25.0 -0.22 HANGER CT1ATUBINGHANGER 3.500
OAS LIFT, , 514.8 514.8 0.48 NIPPLE CAMCO DS NIPPLE 2.875
2,083
("�� 4,478.8 3,740.0 46.36 SLEEVE -O BAKER CMU SLIDING SLEEVE w/DS PROFILE 2.813
J 4,494.8 3,751.0 46.35 NIPPLE CAMCO D NIPPLE 2.750
4,539.1 3,781.6 46.32 PBR BAKER POLISHED PBR 3.000
4,553.1 3,791.3 46.30 ANCHOR BAKER K -22 ANCHOR - TUBING SEAL DOWN 3.000
Perforations & Slots
Shot
Top (TVD) Btm (TVD) Dens
SURFACE, , Top (RKB) Btm (RKB) (RKB) (MB) Zone Date (sh... Type Comment
31 - 2,594 6,950.0 6,960.0 5,519.8 5,527.1 BERMUDA, 3/30 /2002 6.0 IPERF 2.5" Gun, 2506 HJ RDX, 60 deg
2P-441 phase
Stimulations & Treatments
GAS LIFT, Bottom
3,602
" a Min Top Max (Am Top Depth Depth
Depth Depth (TVD) (TVD)
(RKB) (RKB) (RKB) (11013) Type Date Comment
6,950.0 6,960.0 5,519.8 5,527.1 FRAC 4/1/2002 BERMUDA FORMATION FRAC - 97,448 LBS 16/20
PROPPANT BEHIND PIPE W/7.9 PPA ON PERFS
I 6,950.0 6,960.0 5,519.8 5,527.1 RE -FRAC 5/19/2004 RE -FRAC, PLACED 186,000# 16/20 CARBO -LITE,
GAS LIFT.
4,429 9 .._ 10.1 PPA @ PERFS
Notes: General & Safety
U. End Date Annotation
1 1/302004 NOTE: WAIVERED WELL: OA PRESSURE CHARGING FROM RESERVOIR '
11/24/2010 NOTE: View Schematic w/ Alaska Schematic9.0
SLEEVE-O. '
4,479
NIPPLE, 4,495
III
PBR, 4,539
I.
ANCHOR,
4,553 UM
Mill
II
PRODUCTION, . • • Mandrel Details
30-4,696 Top Depth Top Port
(TVD) Ind OD Valve Latch Size TRO Run
Stn Top (RKB) (RKB) (1 Make Model (in) Sery Type Type (in) (poi) Run Date Com...
IPERF, 1 2,082.7 1,997.6 35.06 CAMCO KBG - 2 - 9 1 GAS LIFT DMY INT 0.000 0.0 10/18/2002
8,95043,980
FRAC, 6,950 2 3,601.9 3,095.7 42.74 CAMCO KBG - 2 - 9 1 GAS LIFT DMY INT 0.000 0.0 3/26/2002
RE - FRAC,
6,950 3 4,429.0 3,704.9 45.21 CAMCO KGB -2 -9 1 GAS LIFT OV INT 0.313 0.0 5/26/2004
1
LINER, J '
4,559 -7,325
TD, 7,327
RECEIVED
• • SEP 2 4 2012
ConocoPhillips
1
Alaska AOGCC
P.O. BOX 100360
ANCHORAGE, ALASKA 99510 -0360
September 21, 2012
Commissioner Dan Seamount
Alaska Oil and Gas Conservation Commission
333 West 7 Avenue, Suite 100
Anchorage, AK 99501
Dear Commissioner Seamount:
ConocoPhillips Alaska, Inc. requests to withdraw the 10 -403 Sundry requests for OA
cement shoes on the following wells:
2P -417 (PTD 201 -069)
2P -438 (PTD 201 -082)
7 r2P -441 (PTD 202 -017
This work has been cancelled and will not be completed until further study has been done
at which time the appropriate Sundry requests will be filed.
Please call Martin Walters or me at 659 -7043 if you have any questions.
Sincerely,
MJ Loveland
ConocoPhillips
Well Integrity Projects Supervisor
Enclosures
')
Conoc~hillips
Alaska
'E"'r~ :,c.:
... 'It,~ ,·~u-;;) l#.":,~
1\1 ¡·ì. . I..: "ì
mi & 'ß~1£ C~ if\1~,
AJ1th:fJ1nlr~:e
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
¡;{û~ ~D/l)
June 06, 2006
Mr. Tom Maunder
Alaska Oil & Gas Commission
333 West ih Avenue, Suite 100
Anchorage, AI< 99501
SCANNED JUN 2 7 200,6
Dear Mr. Maunder:
Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of
these wells was foUnd to have a void in the conductor by surface casing annulus. The voids that
were greater than 6 feet were first filled with cement to a level of2.5 feet. The remaining
volume, 2.5 to 6 feet of annular void respectively was coated with a corrosion inhibiter,
RG2401, then filled with a viscous hydrocarbon based sealant, Royfill404B, 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.
The cement top-fill operation was completed on May 05,2006. Schlumberger Well Services
mixed 15.7 ppg Arcticset I in a blender tub. The cement was pumped into the conductor bottom
and cemented up via a hose run to the existing top of cement. The corrosion inhibitor and
sealant were pumped in a similar manner on May 18th, 19th and 31 st, 2006. The attached
spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on
each conductor.
Please call Marie McConnell or myself at 907-659-7224, if you have any questions.
¿ SinC71.rel,Y
\;{ -~ /
PerrfKlein
ConocoPhillips Problem Well Supervisor
Attachment
)
)
ConocoPhillips Alaska Inc.
Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off
Well Initial top
Name of cement
,:' .,;:., ft
?:·:·t~~(:jÊr . :4' . .: .
2P-415 5.5
fAi2P44t¡ :.' :' . '7:5.'
2P-419 1
r:.¡îP4t2Û::·· 1:~, ".:: ::â?~'5 : ".
2P-422 13.5
~;;::·12p.~4r·~,;:' .:. ; 4~5:;·.
2P-427 10
. ·:<2~9::..··t· '. .··2i': .
2P-431 13
·;:.2~.;ø-2··;:·:·:.,· '.1£5."
2P-434 14
.. ':~2P~3&>';:;::"" 5:'·'
2P441 15
:'2P;~'3':' . ·.~'.'3~5:::·: .
2P-447 2.5
::$P~ .,~::. ··.t.S-
2P-449 3
...
. :.:2PJ.4S:1: '. '1·0'
Kuparuk Field
June 6,2006
Vol. of cement Final top of Cement top
pumped cement off date
bbls ft
. .Q¡.,a,',: .' ' :, ~ < ··::4,·"
0.0 5.5
. . .'.Ô~,7", ','" ,,' '."~ ':,"2~5 "
0.0 1
fA.
., . ..' 'J)~o::; .'. ,;'::>3.5.. .' :': ßåì ~.
2.3 2.5
... .'
. . : ": .:. .":G'20.:.. : ".4_5 . :
1.6 2.5
~.¡.., ~
. . ··,OJ) , .' '\" :..::2:\"::
1.9 2.5
" : 'O~9 ._ '"2~5> .
2.0 2.5
'" ,
.' ',>- ij~: ':. ,,',', .:,~(i~~Ö,':·.;.~ , ,. '. "::5 .
2.0 2.5
, . " .' o~o :.: '-:i3~5
'f' .
0,0 2.5
·,:o.iØ' .' ,- ',4~5 .:." .~ :
0.0 3
". .~f· '2.5,·"
··n:a···
na
. '<5J11200~: :......:.
na
5/1/2006
·:::...·':na:
5/1/2006
: . ·-08·'··..··· :;
~. ¡' . \' ", . ',," ~' .'
5/1/2006
,: ·:"5:'1' :'M'0Q6,' '..
.{ . ". 14.. .'
5/1/2006
. ·::,..~nå,.;..·~,::·:
. . . .
5/1/2006
nai;-····
na
oa.
na
. '5/.112006' ."
RG2041 voj'
Qal
;. :·5~:7.
7.1
··..:,5,.1
6.7
·:·'·:7~1."···
7.1
'. 5-:7: :.'
7.1
.··3:~8,.·
7.1
..{.... . ;"5>7:: .
5.7
.': ':,5/1·::, . ...
7.1
": ~..; " '.·8;7: .
9.5
··9:5;: . .
5.7
, : :.' :·7~t·· .
Royfill4048
vol.
Qal
J
, ,17~1
30.9
···:··:·9:·····
o
17'.3,.. .
10.7
". ·:t7~6::
13.7
. . . ~ " >:5~7: '
10.1
. ~'., 1:3;'8:'
6.2
'...·21-.,9··
13.1
.... '1104'
o
0,:' .
11.5
. 6.5
Corrosion
inhibitor/
sealant date
5/19/2006
':$1:91208'6;':';"
5/19/2006
. :.~8I2ØQ6r:!··
5/18/2006
. " : ','.' ·····SÞ'· f:SI2'· "ÐGß" ':: :.j
. r' .' I. " .' ,....
. .' ",' .'. '.~ .", ':,; "
5/18/2006
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Mike Mooney
Wells Group Team Leader
Drilling & Wells
ConocÓPh ¡iii ps
P. O. Box 100360
Anchorage, AK 99510-0360
Phone: 907-263-4574
May 28, 2004
Commissioner
State of Alaska
Alaska Oil & Gas Conservation Commission
333 West ih Avenue Suite 100
Anchorage, Alaska 99501
Subject: Report of Sundry Well Operations for 2P-441 (APD # 202-017)
Dear Commissioner:
ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations
for the recent stimulation operations on the Kuparuk well 2P-441.
If you have any questions regarding this matter, please contact me at 263-4574.
Sincerely,
M.j¡(~
M. Mooney
Wells Group Team Leader
CPAI Drilling and Wells
MM/skad
RECEIVED
JUN 012004
.Alaska Oil & Gas Cons. Commission
Anchorage
OR1G1 NAL
Change Approved Program
2. Operator Name:
ConocoPhillips Alaska, Inc.
3. Address:
P. O. Box 100360
7. KB Elevation (ft):
RKB 27', Pad 224'
8. Property Designation:
ADL 373112, ALK 4998
11. Present Well Condition Summary:
1. Operations PerfDrmed:
Total Depth
Effective Depth
Casing
Structural
CONDUCTOR
SURFACE
PRODUCTION
LINER
CSG WINDOW
Perforation depth:
~
~
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
Abandon 0
Alter Casing 0
0
RepairWell 0
Pull Tubing 0
Operat. ShutdownD
Plug PerfDratiDns 0
Perforate New Pool 0
PerfDrate 0
4. Current Well Status:
Development - [2]
Stratigraphic 0
Exploratory 0
Service 0
Stimulate 0 Other 0
Waiver 0 Time Extension 0
Re-enter Suspended Well 0
5. Permit to Drill Number:
202-017/
6. API Number:
50-103-20407-00
9. Well Name and Number:
2P-441
10. Field/Pool(s):
Kuparuk River Field I Meltwater Oil Pool
measured 7327' feet
true vertical 5795' feet
measured 6979' feet
true vertical feet
Length Size MD
110' 16" 110'
2566' 7-5/8" 2593'
4669' 5-1/2" 4696'
2766' 3-1/2" 7325'
Measured depth: 6950'-6960'
true vertical depth: 5520'-5527'
Plugs (measured)
Junk (measured)
TVD
Burst
Collapse
110'
2377'
3890'
5793'
RECEIVED
JUN 0 1 2004
A\aska Oil & Gas Cons. Commission
Anchorage
Tubing (size, grade, and measured depth)
3-1/2" , L-80. 4554' MD.
Packers & SSSV (type & measured depth) pkr= BAKER 'FB' PACKER; BAKER LINER TOP PACKER pkr= 4553'; 4574'
SSSV= Cameo 'OS' protile nipple @ 515'
12. Stimulation or cement squeeze summary:
Intervals treated (measured)
6950'-6960'
Treatment descriptions including volumes used and final pressure: 186,000# 16/20 carbo-lite, 10.1 ppa @ perfs
13. Representative Daily Average Production or Injection Data
Dil-Bbi Gas-Met Water-Bbl
396 816 0
275 883 0
15. Well Class after proposed work:
Exploratory 0 Development [2] Service 0
16. Well Status after proposed work:
oil0 GasD WAG 0
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Prior to well operation
Subsequent to operation
14. Attachments
Copies of Logs and Surveys run -
Daily Report of Well Operations_X
Form 10-404 Revised 04/2004
Contact
Printed Name
Signature
CasinQ Pressure
TubinQ Pressure
268
271
GINJD
WINJD
WDSPLD
I Sundry Number or N/A if C.O. Exempt:
Mike Mooney @ 265-4374
Mike MoDney
J1J J{ ~
Title
Phone
Wells Group Team leader
Date 43/ ~1-
Prepared ~h~r:~I~UP-Drake 263-4612
MJMS Sf t
JUN 0 3 7004
Submit Original Only
,---
"---""',
2P-441 Well Events Summary
Date Summary
05/11/04 CUT PARAFFIN FROM 675' TO 1690' WLM. IN PROGRESS.O
[Frac-Refrac]
05/12/04 CUT PARAFFIN FROM 1232' TO 2000'. PULLED OV @ 4429' RKB. SET 2.75/1 CAT SV @
4495' RKB. IN PROGRESS.O
[Frac-Refrac, Paraffin]
05/13/04 LOAD TBG/IA WITH 52 BBL FW & 42 BBL DSL CAP. SET DMY @ 4429' RKB. MIT TBG &
IA 3500 PSI, TESTS GOOD. PULLED 2.75" CAT SV.D
[Frac-Refrac]
05/19/04 REFRAC T3 SANDS WITH 30# LG XL GEL AND 282,000# 16/20 CARBO-LITE.
BREAKDOWN, SCOUR, DATAFRAC, BRACKET FRAC, FRAC. HAD NWBSO WITH 185963
# IN FORMATION 10.1 PPA ON PERFS. LEFT 19M# IN WELLBORE.o
[Frac-Refrac]
OS/23/04 PERFORMED A FILL CLEAN OUT WITH 2.3" JET SWIRL NOZZLE; TAGGED TO @ 7210'
CTD. NITROGEN AND SLICK DIESEL PUMPED TO ASSIST RETURNS.D
[FCO]
OS/26/04 DRIFT W/2.70" CENT SB TO 7221; WLM, PULL 1/1 DV INT. & SET 1" INT (5/16/1 OV) @
4429' RKB AFTER LRS DISPLACES IA W/53 BBLS DIESEL.! PUMPED 39 BBLS TO FINISH
DISPLACING TUBING, TOTAL 92 BBLS 0
[GLV, Tag]
~
~
KRU
2P-441
ConocoPhUUps Alaska, Inc.
TUBING
(0-4554,
OD:3.5oo,
ID:2.992)
SURFACE ~
(0-2593,
OD:7.625,
Wt:29.70)
'RODUCTION
(0-4696,
OD:5.500,
Wt:15.50)
Gas Lift
¡ndrelJDummy
Valve 2
(3602-3603,
OD:4.425)
Gas LIft
¡ndrellDummy
Valve 3
(4429-4430,
OD:4.425)
SLEEVE-O
(4478-4479,
OD:4.500)
NIP
(4495-4496,
OD:4.550)
LINER
(4554-7325,
OD:3.500,
Wt:9.30)
PKR
(4574-4575,
OD:4.678)
HANGER
(4579-4580,
OD:4.620)
Perf
(6950-6960)
FRAC
(6950-6960)
RE-FRAC
(6950-6960)
COLLAR
(7261-7462,
OD:3.867)
f"
~
/
>
~
-{---
j
,
r
API: 501032040700
SSSV Type: Nipple
Well Type: PROD
Orig 4/25/2002
Completion:
Last W/O:
Ref Log Date:
TD: 7327 ftKB
6017
Anç¡le @ TS: deg @
Angle @ TD: 42 deg @ 7327
Annular Fluid:
Reference Log:
Last Tag: 6979
Last Date: 10/23/2003
Rev Reason: Set DMY, FRAC
Last Update: 5122/2004
Description
CONDUCTOR
SURFACE
PRODUCTION
LINER
Wt
62.60
29.70
15.50
Grade
Thread
L-80
L-80
L-80
BTCMOD
BTCMOD
BTCMOD
Size
3.500
Interval
6950 - 6960
Comment
BERMUDA FORMATION FRAC - 97,448 LBS 16/20
PROPPANT BEHIND PIPE Wn.9 PPA ON PERFS
RE-FRAC, PLACED 186,000# 16/20 CARBO-LITE, 10.1 PPA
PERFS
Interval
6950 - 6960
Date
4/1/2002
Type
FRAC
6950 - 6960
5/19/2004 RE-FRAC
St
MD TVD Man Man Type
Mfr
2083 1999 CAMCO
3602 3096 CAMCO
4429
V Mfr
V OD Latch
Port
TRO Date Vlv
Run Cmnt
10/18/2002
312612002
V Type
Description
515 515 NIP CAMCO 'DS' PROFILE NIPPLE
4478 3739 SLEEVE-O BAKER CMU SLIDING SLEEVE W/DS PROFILE 2.813"
4495 3751 NIP CAMCO 'D' NIPPLE
4553 3791 LOCATOR BAKER 80-40 GBH-22 W/ANCHOR TUBING SEAL
Description ID
4553 3791 PKR BAKER 'FB' PACKER W/K ANCHOR RECEPTACLE. 3.000
4559 3795 TIE BACK BAKER TIE BACK SLEEVE 4.510
4574 3806 PKR BAKER LINER TOP PACKER 3.910
4574 3806 PBR BAKER POLISHED BORE RECEPTACLE 2.992
4579 3809 HANGER BAKER HMC LINER HANGER 2.910
7261 5746 COLLAR FLOAT COLLAR 2.992
7323 5792 SHOE 2.992
~ tQylÀ{)~4
DATA SUBMITTAL COMPLIANCE REPORT
4/2/2004
Permit to Drill
Well Name/No. KUPARUK RIV U MELT 2P-441
Operator CONOCOPHILLIPS ALASKA INC
.,\p'J..L )~ M(J.A }~ J....
API No. 50-103-20407-00-00
2020170
MD
7327 ./
Completion Date 3/30/2002 ./
Completion Status
5795 ,/
TVD
REQUIRED INFORMATION
Mud Log No
Samples No
DATA INFORMATION
Types Electric or Other Logs Run:
Well Log Information:
Logl Electr
Data Digital Dataset
Type Med/Frmt Number
~b C ~-41't30
Rpt
Log
; Log
Log
Log
Log
Log
Log
Log
Name
Log Log Run
Scale Media No
1
1
25 Blu
25 Blu
25 Blu
25 Blu
25 Blu
25 Blu
25 Blu
25 Blu
Well Cores/Samples Information:
Name
Interval
Start Stop
Received
Sent
ADDITIONAL INFORMATION
Well Cored? Y IQ
Daily History Received?
Chips Received?
Formation Tops
¥-t.bI.-.
Analysis
Received?
~.
Comments:
1-01L
Current Status 1-01L
UIC N
Directional Survey
Yes
(data taken from Logs Portion of Master Well Data Maint)
J
Interval OHI
Start Stop CH Received Comments
120 7327 Open 2/28/2003 MPRIORD/CCN/GR
266 7327 Open 2/28/2003
120 7327 Open 2/28/2003
120 7327 Open 2/28/2003
120 7327 Open 2/28/2003
120 7327 Open 2/28/2003
120 7327 Open 2/28/2003
120 7327 Open 2/28/2003
120 7327 Open 2(28(2003
120 7327 Open 2/28/2003
Sample
Set
Number Comments
)
&/N
QyN
DATA SUBMITTAL COMPLIANCE REPORT
4/2/2004
Permit to Drill 2020170
Well Name/No. KUPARUK RIV U MELT 2P-441
Operator CONOCOPHILLIPS ALASKA INC
MD
7327
Current Status 1-01L
TVD 5795
Completion Date 3/30/2002
Completion Status
1-01L
Compliance Reviewed By:
~
Date:
API No. 50-103-20407-00-00
UIC N
J Cl ~,.{JNj\ l(
)
)
8PHIlliPS Alaska, Inc.
. A SUbsidiary of PHILLIPS PETROLEUM COMPANY
TUBING
{(}4SS4,
OD:3.500,
ID:2.992)
SURFACE
(0-2593,
00:7.625,
Wt29.70)
~ODUCTION
(04696,
00:5.500,
WtI5.50)
Gas Lift
YandreWalvE
3 (44294430,
OD:4.425)
SLEEVE-O
(44784479,
00:4.500)
NIP
(44954496,
00:4.550)
LINER
(4554-7325,
00:3.500,
Wt9.30)
PKR
(4574-4575,
00:4.678)
Perf
(6950-6960)
FRAC
(6950-6960)
r$ti
~--~- J
I(IIIIII! "
I
!
¡
~
~
¡
J
.~
~
ao;).-O\\
KRU
2P.441
API: 501032040700
S88V Type: Nipple
Well Type: PROD
Orlg 4/25/2002
Completion:
Last WID:
Ref Log Date:
TO: 7327 ftKB
49 6017
Angle @¡ T8: deg @
Angle @ TO: 42 deg @ 7327
Annular Fluid:
Reference Log:
Last Tag: 6979
Last Date: 10/17/2002
Rev Reason: Tag, GLV by ImO
Last Update: 10/20/2002
Max
Description
CDNDUCTOR
SURFACE
PRODUCTION
LINER
Size
16.000
7.625
5.500
3.500
Top
0
0
0
4554
Bottom
120
2593
4696
7325
TVD
120
2377
3890
5793
Wt
62.60
29.70
15.50
9,30
Grade
Thread
L-80
L-80
L-80
BTCMOD
BTCMOD
BTCMOD
Size Top Bottom TVD Wt Grade Thread
3.500 0 4554 3792 9.30 L-80 EUE8rd
Interval TVD Zone Status Ft SPF Date Type Comment
6950 - 6960 5520 - 5527 10 6 IPERF 12,5" Gun, 2506 HJ RDX, 60
Ideg phase
Interval
6950 - 6960
Date
4/1/2002
Comment
FORMATION FRAC - 97,448 LBS 16/20
BEHIND PIPE PERFS
Type
St MD TVD Man Man VMfr V Type VOD Latch Port TRO Date Vlv
Mfr Type Run Cmnt
1 2083 1999 CAMCO KBG-2-9 DMY 1.0 INT 0.000 0 10/18/200.
2 3602 3096 CAMCO KBG-2-9 DMY 1.0 INT 0.000 0 3/2612002
3 4429 3705 CAMCO KBG-2-9 OV 1.0 INT 0.313 0 10/18/200. (1)
1. Sheared
TVD Type Description
515 515 NIP CAMCO 'DS' PRDFILE NIPPLE
4478 3739 SLEEVE-O BAKER CMU SLIDING SLEEVE WIDS PROFILE 2.813"
4495 3751 NIP CAMCO 'D' NIPPLE
4553 3791 LOCATOR BAKER 80-40 GBH-22 W/ANCHOR TUBING SEAL
ID
2.875
2.813
2.750
3.000
Type Description
PKR BAKER 'FB' PACKER WIK ANCHOR RECEPTACLE.
SLEEVE- TB BAKER TIE BACK SLEEVE
PKR BAKER LINER TOP PACKER
PBR BAKER POLISHED BORE RECEPTACLE
HANGER BAKER HMC LINER HANGER
COLLAR FLOAT COLLAR
SHOE
10
3.000
4.510
3.910
2.992
2.910
2.992
2.992
4553 3791
4559 3795
4574 3806
4574 3806
4579 3809
7261 5746
7323 5792
Legal Well Name: 2P-441
Common Well Name: 2P-441
Event Name: ROT - DRILLING
Report #: 1
Start: 3/4/2002
Spud Date: 3/5/2002
Report Date: 3/8/2002
End: ~2V2002
String Type: Surface Casing Permanent Datum: Average Pad Grnd Lvi Hole Size: (in) Hole TMD: 2,609.0 (ft)
Hole TVD: 2,389.0 (ft) KB-Datum: 224.00 (ft) Water TMD: (ft) Str Wt on Slips: (100)
Ground Level: (ft) CF Elevation: (ft) Liner Overlap: (ft) Max Hole Angle: 44.00 (") )
Circ Hours: (hr) Mud Lost: (bbl) KB to Cutoff: 30.89 (ft) Days From Spud: 3.00 (days)
Manufacturer:
Hanger Model:
FMC
Fluted
Model: Gen V
Packoff Model:
Top HublAange: (in) I (psi)
BTM Hub/Flange: (in) I (psi)
Actual TMD Set: 2,593.75 (ft)
Casing Hanger 10.750 2.50 30.89 Casing Hanger
Casing 7.625 29.70 L-80 6.750 BTC 1,000.50 33.39 6.875 7518.29.7# LoS
Tam Collar 7.625 2.42 1,033.89
Casing 7.625 29.70 L-80 6.750 BTC 1,469.99 1,036.31 6.875 75/8.29.7# LoS
Float Collar 1.27 2,506.30 Roat Collar )
Casing 7.625 29.70 L-80 6.750 BTC 84.73 2,507.57 6.875 7518.29.7# LoS
Float Shoe 1.45 2,592.30 Roat Shoe
Printed: 912f2003 2:50:50 PM
~
~
Legal Well Name: 2P-441
Common Well Name: 2P-441
Event Name: ROT - DRILLING
Report #:
Start:
1
3/4/2002
Spud Date: 3/5/2002
Report Date: 3/8/2002
End: 3/27/2002
Hole Size: 9.875 (in) Hole Size: Hole Size: Hole Size:
TMD Set: 2,593 (ft) sa TMD: (ft) TMD Set: Top Set: (ft)
Date Set: 3/8/2002 sa Date: Date Set: BTM set: (ft)
Csg Type: Surface Casing sa Type: Csg Type: Plug Date:
Csg Size: 7.625 (in.) sa TMD: Plug Type:
sa Date: Drilled Out:
Cmtd. Csg: Surface Casing Cmtd. Csg: Cmtd. Csg: Cmtd. Csg:
Cement Co: Dowell Schlumberger Cementer: Kevin Anderson Pipe Movement: Reciprocating
Rot Time Start: :
Rae Time Start:14:30
Time End: :
Time End: 17:30
RPM:
SPM: 1
Init Torque: (ft-Ibf)
Stroke Length: 15.0 (ft)
Avg Torque: (ft-Ibf)
Drag Up: 5,000 (Ibs)
Max Torque: (ft-Ibf)
Drag Down: 5,000 (Ibs)
Type: Cement Casing Start Mix Gmt: 16:30 Disp Avg Rate: 6.00 (bbl/min) Returns: Full
Volume Excess 'Yo: 350.00 Start Slurry Displ: 16:30 Disp Max Rate: 6.00 (bbl/min) TotEd Mud Lost: (bbl)
Meas. From: 1400 to surface Start Displ: 18:00 Bump Plug: Y Gmt Vol to Surf: 155.00 (bbl)
Time Circ Prior End Pumping: 18:30 Press Prior: 700 (psi)
To Cementing: 2.00 End Pump Date: 3/8/2002 Press Bumped: 1,160 (psi) Ann Flow After: N
Mud Circ Rate: 252 (gpm) Top Plug: Y Press Held: 3 (min) Mixing Method:
Mud Circ Press: 700 (psi) Bottom Plug: Y Float Held: Y Density Meas By:
Type: Spud Mud Density: 9.6 (ppg) Visc: 42 (s/qt)
Bottom Hole Circulating Temperature:76 (OF)
Displacement Fluid Type:Mud
PV/yP: 22 (cp)/14 (lb/100ft2) Gels 10 sec: 4 (lb/100ft2) Gels 10 min: 6 (lb/100ft2)
Bottom Hole Static Temperature: 56 (OF)
Density: 9.6 (ppg) Volume: 115.00 (bbl)
Slurry Data
Fluid Type: LEAD
Slurry Interval: 2,593.00 (ftJl"o: (ft)
Water Source:
Description: AS Lite
Gmt Vol: 235.0 (bbl)
Slurry Vol~OO (sk)
Class:
Density: 10.70 (ppg) Yield: 4.44 (ft3/sk)
Water Vol: (bbl) Other Vol: 0
Purpose: PRIMARY
Mix Water: 20.70 (gal)
Foam Job: N
Test Data
Thickening Time: 6.00
Free Water: 9.00 ('Yo)
Fluid Loss: 8.7 (cc)
Fluid Loss Pressure: (OF)
Temperature:80 (OF)
Temperature: (OF)
Temperature: (OF)
Time
Compressive Strength 1:
Compressive Strength 2:
Temp
(OF)
(OF)
Pressure
(psi)
(psi)
Printed: 9/212003 2:50:35 PM
~
,~
Legal Well Name: 2P-441
Common Well Name: 2P-441
Event Name: ROT - DRILLING
Report #:
Start:
1
3/4/2002
Spud Date: 3/5/2002
Report Date: 3/8/2002
End: 3/27/2002
Slurry Data
Fluid Type: TAIL Description: LiteCRETE Class: G
Slurry Interval: 2,593.00 (ft¡To: 1,380.00 (ft) Cmt Vol: 70.0 (bbl) Density: 12.00 (ppg) Yield: 2.92 (ft3/sk)
Water Source: Slurry Vol:135 (sk) Water Vol: (bbl) Other Vol: 0
Purpose: TAIL
Mix Water: 8.48 (gal)
Foam Job: N
Test Data
Thickening Time:
Free Water: (%)
Fluid Loss: (cc)
Fluid Loss Pressure:
Temperature: (OF)
Temperature: (OF)
Temperature: (OF)
Time
Compressive Strength 1:
Compressive Strength 2:
Temp
("F)
(OF)
Pressure
(psi)
(psi)
("F)
Test Press: (psi)
For: (min)
Cement Found between
Shoe and Collar:
Pressure:
(ppge)
Liner Lap:
Pos Test: (ppge)
Neg Test: (ppge)
Hrs Before Test:
Cement Found on Tool:
Tool:
Tool:
Tool:
Open Hole: (ft)
Hrs Before Test:
CBL Run:
Under Pressure: (psi)
Bond Quality:
Cet Run:
Bond Quality:
Temp Survey:
Hrs Prior to Log:
CementTop: (ft)
How Determined:
TOC Sufficient:
Job Rating:
If Unsuccessful Detection Indicator:
Remedial Cementing Required:
Number of Remedial Squeezes:
Full retums thru job-Bumped plug on calculated strokes @ 1830 hrs. 03/08/02-Estimated 30% washout-returns of 155 bbls. cement at
surface.
Printed: 91212003 2:50:35 PM
.r---..
.~
JOB NUMBER EVENT CODE 24 HRS PROG TMD ITVD DFS
ODR 2,609.0 2,389.0 3.00
IRELDNAME/OCSNO. AUTHMD I DAILY TANG
Meltwater 7,327.0 0
ACCIDENTS LAST 24 HRS.? DAILY INT WIO MUD
Nipple up rope. 0
24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL
Test bope-pick up bha-rih-test csg.-drill cement-LOT. 3/8/2002 278,730
LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE
AK0232
INC AZIM I LAST CASING I NEXT CASING
44.740 194.400 7.625 (in) @ 2,593.0 (ft) 5.500 (in) @ (ft)
~'1."~I~T'.IB~~l'tM~~lìtfL'êl=¡~>~ ¡,,~~Y ~urF-'; ""âf'7**~
I'ÆrL'~d'J"'I"'t'1.""'~'.'~".'ßI w;w,J"/,,"'ß'dI¡ ~l¡t@t,."",.,,", I' ,~" """'rg'~"i""",Mš1Iä'"
REPT NO. DATE
4 3/8/2002
¡CUM. TANGO
CUM INTANG WI MUD
0
CUM COST WI MUD
702,056
2P-441
SUPERVISOR ¡RIG NAME" NO.
M.C. Heim NORDIC 3 n1433@PPCo.com 3
CURRENT STATUS
AUTH.
LAST SURVEY: DATE TMD
3nt2002 2,559.74
2,519,955
LAST BOP PRES TEST
2
Hole Opener 1 4.15 9.875 2.812
Crossover 1 1.38 7.750 3.000
Float Sub 1 2.51 6.750 2.812
NM Drill Collar - Short 1 10.06 6.250 2.812
Crossover 1 1.01 7.750 3.000
3 Pt Roller Reamer 1 6.67 8.000 2.250
Crossover 1 1.16 7.940 3.000
Drill Pipe - Non-Mag 4 Comp Serv 1 29,04 5.000 2.810
Stabilizer - Non Mag 1 4.87 6.250 2.810
Drill Pipe - Non-Mag 4 Comp Serv 1 29.44 5.000 2.810
Drill Pipe - Non-Mag 4 Comp Serv 1 30.15 5.000 2.810
Crossover 1 2.52 6.750 2.250
Drill Pipe - Heavy Wgt 18 552.46 4.000 2.250
Jars 1 32.04 6.250 2.250
Drill Pipe - Heavy Wgt 14 426.68 3.500 2.250
2.00 DRILL P SURFAC Wash & ream hole wI hole opener from 1500' to 2609'. (Hole clean-occasional
knots in hole while reaming).
