Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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Image Project Well History File Cover Page
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10/6/2005 Well History File Cover Page. doc
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Transmittal Form
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BAKER
HUGHES
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Anchorage GEOScience Center
To: AOGCC
333 West 7th Ave, Suite 100
Anchorage, Alaska
99501
Attention: Helen Warman
Reference: lC-08Ll
Contains the following:
2 LDWG Compact Disc
(Includes Graphic Image files)
2 LDWG lister summary
2 bluelines - MPR-DIR_md Log
2 bluelines - MPR-DIR_tvd Log
5CAMNED JAN () 8 2007
LAC Job#: 726009
Sent By: cose~
Received By: {l
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Date: Dec. 10,2006
Date: r/5/D?
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETU~~ING
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
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DATA SUBMITTAL COMPLIANCE REPORT
9/11/2006
Permit to Drill 2041120
MD 11351 ,/ TVD
Well NamelNo. KUPARUK RIV UNIT 1C-08L 1-01
/ _r
Completion Date 8/13/2004
Operator CONOCOPHILLlPS ALASKA INC
)pu.d 3~~<f
API No. 50-029-20585-61-00
6460
Completion Status
1-01L
Current Status 1-01L
UIC N
-~--------~.--_._---~
--~---~._~-
----.---
--"-
-------_._~-
REQUIRED INFORMATION
Mud Log No
Samples No
Directional Survey Yes
-_._-~-~"-~_.
DATA INFORMATION
Types Electric or Other Logs Run: GR, RES
Well Log Information:
(data taken from Logs Portion of Master Well Data Maint
5 Blu
Interval .
OH/
Start Stop CH Received Comments
Open 8122/2006 -------1
8930 11351 11/8/2004 I
8938 11351 Open 8/22/2006 GR, ROP, Res i
I
9732 11351 Open 8/22/2006 Multi Propagation Res GR I
11-Aug-2004 w/Graphics
9732 11351 Open 8/22/2006 Multi Propagation Res GR
11-Aug-2004 w/Graphics
Log/ Electr
Data Digital Dataset
Type Med/Frmt Number Name
rr;-~- 14~ LIS Verification
I Rpt 1tt
Rpt Directional Survey
lED C Lis 140j('}" Induction/Resistivity
)~
Log 14QiO Induction/Resistivity
I >,
I Log 14o.~ Induction/Resistivity
I }C(
Log Log Run
Scale Media No
25 Blu
Well CoreslSamples Information:
Name
Interval
Start Stop
Sent
Received
Sample
Set
Number Comments
ADDITIONAL INFORMATION
Well Cored? Y ~
Chips Received? ~
Analysis ~
Received?
Daily History Received?
~
.
Formation Tops
~-
Comments:
~
------~~-~--
Compliance Reviewed By: _ ---
,
Date: ) ~ 5~~~-=
.
Transmittal Form
INTEQ
To: AOGCC
333 West 7th Ave, Suite 100
Anchorage, Alaska
99501
Attention: Helen Warman
Reference: 1C-08L1 & 1C-08L101
Contains the following:
2 LDWG Compact Disc
(Includes Graphic Image files)
2 LDWG lister summary
2 bluelines - MPR-DIR _ md Log
2 bluelines - MPR-DIR_tvd Log
LAC Job#: 726009
Sent By: Cosetta Todirica
Received By: C-- ~---------
f2hr ì'5rH/ot e.- (ho./Ut /( efll
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BAKER
HUGHES
Anchorage GEOScience Center
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PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING
OR FAXING YOUR COpy
FAX: (907) 267-6623
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Baker Hughes INTEQ
7260 Homer Drive
Anchorage, Alaska
99518
Direct: (907) 267-6612
FAX: (907) 267-6623
Date: August 17, 2006
Date: ?;-/();:J/D ~
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Terrie Hubble
Direct: (907) 564-4628
hubbletl@bp.com
Technical Assistant
GPB Drilling & Wells
September 15, 2004
Alaska Oil & Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
Reference: Permit to Drill, 204-111, 204-112
To \'V'hom It May Concern:
~'f.
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BP Exploration (Alaska) Inc.
900 East Benson Boulevard
PO Box 196612
Anchorage, Alaska 99519-6612
(907) 561-5111
In addition to the attached Completion Reports for lC-08Ll and lC-08L1-01, I am also submitting the As-
Built on record for 1 C-08. It came to our attention that the surface location for this series of wells was
incorrectly reported in the past. The two Completion Reports now being submitted match what is in our
databases and the As-Built.
Thank you very much for your assistance in this matter,
Sincerely,
~~~
Terrie Hubble
.. STATE OF ALASKA I ~ECEIVED
ALAS~ILAND GAS CONSERVATION COM bSIO~'·
WELL COMPLETION OR RECOMPLETION REPORT AND L~p 1 5 2004
Alaska Oil & Gas Cons, Commission
1a. Well Status: 181 Oil D Gas D Plugged D Abandoned D Suspended D WAG 1b. WelAr:lClarage
20AAC25.105 20AAC25.110 181 Development D Exploratory
No. of Completions One Other D Stratigraphic D Service
5. Date Comp., Susp., or Aband. 12. Permit to Drill Number
8/13/2004 ".. 204-112
6. Date Spudded ~''8 'ð:.( ø . 13. API Number
.~ q.If..(.1>1 50-029-20585-61-00
7. Date T.D. Reached 14. Well Name and Number:
8/11/2004 "". KUP 1 C-08L 1-01
8. KB Elevation (ft): 15. Field I Pool(s):
94' Kuparuk River Field / Kuparuk
River Oil Pool
D GINJ D WINJ D WDSPL
2. Operator Name:
Conoco Phillips Alaska Inc.
3. Address:
clo P.O. Box 196612, Anchorage, Alaska 99519-6612
4a. Location of Well (Governmental Section):
Surface:
1240' SNL, 660' EWL, SEC. 12, T11N, R10E, UM
Top of Productive Horizon:
1147' NSL, 4101' WEL, SEC. 02, T11N, R10E, UM
Total Depth:
2869' NSL, 97' WEL, SEC. 03, T11N, R10E, UM
4b. Location of Well (State Base Plane Coordinates):
Surface: x- 561664 J y- 5968993" Zone- ASP4
TPI: x- 556882 y- 5971343 Zone- ASP4
Total Depth: x- 555592" y- 5973055' Zone- ASP4
18. Directional Survey 181 Yes D No
9. Plug Back Depth (MD+ TVD)
11351 + 6460
10. Total Depth (MD+TVD)
; 11351 + 6460,
11. Depth where SSSV set
1806' MD
19. Water depth, if offshore
N/A MSL
21. Logs Run:
GR, RES
22.
CASING, liNER AND CEMENTING RECORD
SmlNG DEf'THMD SeTTINGDEf'THTIID
I OpBÖT!"OM BOTTOM
Surface 80' Surface 80'
Surface 2714' Surface 2587'
Surface 8933' Surface 6438'
8713' 11270' 6269' 6460'
16"
10-3/4"
WI. PE~FT.
65#
45.5#
26#
6.2# I 6.4#
H-40
K-55
K-55
L-80
36" 425 sx Arcticset II
13-3/4" 3125 sx Arcticset II
8-3/4" 974 sx Arcticset II
4-1/8' x 3-3/4" Uncemented Slotted Liner
7"
3-3/16" x 2-7/8"
23. Perforations op'en to Production (MD + TVD of Top and
Bottom Interval, Size and Number; if none, state "none"):
3-3/16" Slotted Section 2-7/8" Slotted Section
MD TVD MD TVD
8796' - 9408' 6333' - 6501' 9427' - 9903' 6501' - 6505'
10189' - 11236' 6468' - 6459'
24,
SIZE
4-1/2", 12.6#, L-80
Ft
Ft
16. Property Designation:
ADL 025648
17. Land Use Permit:
20. Thickness of Permafrost
1650' (Approx.)
V^P Q732/p1,þ .Ai>
r-..lJ f;> 5""(;4>' 'TY~ q. 'Z( .t..Xf
AMOUNT
PULLED
DEPTH SET (MD)
8823'
PACKER SET (MD)
8639'
DEPTH INTERVAL (MD)
8615'
AMOUNT & KIND OF MATERIAL USED
Freeze Protect with Diesel
26.
Date First Production:
August27,2004
Date of Test Hours Tested PRODUCTION FOR
TEST PERIOD ...
Flow Tubing Casing Pressure CALCULATED .........
Press. 24-HoUR RATET
27. CORE DATA
Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary).
Submit core chips; if none, state "none". ëòMPI81õÑl
None ; -Br:J.1. O>ll
Rooø~SfL SEP 2 lOR I G I ~J I~ L . 'f"Rem f
L=~!?:~;=;:J ~ !--'
PRODUCTION TEST
Method of Operation (Flowing, Gas Lift, etc.):
Flowing
OIL-BsL GAs-McF WATER-BsL
OIL -BSL
GAs-McF
W A TER-BsL
Form 10-407 Revised 12/2003
CONTINUED ON REVERSE SIDE
CHOKE SIZE I GAS-OIL RATIO
OIL GRAVITY-API (CORR)
G
28.
e-
GEOLOGIC MARKERS
29.
e
FORMATION TESTS
NAME
MD
TVD
Include and briefly summarize test results. List intervals tested,
and attach detailed supporting data as necessary. If no tests
were conducted, state "None".
Kuparuk C2
10276'
6452'
None
Kuparuk C3
10464'
6426'
Base Kuparuk C4
11115'
6452'
RECEIVED
SEP 1 5 2004
Alaska Oil & Gas Cons, Commission
Anchorage
30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys
31. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Signed Terrie HUbble~j)"; (J ~ Title Technical Assistant Date ocr -IS -0 L(
KUP 1C-08L 1-01 204-112 Prepared By Name/Number: Terrie Hubble, 564-4628
Well Number P Drilling Engineer: Dan Kara, 564-5667
ermit No. I Approval No.
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.
IrEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water
Supply for Injection, Observation, or Other. 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.
IrEM 4b: TPI (Top of Producing Interval).
IrEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other
spaces on this form and in any attachments.
IrEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
IrEM 20: True vertical thickness.
IrEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the
cementing tool.
IrEM 23: 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).
IrEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or
Other (explain).
IrEM 27: If no cores taken, indicate "None",
IrEM 29: List all test information. If none, state "None".
Form 10-407 Revised 12/2003
Submit Original Only
e
e
BP EXPLORA TIO
Operations Summary
Start: 7/28/2004
Rig Release: 8/13/2004
Rig Number: 2
Phase
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1 C-08
1 C-08
REENTER+COMPLETE
NORDIC CALISTA
NORDIC 2
7/28/2004 21 :00 - 00:00 3.00 MOB P PRE
7/29/2004 00:00 - 01 :30 1.50 MOB P PRE
01:30 - 03:15 1.75 MOB P PRE
03:15 - 14:30 11.25 MOB P PRE
14:30 - 19:00 4.50 BOPSUF P PRE
19:00 - 20:15 1.25 MOB P PRE
20:15 - 21:30 1.25 BOPSUP P PRE
21 :30 - 23:00 1.50 BOPSUF N SFAL PRE
23:00 - 00:00 1.00 MOB P PRE
7/30/2004 00:00 - 01 :30 1.50 MOB P PRE
01 :30 - 07:30 6.00 BOPSUPP PRE
07:30 - 08:30 1.00 RIGU P PRE
08:30 - 09:30 1.00 RIGU P PRE
09:30 - 10:30 1.00 RIGU P PRE
10:30 - 14:30 4.00 RIGU P PRE
14:30 - 15:30 1.00 RIGU P PRE
15:30 - 15:45 0.25 RIGU P PRE
15:45 - 17:30 1.75 RIGU P PRE
17:30 - 18:10 0.67 RIGU P PRE
18:10 - 18:20 0.17 RIGU P PRE
18:20 - 19:30 1.17 RIGU P PRE
19:30 - 20:45 1.25 RIGU P PRE
20:45 - 21 :20 0.58 RIGU P PRE
Page 1 of 13
rt
Spud Date: 5/16/1981
End: 8/13/2004
2004 Maintenance finished
Back rig out onto Spine at Z Pad corner. Start move to
Kuparuk and nearing Milne Pt cutoff at midnite
Continue move to 1 C Pad
Just past MPU junction and had to remove 2 inner bogie tires
after crossing rig mats
Resume move to 1C Pad. Rig on location at 1045 am. Begin
RU. Set rig mats around well head. Verify 1C-12 is shut in at
surface. Place BOPS in cellar and hook up hydraulic lines.
Move over well. Accept rig at 1430 on 7-29-04.
NU BOPS. Level rig. Install 2-3/8" E-CT. Spot mise
equipment
Walkthru w/16 members of Kuparuk Emergency Services
Resume NU BOPE. Spot cuttings box. Fill pits w/ 9.0 ppg
milling fluid (used FloPro mud)
Function test rams
Body test BOP to 4500 psi and leaked at 3" slip ram door.
Replace seals and retest
Prespud mtg wI rig personnel
Load BHI tools into pipeshed. Fin plumb DOD choke. Install
hardline in reel house. APe plumb hardline to tiger tanks
BOPE test to 4500 psi. Witness waived by AOGCC, C.
Scheve. E-mail all data to AOGCC.
SPot KWF upright behind cuttings tank. Berm and load same
with 10.5 ppg brine. Round up slickline components for
deployment system. Complete pad inspection with DSO.
Hold ATP/Pre spud review with day crew in ops cab. Discuss
importance of all aspects of HSE, particularly with new
operations and pressure deployment proceedures. Discuss
objectives and details of well plan. Review DOCTD operations,
new choke schedule.
Install ESD valve on rig floor for 1C-12 well. Review SSSV
panel operations with drill site tech with all hands. Close sssv.
Bleed well. Zero WHP, sssv holding.
MU 4-1/16" deployment lubricator. RU slickline unit and tools.
Change packoff. Hang lubricator in blocks. Test gen set
loading while MU pressure deployment equipment.
Hold table top deployment exercise in ops cab with day crew.
Review steps and make preliminary changes to reflect big tool
BOP configuration.
Pressure test lubricator to 1500 psi with water.
Practice pressure deploy full resistivity MWD & motor. Able to
fit 82' BHA into combination lubricator & wellbore, above closed
master valve. Set in slips. Close VBR's. Unstab lubricator.
Verify ball valve can be accessed. Stab back on well.
Practice un-deploy BHA.
Safety mtg re: plan ahead
RU hoses to injector and general preps to rig floor. Remove bit
and motor, install tree cap
Hands practice using Swaco choke while circulating over the
top. Find that DS monitor has a short, will fix in am (when tech
can get across Kup bridge)
Table top mtg on deploylundeploy procedure
Printed: 8/16/2004 8:58:22 AM
e
BP EXPLORATION
Operations Summary Report
Open master and check well for pressure above closed
TRSSSV-none
Practice pressure deploy/undeploy w/ full BHA. LD BHA tools,
standback lubricator
Set injector on well. Install packoff
Install gooseneck and fin prep injector. Pull CT off reel and
stab. RD tools
Install temporary eTC. Stab onto well. Fill CT wI used mud
system. Got another 'strawberry shake' back initially, then
returns cleaned up (CT had been blown down w/ N2 and rusted
inside for a couple weeks/unknown concentration of Flo Lube in
used mud, but probably was same system from L2-21 . . .)
PT flowpath at 4000 psi. Reverse slack back at 3.4/3400
Cut off 66' CT to find wire
Install CTC. PT 35k
Rehead BHI
Test weight cell on injector.
Install one 2' and two 3' lubricators under injector (for ball valve
space out). MU Baker/lnteq milling assembly (3.8" one step &
string reamer w/ straight motor).
Stab coil. Get on well. Test MWD - ok.
RIH. Zero WHP with SSSV closed.
Stop at 1600'. Pressure well to 700 psi. Well began taking
fluid. Pump sssv open.
RIH taking returns to tiger tank. Follow PWD pressure
schedule while RIH to maintain constant BHP (3450 psi at
8900')
Circulate well to milling fluid (9.0 ppg flo pro). Pump 40 bbls hi
vis clean pill. 1.38 in/1.210ut with 240 psi whp. Increase rate
to 2.0 with zero whp. 1:1 rtns.
Pill to bit. Shut in well and inject pill at 1.0 bpm @ 360 psi.
Close in well to close ECD on mwd. WHP static at 360 psi.
WEXIT Tag WS at 8956' dry (uncorrected). PU and circulate. 2.65
bpm in/1.75 bpm out. Losing too much fluid to continue. Lots
of extra formate on location, but no inexpensive milling fluid.
Call for trucks to get seawater from KRU and more used flc-pro
from Deadhorse.
DPRB WEXIT Shut in well w/ 390 psi. Order used flopro, LCM and additional
biozan from Deadhorse. Order seawater from KRU. Wait on
fluid.
WEXIT Milling window. 2900 psi @ 2.54 in/2.03 out. 36K# up, 12k#
dn wt. ECD: 10.65 ppg. Top of WS at 8930' e-line setting
depth. Tag WS pinch point at 8934.6'. Paint orange flag at
pinch point. Losses slowly healing.
Start milling at 0.1' per 5 minutes.
2.53 in/2.77 out. Increase WHP to 90-100 psi. 2.53 in/2.43
out.
WEXIT Continue milling window at 8935.73. Holding 350 psi whp.
DHP:3461 psi @ 2.32 in/2.35 out.
WEXIT 8936.9' 2.7/2.7/2840/320 ECD 10.5=3462 DHP, PVT 198
WEXIT 8937.5' PUH 32k to chk FS and zero BHI WOB
Resume milling 2.7/2.7/2700/300/3456 ECD 10.53 w/ fluid
density of 8.7+ PVT 198
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
Date
1 C-08
1 C-08
REENTER+COMPLETE
NORDIC CALISTA
NORDIC 2
7/30/2004
Code NPT
21 :20 - 21 :35 0.25 RIGU P PRE
21 :35 - 23:30 1.92 RIGU P PRE
23:30 - 00:00 0.50 RIGU P PRE
00:00 - 02:30 2.50 RIGU P PRE
02:30 - 04:00 1.50 RIGU P PRE
7/31/2004
04:00 - 04:30 0.50 RIGU P PRE
04:30 - 05:00 0.50 RIGU P PRE
05:00 - 07:00 2.00 RIGU P PRE
07:00 - 07:30 0.50 RIGU P PRE
07:30 - 10:00 2.50 STWHIP P WEXIT
10:00 - 10:45 0.75 STWHIP P WEXIT
10:45 - 11:00 0.25 STWHIP P WEXIT
11:00 -12:15 1.25 STWHIP P WEXIT
12:15 - 13:45 1.50 STWHIP P WEXIT
13:45 - 14:15
0.50 STWHIP P
14:15 - 15:45
1.50 STWHIP N
15:45 - 17:00
1.25 STWHIP P
17:00 - 18:30
1.50 STWHIP P
18:30 - 19:15
19:15 - 21:00
0.75 STWHIP P
1.75 STWHIP P
Page 2 of 13
Start: 7/28/2004
Rig Release: 8/13/2004
Rig Number: 2
Spud Date: 5/16/1981
End: 8/13/2004
Printed; 8/1612004 8;58;22 AM
e
e
BP EXPLORATION
Operations Summary Re
WEXIT 8940.0' at calc BOW 2.7/2.7/2700/290/3445 w/ 100 psi diff,
ECD 10.48, 1.2k wob, PVT 198 and appears that this is also
the true BOW based on getting string wt back. Get SR thru
window after 1.5 hrs, then drill formation at 3'lhr to 8944', PVT
198
Drill rathole from 8944-50' at 6'lhr PVT 198 No stalls thruout
window milling
Backream and ream window, clean. Dry tag, clean wI 524 psi
static, 3458 psi DHP 32k, 12k. Open EDC
POOH following pressure schedule. Close TRSSSV at 1500'.
Check for flow at 500'. Close EDC. POOH
LD milling BHA. Mill had center wear and gauged 3.80", 3.79"
NG
MU build assy
RIH w/ BHA #2 (3.0 deg, HCC bi bit) w/ closed choke until
pressure stabliized at 560 psi. Open TRSSSV. RIH using
pressure schedule
Log initial GR tie in from 8820' to 8915' using goo's PDC log.
-19' correction. RIH.
RIH. Tag TD at 8952'. 32k# up, 14k# dn wt
Begin displacement to 9.0 ppg formate flo-pro.
Drill ahead. 2800 psi fs @ 2.6 in/out. 200-400 dpsi mtr work.
WHP:320 psi. ECD: 10.56 ppg/3465 psi BHP. TF:10L. ROP:
30-50 fph. WOB: 1.5-2.5K#
Reduce whp as 9.0 mud displaces coil annulus.
PROD1 Drill ahead. Choke full open, WHP 33 psi. BHP:3476 psi,
ECD: 10.56 ppg (450-500 psi incremental over static bhp) with
9.0 ppg mud all the way around.
Circ rate: 2.51 in! 2.36 out @ 2800 psi fs.
Complete build. Estimate inc at bit: 90 deg.
PROD1 Wiper trip back to window. Make two passes through 7". Circ
OOH at full rate as per BHP schedule.
PROD1 At surface. Get off well. Unstab coif. LD BHA. HTC bi-center
had several broken gauge cutters and one broken nose cutter.
Grade:2-3-0.
MU resistivity BHA assembly with 1.5 deg mtr & HCC bi-center.
Stab coif. Get on well. Test MWD.
RIH to SSSV. Pressure well to 535 psi. Open sssv. Continue
to RIH. Adjust whp to maintain constant BHP as per schedule.
Correct -15' to white flag. Log gr tie in from 8860' to 8902'.
Add 2' correction.
RIH to TD.
Drill ahead. 3050 psi @ 2.53 in/2.45 out. Resistivity doesn't
appear to be working-will log later
Drill ahead wI open choke 2.75/2.5213200/110R ECD 10.75,
DHP 3572, 100-250 psi diff, 0-1k wob @ 91 deg
Revised depths to geo's PDC log are TOWS 8928', TOW
8932.6', BOW 8938.0', RA 8938.0'
Wiper to window, clean
Drill ahead w/ open chole 2.51/2.30/3080/90L ECD 10.78, DHP
3582,100-250 psi diff, 0-2k wob @ 91 deg PVT 282
Stacking, wiper to window PVT 270
Drill ahead w/ open choke albiet slowly and wI a few stalls and
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1 C-08
1 C-08
REENTER+COMPLETE
NORDIC CALISTA
NORDIC 2
Hours Task Code NPT Phase
7/31/2004
21 :00 - 00:00
3.00 STWHIP P
8/1/2004 00:00 - 00:55 0.92 STWHIP P WEXIT
00:55 - 01 :50 0.92 STWHIP P WEXIT
01 :50 - 03:20 1.50 STWHIP P WEXIT
03:20 - 04:00 0.67 STWHIP P WEXIT
04:00 - 04:50 0.83 STKOH P PROD1
04:50 - 06:45 1.92 DRILL P PROD1
06:45 - 07:30 0.75 DRILL P PROD1
07:30 - 08:30 1.00 DRILL P PROD1
08:30 - 1 0:30
2.00 DRILL P
10:30 - 12:30
2.00 DRILL P
12:30 - 14:45
2.25 DRILL P
14:45 - 16:30 1.75 DRILL P PROD1
16:30 - 17:00 0.50 DRILL P PROD1
17:00 - 17:15 0.25 DRILL P PROD1
17:15 - 18:30 1.25 DRILL P PROD1
18:30 - 19:00 0.50 DRILL P PROD1
19:00 - 19:20 0.33 DRILL P PROD1
19:20 - 20:15 0.92 DRILL P PROD1
20:15 - 20:35 0.33 DRILL P PROD1
20:35 - 22:00 1.42 DRILL P PROD1
Start: 7/28/2004
Rig Release: 8/13/2004
Rig Number: 2
Spud Date: 5/16/1981
End: 8/13/2004
of
Printed: 8/1612004 8:58:22 AM
it
BP EX
Operations S
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
Date
1 C-08
1 C-08
REENTER+COMPLETE
NORDIC CALISTA
NORDIC 2
e
TION
aryReport
Page 4 of 13
Start: 7/28/2004
Rig Release: 8/13/2004
Rig Number: 2
Spud Date: 5/16/1981
End: 8/13/2004
Task Code
Description of Operations
PROD1 lower losses after solids from wiper got to surface
2.56/2.50/3200/120L ECD 10.71, DHP 3560 PVT 255
Penetration rate increased at 9410' as did returns to 2.56/2.63.
Increase pump rate wI open choke to compensate
2.7/2.65/3240/60R ECD 10.79 DHP 3582-appears we are right
on the edge of balance wI open choke at drilling rate. Solids in
annulus and pump rate determine the loss rate since just
before wiper 2.7/2.4 ECD 10.84 DHP 3608 PVT 244
Wiper to window. PUH thru window and recip twice to EOT to
flush any solids to surface and 'out' density incr to 9.30 ppg vs
9.05 ppg clean PVT 224
Drill ahead wI open choke 2.7/2.6/3250/80R ECD 10.8 DHP
3590 at 90 deg at 6406' TVD PVT 200
Wiper to window (while fix CTDS which locked up, and then
BHI screen. . .)
Finish wiper to window, clean. Tie-in to RA pip, no correction.
