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~,~~~ STATE OF ALASKA
ALASKA AND GAS CONSERVATION COMMISSI~
APR ~t~T OF SUNDRY WELL OPERATIONS
1. Operations Performed: Abandon
~~ell ~ Plug Fbrforations ~ Stimulate [ Other ~ WINJ to WAG
Conversion
.
~~~ Pull Tubing ~ ; Perforate New Pbol ~ Waiver ~ ~,
Time Extension ,~
Change Approved Program Operat. Shutdow n G Perforate ~ Re-enter Suspended Well
2. Operator Name: 4. Current Well Status: Permit to Drill Number:
Inc.
ConocoPhillips Alaska Development ~ Exploratory r` 207-072
,
3. Address:
Stratigraphic r
Service ~ .API Number:
50-029-23359-61
P. O. Box 100360, Anchorage, Alaska 99510
7. Property Destanatio ~ 8. Well Name and A~umber:
ALK 25661 & 25650 ~ 1 J-122L2
9. Field/Pool(s):
Kuparuk River Field /West Sak Oil Pool
10. Present Well Condition Summary:
Total Depth measured ~ 18078 feet Plugs (measured) None
true vertical ~ 3797 feet Junk (measured) None
Effective Depth measured 18068 feet Packer (measured) 10301'
true vertical 3797 feet (true verucal) 3684'
Casing Length Size MD ND Burst Collapse
CONDUCTOR 106 20 106 106 0 0
SURFACE 3610 14.5 3640 2211 - .... 0 0
INTERMEDIATE 10306 9.625 10331 3931 0 0
"D" LAT SLOTTE 7741 8.27 18068 3797 0 0
Perforation depth: Measured depth: 10576' - 18068' '" ~j c"_ ~ '
True Vertical Depth: 3719' - 3797'
Tubing (size, grade, MD, and TVD) 4.5, L-80, 10299 MD, 3684 TVD
~
& 3684' TVD
Packers &SSSV (type, MD, and TVD) Packer -Baker TorqueMaster
SSSV =Nipple @ 509 MD and 508 TVD
11. Stimulation or cement squeeze summary:
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure:
12. Representative Daily Average Production or Injection Data
Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure
Prior to well operation 0 0 284 1188 610
Subsequent to operation 0 1767 0 954 798
13. Attachments 4. Well Class after proposed work:
Copies of Logs and Surveys run Exploratory r Development [! Service
. Well Status afterwork: Oil ('" Gas ~ WDSPL
Daily Report of Well Operations X
GSTOR ~ WAG ~ GASINJ ~ WINJ ~ SPLUG ~`
16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.o. Exempt:
309-060
Contact Bob Christensen/Darrell Humphrey
Printed Name R bert D. Christensen Title Production Engineering Specialist
Signature - ---~hone:~659-7535 Date ~ ~,~
Form 10-404 Revised 7/200~9,BDMS ppR 2 210 Submlt Orlglnal Only
• 1J-122L2 •
DESCRIPTION OF WORK COMPLETED
SUMMARY
Date Event Summa
04/05/10 WINJ to WAG Conversion.
•
k~ KRU 1J-122L2
~~ ConocoPhillips Alaska, inc.
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P ._ ~ ~ ~ ~' ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ G ~°~ ~ C r S ~~ ~ ~ ~ ~ ~ ' SEAN PARNELL, GOVERNOR
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tu1AS~ ~~! ~sL ~v-..7 "~ 333 W. 7th AVENUE, SUITE 100
COI~TSERQATIO~T COMI~IISSIOI~T ANCHORAGE, ALASKA 99501-3539
PHONE (907) 279-1433
FAX (907) 276-7542
Mr. M.J. Loveland
Well Integrity Project Supervisor
ConocoPhillips Alaska, Inc.
P.O. Box 100360
Anchorage, AK 99510
~b7~Q ~
Re: Kuparuk River Unit, West Sak Pool, 1J-122L2
Sundry Number: 309-060
~~.~I~1~~~ NO`~ 4 ~ 2009
Dear Mr. Loveland:
Enclosed is the approved Application for Sundry Approval relating to the
above referenced well. Please note the conditions of approval set out in the
enclosed form.
When providing notice for a representative of the Commission to witness any
required test, contact the Commission's petroleum field inspector at (907)
659-3607 (pager).
As provided in AS 31.05.080, within 20 days after written notice of this
decision, or such further time as the Commission grants for good cause
shown, a person affected by it may file with the Commission an application
for rehearing. A request for rehearing is considered timely if it is received by
4:30 PM on the 23rd day following the date of this letter, or the next working
day if the 23rd day falls on a holiday or weekend. A person may not appeal
a Commission decision to Superior Court unless rehearing has been
requested.
Sincerely,
~
Cathy P. Foerster
Commissioner
DATED this ~ day of October, 2009
Encl.
~
~ • •
ConocoPh i 1 I i ps
Alaska
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
February 13, 2009
Mr. Tom Maunder
Alaska Oil and Gas Conservation Commission
333 West 7`h Avenue, Suite 100
Anchorage, AK 99501
Dear Mr. Maunder:
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Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips
Alaska, Inc. Trilateral West Sak injection well 1J-122 (207-070), 1J-122L1 (207-071),
1J-122L2 (207-072) for viscosity reducing water alternating gas cycles (WRWAG).
Please call Perry Klein or me at 659-7043 if you have any questions.
Sincerely,
~i ~i-~/ ,
~~ ~%'r/
MJ eland
ConocoPhillips
Well Integrity Projects Supervisor
Enclosures
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STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION ~EE3 1 7 2009
APPLICATION FOR SUNDRY APPRO~(~la.0i1 & Gas ~ans. Commission
20 AAC 25.280 ~--~_____
1. Type of Request: Abandon ~ Suspend ^ Operational Shutdown ^ Pertorate ^ Waiver Other Q
Altercasing ^ Repairwell ^ Plug Pertorations ^ Stimulate ^ Time Extension ~
Change approved program ^ Pull Tubing ~ Perforate New Pool ^ Re-enter Suspended Well ^ VR EOR WAG
2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number:
ConocoPhillips Alaska, Inc. Deve~opment ~ Exploratory ^ 207-072 ~
3. Address: Svatigraphic ~ Service ~ 6. API Number:
P. O. Box 100360, Anchorage, Alaska 99510 50-029-23359-61 •
7. If perforating, closest approach in pool(s) opened by this operation to nearest property line S. Well Name and Number:
where ownership or landownership changes:
Spacing Exception Required? Y@S ^ NO Q 1J-122L2 .
9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s):
ALK 25661 ~& 25650 ~ RKB 109' ' Kuparuk River Field/ West Sak Oil Pool •
12. PRESENT WELL CONDITION SUMMARY
Total depth MD (ft): ~ Total Depth ND (ft):, Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured):
' 37'f? .rt~~R
Casing • ~ Length Size AAD ND Burst Collapse
CONDUCTOR ~g 20" 106' 106'
Surface 3612 13-3/8" 3640 2211'
Intermediate 11900 9-5/8" 11928' 3931'
Liner L2 D sand 7741 7"x5.5"x4.5" 18068' 3931'
Hook Hgr assy (D) 250 5.5x4.5" 10557 3612'
Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft):
Slotted and Blank liner 10576'-18068' 3719-3797' L-80 L-80 10303
Packers and SSSV Type: Packers and SSSV MD (ft)
Baker TorqueMasterPacker, 10301'
No SSSV- nipple 509'
13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work:
Detailed Operations Program ^ BOP Sketch ^ Exploratory ~ Development ^ Service ~^
15. Estimated Date for 16. Well Status after proposed work:
Commencing Operations: ~'7 ~/ v i G 4' Oil ^ Gas ^ Plugged ^ Abandoned ^
17. Verbal Approval: Date: WAG Q. GINJ ^ WINJ ^ WDSPL ~
Commission Representative:
18. I hereby certiy that the foregoing is true and correct to the best of my knowledge. Contact: Perry Klein/MJ Loveland
Printed Name MJ Lovelantl/Per I~fl Title: Well Integrity Project Supervisor
Signature ~',~?„1~ ~- ~.-~ / Phone 659-7043 Date ~~ 3 L5
~ Commission Use Onl
Sundry Number:
Conditions of approval: Notify Commission so that a representative may witness ~~ °~~~'
Plug Integrity ~ BOP Test ~ Mechanical Integrity Test ~ Location Clearance ^
Other: G( ~ t'rMaX~c. 0~0.2~^4~l~ ~i irl. 4G.C or~ ~, f'~ ~~J. 6 y'7
Subsequent Form Required: f ~ °'~ ~-~' ~~'~' ~
APPROVED BY ~
Q~ ~
Approved by: COMMISSIONER THE COMMISSION Date:
Form 10-403 Re~fised 06/2006 ~~~ L ~~ ~'0~ ~~ ~~ Submit in Duplicat~
.~~r~l ~- ~•/7• a9'
.
.
ConocoPhillips Alaska, Inc.
1J-122 (PTD 207-070) & 1J-122L1 (PTD 207-071) & 1J-122L2 (PTD 207-072)
Sundry Notice 10-403 Request
Februray 12, 2009
Purpose:
The purpose of this Sundry Notice is to notify the AOGCC of ConocoPhillips Alaska
Inc., intent to inject viscosity reducing water alternating gas (VRWAG) cycles in ~
West Sak Injection Well 1J-122 and gain approval to do so.
This well is part of a 4 pattern field trial of the West Sak VRWAG process that will
increase the oil recovery in each pattern and prove the incremental benefit of
VRWAG to West Sak for a potential future project to expand EOR on a broader
scale. See attached pattern map.
Well History:
1J-122 was drilled as in July 2007 as a trilateral development well and converted to ~
a water only injector in October 2007.
The well was drilled with a 20" conductor to 106'. The surFace hole was drilled with
a 16" bit and cased with 13-3/8" casing to a TD of 3640'. The casing was
cemented in place with 847 bbl of lead cement (Arctic set) and 165 bbl of tail
cement (Litecrete). Bumped plug on calculated displacement volume and the
floats held. There were good cement returns, 291 bbl recovered. The intermediate
hole was drilled with a 12 1/4" bit and cased to 111932' with 9 5/8" casing. The
casing was cemented in place with 366 bbl Deepcrete cement plug was not
bumped however, good returns were mentioned. The top of cement is confirmed
at 5920' by a USIT log. The USIT log also shows good bond through and above
the West Sak and Ugnu intervals. See attached USIT excerpt.
Proposed Plan:
The proposed plan includes the following:
1. Inject VRWAG cycles into 1 J-122
2. Injection well 1J-122 will be operated and maintained in compliance with 20
AAC 25 and Area Injection Order 2B.
3. All West Sak wells with in '/4 mile of 1 J-122 will be completed (or
recompleted) with a tubing & packer completion (vs. ESP).
4. The VRWAG cycles will be closely monitored with frequent oil and gas
samples from the offset West Sak producers.
5. All Kuparuk wells with in'/4 mile will have OA pressure indicating
transmitters installed prior to VRWAG start up.
6. Prior to start up well integrity issues and corresponding mitigating VRWAG
strategies will be clearly documented.
2009 WSAK EOR
Pattern Targets
.. 1.~- ~` ~
- ,...
1J-170
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[ r
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1 E-117 ~~~
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1 J-122
~
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1 J-122 Cement Log
Bottom interval
11,8E
Middle interval
9,71
Top interval
3,870-4,090
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GASR
MDR
•Pretty good bond around immediate vicinity of shoe
•Persistent poor bond along wellbore uphole but intervals of better cement bond are abundant
•Top of cement at 5,920' Tops
UG C 7,277
•550' of cumulative bond noted from USIT UG B 8,484
UG A 8,979
K13 9,477
D 10,295
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DATA SUBMITTAL COMPLIANCE REPORT
7/14/2009
Permit to Drill 2~7p72p Well Name/No. KUPARUK RIV U WSAK 1J-122L2 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23359-61-00
MD 18078 ND 3797 Completion Date 7/31/2007 Completion Status 1-OIL Current Status 1WINJ UIC
REQUIRED INFORMATION
Mud Log No Samples No Directional Survey Yes
DATAINFORMATqN
Types Electric or Other Logs Run: GR/RES, USIT (data taken from Logs Portion of Master Well Data Maint
Well Log Information:
Log/ Electr
Data Digitai Dataset Log Log Run Interval OH /
~ e mearrmt rvumoer Name acaie inraia rvo s[ar[ s[op ~n rceceroea ~.ommenrs
ED D Asc Directional Survey 0 18078 Open 9/12/2007
Rpt 15534 LIS Verification 3608 18078 Open 10/12/2007 LIS Veri, GR, RPS, FET,
~E'D C Lis
15534" Induction/Resistivity
3608
18078
Open
10/12/2007 ROP
LIS Veri, GR, RPS, FET,
ROP w/ PDF and TIF
graphics
~ Induction/Resistivity 25 Col 108 3797 Open 5/21/2009 ND EWR, DGR
Log Induction/Resistivity 25 Col 108 18078 Open 5/21/2009 MD ROP, EWR, DGR
D C Pdf 18047 "lnduction/Resistivity 0 0 Open 5/21/2009 EWR logs CGM, EMF,
PDF graphics
Well Cores/Samples Information:
Sample
Interval Set
Name Start Stop Sent Received Number Comments
ADDITIONAL INFORMATION ~
Well Cored? Y~I Daily History Received? N
Chips Received? ~Y"ftd- Formation Tops ~N
Analysis '~/ N~~
Received?
•
~
DATA SUBMITTAL COMPLIANCE REPORT
7/14/2009
Permit to Drill 2070720 Weil Name/No. KUPARUK RIV U WSAK 1J-122L2 Operator CONOCOPHILLIPS ALASKA INC
MD 18078 ND 3797 Completion Date 7/31/2007 Completion Status 1-OIL Current Status 1WINJ
Comments:
APINo. 50-029-23359-61-00
UIC Y
Compliance Reviewed By: b~~` Date: ~ l cJ~"1 Z`~~ ~~
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WELL LOG TRANSMITTAL
To: State of Alaska
Alaska Oil and Gas Conservation Comm.
Attn.: Librarian
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
RE: MWD Formation Evaluation Logs: 1J-122+L1+L2
May 14, 2009
AK-MW-5034903
The technical data listed below is being submitted herewith. Please address any problems or
concerns to the attention of:
Bryan Burinda, Sperry Drilling, Arctic Blvd., Anchorage, AK 99518
1J-122+L1+L2
2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log
50-029-23359-00,60,61
2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log
50-029-23359-00,60,61
Digital Log Images 3 CD Rom
~ 50-029-23359-00,60,61
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE
TRANSMITTAL LETTER TO THE ATTENTION OF:
Sperry Drilling
Attn: Bryan Burinda
6900 Arctic Blvd.
Anchorage, Alaska 99518
Office: 907-273-3536
Fax: 907-273-3535
Bry t, on.com
BP Exploration (Alaska) Inc.
Petrotechnical Data Center, MB33
900 E. Benson Blvd.
Anchorage, Alaska 99508
~ ~ ~~
Date: ~~0~ ~ ~ ~o~~ Signed:
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Conocc~Ph~ll~ps
May 13, 2008
T. Maunder
State of Alaska
Alaska Oil & Gas Conservation Commission
333 West 7th Avenue Suite 100
Anchorage, Alaska 99501
Subject: Additional Well Summaries
Dear Mr. Maunder:
~ J. Eggemeyer
Engineering Leader
Drilling & We~ls
~~S~~~cJ` ~ ~ ~~~
P. O. Box 100360
Anchorage, AK 99510-0360
Phon~: 907-265-6049
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ConocoPhillips Alaska, Inc. submits the attached well summaries for wells 1A-01,
CD4-07, 1 J-122, 1 J-122L1, 1 J-122L2, CD4-322, 1 J-162, 1 J-162L1 you requested.
These summaries will replace th-e iorter summaries already submitted with the
completion reports for these wells.
If you have any questions regarding this matter, please contact me at 265-6049.
Sincerely,
'~. / -
. Eggemeyer
Engineering Team Leader
CPAI Drilling
JE/skad
~
~, ~ECEIV~D
STATE OF ALASKA F~~ 2~1 ZO~~
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIOMN!'~ ~ g ~~ C0"~ C'"'~"'~''~
._~_
~. Operations Pertormed: Abandon ^ Repair Well ^ Plug Perforations ~ Stimulate ^ Other ~ Pre-Prod to Inj
Alter Casing ^ Pull Tubing ^ Perforate New Pooi ~ Waiver ^ Time Extension ^
Change Approved Program ^ Operat. Shutdown^ Perforate ~ Re-enter Suspended Well ^
2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number:
COnOCOPhillips Alaska, InC. Development ^ Exploratory ^ 207-072
3. Address: Stratigraphic ^ Service ~^ 6. API Number:
P. O. Box 100360, Anchorage, Alaska 99510 50-029-23359-61
7. KB Elevation (ft): 9. Well Name and Number:
RKB 109' 1J-122L2
8. Property Designation: 10. Field/Pool(s):
ALK 25661 & 25650 Kuparuk River Field / West Sak Oil Pool
11. Present Well Condition Summary:
Total Depth measured 18078' feet
true vertical 3797' feet Piugs (measured)
Effective Depth measured 18068' feet Junk (measured)
true vertical 3797' feet
Casing Length Size MD ND Burst Collapse
Structural
CONDUCTOR 80' 20" 80' 80'
SURFACE 3531' 13-3/8" 3640' 2212'
D-SAND WIND01 1' 9-5/8" 10333' 3690'
INTERMEDIATE 11819' 9-5/8" 11928' 3931'
D-SAND SLOTTE 8' 7" 10524' 3713'
D-SAND SLOTTED LINER 47' S-1/2~~ 10571' 3718~
Perforation depth: Measured depth: Slotted Liner 10616' - 18024'
true vertical depth: 3722' - 3797'
Tubing (size, grade, and measured depth) 4-1/2" , L-80, 10299' MD.
Packers & SSSV (rype & measured depth) no packer
SSSV= NIP SSSV= 509'
12. Stimulation or cement squeeze summary:
Intervals treated (measured)
Treatment descriptions including volumes used and final pressure:
13. Representative Daily Average Production or Injection Data
Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure
Prior to well operation 1119 511 60 1000 208
Subsequent to operation 2217 1569 146
14. Attachments 15. Well Class after proposed work:
Copies of logs and Surveys run _ Exploratory ^ Development ^ Service ^~
Daily Report of Well Operations _X 16. Well Status after proposed work:
Oil^ Gas^ WAG^ GINJ^ WINJ ^~ WDSPL^
17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt:
307-317
contact Bob Christensen / Bob Buchholz
Printed Name Robert W. Buchholz
Si
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659-7535 Production Engineering Technician
Date
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Form 10-404 Revised 04/2004
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`~ ~ ~ ' ~ ~~~~ ~'~'~~ ~ ~ j~d~ ~~~~"~ Submit Ori ' I Only
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1J-122L2
DESCRIPTION OF WORK COMPLETED
SUMMARY
Date Event Summary
02/12/08 Commenced Water injection
~ •
Maunder, Thomas E (DOA)
From: Eggemeyer, Jerome C. [Jerome.C.Eggemeyer@conocophillips.com]
Sent: Wednesday, January 30, 2008 8:13 AM
To: Maunder, Thomas E (DOA)
Cc: Allsup-Drake, Sharon K
Subject: RE: Operations Reports
thanks tom. I am sure we can accommodate.
jce
From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov]
Sent: Wednesday, January 30, 2008 8:07 AM
To: Eggemeyer, Jerome C.
Cc: Allsup-Drake, Sharon K
Subject: RE: Operations Reports
Page 1 of 1
Thanks Jerome. These aren't urgently needed. Only other request, is send the reports "single sided". When we
get double-sided, we have to shoot additional copies in order to scan.