02:00 05:00 3.00 DRILL P CIRC SURFAC Circ. condition mud & hole tor 7 5/8" csg,
05:00 08:00 3.00 DRILL P TRIP SURFAC POH & lay down bha,
08:00 09:00 1.00 DRILL P OTHR SURFAC Clear tloor-move out bha & service rig.
09:00 13:30 4.50 CASE P RUNC SURFAC PJSM-rig up & run 59 its. 7 5/8" csg. wI tam collar as per program.
13:30 14:30 1.00 CASE P RURD SURFAC Rig down till up tool-rig up Hanger-landing it. & cement head.
14:30 16:30 2.00 CASE P CIRC SURFAC PJSM-circ. & condition tor cement.
16:30 18:30 2.00 CEMENT P PUMP SURFAC Test lines to 3500#-mix & pump spacers & cement sas per program. (Bump
Printed: 9/2/2003 2:50:59 PM
~
.~
16:30 18:30
2.00
CEMENT P
PUMP
SURFAC plug on calculated strokes-full returns thru job-recovered 155 bbls.
cement-calculates 30% washout)
SURFAC Rig down cement lines-csg. equipment-landing ]t-cement head. Wash out
diverter lines & system-nipple down dlverter & lines.
18:30 00:00
5,50
CEMENT P
OTHR
Nordic
Catering
ConocoPhlllips Company
4
2
1
Baker Hughes Inteq
Baroid
GBR
4
1
2
1,255
200
¡11~11T1'~~1111
1,530 Camp Fuel
154 Camp Water
Rig Fuel
Rig Water
gals
bbls
gals
bbls
36
3,075
36
Printed: 9/212003 2:50:59 PM
CASING TEST and FORMATION INTEGRITY TEST
Well Name:
Date:
3/9/2002
Supervisor: M.C. Heim
2P-441
0 Initial Casing Shoe Test
0 Formation Adequacy for Annular Injection
0 Deep Test: Open Hole Adequacy for Higher Mud Weight
Casing Size and Description: 7-5/8" 29.7# L-80, BTCM
Reason(s) for test:
Casing Setting Depth: 2,593' TMD Hole Depth: 2,631' TMD
2,377' TVD 2,403' TVD
Mud Weight: 9.1 ppg Length of Open Hole Section: 38'
EMW= Leak-off Press. + Mud Weight = 890 psi + 9.1 ppg
0.052 x TVD 0.052 x 2,403'
EMW for open hole section = 16.2 ppg
Pump output = 0.0154 bps
Fluid Pumped = 0.5 bbl
3,200 psi
3,100 psi
3,000 psi
2,900 psi
2,800 psi
2,700 psi
2,600 psi
2,500 psi
2,400 psi
2,300 psi
2,200 psi
2,100 psi
2,000 psi
W 1,900 psi
a: 1.800 psi
::I 1,700 psi
ZJ 1,600 psi
W 1.500 pSI
a: 1,400 pSI
Do 1,300 psi
1,200 psi
1,1OOpsi
1 ,000 psi
900 psi
~~~j
6oops;
500 psi
400 psi '"
300 psi ..,...'
200 psi .
100 psi
0 psi 0 .. œ ;; ;;; ~ ~
111111111111111111111
I III III III I
,t "'Å"'Å"'A.~~,!.,
I
--LEAK-OFF TEST
"""'CASING TEST
--LOT SHUT IN TIME
---At-CASING TEST SHUT IN TIME ==
-+- TIME LINE
J
"
/
Ii
/~~ M HIli .
,,/
~ ~ ~ ~ t t ~ m g t ~ ~ ~ g ~ ~ ~ ~ 8
STROKES
NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above
LEAK-OFF DATA
Dowell Pump
.277 bpm
PRESSURE
MINUTES 18 SPM
FOR .0154 bps
LOT STROKES
,---- -, ,
I . 0 stks :
,--------- I I
! 1 9 stks 1
¡--------------; 13 stks i
,------- -I ,
I 1 min 1 18 stks 1
i---------- :
. I 23 stks
1---- : .
27 stks '
----------- I
i----------- i 31 stks
!-___~_~in i 35 stks
¡-_u_-- i
, ,
. ,
;---------- i
I
r------------ !
. ,
¡- :
: I
r-------- i
1------
1-----
1
j----------
L__----__-
.
I
:---------
1
1-----------
,
!-------
,
,
,------ ,
~--- i
I I
1-- I
. .
i i
: SHUT IN TIME
¡ O.Omin I
¡- 1.0 min ¡
¡---'2.0 min I
r- 3.0 min i
. .
! 4.0 _min i
¡ 5.0min i
¡ 6.0min i
! 7.0min I
: 8 0 . I
! . mln !
. 90 . I
~---' mln I
L10.0min I
I r
200 . 1 ;
pSI i
300 psi I
426 psi I
560 psi 1
680 psi ì '
810 psi I !
890 . I
¡PSI ¡ i
, 1
i I
! ¡ .
i i
I 1
I 1
j i '
, ,
i ' i
, I
I I
t I
I j' I
I :
, I
I .
i ¡¡I
, I I ;
! 1 1 I
! I i SHUT IN TIME !
¡- ¡ ! 0.0 min i
i 1 1.0 min I
I 1 ¡ 2.0 min I
I . I I
SHUTIN PRESSURE I 3.0 min I
! 890 psi! I 4.0 min !
-'880 -iI50"
I pSI I I . mln I
i 870 psi ¡ i 6.0 min i
1863 .1170' I
pSI I I . mm I
¡ 857 psi ì 8.0 min I
¡ 849 psi i 9.0 min I
i 842 psi I ' 10.0 min 1
-- ¡ 838 psi I : 15.0 min I
¡ 833 psi ¡ ¡ 20.0 min !
1 827 psi i ! 25.0 min i
1822 .11300':
I PSI!!. mln I
CASING TEST DATA
Minutes
for
Csg. Test
Rig Pump
.282 bpm
PRESSURE
60 psi
200 psi
730 psi
1,170 psi .
1,700 psi '
. 2,300 psi
2,550 psi
)
4SPM
.0705 bps
STROKES
i 0 sties I
1 min. I 4 stks I
2.0 min : 8 stks I
3.0 min 12 stIes 'I
4.0 min 16 stks
5.0 min' 20 stks
21 sties
SHUT IN PRESSURE
2,550 psi 1
2,540 psi i
2,540 psi, )
2,540 psi -
. 2,540 psi ¡
I 2,540 psi I
1 2,540 psi .
I 2,540 psi,
2,530 psi :
2,530 psi ¡
2,530 psi
2,520 psi
I 2,520 psi .
i 2,520 psi :
I 2,510 psi J
NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY
~
~
'" .
TMD ITVD
2,631,0 2,403.0 4.00
AUTHMD I DAILY TANG
7,327.0 0
DAILY INT WIO MUD
0
DATE OF LAST SAFETY MEETING DAILY TOTAL
3/8/2002 118,812
ILEAKOFF AFE
16.23 AK0232
¡NEXT CASING
2,593,0 (11) 5.500 (in) @
0
SUPERVISOR
M,C, Heim
CURRENT STATUS
NUMBER ¡EVENT CODE 124 HRS fROG
2P-441 ODR 22,0
I RIG NAME & NO. I FIELD NAME I OCS NO.
NORDIC 3 n1433@ppco.com 3 Meltwater
ACCIDENTS LAST 24 HRS.?
POH=Failed MWD
24 HR FORECAST
Repair mwd-rih-drill & survey.
UTHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP
LAST SURVEY: DATE TMD INC AZIM ¡LAST CASING
317/2002 2,559.74 44.740 194.400 7.625 (in) @
~~§~iJI{~Rti~m 9.60 1'¡í~¡1 1~~ij¡1
tt:~\ :'r¡ ~~~: ',:' I :W Ø~!~ )'! 1m, M/;~Tij~eJ I I', )FÇ~~þ'~, '.:",' i".~(:' ';
"~~~11
3
18
40
Bit
Turbo-Back Stab
Mud Motor
Stabilizer - NonMag
LWDIMAP
LWD/SRIG
LWD/MPR
LWD/SDN
MWD
UPA
Drill Pipe - Non-Mag 4 Camp Serv
Drill Pipe - Non-Mag 4 Comp Serv
Drill Pipe - Non-Mag 4 Comp Serv
Crossover
Drill Pipe - Heavy Wgt
Jars
Drill Pipe - Heavy Wgt
1
1
1
1
1
1
1
1
1
1
1
1
1
1
18
1
14
1.00
0.85
30.78
5.31
3.92
5.04
12.00
16.69
19.25
3.72
30.83
30.94
30,28
2.54
552.46
29.35
426.68
6.750
6.719
6.625
6.625
4.750
4.750
4.750
4.750
4.750
4.750
4.750
4.750
4,750
4.750
4.000
4.750
4.000
NO.
5 3/9/2002
I CUM. TANGO
CUM INTANG WI MUD
0
CUM COST WI MUD
820,868
AUTH.
(ft)
2,519,955
LAST BOP PRES TEST
3/9/2002
0
3
1,201.64
::~4r~:t:!~~~l t~ø:~f!:~~:i
1.500
2.250
2.812
2.812
2.812
2.812
2.812
2.812
2.690
2.690
2.690
2,250
2.250
2.250
2.250
00:00 00:30
00:30 01 :30
01 :30 02:30
02:30 07:30
07:30 11 :30
11:30 12:00
12:00 16:00
CEMENT P
CEMENT P
CEMENT P
CEMENT P
CEMENT P
CEMENT P
DRILL P
OTHR
OTHR
RURD
RURD
SEaT
SEaT
PULD
SURFAC Finish nipple down diverter.
SURFAC Clean cellar area-load well head equipment in cellar.
SURFAC Nipple up csg. & tbg. heads.
SURFAC Nipple up 11" 5K bope-test csg. seal 1 OOO#-change out upper rams to 4".
SURFAC Test bope 250-3000# (retighten lower blind flange.)
SURFAC Pull test it & set wear ring.
SURFAC Make up bha #3-up load-orient mwd & load nukes. (problem reading
0,50
1.00
1.00
5.00
4.00
0.50
4.00
Printed: 10/1/2003 2:30:36 PM
(',
~
2P-441
¡JOB NUMBER ¡EVENT CODE 124 HRS PROG
ODR 22.0
ITMD TVD IDFS
2,631.0 2,403,0 4.00
IREPTNO. ¡DATE
5 3/9/2002
WELL NAME
,ri~~~~ri
SURFAC mwd.break off mwd -pwd & make up new tool.
SURFAC Run in hole wI bha-shallow test moo @ 270'-rih to 2337'.
SURFAC CBU.blow down top drive.
SURFAC Rig up & test 75/8" csg. to 2500# for 30 mins. OK.
SURFAC Drill plugs-fc-cement-shoe & 22' new hole from 2609' to 2631'.
SURFAC Cbu-Iay down single.
SURFAC Attempting LOT.which turned in to FIT @ 16#.
12:00 16:00 4.00 DRILL P PULD
16:00 18:00 2.00 DRILL P TRIP
18:00 19:00 1.00 DRILL P CIRC
19:00 20:00 1.00 DRILL P DEQT
20:00 22:00 2.00 DRILL P OTHR
22:00 22:30 0.50 DRILL P CIRC
22:30 00:00 1.50 DRILL P FIT
Nordic
Catering
ConocoPhillips Company
Baker Hughes Inteq
4
2
1
4
Baroid
Technodyne
Quadco
1
2
1
Rig Fuel
Rig Water
gals
bbls
1,155
170
375
234
Camp Fuel
Camp Water
gals
bbls
24
3,075
12
Printed: 10/1/2003 2:30:36 PM
~
~
CASING DETAIL
5-112" INTERMERIA TE CSG
.PHlllIPS Alaska, Inc.
~ A Subsidiary of PHILLIPS PETROLELtv1 cav1PANY
Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN
Jts 3 to 110
NORDIC RIIG #3 RT to landing ring
FMC 11" X 5-1/211 Csg Hgr
5-112" 15.5#, l-80, BTCM OD 6.050" ID 4.950
5-112" Davis Lynch DBl VlV Float Collar
5-1/2" 15.5#, l-80, BTCM OD 6.050" ID 4.950
5-112" Davis lynch DBl VLV Float Shoe
108 Jts
Jts 1 to 2
2Jts
RATE HOLE
6-3/4" hole TD
Run one bowspring centralizer per joint on joints 1-43. First 2 on stop
collars in the center of the joints, The rest below the casing collars
Let float.
Total of 43 Bowsprings & 2 stop rings
Remarks; String weights with Blocks: Up Wt 80k, On Wt 50k, Blocks 22k. Ran 110 Joints casing.
Drifted casing & Hanger with 4.825" plastic rabbit. Used Arctic grade API modified thread compound
on all connections. Casing is non coated, All casing is new.
Well: 2P-441
Date: 3N 5/02
DEPTH
LENGTH TOPS
30.16
2.90
4576.36
1.30
83.85
1.39
7.04
NORDIC RIG #3
Supervisor: Donald L. Wester
30.16
33.06
4609.42
4610.72
4694.57
4695.96
4703.00
~
~
~PHILLIPS Alaska, Inc.
~ Å Subsidiary or PHILLIPS PETROLEl,t.¡t COMP.4.NY
CASING TALLY
WELL NUMBER:
CASING DESCRIPTION:
DATE:
2P-441
5 1/2" , 15.5# , Lao, BTCM
03/15/02
PAGE:
RIG:
1 of 2
Nodlc Rig 3
Column 1 Column 2 Column 3 Column 4 Column 5 Column 6 Column 7 Column a
No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet
1 41.50 26 43.50 51 41.64 76 40.98 101 43.48 126 151 176
2 42.35 27 41.62 52 43.61 77 43.36 102 39.55 127 152 177
3 36.18 28 38.50 53 43.53 78 35.75 103 43.60 128 153 178
4 40.43 29 40.23 54 41.32 79 43.56 104 42.56 129 154 179
5 40.56 30 43.49 55 43.42 80 40.69 105 38.30 130 155 180
6 43.44 31 43.59 56 36.23 81 43.53 106 43.42 131 156 181
7 41.77 32 43.49 57 41.76 82 43.49 107 41.56 132 157 182
8 43.45 33 42.25 58 43.60 83 43.57 108 43.38 133 158 183
9 42.30 34 43.42 59 43.50 84 43.10 109 43.46 134 159 184
10 42.91 35 43.46 60 40.85 85 43.60 110 43.40 135 160 185
11 43.48 36 43.48 61 43.14 86 43.49 111 136 161 186
12 43.45 37 43.20 62 43.20 87 43.45 112 137 162 187
13 43.50 38 43.45 63 40.17 88 43.46 113 138 163 188
14 43.49 39 43.42 64 42.95 89 43.58 114 139 164 189
15 43.40 40 43.63 65 38.98 90 43.48 115 140 165 190
16 42.49 41 43.43 66 43.40 91 37.80 116 141 166 191
17 43.43 42 34.32 67 43.50 92 43.23 117 142 167 192
18 43.81 43 43.01 68 43.66 93 37.52 118 143 168 193
19 43.61 44 43.50 69 43.56 94 43.60 119 144 169 194
20 43.43 45 39.08 70 43.50 95 43.49 120 145 170 195
21 43.61 46 42.90 71 41.14 96 43.82 121 146 171 196
22 43.27 47 43.21 72 40.99 97 43.51 122 147 172 197
23 43.37 48 43.41 73 43.56 98 41.40 123 148 173 198
24 41.75 49 43.13 74 38.90 99 43,54 124 149 174 199
25 43.24 50 43.05 75 42.87 100 43.53 125 150 175 200
Tot 1064.22 Tot 1059.77 Tot 1052.98 Tot 1060.53 Tot 422.71 Tot Tot Tot
TOTAL LENGTH THIS PAGE = 4660.21
DIRECTIONS:
TOTAL JOINTS THIS PAGE = 110 FLOAT SHOE 1.39'
FLOAT COLLAR 1.30'
RT to landing ring 30.16'
RT to Ground level 30.28'
~
~
~PHILLIPS Alaska, Inc.
~ f¡., Subsidiary or PHILLIPS PETROLELM COMPANY
CASING TALLY
WELL NUMBER:
TUBING DESCRIPTION:
DATE:
2p.441
51/2",15.5#, L80, BTCM
03/15/02
PAGE:
RIG:
2 of 2
Nodlc Rig 3
Column 9 Column 10 Column 11 Column 12 Column 13 Column 14 Column 15 Column 16
No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet
201 226 251 276 301 326 351 376
202 227 252 277 302 327 352 377
203 228 253 278 303 328 353 378
204 229 254 279 304 329 354 379
205 230 255 280 305 330 355 380
206 231 256 281 306 331 356 381
207 232 257 282 307 332 357 382
208 233 258 283 308 333 358 383
209 234 259 284 309 334 359 384
210 235 260 285 310 335 360 385
211 236 261 286 311 336 361 386
212 237 262 287 312 337 362 387
213 238 263 288 313 338 363 388
214 239 264 289 314 339 364 389
215 240 265 290 315 340 365 390
216 241 266 291 316 341 366 391
217 242 267 292 317 342 367 392
218 243 268 293 318 343 368 393
219 244 269 294 319 344 369 394
220 245 270 295 320 345 370 395
221 246 271 296 321 346 371 396
222 247 272 297 322 347 372 397
223 248 273 298 323 348 373 398
224 249 274 299 324 349 374 399
225 250 275 300 325 350 375 400
Tot Tot Tot Tot Tot Tot Tot Tot
TOTAL LENGTH THIS PAGE =
TOTAL LENGTH = 4660.21 DIRECTIONS:
TOTAL JOINTS THIS PAGE =
TOTAL JOINTS = 110,00
AVERAGE JT = 42.37
~
~
¡JOB NUMBER EVENT CODE 124 HRS PROG TMD ITVD DFS
2P-441 ODR 4,228.0 3,561.0 11.00
SUPERVISOR I RIG NAME & NO. I FIELD NAMEIOCS NO. AUTH MD DAILYTANG
Donald L. Wester NORDIC 3 n1433@ppco.com 3 Meltwater 7,327.0 0
CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INTW/O MUD
Off load truck wi equip, No subs Looking Dead Horse at Lynden. 0
24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL
RIH C/O 5.5" csg wi 4-3/4" BHA. LOT and drill hole 3/16/2002 140,728
LITHOLOGY JAR HRS OF SERVICE IBHA HRS SINCEINSP LEAKOFF AFE AUTH.
CLAYSTONE 16.23 AK0232 2,519,955
LAST SURVEY: DATE TMD INC AZIM I LAST CASING I NEXT CASING LAST BOP PRES TEST
3/12/2002 4,620.13 46.230 196.160 7.625 (in) @ 2,593.0 (ft) 5.500 (in) @ (ft) 3/9/2002
IRlfBíB.J~~1 11,00 J~il;~J I~~ßJI ~m1It¡IØ~'Ytlllœ¡æiÇpÃ'1 . 0 .. Irlrt.§~r1¡l 0
.~I~irVLYpj)I'þj~¡;¡S;¡~fØW~fì:iF#:jlff}_i'$ðœr!!iJjÌÔìîJWÂT:Jfi¥Ji~R1!mM:'ar:':t¥;¡¡wø:P;-~~Æ%I:~¡~{if~IiIf¡\1Wf1l'i~m..~.f#fil¡\;'*i2$i~1Uif'-I
!iiNi3;Al1'(W;~/~~A'IH""'4ñ""él'téh"';':'07"""'f' ";Hh.,j1'~""""""j f""""""'7"'~'<"*~I:m"<~"'=í;~"M""'~"'ILtmjL~:~íô!,.%.lli "":"""'7'" """"I"b¡'¡;\1iJ,",.",.AiJiIHJi1.L","j" oi.lli"."..,'Hii I M"""'li,tt",... '"
I REPT NO. DATE
12 3/16/2002
I CUM. TANGO
CUM INTANG WI MUD
0
CUM COST WI MUD
1,740,466
1.50 CASE Np CIRC INTRM1 Continue to circulate and condi mud to a YP 12 wI 5-1/2" casing in hole @
4696'
01:30 02:00 0.50 CEMENT t-p CIRC INTRM1 PJSM Batch mix 40 bbl's MudPUSH @ 12.5 ppg, 10 bbl's CW100 & 42 bbl's
Cmt @ 15.8 ppg.
02:00 04:00 2.00 CEMENTt-p PUMP INTRM1 Test dowelllines to 4000 psi, Pump 10 bb's CW100, Drop btm plug, pump 40
bbl's 12.5 ppg MudPUSH, Drop btm plug #2, Pump 37 bbl's 15.8 ppg class
"G" cmt down pipe, drop top plug. Switch to rig pump and displ w/110 bbl's of
11.0 ppg mud. Bump plug wI 2000 psi @ 0400 hrs 3/16/02
04:00 05:00 1.00 CEMENT OTHR INTRM1 Check floats held O.K. RID cmt head and lines. UD landing joint.
05:00 06:00 1.00 CASE P PTCH INTRM1 Install packoff, Test to 5000 psi f/10 min OK
06:00 07:30 1,50 WELCTL P EaRP INTRM1 BOP's change top and btm pipe rams to 2-7/8"
07:30 10:30 3.00 CASE P SFTY INTRM1 Remove excess 5-1/2" csg and 4" HWDP fl pipe shed. CIO bails. Clean pits
and service equip.
10:30 13:30 3.00 WELCTL P BOPE PROD Set test plug, Test BOP's 250-3000 psi. State man John Spalding. Test gas
alarms.
13:30 17:30 4.00 DRILL P RIRD PROD Load pipe shed w/2 7/8" 10.40# S-135 AOH DP, SWDP and Dc's. C/O saver
sub on top drive, Set M/U Torque @ 5500 ftllb, Drilling @ 7500 ftllb
17:30 18:30 1.00 DRILL P RIRD PROD Set wear ring. RlU floor equip for 2-7/8" power tongs, rig tongs and spinner.
18:30 00:00 5.50 DRILL P PULD PROD PJSM Build 2-7/8" stands in moùse hole. While waiting on equipment
24 HR SUMMARY: Continue to circ and condi mud to cement 5.5" csg. Cement csg w/37 bbl's 15.8 ppg cmt. Displ wI rig bump plug at 0400
hrs. RID equip. UD equip. Test BOP's P/U 2-7/8" dp.
Nordic
Catering
ConocoPhillips Company
;1: 1~'tfWJll1r~II:
"" ,"m~!L",,","lligM1".
4 Baker Hughes Inteq
2 Baroid
2 Technodyne
3
1
1
Rig Fuel
Rig Water
gals
bbls
1,720
286
4,760
174
Camp Fuel
Camp Water
gals
bbls
270
28
3,110
37
Printed: 9/212003 3:10:38 PM
~
~
2P-417
DS-4
2P-441
2P-441
931
57
Printed: 9/212003 3:10:38 PM
CASING TEST and FORMATION INTEGRITY TEST
Well Name:
Date:
3/26/2002
Supervisor: Ralph BowielO Wester
LEAK-OFF DATA
2P-441
0 Initial Casing Shoe Test
Reason(s) for test: 0 Formation Adequacy for Annular Injection
0 Deep Test: Open Hole Adequacy for Higher Mud Weight
Casing Size and Description: 5.5 X 7.625" annulia
Casing Setting Depth:
4,693' TMD
2,717' TVD
2,593' TMD
Hole Depth:
Mud Weight:
Length of Open Hole Section:
2,100'
11.0 ppg
EMW = Leak.off Press/lnj Press. + Mud Weight
0.052 x TVD
= 770 psi + 11.0 ppg
0.052 x 2,717'
EMW for open hole section = 16.5 ppg
Pump output = 0.0573 bps
Fluid Pumped = 5.7 bbl
1,200 psi
1,100 psi
1,000 psi
~ '-\.
,~ ,
~
~
900 psi
. . . .
800 psi
.
.
W 700 psi
II:
æ 600 psi
UI
W
g: 500 psi
400 psi
300 psi
---LEAK-OFF TEST
---CASING TEST
-- LOT SHUT IN TIME
....,¡¡,- CASING TEST SHUT IN TIME -
200 psi
100 psi
0 psi"
0 m 0 ~ ~ ~ ~ ~ ~ ~ ~ m ~ m ~ ~ ~ m 8 ~ 8 ~ ~ ~ ~
STROKES
NOTE #1: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above
NOTE #2 :Pump rate increased from .25 bpm to .5 bpm @ 70 strokes wi pressure @ 750 psi.
NOTE #3: 2717' is TVD of hole section, midpoint of 7.625" shoe & TOC of 5.5" csg operation.
NOTE #4: Mud weight was adjusted to 11.0 ppg before cmt job on 5.5", therefore mud weight
in 5.5 X 7.625" annulus was takened to be 11.0 ppg.
NOTE #4: 770 psi is used as the injection pressure as this is the actual pressure
MINUTES
FOR
LOT
STROKES
0 stks i
4 stks I
8 stks !
12 stks j
14 stks !
18 stks i
24 stks i
28 stks ;
32 stks
34 stks '
36 stks !
38 stks !
40 stks i
45 stks ¡
50 stks i
55 stk~-i
60 stks j
65 stks I
-
70 stks i
80 stks !
90 stks
100 stks
;---------------1
¡-------------- i
, ,
1----- i
, ,
1_____- !
, I
, I
1______----- !
I I
1------------ :
I I
1---------- I
! I
r-------- j
1----------- I
I ,
i-------- i
:------- ~
L____- . !
. ,
, ,
I ,
1------- ;
, I
1------------- :
I I
I I
I I
r------- ¡
1-------- j
~-------- I
. I
1--------- i
1------ i
I I
1------- I
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1---------- ,
, I
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r------- i
¡ SHUT IN TIME:
r- -
, O.Omin
1----- .
I 1.0 mm
)----- .
) 2.0 mm
1----3 0 . I
! . mm I
! 4.0min ¡
I 5.0min i
! 6.0min I
r 7.0 min I
I a.Omin I
i 9.0min I
I - I -
L!Q:9__min i
PRESSURE
Opsi. j ,
430 ps~ i
690 ps~ ¡ "
800 PSI!
850 psi!
. I
890 pSI I
. I I
940 pSI I '
960 psi I
960 psi I
960 psi I
980 ps~ 1
910 PSI!
820 psi j
840 psi ¡
780 psi i
750 psi i !
740 psi I i
750 psi I i
750 psi !
770 psi.
770 psi'
770 psi
SHUT IN PRESSURE
I 770 psi'
, 620 psi
620 psi
620 psi I
610 psi i
610 psi ¡ I'
600 ps~ ¡ .
590 pSI
590 psi i
580 psi.
! 580 psi j
CASING TEST DATA
MINUTES
FOR
eSG TEST
STROKES
i 0 sties i
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SHUT IN TIME i
O.Omin i
1.0 min ¡
2.0min ¡
3.0min I
4.0min I
5.0min I
6.0min ¡
7.0min I
a.Omin :
9.0min
10.0 min ;
15.0 min '
20.0 min
, 25.0 min
¡ 30.0 min
PRESSURE
0 psi i
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NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY
.~
~
NUMBER I EVENT CODE /24 HRS PROG TMD I DFS
2P-441 ODR 7,327.0 5,794.0 21.00
SUPERVISOR I RIG NAME & NO. I FIELD NAME I OCS NO. AUTH MD I DAILY TANG
Donald L. Wester NORDIC 3 n1433@ppco.com 3 Meltwater 7,327.0 0
CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY !NT W/O MUD
Prepare to move to 2P-431 0
24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL
Complete rig movelru to spudlspud in well 3/25/2002 284,624
I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE AUTH.
FINE SAND 15.98 AK0232 2,519,955
LAST SURVEY: DATE TMD INC AZIM I LAST CASING I NEXT CASING LAST BOP PRES TEST
3/23/2002 7,327.00 42,450 171.200 5.500 (in) @ 4,696.0 (ft) 3,500 (in) @ 7,327.0 (ft) 3/26/2002
~~~~,~I~-
REPTNO. ¡DATE
22 3/26/2002
¡CUM. TANGO
CUM INTANG WI MUD
0
CUM COST WI MUD
3,294,240
UTHOLOGY
00:00 02:00 2.00 CMPL TN P TRIP CMPLTN Complete pooh wI 2.875" AOH DP.
02:00 02:30 0.50 CMPL TN P NUND CMPL TN Pull wear bushing.
02:30 03:30 1.00 WELCTL P BOPE CMPL TN Set test plug & xo upper pipe rams to 3.5".
03:30 07:30 4.00 WELCTL P BOPE CMPL TN Test bope 300 psi low 13000 psi high. Pull test plug & test jt - Id same.
07:30 09:30 2.00 CMPL TN P OTHR CMPL TN Ran LOT I Injection test. Injected @ .25 bpm, fomation broke back @ 980 psi
to 750 psi. Increased rate to .5 bpm, pressure increased to 770 psi. SI & held
10 minutes, pressure decreased to 580 psi and held.
09:30 10:00 0.50 CMPL TN P RUNT CMPL TN PU I MU 3.5" baker seal assembly & rih wI same on 3.5" x 9.3 ppf x L-80 x 8
rd mod tbg wI gas lift tools as per program, Incomplete @ end of this time
block.
10:00 11:30 1.50 CMPL TN P FRZP CMPL TN Freeze protect 7.625 x 5.5" annulus wI 31 bbl diesel [1825' tvd] @ .9 bpm /
1020 psi. Hold pressure for 30 minutes / press fell to 750 psi, SI same w/750
psi.
11:30 17:00 5.50 CMPL TN P RUNT CMPLTN Continue to run 3.5" completion as. per completion program. Run a total of
141 its 3.5" w. tools, & space out [2' above locator] wI 14.12' feet of pups,
one full jt below hanger. Observe seals entering PBR wI tbg si, release
pressure & continue wI space out. Results e-mailed to engineering -P Reilly.
17:00 19:00 2.00 CMPL TN P DEQT CMPL TN Pressure tbg to 500 psi. Hold tbg pressure & pressure 3.5 x 5.5 annulus to
3050 psi, tbg pressure increased to 600 psi, held same for 30 minutes, no
bleed down. Bleed off tbg, shear valve sheared before tbg press @ ? 200 psi.
Charted.
19:00 19:30 0.50 CMPL TN P NUND CMPL TN Set ck valve. Clean floor.
19:30 22:30 3.00 CMPL TN P NUND CMPL TN ND riser, remove lower pipe rams & nd bope.
Printed; 10/1/2003 2;29;37 PM
~
~
2P-441
, '
. , ,
I JOB NUMBER I EV~;~DE 124 HRS PROG
TMD ITVD DFS IREPTNO. I DATE
7,327.0 5,794.0 21.00 22 3/26/2002
WELL NAME
24 HR SUMMARY: Camp pooh, Id 2.875" dp/XO up rams to 3.5 & press test bope/run 3.5" completion - space out/run injection test on 5,5 x 7
625"/shear out shear valve/frz prott
Nordic
Catering
ConocoPhillips Company
2
2
1
Baker Hughes Inteq
Baroid
6
3
Rig Fuel
Rig Water
gals
bbls
6,784
198
Camp Fuel
Camp Water
gals
bbls
2,400
40
2P-415
2P-415
2P-415
2P-441
Grizzly
3
0
2 1000
0 0
Printed: 10/1/2003 2:29:37 PM
RE: 2P-422A Annular Disposal Application
~
Subject: RE: 2P-422A Annular Disposal Application
Date: Wed, 22 Oct 2003 09:11 :28 -0800
From: "Hayden, Philip" <Philip.Hayden@conocophillips.com>
To: "Tom Maunder" <tom_maunder@admin.state.ak.us>
Tom,
Here are the recalculated pump in pressures with some comments for the
wells in question. (Did you want them in an excel spreadsheet ?)