Wiper to TD, clean PVT 189
Drill ahead 2.73/2.70/3260/90L ECD 10.8 DHP 3590 and are
not getting required turn to stay in polygon. Drill to 9728'. With
12* DLS will cross intersection of fault (at 60 deg) and top E/W
polygon line and exit polygon (will cut the corner). Discuss wI
geo's and will drill ahead
PROD1 Wiper to window, clean PVT 178
PROD1 Drill ahead 2.73/2.73/3270/100L ECD 10.82 DHP 3603 at 88
deg looking for the fault. Penetration rate decrease and
corresponding GR increase at 9920' must be the start of it.
Start adding fresh mud. Drill to 10000' and need to see about
20' more on the G R
100' wiper was clean
Drill ahead 2.7/2.6/3380/115L ECD 10.89 DHP 3629 at 6427'
TVD and 87 deg to 10020'
Wiper to window. Slow recip in 7". Park in 7" and SD pump to
check static pressure of 320 psi. Open EDC
POOH folllowing pressure schedule @ 2.7 bpm. At surface.
Run back in hole to 100'. Circ back to surface.
Get off well. Unstab coil. LD BHA. HCC bicenter in good
condition: 1-1-0.
Swap out resistivity tools. Re-calibrate HOT.
MU BHA in well.
Stab coil. Test MWD. Get on well.
RIH. Maintain constant BHP using drilling choke. Open sssv.
Continue in hole.
Log gr tie in from 8850'. (No flag) -15' correction.
Circulate in hole maintaining drilled TF.
Drill ahead. 3200 psi fs @ 2.66 in/2.57 out. 200-400 dpsi.
Tf:75r Inc:82 deg WOB:2k-4k#. ROP:20 - 150 fph.
ECD:10.77ppg/3594 psi @ 6440' TVD. Pvt:422 bbls
MAD pass up 300'/hr to 8975'
RIH to 10147' and set down. Pick up heavy. Work to get back
down and losing ground
Backream to 9900' 29k. RIH reaming 2.6/2.4 at 20'/min and
get to 10090' and stack out at drilled TF. PUH 70k and 20k
overpulls to 10050'-this is not where we want to go
8/1/2004
20:35 - 22:00
1.42 DRILL P
22:00 - 22:35 0.58 DRILL P PROD1
22:35 - 23:50 1.25 DRILL P PROD1
23:50 - 00:00 0.17 DRILL P PROD1
8/2/2004 00:00 - 00:40 0.67 DRILL P PROD1
00:40 - 01 :50 1.17 DRILL P PROD1
01 :50 - 02:35
02:35 - 03:50
0.75 DRILL P
1.25 DRILL P
03:50 - 04:00 0.17 DRILL P PROD1
04:00 - 04:15 0.25 DRILL P PROD1
04:15 - 04:45 0.50 DRILL P PROD1
04:45 - 06:30 1.75 DRILL P PROD1
06:30 - 08:30 2.00 DRILL P PROD1
08:30 - 11 :00 2.50 DRILL P PROD1
11 :00 - 11: 15 0.25 DRILL P PROD1
11:15 -11:45 0.50 DRILL P PROD1
11 :45 - 13:25 1.67 DRILL P PROD1
13:25 - 17:25 4.00 DRILL N DFAL PROD1
17:25 - 18:00 0.58 DRILL N DPRB PROD1
18:00 - 18:30 0.50 DRILL N DPRB PROD1
Printed: 8/16/2004 8:58:22 AM
tit
e
BP EXPLORA TJON
Operations Summary Report
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1 C-08
1 C-08
REENTER+COMPLETE
NORDIC CALISTA
NORDIC 2
Hours Task Code NPT Phase
8/2/2004 18:30 - 20:00 1.50 DRILL N DPRB PROD1
20:00 - 21 :45 1.75 DRILL N DPRB PROD1
21 :45 - 22:30 0.75 DRILL N DPRB PROD1
22:30 - 23:15 0.75 DRILL N DPRB PROD1
23:15 - 23:30 0.25 DRILL P PROD1
23:30 - 00:00 0.50 BOPSUF P PROD1
8/3/2004 00:00 - 05:00 5.00 BOPSUP P PROD1
05:00 - 07:00 2.00 STKOH X DPRB PROD1
07:00 - 09: 15 2.25 STKOH C PROD1
09:15-11:15 2.00 STKOH C PROD1
11:15-11:35 0.33 STKOH C PROD1
11 :35 - 12:00 0.42 STKOH C PROD1
12:00 - 12:10 0.17 STKOH C PROD1
12:10 - 12:30 0.33 STKOH C PROD1
12:30 - 14:15 1. 75 STKOH C PROD1
14:15 - 14:45 0.50 STKOH C PROD1
14:45 - 16:20 1.58 STKOH C PROD1
16:20 - 18:00 1.67 STKOH C PROD1
18:00 - 18:25 0.42 STKOH C PROD1
18:25 - 18:45 0.33 STKOH C PROD1
18:45 - 20:15 1.50 STKOH C PROD1
20:15-21:15 1.00 DRILL C PROD1
21 :15 - 00:00 2.75 DRILL C PROD1
8/4/2004 00:00 - 00:30 0.50 DRILL C PROD1
00:30 - 02:20 1.83 DRILL C PROD1
02:20 - 02:45 0.42 DRILL C PROD1
02:45 - 04:30 1.75 DRILL C PROD1
04:30 - 04:50 0.33 DRILL C PROD1
04:50 - 05: 15 0.42 DRILL C PROD1
05:15 - 05:30 0.25 DRILL C PROD1
Start: 7/28/2004
Rig Release: 8/13/2004
Rig Number: 2
Spud Date: 5/16/1981
End: 8/13/2004
of
Wiper 2.612.4/3250 ECD 10.8 DHP 3588 while circ up sample
and discuss. Recip in 7"
POOH following pressure schedule at 2.6 bpm while woo.
Close TRSSSV
LD drilling BHA
WOO
Discuss wI town team and decide the plan ahead. Will use OH
WS and kickoff HS. Kuparuk River Bridge is closed 6 pm to 6
am for upgrades and no WS's on this side of river-will test
BOP's in the meantime
Safety mtg re: plan aheadlBOP test
Test BOPE to 4500 psi. Witness waived by AOGCC
Continue BOPE test
WOWIIOHWS
MU 3.75" OH aluminum WS billet on e-coil.
RIH. Open SSSV. Continue in hole at 80 fph.
Log gr tie in from 8850' and no carr
RIH to 9550', clean. PUH 31k to set depth at 9539.8' at bottom
of tool. Close choke and trap 270 psi while close EDC. Static
WHP rose to 296 psi at 3522 DHP showing 10.53 ECD
Pressure up to 4534 psi and ball seat sheared. PUH 31k
leaving top of billet at 9525'
POOH at 30'/min thru OH
Open EDC. POOH following pressure schedule @ 2.1 bpm.
Retum mud was foamy and cut to 8.22 ppg, but gradually
retumed to 9.0 ppg. Close SSSV. Close EDC
LD WS setting tool
LD BHI tools and test. MU drilling assy
RIH wI BHA #6 (3.75' R335C, 1.5 deg, res). Open SSSV to
560 psi. RIH following pressure schedule @ 0.5 bpm
Log gr tie in from 8830' -2' correction
RIH tag top of OHWS at 9528'.
PU and orient TF to 335. Time drill ahead fl 9528' to 9531'
2.63/2.5/3685 ECD 10.78 DHP 3683 at 6407' TVD
Drill ahead fl 9531' to 9581 ' then hit siderite stringer.
Drilling siderrite stringer from 9581' to 9590'. 2.7/2.6345Ofs
ECD 10.723580 BHP Drilled at 95L. Turned up to 20L in an
attempt to drill out of siderite.
Continue with the attempt to drill out of siderite stringer from
9590'. No progress made. Good motorwork 5-600psi and
weight transfer.
TOH following pressure schedule to 8863'. Open EDC flush 7'
and continue TOH to above SSSV. Close SSSV trapping
525psi bleed off above valve and TOH to surface.
Change out bits. Bit #5 had 3 of the 6 blades broken off. Check
scribe marks on tools.
RIH to 850' ramp up pressure to 550psi to open flapper then
actuate opening sequence on SSSV. Continue RIH
Log tie in at RA -23' correction.
RIH. Res tool quit at 9250'. Continue on. No back-up tools
available on Slope or Anchorage. RIH past OHWS at 30L no
problems go to 9575'.
Wash/ream from 9575' to TO 2.69/2.61 3290fs 3550 BHP 10.7
Printed: 8/1612004 8:58:22 AM
e
e
BP EXPLORA ION
Operations Sum Report
Page 6 of 13
Legal Well Name: 1 C-08
Common Well Name: 1 C-08 Spud Date: 5/16/1981
Event Name: REENTER+COMPLETE Start: 7/28/2004 End: 8/13/2004
Contractor Name: NORDIC CALISTA Rig Release: 8/13/2004
Rig Name: NORDIC 2 Rig Number: 2
From.. To Hours Task Code NPT Description of ()P~rati0nS
8/4/2004 05:15 - 05:30 0.25 DRILL C PROD1 ECD
05:30 - 06:20 0.83 DRILL C PROD1 Directionally drill ahead fl 9590' purposely going slow first
several feet. Drill to 9593'. Increase WOB to 1.5k drilling off
better by 9595'. Increase pump 2.85/2.80 pinching off on choke
to maintain slightly greater loss 2.73/2.61 good ROP by 9597
3670bhp 10.75 ECD, but ground to a halt at 9616' w/4k wob.
No stalls (no indication of junk)
06:20 - 06:50 0.50 DRILL C PROD1 Wiper to above OH WS. Had overpull and MW at TOWS.
Work to revive res tool in 4-1/8' hole and appears to work. RIH
by OH WS at red rate, clean at 30L. Backream slowly above it
and was clean. RIH by OH WS at red rate, clean
06:50 - 07:05 0.25 DRILL X DFAL PROD1 Log MAD pass down from 9555' to capture missed data
07:05 - 08:00 0.92 DRILL C PROD1 Drill ahead at 20'lhr and sharp stall at 9619'. Work thru this
spot and then penetration rate picked back up to normal for this
interval-assume we are out of it. Drilled to 9675' and had
another sharp stall and progress slowed to zero for a while wi
4.2k wob, but then picked up
08:00 - 08:35 0.58 DRILL C PROD1 Drill ahead 2.7212.62/3450/70L w/100 psi whp, 3630 DHP, ECD
10.9 1 OO'lhr until started stacking
08:35 - 09:25 0.83 DRILL C PROD1 Wiper to window. Clean thru out OH and by OH WS
09:25 - 11 :20 1.92 DRILL C PROD1 Drill ahead 2.64/2.53/3430/70R wi 100 psi whp, 3634 DHP,
ECD 10.9 to 9900' Open choke to full open since it appears we
are charging up formation 2.73/2.71
11:20-12:15 0.92 DRILL C PROD1 Wiper to window was clean to 8963'. Stalled motor, pulled tite.
RBIH, free. Try it again and came thru window, clean. Recip
in 7" to cleanout cuttings
12:15 - 13:00 0.75 DRILL C PROD1 Log tie-in down from 8860'. Corr -39' (explains overpull . . . it
was the window). Park at 8884' and SD pump. Check CT
footage counter on injector and found a loose bolt. Static whp
385, DHP 3491 showing 10.74 ECD
13:00 - 13:30 0.50 DRILL C PROD1 RIH thru window, clean. Wiper to TD tagged at 9898', clean
13:30 - 15:10 1.67 DRILL C PROD1 Drill ahead 2.5/2.5/3240/80L wi open choke, DHP 3580, ECD
10.73 to 9920' and start stacking at 9895' which is probably
the first shale at 9920' in PB 1. Continue drilling ahead and had
more stacking-need new mud
15:10 - 16:05 0.92 DRILL C PROD1 Wiper to window was clean. Start new mud while RIH
16:05 - 17:30 1.42 DRILL C PROD1 Drill ahead 2.59/2.57/3350/90R wI open choke, DHP 3610,
ECD 10.87 Back in higher GR at 10080'. Have 10k overpull
on pickup at 10135'
17:30 - 18:45 1.25 DRILL C PROD1 Drill ahead from 10135' to 10190'.
18:45 - 19:45 1.00 DRILL P PROD1 Wiper to window. Flushed 7" annulus. Wi[per to bottom hole in
good shape.
19:45 - 22:15 2.50 DRILL P PROD1 Drill ahead f/ 10190' 2.80/2.823580 DHP 10.79 ECD.
9.0/9.0MW (new mud) Adjust choke to maintain 100whp
2.76/2.65 2-3k wob 150-200'/hr. Drill to 10340'.
22:15 - 23:00 0.75 DRILL P PROD1 Wiper back to window. Tight between 10170'-10120'
23:00 - 23: 15 0.25 DRILL P PROD1 Log tie-in 0 correction
23:15 - 00:00 0.75 DRILL P PROD1 Wiper back to bottom
8/5/2004 00:00 - 00:15 0.25 DRILL P PROD1 Finish making wiper trip to bottom. Minor amount of motor work
starting at 10050'. Slight setdown at 10212' recovered easily
and continue to bottom.
00:15 - 03:50 3.58 DRILL P PROD1 Drill ahead f/10340' 2.8/2.74 maintaining 100 psi at the choke
3654 DHP 10.98 ECD Rap slowed to 15'/hr starting at 10355'
Printed: 8/1612004 8:58:22 AM
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
8/5/2004
00:15 - 03:50
03:50 - 06:15
06:15 - 08:55
08:55 - 10:30
10:30 - 10:55
10:55 - 11 :20
11 :20 - 12:20
12:20 - 12:45
12:45 - 13:20
13:20 - 14:55
14:55 - 15:40
15:40 - 15:55
15:55 - 17:00
17:00 - 18:30
18:30-21:15
21:15 - 00:00
8/6/2004
00:00 - 01:10
01:10 - 03:20
03:20 - 03:35
03:35 - 04:45
04:45 - 07:45
07:45 - 08:30
08:30 - 08:50
08:50 - 09: 15
09:15 - 09:30
09:30 - 10:45
10:45 - 11 :35
e
e
BP EXPLORATION
Operations Summary Report
1 C-08
1 C-08
REENTER+COMPLETE
NORDIC CALISTA
NORDIC 2
Hours Task
3.58 DRILL
2.42 DRILL
2.67 DRILL
1.58 DRILL
0.42 DRILL
0.42 DRILL
1.00 DRILL
0.42 DRILL
0.58 DRILL
1.58 DRILL
0.75 DRILL
0.25 DRILL
1.08 DRILL
1.50 DRILL
2.75 DRILL
2.75 DRILL
1.17 DRILL
2.17 DRILL
0.25 DRILL
1.17 DRILL
3.00 DRILL
0.75 DRILL
0.33 CASE
0.42 CASE
0.25 CASE
1.25 CASE
0.83 CASE
Page 7 of 13
Start: 7/28/2004
Rig Release: 8/13/2004
Rig Number: 2
Spud Date: 5/16/1981
End: 8/13/2004
P
N
N
N
N
N
N
N
N
P
P
P
P
P
P
P
P
P
P
P
P
P
P
P
P
P
P
PROD1
DFAL PROD1
PROD1
PROD1
PROD1
PROD1
PROD1
PROD1
PROD1
PROD1
PROD1
PROD1
PROD1
PROD1
PROD1
PROD1
PROD1
PROD1
PROD1
PROD1
PROD1
PROD1
RUNPRD
RUNPRD
RUNPRD
RUNPRD
RUNPRD
Description of Operations
to 10385' picked up again until 10438' then hit another wall.
Ratty drilling to 10450' then lost contact with orientor.
TOH following pressure schedule to 8863'. Open EDC flush 7'
and continue TOH.
Change bit and orientor. Check motor. Bit was 1-4-1 w/ two
chipped cutters on the taper and 3 of 4 backcutters missing
(due to tagging the window)
RIH wi BHA # Pressure well bore to 560 psi and open SSSV
Log tie-in down from 8860', corr +2'
Wiper, clean to 10088' 2.45 bpm holding 150 psi whp, 3660
DHP, ECD 11.0
Set down at 10088', 10147', 10139', 10132'. Wiper up hole and
10k overpull at 10120'. Set down at 10178', 10165', 10258,
10280', 10265', 10290', 10345' wi 5-15k overpulls. RIH to TD
tagged at 10453'
Backream to 10050' @ 20'/min was relatively clean
Ream to TD 10-20'/min with set downs at 10181' and 10431'
Drill ahead 2.72/2.67/3450/60R holding 100 psi bp to hold 3650
DHP, 11.0 ECD. Reduce backpressure in 20 psi stages based
on ¡n/out rate and DHP. Swap to left at 10540'. Drill to 10600'
2.72/2.72 wi 60 psi bp 3660 DHP 10.94 ECD PVT 245
Wiper to window, clean!
Log tie-in down to RA pip wi well SI 580 psi whp, 3620 psi
DHP, add 1.0'
Wiper to TD and set down on OH WS at 9526' (orientor rolled
just before going by). Rest of hole was clean until set down at
10540' (TF change area). Appears 3650 psi DHP (11.0 EMW)
will control shales
Drill ahead 2.64/2.64/3430/90L wi 70 psi bp, 3660 DHP, 10.96
ECD, PVT 216 Drilled to 10750'.
Wiper trip back to window, 5k overpulls f/10250'- 10230' RIH
setdown at 985' plu and work area RIH other setdowns at
10160, 10433', 10510' mostly due to TF angles. After plu and
adjustment to TF RIH without too much further trouble. Liner
should pass these areas better.
Drill ahead. 3350fs 2.5/2.45 3670 DHP with 90psi WHP
11.0ECD Drilled to 10880'
Continue drilling ahead f/10880' to 10950' 2.62/2.54 w/85psi
whp 10.98 ECD 3675 DHP
Wiper trip above window. Cleanout 7' annulus. RIH
Log tie-in +5' correction.
Wiper to bottom. setdown at 10470' readjust TF and went
through good to bottom at 10954'.
TOH for liner. Paint flag at 8000', open EDC. Follow pressure
schedule at 2.8 bpm. Close SSSV
LD drilling BHA
LD extra lubricator and set injector on legs
RU to run liner
Safety mtg re: MU liner
MU and drift 30 jts predrilled (3/8' holes/8 pf) and one solid
2-7/8' 6.5# L-80 STL liner
MU WI! aluminum deployment sub wi GS and set in
mousehole. Install BHI BHA. MU extra lubs
Printed: 8/16/2004 8:58:22 AM
e
tit
BP EXPLORATION
Operations Sum. Report
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1 C-08
1 C-08
REENTER+COMPLETE
NORDIC CALISTA
NORDIC 2
Start: 7/28/2004
Rig Release: 8/13/2004
Rig Number: 2
Spud Date: 5/16/1981
End: 8/13/2004
From - To Hours Task Code· NPT
8/612004 11 :35 - 12:50 1.25 CASE N SFAL RUNPRD Test BHI tools before RIH and EDC not working. Break off
lubs, LD MWD tool and pickup backup BHA. Stab back onto
well and test okay
12:50 - 14:10 1.33 CASE P RUNPRD RIH wI liner on CT. Pressure wellbore to 550 psi and open
SSSV. RIH following pressure schedule @ 0.4 bpm thru EDC
14:10 - 14:50 0.67 CASE P RUNPRD 8880' 31k, 14.8k RIH thru window. See flag at 9041' and corr
-7'. RIH @ 42'/min and was clean to set down at 10650' which
was solid
14:50 - 15:55 1.08 CASE P RUNPRD Work to get past this point wlo success. Clean pickups, 37k.
PUH 200' and no overpulls, clean when RB/H. Try every trick
in the book and was solid. TOL would be at 9650'. Discuss.
Will do a cleanout run
15:55 - 16:45 0.83 CASE N DPRB RUNPRD POOH wI liner in open hole, 38k, clean. POOH at 1.4 bpm
following pressure schedule
16:45 - 17:15 0.50 CASE N RREP RUNPRD Park wI shoe in 7" to fix hydraulic leak on injector hp filter
17:15 - 18:45 1.50 CASE N DPRB RUNPRD Resume POOH close SSSV trapping 560psi below.
18:45 - 19:45 1.00 CASE N DPRB RUNPRD UD BHA and RU to standback liner
19:45 - 20:50 1.08 CASE N DPRB RUNPRD Stand 15 stds of 2-7/8" liner in derrick. No visible marks on the
end of guide shoe that would indicate running into something
and no marks on other liner componets. RID tools.
20:50 - 21 :50 1.00 CASE N DPRB RUNPRD P/U standard BHi drilling tools.
21:50 - 00:00 2.17 CASE N DPRB RUNPRD RIH to 1000' pressure up annulus to 600psi and open SSSV
dropped to 540psi. RIH following pressure schedule.
8/7/2004 00:00 - 00:20 0.33 CASE N DPRB RUNPRD Continue RIH
00:20 - 00:30 0.17 CASE N DPRB RUNPRD Log tie-in -15' correction
00:30 - 03:15 2.75 CASE N DPRB RUNPRD Continue RIH tagged at 9976' adjust TF and work area, same
for 10450'-60', continue to TD without problems. TOH to 10350'
and work area back to 10550' clean.
03:15 - 05:30 2.25 CASE N DPRB RUNPRD TOH following pressure schedule. Paint flag at 8000' EOP. Pull
above SSSV and close trapping 550psi below. TOH
05:30 - 06:00 0.50 CASE N DPRB RUNPRD UD BHi tools.
06:00 - 06:20 0.33 CASE N DPRB RUNPRD RU to run liner
06:20 - 06:30 0.17 CASE N DPRB RUNPRD Safety mtg re: MU liner
06:30 - 08:00 1.50 CASE N DPRB RUNPRD MU guide shoe (w/less taper), add 3.5" OD turbo to first jt,
then run same assy as prior run which was 30 jts of predrilled
3/8" holes/8 pf and one jt solid 2-718" 6.5# L-80 STL. MU BHI
assy on WI! aluminum deployment sub. Add lubs, stab onto
well
08:00 - 09:30 1.50 CASE N DPRB RUNPRD RIH wI liner assy on CT. Pressure above closed sssv to 550
psi and open sssv. RIH following pressure schedule
09:30 - 10:30 1.00 CASE N DPRB RUNPRD 9046' 32k, 14.3k Corr -12' to flag. RIH thru window and by OH
WS, clean. Close EDC and circ at 0.6 bpm while RIH at
70-100'/min. Get deployment sub by the OH WS, then RIH
120'/min until almost set down at 10650', got wt back, then got
to 10660'. PUH 15k over until gettingt normal wt back, then
use hyper speed to get to 10725'. Repeated attempts with
clean pickups gained nothing. Assume turbos are scraping
shales and depositing debris in belly of wellbore and 3.5" x 10'
deployment sub just won't pass. Need to be able to circ thru
shoe, but 1.5" /D of aluminum WS is too small for inner string
10:30 - 11 :45 1.25 CASE N DPRB RUNPRD Discuss while circ thru closed ECD with stacked wt' Work
occasionally with clean pickups 38k
11 :45 - 13:30 1.75 CASE P RUNPRD Circ at 2.0/3260 and release from liner wI 30.5k
Printed: 8/16/2004 8:58:22 AM
e
e
BP EXPLORATION
Operations Su ary Report
Page 9 of13
Legal Well Name: 1 C-08
Common Well Name: 1 C-08 Spud Date: 5/16/1981
Event Name: REENTER+COMPLETE Start: 7/28/2004 End: 8/13/2004
Contractor Name: NORDIC CALISTA Rig Release: 8/13/2004
Rig Name: NORDIC 2 Rig Number: 2
Date From·.. To Hours Task Desoription ofQperations
8/7/2004 11 :45 - 13:30 1.75 CASE P RUNPRD Top of aluminum billet is at 9725', top of predrilled liner is
9771', shoe is at 10725' and has no checks
POOH thru OH, clean. POOH following pressure schedule
13:30 - 14:00 0.50 CASE P RUNPRD LD liner running tools and BHI BHA
14:00 - 14:20 0.33 DRILL P PROD2 Rig evacuation/H2S drill-discuss
14:20 - 14:45 0.42 DRILL P PROD2 MU BHA incl 5' wt bar wlo resistivity
14:45 - 16:30 1.75 DRILL P PROD2 RIH wI BHA #11 (1.5 deg, 2533r bit)
16:30 - 16:55 0.42 DRILL P PROD2 Log tie-in to RA pip, corr _3'
16:55 - 17:25 0.50 DRILL P PROD2 Wiper in hole was clean
17:25 - 21 :20 3.92 DRILL P PROD2 Tag billet of deployment sub at 9732' at min rate. PUH 32k,
start pump. Set TF to highside and start time drilling of
aluminum billet. 2.74/2.723300 fs 3600 DHP time drilled to
9742'. Continued 40-50'/hr rop to 9785' confirming sidetrack
with NB surveys. PU to 9700' RIH dry to 9785' wo problems.
21 :20 - 23:45 2.42 DRILL P PROD2 TOH following pressure schedule.
23:45 - 00:00 0.25 DRILL P PROD2 UD BHi tools.
8/8/2004 00:00 - 01:15 1.25 DRILL P PROD2 P/U BHA #11 wi resitivity tool and HCC bi-center bit.
01:15 - 03:00 1.75 DRILL P PROD2 RIH charge annulus to 550psi and open SSSV. RIH
03:00 - 03:20 0.33 DRILL P PROD2 Log tie-in -13' correction
03:20 - 04:05 0.75 DRILL P PROD2 RIH to 9785'. Seen gas cut mud at surface max 32 units for 15
min ciruclation time.