Tom
From: Eggemeyer, Jerome C. [mailto:Jerome.C.Eggemeyer@conocophillips.com]
Sent: Tuesday, January 29, 2008 10:36 PM
To: Maunder, Thomas E (DOA)
Cc: Allsup-Drake, Sharon K
Subject: RE: Operations Reports
thanks tom. As soon as Sharon is able to organize the data it will be sent over (hopefully only a few days
depending on other activities). Let us know if it is needed more urgently.
jce
From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov]
Sent: Tuesday, January 29, 2008 4:38 PM
To: Eggemeyer, Jerome C.
Cc: Allsup-Drake, Sharon K
Subject: Operations Reports
Jerome and Sharon,
Thanks for sending the more detailed operations reports. I have further reviewed the Commission's files
regarding 407's submitted since about August and found that more complete reports are needed for a few other
wells. The wells are:
1 J-162, -162L1 207-080, 207-181
CD4-322 207-101
1 J-122, -122L1, -122L2 207-070, 207-071, 207-072 ~ h~~3~E`' Z h~~~
For the multilateral wells, a complete summary is only needed for the main wellbore with only the specific
operations needed for the laterals.
Your assistance in making the well records complete is appreciated. I will be reviewing the recently submitted
sundry reports shortly and will send another message if necessary. Call or message with any questions.
Tom Maunder, PE
AOGCC
8/18/2009
~
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AI.ASB~ ~u ~I1TD G~S
C011TSERQA7`I011T CO1rIIrIISSI011T
Robert Christensen
Production Engineering Technician
ConocoPhillips Alaska, Inc
PO Box 100360
Anchorage, AK 99510
Re: Kuparuk River Field, West Sak Oil Pool, 1J-122L2
Sundry Number: 307-317
Dear Mr. Christensen:
SARAH PALIN, GOVERNOR
333 W. 7thAVENUE, SUITE 100
ANCHORAGE, ALASKA 99501-3539
PHONE (907) 279-1433
FAX (907) 276-7542
Enclosed is the approved Application for Sundry Approval relating to the
above referenced well. Please note the conditions of approval set out in the
enclosed form.
When providing notice for a representative of the Commission to witness any
required test, contact the Commission's petroleum field inspector at (907)
659-3607 (pager).
As provided in AS 31.05.080, within 20 days after written notice of this
decision, or such further time as the Commission grants for good cause
shown, a person affected by it may file with the Commission an application
for rehearing. A request for rehearing is considered timely if it is received by
4:30 PM on the 23rd day following the date of this letter, or the next working
day if the 23rd day falls on a holiday or weekend. A person may not appeal
a Commission decision to Superior Court unless rehearing has been
requested.
DATED this ~day of October, 2007
Encl.
U
~~:;`~-C~'~ ~
Sincerely,
t ~ ~ ~ .. ~~l ~` j~/ ~ . `" ,1 ~~~~..U~ ~~~ . ~ ~~~;~ .
~ . . .. . . . . . . . ~ k ~. } , _ .
. ~ ~ . .. . : ~ 1':d , ~. . .
~ 1~~ ~ ° ~
~ ~ ~ ~ ~ ~ ~STATE OF ALASKA ~ ~~ ~ ~ ~ t~ t, ~ ~ 4 ; ~%, ' %
~ ~ ~ ~ ~ ~ ~ ~ ~~ ~ ~ALASKA OIL AND GAS CONSERVATIQN COMMISSION ~~~ ~, ~ ~ ~:.
APPLICATION FOR SUNDRY APPROVAL x
2o aac 2~.2so
1. Type of Request: Abandon ~ Suspend ^ Operational Shutdown ^ Perforate ^ Waivec ~ Other ^/
Alter casing ~ Repair well ^ Plug Perforations ^ Stimulate ^ Time E~ension ~
Chan e a roved ro ram
9 pp p 9 ^, Pull Tubing ~'
Perforate New Pool -^ Producer to
Re-enter Suspended Weli ^ injector
2. Operator Name: 4. Current Well Class ` 5. Permit to Drili Number:
ConocoPhiliips Alaska, Inc. Developmern Q' Exploratory ^ 207-072 ;-,
3. Address: Stratigraphic ~ Service ~ 6. API Number.
P. O. Box 100360, Anchorage, Alaska 99510 50-029-23359-61 ~
7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number:
where ownership or landownership chang es _
Spacing Exception Required? YeS ^ NO 0 , 1J-122L2 f
9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s):
ALK 25661 & 25650 ; RKB 109' ~ Kuparuk River Field / West Sak Oil Pool ~
12• PRESENT WELL CONDITION SUMMARY
Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured):
18078' ~ 379T = 18068' < 3797' ~
Casing Length Size MD ND Burst Collapse
CONDUCTOR g~~ 20.. $~~ 80'
SURFACE 3531' 13-3/8" - 3640' 2212'
D-SAND WINDOW 1,. 9-5/8" 10333' 3690'
INTERMEDIATE 11819' 9-5/8" 11928' 3931'
SAND SLOTTED LW g~ 7° 10524' "3713'
~-SAND SLOTTED LINER q,T 5-'I /Z° 'I OS7'I ~ 371$~
Perforation Depth MD (ft): Perforation Depth ND {ft): Tubing Siz2; ' Tubing Grade: Tubing MD {;t);
Slotted Liner 10616' - 18024' 3722' - 379T 4-1/2" L-80 10299`
Packers and-SSSV Type: _ Packers and SSSV MQ (ftj_ , __
PKR = Baker HRQ ZXP LT
_ PKR = 10970'
SSSV= NIP SSSV= 509'
13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work:
Detailed Operations Program ^ BOP SketcM ^ Exploratory ~ Development ^ Service Q r
15. Estimated Date far 16. Well Status after proposed work:
Commencing Operations Nov. 11, 2007 Oil ^ Gas ^ Plugged ^ Abandoned ^
17. Verbal Approval' Date: WAG ~ GINJ ;^ WINJ ^~ WDSPL ~
Commission Representative:
18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Bob Christensen / Bob Buchhoiz
Printed Name R el't D. ChriS flSell Title: Production Engineering Technician
Signature !
Phone 659-7535 Date ~ Q
Commissiorr Use Onl
Sundry Number:
Conditions of approvaL• Notify Commission so thaY a representative may witness - +
Plug Integrity ~ BOP Test ~' Mechanical Integrity Test ~ Location Clea~ance ^
Other: ~ ~~'\v`-~Cs~~ ~°s ~°
~ ~C Cy...T~ (~-~ ~ ~'~ Cx~LC`~.. ~'~ ~ / . ~
~~~ ~-
S ~F~ Q GT ~ ~ 2007
Subsequent Form Required: ~v ~
APPROVED BY /iC
/
~
~
Approved by: MISSIONER ~
/
6
THE COMMISSION Date: f~~
.
Form 10-4~3 Revised 06/2006~
7
• Submit in Duplicate ~'!?
~ _
c
a~
. . . . . .. • ~ . ~ ~ ~ . ~~. ... . . . . r~ ... . .
. . . . . . . . . ~ .. ~ ~
1J-122L1
DESCRIPTION SUMMARY
OFPROPOSAL
ConocoPhillips Alaska 1nc. requests approval to begin Water Injection service in West Sak Tri-
laterat Well 1J-122L1. This well has been pre-produced for approximately 30 days in order to
recover Oil based drilling fluids prior to putting the well on injection. 1 J-122L1 wil( provide `
pressure support for the West Sak B sands.
The 13-3/8" Surface casing ( 3640' md / 2212' tvd) was cemented with 1031 sx AS Lite
followed by 372 sx LiteCRETE, The 9-5/8" Intermediate casing ( 11928' md / 3931' tvd) was
cemented with 920 sx DeepCRETE.
The injection tubing/casing annulus is isolated via the following: Upper D sand LEM Baker
Seal Assembly located @ 10451' md / 3705' tvd, Upper B sand HRD ZXP 7" x 9-5/8" Liner
Top Packer with 190-47 Casing Sealbore Receptacle located @ 10442' md / 3705' tvd, and an
Upper A sand HRD ZXP 7" x 9-5/8" Liner Top Packer located @ 10970' mdJ 3788' tvd.
~
The top of West Sak D sand was found at 10295' md / 3684' tvd.
D sand Lateral window top is located @ 10332' md / 3689' tvd.,
_. ~
~- The top of West Sak B sand was found at 10828' md / 3765' tvd. --
B sand Lateral window top is located @ 10827' md / 3765' tvd.
The top of West Sak A sand was found at 11880' md / 3927' tvd.
,
i
:
~
~
~
,
~
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. . . . . . . . . .. . . . . , .. . . .. . . ~ . ~ . . ~; .
. . . . . . . . . . ~ ~ ~ ~ .. . . . ~ . . .. . . . . . . . ~...
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. ~ . . . . . . . . .. .. . ~ .. .. ~~ :
. .. .. . . . . . . ~ ~ . . ~~
~ •
ConocoPhillips Alaska, Inc.
KRU 1 J-122L2
LOCATOR
;10275-10276,
OD:5.500)
XO Bushing
;10515-10516,
OD:6.080)
Perf
17128-18024)
1 J-122L2
API: 500292335961 Well T e: PROD An le TS: de
SSSV T e: NIPPLE Ori Com letion: 8/1/2007 An le TD: 90 de 18078
Annular Fluid: Last W/O: Rev Reason: NEW WELL
Reference L: 28' RKB Ref Loq Date: Last U date: 8/17/2007
Last Ta : TD: 18078 ftKB
Last Ta Date: Max Hole An le: 94 de 14886
Casin Strin - ALL STRINGS
Desc~tion Size To Bottom TVD Wt Grade Thread
__
CONDUCTOR _
20.000 0 80 80 94.00 K-55 WELDED
INTERMEDIATE 9.625 0 11928 3741 40.00 L-80 BTCM
SURFACE 13.375 0 3640 2212 68.00 L-80 BTC
D-SAND WINDOW 10.000 10332 10333 3690 0.00
D-SAND SIOTTED LINER 7.000 10516 10524 3713 26.00 BTCM BTCM
D-SAND SLOTTED LINER 5.500 10524 10571 3718 15.50 BTCM BTCM
D-SAND SLOTTED LINER 4.500 10572 18066 3797 11.60 BTCM BTCM
Tubin Strin - TUBING
Size To Bottom TVD Wt Grade Thread
4.500 0 10299 3684 12.60 L-80 IBT
_ _ = Perforations Summar
Interval TVD Zone Status Ft SPF Date T e Comment
10616 - 10945 3722 - 3727 WS D 329 32 7/27I2007 SLOTS Alternating solidlslotted pipe
2.5"x.125", 4 curcumferential rowslft
3" centers sta ered 80de
11182 - 11661 3733 - 3737 WS D 479 32 7/27/2007 SLOTS Alternating solid/slotted pipe
2.5"x.125", 4 curcumferential rowsHt
3" centers sta ered SOd
11897 - 12415 3741 - 3747 WS D 518 32 7/27I2007 SLOTS Alternating solid/slotted pipe
2.5"x.125", 4 curcumferential rows/ft
3" centers sta ered 80de
12644 - 13124 3750 - 3757 WS D 480 32 7/27I2007 SLOTS Alternating solidlslotted pipe
2.5"x.125", 4 curcumferential rows/ft
3" centers sta ered 80de
13378 -13895 3761 - 3773 WS D 517 32 7/27/2007 SLOTS Alternating solid/slotted pipe
2.5"x.125", 4 curcumferential rows/ft
3" centers staggered 80deg wltorque
rin s
14152 -14647 3777 - 3784 WS D 495 32 7/27/2007 SLOTS AI[ernating solid/slotted pipe
2.5"x.125", 4 curcumferential rows/ft
3" centers staggered 80deg w/torque
rin s
~ 14905 - 15378 3778 - 3761 WS D 473 32 7/27/2007 SLOTS Alternating solid/slotted pipe
2.5"x.125", 4 curcumferential rowslft
3" centers staggered SOdeg wftorque
rin s
~ 15633 - 16137 3764 - 3772 WS D 504 32 7/27/2007 SLOTS Alternating solid/slotted pipe
2.5"x.125", 4 cureumferential rows/ft
3" centers staggered 80deg w/twque
rin s
16395 - 16912 3776 - 3783 WS D 517 32 7/272007 SLOTS Alternating solid/slotted pipe
2.5"x.125", 4 curcumferential rowslft
I I 3" centers sta ered 80de
17128 - 18024 3785 - 3797 WS D 896 32 7/27/2007 SLOTS Alternating solid/slotted pipe
2.5^x.125", 4 curcumferential rows/ft
~
= 3" centers staggered 80deg w/to~que
rin s
Gas Lift Mandrels/Valves
St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv
Cmnt
1 2074 1702 CAMCO KBMG GLV 1.0 BK•5 0.188 1420 9/1I2007
Other lu s, e ui . etc. - COMPLETION
De th TVD T e Descri tion ID
23 23 HANGER TUBING HANGER 3.900
509 508 NIP CAMCO'DB' NIPPLE w/3.875" PROFILE 3.875
10229 3672 SLEEVE-0 BAKER CMU SLIDING SLEEVE - RUN OPEN 7/31I2007 3.812
10275 3680 LOCATOR SEAL ASSEMBLY LOCATOR 3.880
10276 3680 PBR BAKER 190-07 POLISHED BORE RECEPTACLE 3.880
10297 36&4 ANCHOR
SEAL BAKER 800-47 ANCHOR SEAL ASSEMBLY 3.860
10301 3684 PACKER D-SAND LEM BAKER TORQUEMASTER PACKER 813-07 x 38 9.625" 4.750
10313 3686 HANGER D-SAND LEM ABOVE HOOK HANGER 3.960
10327 3689 HANGER ~D-SAND LEM INSIDE HOOK HANGER 3.688
Other lu s, e ui ., etc. - D=SAND LINER DETAIL
De th TVD T e Descri tion ID
10348 3692 HANGER D-SAND BAKER MODEL B-1 HOOK HANGER OUTSIDE CSG 6.210
10354 3693 XO Bushin 0-SAND MH CROSSOVER BUSHING 7" TO 5.5" 4.860
10451 3705 SEAL D-SAND LEM BAKER SEAL ASSEMBLY 3.880
10515 3712 XO Bushin D-SAND HH CROSSOVER BUSHING 5.5" TO 4.5" 4.000
10516 3712 SLEEVE D-SAND BAKER'HR' LINER SETTING SIEEVE 7.500
10524 3713 XO SUB D-SAND LINER CROSSOVER SUB 7" TO 5.5" 4.950
10571 3718 XO D-SAND LINER CROSSOVER 5.5" TO 4.5" 3.920
General Notes
Date Note
8/1/2007 NOTE: MULTI-LATERAL WELL - 1J-122 A•SAND 1J-122L1 B-SAND 1J-122L2 DSAND
i ~
WELL LOG TRANSMITTAL
To: State of Alaska October 3, 2007
Alaska Oil and Gas Conservation Comm.
Attn.: Librarian
333 West 7~' Avenue, Suite 100
Anchorage, Alaska
RE: MWD Formation Evaluation Logs 1J-122 L2 AK-MW-5034903
1 LDWG formatted CD Rom with verification listing.
API# : 5 0-029-23 3 5 9-61
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL
LETTER TO THE ATTENTION OF:
Sperry Drilling Services
Attn: Rob Kalish
6900 Arctic Blvd.
Anchorage, Alaska 99518
-~.,
~~,.~ ~~~,~~ f~ {,~,
;~ ~ '+a~~ ~ tj f~z "~` ,
Date:~ ~~~
~i v~t~ >~ . ~:•t,s ~ oJ a ~i~.~i~~;
~ j ~i ~= `~~'~~i~~~~
~. ~ro ~°+ a,'~~
;~:.t:~`~a~~~~ ~
Signed: (
~o'~-a7a ~~ sS3`~l
~
~" • +~
~ConocoPh~ll~~as
September 14, 2007
~2E~~~~~~"~
Commissioner
State of Alaska S E P~~;~~~
Alaska Oil & Gas Conservation Commission ",~faska Oil &~~~ ~;,~~~~ r; ;~,,~;,t,,,~~,
333 West 7th Avenue Suite 100 ~~~~}~~~~~
Anchorage, Alaska 99501
Subject: Well Compietion Reports for 1 J-122, 1 J-122L1, 1 J-122L2
Dear Commissioner:
ConocoPhiliips Alaska, Inc. submitsa uk West Sak m'ulti-~lateral'1 J- 22, 1 JS 122L1
recent drilling operations of the Kup
and 1J-122L2.
If you have any questions regarding this matter, please contact me at 265-6830 or
Pat Reilly at 265-6048.
Sincerely,
; ~., ~ --~,.
R. Thomas
Kuparuk Drillin~ Team Leader
CPAI Drilling
°Retlqy rnomas
~ Kuparuk Driiling Team Leader
Drilling & Welis
P. O. Box 100360
Anchorage, AK 99510-0360
Phone: 907-265-6830
RT/skad
~~~~~vEu
~ STATEOFALASKA • ~~~ `~ ~ ZOO7
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPO~`~i~°~~~~,~~c~mm'~S`°~
1a. Well Status: Oil ~/ Gas Plugged ~ Abandoned ~ Suspended
20AAC 25.105 20AAC 25.110
GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No.ofCompletions: 1b. Well Class:
Development ~ '"F Exploratory ^
Service ^ StratigraphicTest^
2. Operator Name:
ConocoPhillips Alaska, Inc. 5. Date Comp., Susp.,
orAband.: July 31, 2007 ` 12. Permit to Drill Number:
207-072 /'
3. Address:
P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded:
July 22, 2007 " 13. API Number:
50-029-23359-61 `
4a. Location of Well (Governmental Section):
SurFace: 1837' FSL, 2347' FEL, Sec. 35, T11N, R10E, UM 7. Date TD Reached:
July 25, 2007 ~ 14. Well Name and Number:
1J-122L2 ~
Top of Productive Horizon:
2177' FNL, 360' FEL, Sec. 36, T11N, R10E, UM 8. KB (ft ebOVe MSL): 28' RKB
Ground (ft MSL): 109' AMSL ' 15. Field/Pool(s):
Kuparuk River Field
Total Depth:
319' FSL, 454' FEL, Sec. 24, T11 N, R10E, UM 9. Plug Back Depth (MD + ND):
18068' MD ! 3797' TVD
West Sak Oil Pool
4b. Location of Well (State Base Plane Coordinates):
Surface: x- 558863 ~ y- 5945649 ` Zone- 4 10. Total Depth (MD + ND):
f 18078' MD / 3797' ND ` 16. Properry Designation:
ALK 25661 & 25650
TPI: x- 566119 y- 5946975 Zone- 4
Total Depth: x- 565956 -- - 5954750 ' Zone- 4 11. SSSV Depth (MD + ND):
nipple @ 509' MD / 508' ND 17. Land Use Permit:
471 & 468
18. Directional Survey: Yes Q No ~
(Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore:
N/A (ft MSL) 20. Thickness of Permafrost (ND):
2196' TVD ~
21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): top of window @ 10332' MD / 3689' ND
GR/RES, USIT
22. CASING, LINER AND CEMENTING RECORD
SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT
CASING SIZE Wf. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD pULLED
20" x 34" 78.6# H-40 28' 106' 28' 106' 42" 335 sx AS 1
13.375" 68# L-80 28' 3640' 28' 2211' 16" 1031 sx AS Lite, 372 sx LiteCRETE
9.625" 40# L-80 28' 11928' 28' 3931' 12.25" 92o sx DeepCRETE
7" x 5.5" x 4.5" 11.6# L-80 10327' 18068' 3689' 3797' 8.5" slotted liner
23. Open to production or injection? Yes No Q If Yes, list each 24. TUBING RECORD
Interval open (MD+ND of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET
tubing in main wellbore 10301'
slotted and blank liner from 10576' MD - 18068' MD
25. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
DEPTH INTERVAL (MD) AMOUNTAND KIND OF MATERIAL USED
na
26. PRODUCTION TEST
Date First Production
waiting on facility hook-up Method of Operation (Ffowing, gas lift, etc.)
multi-lateral, pre-produced injector
Date of Test Hours Tested Production for
Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO
Flow Tubing
press. psi Casing Pressure Calculated
24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr)
27. CORE DATA Conventional Core(s) Acquired? Yes No 0 Sidewall Cores Acquired? Yes ~ No ~ •
If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water
(Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071.