2P-417: 14.3 ppg
2P-422: 15.2 ppg (unchanged as the difference between the correct and
incorrect TVDs was so small)
~: 17.2 ppg. This "new calculated" pump in pressure is greater than
the original FIT of 16.2 ppg. This is attributed to the fact that an
intermediate casing string was run on this well due to a well corúrol
problem. This resulted in a shoe (and cement) approximately 1500 ft TVD
higher than any of the other wells drilled on Meltwater. We conclude
that the formations exposed on the other wells, including our candidate
well 2P-422, are isolated in the case of 2P-441.
Regards
Philip
-----Original Message-----
From: Tom Maunder rmailtD:tom maundertâ>.admin.state.ak.usl
Sent: Wednesday, October 22, 2003 8:11 AM
To: Hayden, Philip
Subject: Re: 2P-422A Annular Disposal Application
Philip,
With regard to the "new calculated" pump in pressures for 2P-417, 2P-422
and
2P-441 , would you please provide them??
Thanks,
Tom Maunder
"Hayden, Philip" wrote:
> Tom,
>
> In response to your comments:
> ./
> For the pump in test for well 2P-420 I must apologise for not having
> made sure that the sheet had been correctly filled in. Your
calculation
> of 14.2 ppg EMW had been previously confirmed by us but the sheet had
> not been corrected. /
> ../../ v
> For wells 2P-417, 2P-422 and 2P-441 the incorrect TVO was used for
> calculating the EMW for injection at the shoe. This had been noted by
us
> and the corrected EMW for injection at the shoe had been determined
and
> found to be, in all cases, lower than the original injection pressure
at
> the initial leak off or formation integrity test. We did not amend
these
> files before sending them on to you as they are part of the official
10f3
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10/22/2003 9:59 AM
RE: 2P-422A Annular Disposal Application
~.
> files. This would have lead to two different sets of data for these
> wells and we felt this could be potentially more confusing. On the
other
> hand we recognise now that we should have brought this to your
attention
> in our initial correspondence. We will be sure to do so in the future.
>
> For well 2P-431 we have been unable to locate any record of a pump in
> test after the initial leak off test was performed. We do know that
this
> annulus has been freeze protected and also that methanol has been
pumped
> down it to remove a hydrate plug but accurate pressure information is
> lacking. However, due to its location, between wells 429 and 441 we
are
> confident that its behaviour with respect to a pump in test is similar
> to these wells.
>
> I hope this note adequately addresses your comments and questions. If
> there is anything else please let me know.
>
> Regards
>
> Philip
>
> -----Original Message-----
> From: Tom Maunder [mailto:tom maunderCâJ.admin.state.ak.usl
> Sent: Monday, October 20, 2003 9:07 AM
> To: Hayden, Philip
> Subject: Re: 2P-422A Annular Disposal Application
>
> Phil,
> Here are my further comments/questions on the 2P-422A application. I
> look
> forward to your reply.
> Thanks.
> Tom Maunder, PE
> AOGCC
>
> On the 2P-420 pump in test, the calculation has not been done. TVDs
> have
> not been entered. Using the 550 psi maximum pressure and the shoe
tvd,
>1
> calculate 14.2 EMW The EMW of the sustained pump in pressure would
be
> slightly lower.
>
> On the pump in test of 2P-417, the calculation does not use the tvd of
> the
> rathole at the surface casing shoe. Using 2430' tvd, the EMW
calculates
> to
> 14.2 which is in agreement with the calculation for 2P-420.
>
> Tom Maunder wrote:
>
> > Hi Phil,
> > Welcome back. I was looking at the application and I have a couple
of
> > questions. Please note that I am not finished with my review of the
> > packet. This first note will allow you to capture myeddress.
2 of3
~
10/22/2003 9:59 AM
RE: 2P-422A Annular Disposal Application
r---.
~
»
> > My questions/comments are:
»
> > On the pump in plot for 2P-422ST dated 4/22/02, the TVD used in the
> > calculation is not the same as done on the initial leakoff dated
> > 2/20/02. Why the difference??
»
> > The TVDs on 2P-441 also are different. In particular the pump in
TVD
> is
> > listed as the mid point between the top of cement and surface shoe.
> All
> > EMWs should be referenced to the surface shoe.
»
> > There is no pump in test for 2P-431.
»
> > You have made the appropriate tvd change on 2P-429.
»
> > Tom Maunder, PE
> > AOGCC
30f3
10/22/2003 9:59 AM
.-"
.--...,
doa- 0/7
II 5 3D
Transmittal Form
'&ill
BAKER
HUGHES
II "",uu"", I
C'-..ii.=;;;"---'"
: ~"'.,'
¡:-' :" : ., :"'~
¡;.. :: ~.,,;,
¡-Om - ~ .. -,
INTEQ
Anchorage GEOScience Center
To:
AOGCC
333 West 7th Ave, Suite 100
Anchorage, Alaska
99501
Attention:
Lisa Weepie
Reference:
2P-441
Contains the following:
~-
æ¡,ss ,
1 LDWG Compact Disc
(Includes Graphic Image files)
1 LDWG lister summary
¡:::";'" =:":~;'-:"~
;:":",~:~~~; ~.:",~
~ ¡ .... ,,:-;;;;;;,;;
~1:;:~~
--
1 blueline - MPR Measured Depth Log
1 blueline - MPR TVD Log
1 blueline - CCN-ORD Measured Depth Log
1 blueline - CCN-ORD TVD Log
.h_._._---
_u_---
I
:-~
Sent By: Glen Horel
Received ~~ j
Date: Feb 26, 2003
LAC Job#: 270764
Date:
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING
OR FAXING YOUR COpy
FAX: (907) 267-6623
Baker Hughes INTEQ
7260 Homer Drive
Anchorage, Alaska
99518
Direct: (907) 267-6612
FAX: (907) 267-6623
RECEIVEOd~
'n"'"",
FEB 2 8 2003
Alaeka Oii & Gas Cons. Co~n
Anc:hmge ,
... .
(
(
Sc~."pgep
NO. 2030
Schlumberger Technology Corporation, by and through is Geoquest Division
3940 Arctic Blvd, Suite 300
Anchorage, AK 99503-5711
ATTN: Sherrie
Company:
Well
Field:
Date BL Sepia
03/20/02 1 1
03/30/02 1 1
03/08/02 1 1
03/11/02 1 1
03/08/02 1 1
03/07/02 1 1
Job #
Log Description
1M-17dol..,;;)~
2P-441dQ;)~OI1
2K-25 IqO~oJ~
2K-27 ri,nJ-JIc9
2K-27 .J,
3H-21 IW~DfY£
PRESSITEMP SURVEY
STATIC BOTTOMHOLE
RST-WFL
LEAK DETECTION LOG
LEAK DETECTION LOG
PRODUCTION PROFILE
SIGNE~ í)
DATE:
04/26/02
Alaska Oil & Gas Cons Comm
AUn: Lisa Wee pie
333 West 7th Ave, Suite 100
Anchorage, AK 99501
Kuparuk
CD
Color
RECEIVED
lPR 3 0 2002
Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you.
-\Jeska Oil & Gas Cons. Commiss1orl
I\nchorage
,---'-.
.~.
PHilliPS Alaska, Inc.
A Subsidiary of PHilLIPS PETROLEUM COMPANY
Post Office Box 100360
Anchorage, Alaska 99510-0360
R. Thomas
Phone (907) 265-6830
Fax: (907) 265-6224
April 18,2002
Commissioner Cammy Oechsli Taylor
State of Alaska
Alaska Oil & Gas Conservation Commission
333 West 7th Avenue Suite 100
Anchorage, Alaska 99501
Subject: Completion Report for 2P-441 (202-017 / 302-096)
Dear Commissioner:
Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the
Meltwater we1l2P-441.
If you have any questions regarding this matter, please contact Pat Reilly at 265-6048.
Sincerely,
~~ ---..~
""-~ \ -".
R. Thomas
Greater Kuparuk Team Leader
PAl Drilling
RT/skad
RECEIVED
APR 1 9 2002
Alaska Oil & Gas Cons. Commission
Anchorage
ORIGINAL
'---,
.~
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
Dil 0 Gas D
2. Name of OperatDr
Phillips Alaska, Inc.
3. Address
P. O. Box 100360, Anchorage, AK 99510-0360
4. Location of well at surface r~"';'-" :'..'- ';'-. ". """-.: ~".'.
~ GD~1¡'¡" nnl' '
989' FNL, 1719' FWL, Sec. 17, T8N, R7E, U~ "íÍA1'~ ,.¡, ! (ASP: 443679, 5868890)
At Top Producing Interval ~ ..J.:..;Lt5 .. Q..q
660' FSL, 917' FWL, Sec. 17, T8N, R7E, UM~ ,.. ~~. iEU. ¡.' (ASP: 442862, 5865265)
At Total Depth ¡ -_of
382' FSL, 937' FWL, Sec. 17, T8N, R7E, UM ""~""~""""~""'"'" (ASP: 442881, 5864986)
5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No.
RKB 27', Pad 224 ADL 373112 ALK 4998
12. Date Spudded 13. Date T.D. Reached 14. Date Comp'~¿Psp. Or Ab~nd. 115. Water Depth, if offshDre
March 5, 2002 March 23, 2002 MarclÍß1', 2002 :5þ NIA feet MSL
17. TDtal Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set
7327' MD 15795' TVD 7227' MD 15721' TVD YES 0 No D NIA feet MD
1. Status of well
Suspended
D
Service D
AbandDned D
22. Type Electric or Dther Logs Run
G RIRes/Den/Neu
23.
Classification of Service Well
7. Permit Number
202-017/302-096
8. API Number
50-1\03-20407-00
9. Unit tr Lease Name
Kuparuk River Unit
10. Well Number
2P-441
11. Field and Pool
Kuparuk River Field
Meltwater Oil Pool
16. No. of CompletiDns
21. Thickness of Permafrost
1360'
GRADE
B
L-80
L-80
L-80
CASING, LINER AND CEMENTING RECORD
SETTING DEPTH MD
TOP BOTTDM
Surface 110'
Surface 2594'
Surface 4696'
4559' 7325'
CASING SIZE WT. PER FT.
16" 62.5#
7.625" 29.7#
5.5" 15.5#
3.5" 9.3#
HDLE SIZE
42"
9.875"
6.75"
6.75"
24. PerfDratiDns Dpen tD Production (MD + TVD of Top and Bottom and
interval, size and number)
25.
SIZE
6950' - 6960' MD
5520' - 5527' TVD
6 spf
CEMENTING RECORD
422 sx AS 1
AMOUNT PULLED
300 sx AS IIIL, 135 sx LiteCrete
47 bbls LiteCrete
(included above)
3.5"
TUBING RECORD
DEPTH SET (MD)
4554'
PACKER SET (MD)
4554' & 4574'
26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
DEPTH INTERVAL (MD) AMOUNT & KIND DF MATERIAL USED
6950' - 6960' pumped 97448# Df 16/20 proppant behind pipe
27.
Date First Production
April 8, 2002
Date Df Test HDurs Tested
PRODUCTION TEST
Method Df OperatiDn (Flowing, gas lift, etc.)
Gas Lift Oil
ProductiDn fDr DIL-BBL GAS-MCF
2423 2822
OIL-BBL GAS-MCF
2423 2822
CORE DATA
4/11/2002 24 hours
Flow Tubing Casing Pressure
press 290 psi 728
28.
Test Period>
Calculated
24-Hour Rate>
WATER-BBL
111
WATER-BBL
111
CHDKE SIZE GAS-DIL RATID
100 1161
OIL GRAVITY - API (cDrr)
nDt available
Brief description of lithDlogy, porosity, fractures, apparent dips and pressence Df Dil, gas or water. Submit core chips.
NIA
Form 10-407 Rev. 7-1-80
GRTTb il\j7~SLIDE
RECEIVED
APR 1 9 2002
Alaska Oil & Gas Cons. CommiSSion
Anchorage
Submit in duplicate
RBDMS BFt
APR 2 9 2002
(Qç
,~
~
29.
30.
GEOLOGIC MARKERS
FORMATION TESTS
NAME
MEAS.DEPTH
TRUE VERT. DEPTH
Include interval tested, pressure data, all fluids recDvered and gravity.
GOR, and time of each phase.
T3.1
T-3
T-2
6638'
6803'
7030'
5287'
5411'
5578'
Annulus left open - freeze protected with diesel.
RECEIVED
APR 1 9 2002
Alaska Oil & Gas Cons. CO\1lmISSIO!I
AnchoraQe
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.
OuestiDns? Call Pat Reilly 265-6048
Signed ~::S\\'\"\.J...-"""""""---"itle
R. Thomas
Kuparuk DrillinQ Team Leader
Date
-<tI( ~(c~
Prepared by Sharon Allsup-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".
Form 10-407
~,
--..
legal Well Name:
CDmmon Well Name:
Event Name:
ContractDr Name:
Rig Name:
2P-441
2P-441
ROT - DRilLING
NORDIC 3 n1433@ppco.cDm
Nordic 3
Start: 3/4/2002
Rig Release: 3/27/2002
Rig Number: 3
Spud Date: 3/5/2002
End: 3/27/2002
Group:
3/512002
02:30 - 04:00
1.50 MOVE
MOVE MOVE
3/6/2002
04:00 - 12:00 8.00 MOVE MOVE MOVE
12:00 - 17:00 5.00 MOVE MOVE MOVE
17:00 - 18:00 1.00 MOVE MOVE MOVE
18:00 - 21:00 3.00 DRILL PULD SURFAC
21 :00 - 00:00 3.00 DRILL DRLG SURFAC
00:00 - 18:00 18.00 DRILL DRLG SURFAC
18:00 - 19:30 1.50 DRILL CIRC SURFAC
19:30 - 21 :00 1.50 DRILL WIPR SURFAC
21 :00 - 22:00 1.00 DRILL OTHR SURFAC
22:00 - 23:00 1.00 DRILL WIPR SURFAC
23:00 - 00:00 1.00 DRILL DRLG SURFAC
00:00 - 16:00 16.00 DRILL DRLG SURFAC
16:00 - 17:00 1.00 DRILL CIRC SURFAC
17:00 - 19:00 2.00 DRILL TRIP SURFAC
19:00 - 23:00 4.00 DRILL PULD SURFAC
23:00 - 00:00 1.00 DRILL REAM SURFAC
00:00 - 02:00 2.00 DRILL REAM SURFAC
02:00 - 05:00 3.00 DRILL CIRC SURFAC
05:00 - 08:00 3.00 DRILL TRIP SURFAC
08:00 - 09:00 1.00 DRILL OTHR SURFAC
09:00 - 13:30 4.50 CASE RUNC SURFAC
13:30 - 14:30 1.00 CASE RURD SURFAC
14:30 - 16:30 2.00 CASE CIRC SURFAC
16:30 - 18:30 2.00 CEMENT PUMP SURFAC
3/7/2002
3/8/2002
18:30 - 00:00 5.50 CEMENTOTHR SURFAC
3/9/2002 00:00 - 00:30 0.50 CEMENTOTHR SURFAC
00:30 - 01 :30 1.00 CEMENTOTHR SURFAC
01 :30 - 02:30 1.00 CEMENT RURD SURFAC
02:30 - 07:30 5.00 CEMENT RURD SURFAC
Move rig from well# 2P-451 to well # 2P-441
-Spot & level rig. (accept rig @ 0400 hrs. 31
5/02)
Spot rig support equipment-installing divert
er & diverter line-load tree in cellar-hook u
p mwd & mud buildings.
Work on flow riser-load mud in pits-load bha
in pipe shed-go to hi-line power-change ou
t floor equipment-full service to top drive.
Test diverter-(witness test waived by AOGC
C).
Make up bha & orient tools-tag bottom @ 92'
Clean out to 110' & drlg. from 110' to 191'.
30k up-30k dn-60 rpm 240 gpm-800 torque.
Drlg. & surveys from 191' to 1453'.
Circ.-clean hole for wiper trip.
POH to bit-clean clay off bha-Hole in good c
ondition-knotty @ 550' .
Service rig-repair link tilt ram on top drive.
RIH to 1361'-caution ream to bottom @ 1453
Drlg. & surveys from 1453' to 1519'.
Drlg. & surveys from 1519' to 2609'. (TD) Of
surface Hole.
Circ. condition hole for trip.
POH for hole opener.
Download mwd=lay down smart iron=pick up
new bha & rih to 700'.
Wash & ream from 700' to 1500'.
Wash & ream hole wI hole opener from 1500'
to 2609'. (Hole clean-occasional knots in h
ole while reaming).
Circ. condition mud & hole for 7 5/8" csg.
POH & lay down bha.
Clear floor-move out bha & service rig.
PJSM-rig up & run 59 jts. 7 5/8" csg. wI tam
collar as per program.
Rig down fill up tool-rig up Hanger-landing j
t. & cement head.
PJSM-circ. & condition for cement.
Test lines to 3500#-mix & pump spacers & c
ement sas per program. (Bump plug on calcu
lated strokes-full returns thru job-recovered
155 bbls. cement-calculates 30% washout.)
Rig down cement lines-csg. equipment-Iandi
ng jt.-cement head. Wash out diverter lines
& system-nipple down diverter & lines.
Finish nipple down diverter.
Clean cellar area-load well head equipment
in cellar.
Nipple up csg. & tbg. heads.
Nipple up 11" 5K bope-test csg. seal 1000#-
Printed: 4/1112002 4:30:45 PM
~"
~.
Legal Well Name:
Common Well Name:
Event Name:
ContractDr Name:
Rig Name:
2P-441
2P-441
ROT - DRILLING
NORDIC 3 n1433@ppco.cDm
Nordic 3
Start: 3/4/2002
Rig Release: 3/27/2002
Rig Number: 3
Spud Date: 3/5/2002
End: 3/27/2002
Group:
3/912002
02:30 - 07:30
07:30 - 11 :30
11 :30 - 12:00
12:00 - 16:00
16:00 -18:00
18:00 - 19:00
19:00 - 20:00
20:00 - 22:00
22:00 - 22:30
22:30 - 00:00
3/10/2002
00:00 - 01 :00
01 :00 - 04:30
04:30 - 05:00
05:00 - 06:00
06:00 - 06:30
06:30 - 07:30
07:30 - 11 :00
11 :00 - 12:00
12:00 - 12:30
12:30 - 14:00
3/11/2002
14:00 - 00:00
00:00 - 16:30
16:30 - 21:30
21 :30 - 00:00
3/12/2002
00:00 - 09:00
09:00 - 12:00
12:00 - 15:30
15:30 - 17:30
5.00 CEMENT RURD SURFAC
4.00 CEMENT SEaT SURFAC
0.50 CEMENTSEOT SURFAC
4.00 DRILL PULD SURFAC
2.00 DRILL
1.00 DRILL
1.00 DRILL
2.00 DRILL
0.50 DRILL
1.50 DRILL
1.00 DRILL
3.50 DRILL
0.50 DRILL
1.00 DRILL
0.50 DRILL
1.00 DRILL
3.50 DRILL
1.00 DRILL
0.50 DRILL
1.50 DRILL
10.00 DRILL
16.50 DRILL
5.00 DRILL
2.50 DRILL
9.00 DRILL
3.00 WELCTL KILL
3.50 WELCTL KILL
2.00 WELCTL KILL
TRIP
SURFAC
CIRC SURFAC
DEOT SURFAC
OTHR SURFAC
CIRC
FIT
SURFAC
SURFAC
FIT
PROD
CIRC
PROD
OTHR PROD
TRIP PROD
OTHR PROD
TRIP PROD
TRIP
PROD
OTHR PROD
OTHR PROD
OTHR PROD
DRLG PROD
DRLG PROD
OTHR PROD
DRLG PROD
DRLG PROD
PROD
PROD
PROD
change out upper rams to 4".
Test bope 250-3000# (retighten lower blind f
lange.)
Pull test it. & set wear ring.
Make up bha #3-up load-orient mwd & load n
ukes. (problem reading mwd-break off mwd -
pwd & make up new tool.
Run in hole wI bha-shallow test mwd @ 270'
-rih to 2337'.
CBU-blow down top drive.
Rig up & test 7 5/8" csg. to 2500# for 30 mi
ns. OK.
Drill plugs-fc-cement-shoe & 22' new hole fr
om 2609' to 2631'.
Cbu-Iay down single.
Attempting LOT-which turned in to FIT @ 16
#.
Blow down lines-rig down dowel I & testing Ii
n e s.
Displace well wI clayseal mud & circ. to she
ar mud-change shaker screens-mud running
over shaker.
Drill from 2631 to 2652 attempting to get m
wd to working-no pulse.
POh to check out mwd.
Crew change & service rig & top drive.
Finish poh-remove nukes & change out mwd-
Iwd.
Pick up new mwd-Iwd-up load-load nukes rih
to 2432-shallow test tools @ 1100'. OK.
Cut & slip drlg. line.
Change out wash pipe on top drive.
Attempt to wash to bottom-wash pipe washed
out-change washpipe & packing.
Drlg. & surveys from 2652 to 3235'.
Drlg. & surveys from 3235' to 4070'.
Took 10 bbl. kick on drlg. break-40# on dp-7
0# on csg.-circ. out kick & pump 10.# mud a
round-shut in 10# on dp-160 on csg.-pump 1
0.2# mud around.
Drlg. from 4070' to 4228'. -Gas cut mud-no f
luid gain,
Continue drilling 6-3/4" hole FI 4228' to 470
3' Gas cut mud No fluid gain.
Circ bottoms up. Raise mud weight FI 10.2 P
pg to 10.5 ppg
Cric @ 35 spm holding 550 psi on DP 70 psi
on csg annulus. Shut in 10 min SIDP 40 psi
SICP 70. Break down stand get top drive d
own on floor and inside house.
Circ @ 85 spm 1510 psi down flow line work
ed up to 100 spm @2100 psi. No flow or pit
gain. Monitor well.
Printed: 4/11/2DD2 4:30:45 PM
/-'"
,~
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
2P-441
2P-441
ROT - DRILLING
NORDIC 3 n1433@ppco.com
Nordic 3
Start: 3/4/2002
Rig Release: 3/27/2002
Rig Number: 3
Spud Date: 3/5/2002
End: 3/27/2002
Group:
3/12/2002 17:30 - 18:00 0.50 WELCTL TRIP PROD
18:00 -19:00 1.00 WELCTL TRIP PROD
19:00 - 22:00 3.00 WELCTL KILL PROD
22:00 - 23:00
1.00 WELCTL OTHR PROD
23:00 - 00:00
1.00 WELCTL KILL
PROD
3/13/2002
1.00 WELCTL KILL
PROD
00:00 - 01 :00
01:00 - 01:30
0.50 WELCTL KILL
PROD
01 :30 - 03:30
2.00 WELCTL KILL
PROD
03:30 - 04:30
1.00 WELCTL OBSV PROD
04:30 - 08:00 3.50 WELCTL CIRC PROD
08:00 - 09:00 1.00 WELCTL KILL PROD
09:00 - 11:30 2.50 WELCTL KILL PROD
11:30-12:00 0.50 WELCTL OBSV PROD
12:00 - 14:00 2.00 WELCTL TRIP PROD
14:00 - 15:00 1.00 WELCTL OBSV PROD
15:00 - 00:00 9.00 WELCTL TRIP PROD
3/14/2002 00:00 - 11 :30 11.50 WELCTL TRIP PROD
Pull one stand gas breaking out at surface.
Mud droped in stack. Blow down top drive. F
ill trip tank.
Short trip wI 10 stands up to 3839' hole too
k 2 bbl's then stoped taking fluid. RIH to 47
00' gained 7 bbl's on trip.
CBU @ 55 spm 800 psi Rotate 75 to 80 rpm
and recip. Next @ 65 spm 1000 psi. Next @
90 spm 1680 psi. 3 bottoms up @ 100 spm 2
030 psi
Shut in monitor well. SICP 70 psi after 10 m
in. SlOP O. Afher 30 min SICP 210 SIDP 40
spi. The dp pressure came up fast. After 1 h
r SICP 320 psi SIDP 290. Raise mud 3 point
s FI 10.5 to 10.8
Hold 690 psi on dp while pump @ 35 spm am
d mixing mud 10.8 ppg going in. Continue on
after midnight.
Continue raising mud weight FI 10.5 to 10.8
ppg. Holding 690-720 psi on dp while bring
around. A pallet of bar off elevator. @ 0045
hrs shut in SIDP 170 SICP 170
Monitor well till 0130 hrs SIDP 150 SICP 14
O. Start mixing and maintane mud weght @ 1
1 .1 P P g
Raise mud weight fl 10.8 ppg to 11.1 ppg Ho
Iding DPP @ 600 psi till 11.1 ppg at surface
. Shut in SIDP 230 SICP 210
Monitor well pressure. Bleed DP to "0" spi S
ICP 140 @ 0340 hrs. @ 0345 SIDP 120 SIC
P 120. 0400 hrs SlOP 90 SICP 80. AT 0430
hrs SlOP 40 SICP 50. Need 11.4+ ppg to bal
an c e.
Open Hydrill Bring pumps up to 85 spm @ 17
25 psi. Use ECD to control well. 12.14 ppg
ECD. Circ and recip up wt 85k, Dn wt 80k,
Blow down top drive. Monitor well while rota
ting @ 10 rppm. gained .1 bbl
CBU at 6 bpm 1450 psi. Had light gas at 100
stks, Heavy gas bubbling at 1300 stks. 303
7' cleaned up @ 1400 stks, 4265' ECD 12.
0 ppg. Continue to weight up f/ 11.2 to 11.5
P P g.
Monitor well rotate @ 10 rpm No flow.
Short trip to 7 5/8" csg shoe @ 2593'. Pump
out 22 stands. 2 bbl'd over pipe displacem
en t.
Service top drive. Take rig and camp off hig
h line power.
Mad pass wI MWD f/ csg shoe 2621 ' to 2875
, RIH to 3284' Mad pass to 3565' @ 80 FPH.
Will continue mad pass to 4200'
Continue to make MWD Mad Pass FI 3565' to
Printed: 4/11/2002 4:3D:45 PM
~
,--.....
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
2P-441
2P-441
ROT - DRILLING
NORDIC 3 n1433@ppco.com
Nordic 3
Start: 3/4i2002
Rig Release: 3/27/2002
Rig Number: 3
Spud Date: 3/5/2002
End: 3/27/2002
Group:
3/14/2002 00:00 - 11 :30 11.50 WELCTL TRIP PROD
11 :30 - 12:00 0.50 WELCTL TRIP PROD
12:00 - 13:30 1.50 WELCTL CIRC PROD
13:30 - 14:30 1.00 WELCTL TRIP PROD
14:30 - 17:00 2.50 WELCTL CIRC PROD
17:00 - 19:00 2.00 WELCTL TRIP PROD
19:00 - 21:30 2.50 WELCTL TRIP PROD
21 :30 - 00:00 2.50 WELCTL TRIP PROD
3/15/2002 00:00 - 01 :30 1.50 WELCTL TRIP PROD
01 :30 - 04:30 3.00 CASE DEOT PROD
04:30 - 07:30 3.00 CASE OTHR PROD
07:30 - 09:30 2.00 CASE RURD PROD
09:30 - 16:30 7.00 CASE RUNC PROD
16:30 - 17:30 1.00 CASE RUNC PROD
17:30 - 21:30 4.00 CASE CIRC PROD
21 :30 - 00:00 2.50 CASE CIRC PROD
3/16/2002 00:00 - 01 :30 1.50 CASE CIRC INTRM1
01 :30 - 02:00 0.50 CEMENTCIRC INTRM1
02:00 - 04:00 2.00 CEMENT PUMP INTRM1
04:00 - 05:00
1.00 CEMENTOTHR INTRM1
4285' @ 80 fpm 87 spm 1700 psi. While RI
H After short trip to shoe.
RIH F/4285' taged fill @ 4685' 18' of fill. C
10 to TD 4703'
CBU and condition mud @ 6.5 BPM 1700 psi.
Mudwt11.5ppg
Short trip wI 10 stands to 3763 wlo pump. H
ole in good condition. RIH to 4703'
Circ out gas @ 6 bpm catch mud samples. G
as cut mud @ 1400 stks cleaned up @ 2000
stks. Raise mud weight fI 11.5 to 11.8 ppg.
Monitor well for flow, Blow down top drive.
POOH stand back 4" HT-38 DP
R/U lay down HWDP.
Down load MWD.Load toolsl Clean floor.PJS
M on Raido active sourse. Pull nuke tools. B
reak mwd and motor LID same.
Continue to LID BHA MWD, Motor, Stab and
bit
MIU Baker 7 5/8" test packer RIH on 4" DP t
0 1100' Set Test casing and Tam port collar
@ 1033' to 2500 psi for 15 min O.K. POOH
LID same.
Drain stack. Set test plug. Change out top p
ipe rams to 5-1/2". Test rams to 250-3500 p
s i.
PJSM on running casing. R/U floor to run ca
sing. Change Bails, M/U Franks tool.
P/U and RIH wI 110 it's 5-1/2" 15.5# L-80 B
TCM wI Float shoe & Float. Circ pipe volume
at 7-5/8" Shoe 2593'. Continue RIH wI casi
ng to 4660'
BID Franks tool. P/U landing it WI Gmt head
and FMC 11" X 5.5" Csg hanger. Land casin
g. Shoe at 4696' float at 4610'
Circ and condition mud 2 bpm 240 psi. No g
as off bottom. Pump indicator pill to check
hole wash. Indicates hole 7.25"
Circulate and condition mud to 11.0 ppg wI
Y P 12
Continue to circulate and condi mud to a YP
12 wI 5-1/2" casing in hole @ 4696'
PJSM Batch mix 40 bbl's MudPUSH @ 12.5 P
pg, 10 bbl's CW100 & 42 bbl's Gmt @ 15.8 P
p g.
Test dowell lines to 4000 psi, Pump 10 bb's
CW100, Drop btm plug, pump 40 bbl's 12.5 P
pg MudPUSH, Drop btm plug #2, Pump 37 bb
I's 15.8 ppg class "G" cmt down pipe, drop
top plug. Switch to rig pump and displ wI 11
0 bbl's of 11.0 ppg mud. Bump plug wI 2000
psi @ 0400 hrs 3/16/02
Check floats held O.K. RID cmt head and lin
Printed: 4/11/2002 4:30:45 PM
~
~\
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
2P-441
2P-441
ROT - DRILLING
NORDIC 3 n1433@ppco.com
Nordic 3
Start: 3/4/2002
Rig Release: 3/27/2002
Rig Number: 3
Spud Date: 3/5/2002
End: 3/27/2002
Group:
3/16/2002 04:00 - 05:00 1.00 CEMENTOTHR INTRM1
05:00 - 06:00 1.00 CASE PTCH INTRM1
06:00 - 07:30 1.50 WELCTL EQRP INTRM1
07:30 - 10:30 3.00 CASE SFTY INTRM1
10:30 - 13:30 3.00 WELCTL BOPE PROD
13:30 - 17:30 4.00 DRILL RIRD PROD
17:30 - 18:30 1.00 DRILL RIRD PROD
18:30 - 00:00 5.50 DRILL PULD PROD
3/17/2002 00:00 - 03:30 3.50 DRILL PULD PROD
03:30 - 06:00 2.50 DRILL OTHR PROD
06:00 - 07:00 1.00 RIGMNT RSRV PROD
07:00 - 08:00 1.00 RIGMNT RSRV PROD
08:00 - 11 :00 3.00 DRILL PULD PROD
11 :00 - 14:00 3.00 WAlTON EQIP PROD
14:00 - 18:00 4.00 DRILL TRIP PROD
18:00 - 21 :00 3.00 DRILL DRLG PROD
21 :00 - 21 :30 0.50 CASE DEQT PROD
21 :30 - 00:00 2.50 DRILL DRLG PROD
3/18/2002 00:00 - 04:00 4.00 DRILL DRLG PROD
04:00 - 04:30 0.50 DRILL DEQT PROD
04:30 - 00:00
19.50 DRILL
DRLG PROD
3/19/2002
15.00 DRILL
DRLG PROD
00:00 - 15:00
es. LID landing joint.
Install packoff, Test to 5000 psi f/ 10 min 0
. K.
BOP's change top and btm pipe rams to 2-71
8 "
Remove excess 5-1/2" csg and 4" HWDP f/ P
ipe shed. CIO bails. Clean pits and service
equip.
Set test plug, Test BOP's 250-3000 psi. Stat
e man John Spalding. Test gas alarms.
Load pipe shed wI 2 7/8" 10.40# S-135 AOH
DP, SWDP and Dc's. CIO saver sub on top d
rive, Set M/U Torque @ 5500 ft/lb, Drilling
@ 7500 ftllb
Set wear ring. R/U floor equip for 2-7/8" po
wer tongs, rig tongs and spinner.