04:05 - 06:50 2.75 DRILL P PROD2 Drill ahead with #2 lateral f/9785' 2.78/2.703650 DHP
maintaining 140psi on choke. 10D-120'/hr. Swap to new mud.
See GR change of first fault at 9885'
06:50 - 07:20 0.50 DRILL P PROD2 Wiper to window. Overpull and MW by deployment billet-will
try to dress it later wi bi bit
07:20 - 07:50 0.50 DRILL P PROD2 Backream billet at 9732' until clean
07:50 - 08:05 0.25 DRILL P PROD2 Fin wiper to TD
08:05 - 10:20 2.25 DRILL P PROD2 Drill ahead 2.7/2.69/3250/90R w/170 psi bp to hold 3630 psi
DHP, ECD 10.91 PVT 445. Tum TF HS at 9975' (6412' TVD)
to begin build from C2 to C4
10:20 - 11 :40 1.33 DRILL P PROD2 Wiper to window, tie-in to RA pip, corr + l'
11 :40 - 11 :45 0.08 DRILL P PROD2 Drill ahead 2.7/2.69/3300/90L wI 170 psi bp to hold 3640 DHP,
ECD 10.90 PVT 429
11 :45 - 12:00 0.25 DRILL N STUC PROD2 Stuck BHA while drilling at 10088' (differential). Try a couple
pulls at 70k wlo success. Go to neutral, SD pump and trap
WHP 465 psi, DHP 3600. WO Nordic crew change and watch
DHP bleed to 3588 psi. Pull free @ 50k
12:00 - 12:10 0.17 DRILL N STUC PROD2 Wiper to 9950', clean PVT 423
12:10- 14:10 2.00 DRILL P PROD2 Drill ahead 2.76/2.74/3340/95L wI 165 psi bp, DHP 3623, ECD
10.93 continuing invert and showing 104 deg NB incl at 10085'
120'/hr. Get to 10130' and starting to drill wi neg wt
14:10 - 15:25 1.25 DRILL P PROD2 Wiper to window, clean. Recip in 7" to flush cuttings. RBIH,
clean PVT 407
15:25 - 16:35 1.17 DRILL P PROD2 Drill ahead 2.77/2.71/3400/90R wI 175 psi bp, DHP 3630, ECD
10.95 holding 101 deg and continuing invert in the middle of
C2. Back to drilling wi positive wt after wiper. Get to 10300'
and tough to make hole. Spudding and not getting much motor
work, somewhat sticky pickups
16:35 - 17:30 0.92 DRILL P PROD2 Wiper to window, clean. Log tie-in to RA pip. Corr +5'
17:30 - 18:00 0.50 DRILL P PROD2 Wiper back to TD, clean
18:00 - 20:05 2.08 DRILL P PROD2 Drilling ahead f/10325' to 10475'. Drilling mostly with negitive
coil wieght, adding Lubetex to mud system to bring
Printed: 8/16/2004 8:58:22 AM
--
It
BP EXPLORATION
Operations Summary Report
Legal Well Name: 1 C-08
Common Well Name: 1 C-08 Spud Date: 5/16/1981
Event Name: REENTER+COMPLETE Start: 7/28/2004 End: 8/13/2004
Contractor Name: NORDIC CALISTA Rig Release: 8/13/2004
Rig Name: NORDIC 2 Rig Number: 2
From - To Hours Task Description
8/8/2004 18:00 - 20:05 2.08 DRILL P PROD2 concentration up to 4.5% 2.69/2.65 3630 DHp w/200psi at
choke 11.0ppg ECD.
20:05 - 22: 10 2.08 DRILL P PROD2 Wiper trip into 7". No problems out or back in.
22: 10 - 00:00 1.83 DRILL P PROD2 Drill ahead f/ 10475' 2.76/2.71 3300 fs 2-500psi mw 3650 DHP
and 190psi back pressure at choke. Drill to 10550' seeing
some siderite stringers.
8/9/2004 00:00 - 01 :00 1.00 DRILL P PROD2 Drill aheaad with lateral #2 f/ 10550' to 10607' 2.80/2.76
3660DHP. Lost comms with all BHi topols.
01 :00 - 03:30 2.50 DRILL N DFAL PROD2 TOH. No DHP readout. Follow choke pressure schedule to
TOH. Close SSSV continue pumping to surface then RIH
quickly to clear cuttings.
03:30 - 07:00 3.50 DRILL N DFAL PROD2 Unstab injector. Meg test BHA components and were okay.
Found flat spot on DS CTC. Cut off 40' CT
07:00 - 10:30 3.50 DRILL N DFAL PROD2 Test e-line and determine short is probably at collector. Tear
down collector and check e-line and has continuity, but won't
meg test. WO DS tech. Two different methods found a weak
spot at 9300-9400' from downhole end of eline
Offload used mud from pits in preparation for 60 hr Kuparuk
bridge closure starting at 1800 hrs
10:30 - 12:45 2.25 DRILL N DFAL PROD2 Mobilize equipment to swap E-CT reel out for the standby reel.
WO DS N2
12:45 - 13:00 0.25 DRILL N DFAL PROD2 Safety mtg re: N2 blowdown
13:00 - 15:00 2.00 DRILL N DFAL PROD2 Displace mud in CT wI N2 taking N2 to flowback tank
Fin vac used mud from pits and return to MI. Fill pits wI 290
bbls fresh 9.0 ppg formate mud w/4% L T
15:00 - 16:30 1.50 DRILL N DFAL PROD2 Safety mtg re: simops
Pull CT back to reel and secure. Lower E-CT onto Veco
lowboy. Load standby reel into reelhouse
Begin weekly BOPE test at 1530 hrs. Witness waived by
AOGCC
16:30 - 18:30 2.00 DRILL N DFAL PROD2 Hook up hardline in reel house and prep E-CT
Continue BOPE test
18:30 - 22:30 4.00 DRILL N DFAL PROD2 Prep end of coil for stabbing to injector. Stab coil.
22:30 - 00:00 1.50 DRILL N DFAL PROD2 Perform slack management with e-line. Cut 40' coil.
8/10/2004 00:00 - 04:00 4.00 DRILL N DFAL PROD2 Install SLB CTC and BHi upper quick connect. Will not MEG
test. Cut-off CTC completely rehead again. MEG tested okay.
Check well for pressure above SSSV - none.
04:00 - 05:45 1.75 DRILL N DFAL PROD2 Pick-up drilling BHA #12. (Test CTC and UQC to 3500psi
galled UQC sleeve and replaced). Stab on injector
05:45 - 06:20 0.58 DRILL N DFAL PROD2 Pump 1 coil volume at 2.5bpm with EDC open for slack
management.
06:20 - 07:55 1.58 DRILL N DFAL PROD2 RIH wI BHA #12 @ 0.1 bpm taking well bore fluids to pit #1.
Open SSSV to 560 psi. RIH following pressure schedule
07:55 - 08:15 0.33 DRILL N DFAL PROD2 Log tie-in down to RA pip, corr -15'
08: 15 - 09:00 0.75 DRILL N DFAL PROD2 RIH and precautionary ream to TD and was clean! PVT 274
09:00 - 09:45 0.75 DRILL P PROD2 Drill ahead 2.7/2.68/3290/170L-90L to hold 90 deg at 6325'
TVD wI 150 psi bp, 3660 DHP, ECD 11.05 60-1oo'/hr wI
borderline positive string wt. Mud system is completely
swapped to fresh mud w/4% L T
09:45 - 11 :50 2.08 DRILL P PROD2 Have trouble making hole past 10650', stacking, sharp
near-stalls. See deep ohms start to shoot off scale at 10630',
followed by medium, but both retumed to prior readings at
10665'? Penetration rate picked back up at 10680'. Drill in
Printed: 8/16/2004 8:58:22 AM
e
e
BP EXPLORATION
Operatio . mary Report
Page 11 of13
Legal Well Name: 1 C-08
Common Well Name: 1 C-08 Spud Date: 5/16/1981
Event Name: REENTER+COMPLETE Start: 7/28/2004 End: 8/13/2004
Contractor Name: NORDIC CALISTA Rig Release: 8/13/2004
Rig Name: NORDIC 2 Rig Number: 2
Date From - To Hours Task Code Déscripti()nqf...ºþ~rations
8/10/2004 09:45 - 11 :50 2.08 DRILL P PROD2 spurts w/ neg wt to 10734'
11 :50 - 12:30 0.67 DRILL P PROD2 Wiper to window, clean
12:30 - 12:45 0.25 DRILL P PROD2 Log tie-in down to RA pip, no corr
12:45 - 13:40 0.92 DRILL P PROD2 Wiper to TD, clean
13:40 - 15:50 2.17 DRILL P PROD2 Dril ahead 2.67/2.65/3230/85L w/150 psi bp, 3640 DHP, ECD
11.0 good ROP > 10790' to 10830' then falling back to 15'/hr
then very hard.
15:50 - 17:00 1.17 DRILL P PROD2 Wiper trip up to window - good (new target 6365'tvd at revised
TD of 11200')
17:00 - 18:00 1.00 DRILL P PROD2 Wiper back to bottom..no problems.
18:00 - 20:14 2.23 DRILL P PROD2 Drill ahead hard. 9.0/9.02.80/2.77 3670psi annular 11.14 ECD
holding 135psi at surface.
20:14 - 21:05 0.85 DRILL P PROD2 Drilling at 90R TF with negative WOB
MW=8.97/9.02
Qp = 2.81/2.72 bpm
Pa = 3674/4239 psi
ECD = 11.18ppg
Vp = 227 bbl
IAlOA = 700/63 psi
Vol KWF = 380 bbl ,11 ppg
21 :05 - 22:45 1.67 DRILL P PROD2 Wiper trip to TT to 8600' RIH to tie-in
22:45 - 22:54 0.15 DRILL P PROD2 Tie-in at RA Marker at 8938'/8960' Logging down (+ 1
correction)
22:54 - 00:00 1.10 DRILL P PROD2 RIH and corrected TF as per needed
8/11/2004 00:00 - 01 :45 1.75 DRILL P PROD2 Drilling at HS 57L TF to build angle up to 85 deg to TD w/ -8k
to -15k WOB ROP 10 to 80 fph
MW=8.99/9.03
Qp = 2.82/2.83 bpm
Pc = 150 to 160 psi
Pa = 366/4 psi/4453 psi
ECD= 11.19ppg
Vp = 216 bbl
IAlOA = 720/65 psi
Vol KWF = 380 bbl , 11 ppg
01 :45 - 02:30 0.75 DRILL P PROD2 Drilling at 100R w/-8k to -15k WOB ROP 10 to 100 fph
MW=9.019.03
Qp = 2.82/2.83 bpm
Pc = 150 psi
Pa = 3664/4453 psi
ECD", 11.31 ppg
Vp = 204 bbl. Lost 26 bbl in 8 hrs
IAlOA = 757/66 psi
Vol. KWF = 380 bbl , 11 ppg
02:30 - 05:26 2.93 DRILL P PROD2 Wiper trip, ECD climbing due to higher ROP's Redued running
speed on wiper trip to reduced surge pressure (22 fph). Tagged
3 times at 10832 ft and once at 10900 ft. Orient TF around due
to stops. Started replacement mud down. CT Lost 38 bbl
during last 12 hrs
05:26 - 07:50 2.40 DRILL P PROD2 Drilling at 90 R. Actual WOB 1-2k coil string wt -12k to +2k.
2.8/2.79 3650 annular 11.2ECD
07:50 - 10:15 2.42 DRILL P PROD2 Wiper trip to window. Setdowns at 10709' & 10830', motorwork
from 10830'-10930'. Worked these areas several times.
Printed: 8/1612004 8:58:22 AM
e
e
BP EXPLORATION
erations Summary Report
Legal Well Name: 1 C-08
Common Well Name: 1 C-08 Spud Date: 5/16/1981
Event Name: REENTER+COMPLETE Start: 7/28/2004 End: 8/13/2004
Contractor Name: NORDIC CALISTA Rig Release: 8/13/2004
Rig Name: NORDIC 2 Rig Number: 2
Date From ~ To Hours Description
8/11/2004 10:15 - 11 :30 1.25 DRILL P PROD2 Drill ahead f/ 11193'. 1.3K wob 2.78/2.71 3550fs 2-300mw
3700 annular 11.2ecd Coil wt anywhere from -12k to +2k.
11 :30 - 14:45 3.25 DRILL P PROD2 Wiper trip to window. Flush 7". Tie-in +2' correction. Wiper to
bottom tagged at 10700' and 10835' work areas several times
with varying TF's
14:45 - 16:00 1.25 DRILL P PROD2 Drill ahead f/ 11284' 2.77/2.73 3-400psi MW 3690 annular
11.18ECD 2k wob. Drilled to 11350'TD
16:00-19:10 3.17 DRILL P PROD2 Wiper trip back to window 35k up wt Took a little wt at 10832 ft,
wentthrough, RIH
19:10 - 21:05 1.92 DRILL P PROD2 PUH to tie-in, working pipe shed and mixing liner pill
21 :05 - 21: 15 0.17 DRILL P PROD2 Tied-in to RA Marker at 8938 ft. (No Correction)
21:15 - 23:07 1.87 DRILL P PROD2 RIH to confirm TD Tagged at 10836 with 60 RTF, PU and
orient TF to 75 R. Worked through area again. RIH, clean at
45R. Tagged at PTD @ 11351ft.
23:07 - 00:00 0.88 DRILL P PROD2 PUH to 10700 ft to work problem area while mixing liner pill.
RIH tagged at 10836 ft with 70R TF, PUH and oriented TF to
45R, went through. RIH to 10900 ft
8/12/2004 00:00 - 00:15 0.25 DRILL P PROD2 PUH to 10750 It and RIH, worked through 10836 ft area at 45R
TF.
00: 15 - 00:35 0.33 DRILL P PROD2 RIH to 11351ft
00:35 - 00:50 0.25 DRILL P PROD2 Cir liner pill down CT
00:50 - 02:02 1.20 DRILL P PROD2 PUH laying in liner pill maintaining 3650 psi BHP
02:02 - 02:09 0.12 DRILL P PROD2 At 8830 ft, switch to 11.00 ppg KWF down CT Pull up into
4-1/2" and RIH, Open EDC
02:09 - 03:07 0.97 DRILL P PROD2 Circulate 11 ppg KWF adjusting choke to maintain pressure
schedule at 8800 ft MD
Q = 3.4 to 2.17 bpm. maintaing 3655 psi BHP
With 85 bbl in annulus, lossing 0.18 to 0.20 bpm at 2 bpm.
BHP = 3688 posi at 6241 ft TVD
With 92 bbl pumped in annulus, lossing 0.09 bpm at 1.39 bpm
BHP = 3660 psi at 6241' TVD
Density = 1 0.8/1 0.7ppg taking fluid back to pits
03:07 - 04:00 0.88 DRILL P PROD2 With 101 bbl pumped in annulus reduced Q to 1bpm waiting on
vac truck to transfer more brine before POOH
BHP = 3650 psi w/ 11.35 ppg ECD
Cir at 1.0010.85 bpm, lossing 0.15 bpm; BHP = 3690 psi (11.47
ppg ECD)
Density = 10.9/10.9 ppg MM
04:00 - 04: 15 0.25 DRILL P PROD2 SD, checked flow, WHP = 0 psi, monitored, well dead.
04:15 - 05:45 1.50 DRILL P PROD2 POOH, filling hole, and running trip sheet Painted flag at 4000
ft EOP.
While painting flag, lossing 0.08 bpm
05:45 - 06:00 0.25 DRILL P PROD2 OOH, Monitor well. Well dead. cir across the top, SD and make
ready to unstab
Well on slight vac
06:00 - 06:30 0.50 DRILL P PROD2 MU safety it and UD BHA
06:30 - 06:45 0.25 RUNCOtvP RUNCMP PJSM review liner porocedures and hazards.
06:45 - 10:30 3.75 RUNCOtvP RUNCMP Make-up and RIH wI 2-2/8 'and 3-3/16' liner.
10:30 -11:15 0.75 RUNCOtvP RUNCMP Load shed with 1-1/4' CSH. R/U false table, change out
elevators.
11 :15 - 14:45 3.50 RUNCOtvP RUNCMP Run 81 jts CSH innner string.
14:45 - 15:15 0.50 RUNCOtvP RUNCMP MU CSH spaceout jts and CTLRT
15:15 - 16:30 1.25 RUNCOtvP RUNCMP PU 20 3-1/8" drill collars
Printed: 8/16/2004 8:58:22 AM
e.
-
BP EXPLORATION
Operations Summary Report
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name;
1 C-08
1 C-08
REENTER+COMPLETE
NORDIC CALISTA
NORDIC 2
Date From- To Task Code NPT Phase
8/12/2004 16:30 - 18:23 1.88 RUNCOiIIP RUNCMP
18:23 - 19:58 1.58 RUNCOiIIP RUNCMP
19:58 - 20:25 0.45 RUNCOiIIP RUNCMP
20:25 - 22:10 1.75 RUNCOiIIP RUNCMP
22:10 - 23:43 1.55 RUNCOiIIP RUNCMP
23:43 - 00:00 0.28 RUNCOiIIP RUNCMP
8/13/2004 00:00 - 03:45 3.75 RUNCOiIIP RUNCMP
03:45 - 04:30 0.75 WHSUR P POST
04:30 - 06:00 1.50 WHSUR P POST
06:00 - 08:30 2.50 WHSUR P POST
08:30 - 08:45 0.25 WHSUR P POST
08:45 - 10:00 1.25 WHSUR P POST
10:00 - 11:00 1.00 WHSUR P POST
11 :00 - 12:00
1.00 WHSUR P
POST
12:00 - 13:00
13:00 - 18:00
1.00 WHSUR P
5.00 WHSUR P
POST
POST
Page 13 of 13
Start: 7/28/2004
Rig Release: 8/13/2004
Rig Number; 2
Spud Date: 5/16/1981
End: 8/13/2004
Descriptio
PU BHi tools. Test tools. EDC failed. Change out BHi tools
T est tool at surface
R/H, Wt BHA = 30k at surface. (Corrected to EOP 4000' Flag
-18.2ft)
Wt check at 8800 ft = 20k down, and 4.5K up
RIH
Tagged at 11125 ft. PUH aPUW = 62k, Worked liner from
11 ,125 ft 11 ,186 ft without cir. Closed EDC and circulated
down 1-114" CSH at 0.5 to 1 bpm.
Worked CT and pushed liner to 11, 270 ft. Free travel to this
point. Stuck at 11270ft.
Estimated btm of liner at 11270' and top of liner at 8714 ft
Put deployment slleve in compression, released from liner
POOH with CT/DC and CSH. Filling hole across the top
Stopped at 6491 and checked for flow. POOH. JSA on BHA
handling while POOH
OOH, monitor well, OK, unstab
LD liner running BHA
RD handling tools, PU injector and RU nozzle BHA to FP
wet/bore
RIH to 8615'.
Displace well bore to diesel. Trapped 1000 psi under SSSV.
Displace to surface. Close MV and SV 23 tums..
PJSM review plans procedures to blowdown reel with N2
Blowdown reel with N2 to Tiger Tank
UD nozzle BHA. Remove BHi upeer quick connect. Cut-off
SLB CTC. Seal e-line. Cleaning mud tanks.
Transfering recovered KW brine to 1Y pad. Transferring used
Flo-Pro mud to MI Deadhorse.
Install intemal coil grapple. Unstab 2-3/8" coil from injector and
secure to reel.
Lower 2-3/8" reel to Veco flatbed truck
ND BOPE. Install tree cap and test to 5k. 1st PT on cap failed
Make rig ready to move to 1 Y -24
Rig Released at 18:00 hrs 8/13/2004
Printed: 8/16/2004 8:58:22 AM
.'~
.
BP-GDB
Baker Hughes INTEQ Survey Report
(
Company:
Field:
Site:
Well:
Wellpath:
ConocoPhillips Alaska, Inc.
Kuparuk River Unit
KRU 1C Pad
1 C-08
1C-08L 1-01
Field: Kuparuk River Unit
North Slope
UNITED STATES
Map System:US State Plane Coordinate System 1927
Geo Datum: NAD27 (Clarke 1866)
Sys Datum: Mean Sea level
Site: KRU 1C Pad
UNITED STATES: North Slope
Site Position: Northing: 5968605.00 ft
From: Map Easting: 562247.20 ft
Position Uncertainty: 0.00 ft
Ground Level: 0.00 ft
Well: 1C-08
1 C-08
Well Position: +N/-S
+E/-W
Position Uncertainty:
392.76 ft
-580.02 ft
0.00 ft
Northing:
Easting :
5968992.90 ft
561664.00 ft
Wellpath: 1C-08l1-01
500292058561
Current Datum: Wellhead(94')
Magnetic Data: 8/6/2004
Field Strength: 57575 nT
Vertical Section: Depth From (TVD)
ft
0.00
Height 94.00 ft
+N/-S
ft
0.00
Survey Program for Definitive Wellpath
Date: 8/18/2004 Validated: Yes
Actual From To Survey
ft ft
100.00 8900.00
8930.00 9500.81
9528.00 9716.72
9732.00 11351.00
GMS (100.00-9776.00) (0)
MWD (8930.00-10175.00) (3)
MWD (9528.00-10954.00) (1)
MWD (9732.00-11351.00)
Annotation
MD
ft
8930.00
9716.72
9732.00
11351.00
TVD
ft
6435.36
6505.98
6506.54
6459.94
Window
TIP
KOP
TO
Survey: MWD
CoilTrak
Company: Baker Hughes INTEQ
Tool: MWD;MWD - Standard
.
II..
BA.KD
IIUGMIS
INTEQ
Date: 8/31/2004 Time: 15:38:58 Page:
Co-ordinate(NE) Reference: Well: 1C-08, True North
Vertical (TVD) Reference: Wellhead(94') 94.0
Section (VS) Reference: Well (0.00N,O.00E,318.00Azi)
Survey Calculation Method: Minimum Curvature Db: Sybase
Map Zone:
Coordinate System:
Geomagnetic Model:
Alaska, Zone 4
Well Centre
bggm2004
Latitude: 70 19 29.107 N
Longitude: 149 29 42.918 W
North Reference: True
Grid Convergence: 0.48 deg
Slot Name:
Latitude: 70 19 32.970 N
Longitude: 149 29 59.848 W
Drilled From:
Tie-on Depth:
Above System Datum:
Declination:
Mag Dip Angle:
+E/-W
ft
0.00
1 C-08L 1
9732.00 ft
Mean Sea Level
24.72 deg
80.77 deg
Direction
deg
318.00
Version: 5
Toolcode
Tool Name
Good_gyro
MWD
MWD
MWD
Good Gyro
MWD - Standard
MWD - Standard
MWD - Standard
Start Date:
8/11/2004
Engineer:
Tied-to:
From: Definitive Path
'J.à'1..¡(~
. ~.". . BP-GDB . 11M.