~~i'fPLEiIU,~ ~
CAT~
NONE ~ ~~~~
~ 1/£RiF'~D ~
~ ~
Form 10-407 Revised 2/2007 CONTINUED ON REVERSE SIDE
~ __ ~ _,. ~ L~~~: U~;~` ~ #~ 2~~~
/°'_6~3~~ ~,~%SI Q~6~OJ
r's
~
~
28. GEOLOGIC MARKERS (List all formations and mar rs encountered}: 29. FORMATION TESTS
NAME MD TVD Well tested? ~ Yes ~ No If yes, list intervals and formations tested,
Pe~mefrOSt - TOp g~ound sulfaCe g~ound surfaCe , briefly summarizing test results. Attach separate sheets to this form, if
Permafrost - Bottom 3595' 2196' needed, and submit detailed test information per 2o AAC 25.071.
T3 3595' 2196'
K15 3595' 2196'
Ugnu C 7277' 3052'
Ugnu B 8484' 3313'
Ungu A 8979' 3413'
K13 9477' 3516'
West Sak D 10295' 3684'
West Sak B 18078' 3797'
West Sak A2 18078' 3797'
N/A
Formation at total depth: West Sak D
30. LIST OF ATTACHMENTS
Summary of Daily Operations, Directional Survey, slotted liner
31. I hereby certify that the foregoing is true and ~rcect to the best of my knowledge. ContBCt: Pat Reilly @ 265-6048
Printed Na Rand Thomas Title: Drillinq Team Leader
q
Signature Phone ~ f,~~~ ~ ~ Date ( f ~ `1 ~~7
INSTRUCTIONS
Sharon Allsup-Drake
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.
Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is
changed.
Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposai, 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.
Item 4b: TPI (Top of Producing Interval).
Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in
other spaces on this form and in any attachments.
Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28.
Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing
tool.
Item 23: If this weli is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show
the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately
produced, showing the data pertinent to such interval).
Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other
(explain).
Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed
description and analytical laboratory information required by 20 AAC 25.071.
Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detaited test and
analytical laboratory information required by 20 AAC 25.071.
Form 10-407 Revised 2/2007
• ~
07/21/2007 09:45 10:00 0.25 0 0 COMPZ WELCT SFTY T Held PJSM on changing out annular
element.
10:00 14:15 425 0 0 COMPZ WELC EQRP T ND riser and changed out Hydril
annular element.
14:15 15:30 1.25 0 0 COMPZ WELC7 BOPE T Tested new annular with 4 1/2" and 5"
test jts to 250 psi low and 3,000 psi
hi h, ood test.
15:30 15:45 0.25 0 0 COMPZ DRILL OTHR P Installed wear bushing
15:45 16:00 0.25 0 0 COMPZ RIGMN SVRG P Clean and inspected saver sub and
checked ok.
16:00 16:30 0.50 0 0 PROD3 STK PULD P PU Baker Oil Tools to the rig floor to
set whipstock and mill window f/ the
"D" lateral.
16:30 16:45 0.25 0 0 PROD3 STK OTHR P PJSM on PU/MU Baker whipstock
assembl .
16:45 18:30 1.75 0 143 PROD3 STK PULD P PU/MU Whipstock assembly (BHA #
10).
18:30 19:30 1.00 143 196 PROD3 STK PULD P PU/MU Sperry MWD tools.
19:30 20:00 0.50 196 196 PROD3 STK OTHR P Upload MWD.
20:00 20:30 0.50 196 400 PROD3 STK PULD P PU/MU Baker bumper subs. Make up
a stand of 5" drill pipe, then 1 stand of
5" drill i e.
20:30 21:00 0.50 400 400 PROD3 STK OTHR P Shallow test MWD. Pumping 320 gpm
w/ 350 si.
21:00 00:00 3.00 400 5,038 PROD3 STK TRIP P RIH w/ BHA #10 (whipstock assembly
f/ the "D" lateral .
07/22/2007 00:00 01:45 1.75 5,038 9,601 PROD3 STK TRIP P RIH with whipstock from 5,038' to
9,601'
01:45 02:30 0.75 9,601 9,671 PROD3 STK OTHR P MADD passed K-13 while RtH from
9,601' to 9,671' (9,450' to 9,520' GR
de th
02:30 03:30 1.00 9,671 10,422 PROD3 STK TRIP P RIH from 9,671'to 10,203' and oriented
WS to 18L while RIH, cont. to RIH at
18L and tagged "B" lat TOL at 10,422',
sat down and set WS at 18L, st wt up
180K, dn wt 86K
03:30 07:00 3.50 10,422 10,332 PROD3 STK OTHR P Worked pipe to shear off from
whipstock, worked pipe up to 225K
and dn to blk wt and finally sheared
the bolt, had good down wt and saw
both bumper subs work while
attem tin to shear bolt.
07:00 13:00 6.00 10,332 10,391 PROD3 STK WPST P Milled window in 9 5/8" csg in the "D"
lat sand from 10,332' to 10,348' (16'),
cont to mill to 10,391' MD/ 3,698' TVD.
(59' total with 20' of gauge hole). Milled
at 2-5K WOM, 90-100 rpm's, off btm
torque 9K ft-Ibs, on btm 9-12K, milled
window at 385 gpm at 1,325 psi and
milled OH at 450 qpm at 1.830 psi.
• ~
• ~
i •
• •
• •
07/29/2007 05:30 06:00 0.50 0 0 COMPZ CASIN( RURD P RU to run Hook Hanger assembly.
06:00 06:15 0.25 0 0 COMPZ CASIN< SFTY P Held PJSM with crew and Baker reps
on MU Hook Hanger assembly and
associated hazards.
06:15 08:30 225 0 273 COMPZ CASINC PUTB P MU "D" lateral Hook Hanger assembly
with ECP packer and slim hole MWD
RIH to 273' and shallow tested same.
08:30 13:00 4.50 273 10,300 COMPZ CASIN Rt1NL P RIH from 273' to 10,300'
13:00 15:00 2.00 10,300 10,557 COMPZ CASIN( RUNL P Est. circ at 125 gpm, 750 psi, st wt up
163K, dn wt 63K, oriented bent jt to
high side and RIH thru window,
re-oriented to hook and hooked same
at BOW, unhooked and RIH tagging
XO at 10,570' on depth, PU and
rehooked hanger several times to
confirm BOW at 10,348', set hook with
20k wt down and final orientaion
showed to be 54R.
15:00 17:30 2.50 10,557 10,327 COMPZ CASIN RUNL P Dropped 29l32" ball and pumped down
to seat, with ball on seat pressured up
to 3,500 psi to inflate packer, did not
see any indication of inflating pkr, bled
off press. and pressured back up to
3,700 psi to blow the ball seat and
prior to blowing the ball seat saw
slight indication of packer possibiy
inflating. PU to release from hook,
worked st wt up to 30K over several
times to get cups to pull thru ECP
then came free, slacked back off on
hook and hook was still on de th.
17:30 17:45 0.25 10,327 10,327 COMPZ CASINC CIRC P Monitored well-staic
17:45 22:00 4:25 10,327 50 COMPZ CASIN( RUNL P POOH with running tool from 10,327'
to 50', calc fill on trip out 85 bbis,
actual fill 100 bbls.
22:00 00:00 2.00 50 0 COMPZ CASIN( PUTB P POOH LD running tool and MWD,
cleared rig floor and brought LEM tools
to ri floor.
07/30/2007 00:00 00:15 0.25 0 0 COMPZ CASINC SFTY P Held PJSM with rig crew, Sperry and
Baker rep on MU LEM with
Torquemaster packer and slim hole
MWD.
00:15 01:45 1.50 0 171 COMPZ CASINC PUTB P MU "D" lat. LEM assembiy with Baker
Torquemaster packer and siim hole
MWD R1H to 171' and shallow tested
MWD.
01:45 05:45 4.00 171 10,290 ~ COMPZ CASIN( RUNL P RIH with LEM from 171' to 10,290'
~ ~
• .
Daily Operations Summary Report
---- 1J-122
I
Job: DRILLING ORIGINAL
°'"' BYarti€Ta :.. `~~ . .
'S „ . , . . ~ w: ~ RaY
; F.,. ..~'.. ~:. •
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., ~- ~. .c': ;.~ ~ ~aSt 24hk :St~ r , ~
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, "r<.,. ~\ . -- __„ _ . . ~:~a~ F N t :: . . . ........ .R`.. . , ...`.S? , . ?~:..3a ..
6/16/2007 6/17/2007 Moved rig from 1J-120 to 1J-122 - Set up compiexes & hooked up service lines - NU Riser- Load pipe shed witM
5" DP - Received water to build spud mud.
"` RIG ACCEPTED AT 22:30 "`
61,17f2(
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~~''~
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r ~. ~~~~~~~ s..
~ ' ~`(f~faod ba+c~~' ~'F?'~ . ,~"., ~ NM~ `~s~~»'Furtct~~n fest tliuerte ;f~ILI 'i6'~~Sif a
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Drilled 16" Surface hole with mud motor from 218' to 1606' ~MD.
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Drilled 16" hole from 3,467' to 4,086' (csg pt) monitored well & had slight flow, circ hole raisinq MW to 9.5 ppg,~
well static, BROOH 10 stds, RIH, CBU then spotted lube pill on btm, POOH 10 stds & cont BROOH to 2,706'
~Z~1Z~ : ~ ~~
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: 6 ~ ~ e ~ .:
~~ •' 4 , ;~ar~ ~[~~ ~~ B ~ ~ ;, U ~b`~'e,~ap ~o ~un ~3 ~!$,' cs9 ~il{ 4{ f~iCe ~ ~~ooE ca~r cfrt~ng~t,;.,
^ .. ., :. }'y{~ ~
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6/23/2007 ~ ~, ~z ..., .u:.i
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Attempted to work csg deeper wMo success, stuck csg off btm at 3,640', circ & cond mud f/cmtg, cmtd csg with
291 bbls of good cmt baek to surF., PU & landed csg on slips, cut off csg & ND diverter, made final cut on csg and
prep. to weld on wellhead adapter.
6~~3~~29Q,7~" `~
~ ~~~ ~
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~`~ ~ ' ' UV~(ded=Qi~ welltiead ~"~ `'te ~~luwin'°,. ea '~a ~F G~rams ~[J ~st~iad ~i~dc QP sli~ ~~ ~tvdrE'~f
p~~r~ w~t~, 9 h ,~~.~ : ~..~ ~ ~.. ~ .. . P~~~ , ~
4 C'
it
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Fin RIH to Flt Collar, CBU, tested csg to 3,000 psi for 30 min, good test, drilled out shoe track & 20' of new hole to
3,660', RU & attempted to perform FIT to ,12.0 ppg & Leaked off @ 11.5 ppg, W.O. Orders, Drilled a total of 75' of
new hole w/attempting to sidetrack well, CBU, Performed FIT to 11:0 ppg EMW, cont. to sidetrack well & driUed
from 3,735' to 4,086' (16" hole TD) Drilled from 4,086' to 4,84T
~12~12QQ7 ~ ~ ' ~t25f~
4~ ~~~ ~ ,~~~ ~7 211 jf
~` ~~ ~``~'
Dlrect~on'a~l~t dr~~~~ 1~~#/~ an~~:rmed~af~hole"~~i
rr~ 4 ~7'~
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;6/26/2007 4 ~
.
6/27/2007 ;
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Directionally5drilled 12 1/4" intermediate hole from 7,211' to 9,713'
7/1 /2007
17/2/2007
17/6/2i
7
Cont to RIH f/3;544' & taggeci up @ 3,968', surveyed 8~ showed to be in 12 1/4" hole, washed down to 4,023' then
cont. to RIH to 9,537', washed dn to btm & CBU, drilled from 9,721' to 10,97~', worked pipe while repairing #2
mud pump's mud cross, cont. drilling to 11,2Y5' '
Ctr~lec~ ~~ ~'W ~~~~f€nm 1~ 215' ta`'~~~~~~' ~"{? ~t~ ~18~ csg pt} B ~}}~-i #c~ slt~e' ~ cz~~k~o~~c ~an PC~C3~tcr
~~
F ~.
~~~~~~°M,~~oaded same ~~~~ ~. ~~.~~~..... . ~. ~ ~ ,~ ~ ,~~ ~
~~ ~_-. ~,, , ~ ~,a• ,- _ ~z ~ ,~~
.~„ . 3 s<
Fin LD BHA #3, slip & cut drlg li'ne, pulied wear bushing, R1J & RIM wit~h 9 5/8" csg to 13 3/8" sMoe, CBU &
spotted lube pill, cont to RIH with 9 5/8" csg to 8,941'
Fin POOH & Installing supersliders on 40 stds of 5" DP, tested 9 5/8" csg to 3,000 psi for 30 min. INIU 8 1/2"
Geopilot BHA #4 & singled in hole 180 jts 5" DP, then RIH f/derrick to 11,634', slip & cut drlg line, RIW & tagged
up at 11,842' (FC @ 11,848') drilled out flt coilar and drig shoe track @ 11,9Y7' (F~ @ 11,928'J
Continue to TIH to 11, 830' MD - Displace to OBM - Pump Hi-Vis Sweep - POOH - RIH with 5-1/2" Liner to
94,616' MD - Pump Ball to seat.
7/11/2007 Mill out window from 10,833' to 10,889' MD - POOH - LD BHA - Pull Wear
~-~- PU BHA #7 - RIH to 8,878' MD.
~ ~
I Page 1/2 Report Printed: 9/13/2007,
i
Daily Operations Summary Report
1 J-122
8!1/2007 ~872/2007 ~LD all DP fr~om Derrick - Slip & Cut DL - Clean & Clear Rig, SPCG - Prep Rig & Move to 1J=1D7
I
Page 2/2 Report Printed: 9/13/20Q7!
. ~
Halliburton Company .
Survey Report
I Company: ConocoPhillips Alaska Inc . Date: 8J16/2007 Time: 09:25:39 Page: 1 - I
~ Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1J-122, True North
'`
~ Site: Kuparuk 1 J Pad Vertical (TVD) Reference: D141 (28 + 81) 109A
I Wep: 1J-122 Section (VS) ReFerence: Well (O.OON,O.OOE,O.OOAzi)
Wellpath: 1J-122L2 Survey Caiculation Method: Minimum Curvature ~ Db: Oracle
~ Field: Kuparuk River Unit
~ North Slope Alaska
United States
I Map System:US State Plane Coordinate System 1927 Map 2one: Alaska, Zone 4
Geo Datum: NAD27 (Clarke 1866) Coordinate Sy stem: Well Centre
Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007
Well: 1 J-122 Slot Name:
Well Position: +N/-S -270.75 ft Northing: 594564 9.48 ft` Latitade: 70 15 43.595 N
+E/-W 71.32 ft Easting : 55886 3.37 ft' Longitude: 149 31 26.931 W
Position Uncertainty: 0.00 ft
Welipath: 1 J-122L2 Drilled From: 1 J-122
API 50-029-23359-61 Tie-on Depth: 10263.66 ft
Current Datum: D141 (28 + 81) Height 10 9.00 ft~ Above System Datum: Mean Sea Level
Magnetic Data: 6/16/2007 Declination: 23.31 deg
Field Strength: 57613 nT Mag Dip Angle: 80.79 deg
Vertical Section: Depth From (TVD) +N/-S +E/-W Direction
ft ft ft deg
28.00 0.00 0.00 0.00
Survey Program for Definitive Wellpath
Date: 8/14/2007 Validated: Yes Version: 6
Actual From To Survey Toolcode Tool Name
ft ft
50.00 727.00 1J-122 PB 1 Gyros (50.00-727.00 CB-GYRO-SS Camera based gyro sin gle shot
826.02 3615.17 1J-122 P6 1 IIFR+MS+Sag (826.02 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C
3643.00 10263.66 1J-122 IIFR+MS+Sag (3643.00-15 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C
10332.00 18020.47 1J-122 L2 IIFR+MS+Sag (10332.0 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C
Survey
I MD Incl Azim TVD Sys TVD N/S E/W MapiV MapE Tool
ft deg deg ft ft ft ft ft ft
28.00 0.00 0.00 28.00 -81.00 0.00 0.00 5945649.48 558863.37 TIE LINE
50.00 0.23 262.51 50.00 -59.00 -0.01 -0.04 5945649.47 558863.33 CB-GYRO-SS
100.00 0.23 207.19 100.00 -9.00 -0.11 -0.19 5945649.37 558863_18 CB-GYRO-SS
168.00 0.10 64.84 168.00 59.00 -0.20 -0.20 5945649.27 558863.17 CB-GYRO-SS
263.00 0.20 43.45 263.00 154.00 -0.05 -0.01 5945649.43 558863_36 CB-GYRO-SS
352.00 2.00 104.21 351.98 242.98 -0.32 1.60 5945649.18 558864.98 CB-GYRO-SS
445.00 5.77 102.92 444.75 335.75 -1.76 7.74 5945647.78 558871.92 CB-GYRO-SS
476.00 6.94 104.70 475.56 366.56 -2.59 11.07 5945646.98 558874.46 CB-GYRO-SS
536.00 8.40 109.85 535.02 426.02 -4.99 18.70 5945644.63 558882.10 CB-GYRO-SS
631.00 12.22 111.49 628.47 519.47 -11.03 34.58 5945638.72 558898_03 CB-GYRO-SS
727.00 16.18 110.43 721.52 612.52 -19.43 56.58 5945630.50 558920A9 CB-GYRO-SS
826.02 19.43 110.75 815.78 706.78 -30.08 84.92 5945620.06 558948.51 MWD+IFR-AK-CAZ-SC
897.82 21.80 107.95 882.98 773.98 -38.42 108.77 5945611.91 558972.43 MWD+IFR-AK-CAZ-SC
957.57 24.53 106.48 937.91 828.91 -45.36 131.22 5945605.15 558994.93 MWD+IFR-AK-CAZ-SC
1053.34 29.27 105.77 1023.29 914.29 -57.37 172.84 5945593.47 559036.64 MWD+IFR-AK-CAZ-SC
1148.67 32.87 106.08 1104.93 995.93 -70.88 220.14 5945580.33 559084_04 MWD+IFR-AK-CAZ-SC
1244.03 37.37 106.69 1182.91 1073.91 -86.36 272.76 5945565.26 559136.77 MWD+IFR-AK-GAZ-SC
1337.57 39.44 104.20 1256.22 1147.22 -101.81 328.76 5945550.26 559192.89 MWD+IFR-AK-CAZ-SC
1432.05 44.32 102.32 1326.54 1217.54 -116.22 390.14 5945536.32 559254.37 MWD+IFR-AK-CAZ-SC
1525.77 47.35 102.29
I
1391.83
1282.83
-130.55 455.82
5945522.51 559320.15 I
MWD+IFR-AK-CAZ-SC
~ 1619.34 48.76 100.81 1454.38 1345.38 -144.47 524.00 5945509.12 559388.43 MWD+IFR-AK-CAZ-SC
1714.14 49.71 100.26 1516.28 1407.28 -157.59 594.59 5945496.55 559459.12 MWD+IFR-AK-CAZ-SC
1809.00 55.41 100.64 1573.92 1464.92 -171.26 668.63 5945483.47 559533.25 MWD+IFR-AK-C,4Z-SC
1904.38 58.52 99.98 1625.91 1516.91 -185.56 747.29 5945469.78 559612.01 MWD+IFR-AK-CAZ-SC
1998.16 64.25 99.90 1670.81 1561.81 -199.76 828.34 5945456.22 559693.17 MWD+IFR-AK-CAZ-SC
2092.66 67.25 101.49 1709.62 1600.62 -215.76 912.99 5945440.88 559777.93 MWD+IFR-AK-CAZ-SC
2187.56 70.00 101.39 1744.20 1635.20 -233.29 999.60 5945424.03 559864.67 MWD+IFR-AK-CAZ-SC
~
.