PJSM Build 2-7/8" stands in mouse hole. Wh
ile waiting on equipment
Continue to P/U 2-7/8" 10.40# S-135 AOH dp
MIU stands and stand back.P/U M/U 2-7/8"
SWDP stand back
Clean pits, Floor and change liners in pump
s to 4.5"
Service rig and top drive
Full monthly derrick inspection & service cr
own
M/U 4-3/4" bit #4 on BHA #5 and RIH to Jar
s. Shallow test MWD equip.
Wait on Jars and X-over sub from Deadhorse
RIH to 4603' Tag plugs. Up wt 67k Dn wt 50k
Break circ and CIO cmt plugs and float fl 5-
1/2" csg. to 4620'
Test 5-1/2" csg to 2500 psi for 30 min Lost
40 psi.
CIO Cmt from float & shoe equip 5-1/2" csg.
At midnight 4709'. Will Drill 37' of new 4-31
4" hole to 4740' MD 3921' TVD For LOT.
Continue Directional Drilling 4-3/4" hole f/ 4
709' to 4740' MD 3920' TVD. Displace 11.0 p
pg Clayseal with new 9.5 ppg LSND mud.
Pull inside 5-1/2" Csg shoe @ 4696'. Perfor
m FIT 4740' MD 3920' TVD wI 9.5 ppg mud a
nd 1320 psi surfice pressure. EMW of 16.0 p
pg. Droped 60 psi in 5 min.
Continue drilling 4-3/4" hole. FI 4740' to 53
13' MD 4340' TVD. Run solid control equip a
s needed. Up wt 70k, dn wt 55k, rt wt 62k T
orque 1500 ft/lb on Btm @50 rpm. ECD 11.2
Continue drilling 4 3/4" Hole f/ 5313' to 569
0' MD 4608' TVD. Upwt 68k, dn wt 55k, Rt wt
62k SPR 30 @800 Torque on btm 1550 ft/l
Printed: 4I11/2DD2 4:30:45 PM
~
.~
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
2P-441
2P-441
ROT - DRILLING
NORDIC 3 n1433@ppco.com
NDrdic 3
Start: 3/4/2002
Rig Release: 3/27/2002
Rig Number: 3
Spud Date: 3/5/2002
End: 3/27/2002
Group:
3/19/2002
00:00 - 15:00
15:00 - 16:30
16:30 - 17:30
17:30 - 18:30
18:30 - 21 :00
21 :00 - 00:00
3/20/2002
00:00 - 01 :30
01 :30 - 04:00
04:00 - 08:30
08:30 - 13:30
13:30 - 21 :00
21 :00 - 22:00
22:00 - 00:00
3/21/2002
00:00 - 01 :30
01 :30 - 04:30
04:30 - 06:00
06:00 - 07:00
07:00 - 09:30
09:30 - 10:00
10:00 - 17:30
17:30 - 20:30
20:30 - 00:00
15.00 DRILL
1.50 DRILL
1.00 DRILL
1.00 DRILL
2.50 DRILL
3.00 DRILL
1.50 DRILL
2.50 DRILL
4.50 DRILL
5.00 DRILL
7.50 DRILL
1.00 DRILL
2.00 DRILL
1.50 DRILL
3.00 DRILL
1.50 DRILL
1.00 DRILL
2.50 DRILL
0.50 DRILL
7.50 DRILL
3.00 DRILL
3.50 DRILL
DRLG PROD
CIRC
PROD
TRIP PROD
OBSV PROD
TRIP PROD
TRIP PROD
PULD PROD
TRIP
PROD
OTHR PROD
OTHR PROD
DRLG PROD
CIRC
PROD
TRIP
PROD
TRIP
PROD
PULD PROD
PULD PROD
PULD PROD
PULD PROD
SFTY PROD
PULD PROD
TRIP
PROD
DRLG PROD
b, off btm 1200 ftllb. Will POOH for 3-1/8"
Resistivity logging tool. SPR 30 spm @ 800
psi
Survey, CBU two time. Monitor well. Blow do
wn top drive.
POOH to 5-1/2" csg shoe @ 4696'
Monitor well. Service top drive. No flow
Continue POOH
Handle BHA#5. M/U BHA #6, M/U New bit #5.
P/U Resistivity tool
Continue to Up load MWD Tools. New 3.125"
Resistivity logging tool.
RIH wI BHA #6 Shallow test MWD at 946'. Fi
II every 10 std's. RIH on 2 7/8" DP to 4669'
RIH Mad pass fI 4669' @ 80 fph, Real time
pumping @ 65 spm, Rotate @ RPM 25 to 495
0' M D
RIH Mad pass FI 4950' @ 180 fph to 5690' w
lout pumps or hooked to top drive. Record
data mod.
Contune dlrg 4-3/4" hole fl 5690' to 5946' M
D 4743' tvd. LWD failure tool locked up. 8
0 RPM, 3-10 woe, 75 spm @ 2950 psi Torqu
e 2450 ftllb on btm. Up wt 70k
CBU 2 time @ 5946' Monitor well 10 min O.
K. No Flow.
POOH 4653' MD 5.5" Csg shoe. Monitor for f
low O.K. Blow down top drive. Continue POO
H for LWD change out. Upwt 75-80k, Dnwt 5
5k
Continue to POOH fI 5946' MD 4743' tvd. Fo
r LWD failure Baker Intec.
Remove prob fI housing Grind sub in half to
release probe. Down load MWD.
CIO NPR tool MIU BHA #7, RR bit #5, RIH
Service rig while work on LWD Equip. Chang
e injector well FI 2P-417 total bbl's injected
31,952 TO 2P-415 starting volume 7303 bbl
's
Continue RIH wI BHA #7 Shallow test MWD 3
0 Mln Failed. POOH.
While working on LWD tools. Crews held Qu
arterly Safety assissment meting On rig floo
r.
Continue working on LWD tool and wait on E
EJ. M/U Orient MWD BHA #7 RIH Shallow tes
t. Cut drilling while waiting on tools.
RIH WI BHA #7 and RR bit #5 on 2-7/8" DP
Mad Pass Log fI 5924' to 5946'
Drill 4-3/4" hole f/ 5946' to 6067' MD 4867'
tvd. Up wt 70k, dnwt 65k, rtwt 63k. 2850 psi
off btm 3100 psi on @ 75 spm. Tqr 2500 ftll
b off btm 3300 ft/lb on btm @ 85 rpm. SPR 3
Printed: 4/11/2002 4:30:45 PM
~
..~\
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
2P-441
2P-441
ROT - DRILLING
NORDIC 3 n1433@ppcD.cDm
Nordic 3
Start: 3/4/2002
Rig Release: 3/27/2002
Rig Number: 3
Spud Date: 3/5/2002
End: 3/27/2002
Group:
3/21/2002 20:30 - 00:00 3.50 DRILL DRLG PROD
3/22/2002 00:00 - 06:00 6.00 DRILL DRLG PROD
06:00 - 07:00 1.00 RIGMNT RSRV PROD
07:00 - 19:00 12.00 DRILL DRLG PROD
19:00 - 22:30
3.50 RIGMNT RGRP PROD
22:30 - 00:00
1.50 RIGMNT RURD PROD
3/23/2002
0.50 RIGMNT RGRP PROD
00:00 - 00:30
00:30 - 02:00 1.50 RIGMNT RGRP PROD
02:00 - 19:00 17.00 DRILL DRLG PROD
19:00 - 21:00 2.00 DRILL CIRC PROD
21 :00 - 23:00 2.00 DRILL TRIP PROD
23:00 - 00:00 1.00 WELCTLOBSV PROD
3/24/2002 00:00 - 00:30 0.50 WELCTL OBSV PROD
00:30 - 03:30 3.00 DRILL TRIP PROD
03:30 - 06:30 3.00 DRILL CIRC PROD
06:30 - 13:00 6.50 DRILL TRIP PROD
13:00 - 14:30 1.50 CASE SFTY PROD
14:30 - 19:00 4.50 CASE RUNC PROD
19:00 - 21:00
2.00 CASE
RUNL PROD
0 spm @ 980 psi. Run solid control equip ho
Id mud weight 9.3 to 9.4 ppg. ECD 10.7 ppg.
Continue drlg 4-3/4" hole FI 6047' to 6277'
Swivel Packing washed out.
Change out wash pipe.
Continue drlg 4-3/4" hole FI 6277' to 6715'
MD 5344' TVD. Lost sume mud to formation
about 10 bbl's ECD 10.7 ppg. upwt 75k, dn
wt 65k, rtwt70k. torque 23/2800 ft/lb on btm
,26/2900 ft/lb off btm. 70 spm 3100 psi on
btm, 2850 psi off btm.
Top drive hydraulic pump froze up. Stripped
coupler between motor and pump. Looking f
or replacement parts. Have new pump but no
cuppling. Circulate and clean hole at 35 sp
m 1050 psi.
POOH to 5-1/2" csg shoe @ 4696'. Repair to
p drive hydraulics. BOP weekly test due tom
orrow.
AT 5.5" csg shoe. Continue working on Hydr
aulic forword drive. Changed out pump, coup
ling damaged between pump and motor. Use
reverse drive coupling on forward drive. Can
complete hole wI forward only.
RIH to 6715'
Continue drlg 4-3/4" hole fI 6715' to 7327'
MD TD 5794' TVD. Upwt 75k dnwt 68k Rtwt73
k.
Pull up to 7314' MD Circulate and reciprocat
e
Short trip to 5-1/2" csg shoe @ 4696'. upwt
95k, dnwt 50k,
Monitor well, Service rig and top drive. Gain
ed .8 bbl in 1 hr. NO GAS OIL SHOW.
Continue Monitor well at 5.5" csg shoe 4696
9.3 ppg in hole. No flow.
RIH fI 4696' to 7327' md TD. After short trip
to shoe and monitor ing well for 1 hr.
Circulate a indicator pill to check for wash
out. Came back at 144 bbl's 2 bbl's over ga
uge hole. No Gas Oil show. Raise mud weigh
t fI 9.3 to 9.6 ppg.
POOH to run 3-1/2" liner. Stand back 2-7/8"
dp and SWDP. LID BHA download MWD-LWD.
Clear floor, R/U lifting and turning equipme
n. PJSM on Running 3-1/2" Liner
P/U M/U 88 its of 3-112" 9.3# L-80 IBTM Csg
wI Special clearence collars. As per progra
m. Fill every it, M/U Baker liner and liner to
p packer.
RIH on 19 stds of 2-7/8" DP to 4650'. Circul
ate pipe volume. M/U cement head a it of 2-
Printed: 4J11J20D2 4:3D:45 PM
.~
,.-...,
Legal Well Name:
CDmmon Well Name:
Event Name:
Contractor Name:
Rig Name:
2P-441
2P-441
ROT - DRILLING
NORDIC 3 n1433@ppco.com
Nordic 3
Start: 3/4/2002
Rig Release: 3/27/2002
Rig Number: 3
Spud Date: 3/5/2002
End: 3/27/2002
Group:
3/24/2002 19:00 - 21:00 2.00 CASE RUNL PROD
21 :00 - 00:00 3.00 CASE RUNC PROD
3/25/2002 00:00 - 02:00 2.00 CEMENT CIRC PROD
02:00 - 02:30
0.50 CEMENT PUMP PROD
02:30 - 03:30
1.00 CEMENT PUMP PROD
03:30 - 05:00
1.50 CEMENT PUMP PROD
05:00 - 06:00
1.00 CASE
OTHR PROD
06:00 - 11 :00
5.00 CASE
OTHR PROD
11 :00 - 12:00
1.00 CASE
DEaT CMPL TN
12:00 - 17:00
5.00 CMPL TN TRIP
CMPL TN
17:00 - 22:00 5.00 CMPL TN PULD CMPL TN
22:00 - 23:30 1.50 CMPL TN TRIP CMPL TN
23:30 - 00:00 0.50 CMPL TN PULD CMPL TN
3/26/2002 00:00 - 02:00 2.00 CMPL TN TRIP CMPL TN
02:00 - 02:30 0.50 CMPL TN NUND CMPL TN
02:30 - 03:30 1.00 WELCTL BOPE CMPL TN
03:30 - 07:30 4.00 WELCTL BOPE CMPL TN
07:30 - 09:30 2.00 CMPL TN OTHR CMPL TN
09:30 - 10:00
0.50 CMPL TN RUNT CMPL TN
7/8" SWDP and LID.
RIH wI liner through open hole slowly to 732
7' MD TD. Break circ wI 28 spm 1000 psi. U
pwt 97k Dnwt 60K
COntinue circulate and condition mud with 3
-112" liner on btm @ 7327' Reciprocate and
rotate. Pump 9.3 ppg mud around thined and
YP 11 @ 42 spm 960 psi
Batch mix 50 bbl's LiteCRETE @ 11.0 Ppg a
nd 20 bbl's MudPUSH @ 10.2 ppg. PJSM. CI
ear rig mud lines wI 9.6 ppg Brine.
Pump 10 bbl's Cw100 TIP lines to 4000 psi
Continue wI 30 bbl's total CW100 Followed b
y 20 bbl's MudPUSH @ 10.2 ppg followed by
47 bbl's 11.0 ppg LiteCRETE cmt down pipe.
Drop plug
Switch to rig pump and displace cmt to plug
catcher wI 9.6 ppg clear brinefluid. Bump pi
ug @ 0400 hrs 3/25/2002 wI 3500 psi Set ha
nger O.K Bleed off pressure. Pressure back
to 1000 psi Pull up released f/ liner. Cantin
ue pumping 2 bpm circulate out cmt long wa
y. Recover 6 bbl's cmt.
Set back into liner top packer setting total
string weight down need 29500 # sheared an
d set packer.
POOH LID 2-7/8" SWDP, Stand back 2-7/8"
DP LID Baker liner running tool.
TIP 5-1/2" csg and liner top packer wI 1500
psi for 30 min lost 42 psi O.K. Get ballmill r
eady to move.
M/U Baker FB 5-1/2" X 3" pkr wI 8.81' 3-1/2"
Mule shoed pup below. RIH slowly on 2-7/8
" DP. Tag liner top packer @ 4565' mule sho
e 6' inside line top P/U l' Set FB pkr wI 200
0 psi Top of 'K' anchor reciptical 4553'. Pull
ed 15K sheared out.
PJSM POOH LID 2-7/8" AOH dp. LID pkr sett
ing tool.
RIH wI 2-7/8" AOH dp fl derrick.
POOH LID 2-7/8" AOH dp
Complete pooh wI 2.875" AOH DP.
Pull wear bushing.
Set test plug & xo upper pipe rams to 3.5".
Test bope 300 psi low 13000 psi high. Pull
test plug & test it - Id same.
Ran LOT I Injection test. Injected @ .25 bp
m, tamation broke back @ 980 psi to 750 psi
Increased rate to .5 bpm, pressure increa
sed to 770 psi. SI & held 10 minutes, press
ure decreased to 580 psi and held.
PU I MU 3.5" baker seal assembly & rih wI s
Printed: 4/11/20D2 4:30:45 PM
,~
~
Legal Well Name:
Common Well Name:
Event Name:
CDntractor Name:
Rig Name:
2P-441
2P-441
ROT - DRILLING
NORDIC 3 n1433@ppco.cDm
Nordic 3
Start: 3/4/2002
Rig Release: 3/27/2002
Rig Number: 3
Spud Date: 3/5/2002
End: 3/27/2002
Group:
3/26/2002
09:30 - 10:00
10:00 - 11 :30
11 :30 - 17:00
17:00 - 19:00
0.50 CMPL TN RUNT CMPL TN
1.50 CMPL TN FRZP CMPL TN
5.50 CMPL TN RUNT CMPL TN
2.00 CMPL TN DEQT CMPL TN
19:00 - 19:30 0.50 CMPL TN NUND CMPLTN
19:30 - 22:30 3.00 CMPL TN NUND CMPL TN
22:30 - 00:00 1.50 CMPL TN NUND CMPL TN
3/27/2002 00:00 - 01 :00 1.00 CMPL TN NUND CMPL TN
01 :00 - 02:00 1.00 CMPL TN SEQT CMPL TN
02:00 - 05:00 3.00 CMPL TN FRZP CMPL TN
05:00 - 05:30
05:30 - 07:00
07:00 - 08:00
0.50 CMPL TN NUND CMPL TN
1.50 CMPLTN OTHR CMPLTN
1.00 CMPLTN OTHR CMPLTN
ame on 3.5" x 9.3 ppf x L-80 x 8 rd mod tbg
wI gas lift tools as per program. Incomplet
e @ end of this time block.
Freeze protect 7.625 x 5.5" annulus wI 31 b
bl diesel [1825' tvd] @ .9 bpm 11020 psi.
Hold pressure for 30 minutes I press fell to
750 psi, SI same wI 750 psi.
Continue to run 3.5" completion as per comp
letion program. Run a total of 141 its 3.5"
w. tools, & space out [2' above locator] wI
14.12' feet of pups, one full jt below hange
r. Observe seals entering PBR wI tbg si, rei
ease pressure & continue wI space out. Re
suits e-mailed to engineering -P Reilly.
Pressure tbg to 500 psi. Hold tbg pressure
& pressure 3.5 x 5.5 annulus to 3050 psi, tb
9 pressure increased to 600 psi, held same
for 30 minutes, no bleed down. Bleed off tb
g, shear valve sheared before tbg press @ ?
200 psi. Charted.
Set ck valve. Clean floor.
ND riser, remove lower pipe rams & nd bope
Nu adaptor flange & production tree, [incom
plete rpt time].
Continue to nu prod tree.
Complete nu tree. WI SSV open, test pack
off [void] to 5000 psi, & tree to 300 I 500 P
si 10 minutes each.
RU lines to freeze protect. Freeze protect t
bg I 3.5 x 5.5" annulus wI 50 bbl diesel. Pu
mp down annulus taking returns from tbg. M
anifold together via choke & allow to u-tube
into position to 0 psi [ 45 minutes].
Rd cir lines used for freeze protection. C
k tbg, tbg x 5.5 annulus @ 0 psi & 5.5 x 7.6
25" annulus @ 750 psi.
Set bpv, secure open valve ports on tree wI
caps I tapped blind flanges.
Rd handy berm for move, cellar box. Rig re
ady to move @ 0800 hrs. rig released @ 08
00 hrs.
Printed: 4/11/2002 4:30:45 PM
Date
03/29/02
03/30/02
04/01/02
04/02/02
04/03/02
~
.----...
2P-441 Event History
Comment
DRIFTED TBG WI 22' X 2.625" DUMMY GUN TO 7216' WLM. PULLED 1" SOV & SET DV @ 4429' RKB.
TESTED TBG 3000 PSI, IA TO 3000 PSI, OK. [PERF, TAG]
PERFORATE 6950-60' WI 2-1/2" HSD, 6 SPF, 60 DEG PHASED, 2506 HJ HDX CHARGES. HAD 1600 PSI
SITP FELL TO 1200 AND STABALIZED IMMEDIATELY, 0 PSI WHEN GUNS ARRIVED AT SURF. RIH FOR
SBHP.
PUMP FRAC USING 30# X-LINKED GEL AT 30 BPM. ENCOUNTERED HIGH TREATING PRESSURES
DURING JOB, SO REDUCED RATE IN 1 BPM INCREMENTS DOWN TO 27 BPM. SCREENED OUT WITH
7.9 PPA ON THE PERFS. PLACED 97,448 LBS OF 16/20 PROPPANT BEHIND PIPE.
JETTED OUT FILL TO 6980' CTM WI SEAWATER J313, 2# BIO SWEEPS, AND DIESEL. CHASED OOH,
THEN REV'D FILL TO 7082' CTM (EST. 140' OF RATHOLE) WI DIESEL. WELL LEFT SHUT IN AND FP'D WI
DIESEL TO 2500'+. [FCO]
TAGGED FILL @ 7071' RKB, UNABLE TO PULL DV'S @ 4429' & 3602' RKB, REPLACED DV @ 2083' RKB
WI OV [TAG, GLV]
Page 1 of 1
4/11/2002
.~
~
aOeJ.-O/í
Phillips Alaska, Inc.
Drill Site 2P
441
slot H41
Meltwater
North Slope, Alaska
SUR V E Y
LIS TIN G
by
Baker Hughes INTEQ
Your ref: MWD <0 - 7327' >
Our ref: svy6716
License:
Date printed: 27-Mar-2002
Date created: 7-Mar-2002
Last revised: 27-Mar-2002
Field is centred on 441964.235,5869891.466,999.00000,N
Structure is centred on 441964.235,5869891.466,999.00000, N
Slot location is n70 3 8.795,w150 27 2.548
Slot Grid coordinates are N 5868889.800, E 443679.200
Slot local coordinates are 988.66 S 1722.71 E
Projection type: alaska - Zone 4, Spheroid: Clarke - 1866
Reference North is True North
~
.--..
Phillips Alaska, Inc. SURVEY LISTING Page 1
Drill Site 2p,441 Your ref: MWD <0 - 7327'>
Meltwater,North Slope, Alaska Last revised: 27-Mar-2002
Measured Inclin Azimuth True Vert R E C TAN G U LA R Dogleg Vert G RID COO R D S
Depth Degrees Degrees Depth COO R DIN ATE S Deg/100ft Sect Easting Northing
0.00 0.00 0.00 0.00 O.OON O.OOE 0.00 0.00 443679.20 5868889.80
120.00 0.00 0.00 120.00 O.OON O.OOE 0.00 0.00 443679.20 5868889.80
197.97 0.18 290.73 197.97 0.04N O.llW 0.23 -0.02 4436.79.09 5868889.84
290.29 0.35 1.04 290.29 0.38N 0.25W 0.36 -0.31 443678.96 5868890.18
382.44 0.26 318.15 382.44 0.81N 0.38W 0.26 -0.70 443678.83 5868890.62
475.46 0.44 2.45 475.46 1.33N 0.50W 0.34 -1.17 443678.70 5868891.13
569.06 0.53 331.16 569.05 2.07N 0.70W 0.29 -1.84 443678.52 5868891. 87
659.87 0.26 33.74 659.86 2.61N 0.79W 0.52 -2.35 443678.43 5868892.41
752.84 1.05 132.17 752.83 2.21N 0.04W 1.20 -2.14 443679.18 5868892.01
845.16 1.76 131. 82 845.12 0.70N 1.65E 0.77 -1. 06 443680.85 5868890.48
935.19 2.37 189.13 935.10 2.06S 2.38E 2.28 1. 45 443681.56 5868887.72
1027.83 5.27 194.05 1027.52 8.08S 1. 04E 3.15 7.61 443680.18 5868881. 71
1117.18 8.96 190.53 1116.17 18.91S 1.23W 4.16 18.67 443677.83 5868870.90
1213.82 12.39 190.88 1211.12 36.49S 4.56W 3.55 36.54 443674.36 5868853.34
1308.65 14.06 192.64 1303.43 57.73S 9.00W 1.81 58.23 443669.76 5868832.15
1403.51 17.14 196.16 1394.79 82.405 15.41W 3.40 83.72 443663.16 5868807.53
1498.28 20.83 196.16 1484.39 112.015 23.99W 3.89 114.51 443654.36 5868777.99
1593.82 23.38 196.51 1572.90 146.515 34.11W 2.67 150.42 443643.98 5868743.57
1687.61 25.93 194.40 1658.13 184.225 44.50W 2.88 189.51 443633.30 5868705.95
1782.86 27.95 190.88 1743.05 226.315 53. 89W 2.70 232.64 443623.59 5868663.92
1876.54 30.50 191. 94 1824.80 271.14'5 62. 96W 2.78 278.34 443614.19 5868619.17
1972.34 32.08 192.99 1906.66 319.725 73. 71W 1. 74 328.09 443603.07 5868570.68
2066.95 34.45 195.10 1985.77 370.045 86.33W 2.79 379.97 443590.06 5868520.46
2160.66 37.88 196.51 2061.41 423.23S 101. 41W 3.77 435.21 443574.58 5868467.39
2255.53 41.31 196.86 2134.50 481.14S 118. 78W 3.62 495.58 443556.77 5868409.62
2349.43 44.21 194.05 2203.45 542.585 135.72W 3.70 559.28 443539.36 5868346.32
2444.19 44.56 194.05 2271.17 606.885 151.81W 0.37 625.56 443522.79 5868284.15
2539.91 44.65 194.40 2339.32 672.045 168.33W 0.27 692.77 443505.77 5868219.13
2559.74 44.74 194.40 2353.41 685.545 171.79W 0.45 706.72 443502.20 5868205.65
2630.78 44.38 193.70 2404.03 733.905 183.90W 0.86 756.56 443469.73 5868157.39
2726.17 45.09 193.35 2471. 79 799.175 199.60W 0.79 823.70 443473.54 5868092.25
2821. 93 45.44 193.35 2539.19 865.365 215.30W 0.37 891.72 443457.33 5868026.19
2917.78 45.70 193.35 2606.29 931. 965 231.11W 0.27 960.17 443441.02 5867959.72
3011.17 46.49 194.05 2671. 05 .997.335 247.05W 1.00 1027.45 443424.59 5867894.48
3105.07 45.70 192.99 2736.17 1063.105 262.87W 1.17 1095.10 443408.27 5867828.83
3200.09 44.12 191.59 2803.46 1128.645 277.16W 1. 96 1162.17 443393.48 5867763.41
3295.33 44.74 191. 94 2871.47 1193.915 290.75W 0.70 1228.80 443379.39 5867698.25
3390.98 43.86 190.53 2939.93 1259.435 303.77W 1. 38 1295.55 443365.87 5867632.84
3485.52 41.84 191.24 3009.24 1322.575 315.90W 2.20 1359.77 443353.26 5867569.81
3578.59 42.36 189.83 3078.29 1383.915 327. 31W 1.16 1422.07 443341. 39 5867508.56
3673.92 42.54 192.29 3148.64 1447.055 339.65W 1. 75 1486.34 443328.56 5867445.52
3769.56 42.28 192.99 3219.25 1509.98S 353. 77W 0.56 1550.84 443313.97 5867382.70
3864.46 42.36 194.40 3289.43 1572. 06S 368.89W 1. 00 1614.73 443298.37 5867320.75
3957.42 41.84 192.99 3358.40 1632.605 383. 65W 1.16 1677.04 443283.16 5867260.32
4052.91 41. 40 193.35 3429.79 1694.36S 398.10W 0.52 1740.47 443268.24 5867198.69
4149.31 41. 57 191. 94 3502.00 1756.675 412.08W 0.98 1804.31 443253.79 5867136.49
4242.18 42.89 192.29 3570.77 1817.695 425.18W 1. 44 1866.71 443240.22 5867075.58
4337.89 44.21 195.10 3640.14 1881.745 440.81W 2.45 1932.64 443224.11 5867011.65
4433.55 45.26 194.75 3708.09 1946.805 458.15W 1.13 1999.94 443206.28 5866946.74
4525.31 46.32 197.21 3772.08 2010.015 476.26W 2.24 2065.65 443187.68 5866883.67
All data in feet unless otherwise stated. Calculation uses minimum curvature method.
Coordinates from slot *441 and TVD from RKB: 254' (Nordic 3) (254.00 Ft above mean sea level).
Bottom hole distance is 3984.05 on azimuth 191.13 degrees from wellhead.
Vertical section is from wellhead on azimuth 193.58 degrees.
Grid is alaska - Zone 4.
Grid coordinates in FEET and computed using the Clarke - 1866 spheroid
Presented by Baker Hughes INTEQ
,~
~.
Phillips Alaska, Inc. SURVEY LISTING Page 2
Drill Site 2P,441 Your ref: MWD <0 - 7327'>
Meltwater,North Slope, Alaska Last revised: 27-Mar-2002
Measured Inclin Azimuth True Vert R E C TAN G U LA R Dogleg Vert G RID COO R D S
Depth Degrees Degrees Depth COO R DIN ATE S Deg/100ft Sect Easting Northing
4620.13 46.23 196.16 3837.62 2075.65S 495.94W 0.81 2134.07 443167.51 5866818.19
4783.17 46.05 192.29 3950.61 2189.565 524.82W 1.71 2251. 57 443137.76 5866704.51
4880.68 44.65 191. 94 4019.14 2257.385 539.38W 1.46 2320.92 443122.69 5866636.81
4975.52 43.33 191. 94 4087.37 2321.825 553. 01W 1.39 2386.76 443108.57 5866572.48
5069.53 40.96 189.40 4157.08 2383.795 564. 71W 3.10 2449.75 443096.39 5866510.61
5163.31 40.17 192.99 4228.33 2443.605 576.54W 2.63 2510.66 443084.12 5866450.90
5258.72 41.75 195.10 4300.38 2504.265 591.73W 2.20 2573.19 443068.46 5866390.36
5352.40 40.52 194.40 4370.93 2563.855 607. 42W 1. 40 2634.80 443052.32 5866330.89
5446.54 42.98 196.86 4441.17 2624.205 624. 34W 3.14 2697.43 443034.94 5866270.69
5540.46 45.79 197.56 4508.28 2686.945 643. 78W 3.04 2762.99 443015.02 5866208.10
5633.56 45.62 195.10 4573.30 2750.885 662.52W 1.90 2829.54 442995.80 5866144.31
5733.91 45.35 192.99 4643.66 2820.295 679.89W 1.52 2901. 08 442977.91 5866075.04
5829.45 47.64 193.35 4709.43 2887.765 695.68W 2.41 2970.37 442961. 60 5866007.70
5921.32 48.43 192.29 4770.86 2954.365 710.83W 1.21 3038.67 442945.95 5865941.22
6016.52 48.60 190.88 4833.93 3024.225 725.15W 1.12 3109;94 442931.10 5865871. 48
6112.02 44.74 189.48 4899.45 3092.585 737.45W 4.18 3179.28 442918.27 5865803.23
6208.22 43.95 188.77 4968.24 3158.975 748.12W 0.97 3246.31 442907.10 5865736.93
6301.49 42.63 185.61 5036.14 3222.405 756.14W 2.72 3309.85 442898.60 5865673.57
6395.13 42.10 184.91 5105.33 3285.235 761. 93W 0.76 3372.29 442892.33 5865610.79
6489.70 41. 66 187.02 5175.74 3348.015 768.48w 1. 56 3434.86 442885.30 5865548.06
6584.81 41.22 186.31 5247.04 3410.535 775. 79W 0.68 3497.35 442877.52 5865485.60
6680.82 41.57 185.61 5319.07 3473.685 782. 38W 0.60 3560.27 442870.45 5865422.52
6775.86 41.04 185.26 5390.46 3536.135 788.33W 0.61 3622.37 442864.03 5865360.12
6869.86 42.10 182.80 5460.79 3598.335 792.69W 2.07 3683.87 442859.19 5865297.96
6963.32 43.33 179.28 5529.47 3661. 705 793.82W 2.87 3745.73 442857.58 5865234.61
7058.62 43.86 175.42 5598.50 3727.325 790.77W 2.85 3808.80 442860.12 5865168.97
7152.35 43.42 174.71 5666.33 3791.76S 785.211'1 0.70 3870.13 442865.19 5865104.49
7248.74 42.45 171.20 5736.91 3856.915 777.181'1 2.68 3931.57 442872.73 5865039.30
7327.00 42.45 171.20 5794.66 3909.11S 769.101'1 0.00 3980.41 442880.41 5864987.04
All data in feet unless otherwise stated. Calculation uses minimum curvature method.
Coordinates from slot H41 and TVD from RKB: 254' (Nordic 3) (254.00 Ft above mean sea level) .
Bottom hole distance is 3984.05 on azimuth 191.13 degrees from wellhead.
Vertical section is from wellhead on azimuth 193.58 degrees.
Grid is alaska - Zone 4.
Grid coordinates in FEET and computed using the Clarke - 1866 spheroid
Presented by Baker Hughes INTEQ
~,
,~
Phillips Alaska, ¡nc.
Drill Site 2P,441
Meltwater,North Slope, Alaska
SURVEY LISTING Page 3
Your ref: MWD <0 - 7327'>
Last revised: 27-Mar-2002
Comments in wellpath
------------------
MD
TVD
Rectangular Coords.
Comment
-----------------------------------------------------------------------------------------------------------
7327.00
5794.66
3909.11S
769.1011
Projection to T.D.
Casing positions in string 'A'
========--------
Top MD
TOp TVD
Rectangular Coords.
Bot MD
Bot TVD
Rectangular Coords.