BAKU
~s
Baker Hughes INTEQ Survey Report iNTEQ
Company: ConocoPhillips Alaska, Inc. Date: 8/31/2004 Time: 15:38:58 Page: 2
Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1C-08, True North
Site: KRU 1C Pad Vertical (TVD) Reference: Wellhead(94') 94.0
Well: 1 C-08 Section (VS) Reference: Well (0.00N,O.00E,318.00Azi)
Wellpath: 1C-08L 1-01 Survey Calculation Method: Minimum Curvature Db: Sybase
Survey
I MD Incl Azim TVD SSTVD N/S EIW MapN MapE VS DLS
ft deg deg ft ft ft ft ft ft ft deg/100ft
8930.00 40.00 312.55 6435.36 6341.36 2364.19 -4738.86 5971317.84 556906.33 4927.85 0.00
9716.72 87.22 293.37 6505.98 6411.98 2964.44 -5186.20 5971914.34 556454.11 5673.25 6.35
9732.00 88.60 296.25 6506.54 6412.54 2970.84 -5200.06 5971920.63 556440.20 5687.29 20.89
9746.86 90.78 293.50 6506.62 6412.62 2977.09 -5213.54 5971926.77 556426.67 5700.95 23.61
9780.50 92.38 287.27 6505.69 6411.69 2988.80 -5245.04 5971938.21 556395.08 5730.73 19.11
9808.76 89.59 281.60 6505.20 6411.20 2995.84 -5272. 39 5971945.03 556367.67 5754.26 22.36
9838.89 88.20 278.75 6505.79 6411.79 3001.16 -5302.04 5971950.10 556337.99 5778.05 10.52
9869.43 92.26 280.93 6505.66 6411.66 3006.38 -5332.12 5971955.07 556307.86 5802.06 15.09
9901.48 90.44 285.40 6504.91 6410.91 3013.67 -5363.31 5971962.11 556276.62 5828.35 15.05
9931.34 88.70 290.18 6505.13 6411.13 3022.79 -5391.73 5971971.00 556248.13 5854.15 17.03
9962.77 88.36 295.00 6505.94 6411.94 3034.86 -5420.73 5971982.82 556219.03 5882.52 15.37
9993.18 91.37 292.28 6506.01 6412.01 3047.05 -5448.59 5971994.79 556191.08 5910.22 13.34
10027.44 96.76 291.24 6503.58 6409.58 3059.72 -5480.31 5972007.19 556159.25 5940.86 16.02
10058.70 102.55 290.55 6498.34 6404.34 3070.70 -5509.09 5972017.94 556130.39 5968.28 18.65
10093.98 104.11 285.43 6490.20 6396.20 3081.31 -5541.73 5972028.27 556097.67 5998.00 14.80
10129.47 103.94 280.36 6481.60 6387.60 3088.99 -5575.28 5972035.68 556064.06 6026.15 13.87
10160.08 103.18 284.45 6474.42 6380.42 3095.38 -5604.33 5972041.83 556034.96 6050.35 13.22
10191.75 100.30 289.72 6467.97 6373.97 3104.49 -5633.96 5972050.70 556005.26 6076.94 18.66
10222.96 100.67 295.48 6462.29 6368.29 3116.28 -5662.27 5972062.25 555976.85 6104.65 18.19
10253.46 101.01 300.52 6456.55 6362.55 3130.34 -5688.72 5972076.09 555950.30 6132.79 16.27
10290.31 102.11 305.03 6449.16 6355.16 3149.87 -5719.06 5972095.37 555919.79 6167.61 12.36
10325.04 100.88 310.41 6442.23 6348.23 3170.69 -5745.97 5972115.96 555892.72 6201.09 15.59
10353.56 100.36 315.67 6436.97 6342.97 3189.82 -5766.45 5972134.92 555872.09 6229.00 18.22
10394.41 99.01 321.34 6430.09 6336.09 3219.97 -5793.11 5972164.85 555845.18 6269.25 14.08
10435.09 90.41 321.50 6426.76 6332.76 3251.63 -5818.37 5972196.30 555819.66 6309.68 21.14
10466.89 91.03 326.96 6426.36 6332.36 3277.42 -5836.95 5972221.93 555800.87 6341.28 17.28
10501.18 91.30 334.01 6425.66 6331.66 3307.23 -5853.83 5972251.60 555783.75 6374.73 20.57
10536.78 92.99 339.34 6424.33 6330.33 3339.89 -5867.91 5972284.14 555769.40 6408.42 15.70
10569.11 94.53 346.79 6422.20 6328.20 3370.73 -5877.30 5972314.90 555759.76 6437.62 23.48
10602.92 92.99 351.58 6419.98 6325.98 3403.85 -5883.63 5972347.97 555753.16 6466.47 14.85
10634.57 89.40 349.58 6419.32 6325.32 3435.06 -5888.81 5972379.13 555747.73 6493.13 12.98
10665.59 90.02 346.40 6419.48 6325.48 3465.40 -5895.26 5972409.41 555741.02 6520.00 10.44
10695.17 90.38 341.81 6419.38 6325.38 3493.84 -5903.36 5972437.78 555732.69 6546.55 15.56
10729.59 88.82 336.36 6419.62 6325.62 3525.98 -5915.64 5972469.81 555720.15 6578.65 16.47
10760.39 88.17 333.82 6420.43 6326.43 3553.90 -5928.61 5972497.63 555706.95 6608.08 8.51
10802.68 85.80 326.79 6422.65 6328.65 3590.56 -5949.52 5972534.11 555685.75 6649.31 17.52
10832.72 87.04 325.65 6424.53 6330.53 3615.48 -5966.18 5972558.89 555668.88 6678.98 5.60
10863.59 86.00 329.70 6426.41 6332.41 3641.51 -5982.66 5972584.78 555652.19 6709.35 13.52
10894.27 84.95 334.54 6428.83 6334.83 3668.54 -5996.96 5972611.69 555637.68 6739.00 16.09
1 0923.29 82.73 336.77 6431.94 6337.94 3694.82 -6008.85 5972637.87 555625.57 6766.49 10.81
10954.54 81.86 341.33 6436.13 6342.13 3723.73 -6019.92 5972666.69 555614.26 6795.39 14.73
10982.32 82.09 346.72 6440.01 6346.01 3750.17 -6027.49 5972693.06 555606.48 6820.10 19.23
11015.65 85.83 344.54 6443.52 6349.52 3782.27 -6035.71 5972725.08 555597.99 6849.46 12.97
11044.59 86.33 341.31 6445.50 6351.50 3809.87 -6044.19 5972752.61 555589.29 6875.63 11.27
11078.28 84.29 346.21 6448.26 6354.26 3842.09 -6053.58 5972784.75 555579.63 6905.87 15.71
11108.53 84.23 349.26 6451.28 6357.28 3871.50 -6059.97 5972814.10 555573.00 6932.00 10.03
11139.65 84.82 354.31 6454.25 6360.25 3902.15 -6064.40 5972844.71 555568.32 6957.74 16.26
11174.51 84.42 357.57 6457.52 6363.52 3936.76 -6066.85 5972879.30 555565.58 6985.10 9.38
11208.25 89.74 3.32 6459.24 6365.24 3970.43 -6066.59 5972912.97 555565.57 7009.95 23.20
11239.54 89.49 7.44 6459.45 6365.45 4001.58 -6063.66 5972944.13 555568.25 7031.13 13.19
11271.11 87.90 9.21 6460.17 6366.17 4032.80 -6059.09 5972975.39 555572.56 7051.28 7.54
11305.28 90.78 12.93 6460.57 6366.57 4066.33 -6052.53 5973008.97 555578.84 7071.80 13.77
11351.00 90.78 12.93 6459.94 6365.94 4110.88 -6042.30 5973053.60 555588.70 7098.07 0.00
KRU
1C-Ga
PSI't
-,-
AUG-03-2004 11:11 PHILLIPS AK INC
'REI/r DAn: I BY I CIe", APP I __DESCRIPTION
. 8 l7/is/0J! MFH BGM" Rev. ~r K~31 05ACS
,
Well
No.
'Y'
1
2
.3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
21
22
23
24
25
26
27
101
102
104
106
109
111
113
115
117
119
121
123
125
127
129
5,~6a,523
5.968,590
5,96~,65?
5.968.727
5,968.793
5,96B,860
5,968.926
5.968,993'
_ 5,96B,8~1.Q9
5.968,763.3.3
5.969,008.74
5.969,000.20
5.968,842.13
5.968,672.21
5,968,605.15
5.968,825..37
5,96ª-,838.00
5,~68.758.80
5,968,624.28
5,968,637.7S
5,968,646.48
5,968,579.61
5,968,571.44
5.968,546.47
5.968,5.38.05
5.968,529.79
5.968,821.46
5,968,813.50
5,968,796.65
5,968.779.74
5,968.746.59
5,968,730.13
5.968,713.56
5,96B.69S.96
5,968,680.39
5,968.664.02
5,968,646.80
5,968.630.35
5,968,613.75
5,968,597.14
5,968,580.60
A.S.P,s
Sec.
1
907 265 6224 P.02
1~15n~ìo3IM8~TI.1 APP I Rev, P~~;~80ACS
12, T. 11
LATITUDE
70' 19' 28.29"
70' 19'_ 28.96"
70' 19' 29.61"
70' 19' 30.32"
70' 19' 30.9S"
70' 19' 31.65"
70' 19' 32.30·
70' 19' 3~.97"
70' 19' 31.5934"
70' 19' 30.7107"
70' 1 9' 33.128"
70' 19' 33.043"
70' 19' 31.469"
70' 19' 29.777"
70' 19' 29.109"
70' 19' 31.302"
70' 1~' 31.454"
70' 19' 30.639"
70' 19' 29.287"
70' 1~' 29.434"
70'" 19' 29.50S"
70' 19' 28.855"
70' 19' 28.773"-
70' 19' 26.525"
70" 19' 28.441"
79' 19' 28.358"
70' 19' 31.289
70' 19' .:5'.210"
70' 19' 31.042"
70" 19' 30.874"
10' 19' 30.544"
70' 19' 30.380"
70" 19' 30.215"
70' 19' 30.050"
70' 19' 29.885"
70' "19' 29.722"
70' 19' 29.550;'
70' 19' 29.387"
70' 19' 29.2"21"
70' 19' 29.056"
70' 19' 28.891"
Conoc6Phillips
Alaska,lnc,
f / DRAIMNG NO:-
63001.
èADD FILE NO.
LK6103031
'x'
562,372
562,271
562,172
562,065
561.965
561,664
561.765
561,664 ,
561,548.05
561.680.92
561,641.06
561,6~.3.40
561.891.29
562,146.39
562.247.15
561.916.31
561,568.7!3
564.016.22 "
562,368: 18
562.> 19S.12
562.334.93
562,285.45
562,297.94
562.335,47
562.347.93
562.360.~S
561,593.72
561.606.18
561,631.04
561,656.61
561,706.13
561,731.01
561,755.87
561. 780.86
561,605.95
561,830.61
561,856.20
561,8S0.54
561,905.78
561,930.71
561,955.57
N't
I
R. 1 0 E.
LONGITUDE
SEC.
UNE
O/S
F,N,L.
1.717'
1,649'
, ~582'
1,510'
1,442'
1,375'
1,308'
1,240'
1..3e1'
1,471'
1.225'
1,234'
1.394'
1.566'
1,634'
1.411'
1.395'
1,478'
1,616i"
1,60"
1,593'
1.660'
1,66S;
1,693'
1,702'
1,710'
1,412'
1.420'
1,437'
1,454'
1,487'
1,504'
1,521'
1,538'
1,555'
1,571'
1,589'
1,605'
1,622'
1,639'
1,656'
[p~: PAD I O,G.
o ~s .ElEV. ELEV.
F. W,L.
1,363' N/A N/A
1,263' N/A N/A
1,164' N/A ~/A
1,058' N/A N/A
958' N/A N/A
859' NJA N/A
760' N/A N/A
660' N/A N/A
542' N/A N/A
674' N/A N/A
637' 60.40' 55.0'
649' 60.4' 55.1'
885' 60.40' 55.0'
1.139' 60.4' 55.0'
1239' 60.3' 55.0'
910' 60.3' 55,0'
563' so.5' 5"9.2'
1,Q10' 6004' 55.0'
1,360' 59.1' 52.3'
1,191.' 60..3' 55.0'
1.327' 59.1' 51.6'
1,277' 60.3' .55.2;
1,290' 60.3' 55.2'
~ ,327' 60.2' 55.0'
1.339' ,60.2' 55.0'
1,352' 60.2' 55.0'
588' 60.S' 56.7'
600' SO.S' 56.7'
625' 60.6' 56.7'
650' 60.7' 5s. "
699' 60.7' 56.6'
724' 60.7' 56.5'
749' 60.7' 56.5'
774' 60.7' 56.4'
799' 60.8' 56.3'
823' 60.8' 56.2'
S49' 60.8' 56.1'
873' 60.8' 55.9'
898' GO.8' 55.8'
923' 60.S' 55- 7'
947' 60.8' 55.6'
AREA: 1C MODULE: XXXX
DS1C
WELL CONDUCTORS
ASBUIL T LOCATIONS
GEA-D1CX-6103D31 PART: 2
149' 29' 39.30"
149' 29' 42.21"
149' 29' 45.10"
149' 29' 48.18"
149' 29' 51.08"
149' 29' 54.04"
149' 29' 56.92"
149' 29' 59.85"
149" 30' 03.266"
149' 2.~· 59.410"
149' 30' 00.514"
149' 3D' 00,156"
149' 29' 5~.:249"
149' 29' 45.S44"
149' 29' 42.919"
149' 29' 52.523"
149' 30' 92.665"
149' 29' 49.623"
149' 29' 39.382"
149' 29' 44.342"
149' 29' 40.347"
149' 29' 41.807"
149" 29' 41.445"
1 49' 29' 40.355"
149' 29' 39.994"
149' 29' 39.626"
149' 30' 01.941"
149' .'30' 01.579"
149' 301 00.857"
149' 30' 00.115"
149' 29' 58,678''-
149' 29' 57.955"'·
149' 29' 57.233"
149" 29' 56.50S"
1 49' 29' 55.760"
149' 29' 55.064"
149' 29' S4.~21·
149* 29' 53.614"
149' 29' 52.882"
149' 29' 52.158"
149' 29' 51.43S"
UNIT: 01
REV:
OF .'3 a
TOTAL P. 02
It STATE OF ALASKA .
OIL AND GAS CONSERVATION COMMISSION
BOPE Test Report
S u bm it to: llLD..JJ?f:ltl@ª-çJ.m!.G.,§.~ª-tg;:.{!.LH.~~
aOnccU.ifudhoe _ bay@adrnin.state.ak.us
bob ~f¡eGkenstø¡n@ad mil) .state.ak. us
Rig No.: 2 DATE: 8/9/04
Rig Phone: 670-3249 Rig Fax: 670-3245
Op. Phone: 670-3247 Op. Fax: 670-3245
E-Mailsu.adwdrlgnordic2supervisor@bp.co
PTD # 2....U2 Meridian: UM
Township: 11N Range: 10E
Workover: Explor.:
Weekly: X Other:
Annular: 250/3500 Valves: 250/4500
TEST DATA FLOOR SAFETY VALVES:
P/F Quantity P/F
P Upper Kelly
P Lower Kelly
P Ball Type
Inside BOP
Contractor: NORDICISLB
Rig Rep.: Mckeirnan I Igtanlok
Operator: BPX
Rep.: Sevcik 1 Feketi
Well Name: KUP'tC..øt1';01
Location: Section: 12
Operation: Drlg: X
Test: Initial:
Test Pressure: Rams: 250/4500
MISC. INSPECTIONS:
P/F
P
P
P
P
Location Gen.:
Housekeeping:
PTD On Location
Standing Order Posted
Well Sign
Dr!. Rig
Hazard Sec.
2
P
BOP STACK: Quantity SizelType P/F MUD SYSTEM: Visual Alarm
Stripper 1 2318 " P Trip Tank P P
Annular Preventer 1 71/16 P Pit Level Indicators P P
#1 Rams 1 Blinds P Flow Indicator P P
#2 Rams 1 3" Slips P Meth Gas Detector P P
#3 Rams 1 2 3/8"x 3 1 12" P H2S Gas Detector P P
#4 Rams 1 2 3/8" Combi P
#5 Rams NIA P Quantity P/F
Choke Ln. Valves 1 3-1/8 I 5000 P Inside Reel valves 1 P
HCR Valves 2 3-1/8 I 5000 P
Kill Line Valves 1 3-1/8 I 5000 P ACCUMULATOR SYSTEM:
Check Valve NIA Time/Pressure P/F
System Pressure 3000 P
CHOKE MANIFOLD: Pressure After Closure 2150 P
Quantity P/F 200 psi Attained 23 see P
No. Valves 14 P Full Pressure Attained 90 see P
Manual Chokes 1 P Blind Switch Covers: All stations Yes
Hydraulic Chokes 1 P Nitgn. Bottles (avg): 4 @ 2100
Test Results
Number of Failures: Q Test Time: 4.5 Hours Components tested 28
Repair or replacement of equipment will be made within days. Notify the North Slope
Inspector 659-3607, follow with written confirmation to Superviser at: llm...g~9.9.@ª.Q.m!.G.,§Aª-tg;:'{t~Jt§
Remarks:
Distribution:
orig-Well File
c - Oper./Rig
c - Database
c - Trip Rpt File
c - Inspector
YES
24 HOUR NOTICE GIVEN
NO
x
Date
Waived By John Crisp
8/9104 Time
Witness
Test start
15 00 Finish
1930
Coil Tubing BFL 05129/03
11 00
Nordic 2 BOP 8-9-04.xls
/
.
~l (ill !Æ~!Æ~
.
A.,ASIiA. OILAlWD GAS
CONSERVATION COMMISSION
FRANK H. MURKOWSK/, GOVERNOR
333 W. 7'" AVENUE, SUITE 100
ANCHORAGE, ALASKA 99501-3539
PHONE (907) 279-1433
FAX (907) 276-7542
Dan Kara
CT Drilling Engineer
ConocoPhillips Alaska Inc.
P.O. Box 196612
Anchorage, Alaska 99519-6612
Re: Kuparuk 1C-08L1-01
ConocoPhillips Alaska Inc.
Permit No: 204-112
API No: 50-029-20585-60-01
Surface Location: 1246' SNL, 668' EWL, SEe. 12, T11N, RlOE, UM
Bottomhole Location: 3210' NSL, 35' WEL, SEC. 03, T11N, RlOE, UM
Dear Mr. Kara:
Enclosed is the approved application for permit to redrill the above development well.
The permit is for a new wellbore segment of existing well KRU 1 C-08, Permit No. 181-052, API
50-029-20585-00-00. Production should continue to be reported as a function of the original
API number stated above. Please note that the name of this wellbore segment is slightly changed
from your application where the proposed name was 1 C-08L2. This new wellbore segment
originates in the new 1C-08L1 (Permit No. 204-111) well bore rather than the original 1C-08
wellbore, as the L2 naming would imply. A more appropriate name for this new wellbore
segment is 1C-08L1-01, with the "01" suffix indicating that the segment arises from the L1
lateral. Likewise, the API number must be slightly changed. The Commission plans to employ
the previously unused 13th and 14th digits of the API number to denote these "laterals~drilled-
from-laterals." These second tier lateral well bore segments that are drilled from existing laterals
will be termed "spokes" per terminology that was proposed for inclusion in the 1995 revision of
document API DI2A, entitled "The API Well Number and Standard State and County Codes,
Including Offshore Waters." The Commission will apply this naming and numbering convention
on any future "spoke" wellbore segment. Additional spokes from the same lateral will be
sequential in both name and API number.
This permit does not authorize opening the wellbore to test or regular production, which requires
issuance of a conservation order granting a spacing exception. By commencing drilling
operations before receiving a spacing exception, ConocoPhillips Alaska Inc. assumes the risk
that a spacing exception may not be granted and that ConocoPhillips Alaska Inc. may be required
to plug and abandon the well without enjoying any benefit from the well.
This permit to redrill does not exempt you from obtaining additional permits or approvals
required by law from other governmental agencies, and does not authorize conducting drilling
operations until all other required permits and approvals have been issued. In addition, the
Commission reserves the right to withdraw the permit in the event it was erroneously issued.
.
.
Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the
Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure
to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska
Administrative Code, or a: Commission order, or the terms and conditions of this permit may
result in the revocation or suspension of the permit. Please provide at least twenty-four (24)
hours notice for a representative of the Commission to 'tness any required test. Contact the
Commission's petroleum field inspector at (907) 659- 0 ager).
S' c
BY ORDER OF THE COMMISSION
DATED this.:~ay of July, 2004
cc: Department ofFish & Game, Habitat Section w/o encl.
Department of Environmental Conservation w/o encl.
~. tI.--
(¡;<1
'ì6o
. STATE OF ALASKA .
ALASKA OTAND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
20 MC 25.005
1 a. Type of work 0 Drill . Redrill 11 b. Current Well Class 0 Exploratory . Development OilIJMuI¥~,Zone
ORe-Entry 0 Stratigraphic Test 0 Service 0 Development Gas [JSingleZon"n ... A
2. Operator Name: /J. /J ,J)' A.. (I k . 5. Bond: a Blanket 0 Single Well 11.. Well Name and Number: ~"1/2P
....E!liJliPs Air"''''''' no- ~-D"("lUII:f¥'rflA4 '.::IJw... Bond No. Jj..63061Q'" "'1·5;<~,t.z..è¡' KUP 1C-08,LÆ'\...i.-ai.
3. Address: .¿Þ. B. Proposed Depth~ ~ 12. Field I Pool(s):
P.O. Box 196612, Anchorage, Alaska 99519-6612 (".U-ð'f MD 11720' TVD 6419' ss Kuparuk River Field 1 Kuparuk
4a. Location of Well (Governmental Section): 7. Property£esignation: River Oil Pool
Surface: / if ;/ /lDt. ð¿;;(.~"ADL 025648
1246' SNL 668' EWL SEC. 12 T11 N R 1 OE UM 'R ¡;.. l."l-C'"
Top of Productive HO;izon: ' " 8. Land Use Permit:
1097' NSL. 4049' WEL, SEC. 02, T11N. R10E. UM
Total Depth: 9. Acres in Property: 14. Distance to Nearest Property:
3210' NSL, 35' WEL. SEC. 03, T11N. R10E, UM 2560 13150'
4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Within Pool
'"
Surface: X-561672· y-5968988" Zone-ASP4 (Height above GL): 94' feet 1540' away from 1B-12
16. Deviated Wells: ¡'?L ~~ ftlJ>" Al::> ,.21-,."'¡ 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035)
Kickoff Depth .~ Maximum Hole Angle 102°.,f Downhole: 3400 psig Surface: 2754 ~ psig
IJ( Lì
l. d,
13. Approximate Spud Date:
08/15/04
Hole CasinQ Weight Grade Coupling LenQth MD TVD MD TVD (includinQ staQe data)
4-1/S" x 3-314" 3-3/16" x 2-7/S" 6.2# 16.4# L-80 TCIII STL 2910' 8810' 6242' 11720' 6419' Uncemented Slotted Liner
Total Depth MD (ft): Depth MD (ft): Junk (measured):
9791 9682' N/A
Structural
Conductor 80' 16" 425 sx Arcticset II 80' 80'
Surface 2714' 10-3/4" 3125 sx Arcticset II 2714' 2587'
Intermediate
Production 9767' 7" 974 sx Arcticset II 9767' 7090'
Liner 730' 2-7/8" Uncemented Slotter Liner 10100' - 10830' 6482' - 6507'
20. Attachments 0 Filing Fee, $100 a BOP Sketch
o Property Plat 0 Diverter Sketch
perfOration Depth TVD (ft): 6433' - 6582'
a Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis
o Seabed Report a Drilling Fluid Program a 20 MC 25.050 Requirements
Perforation Depth MD (ft): 8927' - 9122'
21. Verbal Approval: Commission Representative:
22. I hereby certify that the is true and correct to the best of my knowledge.
Printed Name Dan Kara Title CT Drilling Engineer
Date:
Contact Dan Kara, 564-5667
Phone
564-5667
Permit To Dril! (ì _I' API Number: «: ;)-CH (~A"?b:><:::>'-\
Number:;2..0'-I' 50- 029-20585-~ðQ.. ItJ): p\
Conditions of Approval: Samples Required 0 Yes gNo
Hydrogen Sulfide Measures ~ es 0 No
~-\-G-S ~\o.~
Permit Approval
Date:
Mud Log Required
Directional Survey Required
See cover letter for
other requirements
DYes KrNo
!8Yes 0 No
QJ~ IG I N~A l: .~..
BY ORDER OF
THE COMMISSION
ïi:.0G/
Date t4.
S bm;1 !iœ
LFwd: Re: IC-08 Ll&L2 Permit to Drill Applications]
.
.
Subject: [Fwd: Re: IC-08 L1&L2 Pennit to Drill Applications]
From: Thomas Maunder <tom_maunder@admin.state.ak.us>
Date: Fri, 16 Jul2004 08:17:19 -0800
To: Sondra Stewman <StewmaSD@BP.com>
Hi Sondra,
I got an out of office message from Terrie so I thought I would forward this to
you.
I haven't heard anything back from Dan or Dan yet.
Tom
-------- Original Message -------- ,~
Subject: Re: lC-08 Ll&L2 Permit to Drill Applications ~
Date~ Fri, 16 Jul 200\.07:33_:52A-080~. ~ ~\\_"-~'I'A-'''~'<;''~'-J<t~~''::Õ\'-.}(!:U
From. Thomas Maunder <Lorn maund_r@adn'ln.stat~.a!<:.us> n - tJ(:'J
Organization: State of Alaska ____mmmmm \ I\t;,-C)~ ~~
To: Kara, Danny T <KaraDT@BP. com> '>(;j5ÒY.,
CC: Dan Venhaus (E-mail) <Dan.E.Venhaus@conocophillips.com>, Terrie Hubble
<hubblethYbp. com>, Steve Dav{es-~st::-eveda:vTe-s(¿;ãdmin. state. . us>, Sharon
Allsup-Drake ~sallsup@ppco.com>
References: dDB7389531725544A.E434013DD9361620152F055@bplancex002.bpl.ad.bp.com>
Dan, Dan, Terri and Sharon,
Steve Davies and I have been looking closely at the name and API numbering scheme
for the 2nd wellbore segment planned to drill in lC-08.
After much discussion, our recommendation for the protocol to use for this and
future wells of this type is that laterals drilled from another lateral will be
called "spokes" and the final 2 digits of the API number will be used. In the case
of the segments you plan to drill, the first segment's API number would be
50-029-20589-60-00 and the second segment would be 50-029-20589-60-01. In our
database the names we will carry are lC-08Ll for the initial segment and lC-08Ll-0l
for the second.
~~ase message back or call and we can discuss.
~ Tçfm Maunder, PE
b~·······
Tom,
Thanks for reviewing the Kuparuk CTD program.
Question #1: We will run the 3-3/16" liner from Lateral 2 up into the tubing
tail. The whipstock will also remain in place. The existing perfs will not be
accessible unless the liner is cut and pulled from the window depth and the
whipstock retrieved. This cut/pull/retrieve is not in the plans. Production
from existing perfs will not be restricted given that there will be significant
flow area around the through-tubing whipstock and 3-3/16" liner.
--
---"_..."~.,,,-~=.-- -
,,~-..." ..
-.-----------------
Question #2:
I think the proposed schematic is leading to some confusion on which leg is Ll or
L2. The plans are to drill the lower lateral (Cl target) from the window to a TD
of 10830'. We will then run and drop a 2-7/8" pre-drilled liner from TD up to
10100', completing this leg as Lateral 1. Just above this liner top we will open
hole sidetrack and drill Lateral 2 to a TD of 11720' to access the upper C3/C4
sands. A 3-3/16" x 2-7/8" pre-drilled liner will then be run from the production
tubing tail down to the TD of Lateral 2.
The proposed schematic looks as if Ll is a sidetrack of L2. This is not the
case. L2 does however, have the continuous casing string.