Halliburton Company
Survey Report
•
Company: ConocoPhillips Alaska Inc. Date: 8/16l20Q7 Time: 09:25:39 Page: 2
Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1J-12 2, True North
Site: Kuparuk 1J Pad Vertical (TVD) Reference: D141 (28 + 81) 109A
~,ep; 1J _122 Sectio n(VS)Reference: Wep(O.OON,O.O OE,O.OOAzi)
Wellpath: 1 J -122L2 Survey Calculation Method: Minimum Curvat~re Db: Oracle
Survey
MD Inci Azim TVD Sys TVD N/S E/W MapN MapE Tool
ft deg deg ft ft ft ft ft ft
I 2282.44 71.24 100. 27 1775 .69 1666 .69 -250. 10 1087.51 5945407. 91 559952 .69 MWD+IFR-AK-CAZ-SC
~ 2377.66 72.77 100. 85 1805 .10 1696 .10 -266. 70 1176.53 5945392. 01 560041 .84 MWD+IFR-AK-CAZ-SC
j 2475.50 72.64 101. 61 1834 .19 1725 .19 -284. 89 1268.16 5945374. 53 560133 .59 MWD+IFR-AK-CAZ-SC
~
2571.86
70.40
100.
87
1864
.73
1755
.73
-302.
71
1357.79
5945357.
42
560223
.35
MWD+IFR-AK-CAZ-SC
2665.79 70.32 99. 86 1896 .30 1787 .30 -318. 63 1444.81 5945342. 19 560310 .49 MWD+IFR-AK-CAZ-SC
2760.94 71.66 100. 55 1927 .30 1818 .30 -334. 57 1533.34 5945326. 94 560399 .14 MWD+IFR-AK-CAZ-SC
2856.71 71.49 100. 03 1957 .56 1848 .56 -350. 80 1622.74 5945311. 41 560488 .65 MWD+IFR-AK-CAZ-SC
2952.84 71.26 98. 74 1988. 27 1879 .27 -365. 65 1712.62 5945297. 26 5&0578 .63 MWD+IFR-AK-CAZ-SC
3048.06 71.85 98. 09 2018 .39 1909 .39 -378. 87 1801.97 5945284. 74 560668 .07 MWD+IFR-AK-CAZ-SC
3141.34 71.49 98. 07 2047 .73 1938 .73 -391. 32 1889.64 5945272. 98 560755 .83 MWD+IFR-AK-CAZ-SC
3236.18 70.84 98. 20 2078 .35 1969 .35 -404. 02 1978.50 5945260: 98 560844 .77 MWD+IFR-AK-CAZ-SC
3331.73 73.51 98. 65 2107 .59 1998 .59 -417. 35 2068.47 5945248. 35 560934 .84 MWD+IFR-AK-CAZ-SC
3425.95 72.56 98. 11 2135 .09 2026 .09 -430. 48 2157.63 5945235. 92 561024 .09 MWD+IFR-AK-CAZ-SC
3518.01 67.02 98. 46 2166 .88 2057 .88 -442. 92 2243.08 5945224. 15 561109 .63 MWD+IFR-AK-CAZ-SC
3615.17 69.19 100. 33 2203 .11 2094 .11 -457. 65 2332.01 5945210. 12 561198 .67 MWD+IFR-AK-CAZ-SC
3643.00 69.41 100. 69 2212 .95 2103 .95 -462. 40 2357.61 5945205. 57 561224 .30 MWD+IFR-AK-CAZ-SC
3711.25 70.62 97. 13 2236. 28 2127 .28 -472. 32 2420.96 5945196. 14 561287. 72 MWD+IFR-AK-CAZ-SC
3806.75 71.61 99. 08 2267 .19 2158 .19 -485. 06 2510.41 5945184. 10 561377. 26 MWD+IFR-AK-CAZ-SC
3900.55 72.85 98. 63 2295. 82 2186 .82 -498. 81 2598.67 5945171. 04 561465. 61 MWD+IFR-AK-CAZ-SC
3995.33 73.42 100. 00 2323. 32 2214 .32 -513. 49 2688.18 5945157. 06 561555. 22 MWD+IFR-AK-CAZ-SC
4089.15 75.47 100. 58 2348 .48 2239 .48 -529. 64 2777.10 5945141. 61 561644. 26 MWD+IFR-AK-CAZ-SC
4186.11 75.66 100. 44 2372 .65 2263 .65 -546. 77 2869.42 5945125. 21 561736. 71 MWD+IFR-AK-CAZ-SC
4281.20 74.77 100. 77 2396 .91 2287 .91 -563. 69 2959.80 5945109. 00 561827. 20 MWD+IFR-AK-CAZ-SC
4376.04 77.20 100. 45 2419 .88 2310 .88 -580. 63 3050.23 5945092. 77 561917 .75 MWD+IFR-AK-CAZ-SC
4470.83 75.54 98. 97 2442 .22 2333 .22 -596. 17 3141.03 5945077. 94 562008 .66 MWD+IFR-AK-CAZ-SC
4565.83 76.29 99. 56 2465. 34 2356 .34 -611. 00 3231.97 5945063. 82 562099. 70 MWD+IFR-AK-CAZ-SC
4662.92 77.76 99. 94 2487. 13 2378 .13 -627. 03 3325.21 5945048. 52 562193. 06 MWD+IFR-AK-CAZ-SC
4755.99 78.07 99. 33 2506 .62 2397 .62 -642. 26 3414.93 5945034. 00 562282. 89 MWD+IFR-AK-CAZ-SC
4850.72 78.01 99. 19 2526 .25 2417 .25 -657. 17 3506.40 5945019. 80 562374. 46 MWD+IFR-AK-CAZ-SC
4945.03 76.49 99. 07 2547 .06 2438 .06 -671. 77 3597.21 ~945005. 92 562465. 38 MWD+IFR-AK-CAZ-SC
5039.28 77.69 99. 78 2568 .12 2459 .12 -686. 81 3687.84 ~944991. 58 562556. 11 MWD+IFR-AK-CAZ-SC
5133.03 77.50 100. 50 2588 .26 2479 26 -702. 93 3777.97 5944976. 17 562646. 36 MWD+IFR-AK-CAZ-SC
5228.34 77.31 100. 14 2609 .04 2500 .04 -719. 59 3869.48 ~944960. 22 562737. 99 MWD+IFR-AK-CAZ-SC
5323.79 77.12 100. 17 2630 .17 2521 .17 -736. 01 3961.11 ~944944. 53 562829. 73 MWD+IFR-AK-CAZ-SC
5419.10 77.76 100. 67 2650. 89 2541 .89 -752. 83 4052.6~ b944928. 42 562921 .34 MWD+IFR-AK-CAZ-SC
5513.28 79.33 100. 60 2669. 60 2560 .60 -769. 87 4143.32 5944912. 10 563012. 18 MWD+IFR-AK-CAZ-SC
5608.22 78.07 100. 00 2688 .20 2579 .20 -786. 51 4234.91 5944896. 17 563103. 89 MWD+IFR-AK-CAZ-SC
5702.95 " 78.26 100. 39 2707 .63 2598 .63 -802. 92 4326.16 ~944880. 47 563195. 26 MWD+IFR-AK-CAZ-SC
5798.24 79.07 100. 44 2726 .36 2617 .36 -819. 81 4418.06 5944864. 30 563287. 27 MWD+IFR-AK-CAZ-SC
5894.04 77.56 99. 92 2745 .76 2636 J6 -836. 40 4510.39 ~944848. 45 563379. 73 MWD+IFR-AK-CAZ-SC
5988.48 77.94 99. 90 2765 .80 2656 .80 -852. 28 4601.30 5944833. 28 563470. 75 MWD+IFR-AK-CAZ-SC
6083.44 76.86 99. 56 2786 .51 2677 .51 -867. 94 4692.64 5944818. 33 563562. 20 MWD+IFR-AK-CAZ-SC
6178.39 77.37 99. 58 2807 .68 2698 .68 -883. 33 4783.91 5944803. 66 563653. 58 MWD+IFR-AK-CAZ-SC
6273.69 76.93 98. 90 2828 .88 2719 .88 -898. 25 4875.62 5944789. 46 563745. 39 MWD+IFR-AK-CAZ-SC
6369.18 76.74 99. 57 2850 .63 2741 .63 -913. 17 4967.39 5944775. 25 563837. 27 MWD+IFR-AK-CAZ-SC
6466.04 75.60 99. 00 2873 .78 2764 .78 -928. 35 5060.21 3944760. 80 563930. 20 MWD+IFR-AK-CAZ-SC
6561.04 76.42 99. 45 2896 .75 2787 .75 -943. 12 5151.20 5944746. 74 564021. 29 MWD+IFR-AK-CAZ-SC
6655.80 76.80 98. 13 2918 .69 2809 .69 -957. 21 5242.30 5944733. 37 564112. 49 MWD+IFR-AK-CAZ-SC
6749.05 76.67 96. 13 2940 .09 2831 .09 -968. 48 5332.35 5944722. 81 564202. 62 MWD+IFR-AK-CAZ-SC
6844.64 77.25 94. 88 2961 .66 2852 .66 -977. 41 5425.05 5944714. 60 564295 .37 MWD+IFR-AK-CAZ-SC
6940.21 78.13 92. 82 2982 .04 2873 .04 -983. 67 5518.20 5944709. 06 564388 .56 MWD+IFR-AK-CAZ-SC
7034.44 78.07 89. 87 3001 .47 2892 .47 -985. 84 5610.37 5944707. 62 564480 .74 MWD+IFR-AK-CAZ-SC
7130.45 78.32 86. 51 3021 .12 2912 .12 -982. 87 5704.29 b944711. 32 564574 .62 MWD+IFR-AK-CAZ-SC
.
Halliburton Company
Survey Report
.
Company: ConocoPhillips Alaska Inc.
Field: Kuparuk River Unit Date: 8/16/2007 Time: 09:25:39 Page: 3
Co-ordinate(NE) Reference: Well: 1J-122, True North
Site: Ku paruk 1J Pad Vertical (TVD) Reference: D141 (28 + 81') 109.0
Well: 1J -122 Section (VS) Reference: Well (O.OON,O.OOE,O.OOAzi)
Wellpath: iJ -122 L2 Survey Calculation Method: Minimum Curvature Db: Oracfe
Survey
i MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool
ft d eg deg ft ft ft ft ft ft
7223.85 77 .94 83.36 3040 .34 2931.34 -974 :80 5795.32 5944720.10 564665.58 MWD+IFR-AK-CAZ-SC
7321.06 77 .50 79.87 3061 .02 2952.02 -960 .96 5889.28 5944734.68 564759.41 MWD+IFR-AK-CAZ-SC
7416.$9 77 .93 76.88 3081 .41 2972.41 -942 .09 5980.98 5944754:26 564850.96 MWD+IFR-AK-CAZ-SC
7509.94 77 .87 73.24 3100 .92 2991.92 -918 .64 6068.87 5944778.40 564938.65 MWD+IFR-AK-CAZ-SG
7606.20 77 .55 69.61 3121 .42 3012.42 -888 .68 6158.01 5944809.04 565027.55 MWD+IFR-AK-CAZ-SC
7701.51 77 .50 66.04 3142 .01 3033.01 -853 .57 6244.17 5944844.83 565113.42 MWD+IFR-AK-CAZ-SC
7797.32 77 .25 63.06 3162 .96 3053.96 -813 .40 6328.58 5944885.66 565197.51 MWD+IFR-AK-CAZ-SC
7890.97 77 .43 59.93 3183 .49 3074.49 -769 .79 6408.87 5944929.88 565277.44 MWD+IFR-AK-CAZ-SG
7989.13 77 .82 56.45 3204 .53 3095.53 -719 .26 6490.33 5944981.04 565358.50 MWD+IFR-AK-CAZ-SC
8082.76 77 .12 53.16 3224 .85 3115.85 -666 .59 6565.01 5945034.29 565432.76 MWD+IFR-AK-CAZ-SC
8177.99 77 .25 50.55 3245 .98 3136.98 -609 .25 6638.03 5945092.20 565505.33 MWD+IFR-AK-CAZ-SC
8273.83 77 .24 47.56 3267 .14 3158.14 -548 .00 6708.63 5945153.99 565575.43 MWD+IFR-AK-CAZ-SC
8368.99 77 .43 44.89 3288 .01 3179.01 -483 .77 6775.66 5945218.73 565641.96 MWD+IFR-AK-CAZ-SC
8464.35 77 .75 41.57 3308 .51 3199.51 -415 .92 6839.44 5945287.07 565705.20 MWD+IFR-AK-CAZ-SC
8560.45 78 .45 37.68 3328 .33 3219.33 -343 .51 6899.40 5945359.95 565764.58 MWD+IFR-AK-CAZ-SG
8652.81 77 .75 35.21 3347 .38 3238.38 -270 .81 6953.08 5945433.05 565817.69 MWD+IFR-AK-CAZ-SC
8747.98 77 .87 32.75 3367. 48 3258.48 -193 .68 7005.07 5945510.58 565869.06 MWD+IFR-AK-CAZ-SC
8843.49 79 .27 30.23 3386. 41 3277.41 -113 .86 7053.96 5945590.77 565917.32 MWD+IFR-AK-CAZ-SC
8939.65 78 .38 26.23 3405. 05 3296.05 -30 .76 7098.57 5945674.21 565961.29 MWD+IFR-AK-CAZ-SC
9033.80 77 .49 23.05 3424, 73 3315.73 52 .91 7136.96 5945758.17 565999.01 MWD+IFR-AK-CAZ-SC
9129.64 78 .20 19.80 3444. 92 3335.92 140 .11 7171.17 5945845.63 566032.54 MWD+IFR-AK-CAZ-SC
9224.85 78 .38 17.20 3464. 25 3355.25 228 .52 7200.75 5945934.25 566061.42 MWD+IFR-AK-CAZ-SC
9318.79 78 .14 13.57 3483. 37 3374.37 317 .18 7225.15 5946023.10 566085.13 MWD+IFR-AK-CAZ-SC
9413.'!5 78. 09 9.58 3502. 87 3393.87 407 .61 7243.67 5946113.65 566102.94 MWD+IFR-AK-CAZ-SC
9509.96 78. 38 6.02 3522. 68 3413.68 501 .47 7256.53 5946207.61 566115.06 MWD+IFR-AK-CAZ-SC
9605.12 77. 37 2.87 3542. 68 3433.68 594 .22 7263.74 5946300.40 566121.55 MWD+IFR-AK-CAZ-SC
9693.66 77. 62 2.17 3561. 85 3452.85 680 .57 7267.54 5946386.77 566124.67 MWD+IFR-AK-CAZ-SC
9788.92 78 .01 0.53 3581. 95 3472.95 773 .66 7269.73 5946479.86 566126.14 MWD+IFR-AK-CAZ-SC
9884.64 77 .68 359.63 3602. 11 3493.11 867 .23 7269.87 5946573.43 566125.54 MWD+IFR-AK-CAZ-SC
9980.13 77 .75 359.26 3622. 43 3513.43 960 .53 7268.96 5946666.71 566123.90 WIWD+IFR-AK-CAZ-SC
10074.62 78. 13 0.05 3642. 17 3533.17 1052 .93 7268.41 5946759.09 566122.63 MWD+iFR-AK-CAZ-SC
10169.85 78. 76 359.38 3661. 25 3552.25 1146 .23 7267.94 5946852.37 566121.43 MWD+IFR-AK-CAZ-SC
10263.66 80. 15 358.75 3678. 41 3569.41 1238 .44 7266.44 5946944:56 566119.21 MWD+IFR-AK-CAZ-SC
10332.00 81. 25 359.07 3689. 46 3580.46 1305 .87 7265.15 5947011.97 566117.40 MWD+IFR-AK-CAZ-SC
10355.07 81. 92 359.26 3692. 83 3583.83 1328 .69 7264.82 594703478 566116.88 MWD+IFR-AK-CAZ-SC
10451.47 83. 59 0.04 3704. 99 3595.99 1424 .31 7264.24 5947130.39 566115.55 MWD+IFR-AK-CAZ-SC
10545.35 83. 59 0.80 3715. 47 3606.47 1517 .60 7264.92 5947223.68 566115.51 MWD+IFR-AK-CAZ-SC
10641.55 86. 51 1.58 3723. 77 3614.77 1613 .41 7266.91 5947313.49 566116.75 MWD+IFR-AK-CAZ-SG
10735.81 89. 72 3.09 3726. 87 3617.87 1707 .53 7270.75 5947413.62 566119.85 MWD+IFR-AK-CAZ-SC
10829.94 90. 76 1.41 3726. 48 3617.48 1801 .58 7274.45 5947507.69 566122.81 MWD+IFR-AK-CAZ-SC
10925.48 89. 58 1.07 3726. 19 3617.19 1897 .09 7276.51 5947603.21 566124.13 MWD+IFR-AK-CAZ-SC
11019.43 88. 10 359.96 3728. 10 3619.10 1991 .02 7277.36 5947697.13 566124.24 MWD+IFR-AK-CAZ-SC
11115.03 88. 54 0.49 3730. 90 3621.90 2086 .57 7277.73 5947792.68 566123.87 MWD+IFR-AK-CAZ-SC
11211.52 88. 53 0.99 3733. 37 3624.37 2183 .02 7278.98 5947889.12 566124.36 MWD+IFR-AK-CAZ-SC
11304.82 89. 65 1.78 3734. 85 3625.85 2276 .28 7281.23 5947982.39 566125.89 MWD+IFR-AK-CAZ-SC
11400.59 90. 27 2.22 3734. 91 3625_91 2371 .99 7284.58 5948078.11 566128.48 MWD+IFR-AK-CAZ-SC
11496.65 90. 21 359.05 3734. 51 3625.51 2468 .03 7285.64 5948174.15 566128.80 MWD+IFR-AK-CAZ-SC
11592.54 88. 66 0.77 3735. 46 3626.46 2563 .91 7285.49 5948270.02 566127.90 MWD+IFR-AK-CAZ-SC
11688.12 ' 88. 66 0.90 3737. 69 3628.69 2659 .46 7286.88 5948365.56 566128.54 MWD+IFR-AK-CAZ-SC
11781.38 89. 40 1.53 3739. 27 3630.27 2752 .68 7288.86 5948458.79 566129.79 MWD+IFR-AK-CAZ-SC
11876.72 89. 21 2.01 3740. 43 3631.43 2847 .97 7291.81 5948554.09 566131.99 MWD+IFR-AK-CAZ-SC
11972.65 89. 09 2.42 3741. 85 3632.85 2943 .82 7295.51 5948649.95 566134.95 MWD+IFR-AK-CAZ-SC
~
Halliburton Company
Survey Report
•
Company: ConocoPhillips Alaska Inc. Date: 8/1 612 0 0 7 Time: 09:25:39 Page: 4
Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1J-122, T rue North
Site: Kuparuk 1J Pad Vertical (TVD) Reference: D141 (28 + 81) 109.0
Well: 1J -122 Section (VS) Reference: Well (O.OON,O.OOE,O.OOAzi)
Wetlpath: 1 J-122L2 Survey Calculation Method: Minimum Curvature Db: Oracle
Survey
i MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Toot
ft deg deg ft ft ft ft R ft
I 12067.95 89.21 2.27 3743. 26 3634.26 3039.03 7299.41 5948745:18 566138.10 MWD+IFR-AK-CAZ-SC
12161.62 89.46 1.79 3744. 35 3635.35 3132.63 7302.73 5948$38.80 566140.69 MWD+IFR-AK-CAZ-SC
i
12255.43 89.71 0.66 3745. 03 3636.03 3226.42 7304.73 5948932.58 566141.96 MWD+IFR-AK-CAZ-SC
I
i 12351.98
89.40
358.76
3745.