Casing
-----------------------------------------------------------------------------------------------------------
0.00
0.00
0.00
0.00
O. OON
O.OON
O.OOE
O.OOE
2593.00
4696.00
2377.07
3890.16
708.20S
2128.46S
177.5411
510.3411
7 5/8 CSG
3 1/2 CSG
Targets associated with this wellpath
---------------
< - -- --------
Target name
Geographic Location
T.V.D.
Rectangular Coordinates
Revised
-----------------------------------------------------------------------------------------------------------
MW(F) Midpt TGT Rvsd 442767.000,5865235.000,999.00
5504.00
3662.00S
884.4111
22-Feb-2001
/",
~
PHilliPS 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: crmalla@ppco.com
March 14, 2002
Cammy Oechsli Taylor, Chair
Alaska Oil and Gas Conservation Commission
333 West ih Avenue
Suite 100
Anchorage, Alaska 99501
(907) 279-1433
Re: 2P-441 Application for Sundry Approval (APD 202-017)
Dear Commissioner Taylor:
Phillips Alaska, Inc. hereby files this Application for Sundry Approval to top-set 5 W' casing above the
Bermuda interval. A diagram depicting the proposed changes is attached to this letter.
The planned tDp of cement will be 3052' MD (1000' above the C-37 interval). A stage tDDI will be placed
at +/- 2900' MD and will be opened and circulated with mud to ensure the C-80 interval is not covered by
the cement job. This will be done to preserve the ability to freeze protect the annulus with diesel and to
possibly use the annulus for cuttings disposal at a later date.
A 4 %" hole will be drilled beneath the 5 W' casing to the originally planned total depth and a 3 W' liner
will be cemented in place across the producing interval. A 3 W' tubing / gas lift completion will be used.
Attached are the revised cementing summary sheets for both the 5 W' long string and the 3 W' liner.
If you have any questions or require any further informatiDn, please contact Scott LDWry at 265-6869.
Sincerely,
(1~11~
Chuck Mallary ~
Drilling Engineering supeasor
RECEIVED
MAR 1 4 Z
Alaska Oil & Gas Cons. Commission
AnchOíage
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STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
1. Type of request:
AbandDn - Suspend -
Alter casing - Repair well-
Change approved program _X
2. Name of Operator
Phillips Alaska, Inc.
3. Address
P. O. Box 100360
Anchorage, AK 99510-0360
4. Location of well at surface
989' FNL, 1719' FWL, Sec. 17, T8N, R7E, UM
At top of productive interval
629' FSL, 822' FWL, Sec. 17, T8N, R7E, UM
At effective depth
At total depth
374' FSL, 760' FWL, Sec. 17, T8N, R7E, UM
12. Present well condition summary
Total depth: measured
true vertical
Effective depth:
measured
true vertical
4703
3895
4703
3895
Casing
Conductor
Surface
Intermediate
Length
110'
2593'
Size
16"
7.625"
Perforation depth:
measured
No Perforations
true vertical
No Perforations
Tubing (size, grade, and measured depth
No Tubing Run
Packers & SSSV (type & measured depth)
No Packers or SSSV"s
13. Attachments Description summary of proposal_X
14. Estimated date for commencing operation
March 14, 2002
16. If proposal was verbally approved
DperatiDnal shutdown -
Plugging -
Pull tubing-
5. Type of Well:
Development _X
Exploratory -
Stratigraphic -
Service -
(asp's: 443679, 5868890)
(as proposed)
(as proposed)
feet
feet
feet
feet
Plugs (measured)
Re-enter suspended well -
Time extensiDn - Stimulate -
Variance - Perforate-
6. Datum elevation (DF or KB feet)
RKB 254 feet AMSL
7. Unit or Property name
Dther -
Junk (measured)
Cemented
9 cu. Yds High Early
391 sx AS Lite, 202 sx LiteCrete
Kuparuk River Unit
8. Well number
2P-441
9. Permit number I approval number
202-017
10. API number
50-103-20407-00
11. Field I Pool
Kuparuk River Field / Meltwater Oil Pool
Measured Depth
110'
2593'
True vertical Depth
110'
2377'
RECEIVED
MAR 1 4 2002
Alaska Oil & Gas Cons. Commission
Anchorage
./
Detailed operations program -
15. Status of well classification as:
Schematic -
Oil-
Gas-
Suspended -
Name of approver Date approved Service -
17. I hereby certity that the foregoing i true and correct to the best of my knowledge. Questions? Call Scott Lowry 265-6869
Signed C, f, ' A/V Title: Drilling Engineering Supervisor Date ¡if lnf/AcJ, ].,00 z,...
c. Maffarv ¡)' FOR COMMISSION USE ONLY Prepared by Sharon Allsup-Drake
Conditions of approval: Notify Commission so representative may witness3-r;'òò\,,;, '~'-\"'\"~¡-\.. \Sù'p. -4s-\- .1 Approval no.
Plug integrity - BDP Test 'Á Location clearance - . C"\ {'\ .3 0;;;' - 0 if Þ
Mechanical Integrity Test - Original Signed !isequent form required 10- "4D '1 a~"ü'\:)-\-u.)oL l \
Cammy Oechsli 1: j/ ~
Approved by order of the Commission Commissioner Date c:Jj/s/or
Form 10-403 Rev 06/15/88 .
ORIGINAL
SUBMIT IN TRIPLICATE
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O.L PRINTING (907) 563-4743
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Sheet number
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Date I I
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159-5881
" 2P-441
Schlumberger
Preliminary Job Design based on limited input data. For estimate purposes only.
Rig: Nordic 3
Location: Meltwater
Client: Phillips Alaska, Inc.
Revision Date: 3/14/2002
Prepared by: Chris Avant
Location: Anchorage, AK
Phone: (907) 265-6067
Mobile: (907) 223-8808
email: CAvant@slb.com
Volume Calculations and Cement Systems
Volumes are based on 75% excess. Tail slurry is designed for 1651' shoe tack.
Tail Slurry Minimum thickening time: 120 min. (Pump time plus 90 min.)
15.8 ppg class G + 0.45%D065, 2.0 gps D600G, 0.2%D047 - 1.16 ft3/sk
(adjust to give desired thickening time)
0.0835 felft x 1651' x 1.75 (75% excess) =
0.1336 felft x 80' (ShDe Joint) =
241.3fe+10.7ft3=
252.0 fel 1.17 fe/sk = . /
Round up to 220 sks I¡
241.3 fe
10.7fe
252.0 fe
215.4 sks
Previous Csg.
< 75/8",29.7# casing
at 2,593' MD
BHST = 88°F, Estimated BHCT = 69°F.
(BHST calculated using a gradient of 2.3°F/1 00 ft. below the permafrost)
PUMP SCHEDULE
Pump Rate Stage Stage Time Cumulative
Stage (bpm) Volume (min) Time
(bbl) (min)
CW1 00
MudPUSH XL 6 50 8.3 8.3
Drop Bottom Plug 3.0 11.3
Tail Slurry 6 46 7.7 19.0
Drop Top Plug 3.0 22.0
Displacement 6 90 15.0 37.0
Slow Rate 3 20 6.7 43.7
< Top of Tail at
3,052' MD
MUD REMOVAL
< 5 1/2", 15.5# casing
in 6 3/4" OH
Recommended Mud Properties: 11.4 ppg, Pv < 15, T y < 15. As thin and light as possible
to aid in mud removal during cementing.
Spacer Properties: 12.5 ppg MudPUSH* XL, Pv '" 19-22, T y '" 22-29
Centralizers: RecDmmend 1 per joint across zones of interest for proper cement
placement.
TD at 4,703' MD
(3,892' TVD)
Mark of Schlumberger
. 2P-441
Preliminary Job Design based on limited input data. For estimate purposes only.
Rig: Nordic 3
Location: Meltwater
Client: Phillips Alaska, Inc.
Revision Date: 3/14/2002
Prepared by: Chris Avant
Location: Anchorage, AK
Phone: (907) 265-6067
Mobile: (907) 223-8808
email: CAvant@slb.com
Schlumberger
Volume Calculations and Cement Systems
Volumes are based on 50% excess. Displacement is calculated with a 2.9"-10.4# drill
string.
Tail Slurry Minimum thickening time: 130 min. (pump time plus 90 min.)
GasBLOK wI Class G + 3% D53, 2 gps D600G, 0.1 % 0800, 0.2% D047, 0.6% 0065 @
15.8 ppg - 1.2 ft3/sk
Top of Tail at
< 4,353' MD
Liner Cap:
0.1336 fe/ft x 200' x 1.00 (no excess) =
Liner Lap:
0.0668 fe/ft x (4703' - 4553') x 1.00 (no excess) =
Annular Volume:
0.0562 fe/ft x (7327' - 4703') x 1.50 (50% excess) =
Shoe Volume:
0.0488 fe/ft x 80' x 1.00 (nD excess) =
Totals:
26.7 fe + 10 fe + 221.2 fe + 3.9 fe =
261.8 ft31 1.2 fe/sk =
Round up to 220 sks ,,/
< Liner Top at /,
4,553' MD ¿;
26.7fe
10 ft3
221.2 fe
3.9fe
261.8 fe
218.2 sks
BHST = 132°F, Estimated BHCT = 113°F.
(BHST calculated using a gradient of 2.3°F/1 00 ft. below the permafrost)
Previous Csg.
51/2",15.5# casing
at 4,703' MD
PUMP SCHEDULE
Pump Rate Stage Stage Time Cumulative
Stage (bpm) Volume (min) Time
(bbl) (min)
CW100 3 30 10.0 10.0
MudPUSH XL 3 50 16.7 26.7
< 31/2",9.3# casing Tail Slurry 3 47 15.7 42.4
in 4 3/4" OH Drop Top Plug 3.0 45.4
Displacement 3 34 11.3 56.7
Slow Rate 2 10 5.0 61.7
MUD REMOVAL
Recommended Mud Properties: 9.8 ppg, Pv < 15, T y < 15. As thin and light as pDssible
to aid in mud removal during cementing.
Spacer Properties: 11.0 ppg MudPUSH* XL, Pv "" 19-22, T y "" 22-29
Centralizers: Recommend 1 per joint from 4553' MD to TD fDr proper cement placement.
TD at 7,327' MD
(5,774' TV D)
. Mark of Schlumberger
-,
-
~~~~I (IDJ !Æ~!Æ~~~!Æ I
~1#A.SJiA OIL AND GAS í
CONSERVATION COMMISSION /
TONY KNOWLES, GOVERNOR
333 W. 7'" 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 99510-0360
Re:
Kuparuk River Unit 2P-44l
Phillips Alaska, Inc.
Permit No: 202-017
Sur Loc: 989' FNL, 1719' FWL, Sec. 17, T8N,R7E, UM
Btmhole Loc. 374' FSL, 760' FWL, Sec. 17, T8N, R7E, 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 of drilling wastes will not be approved for this well until sufficient data is submitted to
ensure that the requirements of 20 MC 25.080 are met. Annular disposal of drilling waste will be
contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test
(FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission for approval on
form 10403 prior to the start of disposal operations.
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 Kuparuk River Unit 2P
must comply with the requirements and limitations of 20 MC 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.
Blowout prevention equipment (BOPE) must be tested in accordance with 20 MC 25035. Sufficient
notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a
test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission
petroleum field inspector on the North Slope pager at 659-3607.
Sincerely,
r ßA....~ ~. ~
CirIìñltPechsli TãyI6r
Chair
BY ORDER OF THE COMMISSION
DATED this 31st day of January, 2002
cc:
Department ofFish & Game, Habitat Section w/o encl.
Department of Environmental Conservation wlo encl.
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STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
20 MC 25.005
11 b. Type of well. Exploratory U Stratigraphic Test U
Service 0 Development Gas 0 Single Zone 0
5. Datum elevation (DF or KB)
RKB = 254 feet AMSL
6. Property DesignatiDn
ADL373112 ALK4998
Development Oil ~
Multiple Zone 0
10. Field and Pool
Kuparuk River Field
Meltwater Oil Pool
1a. Type of work: Drill ~ Redrill U
Re-entry []Deepen 0
2. Name of Operator
Phillips Alaska, Inc.
3. Address
P.O. Box 100360 Anchorage, AK 99510-0360
4. Location of well at surface
989' FNL, 1719' FWL, Sec. 17, T8N, R7E, UM
At tDp of productive interval
629' FSL, 822' FWL, Sec. 17, T8N, R7E, UM
At total depth
374' FSL, 760' FWL, Sec. 17, T8N, R7E, UM
12. Distance to nearest property line I 13. Distance tD nearest well
822' @ Target 2P-43849' @ 737.5
16. To be completed for deviated wells
KickDff depth: 700 MD
18. Casing program
size
7. Unit or property Name 11. Type BDnd (see 20 AAC 25.0251)
Kuparuk River Unit Statewide
8. Well number Number
2P-441 #59-52-180
9. Approximate spud date Amount
February 11, 2002 $200,000
14. Number of acres in property 15. Proposed depth (MD and TVD)
~ 5'<;;8"'5 .. 7327 I MD 15774 ' TVD
17. Anticipated pressure (see 20 AAC 25.~)(2))
Maximum surface 2224 psig At total depth (TVD) 2309 psig
Setting Depth
feet
Maximum hole angle
44
Top Bottom Quantity of Cement
MD TVD MD TVD (include stage data)
30' 30' 120' 120' 9 c/u yds High Early
30' 30' 2580' 2369' 300 sf( AS Lite, 170 sx LiteCrete
30' 30' 6418' 5122' 310 sX' Class G w/GasBlok
6418' 5122' 7327' 5774' included above
Specifications
Grade CDupling
H-40 welded
L-80 BTC ABmod
L-80 BTC ABmod
L-80 EUE8rd Moc
Length
90'
2550'
5888'
909'
Hole Casing Weight
42" 16" 62.5#
9.875" 7.625" 29.7#
6.75" 5.5" 15.5#
6.75" 3.5" 9.3#
19. TD be cDmpleted for Redrill, Re-entry, and Deepen DperatiDns.
Present well condition summary
Plugs (measured)
feet
feet
measured
true vertical
Total Depth:
Junk (measured)
feet
feet
measured
true vertical
Effective Depth:
True Vertical depth
Measured depth
Size
Cemented
Len9th
Casing
Conductor
Surface
Production
R€CË/I/ËD
JAN 9
.:;, 5 21712
Alaska Oil & G .. Ù
'as Cons. C '
Anchoré~ge ommlsSion
measured
PerforatiDn depth:
true vertical
20. Attachments Filing fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 0 Drilling program 0
Drilling fluid program 0Time vs depth plDt QefractiDn analysis OSeabed report 020 AAC 25.050 requirements 0
21. thereby certp:;tha1Je fore oing is t e correctto the best Df my knDwledge Questions? Call Pat Reilly 265-6048
Signed C L Title: Drilling Engineering Supervisor Date;J.~ t1A.- () 1-
c. Mallary prp.n::lrp.rl~:rnn AII.<:,m-Or::l/ff.
Commission Use Only
Permit Number , I API u be.r.,~ .. ./ . -'.. .1 Approvaldate .). I
2D2 -0/7 5 /D3--~ 2D7Û7~{;O \ ~, O~.
CDnditiDns of approval Samples required D Yes ~ No Mud log required .-
Hydrogen sulfide measures D Yes .~ No Directional survey required ~ Yes
Required wDrking pressure for BDPE 02M; D 3M; 0 5M; D 10M; 0 0
Other. Te~t ßoPE to ~ 000 p~t. \¡,J~A-.
~ee CDver letter
for Dther requirements
Yes hs:V ND
D No
by order of I
the commission Date '\ I
ORIGINAL
Original Signed By
Cðlhlny Ot:l.tr~
2) I /O.J--
Commissioner
Approved by
Submit in triplicate
Form 10-401 Rev. 12/1/85.
.~
Ap~tion for Permit to Drill, WeIl2P-441
Saved: 25-Jan-O2
Permit It - Meltwater 2P-441
Application for Permit to Drill Document
Mo)ximizE
W~II l/oll,I~
Table of Contents
1. Well Name .................................................................................................................3
Requirements of 20 AAC 25.005 (f)........................................................................................................3
2. Location Summary..... ............................ ..................... .............. ................. .............. 3
Requirements of 20 AAC 25.005(c)(2) """"""""""""""""""""""""""""""""""""""""".................3
Requirements of 20 AAC 25.050(b)........................................................................................................3
3. Blowout Prevention Equipment Information ......................................................... 4
Requirements of 20 AAC 25. 005(c) (3) """"""""""""""""""""""""""""""""""""""""'"................4
4. Drilling Hazards Information ...................................................................................4
Requirements of 20 AAC 25.005 (c)( 4) """""""" ......... """"""""" ............................... ............... ......... 4
5. Procedure for Conducting Formation Integrity Tests........................................... 4
Requirements of 20 AAC 25.005 (c)(5) ........ .............. ........... """""""""""'" ..... ............... .................... 4
6. Casing and Cementing Program............................................................................. 4
Requirements of 20 AAC 25. 005(c) (6) """"""""""""""""""""""""""""""""""""""""""""'"........4
7. Diverter System Information ...................................................................................5
Requirements of 20 AAC 25. 005(c)(7) .... ............ .......... ......... """""""""""" ....... ........ """"""" ........... 5
8. Drilling Fluid Program ............................................................................................. 5
Requirements of 20 AAC 25. 005( c)(B) .............. ............................. ........................ ........ ........ ................ 5
9. Abnormally Pressured Formation Information ...................................................... 6
Requirements of 20 AAC 25.005 (c)(9) ..... ............ ......... ...... ........... .......... """""""""'" ................. ....... 6
10. Seismic Analysis ......................................................................................................6
Requirements of 20 AAC 25.005 (c)(1 0) ....................... """""'" ................ ................. ........................... 6
11. Seabed Condition Analysis .....................................................................................6
Requirements of 20 AAC 25.005 (c)(11) """""""""""""""""""""""""""""""""""""""""""""""" 6
12. Evidence of Bonding ............................................................................................... 6
Requirements of 20 AAC 25.005 (c)(12) """""""""""""""""""""""""""""""""""""""""""""""" 6
441 PERMIT IT TEMPLATEdot
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Ap~tion for Permit to Drill, Well 2P-441
Saved: 25-Jan-O2
13. Proposed Drilling 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 AOGCC Form 10-401 (Front of permit package) ............................................................ 7
Attachment 2 Directional Plan ............................................................................................................... 7
Attachment 3 Drilling Hazards Summary............................................................................................... 7
Attachment 4 Well Schematic....... ................ ........... ....... ......... ..... .................. .... .........,... .......... ............ 7
Attachment 5 Cement Details ................................................................ ................................................ 7
441 PERMIT IT TEMPLATE-dot
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,~,
Ag~tion for Permit to Drill, WeIl2P-441
Saved: 25-Jan-O2
1. Well Name
Requirements of 20 AAC 25.005 (f)
Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission
under 20 MC 25.040(b). For a well with multiple well branche~ each branch must similarly be identified by a unique name and API
number by adding a suffix to the name de!>ignated for the well by the operator and to the number assigned to the well by the
commission.
,/
The well for which this Application is submitted will be designated as 2P-441.
2. Location Summary
Requirements of 20 AAC 25.005(c)(2)
An application for a Permit to Dnll must be accompanied by each of tIle following item~ except for 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 showing
(A)the coordinates of the proposed location of the well at the surfacc¡ at the top of each objective formation, and at total depth,
referenced to governmental section lines.
(B) the coordinates of the proposed location of the well at the surf¿,ce, referenced to the state plane cooldinate system for this
state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration'
(C) the proposed depth of the well at the top of each objective formation and at total depth/
Location at Surface
NGS Coordinates
Northings: 5868889.8
989' FNL, 1719' FWL, Sec 17, T8N, R7E, UM
I RKB Elevation: 254 ft AMSL
Eastings: 443679.2 Pad Elevation: 224 ft AMSL
Location at Top of
Productive Interval
(Bermuda Formation)
NGS Coordinates
Northings: 5865295.31
689' FSL, 837' FWL, Sec 17, T8N, R7E, UM
Eastings: 442782.05
Measured Depth (RKB feet):
True Vertical Depth (55 feet):
True Vertical Depth (RKB feet):
6861'
5186'
5440 '
Location at Total Depth
NGS Coordinates
Northings: 5864980.38 Eastings: 442703.45
374' FSL, 760' FWL, Sec 17, T8N, R7E, UM
Measured Depth (RKB feet): 7327 '
True Vertical Depth (55 feet): 5520 '
True Vertical Depth (RKB feet): 5774'
and
(D) other ¡¡lformation required by 20 MC 25.050(b);
Requirements of 20 AAC 25.050(b)
If a well is to be intentionally deviate~ the application for a Permit to Drill (Form 10-401) mU5.T
(1) ineiude a plat;. drawn to a suitable scale, showing the path of the propo.s-ed wellbore, ine/uding all adjacent wellbores within 200
feet of any poltion of the proposed well;
Please see Attachment 2: Directional Plan
and
(2) for all wells wIthin 200 feet of the proposed wel/bore
(A) list the names of the operators of those well~ to the extent that those names are known or discoverable in public record~
and show that each named operator has been furnished a copy of the application by certified mail; or
(B) state that the applicant is the only affected owner.
The Applicant is the only affected owner.
441 PERMIT IT TEMPLAT£'dot
IGINAL Page30f7
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Ap~tion for Permit to Drill, Well 2P-441
Saved: 25-Jan-O2
3. Blowout Prevention Equipment Information
Requirements of 20 AAC 25.005(c)(3)
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:
(3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 AAC 25.035, 20 AAC 25.036r or 20
AAC 25.037, as applicable/
Please refer to Nordic 3 BOP Schematic currently on file with the Commission.
4. Drilling Hazards Information
Requirements of 20 AAC 25.005 (c)(4)
An appiication 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:
(4) information on drilling hazardS¡ including
(A) the maximum downhole pressure that may be encounterect criteria used to determine it, and maximum potential surface
pressure based on a methane gradient/
The expected ~ervoir pressures in the Bermuda sands in the 2P pad area vary from 0.44 to 0.51 psi/ft,
or 8.5 to 9.7 ppg EMW (equivalent mud weight). These are pressures obtained from drilling and testing
operations on the nearby exploration wells, Meltwater North #1 and Meltwater North #2/2A, and on
development wells.
The maximum potential surface pressure (MPSP) based Dn the the above maximum pressure gradient, a
methane gradient (0.11) and the vertical depth of the expected base of the Bermuda formation is:
MPSP as a function of reservoir pressure
=(5559 ft TVD)(0.51 - 0.11 psi/ft)
= 2224 psi
Assuming a LOT / FIT of 16 ppg based on open hole results from the closest offset well, MEL1WATER 2P-
438,
MPSP as a function of LOT / FIT at the surface shoe (2369' TVD)
=( 16* .052*2369')-(2369*0.11)
=1710 psi. .,./
Therefore, the MPSP may be based on the reservoir pressure calculation of 2224 psi.
(B) data on potential gas zones,'
The CAIRN interval is expected from 6518' MD to 6647' MD (5194' TVD to 5287' TVD).
and
(C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones¡ and zones
that have a propensity for differential sticking/
Please see Attachment 3: Drilling Hazards Summary.
5. Procedure for Conducting Formation Integrity Tests
Requirements of 20 AAC 25.005 (c)(5)
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:
(5) a description of the procedure for conducting formation integnty tests¡ as required under 20 MC 25.030(f}/
A formation integrity test will be performed after drilling Dut below surface in accordance with the Phillips
Alaska LOT / FIT procedure, currently on file with the Commission.
6. Casing and Cementing Program
Requirements of 20 AAC 25.005(c)(6)
An application for a Permit to Drill must be acc.vmpanied by eaä! of the following items¡ except for an Item already on file with the
(vmmission and identitìed in the application:
441 PERMIT IT TEMPLATE. dot
0 RIG I N A L Printe:~Z~J::'~~
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A¡;>'"""o;;ation for Permit to Drill, Well 2P-441
Saved; 25-Jan-O2
(6) a complete proposed casing and cementing program as required by 20 MC 25.030; and a description of any slotted liner;. pre-
perforated liner;. or screen to be installed;'
Casing and Cementing Program
Hole Top atm
CsgITbg Size Weight Length MOrrvO MOrrvO
00 (in) (in) (lb/ft) Grade Connection (ft) (ft) (ft) Cement Program
30 X 16 42 62.5 H-40 Welded 80 30 I 30 110 I 110 9 cy High
Insulated Early
7518 9718 29.7 L-80 BTC AB 2550 30 I 30 2580 I 2369 300 sx 10.7
MOD ppg AS3 Lead,
170 sx 12 ppg
LiteCrete Tail
Planned Top of
Cement:
SURFACE
5112 6314 15.5 L-80 BTC AB 6388 30 I 30 6418 I 5122 310 sx 15.8
MOD ppg Class 'G'
3112 6314 9.3 L-80 8RND 909 6418 I 5122 7327 I 5774 Planned Top of
MOD Cement:
5918' MD
7. Diverter System Information
Requirements of 20 AAC 25.005(c)(7)
An application for a PermIt to Dlill must be accompanied by each of the following items¡ except for an Item already on file with the
commission and identified in the application:
(7) a diagram and description of the diverter system as required by 20 AAC 25.03~ unless this requirement is waived by the
commission under 20 MC 25.035(17)(2),'
Please refer Nordic 3 Diverter Schematic currently on file with the CDmmission.
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 the 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;
Water based drilling fluid systems will be utilized to drill this well from spud to TD. These systems will be
built and maintained to the following specifications:
Density (ppg)
Funnel Viscosity
(seconds)
Yield Point
(cP)
Plastic Viscostiy
(Ib/too sf)
10 second Gel
Strength (lb/100 sf)
10 minute Gel
Spud to 9-5/8"
Surface Casing
Initial Value Final Valu~
9.6 9.6 ¡-
50 80
35
13
45
23
15
10
15
40
.. m .. -- ..
Drill Out to Top Bermuda
Top Bermuda To Well TD
Initial Value Final Value _-Initial Value Final Valu~
9.6 9.6 >/ 9.6 9.6
50 65 50 65
15-20
8-18
3-6
4
18-25 20 30
10-18 6 14
4-9 4 7
8 4 8
441 PERMIT IT TEMPLATEdot
0 RIG I N A L Printe:~~~J;:'~~
r---.
A~ation for Permit to Drill, We1l2P-441
Saved: 25-Jan-O2
Strength (lb1100 sf)
pH
API Filtrate(cc)
9.5-10
<15
9.5-10
<6
9.0-9.5
<6
9.0-9.5
<6
7.5-8.5
8-10
7.5-8.5
8-10
Please refer to Nordic Rig 3 Fluid System Components currently Dn file with the Commission.
9. Abnormally Pressured Formation Information
Requirements of 20 AAC 25.005 (c)(9)
An application for a Pem¡it to Drill must be accompanied by each of the following item~ except for an item already on file with the
commis..<;ion and identified in the application:
(9) for an exploratory or stratigraphic test wel¿ a tabulation setting out the depths of predicted abnormally geo-pressured strata as
required by 20 MC 25.033(1),'
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 Permit to Drill mu",t be accompanied by each of the following item~ except for an item already on file with the
commission and identified in the application:
(10) for an exploratory or stratigraphic test wel¿ a seismic refraction or refiection analysis as required by 20 MC 25.061(a};
Not applicable: Application is not for an explDratory of 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
commission and Identified in the application:
(il) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vesse¿ an analysis
of seabed conditions as required by 20 MC 25. 061 (b);
Not applicable: Application is not for an offshore well.
12. Evidence of Bonding
Requirements of 20 AAC 25.005 (c)(12)
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:
(12) evidence showing that the requirements of 20 MC 25.025 {Bonding}have been met;
Evidence Df 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 item~ 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:
/ r'
1. Excavate cellar, install cellar box, set and cement 16" x 30" insulated conductor to +/- 110' RKB.
Weld landing ring on conductor. ./
2. Move in / rig up Nordic 3. Install diverter & function test same. /'
3. Spud and directionally drill 9 7/8" hole to 7 5/8" surface casing point (+/- 2580 MD') according to
directional plan. Run directional and gamma ray logging tools in drill string for directional monitoring
and fDrmation data gathering.
441 PERMIT IT TEMPLATEdot
0 IGINAL Page6of7
R. Printed: 25-Jan-O2
.-
AP-liçation for Permit to Drill, Well 2P-441
Saved: 25-Jan-O2
4. Run and cement 75/8" 29.7# L-80 BTC AB MOD casing to surface using ArcticSet 3 lead slurry and
LiteCrete tail to assure cement returns to the surface. Adequate tail cement will be pumped to
ensure cement reaches the surface. Displace cement with mud.
/
5. Nipple down diverter and install wellhead. Nipple up BOPE and test to 3000 psi. Record results.
/
6. Shut in BOP's and pressure test casing to 2500 psi for 30 minutes. Record results.
7. Drill out cement and 20' minimum to SO' maximum of new hole. Perform formation integrity test not
to exceed 16.0 ppg EMW.
./'
8. Directionally drill 6 3/4" hole to well total depth (+/- 7327' MD) according to directional plan. Run
directional, gamma ray, resistivity, and density/neutron logging tools in drill string for directional
monitoring and formation data gathering. Mud IDgging for quantitative GC analysis and sample
collection fDr cuttings description will take place on 2P-441. Circulate and condition hole. POOH.
9. Run open hole e-line o;:ßrill pipe conveyed logs as ne~d.
10. Run and cement 5 1/2" 15.5# L-80 BTC AB MOD x 3 1/29.3# L-80 8RND MOD tapered production
casing string with Baker casing seal receptacle crossover (CSR). Place CSR +/- 100' MD above the
planned top perforation.
11. Run and land 3 1/2" 9.3#, L-80, 8RND MOD tubing. Displace well to completion brine.
12. Pull landing joint. Install BPV. Nipple down BOP stack, and nipple up production tree. Pull BPV.
Install test plug. Pressure test production tree. Pull test plug. Secure well.
13. Freeze protect well. Set BPV. Release rig and turn well over to productiDn.
14. Clean location and RDMO in preparation for coiled tubing cleanout and perforating.
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 mastc be accompanied by each of the following items¡ except for an item already on file with the
commission and identified in the application:
(14) a general desctiption of how the operator plans to dispose ot' dnJling mud and cuttings and a statement of whether the
operator intends to request authorization under 20 MC 25.080 for an annular disposal operation ¡j¡ the well.;
"./
Waste fluids generated during the drilling process will be disposed of down a permitted annulus on 2P
pad or hauled to a Class II disposal well. All cuttings to be disposed of will be either disposed of down
the annulus or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for
disposal down an approved disposal well.
At the end of drilling operations, a request will be submitted for this well to be permitted for annular
pumping of fluids occurring as a result of future drilling operations on 2P pad.
15. Attachments
Attachment 1 ADGCC Form 10-401 (Front of permit package)
Attachment 2 Directional Plan
Attachment 3 Drilling Hazards Summary
Attachment 4 Well Schematic
Attachment 5 Cement Details
441 PERMIT IT TEMPLATEdot
0 RIG I N A l:rinte:;~~J~:-~~
,/'..
/'"""-"
më;;;;;db;h;;;¡~kmF~;P:Ïi~ïïïy
D'" pl,tt,d , 25-J,,-'OO,
I Plot R"","" If 20-'" V~I" ¡LD.
iC"""""""O"""'","""o"44'.
¡TN' V,nl,,' D,p"" '" ,,',,'"" ro'", 'obi..
I .11
ørILs
}~)h:~lli P s
---.---.
Alaska,
Inc.
Structure: Drill Site 2P
Field: Meltwater
Well: 441
Location: North Slope, Alaska
,....
~
400 -
! RKB Elevation: 254'
0 -
400 -
193.58 AZIMUTH
3767' (TO TARGET)
800 -
. KOP
. 2.00
. 4.00
6.00 OLS: 2.00 deg per 100 It
8.00
Build 3/100
15.00 Bose Permafrost
18.00
21.00 OLS: 3.00 deg per 100 It
24.00
27.00
30.00
33.00
Bose West Sok
39.00
EOC
7 5/8 CSG
C80
...Plone of Proposal'"
1200 -
C40
C37
1600 -
"""
....