I'll let the guy building the schematics know they are somewhat confusing.
Please call me if you need additional clarification.
Thanks.
Dan Venhaus, your proposed schematics are confusing.
lof3
7/20/2004 10:49
lFwd: Re: IC-OS U&L2 Pennit to Drill Applications}
Dan Kara
BP Coiled Tubing Drilling
564-5667 (office)
240-8047 (cell)
564-5510 (Fax)
kal.'adt@bp . c0rr:'
.
.
-----Original Message-----
From: Thomas Maunder [mailto:tom maunder@ad!I1~!.!...:~~9~~..:~J.<;::\~?] Sent:
June 29, 2004 4:28 PM
To: Kara, Danny T
Cc: Steve Davies
Subject: Re: 1C-08 L1&L2 Permit to Drill Attancment
Tuesday,
Dan,
I have a couple of further questions.
1. Looking at the planned pipe program, 3-3/16" liner will come all the way back
to the tubing tail. The existing perfs are planned to be open, is there any plan
to be able to provide access to them??
2. If a wellbore segment is drilled out of an existing well without plugging
back as is planned, the naming convention would have the first segment named
"L1". However what you propose as "L2" actually appears to be the "L1 of the
L1" or as Steve Davies proposes L1-01. This is the first time I have seen this
configuration. Not a lot of coil work on my side of the world. Are there other
wells in Prudhoe that are similarly designed?? Our intent here is to maybe get
ahead of the curve with naming conventions and API numbers.
Since this is a CPAI well, you might want to involve Venhaus on this. I look
forward to your reply.
Tom Maunder, PE
AOGCC
Thomas Maunder wrote:
Thanks Dan.
I will put these in the permit. Things look OK as far as I have gotten.
Interesting, it appears that you are going to drill the L1 of the L1 as opposed
to an L2.
But, not to worry on that L2 is probably the simplest designation to use. Catch
you later.
Tom
Kara, Danny T wrote:
Tom,
I apologize for sending you the wrong attachment "Potential Drilling Hazards -
Post on Rig". Please pull all three pages and replace with attached.
Sorry for the inconvenience.
«lC-08Ll&L2 Summary for drilling Permit.doc»
Dan Kara
BP Coiled Tubing Drilling
564-5667 (office)
240-8047 (cell)
564-5510 (Fax)
karadt@bp.com
~ )~.t.
7/20/2004 10:49 AM
.
.
Kara, Danny T
From:
Sent:
To:
Subject:
Venhaus, Dan E [Dan.E.Venhaus@conocophillips.com]
Friday, June 18, 2004 9:36 AM
Kara, Danny T
Permit authorization
Dan,
This is the standard verbage that we have forwarded to AOGCC in the past
authorizing permit delivery to BP:
The Kuparuk CTD program starting up in August 2004 consists of 5 wells. The
proposed wells are 1C-08A, 1Y-24A, 1D-30A, 1F-18A, #5 TBD and will be drilled
with
BP's Nordic 2 CTD unit and managed through BP's CT drilling organization.
BP's CT drilling services are being provided to the operator, ConocoPhillips,
via a Shared Service operation. As such, Co~qçoPhillips authorizes the
delivery of these permits to BP (Terry Hubble). ConocoPhillips does ret.!uest
that BP provide a copy of the approved permits for COP's files (Sharon Allsup-
Drake) .
If you need anything else, let me know.
Dan Venhaus
ConocoPhillips AK Wells
(907)263-4372 office
(907)230-0188 cell
1
,--1.- c i.liJ.-.?II "} (;)OA
.U 1 C-08L 1 &1-2"5idetrack - Coiled fl!ing Drilling
Summary of Operations:
Coiled tubing drilling will sidetrack KRU lC-08 using the dynamically overbalanced coiled tubing drilling
(DOCTD) technique (see description below). This horizontal laterals (lC-08Ll & L2) will target Kuparuk C
sand reserves for production. The Kuparuk C Sand and A Sand perforations in the existing well, 1 C-08 will not >"
be abandoned and will be open to flow post CTD.
",/
Prior to arrival of the Nordic 2 CTD rig, a rig workover will be performed to swap the tubing to 4-112" 12.6# L-
80. This workover will be done by ConocoPhillips Alaska.
\...r1.. --ð !..
CTD Drill and Complete IC-08LI &j.2"proeram: Planned for Aueust 15.2004
1. Pre CTD install mechanical whipstock at 8930'
2. MIRU Nordic 2. NU 7-1116" BOPE, test.
3. Mill 3.80" window at 8930' md and 10' of openhole.
4. Drill 4. 125"x3. 75" bicenter hole horizontal sidetrack 1 C-08Ll from window to -10830' TD targeting v
Kuparuk Cl sand interval.
5. Run and drop a 2-7/8" slotted (pre-drilled) liner from TD of ] 0830', up to 10100' md.
6. Openhole sidetrack at 10830' in Ll, above the 2-7/8" liner.
7. Drill 3.75" horizontal sidetrack 1 C-08~ from open-hole side track to - 11720' TD targeting Kuparuk C4 ¡/
sand interval. \.. t\. .. Ð A-
8. Complete with 3-3/16" x 2 7/8" pre-drilled liner from the TD of L2 at 11720', up into the 4-112" tubing to
- 8810'.
9. Post CTD rig -Run GL V s. Bring on production.
Mud Program:
· Steps 1: 8.9 ppg Potassium-Formate biozan brine v'
· Steps 2-3: Potassium-Formate based PIo-Pro (8.9 ppg)
Disposal:
/
· No annular injection on this well.
· Class n liquids to KRU lR Pad Class n disposal well
· Class n drill solids to Grind & Inject at PBU Drillsite 4
· Class I wastes will go to Pad 3 for disposal.
Casing Program:
· Ll: 27/8",6.4#, L-80, STL slotted liner from 10830' md - 10100' md
· L2: 3-3/16" 6.2# L-80 Tcn solid pipe from 8810' md to 9900' md.
· L2: 27/8",6.4#, L-80, STL slotted liner from 9900' md to TD at J 1720' md /
Well Control:
· BOP diagram is attached.
· Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 4500 psi.
· The annular preventer will be tested to 400 psi and 2500 psi.
Directional
· See attached directional plans for lC-08LI & L2
· Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run.
./
Logging
· A Gamma Ray log will be run over all of the open hole section.
· Resistivity logs will be recorded over limited sections of openhole.
Kara 564-5667 office, 240-8047 cell
1/3
.. ~-o1. .
KWI!5 1 C-08L 1 &).2'Sidetrack - Coiled Tu g Drilling
Hazards
. One mapped fault in in the direction of the well path; lost circulation risk is low, especially while DOCTD.
Reservoir pressure is estimated to be 10.1 ppg in the fault block. Well 1 C-08 has a H2S reading of 65 ppm
(measured 08/28/03). The highest H2S on lC pad was measured at 232 ppm (IC-123, 8/04/02). lC is an
H2S pad. All H2S monitoring equipment will be operational.
Reservoir Pressure
. Reservoir pressure is approx. 3400 psi at 6460' TVD 10.1 ppg EMW. Max. surface pressure with gas (0.1
psi/ft) to surface is 2754 psi.
Dynamically overbalanced coiled tubing drilling (DOCTD) techniques will be employed to address high
reservoir pressure. Plans are to use 8.9 ppg drilling fluid in combination with annular fuction losses and
applied surface pressure to maintain overbalanced reservoir conditions. A hydraulic choke for regulating
surface pressure will be installed between the BOPE choke manifolding and the mud pits and will be
independent of the BOPE choke.
Using this technique with an underbalanced mud weight requires deployment of the BHA under trapped
wellhead pressure. Deployment will be accomplished utilizing the BOP pipe/slips (2-3/8" rams, see attached
BOP configuration), and/or the tested tubing retrievable sub-surface safety valve. The annular preventer will
act as a secondary containment during deployment and not as a stripper. At least two times hole volume of
kill weight fluid will be on location as a contingency.
The first pre-drilled line will be deployed above a closed tubing retrievable sub-surface safety valve. Once
drilling of L2 is complete, the production liner will be deployed into the wellbore after killing the well with
kill weight fluid.
Estimated reservoir pressure: 3400 psi at 6460' TVD, 10.1 ppg EMW.
Expected annular :&iction losses while circulating (ECD): 400-500 psi
Planned mud density: 8.9 ppg equates to 2990 psi hydrostatic bottom hole pressure.
While circulating 8.9 ppg fluid, bottom hole circulating pressure is estimated to be 3400-3500 psi
When circulation is stopped, a minimum of 400-500 psi surface pressure will be applied to balance the
reservOIr.
Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure
measurements while drilling.
Kara 564-5667 office, 240-8047 cell
2/3
.. L~-O\.
WIIftJ 1C-08L 1&~idetrack - Coiled T mg Drilling
L1- -01-
Kuparuk IC-08 LI&~
Potential Drilling Håzards
POST ON RIG
1. Please perform pre-job Hazard ill and Safety meetings prior to every change in work scope during
the operation. Also, if things don't feel right shut-down the operation and discuss the situation
before making the next operational move. SAFETY FIRST.
2. H2S - WelllC-08 produces H2S at 65 ppm (measured 08/28/03). The highest H2S on lC pad was
measured at 232 ppm (lC-23, 08/04/02). lC is an H2S pad. H2S procedures must be followed
according to the AK Safety Handbook and Shared Services Drilling H2S SOP. All personnel
must be supplied with required PPE and H2S certified. Influxes of reservoir fluid could result in
H2S in the pit area, although KRU CTD sidetracks have not seen this in the past. The Pit watcher
should always cany a calibrated personal H2S monitor.
3. Reservoir pressure - Reservoir pressure is estimated at 3400 psi @ 6460' TVD (10.1 ppg) in the
adjacent fault blocks that will be penetrated with this well plan. Max. surface pressure with gas (0.1
psi/ft) to surface is 2754 psi. Reservoir frac gradient is ~0.7 psi/ft or 13.5 EMW, 4525 psi.
4. The Dynamically Overbalanced Coiled Tubing Drilling (DOCTD) technique will be used.
Drilling will be done with a less than kill-weight fluid (8.9 ppg PIo-Pro). While drilling and
circulating, hydrostatic head from the 8.9 ppg mud (2990 psi), plus 400-500 psi of annular friction,
plus 0 psi choked backpressure held on the return side will provide a 3400-3500 psi BHP and
overbalance the reservoir by ~ 1 00 psi. However, when circulation is shut down, the reservoir could
be underbalanced by 400-500 psi. Maintain at least 400 psi WHP when not circulating to prevent
reservoir in-flux and to maintain formation stability by keeping static BHP close to circulating BHP
seen during drilling. Adjust SIWHP accordingly when BHP increases are seen on the downhole
PWD sub. Increases will occur from higher-than-expected friction pressures and/or reservoir
pressures. Refer to the PWD BHP vs Depth chart to determine if deviations occur. Monitor return-
line flow rate and pit volume continuously. If a pit gain has been identified (underbalance event
occurred), divert those returns to an outside tank.
5. No gas saturated intervals are expected. However, always be prepared for the potential for gas
influx. Ensure all PVT equipment is fully operational and monitor return-line flow rate and pit
volume continuously.
6. Lost circulation is not expected. One fault shold be encountered along the wellbore trajectory. The
faults are sealing and lost circulation is considered low risk. If lost circulation occurs plan to control
it with adjustments to the DOCTD parameters. Lower circulation rate would be utilized prior to
LCM treatments. However, as a contingency ensure that LCM material is on location so that a pill
could be mixed quickly if required.
Kara 564-5667 office, 240-8047 cell
3/3
·U 1 C-08L 1 &L2 Sidetrack - Coiled .ing Drilling
Hazards
· One mapped fault in in the direction of the well path; lost circulation risk is low specially while DOCTD.
Reservoir pressure is estimated to be 10.] ppg in the fault block. WelllC-O as a H2S reading of 65 ppm /
(measured 08/28/03). The highest H2S on lC pad was measured at 232 p (JC-123.8/04/02). lC is any
H2S pad. All H2S monitoring equipment will be operational. //
Reservoir Pressure / .
/
. Reservoir pressure is approx. 3400 psi at ~ TVD 10..1 P. p~ÉMW. Max. surface pressure with gas (0.1
psi/ft) to surface is 2754 psi. v 4~ . //
~ù~ . (.(~
Dynamically overbalanced coiled tubing drilling ( CTD) techniques wiU be employed to address high
reservoir pressure. Plans are to use 8.9 ppg drill' g fluid in combination with annular friction losses and ,/
applied surface pressure to maintain overbala ed reservoir conditions. A hydraulic choke for regulating
surface pressure wiU be installed between t BOPE choke manifolding and the mud pits and will be
independent of the BOPE choke.
Using this technique with an underba nced mud weight requires deployment of the BHA under trapped
wellhead pressure. Deployment wi e accomplished utilizing the BOP pipe/slips (2-3/8" rams, see attached
BOP configuration), and/or the te ed tubing retrievable sub-surface safety valve. The annular preventer will
act as a secondary containment ring deployment and not as a stripper. At least two times hole volume of
kill weight fluid will be on 10 tion as a contingency.
..~'
The first pre-drilled line w: I be deployed above a closed tubing retrievable sub-surface safety valve. Once
drilling of L2 is complet , the production liner will be deployed into the wellbore after killing the well with
kill weight fluid.
Estimated reservoi ressure: 3400 psi at 6460' TVD, 10.1 ppg EMW. v
Expected annular riction losses while circulating (ECD): 400 psi
Planned mud de sity: 8.9 ppg equates to 2990 psi hydrostatic bottom hole pressure. ...
While circulat' g 8.9 ppg fluid, bottom hole circulating pressure is estimated to be 2900 psi
When circul ion is stopped, a minimum of 400 psi surface pressure will be applied to balance the reservoir.
arameters and fluid densities will be adjusted based on real-time bottom hole pressure
ents while drilling.
Kara 564-5667 office, 240-8047 cell
2/3
Kuparuk 3N-18Ll&L2
Potential Drilling Hazards
'u 1 C-08L 1 &L2 Sidetrack - Coiled T!ng Drilling
5ðG
~('CC .. ~(. POST ON RIG
S.::>\ (J r~
1. Please perform pre-job Hazard ill and Safety meetings prior to every c ange in work scope during
the operation. Also, if things don't feel right shut-down the operati and discuss the situation
before making the next operational move. SAFETY FIRST.
2. H2S - We1l3N-18 produces H2S at 110 ppm (measured 12/3 02). The highest H2S on 3N pad was
measured at 156 ppm (3N-02, 12/31/02). 3N is an H2S pad H2S procedures must be followed
according to the AK Safety Handbook and Shared Ser Ices Drilling H2S SOP. All personnel
must be supplied with required PPE and H2S certified. fluxes of reservoir fluid could result in
H2S in the pit area, although KRU CTD sidetracks ha not seen this in the past. The Pit watcher
should always carry a calibrated personal H2S moni r.
3. Reservoir pressure - Reservoir. pressure is esti ted at 3800 psi @ 6500'ss, 6568' TVD (11.1 ppg)
in the adjacent fault blocks that will be penetrat (l with this well plan. Max. surface pressure with
gas (0.1 psi/ft) to surface is 3150 psi. Reservo' frac gradient is -0.7 psilft or 13.5 EMW, 4600 psi.
4. The Dynamically Overbalanced Coiled T bing Drilling (DOCTD) technique will be used.
Drilling will be done with a less than kill- eight fluid (8.5 ppg PIo-Pro). While drilling and
circulating at 1.5 BPM, hydrostatic hea rom the 8.5 ppg mud (2900 psi), plus 1000 psi of annular
friction, plus 0 psi choked backpressur held on the return side will provide a 3900 psi BHP and
overbalance the reservoir by -100 ps' However, when circulation is shut down, the reservoir could
be underbalanced by -900 psi. Mai tain at least 900 psi WHP when not circulating to prevent
reservoir in-flux and to maintain £ mation stability by keeping static BHP close to circulating BHP
seen during drilling. Adjust SIW P accordingly when BHP increases are seen on the downhole
PWD sub. Increases will occur om higher-than-expected friction pressures and/or reservoir
pressures. Refer to the PWD P vs Depth chart to determine if deviations occur. Monitor return-
line flow rate and pit volume ontinuously. If a pit gain has been identified (underbalance event
occurred), divert those retu s to an outside tank.
5. No gas saturated intervals e expected. However, always be prepared for the potential for gas
influx. Ensure all PVT uipment is fully operational and monitor return-line flow rate and pit
volume continuously.
6. Lost circulation is n t expected. Two faults are expected to be encountered along the wellbore
trajectory. The faul are sealing and lost circulation is considered low risk. If lost circulation
occurs plan to cont 01 it with adjustments to the DOCTD parameters. Lower circulation rate (1
BPM minimum) ould be utilized prior to LCM treatments. However, as a contingency ensure that
LCM material is n location so that a pill could be mixed quickly if required. Pump only Liquid
Casing or OM al fine through a slimhole drilling BHA. Do not pump MI Seal through a drilling
BHA due to pI gging potential.
Kara 564-5667 office, 240-8047 cell
3/3
.
.",. ConocoPhillips Alaska, Inc.
1 C-08
API: 500292058500
SSSVType: LOCKEOOUT
SSSV
(1816-1817.
003.500)
Gas Lift
MandrelNalve
1
(2377-2378.
Gas Lift
MandrelNalve
2
(4469-4470,
Gas Lift
mdrel/Oummy
Valve 3
(5829-5830.
00:5.391)
Gas Lift
MandrelNalve
4
(6452-6453.
Gas Lift
MandrelNalve
5
(7195-7196.
Gas Lift
mdrel/Dummy
Valve 6
(7995-7996.
00:5.391)
Gas Lift
IndreVDummy
Valve 7
(8677-8678.
00:5.750)
PBR
(8724-8725.
003.500)
PKR
(8737-8738.
00:6.156)
NIP
(8774-8775,
00:3.500)
TUBING
(0-8808.
00:3.500,
10:2.992)
SOS -
(8808-8809.
00:3.500)
Perf
(8927-9012)
Perf
(9018-9030)
Perf
(9096-9122)
3:
Annular Fluid:
Reference Log:
Last Tag: 9113
Last Tag Date: 5/17/2004
Casing String - ALL STRINGS
Description
CONDUCTOR
SURFACE
PRODUCTION
Tubing String - TUBING
Size I Top
3.500 0
~erforations Summary
Interval TVD
8927 - 9012 6433 - 6498
9018 - 9030
9096 - 9122
6503 - 6512
6562 - 6582
.
KRU
1 C-08
We/I Type: PROD Angle @ TS: 40 deg (éiJ 8928
Orig 5/16/1981 Angle @ TO: 37 deg @ 9791
Completion:
Last W/O: 3/14/1990 Rev Reason: TAG FILL
Ref Log Date: Last Update: 512212004
TO: 9767 ftKB
Max Hole Angle: 57 deg @ 4400
Size Top Bottom TVD Wt Grade Thread
16.000 0 80 80 65.00 H-40
10.750 0 2714 2587 45.50 K-55
7.000 0 9767 9767 26.00 K-55
Bottom TVD Wt Grade Thread
8808 6342 9.20 J-55 BTC-AB-MOD
Zone Status Ft SPF Date Type Comment
UNIT Open 85 4 5/16/1981 IPERF
O,C4,C-3
C-2 Open 12 4 5/16/1981 IPERF
C-1,UNIT Open 26 4 5/16/1981 IPERF
B
_Gas Lift MandrelsNalves
St MD TVD Man Man Type VMfr V Type VOD Latch Port TRO Date Vlv
Mfr Run Cmnt
1 2377 2311 Cameo KBUG GLV 1.0 BK 0.156 1185 7/1212000
2 4469 3682 Cameo KBUG GLV 1.0 BK 0.188 1223 7/1212000
3 5829 4455 Cameo KBUG DMY 1.0 BK 0.000 0 7/12/2000
4 6452 4817 Cameo KBUG GLV 1.0 BK 0.250 1325 7/1212000
5 7195 5234 Cameo KBUG OV 1.0 BK 0.250 0 7/1212000
6 7995 5744 Cameo KBUG OMY 1.0 BK 0.000 0 7/1212000
7 8677 6242 Cameo MMG-2 DMY 1.5 RK 0.000 0 7/1212000
Other (plugs, equip., etc.) - JEWELRY
Depth TVD Type Description ID
1816 1811 SSSV Cameo TRDP 1A-SSA (Locked Out 6/23/97) 2.813
8724 6278 PBR Baker 3.000
8737 6288 PKR Baker 'HB' 3.000
8774 6316 NIP Cameo 'D' Nipple NO GO 2.750
8808 6342 SOS Baker 2.992
8809 6343 TTL 2.992
General Notes
Date I Note
1/31/1998 Pressure tubing & casing test good
12/14/1999 Dropped lower arm pin from 3" OK-1, possibly in LGM @ 7995 RKB
.
.
KRU 1 C-08A Producer
Proposed Completion
u
-~-
I. 4-112" 5M FMC tubing hanger with 4-1/2" L-80 1ST-mod pin down.
H. 4-112" 12.6# L-80 IBT Mod Tubing to surface.
G. 4-1/2" Cameo TRM' SSSV set at +1-2100' MD, 3.813" ID
Conoc~illips
Alaska, Inc.
F. 4-112" 12.6# L-80 IBT Mod tUbing to 'X' landing nipple wi 4-112" x 1" Cameo
'KBG-2' mandrels wI DV's, spaced out as follows:
10-3/4" 45.5# ~ .GI.Mtt MQ TIlQ
55 @ 2714"
1 2734' 2600'
2 4592' 3800'
3 6002' 4650'
4 7080' 5300'
5 7909' 5800'
3-3/16" liner top @
+1-8810' MD
Top of Flowthru
Whipstock & KOP at
+/-8930' MD
Window in 7"
---==:w C4-Sand
7" 26# J-5S @
9767 MD'
~ C1-Sand ~~
Fill
~
Note: Each GLM should have 10' L-80 handling pups installed on top and bottom.
E. 4-112" x 1" Cameo 'KSG-2' Mandrel at +/-8630' MD wI DCK Dump Kill Valve (2000 psi casing to
tubing shear). 10' L-80 handling pups installed on top and bottom of mandrel.
D. 1 joint 4-112" 12.6# L-80 1ST Mod Tubing
C. Baker 4-1/2" SABL packer at +/-8670' MD with PBR/seal assembly. 4" ID bore
A. 4-112" wireline entry sub at +1-8820' MD
B. 4-112" HES 'X' selective landing nipple with 3.813"'D at +/-8815' MD (necessary for 3.8" CTD bits)
C3/C4 Lateral, TD @ 11720' md ,/.
oj)
4-1/8" openhole
/
3-3/16" x 2-7/8" crossover @
9900'
.
o
o
Open hole KOP @ 10.100' md
....
2-718" pre-drilled liner
L 1..- 0 1- ~&,-<:'4,
o
o
o
o
o
o
C1lateral. TD @ 10830' md
LL
DEV 6/2/04
(08!Plan #8 1 C-08L;
Date: 09/066/2004
#8
Plan: Pia
Created By: Mel Rixse
Azimuths to True North
Magnetic North: 24.83'
T
ConocoPhil
WELLPATH DETAILS
Plat! #$ 1ç..o3L2
>"~l'It WêUpathJ Man#/! 1C-9¡
Ti<oon MO, 100(lO.{li)
RIg, Nm'die 2: 11'4.110«
Ref. Datum: Wel1hø"(94'j
V.$$C-fu»! Origin ~~~ ~:::~D
Anel. +NI..$
337.00' 0.00 0.06
REFERENCE INFORMATION
5950
6000
6100 6500
4600
4500
4400
4300
'aker Hughes IncorporatJ
INTEQ Planning Report
I Fi~ld: Kuparuk River Unit
I North Slope, Alaska
USA
Map System:US State Plane Coordinate System 1927
II Geo Datum: NAD27 (Clarke 1866)
Sys Datum: Mean Sea Level
L_~ ~-__________~_~__~_e~__
jsit;---P~d1C---------~~
I North Slope, Alaska
I Site Position: Northing: 5970228.13 ft
\ From: Map Easting: 560993.64 ft
I Position Uncertainty: 0.00 ft
, Ground Level: 60.50 ft
L__e_ ____ __e_~___.____e~___e_
Map Zone:
Coordinate System:
Geomagnetic Model:
Alaska, Zone 4
Well Centre
bggm2003
------______1
~-~---^.~---
--~-~-----.._-------~_._--_.------,
I
I
I
___J
Latitude: 70 19 45.173 N
Longitude: 149 30 19.124 W
North Reference: True
Grid Convergence: 0.47 deg
--,~--~-_._---
r W;II:·----oã----·~------
I Well Position: +N/-S -1245.87 ft
I +E/-W 668.58 ft
I Position Uncertainty: 0.00 ft
L____._____~__.
--~~-
-~~-~-~~~-~---e----~-----l
Slot Name:
Latitude: 70 19 32.920 N I
Longitude: 149 29 59.608 W I
~----j
Northing: 5968987.86 ft
Easting: 561672.26 ft
iWeupath-;-pìa~#81C-08L2-- ~;~~e: ¿:::~ Pla1~~g01góO~ 1------------1
Current Datum: Wellhead(94') Height 94.00 ft Above System Datum: Mean Se~ Level I
I Magnetic Data: 09/066/2004 Declination: 24.83 deg I
Field Strength: 57557 nT Mag Dip Angle: 80.79 deg ,
" v.....,,' ""","" "'... F_ (fVD) +N/-8 +FJ-W ÐI~". !