78
3636.78
3322.96
7304.25
5949029.11
566140.72
MWD+IFR-AK-CAZ-SC
! 12447.75 89.15 358.32 3746. 99 3637.99 3418.69 7301.81 5949124:81 566137.53 MWD+IFR-AK-CAZ-SC
~ 12543.64 89.34 358.45 3748. 26 3639.26 3514.53 7299.10 5949220.62 566134.08 MWD+IFR-AK-CAZ-SC
12638.84 89.09 359.28 3749. 56 3640.56 3609.70 7297.22 5949315.76 566131.45 MWD+IFR-AK-CAZ-SC
12731.32 89.34 358.19 3750. 83 3641.83 3702.15 7295.18 5949408.18 566128.68 MWD+IFR-AK-CAZ-SC
12826.42 89.15 358.02 3752. 08 3643.08 3797.19 7292.03 5949503.19 566124.80 MWD+IFR-AK-CAZ-SC
12923.24 89.03 358.00 3753. 62 3644.62 3893.94 7288.67 5949599.90 566120.68 MWD+IFR-AK-CAZ-SC
13017.70 89.15 358.64 3755. 12 3646.12 3988.35 7285.90 5949694.27 566117.17 MWD+IFR-AK-CAZ-SC
13113.66 89.09 359.14 3756. 59 3647.59 4084.28 7284.04 5949790.18 566114.57 MWD+IFR-AK-CAZ-SC
I
I 13209.21 89.03 358.86 3758. 16 3649.16 4179.80 7282.38 5949885.67 566112.15 MWD+IFR-AK-CAZ-SC
13304.01 89.52 359.53 3759. 36 3650.36 4274.58 7281.04 5949980.43 566110.08 MWD+IFR-AK-CAZ-SC
13395.47 88.59 358.80 3760. 87 3651.87 4366.02 7279.71 5950071.85 566108.03 MWD+IFR-AK-CAZ-SC
13488.11 88.29 359.04 3763. 39 3654.39 4458.61 7277.97 5950164.41 566105.56 MWD+IFR-AK-CAZ-SC
I 13581.01 88.78 359.13 3765 J6 3656.76 4551.46 7276.48 5950257.24 566103.35 MWD+IFR-AK-CAZ-SC
~ 13674.54 88.53 359.17 3767. 96 3658.96 4644.96 7275.10 5950350.72 566101.24 MWD+IFR-AK-CAZ-SC
13766.61 88.29 359.21 3770. 51 3661.51 4736.98 7273.79 5950442.72 566099.22 MWD+IFR-AK-CAZ-SC
13858.25 88.97 358.88 3772. 71 3663.71 4828.58 7272.27 5950534.30 566096.97 MWD+IFR-AK-CAZ-SC
13953.91 89.28 358.70 3774. 17 3665.17 4924.21 7270.25 5950629.90 566094.21 MWD+IFR-AK-CAZ-SC
14044.46 89.15 358.60 3775. 41 3666.41 5014.73 7268.11 5950720.38 566091.37 MWD+IFR-AK-CAZ-SC
14137.47 89.15 357.71 3776. 79 3667.79 5107.68 7265.12 5950813.30 566087.65 MWD+IFR-AK-CAZ-SC
i
;
14229.59
89.03
357.72
3778.
25
3669.25
5199.71
7261.45
5950905.29
566083.25
MWD+IFR-AK-CAZ-SC
+ 14321.98 89.15 357.19 3779. 72 3670.72 5292.00 7257.35 5950997.54 566078.43 MWD+~FR-AK-CAZ-SC
14415.01 89.21 357.23 3781. 05 3672.05 5384.91 7252.82 5951090.40 566073.18 MWD+tFR-AK-CAZ-SC
14507.48 89.28 357.64 3782. 27 3673.27 5477.28 7248.68 5951182.73 566068.32 MWD+IFR-AK-CAZ-SC
14601.16 89.15 357.39 3783. 55 3674.55 5570.86 7244.62 5951276.26 566063.53 MWD+IFR-AK-CAZ-SC
14695.24 89.15 358.20 3784. 95 3675.95 5664.86 7241.00 5951370.22 566059.17 MWD+IFR-AK-CAZ-SC
14791.25 91.76 359.16 3784. 18 3675.18 5760.83 7238.79 5951466.17 566056.21 MWD+IFR-AK-CAZ-SC
14886.48 94.04 359.93 3779. 37 3670.37 5855.93 7238.03 5951561.25 566054.71 MWD+IFR-AK-CAZ-SC
14981.37 93.10 359.69 3773. 46 3664.46 5950.64 7237.72 5951655.94 566053.66 MWD+IFR-AK-CAZ-SC
15076.95 92.36 358.53 3768. 91 3659.91 6046.09 7236.23 595t751.37 566051.43 MWD+IFR-AK-CAZ-SC
15171.02 93.48 358.78 3764. 11 3655.11 6140.01 7234.03 595'~845.26 566048.49 MWD+IFR-AK-CAZ-SC
15266.40 90.26 357.89 3761. 00 3652.00 6235.29 7231.26 5951940.50 566044.98 MWD+IFR-AK-CAZ-SC
15360.54 90.01 358.31 3760. 78 3651.78 6329.38 7228.14 5952034.55 566041.12 MWD+IFR-AK-CAZ-SC
15457.68 89.21 358.73 3761. 44 3652.44 6426.48 7225.63 5952131.63 566037.85 MWD+IFR-AK-CAZ-SC
15553.21 89.21 359.49 3762. 76 3653.76 6521.99 7224.15 5952227.11 566035.62 MWD+IFR-AK-CAZ-SC
15644.15 89.09 0.10 3764. 11 3655.11 6612.92 7223.82 5952318.03 566034.59 MWD+IFR-AK-CAZ-SC
15740.14 89.15 0.44 3765. 58 3656.58 6708.90 7224.27 5952414.00 566034.29 MWD+IFR-AK-CAZ-SC
15836.20 89.59 0.73 3766. 64 3657.64 6804.95 7225.25 5952510.04 566034.52 MWD+IFR-AK-CAZ-SC
15933.13 88.41 358.84 3768. 33 3659.33 6901.85 7224.89 5952606.93 566033.40 MWD+IFR-AK-CAZ-SG
16025.79 89.09 359.21 3770. 35 3661.35 6994.48 7223.31 5952699.53 566031.10 M1ND+IFR-AK-CAZ-SC
16122.71 89.21 359.58 3771. 79 3662.79 7091.38 7222.29 5952796.42 566029.32 MWD+IFR-AK-CAZ-SC
16217.38 89.40 359.82 3772. 94 3663.94 7186.04 7221.79 5952891.06 566028.08 MWD+IFR-AK-CAZ-SC
16312.29 88.90 0.50 3774. 34 3665.34 7280.94 7222.06 5952985.95 566027.60 MWD+IFR-AK-CAZ-SC
16408.09 89.15 0.28 3775. 97 3666.97 7376.72 7222.71 5953081.73 566027.51 MWD+IFR-AK-CAZ-SC
16500.97 89.09 0.16 3777. 40 3668.40 7469.59 7223.07 5953174.59 566027.14 MWD+IFR-AK-CAZ-SC
16597.80 89.34 0.02 3778. 73 3669.73 7566.41 7223.22 5953271.40 566026.53 MWD+IFR-AK-CAZ-SC
16694.06 89.34 359.52 3779. 84 3670.84 7662.67 7222.83 5953367.63 586025.39 MWD+lFR-AK-CAZ-SC
16787.54 88.84 359.18 3781. 32 3672.32 7756.13 7221.77 5953461.08 566023.60 MWD+IFR-AK-CAZ-SC
16882.12 89.28 358.82 3782. 87 3673.87 7850.68 7220.12 5953555.60 566021.21 MWD+IFR-AK-CAZ-SC
16976.98 89.27 358.98 3784. 07 3675.07 7945.52 7218.30 5953650.41 566018.65 MWD+IFR-AK-CAZ-SC
C~
J
Halliburton Company
Survey Report
i
Company: ConocoPhillips Alaska Inc. Date: 8/16/2007 Time: 09:25:39 Page: 5
Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1J-122, True North
Site: Kuparuk 1J Pad Vertical (1'VD) Reference: D141 (28 + 81) 1-09.0
Well: 1J-122 Section (VS) Reference: WeII (O.OON,O.OOE,O.OOAzi)
Wellpath: 1J-122L2 Survey Calculation Method: Minimum Curvature Db: Orecle
Survey
i, MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Toof
ft deg deg ft ft ft ft ft ft
17072.28 90.02 358.77 3784.66 3675.66 8040.79 7216.43 5953745.66 566016.04 MWD+IFR-AK-CAZ-SC
17166.52 89.83 358.19 3784.79 3675.79 8135.00 7213.93 5953839.84 566012.80 MWD+IFR-AK-CAZ-SC
17261.17 89.46 358.01 3785.37 3676.37 8229.60 7210.79 5953934.40 566008.92 MWD+IFR-AK-CAZ-SC
17357.71 89.40 357.21 3786.33 3677.33 8326.05 7206.77 5954030.81 566004.14 MWD+IFR-AK-CAZ-SC
17453.76 89.52 354.94 3787.24 3678.24 8421.86 7200.19 5954126.56 565996.82 MWD+IFR-AK-CAZ-SC
17549.44 90.89 356.11 3786.90 367~.90 8517.25 7192.73 5954221.87 565988.61 MWD+IFR-AK-CAZ-SC
17644.33 87.24 355J8 3788.45 3679.45 ° 8611.87 7186.02 5954316.43 565981.17 MWD+IFR-AK-CAZ-SC
17739.01 88.04 355.64 3792.34 3683.34 8706.20 7178.94 5954410.70 565973.35 MWD+IFR-AK-CAZ-SC
17833.00 88.54 356.66 3795.15 3686.15 8799.94 7172.64 5954504.37 565966.31 MWD+IFR-AK-CAZ-SC
17928.77 89.71 357.90 3796.61 3687.61 8895.58 7168.09 5954599.97 565961.02 MWD+IFR-AK-CAZ-SC
18020.47 89.65 358.25 3797.12 3688.12 8987.23 7165.01 5954691.58 565957.23 MWD+IFR-AK-CAZ-SC
F 18078.00 89.65 358.25 3797.47 - 3688.47 9044.73 7163.26 5954749.06 565955.02 PROJECTED to TD
~ •
~ 1
~J
~
27-Aug-07
AOGCC
Librarian
333 W. 7th Ave. Suite 100
Anchorage, AK 99501
Re: Distribution of Survey Data for Well 1 J-122L2
Dear Dear Sir/Madam:
Enclosed is one disk with the *.PTT and *.PDF files.
Tie-on Survey: 10,263.66' MD
Window / Kickoff Survey: 10,332.00' MD (if applicable)
Projected Survey: 18,078.00' MD
PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO
Timothy.Allen@HALLIBURTON.COM OR SIGNING AND
RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE
ATTENTION OF:
Sperry-Sun Drilling Services
Attn: Timothy Allen
6900 Arctic Blvd.
Anchorage, AK 99518 ~/ ,~ . ,
Date ~ ~~ ~~ Signed
Please call me at 273-3534 if you have any questions or concerns.
Regards,
Timothy Allen
Survey Manager
Attachment(s)
a~~ - ~ 7~
~ ~
~ ~ ~ ~
~
SARAH PAUN, GOVERNOR
°~~1~T 0~ ~~ 333 W. 7thAVENUE, SUITE 100
C~~E~~~~a` C,~~s~IQ~ ~ ANCHORAGE, ALASKA 99501-3839
PHONE (907) 279-1433
Randy Thomas Fnx ~so>> z~e-~5az
Drilling Team Leader
ConocoPhillips Alaska Inc.
PO Box 100360
Anchorage, AK 99510-0360
Re: Kuparuk River Field, West Sak Oil Pool, 1J-122L2
ConocoPhillips Alaska Inc.
Permit No: 207-072
Surface Location: 1837' FSL, 2347' FEL, SEC. 35, T11N, R1pE, UM
Bottomhole Location: 318' FSL, 422' FEL, SEC. 24, T 11 N, R l 0E, UM
Dear Mr. Thomas:
Enclosed is the approved application for permit to drill the above referenced service
well.
The permit is for a new wellbore segment of existing well KRU 1J-122, Permit No 20?-
070, API 50-029-23359-00. Production should continue to be reported as a function
of the original API number stated above.
This permit to drill does not exempt you from obtaining additional permits or an
approval required by law from other governmental agencies and does not authorize
conducting drilling operations until all other required perrnits 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.
When providing notice for a representative of the Commission to witness any required
test, contact the Commission's petroleum field insp~or at (907) 659-3607 (pager).
DATED this ~/day of June, 2007
cc: Department of Fish 8~ Game, Habitat Section w/o encl.
Department of Environmental Conservation w/o encl,
~ ~ RECEIVED
STATE OF ALASKA }~
ALASKA OIL AND GAS CONSERVATION COMMISSION /~1-~ MAY 2 5 70~1
PERMIT TO DRILL ~n ( ~~
2o,4ac 2s.oo5 Alaska Oil & Gas Cons. Co-mmission
1 a. Type of Work:
Dril! Q/ Re-drill ^
Re-entry ^ 1 b. Current Well Class: Exploratory ~ Development Oil ~
Stratigraphic Test ^ Service ^~ Development Gas ~
Multiple Zone^ Single Zone ~ 1 c. Specify if well is pro .
Coalbed Methane ~ Gas Hydrates ^
Shale Gas ^
2. Operator Name:
ConocoPhillipsAlaska, Inc. 5. Bond: / Blanket Single Well
Bond No. 59-52-180 ~ 11. Well Name and Number:
1J-122L2 •
3. Address:
P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth:
MD: 18032' ~ ND: 3778' " 12. Field/Pool(s):
Kuparuk River Fieid
4a. Location of Well (Governmental Section):
Surface: 1837' FSL, 2347' FEL, Sec. 35, T11 N, R10E, UM • 7. Property Designation:
ADL 25661 & 25650
West Sak Oil Pooi ~
Top of Productive Horizon:
2059' FNL, 375' FEL, Sec. 36, T11 N, R10E, UM ~ S. Land Use Permit:
ALK 471 & 468 13. Approximate Spud Date:
6/28/2007
Total Depth:
318' FSL, 422' FEL, Sec. 24, T11 N, R10E, UM • 9. Acres in Property:
2560 14. Distance to
Nearest Property: ~ 1 mile <<.~~.
4b. Location of Well (State Base Plane Coordinates):
Surface: x- 558863 ' y- 5945649 " Zone- 4 10. KB Elevation
(Height above GL): 1 O9' RKB feet 15. Distance to Nearest
~/ell within Pool: ~J-~os , ~0840' @ 1711
16. Deviated wells: Kickoff depth: 10368 • ft.
Maximum Hoie Angle: g3° de9 17. Maximum Anticipated Pressures in psig (see 2o aaC 25.035)
Downhole: 1701 psig Surface: 1285 psig
18. Casing Program
if
ti
S Setting Depth Quantity of Cement
Size peC
iCa
ons Top Bottom c. f. or sacks
Hole Casing Weight Grade Coupling Length MD ND MD ND (inctuding stage data)
40" 20" 62.5# H-40 Welded 80' 28' 28' 108' 108' 260 cf ArcticCrete
16" 13-3l8" 68# L-80 BTC 4164' 28' 28' 4204' • 2265' 770 sx AS Lite, 220 sx DeepCRETE
12.25" 9-5/8" 40# L-80 BTCM 11778' 28' 28' 11818' - 3969' ~ 900 sx DeepCrete
8.5" 4.5" 11.6# L-80 BTC CSG 7663' 10368' 3701' 18031' 3778' slotted liner
19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations)
Total Depth MD (ft): Total Depth ND (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth ND (ft): Junk (measured)
Casing Length Size Cement Volume MD TVD
Cond uctor/Structu ral
Surface
Intermediate
Production
Liner
Perforation Depth MD (ft): ~~ PerForation Depth ND (ft):
20. Attachments: Filing Fee ~ BOP Sketch Drilling Program Q Time v. Depth Plot Shallow Hazard Analysis Q
Property Plat ~ Diverter Sketch ^ Seabed Report ^ Orilling Fluid Program Q/ 20 AAC 25.050 requirements ^~
21. Verbal Approval: Commission Representative: Date:
22. I hereby certify that the foregoing is true and correct to the best of my knowledge. ContaCt P8t Reilly @ 265-6048
Printed Name Ran/d~ omas / Titie Drilling Team Leader /
Signature ~ ` ~~~ ~ ~ ~ ~[~~~ Phone Date ~!"~ ~/U'~
~~ ~ ro D k
Commission Use Only
Permit to Drill
Number. ~?'~~??j API Number:
50- 02..~ ~~J3~~~p ~ Permit Approval
Date: ,~ See cover letter
for other requirements
COnditi0ns of approval : If box is checked, well may not be used to explore for, test, or produce coalbed me ane, gas hydrates, or gas contained in shales:
'3,~~~~ ~~~ l~~S~ Samples req'd: Yes ^ No Mud log req'd: Yes ^ No [~'
Other: ~~ H2S measures: Yes ~ ir tional svy req'd: Yes [/]~ No ^
S~~ a~r1-o''1 O ~oc-~~ ~~v~ ~~'e.,~
/~ J+~ ~ D~ AP OVED BY THE COMMISSION
DATE' ("~ ~ ~r~ , COMMISSIONER
Form 10-401 Revised 12/2005 ~p ~~ ~~~~~ r~ ~~ v ~ e~ ubmi# in Duplicate ~
f~ ~,~ s, 3,, o
•
A~ion for Perrnit to Drill, Well 1J-122 L2
Revision No.O
Saved: 24-May-07
Permit It - West Sak Well #1J-122L2 ""~
f.A
~~
Application for Pe~mit to D~ill Document r~
~~~~~~
_ M~x~rr~iz~
14e~11 Y414e
Table of Contents
1. Well Name .... ..................................................... ................................................... 2
... ...
Re uirements o 20AAC2S.005 ................................................•-•-•---............................................ 2
4 .f ~-........
2. Location Summary ..................................................................................................... 2
Requirements of 20 AAC 25.005(c)(2) ......................................................................................................... 2
Requirements of 20 AAC 25.050(b) ............................................................................._...-.------.................... 2
3. Blowout Prevention Equipment Information ............................................................... 3
Requirements of 20 AAC 25.005(c)(3) .....................................~--~-~-~--~-~....................................................... 3
4. Drilling Hazards Information ..................................................................................... 3
Requirements of 20 AAC 25.005 (c)(4) ........................................................................................................ 3
5. Procedure for Conducting Formation Integrity Tests .................................................. 3
Requirements of 20 AAC 25.005 (c)(S) ........................................................................................................ 3
6. Casing and Cementing Program ................................................................ ...... .....
... ... 4
Requirements of 20 AAC 25.005(c)(6) ..................................................:.....•--.............................................. 4
7. Diverter System Information ...........................................................................:.......... 4
Requirements of 20 AAC 25.005(c)(7) ......................................................................................................... 4
8. Drilling Fluid Program ............................................................................................... 4
Requirements of 20 AAC 25.005(c)(8) .....................................................~-~-~--..................,.......................... 4
Lateral Mud Program (MI VersaPro Mineral Oil Base) .........................................:..................................... 4
9. Abnormally Pressured Formation Information ........................................................... 5
Requirements of 20 AAC 25.005 (c)(9) ........................................................................................................ 5
10. Seismic Analysis ............................................................................................. .........
... 5
Requirements of 20 AAC 25.005 (c)~1 ~) •---• ........................................................................••-•-•--.........:....... 5
11. Seabed Condition Analysis .......................................................................................... 5
Requirements of 20 AAC 25.OOS (c)(II) .............................................................................................,........ 5
12. Evidence of Bonding ................................................................................................... 5
1J-122 L2 PERM/T IT
Page 1 of 6
Printed: 24-May-07
~ ~~~~~~-L
~J
A~ion for Permit to Drill, Well 1 J-122 L2
Revision No.O
Saved: 24-May-07
Requirements of 20 AAC 25.005 (c)(12) ...................................................................................................... 5
13. Proposed Drilling Program ......................................................................................... 5
Requirements of 20 AAC 25.005 (c)(13) ........................•-•-•--•--......................................................,............. 5
14. Discussion of Mud and Cuttings Disposal and Annular Disposal ................................... 6
IZequirements of 20 AAC 25.005 (c)(14) ...., ...........................:..................................................................... 6
15. Attachments ............................................................................................................... 6
Attachment 1 Doyon 141 West Sak 2004 3 ksi BOP Configuration (1 page) .. Error! Bookmark not defined.