~ 2000-
'+-
'-"
:E 2400-
0-
(l)
0
2800 -
0
0
C50
1:
(l)
>
(l)
:J
'-
I-
3200 -
3600 -
TANGENT ANGLE
44.17 DEG
I
V
4000 -
4400 -
T7
4800 -
5200 -
5 1/2 X 3 1/2 XD
T4.1 (Top Cairn)
13.1 (Bose Cairn)
13 (Top Bermuda)
T2 (Bose Bermuda)
C35 (Top Albion)
TO - Csg pt
MW(F) Midpt TGT Rvsd 22 Jon 01
5600 -
6000 -
6400
800
4000
4400
4800
400
800
1600
2000
2800
3200
3600
400
1200
2400
Vertical Section (feet) ->
Azimuth 193.58 with reference 0.00 N, 0.00 E from slot #441
~
5200
ORIGINAL
e"ot" by h"oti" For P. Reilly
Dot, plott,' , 25-Jo"-2DD2
Plot R,t"",," 2P-441 V..,;O" ¡1.D.
e"","ot.. '" '" toot "t..,"" "ot 144f.
'" V,"kol D,pth, '" "t..,"" "tory tobl"
mil
~
~
~
Phillips
Structure: Drill Site 2P
Field: Meltwater
Alaska,
Ine
Well: 441
Location: North Slope, Alaska
2000
1750
1500
193.58 AZIMUTH
3767' (TO TARGET)
"'Plone of Proposal...
~
<f
TRUE
I TOP BERMUDA I
LOCATION
689' FSL, 837' FWL
SEC. 17. T8N, R7E
I TARGET LOCATION I
629' FSL, 822' FWL
SEC. 17, T8N, R7E
I TO LOCATION I
374' FSL. 760' FWL
SEC. 17, T8N, R7E
<- West (feet)
1250
750
500
250
250
1000
I ESTIMATED SURFACE I
LOCATION,
989' FNL, 1719' FWL
SEe. 17, T8N, R7E
KOP
Build 3/100
Bose Permafrost
~
IPHILLlP~
500
750
250
- 0
- 250
- 500
- 750
- 1000
- 1250
- 1500
(/)
0
- 1750 C
-+
:::¡-
r--,
- 2000 -+,
<D
~
"--'
- 2250 I
V
- 2500
- 2750
- 3000
- 3250
- 3500
- 3750
- 4000
- 4250
ORIGINAL
..----'.
~
Philli
s
Alaska,
Inc.
~
C",t,d by ""ot'ok
Doto plottod
PI., Ro"""" ;, 2P-441 Vo~;." I!.D.
C..,"oo"""'"'"',,',,,",,,'oll44!.
Vort"" Dopth, '" """000 ..tooy
1!Rt!!
.......
.....-
TNTF.Q
Structure: Drill Site 2P
Field: Meltwater
Well: 441
Location: North
TRUE NORTH
<:?-
=
~ 350 0 ~ 10
34 \ 20m~
330 210 30
~ 320 40
310 50
300 60
290 70
280 80
270
90
260 100
110
240 120
230 130
,,1300
220 2100~ 40
/
/ 210 150
ø'500 "~o
",," r!J 1900
t 160 "',
,
180 170
Normal Plane Travelling Cylinder - Feet
All depths shown are Measured depths on Reference Well
ORIGINAL
C'eated by hnaUuk For P. Reilly
Date platted: 25-Jan-2002
Plat Refe,enee Is 2P-441 Version #1.0.
Coo,dlnat" are In feet refe,enee slot #441.
Vertical Depths a,e reference ,alacy
l1li.1111
BAIlER
~
INTEQ
P hi IIi
Alaska,
Inc.
<'PHI~LlPS\
s
Well: 441
Location: North
Alaska
Structure: Drill Site 2P
Field: Meltwater
~=~~ PROF~LE COMMENT DATA ===~
----- Point ----- MD Inc Dir TVD North East V. Sect Oe9/100 ')
KOP 700.00 0.00 193.58 700.00 0.00 0.00 0.00 0.00
Build 3/100 1200.00 10.00 193.58 1197.47 -42.31 -10.22 43.52 2.00
Base Permafrost 1360.32 14.81 193.58 1354.00 -75.77 -18.30 77.95 3.00
Base West Sak 2024.47 34.73 193.58 1954.00 -344.92 -83.30 354.83 3.00
EOC 2338.96 44.17 193.58 2196.56 -538.95 -130.16 554.44 3.00
7 5/8 CSG 2579.74 44.17 193.58 2369.27 - 702.03 -169.55 722.21 0.00
C80 2679.74 44.17 193.58 2441.00 - 769.76 -185.90 791.89 0.00
C50 3425.60 44.17 193.58 2976.00 -1274.93 -307.91 1311.59 0.00
C40 3818.75 44.17 193.58 3258.00 -1541.21 -372.22 1585.52 0.00
C37 4051.57 44.17 193.58 3425.00 -1698.90 -410.30 1747.74 0.00
T7 5705.01 44.17 193.58 4611.00 -2818.78 -680.76 2899.82 0.001 )
5 1/2 X 3 1/2 XO 6417.79 44.17 193.58 5122.27 -3301 .55 - 797 .35 3396.47 0.00
T4.1 (Top Cairn) 651 7.79 44.17 193.58 5194.00 -3369.28 -813.71 3466.15 0.00
<:::> 113.1 (Base Cairn) 6647.45 44.17 193.58 5287.00 -3457.10 -834.92 3556.49 0.00
::r::J 113 (Top Bermuda) 6860.75 44.17 193.58 5440.00 -3601.57 -869.81 3705.11 0.00
-- ¡MW(F) Midpt TGT Rvsd
{;'"') 6949.97 44.17 193.58 5504.00 -3662.00 -884.41 3767.28 0.00
-- i12 (Base Bermuda) 7026.65 44.17 193.58 5559.00 -3713.93 -896.95 3820.71 0.00
<:::
::t::=. Ic35 (Top Albian) 7207.89 44.17 193.58 5689.00 -3836.68 -926.59 3946.99 0.00
r--
~
.~
Phillips Alaska, Inc.
Drill Site 2P
441
slot #441
Meltwater
North Slope, Alaska
PRO PO SA L
LIS TIN G
by
Baker Hughes INTEQ
Your ref: 2P-441 Version #l.D
Our ref: prop4485
License:
Date printed: 25-Jan-2002
Date created: 23-Feb-2001
Last revised: 25-Jan-2002
Field is centred on 441964.235,5869891.466,999.00000,N
Structure is centred on 441964.235,5869891.466,999.00000,N
Slot location is n70 3 8.795,w150 27 2.548
Slot Grid coordinates are N 5868889.800, E 443679.200
Slot local coordinates are 988.66 S 1722.71 E
Projection type: alaska - Zone 4, Spheroid: Clarke - 1866
Reference North is True North
ORIGINAL
,,--.. .
Phillips Alaska, Inc.
Drill Site 2P,441
Meltwater,North Slope, Alaska
Measured Inclin. Azimuth True Vert
Depth Degrees Degrees Depth
0.00
100.00
200.00
300.00
400.00
500.00
600.00
700.00
800.00
900.00
1000.00
1100.00
1200.00
1266.67
1360.32
1366.67
1466.67
1566.67
1666.67
1766.67
1866.67
1966.67
2024.47
2066.67
2166.67
2266.67
2338.96
2500.00
2579.74
2679.74
3000.00
3425.60
3500.00
3818.75
4000.00
4051.57
4500.00
5000.00
5500.00
5705.01
6000.00
6417.79
6500.00
6517.79
6647.45
6860.75
6949.97
7000.00
7026.65
7207.89
6.00
8.00
10.00
12.00
14.81
15.00
18.00
21. 00
24.00
27.00
30.00
33.00
34.73
36.00
39.00
42.00
44.17
44.17
44.17
44.17
44.17
44.17
44.17
44.17
44.17
44.17
44.17
44.17
44.17
44.17
44.17
44.17
44.17
44.17
44.17
44.17
44.17
44.17
44.17
44.17
0.00
0.00
0.00
0.00
0.00
0.00
193.58
193.58
193.58
193.58
0.00
0.00
0.00
2.00
4.00
193.58
193.58
193.58
193.58
193.58
193.58
193.58
193.58
193.58
193.58
193.58
193.58
193.58
193.58
193.58
193.58
193.58
193.58
193.58
193.58
193.58
193.58
193.58
193.58
193.58
193.58
193.58
193.58
193.58
193.58
193.58
193.58
193.58
193.58
193.58
193.58
193.58
193.58
193.58
193.58
193.58
193.58
193.58
193.58
193.58
0.00
100.00
200.00
300.00
400.00
500.00
600.00
700.00
799.98
899.84
999.45
1098.70
1197.47
1262.90
1354.00
1360.13
1456.00
1550.25
1642.63
1732.88
1820.75
1906.01
1954.00
1988.41
2067.74
2143.77
2196.56
2312.08
2369.27
2441. 00
2670.72
2976.00
3029.37
3258.00
3388.01
3425.00
3746.66
4105.30
4463.95
4611.00
4822.59
5122.27
5181. 24
5194.00
5287.00
5440.00
5504.00
5539.88
5559.00
5689.00
R E C TAN G U L A R
COO R DIN ATE S
0.00 N
0.00 N
0.00 N
0.00 N
0.00 N
0.00 N
0.00 N
0.00 N
1.70 S
6.78 S
15.26 S
27 .10 S
42.31 S
54.67 S
75.77 8
77.36 S
104.97 S
137.418
174.60 S
216.45 S
262.82 S
313.61 S
344.92 S
368.66 S
427.83 S
490.95 S
538.95 S
648.02 8
702.03 S
769.76 S
986.67 S
1274.93 S
1325.32 S
1541.21 S
1663.97 S
1698.90 S
2002.63 S
2341.28 S
2679.93 S
2818.78 S
3018.58 S
3301.55 S
3357.23 S
3369.28 S
3457.10 S
3601.57 S
3662.00 S
3695.88 S
3713.93 S
3836.68 S
0.00 E
0.00 E
0.00 E
0.00 E
0.00 E
0.00 E
0.00 E
0.00 E
0.41 W
1. 64 W
3.68 W
6.54 W
10.22 W
13.20 W
18.30 W
18.68 W
25.35 W
33.18 W
42.17 W
52.27 W
63.47 W
75.74 W
83.30 W
89.03 W
103.32 W
118.57 W
130.16 W
156.50 W
169.55 W
185.90 W
238.29 W
307.91 W
320.08 W
372.22 W
401. 87 W
410.30 W
483.65 W
565.44 W
647.23 W
680.76 W
729.01 W
797.35 W
810.80 W
813 . 71 W
834.92 W
869.81 W
884.41 W
892.59 W
896.95 W
926.59 W
Dogleg
Deg/l00ft
~
PROPOSAL LISTING Page 1
Your ref: 2P-441 Version #1.D
Last revised: 25-Jan-2002
Vert
8ect
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
2.00
2.00
0.00
0.00
0.00 KOP
1. 75
6.98
2.00
2.00
2.00
3.00
3.00
15.69
27.88
43.52
56.24
77.95
Base Permafrost
Build 3/100
3.00
3.00
3.00
3.00
3.00
79.58
107.98
141.36
179.62
222.67
3.00
3.00
3.00
3.00
3.00
270.38
322.62
354.83
379.26
440.13
Base West Sak
3.00
3.00
0.00
0.00
0.00
505.06
554.44 EOC
666.65
722.21 7 5/8 CSG
791.89 C80
0.00
0.00
0.00
0.00
0.00
1015.04
1311. 59 C50
1363.43
1585.52 C40
1711. 81
0.00
0.00
0.00
0.00
0.00
1747.74 C37
2060.20
2408.59
2756.98
2899.82 T7
0.00
0.00
0.00
0.00
0.00
3105.36
3396.47 5 1/2 X 3 1/2 XO
3453.75
3466.15 T4.1 (Top Cairn)
3556.49 T3.1 (Base Cairn)
0.00
0.00
0.00
0.00
0.00
T3 (Top Bermuda)
MW(F) Midpt TGT Rvsd 22 Jan 01
3705.11
3767.28
3802.14
3820.71
3946.99
T2 (Base Bermuda)
C35 (Top Albian)
All data is in feet unless otherwise stated.
Coordinates from slot #441 and TVD from rotary table (254.00 Ft above mean sea level).
Bottom hole distance is 4029.74 on azimuth 193.58 degrees from wellhead.
Total Dogleg for wellpath is 44.17 degrees.
Vertical section is from wellhead on azimuth 193.58 degrees.
Calculation uses the minimum curvature method.
Presented by Baker Hughes INTEQ
ORIGINAL
""-"""
.....-:..
Phillips Alaska, Inc.
Drill Site 2P,441
Meltwater,North Slope, Alaska
PROPOSAL LISTING Page 2
Your ref: 2P-441 Version #l.D
Last revised: 25-Jan-2002
Measured Inclin. Azimuth True Vert
Depth Degrees Degrees Depth
R E C TAN G U L A R
COO R DIN ATE S
Dogleg
Deg/100ft
Vert
Sect
7326.65
44.17
193.58
5774.19
3917.12 S
946.02 W
0.00
4029.74 TD - Csg pt
All data is in feet unless otherwise stated.
Coordinates from slot #441 and TVD from rotary table (254.00 Ft above mean sea level).
Bottom hole distance is 4029.74 on azimuth 193.58 degrees from wellhead.
Total Dogleg for wellpath is 44.17 degrees.
Vertical section is from wellhead on azimuth 193.58 degrees.
Calculation uses the minimum curvature method.
Presented by Baker Hughes INTEQ
ORIGINAL
/'-0.,
--\
Phillips Alaska, Inc.
Drill Site 2P,44l
Meltwater,North Slope, Alaska
PROPOSAL LISTING Page 3
Your ref: 2P-44l Version #l.D
Last revised: 25-Jan-2002
Comments in wellpath
--------------------
--------------------
MD
TVD
Rectangular Coords.
Comment
-----------------------------------------------------------------------------------------------------------
700.00 700.00 0.00 N 0.00 E KOP
1200.00 1197.47 42.31 S 10.22 W Build 3/100
1360.32 1354.00 75.77 S 18.30 W Base Permafrost
2024.47 1954.00 344.92 S 83.30 W Base West Sak
2338.96 2196.56 538.95 S 130.16 W EOC
2579.74 2369.27 702.03 S 169.55 W 7 5/8 CSG
2679.74 2441.00 769.76 S 185.90 W C80
3425.60 2976.00 1274.93 S 307.91 W C50
3818.75 3258.00 1541. 21 S 372.22 W C40
4051. 57 3425.00 1698.90 S 410.30 W C37
5705.01 4611. 00 2818.78 S 680.76 W T7
6417.79 5122.27 3301. 55 S 797.35 W 5 1/2 X 3 1/2 XO
6517.79 5194.00 3369.28 S 813 .71 W T4.1 (Top Cairn)
6647.45 5287.00 3457.10 S 834.92 W T3.1 (Base Cairn)
6860.75 5440.00 3601.57 S 869.81 W T3 (Top Bermuda)
6949.97 5504.00 3662.00 S 884.41 W MW(F) Midpt TGT Rvsd 22 Jan 01
7026.65 5559.00 3713.93 S 896.95 W T2 (Base Bermuda)
7207.89 5689.00 3836.68 S 926.59 W C35 (Top Albian)
7326.65 5774.19 3917.12 S 946.02 W TD - Csg pt
Casing positions in string 'A'
------------------------------
------------------------------
Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing
-----------------------------------------------------------------------------------------------------------
0.00
0.00
0.00
0.00
O.OON
O.OON
O.OOE
O.OOE
7326.65
2579.74
5774.19
2369.27
3917.12S
702.03S
946.02W
169.55W
3 1/2 CSG
7 5/8 CSG
Targets associated with this wellpath
-------------------------------------
-------------------------------------
Target name
Geographic Location
T.V.D.
Rectangular Coordinates
Revised
-----------------------------------------------------------------------------------------------------------
MW(F) Midpt TGT Rvsd 442767.000,5865235.000,999.00
5504.00
3662.00S
884.41W
22-Feb-2001
ORIGINAL
,,-....,
Phillips Alaska, Inc.
Drill Site 2P
441
slot #441
Meltwater
North Slope, Alaska
PROPOSAL LISTING
by
Baker Hughes INTEQ
Your ref: 2P-44l Version H.D
Our ref: prop4485
License:
Date printed: 25-Jan-2002
Date created: 23-Feb-200l
Last revised: 25-Jan-2002
Field is centred on 441964.235,5869891. 466,999.00000, N
Structure is centred on 441964.235,5869891. 466,999.00000, N
Slot location is n70 3 8.795,w150 27 2.548
Slot Grid coordinates are N 5868889.800, E 443679.200
Slot local coordinates are 988.66 S 1722.71 E
Projection type: alaska - Zone 4, Spheroid: Clarke - 1866
Reference North is True North
~
ORIGINAL
¡-..
"'-""'\
Phillips Alaska. Inc. PROPO5AL LI5TING Page 1
Drill 5ite 2P, 441 Your ref : 2P-441 Version U.D
Me1twater,North 51ope, Alaska Last revised : 25-Jan-2002
Measured Inclin Azimuth True Vert RECTANGULAR G RID COORD5 G EO G RAPHIC
Depth Degrees Degrees Depth COORDINATE5 Easting Northing COO R DINATE5
0.00 0.00 0.00 0.00 O.OON O.OOE 443679.20 5868889.80 n70 3 08.79 w150 27 02.55
100.00 0.00 193.58 100.00 O.OON O.OOE 443679.20 5868889.80 n70 3 08.79 w150 27 02.55
200.00 0.00 193.58 200.00 O.OON O.OOE 443679.20 5868889.80 n70 3 08.79 w150 27 02.55
300.00 0.00 193.58 300.00 O.OON O.OOE 443679.20 5868889.80 n70 3 08.79 w150 27 02.55
400.00 0.00 193.58 400.00 O.OON O.OOE 443679.20 5868889.80 n70 3 08.79 w150 27 02.55
500.00 0.00 193.58 500.00 O.OON O.OOE 443679.20 5868889.80 n70 3 08.79 w150 27 02.55
600.00 0.00 193.58 600.00 O.OON O. OOE 443679.20 5868889.80 n70 3 08.79 w150 27 02.55
700.00 0.00 193.58 700.00 O.OON O. OOE 443679.20 5868889.80 n70 3 08.79 w150 27 02.55
800.00 2.00 193.58 799.98 1. 705 0.41W 443678.78 5868888.11 n70 3 08.78 w150 27 02.56
900.00 4.00 193.58 899.84 6.785 1.64W 443677.51 5868883.03 n70 3 08.73 w150 27 02.59
1000.00 6.00 193.58 999.45 15.265 3.68W 443675.40 5868874.57 n70 3 08.64 w150 27 02.65
1100.00 8.00 193.58 1098.70 27.105 6.54W 443672.45 5868862.75 n70 3 08.53 w150 27 02.74
1200.00 10.00 193.58 1197.47 42.315 10.22W 443668.66 5868847.58 n70 3 08.38 w150 27 02.84
1266.67 12.00 193.58 1262.90 54.675 13. 20W 443665.58 5868835.24 n70 3 08.26 w150 27 02.93
1360.32 14.81 193.58 1354.00 75.775 18.30W 443660.33 5868814 .17 n70 3 08.05 w150 27 03.08
1366.67 15.00 193.58 1360.13 77.365 18. 68W 443659.93 5868812.59 n70 3 08.03 w150 27 03.09
1466.67 18.00 193.58 1456.00 104.975 25.35W 443653.05 5868785.04 n70 3 07.76 w150 27 03.28
1566.67 21. 00 193.58 1550.25 137.415 33.18W 443644.97 5868752.66 n70 3 07.44 w150 27 03.50
1666.67 24.00 193.58 1642.63 174.605 42.17W 443635.71 5868715.54 n70 3 07.08 w150 27 03.76
1766.67 27.00 193.58 1732.88 216.455 52.27W 443625.28 5868673.78 n70 3 06.67 w150 27 04.05
1866.67 30.00 193.58 1820.75 262.825 63.47W 443613.73 5868627.49 n70 3 06.21 w150 27 04.38
1966.67 33.00 193.58 1906.01 313.615 75. 74W 443601. 08 5868576.81 n70 3 05.71 w150 27 04.73
2024.47 34.73 193.58 1954.00 344.925 83.30W 443593.28 5868545.56 n70 3 05.40 w150 27 04.95
2066.67 36.00 193.58 1988.41 368.665 89.03W 443587.37 5868521.87 n70 3 05.17 w150 27 05.11
2166.67 39.00 193 .58 2067.74 427.835 103.32W 443572.63 5868462.81 n70 3 04.59 w150 27 05.53
2266.67 42.00 193.58 2143.77 490.955 118.57W 443556.91 5868399.81 n70 3 03.97 w150 27 05.97
2338.96 44.17 193.58 2196.56 538.955 130.16W 443544.95 5868351. 91 n70 3 03.49 w150 27 06.30
2500.00 44.17 193.58 2312.08 648.025 156. 50W 443517.78 5868243.05 n70 3 02.42 w150 27 07.06
2579.74 44.17 193.58 2369.27 702.035 169.55W 443504.33 5868189.15 n70 3 01. 89 w150 27 07.44
2679.74 44.17 193.58 2441. 00 769.765 185. 90W 443487.45 5868121.55 n70 3 01.22 w150 27 07.91
3000.00 44.17 193.58 2670.72 986.675 238.29W 443433.42 5867905.07 n70 2 59.09 w150 27 09.42
3425.60 44.17 193.58 2976.00 1274.935 307. 91W 443361.62 5867617.37 n70 2 56.26 w150 27 11. 42
3500.00 44.17 193.58 3029.37 1325.325 320.08W 443349.06 5867567.08 n70 2 55.76 w150 27 11.77
3818.75 44.17 193.58 3258.00 1541. 215 372 .22W 443295.29 5867351.62 n70 2 53.64 w150 27 13.28
4000.00 44.17 193.58 3388.01 1663.975 401.87W 443264.71 5867229.10 n70 2 52.43 w150 27 14.13
4051. 57 44.17 193.58 3425.00 1698.905 410.30W 443256.01 5867194.24 n70 2 52.09 w150 27 14.38
4500.00 44.17 193.58 3746.66 2002.635 483. 65W 443180.35 5866891.11 n70 2 49.10 w150 27 16.49
5000.00 44.17 193.58 4105.30 2341.285 565.44W 443095.99 5866553.13 n70 2 45.77 w150 27 18.85
5500.00 44.17 193.58 4463.95 2679.935 647.23W 443011.63 5866215.14 n70 2 42.44 w150 27 21.20
5705.01 44.17 193.58 4611.00 2818.785 680.76W 442977.04 5866076.56 n70 2 41. 07 w150 27 22.17
6000.00 44.17 193.58 4822.59 3018.585 729. 01W 442927.28 5865877 .16 n70 2 39.11 w150 27 23.56
6417.79 44.17 193.58 5122.27 3301. 555 797.35W 442856.79 5865594.74 n70 2 36.32 w150 27 25.53
6500.00 44.17 193.58 5181.24 3357.235 810. 80W 442842.92 5865539.17 n70 2 35.78 w150 27 25.92
6517.79 44.17 193.58 5194.00 3369.285 813.71w 442839.92 5865527.14 n70 2 35.66 w150 27 26.00
6647.45 44.17 193.58 5287.00 3457.105 834. 92W 442818.04 5865439.50 n70 234.79 w150 27 26.61
6860.75 44.17 193.58 5440.00 3601. 575 869. 81W 442782.05 5865295.31 n70 233.37 w150 27 27.62
6949.97 44.17 193.58 5504.00 3662.005 884.41W 442767.00 5865235.00 n70 232.78 w150 27 28.04
7000.00 44.17 193.58 5539.88 3695.885 892. 59w 442758.56 5865201.18 n70 2 32.45 w150 27 28.27
7026.65 44.17 193.58 5559.00 3713.935 896. 95W 442754.06 5865183.17 n70 2 32.27 w150 27 28.40
7207.89 44.17 193.58 5689.00 3836.685 926. 59w 442723.49 5865060.66 n70 2 31.06 w150 27 29.25
All data in feet unless otherwise stated. Calculation uses minimum curvature method.
Coordinates from slot *441 and TVD from rotary table (254.00 Ft above mean sea level).
Bottom hole distance is 4029.74 on azimuth 193.58 degrees from wellhead.
Total Dogleg for we11path is 44.17 degrees.
Vertical section is from wellhead on azimuth 193.58 degrees.
Grid is alaska - Zone 4.
Grid coordinates in FEET and computed using the Clarke - 1866 spheroid
Presented by Baker Hughes INTEQ
ORIGINAL
,~
~.
Phillips Alaska, Inc.
Drill Site 2P.44l
Meltwater,North Slope, Alaska
PROPOSAL LISTING Page 2
Your ref, 2P-44l Version U. D
Last revised, 25-Jan-2002
Measured Inclin Azimuth True Vert
Depth Degrees Degrees Depth
RECTANGULAR
COORDINATES
GRID COORDS
Easting Northing
GEOGRAPHIC
COORDINATES
7326.65
44.17
193.58
5774.19
3917.l2S
946. 02W
442703.45
5864980.38
n70
2 30.27
w150 27 29.81
All data in feet unless otherwise stated. Calculation uses minimum curvature method.
Coordinates from slot #441 and TVD from rotary table (254.00 Ft above mean sea level).
Bottom hole distance is 4029.74 on azimuth 193.58 degrees from wellhead.
Total Dogleg for wellpath is 44.17 degrees.
Vertical section is from wellhead on azimuth 193.58 degrees.
Grid is alaska - Zone 4.
Grid coordinates in FEET and computed using the Clarke - 1866 spheroid
Presented by Baker Hughes INTEQ
ORIGINAL
,...........
Phillips Alaska, Inc.
Drill Site 2P, 441
Meltwater,North Slope, Alaska
~.
PROPOSAL LISTING Page 3
Your ref: 2P-441 Version n. D
Last revised: 25-Jan-2002
Comments in wellpath
--------------------
--------------------
MD
Rectangular Coords.
Comment
- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - --
TVD
700.00 700.00 O.OON O.OOE KOP
1200.00 1197.47 42.31S 10.22W Build 3/100
1360.32 1354.00 75. 77S 18.30W Base Permafrost
2024.47 1954.00 344.92S 83.30W Base West Sak
2338.96 2196.56 538.95S 130.16W EOC
2579.74 2369.27 702.03S 169. 55W 7 5/8 CSG
2679.74 2441.00 769. 76S 185. 90W C80
3425.60 2976.00 1274.93S 307. 91W C50
3818.75 3258.00 1541. 21S 372.22W C40
4051. 57 3425.00 1698.90S 410.30W C37
5705.01 4611.00 2818.78S 680.76W T7
6417.79 5122.27 3301. 55S 797.35W 5 1/2 X 3 1/2 XO
6517.79 5194.00 3369.28S 813. 71W T4.1 (Top Cairn)
6647.45 5287.00 3457.10S 834.92W T3.1 (Base Cairn)
6860.75 5440.00 3601. 57S 869.81W T3 (Top Bermuda)
6949.97 5504.00 3662. OOS 884. 41W MW(F) Midpt TGT Rvsd 22 Jan 01
7026.65 5559.00 3713.93S 896. 95W T2 (Base Bermuda)
7207.89 5689.00 3836.68S 926. 59W C35 (Top Albian)
7326.65 5774.19 3917.12S 946.02W TD - Csg pt
Casing positions in string 'A'
- - - - - ------- ------------ ------
- - - -- ------------------ - - - ----
Top MD Top TVD
Rectangular Coords.
Bot MD Bot TVD
Rectangular Coords.
Casing
7326.65
2579.74
3917.12S
702.03S
- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - --
0.00
0.00
0.00
0.00
O.OOE
O.OOE
5774.19
2369.27
O.OON
O.OON
Targets associated with this wellpath
-- - - - - - - - - ----- ---------- -- - - - -------
--- - - - - -- - --------------- -- -- - -------
Target name
Geographic Location
T.V.D.
946.02W 3 1/2 CSG
169.55W 7 5/8 CSG
MW(F) Midpt TGT Rvsd 442767.000,5865235.000,999.00
3662. OOS
Rectangular Coordinates
884.41W 22-Feb-2001
Revised
- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - --
5504.00
ORIGINAL
.;--.,
SUMMARY
Phillips Alaska, Inc.
Drill Site 2P
441
slot #441
Meltwater
North Slope, Alaska
C LEA RAN C E
by
Baker Hughes INTEQ
/""" \.
R E paR T
Your ref: 2P-441 Version #l.D
Our ref: prop4485
License:
Date printed: 25-Jan-2002
Date created: 23-Feb-2001
Last revised: 25-Jan-2002
Field is centred on 441964.235,5869891.466,999.00000,N
Structure is centred on 441964.235,5869891.466,999.00000,N
Slot location is n70 3 8.795,w150 27 2.548
Slot Grid coordinates are N 5868889.800, E 443679.200
Slot local coordinates are 988.66 S 1722.71 E
Projection type: alaska - Zone 4, Spheroid: Clarke - 1866
Object wellpath
MWD <0-9224'>,,438,Drill Site 2P
MWD <3660 - 11075'>,,415,Drill Site 2P
MWD <5552 - 9038'>, ,415A,Drill Site 2P
MWD <0 - 6008'>,,417,Drill Site 2P
MWD <0-6860'>,,420,Dri11 Site 2P
MWD <754 - 8663'>, ,448A,Dril1 Site 2P
MWD <4000 - 7593'>,,448B,Drill Site 2P
MWD <0-2040'>, ,448,Drill Site 2P
MWD <0-8974'>, ,429,Drill Site 2P
PMSS <0-6122'>"MWN#1,Meltwater North #1
PMSS <0-8935'>"MWSouth1,Meltwater South #1
PMSS <0-6300'>, ,MWN#2,Meltwater North #2
PMSS <2212-7349'>"MWN#2A,Me1twater North #2
Reference North is True North
Closest approach with 3-D
Last revised Distance
4-Jun-2001 49.0
2-Dec-2001 519.7
17-Dec-2001 519.7
25-May-2001 479.9
14-Jan-2002 420.1
10-Jan-2002 139.8
14-Jan-2002 139.8
28-Dec-2001 139.8
18-Dec-2001 240.0
26-Feb-2001 2913.2
6-Mar-2001 43133.2
26-Feb-2001 3859.1
26-Feb-2001 3408.6
Minimum Distance method
M.D. Diverging from M.D.
737.5 737.5
200.0 200.0
200.0 200.0
0.0 712.5
100.0 100.0
0.0 0.0
0.0 7000.0
0.0 0.0
0.0 0.0
7326.6 7326.6
7326.6 7326.6
3340.0 3420.0
3300.0 3300.0
ORIGINAL
,~
",--. \.
Phillips Alaska, Inc.
Drill Site 2P
441
slot #441
Meltwater
North Slope, Alaska
PRO PO S ALL I S TIN G
INCLUDING POSITION UNCERTAINTIES
by
Baker Hughes INTEQ
Your ref: 2P-441 Version #l.D
Our ref: prop4485
License:
Date printed: 25-Jan-2002
Date created: 23-Feb-2001
Last revised: 25-Jan-2002
Field is centred on 441964.235,5869891.466,999.000OO,N
Structure is centred on 441964.235,5869891.466,999.OOOOO,N
Slot location is n70 3 8.795,w150 27 2.548
Slot Grid coordinates are N 5868889.800, E 443679.200
Slot local coordinates are 988.66 S 1722.71 E
Projection type: alaska - Zone 4, Spheroid: Clarke - 1866
Reference North is True North
ORIGINAL
r",
,,--\
Phillips Alaska, Inc. PROPOSAL LISTING Page 1
Drill Site 2P,441 Your ref : 2P-441 Version #l.D
Meltwater,North Slope, Alaska Last revised : 25-Jan-2002
Measured Inclin. Azimuth True Vert RECTAN GULAR Vert Ellipse Semi Axes Minor
Depth Degrees Degrees Depth COO R D I N ATE S Sect Major Minor Vert. Azi.