I=~_-=-=-===-_-=~~oo _-=-=__-=-=-_6~oo ~__~ o:~--==-~-__ i3;.~~=-=======-==J
Annotation
10000.00
10100.00
10200.47
10645.00
10720.00
10920.00
11270.00
11570.00
11720.00
6476.99
6482.22
6476.12
6391.46
6386.53
6394.49
6408.27
6415.74
6418.60
TIP
KOP'
3
4
5
6
7
8
TO
r·PJ;;;;-e-Plan-#8----------~-~------- D~te ëompo~-;¡;-~09/066i2004------e------1
l_p~in~p~:_y!S_______________~______j~:;~;~~___ ~r~m:yefil1i!i"e pattJ...______~J
Plan Section Information
;.1 10000.00 87.08 274.20 6476.99 3075.68 -5412.51 0.00 0.00 0.00 0.00
10100.00 86.96 289.22 6482.22 3095.89 -551 0.02 15.00 -0.12 15.02 90.85
10200.47 100.00 281.63 6476.12 3122.54 -5606.40 15.00 12.98 -7.55 330.00
10645.00 99.40 349.41 6391.46 3416.14 -5894.35 15.00 -0.14 15.25 84.00
10720.00 88.15 349.41 6386.53 3489.58 -5908.09 15.00 -15.00 0.00 180.00
10920.00 87.40 19.42 6394.49 3686.56 -5892.89 15.00 -0.38 15.01 92.00
11270.00 88.41 326.89 6408.27 4021.75 -5933.17 15.00 0.29 -15.01 -90.00
11570.00 88.88 11.90 6415.74 4309.02 -5986.92 15.00 0.15 15.00 90.00
11720.00 88.96 349.40 6418.60 4458.02 -5985.23 15.00 0.06 -15.00 -90.00
taker Hughes Incorporat!P
INTEQ Planning Report
10000.00 87.08 274.20 6476.99 3075.68 -5412.51 5972018.66 556235.17 0.00 0.00
10025.00 87.03 277.96 6478.27 3078.33 -5437.33 5972021.10 556210.33 15.00 90.85
10050.00 86.99 281.71 6479.58 3082.59 -5461.93 5972025.16 556185.71 15.00 90.66
10075.00 86.97 285.47 6480.89 3088.45 -5486.19 5972030.83 556161.40 15.00 90.46
10100.00 86.96 289.22 6482.22 3095.89 -5510.02 5972038.07 556137.51 15.00 90.26
10125.00 90.21 287.35 6482.84 3103.73 -5533.74 5972045.71 556113.73 15.00 330.00
10150.00 93.46 285.47 6482.04 3110.79 -5557.71 5972052.57 556089.71 15.00 330.05
10175.00 96.70 283.58 6479.82 3117.04 -5581.81 5972058.62 556065.56 15.00 329.99
10200.47 100.00 281.63 6476.12 3122.54 -5606.40 5972063.92 556040.93 15.00 329.82
10225.00 100.36 285.35 6471.79 3128.17 -5629.87 5972069.36 556017.41 15.00 84.00
10250.00 100.69 289.15 6467.22 3135.46 -5653.34 5972076.45 555993.89 15.00 84.66
10275.00 100.97 292.96 6462.52 3144.28 -5676.25 5972085.08 555970.91 15.00 85.35
10300.00 101.20 296.78 6457.71 3154.59 -5698.50 5972095.21 555948.57 15.00 86.07
10325.00 101.39 300.59 6452.81 3166.36 -5720.01 5972106.80 555926.97 15.00 86.80
10350.00 101.52 304.42 6447.84 3179.52 -5740.66 5972119.79 555906.21 15.00 87.55
10375.00 101.61 308.25 6442.83 3194.03 -5760.39 5972134.14 555886.37 15.00 88.31
10400.00 101.65 312.07 6437.79 3209.82 -5779.10 5972149.77 555867.53 15.00 89.08
10425.00 101.63 315.90 6432.74 3226.82 -5796.72 5972166.63 555849.78 15.00 89.85
10450.00 101.56 319.73 6427.71 3244.97 -5813.16 5972184.63 555833.19 15.00 90.62
10475.00 101.45 323.56 6422.73 3264.17 -5828.36 5972203.71 555817.83 15.00 91.39
10500.00 101.28 327.38 6417.80 3284.36 -5842.25 5972223.78 555803.78 15.00 92.16
10525.00 101.07 331.19 6412.95 3305.44 -5854.77 5972244.76 555791.08 15.00 92.91
10550.00 100.81 335.00 6408.21 3327.33 -5865.88 5972266.55 555779.80 15.00 93.65
10575.00 100.50 338.81 6403.58 3349.92 -5875.51 5972289.06 555769.98 15.00 94.37
10600.00 100.14 342.60 6399.10 3373.13 -5883.64 5972312.20 555761.66 15.00 95.07
10625.00 99.74 346.39 6394.79 3396.85 -5890.22 5972335.87 555754.89 15.00 95.75
10645.00 99.40 349.41 6391.46 3416.14 -5894.35 5972355.11 555750.59 15.00 96.41
10650.00 98.65 349.41 6390.68 3420.99 -5895.26 5972359.96 555749.65 15.00 180.00
10675.00 94.90 349.41 6387.73 3445.39 -5899.82 5972384.31 555744.88 15.00 180.00
10700.00 91.15 349.41 6386.41 3469.92 -5904.41 5972408.81 555740.10 15.00 180.00
10720.00 88.15 349.41 6386.53 3489.58 -5908.09 5972428.43 555736.26 15.00 180.00
10725.00 88.12 350.16 6386.70 3494.50 -5908.97 5972433.34 555735.33 15.00 92.00
10750.00 88.00 353.91 6387.54 3519.24 -5912.44 5972458.05 555731.67 15.00 91.98
10775.00 87.88 357.66 6388.44 3544.15 -5914.27 5972482.95 555729.62 15.00 91.85
10800.00 87.77 1.41 6389.39 3569.13 -5914.48 5972507.92 555729.22 15.00 91.71
10825.00 87.67 5.16 6390.39 3594.06 -5913.05 5972532.86 555730.44 15.00 91.57
10850.00 87.59 8.91 6391.42 3618.85 -5909.99 5972557.67 555733.30 15.00 91.42
10875.00 87.51 12.67 6392.49 3643.38 -5905.31 5972582.23 555737.77 15.00 91.27
10900.00 87.44 16.42 6393.59 3667.55 -5899.04 5972606.45 555743.84 15.00 91.11
10920.00 87.40 19.42 6394.49 3686.56 -5892.89 5972625.51 555749.83 15.00 90.94
10925.00 87.40 18.67 6394.72 3691.28 -5891.26 5972630.24 555751.42 15.00 270.00
10950.00 87.40 14.92 6395.86 3715.18 -5884.05 5972654.21 555758.44 15.00 270.03
10975.00 87.42 11.16 6396.99 3739.51 -5878.42 5972678.57 555763.87 15.00 270.20
11000.00 87.45 7.41 6398.10 3764.15 -5874.39 5972703.25 555767.70 15.00 270.37
11025.00 87.49 3.66 6399.21 3789.01 -5871.98 5972728.12 555769.90 15.00 270.54
11050.00 87.54 359.90 6400.29 3813.97 -5871.20 5972753.08 555770.47 15.00 270.71
11075.00 87.61 356.15 6401.35 3838.93 -5872.06 5972778.03 555769.41 15.00 270.87
11100.00 87.68 352.40 6402.38 3863.78 -5874.55 5972802.86 555766.71 15.00 271.03
11125.00 87.76 348.65 6403.37 3888.41 -5878.67 5972827.45 555762.40 15.00 271.18
11150.00 87.85 344.89 6404.33 3912.72 -5884.38 5972851.72 555756.48 15.00 271.33
11175.00 87.95 341.14 6405.24 3936.61 -5891.68 5972875.55 555748.99 15.00 271.48
11200.00 88.06 337.39 6406.11 3959.98 -5900.52 5972898.83 555739.96 15.00 271.61
11225.00 88.18 333.64 6406.93 3982.71 -5910.87 5972921.48 555729.42 15.00 271.74
· .
Baker Hughes Incorporated
INTEQ Planning Report
Survey
329.89 6407.69 4004.72 -5922.69 5972943.39 555717.42 15.00 271.87
326.89 6408.27 4021.75 -5933.17 5972960.33 555706.81 15.00 271.98
11275.00 88.41 327.64 6408.40 4025.95 -5935.87 5972964.51 555704.07 15.00 90.00
11300.00 88.42 331.39 6409.10 4047.49 -5948.55 5972985.94 555691.22 15.00 89.98
11325.00 88.43 335.15 6409.78 4069.80 -5959.78 5973008.16 555679.80 15.00 89.88
11350.00 88.45 338.90 6410.46 4092.81 -5969.54 5973031.08 555669.86 15.00 89.77
11375.00 88.47 342.65 6411.13 4116.40 -5977.77 5973054.60 555661.44 15.00 89.67
11400.00 88.51 346.40 6411.79 414Q.48 -5984.43 5973078.62 555654.57 15.00 89.57
11425.00 88.54 350.15 6412.44 4164.95 -5989.51 5973103.04 555649.30 15.00 89.47
11450.00 88.59 353.90 6413.06 4189.69 -5992.98 5973127.76 555645.63 15.00 89.37
11475.00 88.64 357.65 6413.67 4214.61 -5994.82 5973152.66 555643.58 15.00 89.28
11500.00 88.69 1.40 6414.25 4239.60 -5995.02 5973177.64 555643.17 15.00 89.19
11525.00 88.76 5.15 6414.81 4264.55 -5993.59 5973202.60 555644.40 15.00 89.10
11550.00 88.82 8.90 6415.34 4289.35 -5990.54 5973227.42 555647.25 15.00 89.02
11570.00 88.88 11.90 6415.74 4309.02 -5986.92 5973247.12 555650.70 15.00 88.94
11575.00 88.88 11.15 6415.84 4313.91 -5985.93 5973252.02 555651.66 15.00 270.00
11600.00 88.88 7.40 6416.32 4338.58 -5981.90 5973276.72 555655.48 15.00 270.01
11625.00 88.89 3.65 6416.81 4363.45 -5979.49 5973301.61 555657.69 15.00 270.09
11650.00 88.90 359.90 6417.29 4388.43 -5978.71 5973326.59 555658.26 15.00 270.16
11675.00 88.92 356.15 6417.77 4413.41 -5979.57 5973351.55 555657.19 15.00 270.23
11700.00 88.94 352.40 6418.23 4438.27 -5982.07 5973376.40 555654.49 15.00 270.30
/ 11720.00 88.96 349.40 6418.60 . 4458.02 -5985.23 5973396.11 555651.17 15.00 270.37
BOP-Tree
~.,
Floor
KB Elevation
I
·
Lubricator ID = 6.375w with 6w Otis Unions
I: 1/16w 5000 psi BOP·s. ID = 7.06" I
7 1/16" 5000 psi. RX-46 I
l1/4 Turn L T Valve .
13" 5000 psi
I
A
I,
I,
17 1/16ft 5000 psi (RX-46) or
4 1/16" 5000 psi (RX-39)
I
·
~
Swab Valve
I
Tree Size
.
I, SSV .
I,
·
Master Valve .
I
Base Flange .
·
Page 1
T12N
T11N
CTO out of 1 C-08
T11 N-R1
SW~
¡
ì
I
I
¡
I
j
I
I
I
I
I
I
I
¡
I
+ 0-
\
3
I
{)
: Feet
I: 1
1,OPO 2,000 3,000 4,000
3
.
.
PERMIT TO DRILL
20 MC 25.005
(e) If a well has multiple well branches, each branch requires a separate Permit to Drill. If multiple well
branches are proposed from a single conductor, surface, or production casing, the applicant shall
designate one branch as the primary wellbore and include all information required under (c) of this section
with the application for a Permit to Drill for that branch. For each subsequent well branch, the application
for a Permit to Drill need only include information under (c) of this section that is unique to that branch
and need not include the $100 fee.
.
.
TRANSMITAL LETTER CHECK LIST
CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO
BE INCLUDED IN TRANSMITTAL LETTER
L~-a\
WELL NAME t::;et< /C-{)8~
PTD# ZO<J - lie
~/ Development
Service
CHECK WßA T
APPLIES
ADD-ONS
(OPTIONS)
MULTI
LATERAL
v/
(If API Dumber
last two (2) digits
are between 60-69)
Exploration
Stratigraphic
"CLUE".
T~e ~ermit is fora n¿~~iJlbore segment of .!
e:llstJDg well J</~t\ ¡ . .., <t:_ .2.ô5'1fÇ" _ OCJ
Permit No, /fll-ð5Z-API No. ~'Z:¡ .
Production. should continue to be reported as
a function 'of tbe original API number. stated
above.
HOLE In accordance witb 20 MC 25.005(1), all
records, data and logs acquired for tbe piJot
bole must be dearly differentiated In both
name (name on permit plus PH)
and API number (50
70/80) from records, data and logs acquired
for wen (name on permit).
PILOT
(PH)
SPACING
EXCEPTION
V"
DRY DITCH
SAMPLE
Tbe permit is approved subject ·to fun
compliance witb 20 AAC 25.055. Approval to
perforate and produce is contingent upon
issua.nce of ;¡ conser¡ation ord~r ap~~f1:~ a.
spaclDg . e:xceptlon. ("¿~1IC4:> \, ,/~?'S
(Company Name) assumes tbe liability of any
protest to the spacing .exception tbat may
occur.
AU dry ditch sample sets submitted to tbe
Commission must be in no greater tban 30'
sample inten'~1Js from below tbe permafrost
or from wbere samples are first caught and
] 0' sample intervals tbrough target zones.
D
Well bore seg
Annular Disposal
KUPARUK RIV UNIT 1C-08L 1-01
Unit 11160
th_eXupar\Jk "C1" $and. fee_not r_eguir~d.
PrQd!Jctiye lnterval in ADL 025649;TDjn .Þ.Dl. 025648. _Correctipnsmad_eJo
On
Program PEV
On/Off Shore
Well Name:
PEND GeoArea890
M\Jlti-lateJal produc~r in
DEV
10-401
Kick off point <lndtop of
Kuparuk Rjver F:ield, Kuparuk RiveJ Oil ppol~ goveroedby _CO 432B
2004~
be ~CQ. _Notice_ puÞHshect June 21
i$ _59-_52-_180.
CO 4326 ha$ _no <ldministraJive œljeJ ruJe~ spa~ing exceptton wi
Operatorj$ Con9coPNllips;.proper. bond number
.
NA
Yes
Y.es
Yes
Yes
Y~s
No
Yes
Yes
Yes
No
Yes
Yes
NA
.NA
.NA
NA
nitial ClassfType
KUPARUK RIVER, KUPARUK RV OIL - 490100
NC
Field & Pool
Company
~ .'!"~I""r"'-,I~"",-,
.U.ntq\Je well
loc<lt~d
loc<lled proper .dtstanç
loc<lted pr.oper _dtstance_
_S.ufficient _acreage.aY<lil~ble
Jfdevi<lted, js. weJlbore pl<lt
Operator onl1' affected party
.Oper.ator lJas.appropriate.Qond i.nJorce
We
Wel
We
co.nserva.tion order
<ldmini$tratÌl(e. approvaJ
Permit
Permit
in_c.omments). (For
Injectioo
15-day wait
,....v'"',,,d wtthin <lrea and.str<lt<la\Jthorized by
servtce well only)
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
PTD#: 2041120
Administration
ut:; ....I""'r-'vv....u UÇlvre
Date
6/22/2004
Appr
SFD
Multi-lateral pf. e_xtsting.wel
Con.d\Jctor instaJled in j CoOS.
811 aquiJer$ exempted 40 cm
103(b)(3)
47.
CoOS. _
in. 1.C.-08~
inst~lJedin
Production nn inst<llled
Slotted liner cor letton planned.
Surface ca.stng
Célsi"",
1 CoOS.
Production castng cemented in
wells_.
J
No re$erve_pjtplanoe.d. All W<l$te to Class
Rig js.eq\Jippe.dwIih steelpit$.
MQthe.rbore an.dU OOly wells.pro.ximate..
~Q clo$.e.apprO<lc.hi$.s\Jes~ .C.oil sidetr.acks.are within.Kup<lr!Jk ~o_ne$.
BOP st<lck. wiIJ be. in place..
BI:IP expectect aU OJEMW. Plan. tp _use dyn<lmic overbaJa.nce with 8.9 ppg.and 400. psi at surface.
.'
4500 psiBOP te$t planne~:L
MASPcircuJating 29.00 P$Î._
M.Þ.SP calcuJatedat 2754 psi
Reservoir
Rige.quippedwitlJ sen.sors ~oct alarms.
M\Jd $h.ould pœcl!Jde 1:12S. on_rig.
65. ppm.1:I2S_ prod.uced on tC pad.
NA
NA
NA
No_
No.
Yes
Yes
NA
.Yes
_NA
Yes
Yes
Yes
Yes
YeS
Yes
NA
Con_si$tencyhas been
AÇMP F:indjng 9f
Condu.ctor
_S.urface _c<lsing pJote~t$. al
$tring_pJovided
8< surf. csg
.known USDW$
CMT vol adequate. to circ.ulateon .conductor.
Jongstring tos!Jrf C$g_
CMT v.ol adeQ uate_ to tie-in
_CMT will coyeraJl koown -Pfo.d!JctiYe horizons
C,.T, B&_ permafr9st
.C.asing design$ <ld.eC ua.te for
reserve pit
10A03 JQr ~bandonme.nt been approved
_Adequ~tetan.k<lge_ OJ
JfaJe-drill~ has.a
.Adequ~te.wellbore $ep<lr<ltion propO$ed
JfdivfJrter Jequired, dQes it mefJt reguJations.
_Drilliog fluid. program s~hem<ltic& e~uip list.adequale
.BPPEs,do
reguJation
_they meet
test to (pu.t p$ig in.comments)
.C.hokemanifold complie$. w/APl RF'-53 (May 84)
WQrk will PCCUr withput
BOPEpress ratiog <lpprop(iate;
operatjon.shutdo_w.n.
8
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
Engineering
Date
7/20/2004
Appr
TEM
ht~
~,9
wells wtthin 80R verified (for. s_ervjce WfJlJ only)
H2S g<ls_ prob.able
Me~ha.nic<llcpndjtton of
J$. pre$.ence. of
Þe drilled d1'n~mical!y.oYerbalan_ced withcoiJe.dtubjn-9.and 8.9 ppg m!Jd
KRU 1 C-08 mea~ure.d .65 ppm .H2S 00 8/23/200.3.
ResfJrvoir pressure.e$t. 10.
ppg; wi
No
.Yes
NA
.NA
NA
can be i.ssued w{o hydr.ogen. s.ulfide meas.u(e§;
Permit
D.atapJesented on potential pverpres.s\Jre .zOne!>
35
36
Date 37
6/22/2004138
39
Geology
Appr
SFD
.Seismican<llysjs. Qf §;haJlow gas.zooes.
_Se<lbedconditioo survey
off-sh.ore)
f
Date Multi-lateral producer in Kup "C3 & C4" sands. Productive interval crosses the boundary between leases ADL 025649 &
~ 025648. However, these leases and adjacent leases are committed to KRU & Kuparuk PA. The State of Alaska is the
~~ landowner. Spacing exception required as this will be the 3rd well bore open to the pool in SW/4 of Sec. 2, T11 N, R10E and
, A í1'~ the 2nd well bore open to the pool in the SE/4 and NE/4 of Sec. 3, T11 N, R10E. CO 432B has no administrative relief rule,
~ ~_ so soacina exceotion will be in the form of a CO. Notice oublished June 21. 2004.
Conta.ct nam.elpl1one.forweekly progress reports [exploratpiyonlyJ.
Public
~oe,
CONOCOPHILLlPS ALASKA
Permittee attache~ . .
Lease n!Jmber """'^""'¡;"^
n.a 1b.er .
in pol.
e. from driJling unitb.o!Jnd.aiy_
from other welJs
ndJilIiog unit
eluded
can be tssued without
c.ao be issued wjthQut
Can permit '-^ """'^',^-' '-","
Well'^^"'^" Order # (pullO#
.AJI w )f review ideotified (FOr $ervjc.e well onl1'). .
Pre- Qn.of pre-,prod\JçtiPIJ les$. th<ln 3 months (For
i$.s!Jed_ for. thi§; proiect.
Date
Engineering
Commissioner
Date:
7j¿d J~
Geologic
Commissioner:
OJ\{
e
e
Well History File
APPENDIX
Information of detailed nature that is not
particularly gennane to the Well Pennitting Process
but is part of the history file.
To improve the readability of the Well History file and to
simplify finding information, infonnation of this
nature is accumulated at the end of the file under APPENDIX.
No special effort has been made to chronologically
organize this category of information.
.
**** REEL HEADER
LDWG
06/12/08
****
AWS
01
**** TAPE HEADER ****
LDWG
04/08/11
01
*** LIS COMMENT RECORD ***
.
REViSED
COP'"
RECEIVED
OEe 2·8 2006
~OII&GasCons. CommlSSlCi
. Anchorage
!!!!!!!!!!!!!!!!!!! LDWG File Version 1.000
!! !!!!!!!!!!!!!!!!! Extract File: LISTAPE.HED
TAPE HEADER
KUPARUK RIVER 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:
JOB NUMBER:
LOGGING ENGINEER:
OPERATOR WITNESS:
MWD RUN 2
2
E. AQUIRRE
C. SEVCIK
MWD RUN 7
7
D. BARBA
C. SEVCIK
MWD RUN 15
15
D. BARBA
C. SEVCIK
#
SURFACE LOCATION
SECTION:
TOWNSHIP:
RANGE:
FNL:
FSL:
FEL:
FWL:
ELEVATION(FT FROM MSL 0)
KELLY BUSHING:
DERRICK FLOOR:
GROUND LEVEL:
#
DXC.
fÞ<{ -1/ d .f! !Li-¿:;0 i
j\ lC-08L10l
/ . 500292058561
ConocoPhillips Alaska, Inc.
BAKER HUGHES INTEQ
17-AUG-06
MWD RUN 3 MWD RUN 6
3 6
D. BARBA E. AQUIRRE
G. GOODRICH C. SEVCIK
MWD RUN 13 MWD RUN 14
13 14
D. BARBA E. AQUIRRE
C. SEVCIK M. FEKETI
12
11N
IDE
94.00
00.00
00.00
.
.
WELL CASING RECORD
OPEN HOLE
BIT SIZE (IN)
CASING
SIZE (IN)
10.750
7.000
4.500
DRILLERS
DEPTH (FT)
2714.0
9767.0
8820.0
11351. 0
1ST STRING
2ND STRING
3RD STRING
PRODUCTION STRING
3.750
#
REMARKS:
PER CONOCOPHILLIPS ALASKA STANDING ORDER, 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 19' 32.920"
LONG: W149 DEG 29' 59.608"
LOG MEASURED FROM K.B. AT 94.0 FT. ABOVE PERM. DATUM
(M.S.L.) .
COMMENTS:
(1) All depths are Measured Depths (MD) unless otherwise
noted.
(2) All depths are Bit Depths unless otherwise noted.
(3) All Gamma Ray data are real time data.
(4) Baker Hughes INTEQ utilized Coiltrak downhole tools
and the
Advantage surface system to log this well.
(5) Tools ran in the string included Casing Collar
Locator,
a Electrical Disconnect and Circulating Sub, a
Drilling
Performance Sub (inner and outer downhole pressure,
downhole
weight on bit, and vibration stick-slip), a Gamma
and
Directional Sub, and Hydraulic Orienting Sub with a
near bit
inclination sensor.
(6) Data presented here is final and was depth adjusted
to a PDC
(Primary Depth Control) log. The INTEQ Gamma Ray is
the PDC
for well lC-08L10l.
(7) The lC-08L10l wellbore was drilled from lC-08
through a milled window
in 7" liner.
Top of window
8923.6 ft. MD (6343.3 ft.
SSTVD)
Bottom of window
8938.0 ft. MD (6348.0 ft.
SSTVD)
(8) The interval from 11320 ft. to 11351 ft. MD
(6366 ft. to 6367 ft. SSTVD)was not logged due to
bit
to sensor offset.
(9) The lC-08L10l wellbore was tied to lC-08 at 8856 ft.
MD (6285 ft. SSTVD).
(10) The 1C-08L101 wellbore was sidetracked at 9732 ft. MD (6412
ft. SSTVD)
from lC-08L1.
(11) USR data from 8940 ft. to 9528 ft. MD
(6349 ft. to 6407 ft. SSTVD)is MAD PASS data.
$
Tape Subfile: 1
89 records...
Minimum record length:
Maximum record length:
8 bytes
132 bytes
!!!!!!!!!!!!!!!!!!! LDWG File Version 1.000
!!!!!!!!!!!!!!!!!!! Extract File: FILEOOl.HED
FILE HEADER
FILE NUMBER:
EDITED MERGED MWD
Depth shifted
DEPTH INCREMENT:
#
FILE SUMMARY
PBU TOOL CODE
MWD
$
.
**** FILE HEADER ****
LDWG .001
1024
*** LIS COMMENT RECORD ***
.
1
and clipped curves; all bit runs merged.