Attachment 2 DiYectional Plan (6 pages) .....:..........•-•--............................................................................... 6
Attachment 3 Drilling Hazards Summary (1 page) .................•---................................................................. 6
~ Attachment 4 Well Schematic 1 a e ~ ............. 6 ~
( P g ) ................................•--.......................................................
L Well Name
Requirements of 20 AAC 25.005 (~
I;ach vt~ell rnztst be idera~ified bv a uniqr,re name desig72ated b3~ ttte oper atar arrd n urarque.4E'1 rurrcher assigned hv ttzz c~mmisszart i.tnder 20 ~1AG
25:040{~). For a well ~vrth multipte wett br•anches, each I~rrztacli rraz{st similardy fie ictexitif et! ~y a unigzce name and ~~PL rtarmber fiv addi:xg a sa~ffrx
to tlte rt4rr.e de.rigncated fc~r the x~edl hv the operaGor nrad tc~ the nutraf~er cassigt~ted lo tlse welG by~ tT2e c~~Frart~aission. ~ ~ ~ ~
The well for which this Application is submitted will be designated as 1J-122 L2.
2. Location Summary
Requirements of 20 AAC 25.005(c)(2)
.4n a~l~d£ccation,fhr ca Pet-rttal to I~rill musl be uceom~anzecl f.ry• eczeh of the fallenvitxg itrms, exeept,f'or an itefsa alrea~'y on file wa!)z the c~rntrtissi<+n
~ and iderttlfzer~ zrz the a~~plicanora: ~ ~ ~
(2) a plat identifj~ing the pt~operiy ancl the ~~roper~ly ;s owtaers ancl shotvzng
(A)the c~ordinates of the ~roposed locatzoiz of tlae well c~t thz sut~face,< at the to~ ~?f'each ~bjective fr.~r•rnafton, ane~t at todal depth, r~ferenced tn
goi~eretrrzetata(seetion Iines.
(B} the conrdinatar vJ'tlae pr-opo,red locatiort of Che ~well al tlae s2trfczce, rEferenced to the sfc~teplarr~~coorifir~aPe sy~`tert2 f"or thrs state as mairatcti~~aed
~ry the hratiortal Geodetic Sur-vev in the .Nati~raal Oceanic an~I tllmospFaer~dc ~~dministf~atinda;
(CJ the propas€ d deplh ~j the n%c:lt c~t the top ~f each objective f«rmati~n atzd at total depth,; ~ ~ ~
Location at Surface 183T FSL, 2347' FEL, Section 35, T11N, R10E
ASP Zone 4 NAD 27 Coordinates RKB EZ2vatioY! 1 ~9' E1MSL
NoYthings.• 5,945,649 Eastings: 558,863 ~ Pad Elevation 81' AMSL ~
Location at Top of
Productive Interval (West
Sak "B" Sand
2,059' FNL, 37S FEL, Section 36, T11N, R10E
ASP zone 4 1vAD 27 coordtnates Measured Depth, RKB: 10,370
NoNthings: 5,947,095 Eastings: 566,103 Total T~ertical Depth, RKB: ~ 3,701 ~~~
Total Vertical De t17, SS: 3,592
Location at Totai De th 318' FSL, 422' FEL, Section 24, T11N, R10E
ASP Zone 4 NAD 27 Coordinates Measul^2Cd~ D2pth, RKB: 1 g~032 ;,
Northings: 5,954,749 Eastings: 565,988 Total iJertical Depth, RKB: 3,778 ~
Total Vertical Depth, SS: 3,669
crn~~
(D) otlier• inforrraatiorr reyuired by 2J.~1C lS.f~~O((>j; ~~ ~ ~ ~
Requirements of 20 AAC 25.050(b)
Ifa well is do be iratentinnUdZy~ c~evr~c~cecl, [he uppdfcation foY a P~rmit to L?f~•ilt (Form Z~-~1~1) rrtt~rst ~ ~~
~~~~~f~AL
1J-122 L2 PERMIT lT
Page 2 of 6
Printed: 24-May-07
~
A~ion for Permit to Drill, Well 1J-122 L2
Revision No.O
Saved: 24-May-07
{'11 inclutte a plat, dratvr~ t~ a s'uituhle seale, showing Ihe ~aLdt of the ~~oprue~l we1lZ~ore, z~zch~tdittg all c~c~jacenl welllrot-es withirz ?C1Q feef of am~
~~~rti~n af [lae~~rr~~lczsed ~vel?;
Please see Attachment 1: Directional Plan
and
(2) for all ~~e11s ~b~ithin 2QO~c:et oft~zepro~~r~sed ~v<:ttbore
(~?) Irst Phe r,ar~ses of tlae aperators of t~zo~e u~ells, io the extertt tlaat tktosc= names ut•e l~zozvn or dascover-abtz irt Ft;rfiZic r•ecords, zand shz~w tltat
each nur~sed operatoN Jias been fur~nis]aer~ ~z copy of tlze ~~p~_lictztron by eertifed r~~aiT,• ~r
(13) stute Cdacrf C&e~a~~Iicant is the orEly aJ~ected ownet•. ~ ~ ~ ~ ~
The Applicant is the only affected owner.
3. Blowout Prevention Equipment Information
Requirements of 20 AAC 25.005(c)(3)
An applicati~rz_far a Permr.'t to L1~~al'Z t>azsst be czccc~mpa~^tred Uy eac{t of tl2e follou~irag zterras, e:xcept fot~ an itern~ alrecacdy ora file.~evith th~ cc~mm~zssiofa ~~
czrzc~ aca'eniified ira t/2e ap~lzcaiiat~: ~ ~ ~ ~ ~ ~
(3) ts diagrtam anc~rlesct-i~~tic~n ofthe blowr~ufprevesafiot3 ec~tt~~rneni (BQ~'E) as requir~edhy ?f1,4.~C'25.035, 20,4(1C2.5.~l3n or2p,4~C 25,f137,
as r~pplicr,~1?le; ~ ~ ~ ~ ~ ~ ~
An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to~ drill and complete well 1 J-122 L2. Please see ~ ~
information on the Doyon Rig 141 blowout prevention equipment placed on file with the Commission.
4. Drilling Hazards Information
Requirements of 20 AAC 25.005 (c)(4)
~Iaz appHeaiian for a Pe~rnit to 17rilt must he nccnmp~nin.d by each of the fo?lowin~ iterras, <xce~fi for nss item a~r•eady on file v~ith the comrnissiort~
aztzd zdcniified in tFie application; ~ ~ ~
{'41 inf'oprvzaLian ort d~r."Zlirag hrzzfat•ds; fteclzt~irtg
(~2J the maximum c~~x~nhole pres°sur~e that rrray be ~ricr~ur~Fere~t criteria used to determine it, atul maxdmum pUtentirzl stsrface pYessur•e t ased an
ca methanr ~rcacfient;
The expected reservoir pressure in the West Sak sands in the 1J-122 L2 is 0.45 psi/ft, or 8.6 ppg EMW (equivalent
mud weight).
The maximum potential surface pressure (MPSP) Based on the above maximum pressure gradient, a methane
gradient (0.11), and the deepest planned vertical depth of the West Sak A2 sand formation is 1,285 PSI, calculated
as follows:
The MPSP is:
MPSP = (3,779 ft)(0.45 - 0.11 psi/ft) ~ ~ ~ ~ ~ ~
=1,285 psi
~ {B) data on poterztial has zorzes,- ~ ~ ~ ~ ~
The well bare is not expected to penetrate any gas zones.
,2nc~
(C) c~ata eancernirt~ I~otential azuses c fhole~3rob?erns such <zs ~abtzt~r~mally geo ~re~c,satred .ctrutca, lost eirezrlatzon zones, unc~zoizcs thui hai=e ca
F~r<~pensih~ for c~if'ferential strckin~;
Please see Attachment 2: Drilling Hazards Summary.
5. Procedure for Conducting Formation Integrity Tests
Requirements of 20 AAC 25.005 (c)(S)
<4~^~ aF~~ticatiora far a Permit to 1)rill must be czecom~rarziecl by each of the follorf~iyag iterns, e~cept f~r an itent alreudy c~te j'sle zvzik Jhe commzsszan'
arrr~ ideratiJ'rect irz the appZication: ~ ~ ~~ ~ ~ ~
(5) a deseviptian c~f fhe frrocedure for carrducting formatior~ ifzte~rity tests, css reguit~etl z~nder 20 tl AC 25. {)30(f~;
No formation integrity test will be performed in the drilling of 1J-122 L2
1J-122 L2 PERMIT IT
Page 3 of 6
~ ~ ~ ~ ~ ~ ~ ~ Printed: 24-May-07
~ A~ion for Permit to Drill, Well 1J-122 L2
Revision No.O
Saved: 24-May-07
6. Casing and Cementing Program
Requirements of 20 AAC 25.005(c)(6)
.4t~i ap~licatzora for a Perrynzt ta ~rtll ~s~a~t~st be uccom~~<anied by eacl~a of th~ follotii~ir~ag ztems, except fr~r~ an ite~n alYeady orz fil~ with the coinmissian
~ anrT identified irt the application: ~ ~ ~ ~ ~
(6~ a cor~t~lete prop~sed casing and cernertfir2g progr•arn as r~eqt~i~ed 1~}= 2(1 ~?~~C 2S.(~30, arul a tlrrcriptr~ra c~f czf~ty slatted Lirzer,~ pre-perJorated
dine~~, or sc~°een to fie insCatletl;
Casing and Cementing Program I
See also Attachment 3: Cement Summarv
Hole Top Btm
Csg/Tbg Size Weight Length MD/TVD NID/TVD ~~ ~
OD (in) (in) (Ib/ft) Grade Connection t) (ft) ~ (ft) CemenfPro ram
20" 40" 62S H-40 Welded 80 28' / 28' 80' / 80' Cemented to surface with 260 cf
ArcticCRETE
Cemented to Surface with
13-3/8" 16" 68 L-80 BTC 4,164 28' / 28' 4,204' / 2,265' 770 sx ArcticSet Lite L,ead,
220 sx DeepCRETE Tail
Cement Top planned @ 6,750'
9-5/8" 12-1/4" 40 L-8D BTCM 11
778 28' / 28' 969'
11
818' / 3 MD / 2,860' TVD. Cemented
, ,
, w/
900 sx Dee CRETE
5-1/2 8-1/2" A2 Sand 15.5 BTCM 7 0 8 ' ' '/ 3,990' Slotted-no cement
~ ~
4-1/2 8-1/2" B Sand Lateral 11.6 L-80 BTC CSG 260
7 10
969'
779' / 3 845'
18
039' / 3 Slotted- no cement
~ slotted ~ (iJ-izzLi~ ~ , ,
, ,
,
~
- - 2" D Sand Iateral 11.6 L-80 BTC CSG 7
663' 10
368' / 3
70 Sl -
slotted (iJ-i~z Lz~ , ,
, , ,
7. Diverter System Information
Requirements of 20 AAC 25.005(c)(7)
,~.n r~p~~licatio,s,for a Pennii tQ L?i^i11 mu,st be aecom~~aniec~ hy e~eh of ~tlxe f'ollowi;zg irems, except for an itemm c~lreadv on jzle wirf~ the cornrnis,sion
and zdetzt~ed zt2 the a~plzcation: ~ ~ ~ ~ ~ ~
{ij ca c~itagram rxnd ttescri~a'ion vf the ctr."verter systeera as requir-ed hy 2~ AAC 25. t13 ~; uraless tlzis r~quirernettt zs wcZived hy the cr~rrarriissiora unc~er
2t1 ~?~~C 2.i.U35(hj(2,),
No diverter system will be used during operations on 1J-122 L2
8. Drilling Fluid Program
Requirements of 20 AAC 25. 005(c)(8)
.~tn cap~lication.far a Per-r12i! to Drill rrtust he accornj~anietl Fiy ecach ofthe followiny, ifems, except fi~r an irein calreaclv an file ~vidl7 the cotttrnissu~n
and irlettt~ed in the rs~~Plzcatdora: ~ ~ ~
(8) a clt-illing flui~'F~rogt-am, incl2rditzg a diagram atul description of tlze tdrillrng,f7uid system, as requrr•e~~ by= ?[~:4i4C? 5. t133;
Drilling will be done with muds having the following properties over the listed intervals:
Lateral Mud Program (MI VersaPro Mineral Oil Base)
i
Value
Densi (pp ) 9A
Plastic Viscostiy 15-25
(lb/100 s
~ Yield Point ~ ~ 18-28
~ (cP ~
HTHP Fluid loss ~
(ml/30 min @ <4A
200psi & I50°
Oil / Water Ratio 80:20
~
1J-122 L2 PERMIT lT
Page 4 of 6
Printed: 24-May-07
~ A~ion for Permit to Drill, Weil 1J-122 L2
Revision No.O
Saved: 24-May-07
Electrical >600
~ ~ ~ ~ ~ Stability ~ ~ ~ ~ ~
Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see
information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 14 L
9. Abnormally Pressured Formation Information
~ Requirements of 20 AAC 25.005 (c)(9) ~ ~ ~ ~ ~ ~ ~ ~ ~ ~
~ An eap~ltcaii~n for a 1'errrtit to L?rill must be accorn~anied hy ec~ch of the, foll~wzng> items, eece~at_f'~r ayt xtemn alrear~v ~n,~le ?vith the corrttraissior~ ~
and iilentifed zn the ar~plfce2tdo~2:
(9) f~r~ an exploratory or straCi~raphic tesC well, a tabulatir~n seCtirig out the del~ll~s ~f,rireclaeXecl afinvrmcrdly geo ~ressured ctrcata as Y~yuire~f ~y
20 A,2C 25. D3.i(f);
Not applicable: Application is not for an exploratory or stratigraphic test we1L
10. Seismic Analysis
Requirements of 20 AAC 25.005 (c)(10)
.4~2 c~~~lteatz~;2 for a Per'rnzt to Z~Yill m~ust be ucr,om~anied hy e~zcla of th~e foll~wi;i~ iiems, exc;ept for- tan item alrzac~j~ ots file wiifa the eornmkesion ~~ ~~
and idetitified zn the a~~ptdcationr
(10) for an ex~lor•atot y= or str-atioraphic test ~vell, a seismic r~fracti~n or reflection araaly~is as r-equif-ed by ?0 AAC ZS. ~SL (a1;
' Not applicable: Application is not for an exploratory or stratigraphic test well.
ll. Seabed Condition Analysis
Requirements of 20 AAC 25.005 (c)(11)
An ztpplicntion for a P~rnzi! to 1>rill must be accarrt~anied &y erzclz oJ dhe. following items, ~ce~t, for ari item zzlrectdv nn~le n~ith the contrrtiss ion
ra~~' zrlentzfiecl an-tke ~zpplicatioiz:
~~ ('11) f'or^ a ive11 dr-illecl from czf~i ~~ff.sFzore platforrn, mofiile ~=otLom-fourzc.led struct¢tre, jack-up Nig, or^ floc~ting drallcn~ vesset, an analysis of ~seahed ~
c~3raditic~n.c as requirerl fiy 20 ,4AC 2 S.Ofi!(fr};
Not applicable: Application is not for an offshore we1L
12. Evidence of Bonding
Requirements of 20 AAC 2S.OOS (c)(12)
An applicatzon fhr a Pennit to Drill rnust be accom~anie~l by each t?f tha follotivina items, except for an item alrer~th~ otz f ile ivitla the commzssic~n
and ident~ed zrz the crF~p?zcalion:
(L2) evzdertce shoroying that the reqtrzretnents of 20 ~1~4C 'S.OlS {Bonc~ing,tlaave been met;
Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission.
13. Proposed Drilling Program
Requirements of 20 AA~ 25.005 (c)(13) ~ ~ ~ ~ ~ ~
An ezp~ficataon for caPerrriit to Brill must be accompanied b}~ each oj the,following idems, ~rce~t for «ra iPem aCreadv on file ~~ith the conzr~rtis,rion
ancl r,'clenlzfiec~ dn the applicexizon: ~
The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematic.
Note: Previous operations are covered under the 1J-122 and 1J-122 L1 Application for Permit to Drill.
1. Run and set Baker WindowMaster whipstock system, at window point of 10,368' MD / 3,701' TVD, the top of the
«D„ sand. '
2. Mi118-1/2" window. POOH.
3. Pick up 8-1/2'' drilling assembly with LWD and MWD and PWD. RIH.
4. Drill to TD of "D" sand lateral at 18,031' MD / 3,778' TVD, as per directional plan.
Sa POQH, back reaming out of lateral. POOH.
6. RIH with whipstock retrieval tool. Retrieve whipstock and POOH.
7. PU and run 4-1/2" slottedliner.
8. RIH, until liner hanger is just above window. Orient hanger to window and land hanger.
9. Release hanger running tool. POQH.
~~'~~~~~L
1J-122 L2 PERMIT IT
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~ A~ion for Permit to Drill, Well 1J-122 L2
Revision NoA
Saved: 24-May-07
10. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth, Orient and set
packer atop assembly and release from assembly. POOH.
11. POOH, laying down drill pipe as required.
12. PU completion as required and RIH to depth. Run CMD sliding sleeve in open position for gas lift
during injector pre-production period. Land tubing. Set BPV.
13. Nipple down BOPE, nipple up tree and test. Pull BPV.
14. Freeze protect well with diesel by pumping into 4-1/2" x 9-5/8" annulus, taking returns from tubing and allowing to
equalize.
15. Set BPV and move rig off.
16. Rig up wire line unit. Pull BPV.
~
17. Set gas lift valves in mandrels. Operate well on gas lift for +/- 45 days through open CMD sliding
sleeve (flowback cleanup). Shut well in.
18. Rig up wireline. Replace gas Jift valves with blank dummy valves. Close sliding sleeve. Perform
MITIA. Return well to injection.
14. Discussion of Mud and Cuttings Disposal and AnnuIar Disposal
Requirements of 20 AAC 25:005 (c)(14)
~tz aF~pticatiosa f4r a PermiZ to Z)Yill r~austc Ite aecompanted by each of the_followzng items, except f~rr ~n iterra ~zlreactv on file with the curnrraission
and iderattfxed ira the applzcation: ~ ~ ~ ~ ~
(14) a general descriptzott c f l~aotit~ the o~>et•ator plans to ~lirpvse of dr^dlling mud Urrd czattings and a staten~tent of whether ~1'~ae~opet•afor anLerul.s ~tu ~
requesC~auth~rizativ~a zrncter 2lI fIAC 25.OSf) for cxrz annular disl~osal opePnCaors in tlae welL; ~ ~ ~ ~ ~
Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a
permitted annulus on 1J Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be
disposed of either down a permitted annulus on lE Pad, hauled to the Prudhoe Bay Grind and Inject Facility for
temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for
hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in
accordance with a permit from the State of Alaska.
ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal
operations.
15. Attachments
Attachment 1 Directional Plan ~ ~ ~ ~ ~ ~ ~ ~~ ~
Attachment 2 Drilling Hazards Summary
Attachment 3 Well Schematic
1J-122 L2 PERMIT IT
Page 6 of 6
Printed: 24-May-07
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Plan: 1J-122 L2 (wp06)
Sperry Drilling Services
Proposal Report - Geographic
09 May, 2007
ConocoPhillips Alaska, Inc.