0.00 0.00 0.00 0.00 0,00 N 0.00 E 0.00 0.00 0.00 0.00 N/A
100.00 0.00 193.58 100.00 0.00 N 0.00 E 0.00 0.26 0.26 0.15 N/A
200.00 0.00 193.58 200.00 0.00 N 0.00 E 0.00 0.52 0.52 0.30 N/A
300.00 0.00 193.58 300.00 0.00 N 0.00 E 0.00 0.78 0.78 0.45 N/A
400.00 0.00 193.58 400.00 0.00 N 0.00 E 0.00 1. 04 1. 04 0.60 N/A
500.00 0.00 193.58 500.00 0.00 N 0.00 E 0.00 1. 31 1. 31 0.75 N/A
600.00 0.00 193.58 600.00 0.00 N 0.00 E 0.00 1. 57 1. 57 0.90 N/A
700.00 0.00 193.58 700.00 0.00 N 0.00 E 0.00 1. 83 1. 83 1. 05 N/A
800.00 2.00 193.58 799.98 1.70 S 0.41 W 1. 75 2.09 2.09 1. 20 N/A
900.00 4.00 193.58 899.84 6.78 S 1. 64 W 6.98 2.38 2.35 1. 35 13.58
1000.00 6.00 193.58 999.45 15.26 S 3.68 W 15.69 2.71 2.62 1. 50 13.58
1100.00 8.00 193.58 1098.70 27.10 S 6.54 W 27.88 3.12 2.89 1. 65 13.58
1200.00 10.00 193.58 1197.47 42.31 S 10.22 W 43.52 3.63 3.18 1. 81 13.58
1266.67 12.00 193.58 1262.90 54.67 S 13.20 W 56.24 4.04 3.38 1. 91 13.58
1360.32 14.81 193.58 1354.00 75.77 S 18.30 W 77.95 4.76 3.67 2.06 13.58
1366.67 15.00 193.58 1360.13 77.36 S 18.68 W 79.58 4.81 3.69 2.07 13.58
1466.67 18.00 193.58 1456.00 104.97 S 25.35 W 107.98 5.77 4.02 2.25 13.58
1566.67 21. 00 193.58 1550.25 137.41 S 33.18 W 141.36 6.93 4.38 2.43 13.58
1666.67 24.00 193.58 1642.63 174.60 S 42.17 W 179.62 8.28 4.77 2.63 13.58
1766.67 27.00 193.58 1732.88 216.45 S 52.27 W 222.67 9.83 5.19 2.86 13.58
1866.67 30.00 193.58 1820.75 262.82 S 63.47 W 270.38 11.57 5.63 3.11 13.58
1966.67 33.00 193.58 1906.01 313.61 S 75.74 W 322.62 13.49 6.09 3.40 13.58
2024.47 34.73 193.58 1954.00 344.92 S 83.30 W 354.83 14.71 6.37 3.60 13 .58
2066.67 36.00 193.58 1988.41 368.66 S 89.03 W 379.26 15.60 6.58 3.74 13.58
2166.67 39.00 193.58 2067.74 427.83 S 103.32 W 440.13 17.88 7.08 4.12 13.58
2266.67 42.00 193.58 2143.77 490.95 S 118.57 W 505.06 20.33 7.60 4.55 13.58
2338.96 44.17 193.58 2196.56 538.95 S 130.16 W 554.44 22.20 7.98 4.90 13 .58
2500.00 44.17 193.58 2312.08 648.02 S 156.50 W 666.65 26.37 8.82 5.70 13.58
2579.74 44.17 193.58 2369.27 702.03 S 169.55 W 722.21 28.45 9.25 6.11 13.58
2679.74 44.17 193.58 2441. 00 769.76 S 185.90 W 791. 89 31.06 9.79 6.63 13 .58
3000.00 44.17 193.58 2670.72 986.67 S 238.29 W 1015.04 39.43 11.52 8.29 13.58
3425.60 44.17 193.58 2976.00 1274.93 S 307.91 W 1311.59 50.61 13.86 10.57 13.58
3500.00 44.17 193.58 3029.37 1325.32 S 320.08 W 1363.43 52.56 14.27 10.97 13.58
3818.75 44.17 193.58 3258.00 1541.21 S 372.22 W 1585.52 60.95 16.04 12.69 13.58
4000.00 44.17 193.58 3388.01 1663.97 S 401. 87 W 1711. 81 65.72 17.04 13.67 13.58
4051.57 44.17 193.58 3425.00 1698.90 S 410.30 W 1747.74 67.08 17.33 13.95 13.58
4500.00 44.17 193.58 3746.66 2002.63 S 483.65 W 2060.20 78.90 19.83 16.39 13.58
5000.00 44.17 193.58 4105.30 2341.28 S 565.44 W 2408.59 92.08 22.63 19.12 13.58
5500.00 44.17 193.58 4463.95 2679.93 S 647.23 W 2756.98 105.26 25.44 21. 86 13.58
5705.01 44.17 193.58 4611.00 2818.78 S 680.76 W 2899.82 110.67 26.59 22.98 13.58
6000.00 44.17 193.58 4822.59 3018.58 S 729.01 W 3105.36 118.45 28.25 24.59 13.58
6417.79 44.17 193.58 5122.27 3301. 55 S 797.35 W 3396.47 129.47 30.60 26.89 13.58
6500.00 44.17 193.58 5181. 24 3357.23 S 810.80 W 3453.75 131. 64 31. 06 27.34 13.58
6517.79 44.17 193.58 5194.00 3369.28 S 813 . 71 W 3466.15 132.11 31.16 27.43 13.58
6647.45 44.17 193.58 5287.00 3457.10 S 834.92 W 3556.49 13 5.53 31.89 28.15 13 .58
6860.75 44.17 193.58 5440.00 3601.57 S 869.81 W 3705.11 141.16 33.09 29.32 13.58
6949.97 44.17 193.58 5504.00 3662.00 S 884.41 W 3767.28 143.52 33.59 29.81 13.58
7000.00 44.17 193.58 5539.88 3695.88 S 892.59 W 3802.14 144.84 33.87 30.08 13.58
7026.65 44.17 193.58 5559.00 3713.93 S 896.95 W 3820.71 145.54 34.02 30.23 13.58
7207.89 44.17 193.58 5689.00 3836.68 S 926.59 W 3946.99 150.32 35.04 31.22 13.58
All data is in feet unless otherwise stated.
Coordinates from slot #441 and TVD from rotary table (254.00 Ft above mean sea level).
Bottom hole distance is 4029.74 on azimuth 193.58 degrees from wellhead.
Vertical section is from wellhead on azimuth 193.58 degrees.
Calculation uses the minimum curvature method.
Presented by Baker Hughes INTEQ
ORIGINAL
)~
/--\
Phillips Alaska, Inc.
Drill Site 2P,441
Meltwater , North Slope, Alaska
PROPOSAL LISTING Page 2
Your ref: 2P-441 Version #l.D
Last revised: 25-Jan-2002
Measured Inclin. Azimuth True Vert
Depth Degrees Degrees Depth
R E C TAN G U L A R
COO R DIN ATE S
Vert
Sect
Ellipse Semi Axes
Major Minor Vert.
Minor
Azi.
7326.65
44.17
193.58
5774.19
3917.12 S
946.02 W
4029.74
153.46
35.71
31. 87
13.58
POSITION UNCERTAINTY SUMMARY
------------------------------
------------------------------
Depth
From To
Survey Tool
Error Model
Position uncertainty
Major Minor Vert.
----------------------------------------------------------------------------------------------------
0
7327
ARCO (H.A) Mag)
User specified
153.46
35.71
31. 87
1. Ellipse dimensions are half axis.
2. Casing dimensions are not included.
3. Ellipses are calculated on 2.58 standard deviations.
4. Uncertainty calculations start at drill depth zero.
5. Surface position uncertainty is not included.
6. Where two surveys are tied together the errors of one are considered
to have a systematic relationship to the corresponding errors of the
7. Detailed description of the INTEQ error models can be found
in the Ec*Trak manual.
other.
All data is in feet unless otherwise stated.
Coordinates from slot #441 and TVD from rotary table (254.00 Ft above mean sea level).
Bottom hole distance is 4029.74 on azimuth 193.58 degrees from wellhead.
Vertical section is from wellhead on azimuth 193.58 degrees.
Calculation uses the minimum curvature method.
Presented by Baker Hughes INTEQ
ORIGINAL
r---
.~.
Phillips Alaska, Inc.
Drill Site 2P,441
Meltwater,North Slope, Alaska
PROPOSAL LISTING Page 3
Your ref: 2P-441 Version #l.D
Last revised: 25-Jan-2002
Comments in wellpath
--------------------
--------------------
MD
TVD
Rectangular Coords.
Comment
-----------------------------------------------------------------------------------------------------------
700.00 700.00 0.00 N 0.00 E KOP
1200.00 1197.47 42.31 S 10.22 W Build 3/100
1360.32 1354.00 75.77 S 18.30 W Base Permafrost
2024.47 1954.00 344.92 S 83.30 W Base West Sak
2338.96 2196.56 538.95 S 130.16 W EOC
2579.74 2369.27 702.03 S 169.55 W 7 5/8 CSG
2679.74 2441. 00 769.76 S 185.90 W C80
3425.60 2976.00 1274.93 S 307.91 W C50
3818.75 3258.00 1541. 21 S 372.22 W C40
4051. 57 3425.00 1698.90 S 410.30 W C37
5705.01 4611. 00 2818.78 S 680.76 W T7
6417.79 5122.27 3301. 55 S 797.35 W 5 1/2 X 3 1/2 XO
6517.79 5194.00 3369.28 S 813.71 W T4.1 (Top Cairn)
6647.45 5287.00 3457.10 S 834.92 W T3.1 (Base Cairn)
6860.75 5440.00 3601.57 S 869.81 W T3 (Top Bermuda)
6949.97 5504.00 3662.00 S 884.41 W MW(F) Midpt TGT Rvsd 22 Jan 01
7026.65 5559.00 3713.93 S 896.95 W T2 (Base Bermuda)
7207.89 5689.00 3836.68 S 926.59 W C35 (Top Albian)
7326.65 5774.19 3917.12 S 946.02 W TD - Csg pt
Casing positions in string 'A'
------------------------------
------------------------------
Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing
-----------------------------------------------------------------------------------------------------------
0.00
0.00
0.00
0.00
O.OON
O.OON
O.OOE
O.OOE
7326.65
2579.74
5774.19
2369.27
3917.12S
702.03S
946.02W
169.55W
3 1/2 CSG
7 5/8 CSG
Targets associated with this wellpath
-------------------------------------
-------------------------------------
Target name
Geographic Location
T.V.D.
Rectangular Coordinates
Revised
-----------------------------------------------------------------------------------------------------------
MW(F) Midpt TGT Rvsd 442767.000,5865235.000,999.00
5504.00
3662.00S
884.41W
22-Feb-2001
ORIGINAL
/------
/--\
2P-441 Drillina Hazards Summary
(to be posted in Rig Floor Doghouse Prior to Spud)
Surface Casin~ Interval
Event
Tight hole / Packoff problems
Conductor Broach
Well Collision
Gravel and sand sloughing
Shakerrrrough Cuttings
System Overflow
Permafrost Hydrates
Shoe Fracture/LDst Returns
during cement job
Risk Level
MDderate
Low
Low
Low
Low
Low
Low
Production Casin~ Interval
Interval Risks
Event
Lost Circulation
High ECO and swabbing if ./
higher MW is required
Tight hDle / PackDff problems
Risk Level
High
High
Moderate
I Mitigation Strategy
Revised BHA design, goDd hole cleaning practices
MonitDr cellar continuously during interval.
Careful well planning and surveying, adherence to
anti-collision pDlicy
Elevated mud viscosity from spud; Hi dens sweeps.
Controlled ROP
Controlled drilling, reduced pump rates, higher mud
weights, cold mix water and mud, lower viscosities,
and lecithin additions as needed.
Reduced pump rates, and lightweight tail cement
Mitigation Strategy
Good drilling practices. LCM, InstanSEAL as
needed. Stay within ECO hardlines
Pumping and rotating out on all trips to reduce swab
and barite sag potential. Keep hole mud system as
clean as pDssible. Bring pumps Dn slowly. RIH
slowly to avDid surge.
Revised BHA design, gDod hole cleaning practices
2P-441 Drilling Hazards Summary. doc
prepared by Pat Reilly
ORIGIN~P
,~
Meltwater 2P-~ 11
Proposed Completion Schematic
Slimhole Base Case - 3-1/2" Completion String
~ i
~ ~
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~ ~
8 ~
~ ~
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~ ~
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16" 62.6# ~ ~
@+1_120'MDii'
Port Collar 1 000' MD~';
Depths are
based on . ~
Doyon 141 '. ~
RKB ~
~
~
~
~
~
I
~
~
~
~
~
Surface csg.
7-5/B" 29.7# L-BO BTCM
+1- 25BO' MD I 2369' TVD
12' Pup (Critical)
Intermediate csg.
5-1/2" 15.5# L-BO BTCM
run CSR to surface
+1- 641B' MD 15122 TVD
Future Perforations
Production csg
3-1/2" 9.3# L-BO EUEBRD
TD to CSR
+/- 7327' MD /5774' TVD
~ r ~ r
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PHILLIPS Alaska, Inc.
A Subsidiary of PHILLIPS PETROLEUM COMPANY
3-1/2" FMC Gen 5 Tubing Hanger, 3-1/2" L-BO EUEBRD pin down
3-1/2" 9.3# L-BO EUEBRD Spaceout Pups as Required
3-1/2" 9.3# L-BO EUEBRD Tubing to Surface
3-1/2" Cameo 'DS' nipple w/2.B75" No-Go Profile. 3-112" x 6' L-BO handling
pups installed above and below, EUEBRD set at +1- 500' MD
3-1/2" 9.3# L-BO EUEBRD tubing to landing nipple
3-1/2" x 1" Cameo 'KBG-2-9' Mandrels wI DVs and RK latch's (Max. OD 4.725", ID
2.90"), IBT box x box, 3-1/2" x 6' L-BO EUEBRD box x IBT pin handling pup installed
above, 3-1/2" x 6' L-BO IBT pin x EUEBRD pin handling pup installed below. Spaced
out wI 3-1/2" 9.3# L-BO EUEBRD tubing as follows:
GLM # TVD-RKB MD-RKB
GLM Numbers and Spacing To Be Determined
3-1/2" x 1" Cameo 'KBG-2-9' mandrel wI DCK-3 shear valve and bottom latch
(Max. OD 4.725", ID 2.90"), IBT box x box, pinned for 3000 psi shear (casing to
tubing differential), 3-1/2" x 6' L-BO EUEBRD box x IBT pin handling pup installed
above, 3-1/2" x 6' L-BO IBT pin x EUEBRD pin handling pup installed below
1 jt 3-1/2" 9.3# L-BO EUEBRD tubing
3-1/2" Baker 'CMU' sliding sleeve w/2.B13" Cameo No-Go profile, EUEBRD
box x pin. 3-1/2" x 6' L-BO EUEBRD handling pups installed above
3-1/2" Cameo '0' nipple wI 2.75" No-Go profile. 3-1/2" x 12' L-BO EUEBRO
handling pup installed above. 3-1/2" x 6' L-BO EUEBRD handling pup below
1 jt 3-1/2" 9.3# L-BO EUEBRD tubing
3-1/2" Baker 80-40 GBH-22 casing seal assembly wI 15' stroke, 3-1/2" L-80
EUE8RD box up, 3-1/2" x 6' L-80 EUE8RD handling pup installed on top
- Baker Casing Seal Receptacle, BO-40, 5-1/2"BTCM x 3-1/2" EUEBRD
Baker 5" OD x 4" ID 17' Seal Bore Extension
CSR set at +1- 100' MD above the top of the Bermuda (OR 100' MD ABOVE THE
- TOP OF THE CAIRN IF THE CAIRN IS PRESENT)
0 RIG ¡ IV A ~JR, 1/25/02
Rig: Doyon 141
Location: Kuparuk (Meltwater)
Client: Phillips Alaska, Inc.
Revision Date: 1/25/2002
Prepared by: Kevin Tanner
Location: Anchorage, AK
Phone: (907) 265-6205
Mobile: (907) 230-6628
email: ktanner@slb.com
IJ
I....'.'..
1
I
ib
< Toe at Surface V'
Prel.Ïous egg.
< 16",62.6#, H-40 grade
Welded Connection
at 120 ft. MD
< Base of Permafrost
at 1,360 ft. MD
(1,354 ft. lVD)
< Top of Tail at
1,380 ft. MD
< 75/8",29.7#, L-80 grade
BTC, AB Modified
in 9 7/8" OH
TO at 2,580 ft. MD
(2,369 ft. 1VD)
Mark of Schlumberger
Schlumbøpgøp
Preliminary Job Design based on limited input data. For estimate purposes only.
Volume Calculations and Cement Svstems
(Volumes are based on 350% excess in the permafrost and 45% excess below the
permafrost. Top of tail slurry is designed to be 20' below base of permafrost.)
Lead Slurry (minimum pump time 167 min.)
ASLite @ 10.7 PPg, Class G + 50%D124, 9%D44, 0.4%D46, 30%D53, 1.5%S1,
1.5%D79 - 4.44 ft /sk
0.9513 ft3/ft x (120') x 1.00 (nD excess) =
0.2148 fe/ft x (1360' - 120') x 4.50 (350% excess) =
0.2148 fe/ft x (1380' -1360') x 1.45 (45% excess) =
114.2 fe + 1198.6 ft3 + 6.2 ft3 =
1319 fe 14.44 fe/sk = ,,/
Round up to 300 sks
114.2 ft3
1198.6 fe
6.2 fe
1319fe
297.1 sks
Have 220 sks of additional Lead on location for Top Out stage, if necessary.
Tail Slurry (minimum pump time 128 min.)
LiteCRETE @ 12.0 ppg - 2.40 fe/sk
0.2148 fe/ft x (2580' - 1380') x 1.45 (45% excess) =
0.2578 fe/ft x 80' (Shoe Joint) =
373.8 fe + 20.6 fe =
394.4 fel 2.40 ft%k = /
Round up to 170 sks
373.8 fe
20.6 fe
394.4 fe
164.3 sks
BHST = 55°F, Estimated BHCT = 73°F.
(BHST calculated using a gradient of 2.3°F/1 00 ft. below the permafrost)
PUMP SCHEDULE
Pump Rate Stage Stage Time Cumulative
Stage (bpm) Volume (min) Time
(bbl) (min)
CW100 6 40 6.7 6.7
Drop Bottom Plug 3.0 9.7
MudPUSH XL 6 40 6.7 16.4
Lead Slurry 6 237 39.5 55.9
Tail Slurry 6 73 12.2 68.1
Drop Top Plug 3.0 71.1
Displacement 6 95 15.8 86.9
Bump Plug 3 20 6.7 93.6
MUD REMOVAL
Recommended Mud Properties: 9.8 ppg, Pv < 15, T y < 15. As thin and light as possible
tD aid in mud remDval 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
Rig: Doyon 141
Location: Kuparuk (Meltwater)
Client: Phillips Alaska, Inc.
Revision Date: 1/25/2002
Prepared by: Kevin Tanner
Location: Anchorage, AK
Phone: (907) 265-6205
Mobile: (907) 230-6628
email: ktanner@slb.com
, PrelAous Csg.
~
'A < 75/8",29.7#, L.80 grade
BTC, AB Modified
at 2,580 ft. MD
Schlumbøpgøp
Preliminary Job Design based on limited input data. For estimate purposes only.
Volume Calculations and Cement Systems
(Volumes are based on 75% excess. Top of tail slurry is designed to be 500' above
casing X-over.
Tail Slurry (minimum thickening time 144 min.)
GasBLOK wi Class G + D53, D600, D135, D800, D047, D065, per lab testing
@ 15.8 ppg, 1.2 fe/sk
0.0835 felft x 500' x 1.75 (75% excess) =
0.1817 felft x (7327' - 6418') x 1.75 (75% excess) =
0.0488 felft x 80' (Shoe Joint) =
73.1 fe + 289 fe + 3.9 fe =
366.0 fe/1.2 fe/sk = ,./
Round up to 310 sks
73.1 fe
289fe
3.9 fe
366.0 fe
305 sks
BHST = 134°F, Estimated BHCT = 115°F.
(BHST calculated using a gradient of 2.3°F/1 00 ft. below the permafrost)
PUMP SCHEDULE
Pump Rate Stage Stage Time Cumulative
< 5 1/2", 15.5#, L-80 grade Stage (bpm) Volume (min) Time
BTC, AB Modified (bbl) (min)
in 6 3/4" OH CW100 5 80 16.0 16.0
MudPUSH XL 5 40 8.0 24.0
Tail Slurry 5 66 13.2 37.2
Drop Top Plug 3.0 40.2
Displacement 5 90 18.0 58.2
SIDW Rate 4 60 15.0 73.2
< Top ofTail at / Bump Plug 2 10 5.0 78.2
5,918 ft, MD
< X-o\erat 6,418 ft. MD
< Top of Bermuda Fm.
at 6,861 ft. MD
< 3 1/2", 9.3#, L-80 grade
EUE, 8re1 Modified
in 6 3/4" OH
m at 7,327 ft. MD
(5,774 ft. TVD)
Mark of Schlumberger
MUD REMOVAL
Recommended Mud Properties: 9.8 ppg, Pv < 15, T y < 15. As thin and light as possible
to aid in mud removal during cementing.
Spacer Properties: 12.0 ppg MudPUSH* XL, Pv "" 19-22, T y "" 22-29
Centralizers: Recommend 1 per joint across zones of interest for proper cement
placement.
ORIGINAL
\ti6A- I hit'\> L
PHlll~S Alaska, Inc.
A Subsidiary of PHILLIPS PETROLEUM COMPANY
~
Phillips Alaska, Inc.
Post Office Box 100360
Anchorage, Alaska 99510
January 25, 2002
Ms. Cammy Oechsli Taylor
Commissioner
Alaska Oil and Gas Conservation Commission
333 West ¡th Avenue, Suite 100
Anchorage, AK 99501
(907) 279-1433
Re:
Application for Permit to Drill:
KRU 2P-441
Surface Location:
Target Location:
Bottom Hole Location:
989'FNL, 1719'FWL,Sec.17,T8N, R7E
629'FSL,822'FWL,Sec.17,T8N,R7E
374'FSL,760' FWL, Sec. 17,T8N,R7E
Dear Commissioner:
Phillips Alaska, Inc. hereby applies for a Permit to Drill an Dnshore development well KRU 2P-441.
The well will be drilled and completed using Nordic 3. Please utilize dDcuments on file for this rig.
Subject to AOGCC approval, fluids and cuttings generated from drilling the well will be pumped down an
approved and existing annulus on Drillsite 2P, or hauled to an approved Prudhoe or GKA Class II dispDsal
well.
The following people are the designated contacts for reporting responsibilities to the Commission:
A) Completion Report Sharon Allsup-Drake, Drilling TechnolDgist
(20 AAC 25.070) 263-4612
B)
GeolDgic Data and Logs
(20 AAC 25.071)
Steve Moothart, Geologist
265-6965
If you have any questions or require further information, please contact Pat Reilly at (907) 265-6048.
Sincerely,
~~~
Drilling Engineering Supervisor
RECEIVED
JAN 2 5 2002
Alaska Oil & Gas Cons. Commission
Anchorage
ORIGINAL
- ...
."-"'"
~
\
. .'."--....
_. .-..-.
~
~
Phillips Alaska, Inc.
POBox 102776
Anchorage, AK 99510-2776
**************100.00*
SUITE 1.00
AK 995013539
Date
Amount
Void.after 90 days
. ..
. .. . ..
. ..
------.--..-_uu..----..
. ~..{)mJ\U~
oSlgnal\\res re<l\\':'êO . ..
.'. . ... oramoun,sove, $25,000,00 ...,' ,,'..)
'.."- ,. ..._-. ...--...,-
1180000 .O.~O 5118
':08 :ì gO L. 2 to 2':
Og
gOOOO"8
- ----.--..-- .
CHECK 1
STANDARD LETTER
DEVELOPMENT
¡
DEVELOPMENT
REDRILL
EXPLORATION
INJECTION WELL
INJECTION WELL
RED RILL
/~
~\
TRANSMIT AL LETTER CHECK LIST
CIR CLE APPRO PRIA TE LETTERIP ARA GRAPHS TO
BEINCLUDEDINTRANSNDTTALLETTER
WELLNAME KEt( 2~-:J-Ç/¿¡ I
CHECK WHAT APPLIES
ADD-ONS (OPTIONS)
MULTI LATERAL
(If api number last two (2)
digits are between 60-69)
PILOT HOLE (PH)
ANNULAR DISPOSAL
<-)NO
ANNULAR DISPOSAL
<-) YES
ANNULAR DISPOSAL
THIS WELL
=~~ lie OTHER
V YES +
SPACING EXCEPTION
Templates are located m drive\jody\templates
"CLUE"
The permit is for a new well bore segment of existing weD
--'--' 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(1), 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.sùbject 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.
(Company Name) wiII assume the liability of any protest to
the spacing exception that may occur.
~ ~ .
WELL PERMIT CHECKLIST 1t;rf:1.. OMPANY r'Ii ~ /,5 WELL NAME 2/2 '/<1/ PROGRAM' e,p - dev /,ed"'- seN -.. wellbore seg _ann. disposal para req -
FIELD & POOL '7'9C/~ INrrCLASSÛ ~(,/ /Û/L.G!.9.:AREA £Y(':J UNIT# fi[~ ON/OFF SHORE ðÞ]
ADMINISTRATION 1. Permittee attached. . . . . . . . . . . . . . . . . . . . . . . ' ~
2. Lease number appropriate. . . . . . . . . . . . . . . . . . . N
3.Uniquewellnameandnumber.................. ..N
4.Welllocatedinadefinedpool.................. .!:IN
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 included.. . . . . . . . . . . . . . ' N
9. Operator only affected party.. . . . . . . . . . . . . . . . . . ..:> N
10. Operator has appropriate bond in force. . . . . . . . . . . . . . N
11. Permit can be issued without conservation order. . . . . . . . Y) N
APPR PJ),TE 12. Permit can.be issued without administrative approval. . . . . . :) N
~. II ~O'DZ-----13. Can permit be approved before 15-day wait.. . . . . . . . . . /Ýì N
DV c¿ ,
ENGINEERING 1~. Conductors.tringprovided ................. .-:-. ~N ,~/f@ /Ü? TVP.,
10. Surface casing protects alt known USDWs. . . . . . . . . . . N A J - ....L ..L
16. CMT vol adequate to circulate on conductor & surf csg. . . . . N ~~ tLev r-e UU s,Ç" ~-e-t..{" C' '
17. GMT vol adequate to tie-in long string to surf csg. . . . . . . . Y. N Al/~
18. CMT will cover all known productive horizons. . . . . '. . . . . ~N
19. Casing designs adequate for C: T, B & permafrost. . . . . . . . . N ¡ (iJ ~ ~
20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N I'JJ) (J.{C ~ 3 .
21. If a re-drill, has a 10-403 for abandonment been approved. . . N /oJ/A..
22. Adequate well bore separation proposed.. . . . . . . . . . . . N
23. If diverter required, does it meet regulations. . . . . . . . . . N
24. Drilling fluid program schematic & equip list adequate. . . . . Ý N
25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N ,
; APPR DA TI=. . 26. BOPE press rating appropriate; test to 3 000 psig. N fAAS P -: '2..7- 7.JI P <;1,
vJG'" II ?;l éJ 7-.. 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N
28. Work will occur without operation shutdbwn. . . . . . . . . . . 1i
29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y CW
30. Permit can be issued w/o hydrogen sulfide measures. . . .. G N
31. Da!a ~resented. On potential overpressure zones. . . . . .. . . vA
; 32. Seismic anal~~ls of shallow gas zones. . . . . . . . . . . .. . A/Ý N
, APPR DATE 33. Seabed condition survey (If off-shore). . . . . . . . . . . . / Y N
ßJ I, 3v, ciV 34. Contact name/phone for weekly progress reports [expl9"ry only] Y N
ANNULAR DISPOSAL35. With proper cementing records, this plan .
. (A) will contain waste in a suitable receiving zone; . . . . . . .
: APPR DATE (B) wilt not contaminate freshwater; or cause drilling waste. ..
to surface;
(C) will not impair mechanical integrity of the well used for disposal; Y N
(D) will not damage producing formation or impair recovery from a Y N
pool; and
(E) will not circumvent 20 MC 25.252 or 20 AAC 25.412. Y N
GEOLOGY: ENGINEERING: UIC/Annular COMMISSION:
1fH Æ ./ WM
TEM
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. GEOLOGY
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Y N
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Com m entsllnstructions:
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9~~ ðtV\ \l-
\/$1/01-
c:\msoffice\wordian\diana\checklist (rev. 111011100)
.~
~
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
siIT1plify finding infonnation, 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 infonnation.
~
**** REEL HEADER ****
LDWG
03/02/27
AWS
01
**** TAPE HEADER ****
LDWG
03/02/26
01
*** LIS COMMENT RECORD ***
! ! ! ! ! ! !! ! !! ! ! ! ! ! ! ! !
! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! !
TAPE HEADER
MELTWATER UNIT
MWD/MAD LOGS
#
WELL NAME:
API NUMBER:
OPERATOR:
LOGGING COMPANY:
TAPE CREATION DATE:
#
JOB DATA
JOB NUMBER:
LOGGING ENGINEER:
OPERATOR WITNESS:
JOB NUMBER:
LOGGING ENGINEER:
OPERATOR WITNESS:
#
SURFACE LOCATION
SECTION:
TOWNSHIP:
RANGE:
FNL:
FSL:
FEL:
FWL:
ELEVATION(FT FROM
KELLY BUSHING:
DERRICK FLOOR:
GROUND LEVEL:
#
WELL CASING RECORD
1ST STRING
2ND STRING
~,
¿;¡Od-OJj
II 53ò
LDWG File Version 1.000
Extract File: LISTAPE.HED
MWD RUN 1
1
S. TUFTON
D. HElM
MWD RUN 4
4
F. WENDLER
D. WESTER
2P-441
501032040700
Phillips Alaska, Inc.
BAKER HUGHES INTEQ
26-FEB-03
MWD RUN 2
2
C. WONG
D. WESTER
MWD RUN 5
5
E. AGUIRRE
D. WESTER
MWD RUN 3
3
G. SUTING
D. WESTER
MWD RUN 6
J. BROUSSARD
D. WESTER
17
8N
7E
MSL 0)
254.00
224.00
OPEN HOLE CASING DRILLERS
BIT SIZE (IN) SIZE (IN) DEPTH (FT)
16.000 120.0
9.625 7.625 2594.0
~
---..
#
REMARKS:
3RD STRING
PRODUCTION STRING
6.750
4.750
5.500
4696.0
7327.0
Tape Subfile: 1
PER PHILLIPS ALASKA REQUEST, THE GAMMA RAY CURVE
FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS
WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED.
INDIVIDUAL MWD RUN DATA WAS MERGED IN THE FIELD PRIOR
TO DELIVERY FROM THE WELL SITE.
SURFACE LOCATION:
LAT: N 70 DEG 3' 8.795"
LONG: W150 DEG 27' 2.548"
LOG MEASURED FROM D.F. AT 254 FT. ABOVE PERM. DATUM
(M.S.L.) .
COMMENTS:
(I) Baker Hughes INTEQ run 1 utilized Gamma Ray with
MPR (Modular Annular Pressure) services from 120 - 2609
feet (120 - 2388' TVD).
(2) Baker Hughes INTEQ runs 2 and 3 utilized the Slim
Advantage Porosity Logging Service (APLS) which include
Optimized Rotational Density (ORD), Caliper Corrected
Neutron (CCN), along with MAP (Modular Annular Pressure
MPR (Multiple Propagation Resistivity) services from
2609 - 4705 feet MD (2388 - 3896' TVD).
(3) Baker Hughes INTEQ run 4 utilized NaviGamma with
Directional services from 4705 - 5690 feet MD
(3896 - 4813' TVD).
(4) Baker Hughes INTEQ runs 5 and 6 utilized USMPR
(Ultra Slim Multiple Propagation Resistivity) with
directional services from 5690 to 7327 feet MD
(4813 - 5795' TVD).
REMARKS:
(I) Depth of 16" Casing Shoe - Driller: 120 feet MD
(120' TVD)
(2) The interval from 2562 to 2609 feet MD (2355-2388
TVD) was not logged due to sensor-bit offsets at the
7 1/2" casing point.
(3) Depth of 7 5/8" Casing Shoe - Logger: 2593 feet MD
(2378 I TVD)
Depth of 7 5/8" Casing Shoe - Driller:2593 feet MD
(2378' TVD)
(4) The interval from 2607 to 2652 feet MD (2387-2419
TVD) was logged up to 16.5 hours after being drilled
due to a trip out of the hole to change out the MWD
pulser.
(5) Depth of 5 1/2" Casing Shoe - Logger: 4690 feet MD
(3887' TVD)
Depth of 5 1/2" Casing Shoe - Driller:4696 feet MD
(3890' TVD)
The interval from 4653 to 4692 feet MD (3860-3887'TVD)
was not logged due to interference from the casing.