.5000
START DEPTH
8938.0
STOP DEPTH
11351. 0
#
BASELINE CURVE FOR SHIFTS:
CURVE SHIFT DATA (MEASURED DEPTH)
--------- EQUIVALENT UNSHIFTED DEPTH ---------
BASELINE DEPTH
$
#
MERGED DATA SOURCE
PBU TOOL CODE
MWD
MWD
MWD
MWD
MWD
MWD
MWD
$
#
REMARKS:
BIT RUN NO
2
3
6
7
13
14
15
MERGE BASE
9061.0
9493.0
9559.0
9698.0
9751.0
10570.0
11351.0
MERGE TOP
8938.0
9061.0
9493.0
9559.0
9698.0
9751. 0
10570.0
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
KRU-1C-08L1-01 5.xtf
150
ConocoPhillips Alaska, Inc.
lC-08L10l
Kuparuk River
North Slope
Alaska
*** INFORMATION TABLE: CIFO
MNEM CHAN DIMT CNAM
ODEP
.
.
----------------------------------------------------
GR GR GRAX 0.0
RPD RPD RPCL 0.0
RPS RPS RPCH 0.0
RAD RAD RACL 0.0
RAS RAS RACH 0.0
ROP ROP ROPA 0.0
* FORMAT RECORD (TYPE# 64)
Data record type is: 0
Datum Frame Size is: 28 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: 36
One depth per frame (value= 0)
Datum specification Block Sub-type is: 1
FRAME SPACE =
0.500 * F
ONE DEPTH PER FRAME
Tape depth ID: F
6 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 RPS MWD 68 1 OHMM 4 4
4 RAD MWD 68 1 OHMM 4 4
5 RAS MWD 68 1 OHMM 4 4
6 ROP MWD 68 1 FPHR 4 4
-------
24
Total Data Records: 135
Tape File Start Depth
Tape File End Depth
Tape File Level spacing
Tape File Depth Units
8938.000000
11350.000000
0.500000
feet
**** FILE TRAILER ****
Tape Subfile: 2 181 records...
Minimum record length:
Maximum record length:
8 bytes
4124 bytes
**** FILE HEADER ****
LDWG .002
1024
*** LIS COMMENT RECORD ***
· .
!!!!!!!!! !!!!!!!!!! Remark File Version 1.000
!!!!!!!!!!!! !!!!!!! Extract File: FILEOll.HED
3.125FILE HEADER
FILE NUMBER:
RAW MWD
Curves and
BIT RUN NO:
DEPTH INCREMENT:
#
FILE SUMMARY
VENDOR TOOL CODE
MWD
$
2
log header data for each bit run in separate files.
2
.2500
START DEPTH
8938.0
STOP DEPTH
9061. 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
MPR
GRAM
DIR
$
BOTTOM)
TOOL TYPE
MULT. PROP.
GAMMA RAY
DIRECTIONAL
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):
#
01-AUG-04
ADVANTAGE
3.125 CTK
MEMORY
9090.0
8921. 0
9061.0
o
45.2
88.7
TOOL NUMBER
10000103
10105429
10099075
3.750
8938.0
SFFP
9.00
.0
.0
4800
.0
.000
.000
.000
.000
127.0
.0
.0
.0
.00
.000
.0
o
BIT RUN 2 (MWD Run 2) .
GR/MPR.
CURVE GLOSSARY:
GRAM - GAMMA RAY APPARENT (MWD-API)
RPCL - DEEP PHASE RESISTIVITY (OHMM)
RPCH - SHALLOW PHASE RESISTIVITY (OHMM)
ROPS - RATE OF PENETRATION (FPHR)
REMARKS:
.
.
RACL - DEEP ATTENUATION RESISTIVITY (OHMM)
RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM)
$
#
*** INFORMATION TABLE: CONS
MNEM VALU
--------------------------------
WDFN
LCC
CN
WN
FN
COUN
STAT
KRU-IC-08L1-01.xtf
150
ConocoPhillips Alaska, I
lC-08L101
Kuparuk River
North Slope
Alaska
*** INFORMATION TABLE: CIFO
MNEM CHAN DIMT CNAM
ODEP
----------------------------------------------------
GRAX GRAX GRAX 0.0
RPCL RPCL RPCLX 0.0
RPCH RPCH RPCHX 0.0
RACL RACL RACLX 0.0
RACH RACH RACHX 0.0
ROPA ROPA ROPA 0.0
* FORMAT RECORD (TYPE# 64)
Data record type is: 0
Datum Frame Size is: 28 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: 36
One depth per frame (value= 0)
Datum Specification Block Sub-type is: 1
FRAME SPACE =
0.250 * F
ONE DEPTH PER FRAME
Tape depth ID: F
6 Curves:
Name Tool Code Samples Units Size Length
1 GRAX 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 ROPA MWD 68 1 FPHR 4 4
-------
24
Total Data Records:
14
Tape File Start Depth
Tape File End Depth
Tape File Level Spacing
8938.000000
9061.000000
0.250000
.
.
Tape File Depth Units
feet
**** FILE TRAILER ****
Tape Subfile: 3 96 records...
Minimum record length:
Maximum record length:
8 bytes
4124 bytes
**** FILE HEADER ****
LDWG .003
1024
*** LIS COMMENT RECORD ***
!!!!!!!!!!! !!!!!!!! LDWG File Version 1.000
!!!!!!!!!!!!!!!!!!! Extract File: FILEOI2.HED
FILE HEADER
FILE NUMBER:
RAW MWD
Curves and
BIT RUN NO:
DEPTH INCREMENT:
#
FILE SUMMARY
VENDOR TOOL CODE
MWD
$
3
log header data for each bit run in separate files.
3
.2500
START DEPTH
9061.0
STOP DEPTH
9493.0
#
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:
02-AUG-04
ADVANTAGE
3.125 CTK
MEMORY
9525.0
9061.0
9493.0
o
84.0
90.0
#
TOOL STRING (TOP TO
VENDOR TOOL CODE
MPR
GRAM
DIR
$
BOTTOM)
TOOL TYPE
MULT. PROP.
GAMMA RAY
DIRECTIONAL
RESIST.
TOOL NUMBER
10000103
10105429
10099075
#
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT):
3.750
8938.0
#
BOREHOLE CONDITIONS
MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S):
MUD PH:
MUD CHLORIDES (PPM):
SFFP
9.00
.0
.0
4800
.
.
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:
.0
.000
.000
.000
.000
123.0
.0
.0
.0
#
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
.00
.000
#
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
.0
o
#
REMARKS:
BIT RUN 3 (MWD Run 3) .
GR/MPR.
CURVE GLOSSARY:
GRAM - GAMMA RAY APPARENT (MWD-API)
RPCL - DEEP PHASE RESISTIVITY (OHMM)
RPCH - SHALLOW PHASE RESISTIVITY (OHMM)
ROPS - RATE OF PENETRATION (FPHR)
RACL - DEEP ATTENUATION RESISTIVITY (OHMM)
RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM)
$
#
*** INFORMATION TABLE: CONS
MNEM VALU
--------------------------------
WDFN
LCC
CN
WN
FN
COUN
STAT
KRU-1C-08L1-01.xtf
150
ConocoPhillips Alaska, I
1C-08LI0l
Kuparuk River
North Slope
Alaska
*** INFORMATION TABLE: CIFO
MNEM CHAN DIMT CNAM
ODEP
----------------------------------------------------
GRAX GRAX GRAX 0.0
RPCL RPCL RPCLX 0.0
RPCH RPCH RPCHX 0.0
RACL RACL RACLX 0.0
RACH RACH RACHX 0.0
ROPA ROPA ROPA 0.0
* FORMAT RECORD (TYPE# 64)
Data record type is: 0
Datum Frame Size is: 28 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: 36
One depth per frame (value= 0)
Datum Specification Block Sub-type is: 1
FRAME SPACE =
0.250 * F
ONE DEPTH PER FRAME
.
Tape depth ID: F
6 Curves:
Name Tool Code Samples Units Size Length
1 GRAX 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 ROPA MWD 68 1 FPHR 4 4
-------
24
Total Data Records: 49
Tape File Start Depth
Tape File End Depth
Tape File Level spacing
Tape File Depth Units
9061.000000
9493.000000
0.250000
feet
**** FILE TRAILER ****
Tape Subfile: 4 131 records...
Minimum record length:
Maximum record length:
8 bytes
4124 bytes
**** FILE HEADER ****
LDWG .004
1024
*** LIS COMMENT RECORD ***
!!!!!!!!!!!!!!!!!!! LDWG File Version 1.000
! ! ! ! ! ! ! ! ! ! ! !!!!! ! !! Extract File: FILEOI3.HED
FILE HEADER
FILE NUMBER:
RAW MWD
Curves and
BIT RUN NO:
DEPTH INCREMENT:
#
FILE SUMMARY
VENDOR TOOL CODE
MWD
$
4
.
log header data for each bit run in separate files.
6
.2500
START DEPTH
9493.0
STOP DEPTH
9559.0
#
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):
04-AUG-04
ADVANTAGE
3.125 CTK
MEMORY
9591.0
9493.0
9559.0
.
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG)
MINIMUM ANGLE:
MAXIMUM ANGLE:
#
TOOL STRING (TOP TO
VENDOR TOOL CODE
MPR
GRAM
DIR
$
BOTTOM)
TOOL TYPE
MULT. PROP.
GAMMA RAY
DIRECTIONAL
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):
#
.
o
90.0
90.0
TOOL NUMBER
10080984
10105429
10099075
3.750
8938.0
SFFP
9.00
.0
.0
4800
.0
.000
.000
.000
.000
119.0
.0
.0
.0
.00
.000
.0
o
BIT RUN 6 (MWD Run 6).
GR/MPR.
CURVE GLOSSARY:
GRAM - GAMMA RAY APPARENT (MWD-API)
RPCL - DEEP PHASE RESISTIVITY (OHMM)
RPCH - SHALLOW PHASE RESISTIVITY (OHMM)
ROPS - RATE OF PENETRATION (FPHR)
RACL - DEEP ATTENUATION RESISTIVITY (OHMM)
RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM)
$
REMARKS:
#
*** INFORMATION TABLE: CONS
MNEM VALU
--------------------------------
WDFN
LCC
CN
WN
FN
COUN
STAT
KRU-IC-08L1-01.xtf
150
ConocoPhillips Alaska, I
lC-08L101
Kuparuk River
North Slope
Alaska
*** INFORMATION TABLE: CIFO
MNEM CHAN DIMT CNAM
ODEP
.
.
GRAX GRAX GRAX 0.0
RPCL RPCL RPCLX 0.0
RPCH RPCH RPCHX 0.0
RACL RACL RACLX 0.0
RACH RACH RACHX 0.0
ROPA ROPA ROPA 0.0
* FORMAT RECORD (TYPE# 64)
Data record type is: 0
Datum Frame Size is: 28 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: 36
One depth per frame (value= 0)
Datum specification Block Sub-type is:
1
FRAME SPACE = 0.250 * F
ONE DEPTH PER FRAME
Tape depth ID: F
6 Curves:
Name Tool Code Samples Units Size Length
1 GRAX 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 ROPA MWD 68 1 FPHR 4 4
-------
24
Total Data Records: 8
Tape File Start Depth
Tape File End Depth
Tape File Level Spacing
Tape File Depth Units
9493.000000
9559.000000
0.250000
feet
**** FILE TRAILER ****
Tape Subfile: 5 90 records...
Minimum record length:
Maximum record length:
8 bytes
4124 bytes
**** FILE HEADER ****
LDWG .005
1024
*** LIS COMMENT RECORD ***
!!!!!!!!!!! !!!!! !!! LDWG File Version 1.000
· .
!!!!!!!!! !!!!!!!!!! Extract File: FILEOI4.HED
FILE HEADER
FILE NUMBER:
RAW MWD
Curves and
BIT RUN NO:
DEPTH INCREMENT:
#
FILE SUMMARY
VENDOR TOOL CODE
MWD
$
5
log header data for each bit run in separate files.
7
.2500
START DEPTH
9559.0
STOP DEPTH
9698.0
#
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
MPR
GRAM
DIR
$
BOTTOM)
TOOL TYPE
MULT. PROP.
GAMMA RAY
DIRECTIONAL
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):
#
05-AUG-04
ADVANTAGE
3.125 CTK
MEMORY
9732.0
9559.0
9698.0
o
80.4
94.2
TOOL NUMBER
10080984
10105429
10099075
3.750
8938.0
SFFP
9.00
.0
.0
4000
.0
.000
.000
.000
.000
127.0
.0
.0
.0
.00
.000
.0
o
BIT RUN 7 (MWD Run 7) .
GR/MPR.
CURVE GLOSSARY:
GRAM - GAMMA RAY APPARENT (MWD-API)
RPCL - DEEP PHASE RESISTIVITY (OHMM)
RPCH - SHALLOW PHASE RESISTIVITY (OHMM)
ROPS - RATE OF PENETRATION (FPHR)
RACL - DEEP ATTENUATION RESISTIVITY (OHMM)
REMARKS:
.
.
#
RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM)
$
*** INFORMATION TABLE: CONS
MNEM VALU
--------------------------------
WDFN
LCC
CN
WN
FN
COUN
STAT
KRU-IC-08L1-01.xtf
150
ConocoPhillips Alaska, I
1C-08L101
Kuparuk River
North Slope
Alaska
*** INFORMATION TABLE: CIFO
MNEM CHAN DIMT CNAM
ODEP
----------------------------------------------------
GRAX GRAX GRAX 0.0
RPCL RPCL RPCLX 0.0
RPCH RPCH RPCHX 0.0
RACL RACL RACLX 0.0
RACH RACH RACHX 0.0
ROPA ROPA ROPA 0.0
* FORMAT RECORD (TYPE# 64)
Data record type is: 0
Datum Frame Size is: 28 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: 36
One depth per frame (value= 0)
Datum Specification Block Sub-type is: 1
FRAME SPACE =
0.250 * F
ONE DEPTH PER FRAME
Tape depth ID: F
6 Curves:
Name Tool Code Samples Units Size Length
1 GRAX 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 ROPA MWD 68 1 FPHR 4 4
-------
24
Total Data Records: 16
Tape File Start Depth
Tape File End Depth
Tape File Level Spacing
Tape File Depth Units
9559.000000
9698.000000
0.250000
feet
.
.
**** FILE TRAILER ****
Tape Subfile: 6 98 records...
Minimum record length:
Maximum record length:
8 bytes
4124 bytes
**** FILE HEADER ****
LDWG .006
1024
*** LIS COMMENT RECORD ***
!!!!!!!! !!!!!!!!!!! LDWG File Version 1.000
!!!!!!!!!! !!!!!!!!! Extract File: FILEOI5.HED
FILE HEADER
FILE NUMBER:
RAW MWD
Curves and
BIT RUN NO:
DEPTH INCREMENT:
#
FILE SUMMARY
VENDOR TOOL CODE
MWD
$
6
log header data for each bit run in separate files.
13
.2500
START DEPTH
9698.0
STOP DEPTH
9751. 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-AUG-04
ADVANTAGE
3.125 CTK
MEMORY
9785.0
9698.0
9751. 0
o
88.6
92.4
#
TOOL STRING (TOP TO
VENDOR TOOL CODE
MPR
GRAM
DIR
$
BOTTOM)
TOOL TYPE
MULT. PROP.
GAMMA RAY
DIRECTIONAL
RESIST.
TOOL NUMBER
10080984
10105429
10079128
#
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT):
3.750
8938.0
#
BOREHOLE CONDITIONS
MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S):
MUD PH:
MUD CHLORIDES (PPM):
FLUID LOSS (C3):
SFFP
9.00
.0
.0
3500
.0
.
.
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TEMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
.000
.000
.000
.000
125.0
.0
.0
.0
#
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
.00
.000
#
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
.0
o
#
REMARKS:
BIT RUN 13 (MWD Run 13).
GR/MPR.
CURVE GLOSSARY:
GRAM - GAMMA RAY APPARENT (MWD-API)
RPCL - DEEP PHASE RESISTIVITY (OHMM)
RPCH - SHALLOW PHASE RESISTIVITY (OHMM)
ROPS - RATE OF PENETRATION (FPHR)
RACL - DEEP ATTENUATION RESISTIVITY (OHMM)
RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM)
$
#
*** INFORMATION TABLE: CONS
MNEM VALU
--------------------------------
WDFN
LCC
CN
WN
FN
COUN
STAT
KRU-IC-08L1-01.xtf
150
ConocoPhillips Alaska, I
1C-08L101
Kuparuk River
North Slope
Alaska
*** INFORMATION TABLE: CIFO
MNEM CHAN DIMT CNAM
ODEP
----------------------------------------------------
GRAX GRAX GRAX 0.0
RPCL RPCL RPCLX 0.0
RPCH RPCH RPCHX 0.0
RACL RACL RACLX 0.0
RACH RACH RACHX 0.0
ROPA ROPA ROPA 0.0
* FORMAT RECORD (TYPE# 64)
Data record type is: 0
Datum Frame Size is: 28 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: 36
One depth per frame (value= 0)
Datum Specification Block Sub-type is: 1
FRAME SPACE =
0.250 * F
ONE DEPTH PER FRAME
.
Tape depth ID: F
6 Curves:
Name Tool Code Samples Units Size Length
1 GRAX 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 ROPA MWD 68 1 FPHR 4 4
-------
24
Total Data Records: 6
Tape File Start Depth
Tape File End Depth
Tape File Level Spacing
Tape File Depth Units
9698.000000
9751.000000
0.250000
feet
**** FILE TRAILER ****
Tape Subfile: 7 88 records...
Minimum record length:
Maximum record length:
8 bytes
4124 bytes
**** FILE HEADER ****
LDWG .007
1024
*** LIS COMMENT RECORD ***
!!!!!!!!!!!!!!!!!!! LDWG File Version 1.000
! !! ! ! ! !! ! ! ! ! ! ! ! ! ! !! Extract File: FILE016.HED
FILE HEADER
FILE NUMBER:
RAW MWD
Curves and
BIT RUN NO:
DEPTH INCREMENT:
#
FILE SUMMARY
VENDOR TOOL CODE
MWD
$
7
.
log header data for each bit run in separate files.
14
.2500
START DEPTH
9751. 0
STOP DEPTH
10570.0
#
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):
09-AUG-04
ADVANTAGE
3.125 CTK
MEMORY
10607.0
9751.0
10570.0
o
.
HOLE INCLINATION (DEG)
MINIMUM ANGLE:
MAXIMUM ANGLE:
#
TOOL STRING (TOP TO
VENDOR TOOL CODE
MPR
GRAM
DIR
$
BOTTOM)
TOOL TYPE
MULT. PROP.
GAMMA RAY
DIRECTIONAL
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):
#
.
88.2
104.1
TOOL NUMBER
10080984
10079134
10079128
3.750
8938.0
SFFP
9.00
.0
.0
4000
.0
.000
.000
.000
.000
133.0
.0
.0
.0
.00
.000
.0
o
BIT RUN 14 (MWD Run 14) .
GR/MPR.
CURVE GLOSSARY:
GRAM - GAMMA RAY APPARENT (MWD-API)
RPCL - DEEP PHASE RESISTIVITY (OHMM)
RPCH - SHALLOW PHASE RESISTIVITY (OHMM)
ROPS - RATE OF PENETRATION (FPHR)
RACL - DEEP ATTENUATION RESISTIVITY (OHMM)
RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM)
$
REMARKS:
#
*** INFORMATION TABLE: CONS
MNEM VALU
--------------------------------
WDFN
LCC
CN
WN
FN
COUN
STAT
KRU-IC-08L1-01.xtf
150
ConocoPhillips Alaska, I
lC-08L101
Kuparuk River
North Slope
Alaska
*** INFORMATION TABLE: CIFO
MNEM CHAN DIMT CNAM
ODEP
----------------------------------------------------
GRAX
0.0
GRAX
GRAX
.
.
RPCL RPCL RPCLX 0.0
RPCH RPCH RPCHX 0.0
RACL RACL RACLX 0.0
RACH RACH RACHX 0.0
ROPA ROPA ROPA 0.0
* FORMAT RECORD (TYPE# 64)
Data record type is: 0
Datum Frame Size is: 28 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: 36
One depth per frame (value= 0)
Datum Specification Block Sub-type is:
1
FRAME SPACE =
0.250 * F
ONE DEPTH PER FRAME
Tape depth ID: F
6 Curves:
Name Tool Code Samples Units Size Length
1 GRAX 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 ROPA MWD 68 1 FPHR 4 4
-------
24
Total Data Records: 92
Tape File Start Depth
Tape File End Depth
Tape File Level Spacing
Tape File Depth Units
9751.000000
10570.000000
0.250000
feet
**** FILE TRAILER ****
Tape Subfile: 8 174 records...
Minimum record length:
Maximum record length:
8 bytes
4124 bytes
**** FILE HEADER ****
LDWG .008
1024
*** LIS COMMENT RECORD
***
!!!!!!!!!!!!!!!!!! !
!!!!!!!!!!!!!!!!!! !
LDWG File Version 1.000
Extract File: FILE017.HED
.
FILE HEADER
FILE NUMBER:
RAW MWD
Curves and
BIT RUN NO:
DEPTH INCREMENT:
#
FILE SUMMARY
VENDOR TOOL CODE
MWD
$
8
.
log header data for each bit run in separate files.
15
.2500
START DEPTH
10570.0
STOP DEPTH
11351. 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
MPR
GRAM
DIR
$
BOTTOM)
TOOL TYPE
MULT. PROP.
GAMMA RAY
DIRECTIONAL
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):
#
12-AUG-04
ADVANTAGE
3.125 CTK
MEMORY
11351. 0
10570.0
11351. 0
o
81. 9
90.8
TOOL NUMBER
10080984
10079134
10079128
3.750
8938.0
SFFP
9.00
.0
.0
4000
.0
.000
.000
.000
.000
133.0
.0
.0
.0
.00
.000
.0
o
BIT RUN 15 (MWD Run 15) .
GR/MPR.
CURVE GLOSSARY:
GRAM - GAMMA RAY APPARENT (MWD-API)
RPCL - DEEP PHASE RESISTIVITY (OHMM)
RPCH - SHALLOW PHASE RESISTIVITY (OHMM)
ROPS - RATE OF PENETRATION (FPHR)
RACL - DEEP ATTENUATION RESISTIVITY (OHMM)
RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM)
REMARKS:
.
.
$
#
*** INFORMATION TABLE: CONS
MNEM VALU
--------------------------------
WDFN
LCC
CN
WN
FN
COUN
STAT
KRU-1C-08L1-01.xtf
150
ConocoPhillips Alaska, I
1C-08L101
Kuparuk River
North Slope
Alaska
*** INFORMATION TABLE: CIFO
MNEM CHAN DIMT CNAM
ODEP
----------------------------------------------------
GRAX GRAX GRAX 0.0
RPCL RPCL RPCLX 0.0
RPCH RPCH RPCHX 0.0
RACL RACL RACLX 0.0
RACH RACH RACHX 0.0
ROPA ROPA ROPA 0.0
* FORMAT RECORD (TYPE# 64)
Data record type is: 0
Datum Frame Size is: 28 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: 36
One depth per frame .(value= 0)
Datum Specification Block Sub-type is: 1
FRAME SPACE =
0.250 * F
ONE DEPTH PER FRAME
Tape depth ID: F
6 Curves:
Name Tool Code Samples Units Size Length
1 GRAX 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 ROPA MWD 68 1 FPHR 4 4
-------
24
Total Data Records: 87
Tape File Start Depth
Tape File End Depth
Tape File Level Spacing
Tape File Depth Units
10570.000000
11350.000000
0.250000
feet
.
**** FILE TRAILER ****
.
Tape Subfile: 9 169 records...
Minimum record length:
Maximum record length:
**** TAPE TRAILER ****
LDWG
04/08/11
01
**** REEL TRAILER ****
LDWG
06/12/08
AWS
01
Tape Sub file: 10
Minimum record length:
Maximum record length:
~ ,
8 bytes
4124 bytes
2 records...
132 bytes
132 bytes
.
**** REEL HEADER ****
LDWG
06/08/17
AWS
01
**** TAPE HEADER ****
LDWG
04/08/11
01
*** LIS COMMENT RECORD ***
.
!!!!!!!!!!!!!!!!!!! LDWG File Version 1.000
! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! Extract File: LISTAPE.HED
TAPE HEADER
KUPARUK RIVER 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:
JOB NUMBER:
LOGGING ENGINEER:
OPERATOR WITNESS:
MWD RUN 2
2
E. AQUIRRE
C. SEVCIK
MWD RUN 7
7
D. BARBA
C. SEVCIK
MWD RUN 15
15
D. BARBA
C. SEVCIK
#
SURFACE LOCATION
SECTION:
TOWNSHIP:
RANGE:
FNL:
FSL:
FEL:
FWL:
ELEVATION(FT FROM MSL 0)
KELLY BUSHING:
DERRICK FLOOR:
GROUND LEVEL:
#
:Jô'l-l /;;).
· ,,:,J t{ 06""Ö
-I 'iDJ 1
1C-08L101
500292058561
ConocoPhil1ips Alaska, Inc.
BAKER HUGHES INTEQ
17-AUG-06
MWD RUN 3 MWD RUN 6
3 6
D. BARBA E. AQUIRRE
G. GOODRICH C. SEVCIK
MWD RUN 13 MWD RUN 14
13 14
D. BARBA E. AQUIRRE
C. SEVCIK M. FEKETI
12
11N
10E
52.00
00.00
00.00
.
.