Kuparuk River Unit
Kuparuk 1J Pad
Plan 1J-122 - Slot 1J-122
1J-122 L2
Local Coordinate Origin: Centered on Well Plan 1J-122 - Slot 1J-122
Viewing Datum: Planned RKB @ 109.OOft (Doyon 141 (28+81)) ~
TVDs to System: N
North Reference: True ~
Unit System: API - US Survey Feet ~
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Spe~ry Orilling Servlces
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1000
Project: Kuparuk River Un
Site: Kuparuk 1J Pad
Well: Plan 1J-122
Wellbore: 1J-122 L2
Plan: 1J-122 L2 (wp06)
WELL DETAII.S: Plan 1 J-122 NAD 1927 (NADCON CONUS) Alaska Zone 04
Gound I.evel: 81.00 ~
+N/-S +FJ-W Northing Ea sbng Latittude Longitude Sbt
0.00 0.00 594564448 55886337 70°IS'43.595N l49°31'26.931W ll-122
FORMATION TOP DETAILS
No .NDPath TVDSS MDPath Formation
1 1504.91 1395.91 1650.33 Pfrost
2 1657.88 1548.88 1893.72 K15
3 1987.83 1878.83 3017.64 T3
4 2265.39 2156.39 4204.89 Casing Pt
5 2975.71 2866.71 724324 Ugnu C
6 3275.25 3166.25 8524.50 Ugnu B
7 3352.32 3243.32 8854.16 Ugnu A
8 3541.64 3432.64 9663.97 K 13
9 3701.06 3592.0610368.70 W Sak D
CASING DETAILS
1500
No MD TVD TVDss Nazne Size
1 4204.89 226539 2156.39 13 3/8" 13-3
2 103G8.72 3701.OG 3592.06 9 5/8" TOW 9-5/1
3 1803139 377830 3G693 5 V2" 5-I/:
2000 -------------------- ---------------------------------------
Q 2500 L2 9 5/8" TOW @ 10369' MD, 3701' ND: 2059' FNL, 375' FEL - Sec36-T11 N-R10E
L2 BHL @ 18031' MD, 3778' ND: 318' FSL, 422' FEL - Sec24-T11N-R10E
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Vertical Section at 0.00° (1000 ff/in) ~..____ ~:~~.y„
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Halliburton Company
Compass Proposal Report - Geographic
Ku aruk RiverUnit, North Slo Alaska, United States
Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level
Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point
Map Zone: Alaska Zone 04 Using geodetic scale factor
Audit Notes:
Version:
Phase: PLAN
28.~0
Tie On Depth:
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5/9/2007 3:49:38PM Page 2 of 8 COMPASS 2003.11 Build 48
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Well Position +N/-S 0.00 ft Northing: 5,945,649.48 ft~ Latitude: 70° 15' 43.595" N
+E/-W 0.00 ft Easting: 558,863.37 ft~ Longitude: 149° 31' 26.931" W
Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 81.OOft
~ ~
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10,368.70 ~ 77.41 1.76 3,701.06 3,592.06 1,388.01 7,251.40 0.00 0.00 0.00 0.00
10,385.20 79.66 1.76 3,704.34 3,595.34 1,404.18 7,251.89 13.60 13.60 0.00 0.00
10,405.20 79.66 1.76 3,707.93 3,598.93 1,423.84 7,252.50 0.00 0.00 0.00 0.00
10,658.82 91.66 5.87 3,727.10 3,618.10 1,675.66 7,269.37 5.00 4.73 1.62 19.06
10,745.85 91.66 5.87 3,724.57 3,615.57 1,762.19 7,278.27 0.00 0.00 0.00 0.00
10,894.81 89.19 0.45 3,723.47 3,614.47 1,910.86 7,286.48 4.00 -1.66 -3.64 -114.46
11,144.81 89.19 0.45 3,727.00 3,618.00 2,160.82 7,288.44 0.00 0.00 0.00 0.00
11,163.93 89.38 0.45 3,727.24 3,618.24 2,179.94 7,288.59 1.00 1.00 -0.01 -0.63
12,401.01 89.38 0.45 3,740.60 3,631.60 3,416.91 7,298.26 0.00 0.00 0.00 0.00
12,567.66 88.96 358.83 3,743.01 3,634.01 3,583.53 7,297.22 1.00 -0.25 -0.97 -104.57
13,301.55 88.96 358.83 3,756.30 3,647.30 4,317.14 7,282.30 0.00 0.00 0.00 0.00
13,330.68 88.68 358.89 3,756.90 3,647.90 4,346.27 7,281.72 1.00 -0.98 0.20 168.19
14,002.06 88.68 358.89 3,772.40 3,663.40 5,017.34 7,268.77 0.00 0.00 0.00 0.00
14,043.95 89.08 359.02 3,773.22 3,664.22 5,059.22 7,268.01 1.00 0.95 0.31. 17.81
14,402.27 89.08 359A2 3,779.00 3,670.00 5,417.44 7,261.90 0.00 0.00 0.00 0.00
14,556.00 92.15 359.01 3,777.35 3,668.35 5,571.12 7,259.26 2.00 2.00 -0.01 -0.15
14,802.64 92.15 359.01 3,768.10 3,659.10 5,817.55 7,255.02 0.00 0.00 0.00 0.00
14,878.14 92.90 358.91 3,764.77 3,655.77 5,892.97 7,253.65 1.00 0.99 -0.14 -8.16
15,103.14 92.90 358.91 3,753.40 3,644.40 6,117.63 7,249.37 0.00 0.00 0.00 0.00
15,225.29 90.46 359.04 3,749.82 3,640.82 6,239.71 7,247.17 2.00 -2.00 0.11 176.98
15,503.37 90.46 359.04 3,747.60 3,638.60 6,517.73 7,242.49 0.00 0.00 0.00 0.00
95,622.57 89.27 358.91 3,747.88 3,638.88 6,636.91 7,240.36 1.00 -0.99 -0.10 -174.07
16,403.84 89.27 358.91 3,757.80 3,648.80 7,417.98 7,225.53 0.00 0.00 0.00 0.00
16,421.26 89.10 358.96 3,758.05 3,649.05 7,435.39 7,225.20 1.00 -0.97 0.26 164.95
17,403.40 89.10 358.96 3,773.40 3,664.40 8,417.25 7,207.34 0.00 0.00 0.00 0.00
17,450.12 89.57 358.99 3,773.94 3,664.94 8,463.96 7,206.50 1.00 1.00 0.07 3.92
18,031.58 89.57 358.99 3,778.30 3,669.30 9,045.32 7,196.24 0.00 0.00 0.00 0.00
5/9/2007 3:49:38PM Page 3 of 8 COMPASS 2003.11 Build 48
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Halliburton Company HALI_I URTOt~-1
ConocoPhilfips Compass Proposal Report - Geographic
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10,369.70 77.55 1.76 3,701.28 3592.28 1,388.99 7,251.43 5,947,094.97 566,103.02 13.60 1,388.99
LZ 9 5/8" TOW @ 10370' MD, 3701 ' ND: 2059' FNL, 375' FEL - Sec36-T11 N-R10E
10,385.20 79.66 1.76 3,704.34 3595.34 1,404.18 7,251.89 5,947,110.16 566,103.37 13.60 1,404.18
10,400.00 79.66 1.76 3,707.00 3598.00 1,418.73 7,252.34 5,947,124.72 566,103.70 0.00 1,418.73
10,405.20 79.66 1.76 3,707.93 3598.93 1,423.84 7,252.50 5,947,129.83 566,103.82 0.00 1,423.84
10,456.74 82.10 2.61 3,716.10 3607.10 1,474.69 7,254.44 5,947,180.68 566,105.36 5.00 1,474.69
1J-122 1/4 Mile Heel -1J-122 MB D Heei 04/13l07
10,500.00 84.14 3.31 3,721.28 3612.28 1,517.58 7,256.66 5,947,223.59 566,107.25 5.00 1,517.58
10,600.00 88.87 4.93 3,727.37 3618.37 1,617.10 7,263.83 5,947,323.15 566,113.64 5.00 1,617.10
10,658.82 91.66 5.87 3,727.10 3618.10 1,675.66 7,269.37 5,947,381.75 566,118.72 5.00 1,675.66
10,700.00 91.66 5.87 3,725.90 3616.90 1,716.60 7,273.58 5,947,422.72 566,122.61 0.00 1,716.60
10,745.85 91.66 5.87 3,724.57 3615.57 1,762.19 7,278.27 5,947,468.34 566,126.94 0.00 1,762.19
10,800.00 90.76 3.90 3,723.43 3614.43 1,816.13 7,282.88 5,947,522.31 566,131.13 4.00 1,816.13
10,894.81 89.19 0.45 3,723.47 3614.47 1,910.86 7,286.48 5,947,617.05 566,133.99 4.00 1,910.86
10,900.00 89.19 0.45 3,723.54 3614.54 1,916.04 7,286.52 5,947,622.23 566,133.99 0.00 1,916.04
11,000.00 89.19 0.45 3,724.95 3615.95 2,016.03 7,287.31 5,947,722.21 566,133.99 0.00 2,016.03
11,100.00 89.19 0.45 3,726.37 3617.37 2,116.02 7,288.09 5,947,822.20 566,134.00 0.00 2,116.02
11,144.81 89.19 0.45 3,727.00 3618.00 2,160.82 7,288.44 5,947,867.00 566,134.00 0.00 2,160.82
1J-122 MB D CP7 04/13/07
11,163.93 89.38 0.45 3,727.24 3618.24 2,179.94 7,288.59 5,947,886.11 566,134.00 1.0~ 2,179.94
11>200.00 89.38 0.45 3,727.63 3618.63 2,216.00 7,288.87 5,947,922.18 566,134.00 0.00 2,216.00
11,300.00 89.38 0.45 3,728.71 3619.71 2,316.00 7,289.66 5,948,022.16 566,134.00 0.00 2,316.00
11,400.00 89.38 0.45 3,729.79 3620.79 2,415.99 7,290.44 5,948,122.15 566,134.00 0.00 2,415.99
11,500.00 89.38 0.45 3,730.87 3621.87 2,515.98 7,291.22 5,948,222.13 566,134.00 0.00 2,515.98
11,600.00 89.38 0.45 3,731.95 3622.95 2,615.97 7,292.00 5,948,322.12 566,134.00 0.00 2,615.97
11,700.00 89.38 0.45 3,733.03 3624.03 2,715.96 7,292.78 5,948,422.10 566,134.00 0.00 2,715.96
11,800.00 89.38 0.45 3,734.11 3625.11 2,815.95 7,293.56 5,948,522.08 566,134.00 0.00 2,815.95
11,900.00 89.38 0.45 3,735.19 3626.19 2,915.94 7,294.35 5,948,622.07 566,134.00 0.00 2,915.94
12,000.00 89.38 0.45 3,736.27 3627.27 3,015.93 7,295.13 5,948,722.05 566,134.00 0.00 3,015.93
12,100.00 89.38 0.45 3,737.35 3628.35 3,115.92 7,295.91 5,948,822.04 566,134.00 0.00 3,115.92
12,200.00 89.38 0.45 3,738.43 3629.43 3,215.92 7,296.69 5,948,922.02 566,134.00 0.00 3,215.92
12,300.00 89.38 0.45 3,739.51 3630.51 3,315.91 7,297.47 5,949,022.01 566,134.00 0.00 3,315.91
12,400.00 89.38 0.45 3,740.59 3631.59 3,415.90 7,298.25 5,949,121.99 566,134.00 0.00 3,415.90
12,401.01 89.38 0.45 3,740.60 3631.60 3,416.91 7,298.26 5,949,123.00 566,134.00 0.00 3,416.91
1J-122 MB D CP2 04/13/07
12,500.00 89.13 359.49 3,741.88 3632.88 3,515.89 7,298.21 5,949,221.97 566,133.17 1.00 3,515.89
12,567.66 88.96 358.83 3,743.01 3634.01 3,583.53 7,297.22 5,949,289.59 566,131.65 1.00 3,583.53
12,600.00 88.96 358.83 3,743.59 3634.59 3,615.86 7,296.56 5,949,321.92 566,130.74 0.00 3,615.86
12,700.00 88.96 358.83 3,745.41 3636.41 3,715.82 7,294.53 5,949,421.85 566,127.93 0.00 3,715.82
12,800.00 88.96 358.83 3,747.22 3638.22 3,815.78 7,292.50 5,949,521.78 566,125.12 0.00 3,815.78
12,900.00 88.96 358.83 3,749.03 3640.03 3,915.75 7,290.46 5,949,621.72 566,122.30 0.00 3,915.75
13,000.00 88.96 358.83 3,750.84 3641.84 4,015.71 7,288.43 5,949,721.65 566,119.49 0.00 4,015.71
13,100.00 88.96 358.83 3,752.65 3643.65 4,115.67 7,286.40 5,949,821.59 566,116.67 0.00 4,115.67
13,200.00 88.96 358.83 3,754.46 3645.46 4,215.64 7,284.36 5,949,921.52 566,113.86 0.00 4,215.64
5/9/2007 3:49:38PM Page 4 of 8 COMPASS 2003.11 Build 48
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13,301.55 88.96 358.83 3,756.30 3647.30 4,317.14 7,282.30 5,950,023.00 566,111.00 0.00 4,317.14
1J-722 MB D CP3 04/13t07
13,330.68 88.68 358.89 3,756.90 3647.90 4,346.27 7,281.72 5,950,052.12 566,110.20 1.00 4,346.27
13,400.00 88.68 358.89 3,758.50 3649.50 4,415.56 7,280.38 5,950,121.38 566,108.32 0.00 4,415.56
13,500.00 88.68 358.89 3,760.81 3651.81 4,515.51 7,278.45 5,950,221.31 566,105.61 0.00 4,515.51
13,600.00 88.68 358.89 3,763.12 3654.12 4,615.46 7,276.52 5,950,321.24 566,102.90 0.00 4,615.46
13,700.00 88.68 358.89 3,765.43 3656.43 4,715.42 7,274.60 5,950,421.17 566,100.19 0.00 4,715.42
13,800.00 88.68 358.89 3,767.74 3658.74 4,815.37 7,272.67 5,950,521.09 566,097.48 0.00 4,815.37
13,900.00 88.68 358.89 3,770.04 3661.04 4,915.33 7,270.74 5,950,621.02 566,094.77 0.00 4,915.33
14,000.00 88.68 358.89 3,772.35 3663.35 5,015.28 7,268.81 5,950,720.95 566,092.06 0.00 5,015.28
14,002.06 88.68 358.89 3,772.40 3663.40 5,017.34 7,268.77 5,950,723.00 566,092.00 0.00 5,017.34
1J-122 MB D CP4 04/13/07
14,043.95 89.08 359.02 3,773.22 3664.22 5,059.22 7,268.01 5,950,764.87 566,090.91 1.00 5,059.22
14,100.00 89.08 359.02 3,774.13 3665.13 5,115.25 7,267.05 5,950,820.89 566,089.52 0.00 5,115.25
14,200.00 89.08 359.02 3,775.74 3666.74 5,215.22 7,265.35 5,950,920.83 566,087.03 0.00 5,215.22
14,300.00 89.08 359.02 3,777.35 3668.35 5,315.20 7,263.64 5,951,020.78 566,084.54 0.00 5,315.20
14,358.87 89.08 359.02 3,778.30 3669.30 5,374.05 7,262.64 5,951,079.62 566,083.08 0.00 5,374.05
1J-1221/4 Mile Toe
14,400.00 89.08 359.02 3,778.96 3669.96 5,415.17 7,261.93 5,951,120.73 566,082.06 0.00 5,415.17
14,402.27 89.08 359.02 3,779.00 3670.00 5,417.44 7,261.90 5,951,123.00 566,082.00 0.00 5,417.44
1J-122 MB D CP5 04113l07
14,500.00 91.03 359.02 3,778.91 3669.91 5,515.15 7,260.22 5,951,220.68 566,079.56 2.00 5,515.15
14,556.00 92.15 359.01 3,777.35 3668.35 5,571.12 7,259.26 5,951,276.64 566,078.17 2.00 5,571.12
14,600.00 92.15 359.01 3,775.70 3666.70 5,615.08 7,258.51 5,951,320.59 566,077.07 0.00 5,615.08
14,700.00 92.15 359.01 3,771.95 3662.95 5,715.00 7,256.79 5,951,420.48 566,074.57 0.00 5,715.00
14,800.00 92.15 359.01 3,768.20 3659.20 5,814.91 7,255.07 5,951,520.36 566,072.07 0.00 5,814.91
14,802.64 92.15 359.01 3,768.10 3659.10 5,817.55 7,255.02 5,951,523.00 566,072.00 0.00 5,817.55
1J-122 MB D CP6 04/13/07
14,878.14 92.90 358.91 3,764.77 3655.77 5,892.97 7,253.65 5,951,598.40 566,070.04 1.00 5,892.97
14,900.00 92.90 358.91 3,763.67 3654.67 5,914.79 7,253.24 5,951,620.22 566,069.46 0.00 5,914.79
15,000.00 92.90 358.91 3,758.61 3649.61 6,014.64 7,251.33 5,951,720.04 566,066.77 0.00 6,014.64
15,100.00 92.90 358.91 3,753.56 3644.56 6,114.50 7,249.43 5,951,819.87 566,064.08 0.00 6,114.50
15,103.14 92.90 358.91 3,753.40 3644.40 6,117.63 7,249.37 5,951,823.00 566,064.00 0.00 6,117.63
1J-122 MB D CP7 04/13/07
15,200.00 90.96 359.01 3,750.14 3641.14 6,214.42 7,247.61 5,951,919.76 566,061.48 2.00 6,214.42
15,225.29 90.46 359.04 3,749.82 3640.82 6,239.71 7,247.17 5,951,945.04 566,060.85 2.00 6,239.71
15,300.00 90.46 359.04 3,749.23 3640.23 6,314.40 7,245.92 5,952,019.72 566,059.01 0.00 6,314.40
15,400.00 90.46 359.04 3,748.43 3639.43 6,414.38 7,244.23 5,952,119.68 566,056.55 0.00 6,414.38
15,500.00 90.46 359.04 3,747.63 3638.63 6,514.37 7,242.55 5,952,219.63 566,054.08 0.00 6,514.37
15,503.37 90.46 359.04 3,747.60 3638.60 6,517.73 7,242.49 5,952,223.00 566,054.00 0.00 6,517.73
fJ-122 MB D CP8 04t13/07
15,600.00 89.50 358.94 3,747.64 3638.64 6,614.35 7,240.78 5,952,319.59 566,051.53 1.00 6,614.35
15,622.57 89.27 358.91 3,747.88 3635.88 6,636.91 7,240.36 5,952,342.14 566,050.93 1.00 6,636.91
15,700.00 89.27 358.91 3,748.86 3639.86 6,714.32 7,238.89 5,952,419.54 566,048.86 0.00 6,714.32
5/9/2007 3:49:38PM Page 5 of 8 COMPASS 2003.11 Build 48
~~~~~~~~~
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Well Plan 1J-122 - S1ot 1J-122 '
__ ConocoPhillips Alaska, Inc. ` Pianned RKB @ 109.OOft (Doyon 141 (28+81))
Kuparuk River Unit Pianned RKB @ 109.OOft (Doyon 141 (28+81)j
_ - Kuparuk 1J Pad < True "
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1 J-122 L2 = I~
1 J-122 L2 (wp06)
15,800.00 89.27 358.91 3,750.13 3641.13 6,814.30 7,236.99 5,952,519.48 566,046.18 0.00 6,814.30
15,900.00 89.27 358.91 3,751.40 3642.40 6,914.27 7,235.09 5,952,619.43 566,043.50 0.00 6,914.27
16,000.00 89.27 358.91 3,752.67 3643.67 7,014.24 7,233.19 5,952,719.38 566,040.82 0.00 7,014.24
16,100.00 89.27 358.91 3,753.94 3644.94 7,114.22 7,231.30 5,952,819.32 566,038.14 0.00 7,114.22
16,200.00 89.27 358.91 3,755.21 3646.21 7,214.19 7,229.40 5,952,919.27 566,035.46 0.00 7,214.19
16,300.00 89.27 358.91 3,756.48 3647.48 7,314.17 7,227.50 5,853,019.21 566,032.78 0.00 7,314.17
16,400.00 89.27 358.91 3,757.75 3648.75 7,414.14 7,225.60 5,953,119.16 566,030.10 0.00 7,414.14