(6) The interval from 4705 to 5690 feet MD (3896-4613
TVD) was logged up to 52.3 hours after being drilled
due to a trip out of the hole to pick up USMPR (Ultra
Slim Multiple Propagation Resistivity).
Please note that due to the change in resistivity tools
from MPR to USMPR, that the presentation goes from 4
resistivity curves to 2 resistivity curves below 4691
feet (3887' TVD).
(7) The interval from 5871 to 5947 feet MD (4737-4788
TVD) was logged up to 31.5 hours after being drilled
due to a trip out of the hole to change out USMPR
(Ultra Slim Multiple Propagation Resistivity).
(8) The interval from 7280 to 7327 feet MD (5760-5795
TVD) was not logged due to sensor-bit offset at TD.
$
107 records...
~
~
Minimum record length:
Maximum record length:
8 bytes
132 bytes
**** FILE HEADER ****
LDWG
.001
1024
*** LIS COMMENT RECORD ***
!! ! ! ! ! ! !!!!!! !!! !!!
!!!!!!!!!!!!!!!!!! !
LDWG File Version 1.000
Extract File: FILEO01.HED
FILE HEADER
FILE NUMBER:
EDITED MERGED MWD
Depth shifted and
DEPTH INCREMENT:
#
FILE SUMMARY
PBU TOOL CODE
MWD
$
1
clipped curves; all bit runs merged.
.5000
START DEPTH
266.0
STOP DEPTH
7327.0
#
BASELINE CURVE FOR SHIFTS:
CURVE SHIFT DATA (MEASURED DEPTH)
--------- EQUIVALENT UNSHIFTED DEPTH ---------
BASELINE DEPTH
$
#
MERGED
PBU
MWD
MWD
MWD
MWD
MWD
MWD
$
DATA SOURCE
TOOL CODE
BIT RUN NO
1
2
2
3
4
4
MERGE TOP
266.0
2566.0
2581. 0
4653.0
5640.0
5871.0
MERGE BASE
2566.0
2581.0
4653.0
5640.0
5871. 0
7327.0
#
REMARKS:
MERGED PASS.
NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH
REFERENCE FOR THIS WELL.
$
#
*** INFORMATION TABLE: CONS
MNEM VALU
------------------------------
WDFN
LCC
CN
WN
FN
COUN
STAT
2p-441_5.xtf
150
Phillips Alaska, Inc.
2P-441
Meltwater
North Slope
Alaska
~
~
*** INFORMATION TABLE: CIFO
MNEM CRAN DIMT CNAM
ODEP
----------------------------------------------------
GR GR GRAM 0.0
RPD RPD RPD 0.0
RPM RPM RPCSLM 0.0
RPS RPS RPS 0.0
RPX RPX RPCSHM 0.0
RHOB RHOB BDCM 0.0
DRHO DRHO DRHM 0.0
PEF PEF DPEM 0.0
NPHI NPHI NPCKSM 0.0
CALN CALN CALM 0.0
ROP ROP ROPS 0.0
FET FET RPTH 0.0
MTEM MTEM TCDM 0.0
* FORMAT RECORD (TYPE# 64)
Data record type is: 0
Datum Frame Size is: 56 bytes
Logging direction is down (value= 255)
Optical Log Depth Scale Units: Feet
Frame spacing: 0.500000
Frame spacing units: [F ]
Number of frames per record is:
One depth per frame (value= 0)
Datum Specification Block Sub-type is:
18
1
FRAME SPACE = 0.500 * F
ONE DEPTH PER FRAME
Tape depth ID: F
13 Curves:
Name Tool Code Samples Units Size Length
1 GR MWD 68 1 GAP I 4 4
2 RPD MWD 68 1 OHMM 4 4
3 RPM MWD 68 1 OHMM 4 4
4 RPS MWD 68 1 OHMM 4 4
5 RPX MWD 68 1 OHMM 4 4
6 RHOB MWD 68 1 G/C3 4 4
7 DRHO MWD 68 1 G/C3 4 4
8 PEF MWD 68 1 BN/E 4 4
9 NPHI MWD 68 1 PU-S 4 4
10 CALN MWD 68 1 IN 4 4
11 ROP MWD 68 1 FPHR 4 4
12 FET MWD 68 1 HR 4 4
13 MTEM MWD 68 1 DEGF 4 4
-------
52
Total Data Records: 785
Tape File Start Depth 265.000000
Tape File End Depth 7327.000000
Tape File Level Spacing = 0.500000
Tape File Depth Units = feet
**** FILE TRAILER ****
Tape Subfile: 2
838 records...
r--.
,"-".
Minimum record length:
Maximum record length:
8 bytes
4124 bytes
**** FILE HEADER ****
LDWG
.002
1024
*** LIS COMMENT RECORD ***
! ! ! ! !! ! ! ! ! ! ! ! ! ! ! ! ! !
! ! !!!!!!!!!!!!!!!! !
FILE HEADER
FILE NUMBER:
RAW MWD
Curves and
BIT RUN NO:
DEPTH INCREMENT:
#
FILE SUMMARY
VENDOR TOOL CODE
MWD
$
LDWG File Version 1.000
Extract File: FILE011.HED
2
log header data for each bit run in separate files.
1
.2500
START DEPTH
265.0
STOP DEPTH
2566.0
#
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME):
TD DRILLER (FT):
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT):
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG)
MINIMUM ANGLE:
MAXIMUM ANGLE:
07-MAR-02
MSB 18704
6.75 MAP
MEMORY
2609.0
265.0
2566.0
0
.0
45.0
#
TOOL STRING (TOP TO
VENDOR TOOL CODE
GRAM
DIR
$
BOTTOM)
TOOL TYPE
GAMMA RAY
DIRECTIONAL
TOOL NUMBER
1211
DAS 7071
#
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT):
9.625
120.0
#
BOREHOLE CONDITIONS
MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S):
MUD PH:
MUD CHLORIDES (PPM):
FLUID LOSS (C3):
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TEMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
Spud Mud
9.60
.0
.0
700
.0
.000
.000
.000
.000
112.0
.0
.0
.0
#
~.
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
#
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
#
REMARKS:
BIT RUN 1 (MWD Run 1).
GR/Directional.
CURVE GLOSSARY:
GRAM - GAMMA RAY APPARENT (MWD-API)
ROPS - RATE OF PENETRATION (FPHR)
RPTH - FORMATION EXPOSURE TIME (MIN)
TCDM - TEMPERATURE (DEGF)
$
#
*** INFORMATION TABLE: CONS
MNEM VALU
------------------------------
WDFN
LCC
CN
WN
FN
COUN
STAT
2p-441.xtf
150
Phillips Alaska, Inc.
2P-441
Meltwater
North Slope
Alaska
*** INFORMATION TABLE: CIFO
MNEM CHAN DIMT CNAM
ODEP
----------------------------------------------------
GRAM GRAM GRAM 0.0
ROPS ROPS ROPS 0.0
RPTH RPTH RPTHM 0.0
TCDM TCDM TCDM 0.0
* FORMAT RECORD (TYPE# 64)
Data record type is: 0
Datum Frame Size is: 20 bytes
Logging direction is down (value= 255)
Optical Log Depth Scale Units: Feet
Frame spacing: 0.250000
Frame spacing units: [F ]
Number of frames per record is:
One depth per frame (value= 0)
Datum Specification Block Sub-type is:
50
1
FRAME SPACE = 0.250 * F
ONE DEPTH PER FRAME
Tape depth ID: F
4 Curves:
Name Tool Code Samples Units
1 GRAM MWD 68 1 GAP I
2 ROPS MWD 68 1 FPHR
3 RPTH MWD 68 1 MINS
Size
Length
4
4
4
.-"
.00
.000
. 0
0
4
4
4
~
,-..,
4
TCDM
MWD
68
1
DEGF
4
4
-------
16
Total Data Records:
185
Tape File Start Depth 265.000000
Tape File End Depth 2566.000000
Tape File Level Spacing = 0.250000
Tape File Depth Units = feet
**** FILE TRAILER ****
Tape Subfile: 3
263 records...
Minimum record length:
Maximum record length:
50 bytes
4124 bytes
**** FILE HEADER ****
LDWG
.003
1024
*** LIS COMMENT RECORD ***
!! ! ! ! ! ! ! ! ! ! ! ! ! ! !! ! !
I!!!!!!!!!!!!!!!!!!
FILE HEADER
FILE NUMBER:
RAW MWD
Curves and
BIT RUN NO:
DEPTH INCREMENT:
#
FILE SUMMARY
VENDOR TOOL CODE
MWD
$
LDWG File Version 1.000
Extract File: FILEO12.HED
3
log header data for each bit run in ~eparate files.
2
.2500
START DEPTH
2566.0
STOP DEPTH
2581. 0
#
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME):
TD DRILLER (FT):
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT):
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG)
MINIMUM ANGLE:
MAXIMUM ANGLE:
10-MAR-02
MSB 18704
4.75 SDN
MEMORY
2652.0
2566.0
2581.0
0
45.0
45.0
#
TOOL STRING (TOP TO
VENDOR TOOL CODE
DIR
CCN
ORD
MPR
GRAM
BOTTOM)
TOOL TYPE
DIRECTIONAL
CAL. COR. NEUTRON
OPT. ROT. DENSITY
MULT. PROP. RESIST.
GAMMA RAY
TOOL NUMBER
DAS 1434
10045227
10045227
MPR 1088
2116
/"'-.
.-',
$
#
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT):
6.750
2594.0
#
BOREHOLE CONDITIONS
MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S):
MUD PH:
MUD CHLORIDES (PPM):
FLUID LOSS (C3):
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TEMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
Clay Seal
9.60
.0
.0
28500
.0
.000
.000
.000
.000
70.0
.0
.0
.0
#
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
#
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
#
SANDSTONE
2.65
.000
.0
0
REMARKS:
BIT RUN 2 (MWD Run 2).
GR/MPR/oRD/cCN (logged behind casing).
CURVE GLOSSARY:
GRAM - GAMMA RAY APPARENT (MWD-API)
RPCL - DEEP PHASE RESISTIVITY (OHMM)
RPSL - MEDIUM PHASE RESISTIVITY (OHMM)
RPCH - SHALLOW PHASE RESISTIVITY (OHMM)
RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM)
BDCM - BULK DENSITY COMPENSATED (G/CC)
DRHM - DENSITY CORRECTION (G/CC)
DPEM - PHOTOELECTRIC CROSS SECTION (B/E)
NPCK - NEUTRON POROSITY, CALIPER & SALINITY
CORRECTED (SANDSTONE PU)
CALM - BOREHOLE CALIPER (INCH)
ROPS - RATE OF PENETRATION (FPHR)
RPTH - FORMATION EXPOSURE TIME (MIN)
TCDM - TEMPERATURE (DEGF)
PER PHILIPS ALASKA (WAYNE CAMPAIGN), THE
FOLLOWING CURVES ARE NOT PRESENTED ON THE
MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR
THE SAKE OF COMPLETENESS:
RACL - DEEP ATTENUATION RESISTIVITY (OHMM)
RASL - MEDIUM ATTENUATION RESISTIVITY (OHMM)
RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM)
RASH - EXTRA SHALLOW ATTENUATION RESISTIVITY (OHMM)
$
#
*** INFORMATION TABLE: CONS
MNEM VALU
------------------------------
WDFN
LCC
CN
WN
FN
COUN
STAT
2p-441.xtf
150
Phillips Alaska, Inc.
2P-441
Meltwater
North Slope
Alaska
~
.--,
*** INFORMATION TABLE: CIFO
MNEM CHAN DIMT CNAM
ODEP
----------------------------------------------------
GRAM GRAM GRAM 0.0
RPCL RPCL RPD 0.0
RPSL RPSL RPCSLM 0.0
RPCH RPCH RPS 0.0
RPSH RPSH RPCSHM 0.0
RACL RACL RAD 0.0
RASL RASL RACSLM 0.0
RACH RACH RAS 0.0
RASH RASH RACSHM 0.0
BDCM BDCM BDCM 0.0
DRHM DRHM DRHM 0.0
DPEM DPEM DPEM 0.0
NPCK NPCK NPCKSM 0.0
CALM CALM CALM 0.0
ROPS ROPS ROPS 0.0
RPTH RPTH RPTHM 0.0
TCDM TCDM TCDM 0.0
* FORMAT RECORD (TYPE# 64)
Data record type is: 0
Datum Frame Size is: 72 bytes
Logging direction is down (value= 255)
optical Log Depth Scale Units: Feet
Frame spacing: 0.250000
Frame spacing units: [F ]
Number of frames per record is:
One depth per frame (value= 0)
Datum Specification Block Sub-type is:
14
1
FRAME SPACE = 0.250 * F
ONE DEPTH PER FRAME
Tape depth ID: F
17 Curves:
Name Tool Code Samples Units Size Length
1 GRAM MWD 68 1 GAP I 4 4
2 RPCL MWD 68 1 OHMM 4 4
3 RPSL MWD 68 1 OHMM 4 4
4 RPCH MWD 68 1 OHMM 4 4
5 RPSH MWD 68 1 OHMM 4 4
6 RACL MWD 68 1 OHMM 4 4
7 RASL MWD 68 1 OHMM 4 4
8 RACH MWD 68 1 OHMM 4 4
9 RASH MWD 68 1 OHMM 4 4
10 BDCM MWD 68 1 G/C3 4 4
11 DRHM MWD 68 1 G/C3 4 4
12 DPEM MWD 68 1 BN/E 4 4
13 NPCK MWD 68 1 PU-S 4 4
14 CALM MWD 68 1 IN 4 4
15 ROPS MWD 68 1 FPHR 4 4
16 RPTH MWD 68 1 MINS 4 4
17 TCDM MWD 68 1 DEGF 4 4
-------
68
Total Data Records: 5
~
,~
Tape File Start Depth 2566.000000
Tape File End Depth 2581.000000
Tape File Level Spacing = 0.250000
Tape File Depth Units = feet
**** FILE TRAILER ****
Tape Subtile: 4
117 records...
Minimum record length:
Maximum record length:
8 bytes
4124 bytes
**** FILE HEADER ****
LDWG
.004
1024
*** LIS COMMENT RECORD ***
I!!!!!!!!!!!!!!!!!!
! ! ! !! !!!!!!!!!!!! ! !
FILE HEADER
FILE NUMBER:
RAW MWD
Curves and
BIT RUN NO:
DEPTH INCREMENT:
#
FILE SUMMARY
VENDOR TOOL CODE
MWD
$
LDWG File Version 1.000
Extract File: FILEO13.HED
4
log header data for each bit run in separate files.
2R
.2500
START DEPTH
2581.0
STOP DEPTH
4653.0
#
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME):
TD DRILLER (FT):
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT):
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG)
MINIMUM ANGLE:
MAXIMUM ANGLE:
14-MAR-02
MSB 18704
4.75 SDN
MEMORY
4705.0
2581. 0
4653.0
0
41. 0
46.0
#
TOOL STRING (TOP TO
VENDOR TOOL CODE
DIR
CCN
ORD
MPR
GRAM
$
BOTTOM)
TOOL TYPE
DIRECTIONAL
CAL. COR. NEUTRON
OPT. ROT. DENSITY
MULT. PROP. RESIST.
GAMMA RAY
TOOL NUMBER
DAS 1363
10044706
10044706
MPR 1073
SRIG 2117
#
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT):
6.750
2594.0
/~
"'-""',
#
BOREHOLE CONDITIONS
MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S):
MUD PH:
MUD CHLORIDES (PPM):
FLUID LOSS (C3):
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TEMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
Clay Seal
9.60
.0
.0
28500
.0
.000
.000
.000
.000
92.0
.0
.0
.0
#
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
#
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
#
SANDSTONE
2.65
.000
.0
0
REMARKS:
BIT RUN 2R (MWD Run 3).
GR/MPR/ORD/cCN.
CURVE GLOSSARY:
GRAM - GAMMA RAY APPARENT (MWD-API)
RPCL - DEEP PHASE RESISTIVITY (OHMM)
RPSL - MEDIUM PHASE RESISTIVITY (OHMM)
RPCH - SHALLOW PHASE RESISTIVITY (OHMM)
RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM)
BDCM - BULK DENSITY COMPENSATED (G/CC)
DRHM - DENSITY CORRECTION (G/CC)
DPEM - PHOTOELECTRIC CROSS SECTION (B/E)
NPCK - NEUTRON POROSITY, CALIPER & SALINITY
CORRECTED (SANDSTONE PU)
CALM - BOREHOLE CALIPER (INCH)
ROPS - RATE OF PENETRATION (FPHR)
RPTH - FORMATION EXPOSURE TIME (MIN)
TCDM - TEMPERATURE (DEGF)
PER PHILIPS ALASKA (WAYNE CAMPAIGN), THE
FOLLOWING CURVES ARE NOT PRESENTED ON THE
MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR
THE SAKE OF COMPLETENESS:
RACL - DEEP ATTENUATION RESISTIVITY (OHMM)
RASL - MEDIUM ATTENUATION RESISTIVITY (OHMM)
RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM)
RASH - EXTRA SHALLOW ATTENUATION RESISTIVITY (OHMM)
$
#
*** INFORMATION TABLE: CONS
MNEM VALU
------------------------------
WDFN
LCC
CN
WN
FN
COUN
STAT
2p-441. xtf
150
Phillips Alaska, Inc.
2P-441
Meltwater
North Slope
Alaska
*** INFORMATION TABLE: CIFO
MNEM CHAN DIMT CNAM
ODEP
~
~.
----------------------------------------------------
GRAM GRAM GRAM 0.0
RPCL RPCL RPD 0.0
RPSL RPSL RPCSLM 0.0
RPCH RPCH RPS 0.0
RPSH RPSH RPCSHM 0.0
RACL RACL RAD 0.0
RASL RASL RACSLM 0.0
RACH RACH RAS 0.0
RASH RASH RACSHM 0.0
BDCM BDCM BDCM 0.0
DRHM DRHM DRHM 0.0
DPEM DPEM DPEM 0.0
NPCK NPCK NPCKSM 0.0
CALM CALM CALM 0.0
ROPS ROPS ROPS 0.0
RPTH RPTH RPTHM 0.0
TCDM TCDM TCDM 0.0
* FORMAT RECORD (TYPE# 64)
Data record type is: 0
Datum Frame Size is: 72 bytes
Logging direction is down (value= 255)
Optical Log Depth Scale Units: Feet
Frame spacing: 0.250000
Frame spacing units: [F ]
Number of frames per record is:
One depth per frame (value= 0)
Datum Specification Block Sub-type is:
14
1
FRAME SPACE = 0.250 * F
ONE DEPTH PER FRAME
Tape depth ID: F
17 Curves:
Name Tool Code Samples Units Size Length
1 GRAM MWD 68 1 GAP I 4 4
2 RPCL MWD 68 1 0 HMM: 4 4
3 RPSL MWD 68 1 0 HMM: 4 4
4 RPCH MWD 68 1 0 HMM: 4 4
5 RPSH MWD 68 1 0 HMM: 4 4
6 RACL MWD 68 1 0 HMM: 4 4
7 RASL MWD 68 1 0 HMM: 4 4
8 RACH MWD 68 1 0 HMM: 4 4
9 RASH MWD 68 1 0 HMM: 4 4
10 BDCM MWD 68 1 G/C3 4 4
11 DRHM MWD 68 1 G/C3 4 4
12 DPEM MWD 68 1 BN/E 4 4
13 NPCK MWD 68 1 PU-S 4 4
14 CALM MWD 68 1 IN 4 4
15 ROPS MWD 68 1 FPHR 4 4
16 RPTH MWD 68 1 MINS 4 4
17 TCDM MWD 68 1 DEGF 4 4
-------
68
Total Data Records: 593
Tape File Start Depth 2581.000000
Tape File End Depth 4653.000000
Tape File Level spacing = 0.250000
~.
.~
Tape File Depth Units
= feet
**** FILE TRAILER ****
Tape Subfile: 5
705 records...
Minimum record length:
Maximum record length:
8 bytes
4124 bytes
**** FILE HEADER ****
LDWG
.005
1024
*** LIS COMMENT RECORD ***
!! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !
!!!!!!!!!!!!! ! !!!!!
FILE HEADER
FILE NUMBER:
RAW MWD
Curves and
BIT RUN NO:
DEPTH INCREMENT:
#
FILE SUMMARY
VENDOR TOOL CODE
MWD
$
LDWG File Version 1.000
Extract File: FILEO14.HED
5
log header data for each bit run in separate files.
3
.2500
START DEPTH
4653.0
STOP DEPTH
5640.0
#
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME):
TD DRILLER (FT):
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT):
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG)
MINIMUM ANGLE:
MAXIMUM ANGLE:
19-MAR-02
MSB 18704
NaviGaroma
MEMORY
5690.0
4653.0
5640.0
0
46.0
46.0
#
TOOL STRING (TOP TO
VENDOR TOOL CODE
DIR
GRAM
$
BOTTOM)
TOOL TYPE
DIRECTIONAL
GAMMA RAY
TOOL NUMBER
DAS 1234
SGAM 9086
#
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT):
4.750
4696.0
#
BOREHOLE CONDITIONS
MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S):
MUD PH:
MUD CHLORIDES (PPM):
FLUID LOSS (C3):
LSND
9.50
.0
.0
600
.0
.~
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TEMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
#
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
#
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
#
REMARKS:
BIT RUN 3 (MWD Run 4).
GR/Directional.
CURVE GLOSSARY:
GRAM - GAMMA RAY APPARENT (MWD-API)
ROPS - RATE OF PENETRATION (FPHR)
RPTH - FORMATION EXPOSURE TIME (MIN)
TCDM - TEMPERATURE (DEGF)
$
#
*** INFORMATION TABLE: CONS
MNEM VALU
------------------------------
WDFN
LCC
CN
WN
FN
COUN
STAT
2p-441.xtf
150
Phillips Alaska, Inc.
2P-441
Meltwater
North Slope
Alaska
*** INFORMATION TABLE: CIFO
MNEM CHAN DIMT CNAM
ODEP
----------------------------------------------------
GRAM GRAM GRAM 0.0
ROPS ROPS ROPS 0.0
RPTH RPTH RPTHM 0.0
TCDM TCDM TCDM 0.0
* FORMAT RECORD (TYPE# 64)
Data record type is: 0
Datum Frame Size is: 20 bytes
Logging direction is down (value= 255)
Optical Log Depth Scale Units: Feet
Frame spacing: 0.250000
Frame spacing units: [F ]
Number of frames per record is:
One depth per frame (value= 0)
Datum specification Block Sub-type is:
50
1
FRAME SPACE =
0.250 * F
ONE DEPTH PER FRAME
Tape depth ID: F
4 Curves:
.~
.000
.000
.000
.000
.00
.000
.0
110.0
.0
.0
.0
0
,.-.....
Name Tool Code Samples Units Size Length
1 GRAM MWD 68 1 GAP I 4 4
2 ROPS MWD 68 1 FPHR 4 4
3 RPTH MWD 68 1 MINS 4 4
4 TCDM MWD 68 1 DEGF 4 4
-------
16
Total Data Records:
79
Tape File Start Depth 4653.000000
Tape File End Depth 5640.000000
Tape File Level Spacing = 0.250000
Tape File Depth Units = feet
**** FILE TRAILER ****
Tape Subfile: 6
156 records...
Minimum record length:
Maximum record length:
8 bytes
4124 bytes
**** FILE HEADER ****
LDWG
.006
1024
*** LIS COMMENT RECORD ***
! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! ! !
!! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! !
FILE HEADER
FILE NUMBER:
RAW MWD
Curves and
BIT RUN NO:
DEPTH INCREMENT:
#
FILE SUMMARY
VENDOR TOOL CODE
MWD
$
LDWG File Version 1.000
Extract File: FILEO15.HED
6
..--....
log header data for each bit run in separate files.
4
.2500
START DEPTH
4653.0
STOP DEPTH
5871. 0
#
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME):
TD DRILLER (FT):
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT):
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG)
MINIMUM ANGLE:
MAXIMUM ANGLE:
#
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE
20-MAR-02
MSB 18704
3.125 USR
MEMORY
5947.0
4653.0
5871.0
0
46.0
48.0
TOOL NUMBER
~.
DIR
MPR
GRAM
$
DIRECTIONAL
MULT. PROP. RESIST.
GAMMA RAY
#
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT):
#
BOREHOLE CONDITIONS
MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S):
MUD PH:
MUD CHLORIDES (PPM):
FLUID LOSS (C3):
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TEMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
#
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
#
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
#
.~
DAS 1234
USR 3007
SRIG 5317
4.750
4696.0
LSND
9.50
.0
.0
600
.0
.000
.000
.000
.000
110.0
.0
.0
.0
.00
.000
.0
0
BIT RUN 4 (MWD Run 5).
GR/USMPR.
THE INTERVAL FROM 4653 - 5640 WAS DRILLED ON THE
PREVIOUS BIT RUN. THE GR & ROP DATA FROM THIS INTERVAL
WAS ALSO COLLECTED ON THE PREVIOUS BIT RUN.
RESISTIVITY OVER THIS INTERVAL WAS COLLECTED ON A MAD
PASS PRIOR TO DRILLING AHEAD WITH THIS BIT RUN. ALL
DATA IS PRESENTED TOGETHER HERE FOR COMPLETENESS.
CURVE GLOSSARY:
GRAM - GAMMA RAY APPARENT (MWD-API)
RPCL - DEEP PHASE RESISTIVITY (OHMM)
RPCH - SHALLOW PHASE RESISTIVITY (OHMM)
ROPS - RATE OF PENETRATION (FPHR)
RPTH - FORMATION EXPOSURE TIME (MIN)
TCDM - TEMPERATURE (DEGF)
PER PHILIPS ALASKA (WAYNE CAMPAIGN), THE
FOLLOWING CURVES ARE NOT PRESENTED ON THE
MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR
THE SAKE OF COMPLETENESS:
RACL - DEEP ATTENUATION RESISTIVITY (OHMM)
RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM)
$
REMARKS:
#
*** INFORMATION TABLE: CONS
MNEM VALU
------------------------------
WDFN
LCC
CN
WN
FN
COUN
STAT
2p-441.xtf
150
Phillips Alaska, Inc.
2P-441
Meltwater
North Slope
Alaska
~,
.~
*** INFORMATION TABLE: CIFO
MNEM CHAN DIMT CNAM
ODEP
----------------------------------------------------
GRAM GRAM GRAM 0.0
RPCL RPCL RPD 0.0
RPCH RPCH RPS 0.0
RACL RACL RAD 0.0
RACH RACH RAS 0.0
ROPS ROPS ROPS 0.0
RPTH RPTH RPTHM 0.0
TCDM TCDM TCDM 0.0
* FORMAT RECORD (TYPE# 64)
Data record type is: 0
Datum Frame Size is: 36 bytes
Logging direction is down (value= 255)
Optical Log Depth Scale Units: Feet
Frame spacing: 0.250000
Frame spacing units: [F ]
Number of frames per record is:
One depth per frame (value= 0)
Datum Specification Block Sub-type is:
28
1
FRAME SPACE = 0.250 * F
ONE DEPTH PER FRAME
Tape depth ID: F
8 Curves:
Name Tool Code Samples Units Size Length
1 GRAM MWD 68 1 GAP I 4 4
2 RPCL MWD 68 1 OHMM 4 4
3 RPCH MWD 68 1 OHMM 4 4
4 RACL MWD 68 1 OHMM 4 4
5 RACH MWD 68 1 OHMM 4 4
6 ROPS MWD 68 1 FPHR 4 4
7 RPTH MWD 68 1 MINS 4 4
8 TCDM MWD 68 1 DEGF 4 4
-------
32
Total Data Records: 175
Tape File Start Depth 4653.000000
Tape File End Depth 5871.000000
Tape File Level Spacing = 0.250000
Tape File Depth Units = feet
**** FILE TRAILER ****
Tape Subfile: 7
271 records...
Minimum record length:
Maximum record length:
8 bytes
4124 bytes
**** FILE HEADER ****
LDWG
.007
~.
1024
*** LIS COMMENT RECORD ***
! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! ! !
!!!!!!!!!!!!!! ! ! !!!
FILE HEADER
FILE NUMBER:
RAW MWD
Curves and
BIT RUN NO:
DEPTH INCREMENT:
#
FILE SUMMARY
VENDOR TOOL CODE
MWD
$
LDWG File Version 1.000
Extract File: FILEO16.HED
7
..~
log header data for each bit run in separate files.
5
.2500
START DEPTH
5871. 0
STOP DEPTH
7327.0
#
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME):
TD DRILLER (FT):
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT):
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG)
MINIMUM ANGLE:
MAXIMUM ANGLE:
#
TOOL STRING (TOP TO
VENDOR TOOL CODE
DIR
MPR
GRAM
$
BOTTOM)
TOOL TYPE
DIRECTIONAL
MULT. PROP.
GAMMA RAY
RESIST.
#
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT):
#
BOREHOLE CONDITIONS
MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S):
MUD PH:
MUD CHLORIDES (PPM):
FLUID LOSS (C3):
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TEMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
#
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
#
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
23-MAR-02
MSB 18704
3.125 USR
MEMORY
7327.0
5871. 0
7327.0
0
43.0
48.0
TOOL NUMBER
DAS 7196
USR 3002
SRIG 5355
4.750
4696.0
LSND
9.30
.0
.0
600
.0
.000
.000
.000
.000
120.0
.0
.0
.0
.00
.000
.0
0
~
.~.
#
REMARKS:
BIT RUN 4R (MWÐ Run 6).
GR/USMPR.
CURVE GLOSSARY:
GRAM - GAMMA RAY APPARENT (MWÐ-API)
RPCL - DEEP PHASE RESISTIVITY (OHMM)
RPCH - SHALLOW PHASE RESISTIVITY (OHMM)
ROPS - RATE OF PENETRATION (FPHR)
RPTH - FORMATION EXPOSURE TIME (MIN)
TCDM - TEMPERATURE (DEGF)
PER PHILIPS ALASKA (WAYNE CAMPAIGN), THE
FOLLOWING CURVES ARE NOT PRESENTED ON THE
MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR
THE SAKE OF COMPLETENESS:
RACL - DEEP ATTENUATION RESISTIVITY (OHMM)
RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM)
$
#
*** INFORMATION TABLE: CONS
MNEM VALU
------------------------------
WDFN
LCC
CN
WN
FN
COUN
STAT
2p-441.xtf
150
Phillips Alaska, Inc.
2P-441
Meltwater
North Slope
Alaska
*** INFORMATION TABLE: CIFO
MNEM CHAN DIMT CNAM
ODEP
----------------------------------------------------
GRAM GRAM GRAM 0.0
RPCL RPCL RPD 0.0
RPCH RPCH RPS 0.0
RACL RACL RAD 0.0
RACH RACH RAS 0.0
ROPS ROPS ROPS 0.0
RPTH RPTH RPTHM 0.0
TCDM TCDM TCDM 0.0
* FORMAT RECORD (TYPE# 64)
Data record type is: 0
Datum Frame Size is: 36 bytes
Logging direction is down (value= 255)
Optical Log Depth Scale Units: Feet
Frame spacing: 0.250000
Frame spacing units: [F ]
Number of frames per record is:
One depth per frame (value= 0)
Datum Specification Block Sub-type is:
28
1
FRAME SPACE =
0.250 * F
ONE DEPTH PER FRAME
Tape depth ID: F
8 Curves:
Name
Tool
Code Samples Units
Size
Length
~
1 GRAM MWD 68 1 GAP I 4 4
2 RPCL MWD 68 1 OHMM 4 4
3 RPCH MWD 68 1 OHMM 4 4
4 RACL MWD 68 1 OHMM 4 4
5 RACH MWD 68 1 OHMM 4 4
6 ROPS MWD 68 1 FPHR 4 4
7 RPTH MWD 68 1 MINS 4 4
8 TCDM MWD 68 1 DEGF 4 4
-------
32
Total Data Records: 209
Tape File Start Depth 5871.000000
Tape File End Depth 7327.000000
Tape File Level Spacing = 0.250000
Tape File Depth Units = feet
**** FILE TRAILER ****
Tape Subfile: 8
299 records...
Minimum record length:
Maximum record length:
8 bytes
4124 bytes
**** TAPE TRAILER ****
LDWG
03/02/26
01
**** REEL TRAILER ****
LDWG
03/02/27
AWS
01
Tape Subtile: 9
2 records...
Minimum record length:
Maximum record length:
132 bytes
132 bytes
.~