WELL CASING RECORD
OPEN HOLE
BIT SIZE (IN)
CASING
SIZE (IN)
10.750
7.000
4.500
DRILLERS
DEPTH (FT)
2714.0
9767.0
8820.0
11351. 0
1ST STRING
2ND STRING
3RD STRING
PRODUCTION STRING
3.750
#
REMARKS:
PER CONOCOPHILLIPS ALASKA STANDING ORDER, 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 19' 32.920"
LONG: W149 DEG 29' 59.608"
LOG MEASURED FROM K.B. AT 52.0 FT. ABOVE PERM. DATUM
(M.S.L.) .
COMMENTS:
(1) All depths are Measured Depths (MD) unless otherwise
noted.
(2) All depths are Bit Depths unless otherwise noted.
(3) All Gamma Ray data are real time data.
(4) Baker Hughes INTEQ utilized Coiltrak downhole tools
and the
Advantage surface system to log this well.
(5) Tools ran in the string included Casing Collar
Locator,
a Electrical Disconnect and Circulating Sub, a
Drilling
Performance Sub (inner and outer downhole pressure,
downhole
weight on bit, and vibration stick-slip), a Gamma
and
Directional Sub, and Hydraulic Orienting Sub with a
near bit
inclination sensor.
(6) Data presented here is final and was depth adjusted
to a PDC
(Primary Depth Control) log. The INTEQ Gamma Ray is
the PDC
for well 1C-08L101.
(7) The sidetrack was drilled from 1C-08 through a
milled window
in 7" liner.
Top of window
8923.6 ft. MD (6343.3 ft.
SSTVD)
Bottom of window
8938.0 ft. MD (6348.0 ft.
SSTVD)
(8) The interval from 11320 ft. to 11351 ft. MD
(6366 ft. to 6367 ft. SSTVD)was not logged due to
bit
to sensor offset.
(9) Tied to 1C-08 at 8856 ft. MD (6285 ft. SSTVD).
(10) Sidetracked at 9528 ft. MD (6407 ft. SSTVD) from 1C-
08L1PB1.
(11) Sidetracked at 9732 ft. MD (6412 ft. SSTVD) from 1C-08L1.
(12) USR data from 8940 ft. to 9528 ft. MD
(6349 ft. to 6407 ft. SSTVD)is MAD PASS data.
$
Tape Subfile: 1
89 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: FILE001.HED
FILE HEADER
FILE NUMBER:
EDITED MERGED MWD
Depth shifted
DEPTH INCREMENT:
#
FILE SUMMARY
PBU TOOL CODE
MWD
$
1
and clipped curves; all bit runs merged.
.5000
START DEPTH
8938.0
STOP DEPTH
11351. 0
#
BASELINE CURVE FOR SHIFTS:
CURVE SHIFT DATA (MEASURED DEPTH)
--------- EQUIVALENT UNSHIFTED DEPTH ---------
BASELINE DEPTH
$
#
MERGED DATA SOURCE
PBU TOOL CODE
MWD
MWD
MWD
MWD
MWD
MWD
MWD
$
#
REMARKS:
BIT RUN NO
2
3
6
7
13
14
15
MERGE BASE
9061. 0
9493.0
9559.0
9698.0
9751. 0
10570.0
11351. 0
MERGE TOP
8938.0
9061.0
9493.0
9559.0
9698.0
9751.0
10570.0
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
KRU-1C-08L1-01 5.xtf
150
conocoPhillips Alaska, Inc.
1C-08L101
Kuparuk River
North Slope
Alaska
*** INFORMATION TABLE: CIFO
MNEM CHAN DIMT CNAM
ODEP
. .
GR GR GRAX 0.0
RPD RPD RPCL 0.0
RPS RPS RPCH 0.0
RAD RAD RACL 0.0
RAS RAS RACH 0.0
ROP ROP ROPA 0.0
* FORMAT RECORD (TYPE# 64)
Data record type is: 0
Datum Frame Size is: 28 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: 36
One depth per frame (value= 0)
Datum Specification Block Sub-type is: 1
FRAME SPACE =
0.500 * F
ONE DEPTH PER FRAME
Tape depth ID: F
6 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 RPS MWD 68 1 OHMM 4 4
4 RAD MWD 68 1 OHMM 4 4
5 RAS MWD 68 1 OHMM 4 4
6 ROP MWD 68 1 FPHR 4 4
-------
24
Total Data Records: 135
Tape File Start Depth
Tape File End Depth
Tape File Level Spacing
Tape File Depth Units
8938.000000
11350.000000
0.500000
feet
**** FILE TRAILER ****
Tape Subfile: 2 181 records...
Minimum record length:
Maximum record length:
8 bytes
4124 bytes
**** FILE HEADER ****
LDWG .002
1024
*** LIS COMMENT RECORD ***
!!!!!!!!!!!!!!!!!!! Remark File Version 1.000
· .
!!!!!!!!!!!!!!!!!!! Extract File: FILEOll.HED
3.125FILE HEADER
FILE NUMBER:
RAW MWD
Curves and
BIT RUN NO:
DEPTH INCREMENT:
#
FILE SUMMARY
VENDOR TOOL CODE
MWD
$
2
log header data for each bit run in separate files.
2
.2500
START DEPTH
8938.0
STOP DEPTH
9061. 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
MPR
GRAM
DIR
$
BOTTOM)
TOOL TYPE
MULT. PROP. RESIST.
GAMMA RAY
DIRECTIONAL
#
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):
#
01-AUG-04
ADVANTAGE
3.125 CTK
MEMORY
9090.0
8921. 0
9061.0
o
45.2
88.7
TOOL NUMBER
10000103
10105429
10099075
3.750
8938.0
SFFP
9.00
.0
.0
4800
.0
.000
.000
.000
.000
127.0
.0
.0
.0
.00
.000
.0
o
BIT RUN 2 (MWD Run 2) .
GR/MPR.
CURVE GLOSSARY:
GRAM - GAMMA RAY APPARENT (MWD-API)
RPCL - DEEP PHASE RESISTIVITY (OHMM)
RPCH - SHALLOW PHASE RESISTIVITY (OHMM)
ROPS - RATE OF PENETRATION (FPHR)
RACL - DEEP ATTENUATION RESISTIVITY (OHMM)
REMARKS:
.
.
RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM)
$
#
*** INFORMATION TABLE: CONS
MNEM VÞ.LU
--------------------------------
WDFN
LCC
CN
WN
FN
COUN
STAT
KRU-IC-08LI-0l.xtf
150
ConocoPhillips Alaska, I
lC-08L10l
Kuparuk River
North Slope
Alaska
*** INFORMATION TABLE: CIFO
MNEM CHAN DIMT CNAM
ODEP
----------------------------------------------------
GRAX
ROPA
GRAX
ROPA
GRAX
ROPA
0.0
0.0
* FORMAT RECORD (TYPE# 64)
Data record type is: 0
Datum Frame Size is: 12 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: 84
One depth per frame (value= 0)
Datum Specification Block Sub-type is: 1
FRAME SPACE = 0.250 * F
ONE DEPTH PER FRAME
Tape depth ID: F
2 Curves:
Name Tool Code Samples Units Size Length
1 GRAX MWD 68 1 GAP I 4 4
2 ROPA MWD 68 1 FPHR 4 4
-------
8
Total Data Records: 6
Tape File Start Depth
Tape File End Depth
Tape File Level Spacing
Tape File Depth Units
8938.000000
9061.000000
0.250000
feet
**** FILE TRAILER ****
Tape Subfile: 3 84 records...
Minimum record length:
Maximum record length:
8 bytes
4124 bytes
.
**** FILE HEADER ****
LDWG .003
1024
*** LIS COMMENT RECORD ***
!!!!!!!!!!!! !!!! !!! LDWG File Version 1.000
!!!!!!!!!!!!!!!!!!! Extract File: FILE012.HED
FILE HEADER
FILE NUMBER:
RAW MWD
Curves and
BIT RUN NO:
DEPTH INCREMENT:
#
FILE SUMMARY
VENDOR TOOL CODE
MWD
$
3
.
log header data for each bit run in separate files.
3
.2500
START DEPTH
9061.0
STOP DEPTH
9493.0
#
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
MPR
GRAM
DIR
$
BOTTOM)
TOOL TYPE
MULT. PROP.
GAMMA RAY
DIRECTIONAL
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:
02-AUG-04
ADVANTAGE
3.125 CTK
MEMORY
9525.0
9061. 0
9493.0
o
84.0
90.0
TOOL NUMBER
10000103
10105429
10099075
3.750
8938.0
SFFP
9.00
.0
.0
4800
.0
.000
.000
.000
.000
123.0
.0
.0
.0
.
.
MATRIX DENSITY:
HOLE CORRECTION (IN):
.00
.000
#
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
.0
o
#
REMARKS:
BIT RUN 3 (MWD Run 3) .
GR/MPR.
CURVE GLOSSARY:
GRAM - GAMMA RAY APPARENT (MWD-API)
RPCL - DEEP PHASE RESISTIVITY (OHMM)
RPCH - SHALLOW PHASE RESISTIVITY (OHMM)
ROPS - RATE OF PENETRATION (FPHR)
RACL - DEEP ATTENUATION RESISTIVITY (OHMM)
RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM)
$
#
*** INFORMATION TABLE: CONS
MNEM VALU
--------------------------------
WDFN
LCC
CN
WN
FN
COUN
STAT
KRU-IC-08LI-0l.xtf
150
ConocoPhillips Alaska, I
lC-08L10l
Kuparuk River
North Slope
Alaska
*** INFORMATION TABLE: CIFO
MNEM CRAN DIMT CNAM
ODEP
GRAX
ROPA
----------------------------------------------------
GRAX
ROPA
GRAX
ROPA
0.0
0.0
* FORMAT RECORD (TYPE# 64)
Data record type is: 0
Datum Frame Size is: 12 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: 84
One depth per frame (value= 0)
Datum Specification Block Sub-type is: 1
FRAME SPACE =
0.250 * F
ONE DEPTH PER FRAME
Tape depth ID: F
2 Curves:
Name Tool Code Samples Units
Size Length
1
2
4
4
4
4
68
68
1
1
GAP I
FPHR
GRAX MWD
ROPA MWD
-------
8
Total Data Records: 21
.
.
Tape File Start Depth
Tape File End Depth
Tape File Level Spacing
Tape File Depth Units
9061.000000
9493.000000
0.250000
feet
**** FILE TRAILER ****
Tape Subfile: 4 99 records...
Minimum record length:
Maximum record length:
8 bytes
4124 bytes
**** FILE HEADER ****
LDWG .004
1024
*** LIS COMMENT RECORD ***
!!!!!!!!!!! !!!!!!!! LDWG File Version 1.000
! ! ! ! ! ! ! ! ! ! !!!! ! ! ! !! Extract File: FILEOI3.HED
FILE HEADER
FILE NUMBER:
RAW MWD
Curves and
BIT RUN NO:
DEPTH INCREMENT:
#
FILE SUMMARY
VENDOR TOOL CODE
MWD
$
4
log header data for each bit run in separate files.
6
.2500
START DEPTH
9493.0
STOP DEPTH
9559.0
#
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:
04-AUG-04
ADVANTAGE
3.125 CTK
MEMORY
9591.0
9493.0
9559.0
o
90.0
90.0
#
TOOL STRING (TOP TO
VENDOR TOOL CODE
MPR
GRAM
DIR
$
BOTTOM)
TOOL TYPE
MULT. PROP.
GAMMA RAY
DIRECTIONAL
RESIST.
TOOL NUMBER
10080984
10105429
10099075
#
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT):
3.750
8938.0
#
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:
#
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
#
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
#
.
SFFP
9.00
.0
.0
4800
.0
.000
.000
.000
.000
119.0
.0
.0
.0
.00
.000
.0
o
BIT RUN 6 (MWD Run 6).
GR/MPR.
CURVE GLOSSARY:
GRAM - GAMMA RAY APPARENT (MWD-API)
RPCL - DEEP PHASE RESISTIVITY (OHMM)
RPCH - SHALLOW PHASE RESISTIVITY (OHMM)
ROPS - RATE OF PENETRATION (FPHR)
RACL - DEEP ATTENUATION RESISTIVITY (OHMM)
RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM)
$
REMARKS:
#
*** INFORMATION TABLE: CONS
MNEM VALU
--------------------------------
WDFN
LCC
CN
WN
FN
COUN
STAT
KRU-IC-08LI-0l.xtf
150
ConocoPhillips Alaska, I
lC-08L10l
Kuparuk River
North Slope
Alaska
*** INFORMATION TABLE: CIFO
MNEM CHAN DIMT CNAM
ODEP
----------------------------------------------------
GRAX
ROPA
0.0
0.0
GRAX
ROPA
GRAX
ROPA
* FORMAT RECORD (TYPE# 64)
Data record type is: 0
Datum Frame Size is: 12 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: 84
One depth per frame (value= 0)
Datum Specification Block Sub-type is: 1
FRAME SPACE =
0.250 * F
.
.
ONE DEPTH PER FRAME
Tape depth ID: F
2 Curves:
Name Tool Code Samples Units
Size Length
1
2
GRAX MWD
ROPA MWD
68
68
1
1
GAP I
FPHR
4
4
4
4
-------
8
Total Data Records: 4
Tape File Start Depth
Tape File End Depth
Tape File Level Spacing
Tape File Depth Units
9493.000000
9559.000000
0.250000
feet
**** FILE TRAILER ****
Tape Subfile: 5 82 records...
Minimum record length:
Maximum record length:
8 bytes
4124 bytes
**** FILE HEADER ****
LDWG .005
1024
*** LIS COMMENT RECORD ***
!!!!!!!!!!!!!!!!!!! LDWG File Version 1.000
!!!!!!!!!!!!!!!!!!! Extract File: FILEOI4.HED
FILE HEADER
FILE NUMBER:
RAW MWD
Curves and
BIT RUN NO:
DEPTH INCREMENT:
#
FILE SUMMARY
VENDOR TOOL CODE
MWD
$
5
log header data for each bit run in separate files.
7
.2500
START DEPTH
9559.0
STOP DEPTH
9698.0
#
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:
05-AUG-04
ADVANTAGE
3.125 CTK
MEMORY
9732.0
9559.0
9698.0
o
80.4
.
MAXIMUM ANGLE:
#
TOOL STRING (TOP TO
VENDOR TOOL CODE
MPR
GRAM
DIR
$
BOTTOM)
TOOL TYPE
MULT. PROP.
GAMMA RAY
DIRECTIONAL
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):
#
.
94.2
TOOL NUMBER
10080984
10105429
10099075
3.750
8938.0
SFFP
9.00
.0
.0
4000
.0
.000
.000
.000
.000
127.0
.0
.0
.0
.00
.000
.0
o
BIT RUN 7 (MWD Run 7) .
GR/MPR.
CURVE GLOSSARY:
GRAM - GAMMA RAY APPARENT (MWD-API)
RPCL - DEEP PHASE RESISTIVITY (OHMM)
RPCH - SHALLOW PHASE RESISTIVITY (OHMM)
ROPS - RATE OF PENETRATION (FPHR)
RACL - DEEP ATTENUATION RESISTIVITY (OHMM)
RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM)
$
REMARKS:
#
*** INFORMATION TABLE: CONS
MNEM VALU
--------------------------------
WDFN
LCC
CN
WN
FN
COUN
STAT
KRU-IC-08LI-0l.xtf
150
ConocoPhillips Alaska, I
lC-08L10l
Kuparuk River
North Slope
Alaska
*** INFORMATION TABLE: CIFO
MNEM CHAN DIMT CNAM
ODEP
----------------------------------------------------
GRAX
ROPA
GRAX
ROPA
GRAX
ROPA
0.0
0.0
.
.
* FORMAT RECORD (TYPE# 64)
Data record type is: 0
Datum Frame Size is: 12 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: 84
One depth per frame (value= 0)
Datum Specification Block Sub-type is: 1
FRAME SPACE = 0.250 * F
ONE DEPTH PER FRAME
Tape depth ID: F
2 Curves:
Name Tool Code Samples Units Size Length
1 GRAX MWD 68 1 GAP I 4 4
2 ROPA MWD 68 1 FPHR 4 4
-------
8
Total Data Records: 7
Tape File Start Depth
Tape File End Depth
Tape File Level Spacing
Tape File Depth Units
9559.000000
9698.000000
0.250000
feet
**** FILE TRAILER ****
Tape Subfile: 6 85 records...
Minimum record length:
Maximum record length:
8 bytes
4124 bytes
**** FILE HEADER ****
LDWG .006
1024
*** LIS COMMENT RECORD
***
!!!!!!!!!!!!!!!!!! !
!!!!!!!!!!!!!!!!!! !
LDWG File Version 1.000
Extract File: FILEOI5.HED
FILE HEADER
FILE NUMBER:
RAW MWD
Curves and
BIT RUN NO:
DEPTH INCREMENT:
#
FILE SUMMARY
VENDOR TOOL CODE
MWD
6
log header data for each bit run in separate files.
13
.2500
START DEPTH
9698.0
STOP DEPTH
9751. 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
MPR
GRAM
DIR
$
BOTTOM)
TOOL TYPE
MULT. PROP.
GAMMA RAY
DIRECTIONAL
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):
#
.
06-AUG-04
ADVANTAGE
3.125 CTK
MEMORY
9785.0
9698.0
9751. 0
o
88.6
92.4
TOOL NUMBER
10080984
10105429
10079128
3.750
8938.0
SFFP
9.00
.0
.0
3500
.0
.000
.000
.000
.000
125.0
.0
.0
.0
.00
.000
.0
o
BIT RUN 13 (MWD Run 13).
GR/MPR.
CURVE GLOSSARY:
GRAM - GAMMA RAY APPARENT (MWD-API)
RPCL - DEEP PHASE RESISTIVITY (OHMM)
RPCH - SHALLOW PHASE RESISTIVITY (OHMM)
ROPS - RATE OF PENETRATION (FPHR)
RACL - DEEP ATTENUATION RESISTIVITY (OHMM)
RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM)
$
REMARKS:
#
*** INFORMATION TABLE: CONS
MNEM VALU
--------------------------------
WDFN
LCC
KRU-IC-08LI-0l.xtf
150
.
.
CN
WN
FN
COUN
STAT
ConocoPhillips Alaska, I
1C-08L101
Kuparuk River
North Slope
Alaska
*** INFORMATION TABLE: CIFO
MNEM CHAN DIMT CNAM
ODEP
----------------------------------------------------
GRAX
ROPA
GRAX
ROPA
GRAX
ROPA
0.0
0.0
* FORMAT RECORD (TYPE# 64)
Data record type is: 0
Datum Frame Size is: 12 bytes
Logging direction is down (value= 255)
Optical Log Depth Scaie Units: Feet
Frame spacing: 0.250000
Frame spacing units: [F ]
Number of frames per record is: 84
One depth per frame (value= 0)
Datum Specification Block Sub-type is: 1
FRAME SPACE = 0.250 * F
ONE DEPTH PER FRAME
Tape depth ID: F
2 Curves:
Name Tool Code Samples Units Size Length
1 GRAX MWD 68 1 GAP I 4 4
2 ROPA MWD 68 1 FPHR 4 4
-------
8
Total Data Records: 3
Tape File Start Depth
Tape File End Depth
Tape File Level Spacing
Tape File Depth Units
9698.000000
9751.000000
0.250000
feet
**** FILE TRAILER ****
Tape Subfile: 7 81 records...
Minimum record length:
Maximum record length:
8 bytes
4124 bytes
**** FILE HEADER ****
LDWG .007
1024
· .
*** LIS COMMENT RECORD ***
!!!!!!!!!!!!!!!!!!! LDWG File Version 1.000
! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! Extract File: FILEOI6.HED
FILE HEADER
FILE NUMBER:
RAW MWD
Curves and
BIT RUN NO:
DEPTH INCREMENT:
#
FILE SUMMARY
VENDOR TOOL CODE
MWD
$
7
log header data for each bit run in separate files.
14
.2500
START DEPTH
9751. 0
STOP DEPTH
10570.0
#
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
MPR
GRAM
DIR
$
BOTTOM)
TOOL TYPE
MULT. PROP.
GAMMA RAY
DIRECTIONAL
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):
#
REMARKS:
BIT RUN 14 (MWD Run 14).
GR/MPR.
CURVE GLOSSARY:
GRAM - GAMMA RAY APPARENT (MWD-API)
RPCL - DEEP PHASE RESISTIVITY (OHMM)
08-AUG-04
ADVANTAGE
3.125 CTK
MEMORY
10607.0
9751. 0
10570.0
o
88.2
104.1
TOOL NUMBER
10080984
10079134
10079128
3.750
8938.0
SFFP
9.00
.0
.0
4000
.0
.000
.000
.000
.000
133.0
.0
.0
.0
.00
.000
.0
o
.
.
RPCH - SHALLOW PHASE RESISTIVITY (OHMM)
ROPS - RATE OF PENETRATION (FPHR)
RACL - DEEP ATTENUATION RESISTIVITY (OHMM)
RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM)
$
#
*** INFORMATION TABLE: CONS
MNEM VALU
--------------------------------
WDFN
LCC
CN
WN
FN
COUN
STAT
KRU-1C-08L1-01.xtf
150
ConocoPhillips Alaska, I
1C-08L101
Kuparuk River
North Slope
Alaska
*** INFORMATION TABLE: CIFO
MNEM CHAN DIMT CNAM
ODEP
GRAX
ROPA
----------------------------------------------------
GRAX
ROPA
GRAX
ROPA
0.0
0.0
* FORMAT RECORD (TYPE# 64)
Data record type is: 0
Datum Frame Size is: 12 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: 84
One depth per frame (value= 0)
Datum Specification Block Sub-type is: 1
FRAME SPACE =
0.250 * F
ONE DEPTH PER FRAME
Tape depth ID: F
2 Curves:
Name Tool Code Samples Units
Size Length
1
2
4
4
4
4
68
68
1
1
GRAX MWD
ROPA MWD
GAP I
FPHR
-------
8
Total Data Records: 40
Tape File Start Depth
Tape File End Depth
Tape File Level Spacing
Tape File Depth Units
9751.000000
10570.000000
0.250000
feet
**** FILE TRAILER ****
Tape Subfile: 8 118 records...
.
Minimum record length:
Maximum record length:
8 bytes
4124 bytes
**** FILE HEADER ****
LDWG .008
1024
*** LIS COMMENT RECORD ***
!!!!!!!!!!!!!!!!!!! LDWG File Version 1.000
!!!!!!!!!!!!!!!!!!! Extract File: FILE017.HED
FILE HEADER
FILE NUMBER:
RAW MWD
Curves and
BIT RUN NO:
DEPTH INCREMENT:
#
FILE SUMMARY
VENDOR TOOL CODE
MWD
$
8
.
log header data for each bit run in separate files.
15
.2500
START DEPTH
10570.0
STOP DEPTH
11351. 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
MPR
GRAM
DIR
$
BOTTOM)
TOOL TYPE
MULT. PROP.
GAMMA RAY
DIRECTIONAL
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:
10-AUG-04
ADVANTAGE
3.125 CTK
MEMORY
11351.0
10570.0
11351. 0
o
81. 9
90.8
TOOL NUMBER
10080984
10079134
10079128
3.750
8938.0
SFFP
9.00
.0
.0
4000
.0
.000
.000
.000
.000
133.0
.0
.0
.0
. .
#
NEUTRON TOOL
MATRIX:
MATRIX DENSITY: .00
HOLE CORRECTION (IN) : .000
#
TOOL STANDOFF (IN) : .0
EWR FREQUENCY (HZ) : 0
#
REMARKS:
BIT RUN 15 (MWD Run 15).
GR/MPR.
CURVE GLOSSARY:
GRAM - GAMMA RAY APPARENT (MWD-API)
RPCL - DEEP PHASE RESISTIVITY (OHMM)
RPCH - SHALLOW PHASE RESISTIVITY (OHMM)
ROPS - RATE OF PENETRATION (FPHR)
RACL - DEEP ATTENUATION RESISTIVITY (OHMM)
RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM)
$
#
*** INFORMATION TABLE: CONS
MNEM VALU
--------------------------------
WDFN
LCC
CN
WN
FN
COUN
STAT
KRU-IC-08LI-0l.xtf
150
ConocoPhillips Alaska, I
lC-08LI0l
Kuparuk River
North Slope
Alaska
*** INFORMATION TABLE: CIFO
MNEM CHAN DIMT CNAM
ODEP
----------------------------------------------------
GRAX
ROPA
GRAX
ROPA
GRAX
ROPA
0.0
0.0
* FORMAT RECORD (TYPE# 64)
Data record type is: 0
Datum Frame Size is: 12 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: 84
One depth per frame (value= 0)
Datum Specification Block Sub-type is: 1
FRAME SPACE = 0.250 * F
ONE DEPTH PER FRAME
Tape depth ID: F
2 Curves:
Name Tool Code Samples Units Size Length
1 GRAX MWD 68 1 GAP I 4 4
2 ROPA MWD 68 1 FPHR 4 4
<I
.
Total Data Records: 38
Tape File Start Depth
Tape File End Depth
Tape File Level Spacing
Tape File Depth Units
10570.000000
11350.000000
0.250000
teet
**** FILE TRAILER ****
Tape Subtile: 9 116 records...
Minimum record length:
Maximum record length:
8 bytes
4124 bytes
**** TAPE TRAILER ****
LDWG
04/08/11
01
**** REEL TRAILER ****
LDWG
06/08/17
AWS
01
Tape Subtile: 10
2 records...
Minimum record length:
Maximum record length:
132 bytes
132 bytes
.
8