16,403.84 89.27 358.91 3,757.80 3648.80 7,417.98 7,225.53 5,953,123.00 566,030.00 0.00 7,417.98
1J-122 MB D CP9 04/13/07
16,421.26 89.10 358.96 3,758.05 3649.05 7,435.39 7,225.20 5,953,140.41 566,029.54 1.00 7,435.39
16,500.00 89.10 358.96 3,759.28 3650.28 7,514.11 7,223.77 5,953,219.11 566,027.49 0.00 7,514.11
16,600.00 89.10 358.96 3,760.84 3651.84 7,614.08 7,221.95 5,953,319.05 566,024.89 0.00 7,614.08
16,700.00 89.10 358.96 3,762.40 3653.40 7,714.05 7,220.13 5,953,418.99 566,022.29 0.00 7,714.05
16,800.00 89.10 358.96 3,763.97 3654.97 7,814.03 7,218.31 5,953,518.94 566,019.69 0.00 7,814.03
16,900.00 89.10 358.96 3,765.53 3656.53 7,914.00 7,216.49 5,953,618.88 566,017.09 0.00 7,914.00
17,000.00 89.10 358.96 3,767.09 3658.09 8,013.97 7,214.68 5,953,718.83 566,014.49 0.00 8,013.97
17,100.00 89.10 358.96 3,768.66 3659.66 8,113.94 7,212.86 5,953,818.77 566,011.89 0.00 8,113.94
17,200.00 89.10 358.96 3,770.22 3661.22 8,213.91 7,211.04 5,953,918.72 566,009.29 0.00 8,213.91
17,300.00 89.10 358.96 3,771.78 3662.78 8,313.88 7,209.22 5,954,018.66 566,006.69 0.00 8,313.88
17,400.00 89.10 358.96 3,773.35 3664.35 8,413.85 7,207.40 5,954,118.60 566,004.09 0.00 8,413.85
17,403.40 89.10 358.96 3,773.40 3664.40 8,417.25 7,207.34 5,954,122.00 566,004.00 0.00 8,417.25
1J-122 MB D CP10 04/13/07
17,450.12 89.57 358.99 3,773.94 3664.94 5,463.96 7,206.50 5,954,168.70 566,002.80 1.00 8,463.96
17,500.00 89.57 358.99 3,774.31 3665.31 8,513.83 7,205.62 5,954,218.56 566,001.53 0.00 8,513.83
17,600.00 89.57 358.99 3,775.06 3666.06 8,613.81 7,203.86 5,954,318.51 565,998.98 0.00 8,613.81
17,700.00 89.57 358.99 3,775.81 3666.81 8,713.80 7,202.09 5,954,418.47 565,996.44 0.00 8,713.80
17,800.00 89.57 358.99 3,776.56 3667.56 8,813.78 7,200.33 5,954,518.42 565,993.89 0.00 8,813.78
17,900.00 89.57 358.99 3,777.31 3668.31 8,913.76 7,198.57 5,954,618.38 565,991.35 0.00 8,913.76
18,000.00 89.57 358.99 3,778.06 3669.06 9,013.74 7,196.80 5,954,718.33 565,988.80 0.00 9,013.74
~ 18,031.58 89.57 358.99 3,778.30 ~ 3669.30 . 9,045.32 7,196.24 5,954,749.90 565,988.00 0.00 9,045.32
L2 BHL @ 18032' MD, 3778' ND : 318' FSL, 422' FEL - Sec 24-T11N-R10E - 4 1/2" -1J-122 MB D Toe 04l13/07
5/9/2007 3:49:38PM Page 6 of 8 COMPASS 2003.11 Build 48
~~~~~~~~~
~ ~
~ ' Halliburton Company HALL.IBURTQIV
ConocoPhillips Compass Proposal Report - Geographic
Alaska Sperry Drililns Sorvicros
3,778.30 1J-122 MB_D_Toe 04/13/07 9,045.32 7,196.24 5,954,749.90 565,988.00
- Point
3,778.30 1J-122 1/4 Mile Toe 9,045.32 7,196.24 5,954,749.90 565,988.00
- Circle (radius 1,320.00)
3,781.10 1J-122 MB_D_Toe 02l01/07 9,004.02 7,311.28 5,954,709.51 566,103.34
- Point
3,753.40 1J-122 MB_D_CP7 04/13/07 6,117.63 7,249.37 5,951,823.00 566,064.00
- Polygon
Point 1 0.00 0.00 5,951,823.00 566,064.00
Point 2 400.17 -6.87 5,952,223.00 566,054.00
3,773.40 1J-122 MB_D_CP10 04/13/07 8,417.25 7,207.34 5,954,122.00 566,004.00
- Polygon
Point 1 0.00 0.00 5,954,122.00 566,004.00
Point 2 627.17 -11.10 5,954,749.00 565,988.00
3,747.60 1J-122 MB_D_CP8 04/13/07 6,517.73 7,242.49 5,952,223.00 566,054.00
- Polygon
Point 1 0.00 0.00 5,952,223.00 566,054.00
Point 2 900.31 -16.97 5,953,123.00 566,030.00
3,716.10 1J-122 MB_D_Heel 04/13/07 1,388.01 7,251.40 5,947,094.00 566,103.00
- Polygon
Point 1 0.00 0.00 5,947,094.00 566,103.00
Point 2 772.88 37.05 5,947,867.00 566,134.00
3,740.60 1J-122 MB_D_CP2 04/13/07 3,416.91 7,298.26 5,949,123.00 566,134.00
- Polygon
Point 1 0.00 0.00 5,949,123.00 566,134.00
Point 2 900.35 -15.97 5,950,023.00 566,111.00
3,756.30 1J-122 MB_D_CP3 04/13/07 4,317.14 7,282.30 5,950,023.00 566,111.00
- Polygon
Point 1 0.00 0.00 5,950,023.00 566,111.00
Point 2 700.38 -13.53 5,950,723.00 566,092.00
3,757.80 1J-122 MB_D_CP9 04/13/07 7,417.98 7,225.53 5,953,123.00 566,030.00
- Polygon
Point 1 0.00 0.00 5,953,123.00 566,030.00
Point2 999.39 -18.19 5,954,122.00 566,004.00
3,727.00 1J-122 MB_D_CP1 04/73/07 2,160.82 7,288:44 5,947,867.00 566,134.00
- Polygon
Point 1 0.00 0.00 5,947,867.00 566,134.00
Point 2 1,256.18 9.82 5,949,123.00 566,134.00
3,772.40 1J-122 MB_D_CP4 04/13/07 5,017.34 7,268.77 5,950,723.00 566,092.00
- Polygon
Point 1 0.00 0.00 5,950,723.00 566,092.00
Point 2 400.17 -6.87 5,951,123.00 566,082.00
3,779.00 1J-122 MB_D_CP5 04/13/07 5,417.44 7,261.90 5,951,123.00 566,082.00
- Po~on
5/9/2007 3:49:38PM Page 7 of 8 COMPASS 2003.11 Build 48
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Point 1 0.00 0.00 5,951,123.00 566,082.00
Point 2 400.27 -6.87 5,951,523.00 566,072.00
3,716.10 1J-122 1/4 Mile Heel 1,388.01 7,251.40 5,947,094.00 566,103.00
- Circle (radius 1,320.00)
3,768.10 1J-122 MB_D_CP6 04/13/07 5,817.55 7,255.02 5,951,523.00 566,072.00
- Polygon
Point 1 0.00 0.00 5,951,523.00 566,072.00
Point 2 300.57 -5.65 5,951,823.00 566,064.00
4,204.50 2,265.30 13-3/8 16
10,368.72 3,701.06 9-5/8 12-1/4
18,031.57 3,778.30 4-1/2 6-3/4
--- - nr >~~ ~~
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1,650.33 48.69 101.47 1,504.91 -126.53 494.54 Pfrost
1,893.72 56.21 100.76 1,657.88 -163.36 679.93 K15
3,017.64 76.48 99.31 1,987.83 -340.40 1,733.08 T3
4,204.89 76.48 99.31 2,265.39 -527.16 2,872.22 Casing Pt
7,243.24 76.48 81.22 2,975.71 -920.57 5,792.30 Ugnu C
8,524.50 76.48 39.32 3,275.25 -316.48 6,850.16 Ugnu B
8,854.16 76.48 28.54 3,352.32 -50.94 7,028.82 Ugnu A
9,663.97 76.48 2.06 3,541.64 701.76 7,234.77 K 13
10,368.70 77.41 1.76 3,701.06 1,388.01 7,251.40 W Sak D
5/9/2007 3:49:38PM Page 8 of 8 COMPASS 2003.11 Build 48
~~~ ~ ~
~
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~ Halliburton Company HALt..tBURTClN
~~~~'~~ Compass Proposal Report - Geographic
qla.ska Spsrry Driliing ~srvico~
~
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CanocoPh i I I ~ ps
Alaska
~
Plan: 1J-122 L2 (wp06)
Sperry Drilling Services
Anticollision Summary
09 May, 2007
ConocoPhillips Alaska, Inc.
Kuparuk River Unit
Kuparuk 1J Pad
Plan 1J-122
1J-122 L2
Local Coordinate Origin: Centered on Well Plan 1J-122 - Slot 1J-122
Viewing Datum: Planned RKB @ 109.OOft (Doyon 141 (28+g1))
NDs to System: N
North Reference: True
Unit System: API - US Survey Feet
HA~L~ V QiT
Spsrry Drilltng Service~
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SURVEY PROGRAM
Date: 2007-0417T00:00:00 VaGdated: Yes Version:
Depth FromDepth To Survey/Plan Tool
28.00 800.00 C~GYRO-SS
800.0010368.70 MWD+IFR-AK-C~SC
10368J018031.58 IJ-122 L2 (wp06) MWI7+IFR-Ali-CAZ-LC
0
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iso
Engineering
Calculation Method: Minimum Curvature
Error System: ISCWSA
Scan Method: Trav. Cylinder North
Error Surtace: Elliptical Conic
Warning Method: Rules Based
so
Travelling Cylinder Azimuth (TFO+AZI) [°J vs Centre to Centre Separation ~300 fUin~
REFERENCE INPORMATION
Co-ordinate (N/E) Reference: Well Plan 1J•122 • Slot 1J-122, True North
Vertical (ND) Reference: Planned RKB @ 109.OOR (Doyon 141 (28+81))
Section (VS) Reference: Slot - 1J-122(O.OON, O.OOE)
Measured Depth Reference: Planned RKB ~ 709.OOft (Doyon 141 (28+87~)
Calculation Method: Minimum Curvature
COMPANY DETAILS: ConocoPhillips Alaska, Inc.
From Colour To MD I
0 10250
10250 10500
10500 10750
io~so iiooo
iiooo ~i2so
11250 11500
11500 11750
11750 12000
12000 12250
12250 12500
12500 12750
12750 13000
13000 13250
13250 13500
13500 13750
13750 14000
14000 14250
14250 14500
14500 14750
14750 15000
15000 15250
15250 - --"' 15500
15500 75750
15750 16000
16000 16250
16250 16500
16500 16750
16750 17000
17000 17250
17250 17500
17500 17750
17750 - '- 18000
18000 18250
18250 18500
18500 18750
NAD 27 ASP Zone 4: WELL DETAILS: Plan 1J-122
Ground Level: 81.00
+N/-S +FJ•W Northing Easting Latittude Longitude Slot
0.00 0.00 5945649.48 558863.37 70°15'43.595N 149°31'26.931W 1J-122
90
Irrc PZi ND ~W-S ~E/-W ~l~p TFVw VSac T~r9at
]1.41 1.I8 310108 1JB801 ]ISt.iO OW
)B66 1.'!6 ~]00.31 1d04.tB i25189 1360 000 138801
0.00 1401.18
]988 1]6 3"!0]93 1d2J84 125350 0.00 0.00 143361
81.68 58"/ )]1).10 18]SBB 'R89.3] 5W
91fi6 5.8] 3]20.5] 1163.19 T118.3] 000 18.08 16]5.68
000 1]63.f9
89.19 0.<5 J]23.9] 1910.86 T186.96 9.00 .11448 1910.86
09.19 O.CS 3]2].00 21G0.83 1'18B.N 0.00
89.38 0.95 313).l4 ]1I9.94 ]188.59 100 000 ]1B0.8] 11122M8 D_CP10/11Y0]
-0fi] ]t]9.9G -
89.38 0.0.5 31<O.fiO 3C16.81 ]]BB.]8 0.00
89.96 J58.83 ~]C30t 35835] ]19].23 1.00 OW JC1fi81 1111IMB ~ CP301I1101
-101.5) JSBJ.SJ
88.98 359.83 3I58.30 43t)t4 Ylei](1 000 000 I]t].1< 1J-1]]MB D CGJOUl10l
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8868 35888 3]56.90 AW6.31 ]381.I3 t0U
6868 ~5889 3])2C0 501]~C ]268.n 0.00 IBB.19 43C6.3)
0.00 501].34 1J-11]MBDCP4W1Y0]
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89.08 ~59.03 3'/]3.13 `#.9.22 'I26801 t00
9908 3S901 3]]900 SC1)d< ]36180 0.0~ 1].91 5059.32
0.00 541]6C 1J-1]]MBDCPSOUIYO)
92.15 359.01 3)])35 55)1.13 ]359.I6 I.00
92.15 359.01 3]68.10 581]55 ]355.03 0.00 -0.~5 5511.1]
0.00 581).55 1J-11]MB D CP804I110]
--
9290 35891 3]64]1 589191 ]35J.65 1.00
9290 358.91 3]53.40 611].6] ]349.3] OW -B.1B 5893.9]
000 611]6] 1J-133MBOCP]OII110]
--
90dfi 35904 3]49.83 6339.]1 ]34).1) 10~ 1I89B 6]]9.I1
904fi 3590< 3]<~60 651].]3 1343C9 000
99.2) 358.91 3]4)88 663691 ]240]6 1.00 000 851].]] IJ-1I3MB O CPB00/13I0]
-1)4.0] 6636.91
99.2) J58.91 3]5)80 ]C1]98 ]22553 400 0.00 ]41i98 1J-133MBOCPBOUIYO]
89.10 358.96 3]SBM 1CJ5~9 ]22520 100
89.10 358.% 31]340 8111.35 130].3C Q0p i6d.95 ]<3539
0.00 Bd1]]5 1J-13]MB_~CP1000I110'!
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89.5] 358.99 3]]B.]0 9DI5.]] ]186.I0 0.00 3.93 BO6]%
000 904532 1J-123MB D Toe0N1J10]
ANTI-COLLISION SETTINGS
Interpolation Method: MD Interval: 50Stations
Depth Range From: 10368.7 To 18031.5806479812
Maximum Range:2000.35806479812
Reference: Plan: 1J-122 L2(wp06)
~
180
Travelling Cylinder Azimuth (TFO+AZI) ~°J vs Centre to Centre Separa[ion ~30 ftlin~
~ Halliburton Company~
Anticollision Report
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ConocoPhillips
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ConocoPhillips Alaska, Inc.
Kuparuk River Unit
Kuparuk 1J Pad
Plan: 1J-122 L2 (wp06)
1/4 Mile Pool Scan
Sperry Drilling Services
May 1, 2007
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HALLIBURTON
Drilling and Formation
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1~-122LlDrilling Hazard~Summarv
(SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS)
Production Hole
Hazard Risk Level Miti ation Strate
Abnormal Reservoir Low Stripping drills, shut-in drills, inereased
Pressure ~ mud wei ht.
Stuck Pipe Low Good hole cleaning, PWD tools, hole
o ener runs, decreased mud wei ht
Lost Circulation Low Reduced um rates, mud rheolo , LCM
Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip
~ sheets , um in out, backreamin
~ ~ ~ ~ ~ ~ ~~ ~ 1J-122L2 Drilling Hazards Summary
5/24/2007 1:5T.00 PM
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20" 94.0# x 34" Insulated Conductor, K-55, set at+/- 80'
133/8", 68#, BTC "
Shoe set @ 4204' MD,
2265' ND
Tubing String /
41/2" 12.6#, L-80, IBTM
3.958" ID, 3.833" Drift
/ Seal
7" X 9518" ZXP Liner psxmbly
Top Packer wl Hold 4.75" Seal OD
Downs
Tubing, 4712", 12.6#, IBTM, Special Drift to +/- 500'
3.875" DB Nipple, for Possible SSSV, +/- 500'
GLM, Camco KBMG, 4112" X 1"
GLM, Camco KBMG, 41/2" X 1"
Sliding Sleeve, w/ 3.81" DB Nipple, +/-1 jt above seals
Casing Sealbore Receplacle, 20'
ConocoPhillip5
West Sak 9-5/8" HBB Injector
1 J-122
Tri-Lateral Completion
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LateralE odule(LEIII) ~ ~~~ 1\~
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D-sand Window
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4112" 11.6# L-80 Slotted
Payzone ECP Liner Every Other Joint
`~ ~ ~ ~ ~ ~ .. i 4-112" Guide Shoe
~ 41/2" Liner Shoe, 11.6#, L-80
7" Tieback Sleeve Set ~ 18031' MD~377,8'-fi'V
7" X 9-518" Seal Bores `
Model'B' HOOK Hanaer 3.68" ID
7" % 9-518" ZXP Liner Top
Packer wl Hold Downs
Assemblv
,,..-- 7" X 9S18" ZXP Liner Top
Packer with Hold Downs
Casing Sealbore Receptaele
475" ID
Orienting Profile
Automati~ Alignment of LEM
Positive Latching Collet
~ Indicates Correct Location
~ Seal Bore for Latenl
Isolation - 3.68" ID
~ Access Window
Positive Latenl Access Via
Thru-Tubing DiverDer
Seal Bore tor Lateral
Isolation - 3.68" ID
~
Isolation Seal Asembly
4.75" Seal OD 3.875" SeaIID
Casing Sealbore
Receptacle
20' LengM
Seal Assembly ~------ ._
475" Seal OD ,~^a ~ "~ - . .
Laterel ~niryiVlodule(LEM)
_-" \~-\~a ~'~
B-sand Window
at 10779' MD, s~ar Tv~ 'B' Sand Lateral
f 4-112" 11.6# L-80 Slotted
Payzone ECP Liner Every Other Joint
. -,?t 4
~ "---- 1
7" Tieback Sleeve
4-112" bent muleshce
41/2" 12.6# Tubin
3.833" Drift
3.958" ID r
~
7" X 9-518" 2XP
LinerTopPacker ~
with Hold Downs
7" X 9-5/8" Flex Lock
Liner Hanger I Packer Assembly at Line~ Hanger
•1-10880' MD, 3787 ND
Casing Sealbore Receptacle,
20' Length
9-5/8" 40 # Casing, L-80, BTCM, Set
0 Baker Hu9hes 1005. T~IS Eocument maynot be reproEUCeE ordlstrlEU~eE, In v.nole or In parl, In any iorm or by at @ 11878' MD, 3969' ND (84 deg)
any mems elecROnlc or mechanleal, InGUtling photoeopying, re<ordlnp, or by any Inbrmatlon ston9e antl
retrleval syshmnow Mnown w ~ereaRer Invenfed, xiTOUtwrltten pertN55lon from Baker Hug~es Inc.
7" X 9-5/8" HOOK Hanger
Mainbore Drift: 7.00"
Mainbore Drift, with diverter: 6.25"
Latenl Orift, no diverter or LEM: 6.28"
Wtenl Drif4 wl diverter, no LEM: 5.12"
LaMrallMainbore Diverter OD: 8.50"
41/2" Lateral Entry Module
Mainbore Drift: 3.68"
Mainbore Drift, wl isolation sleeve: 2,50"
Lateral Drift, wl coil diverter: 3.00"
OD of Diverter and Sleeve: +/- 3.61
Diverter and Sleeve Length: +l- 79'
5-1/2" Casing Shoe, 15.5 #, L-80 BTC
Set @ 18054' MD, 3990' ND
sw~Rf^
~wwx~s
Baker Oil Tools
As Planned
With Diverters and Isolation
Lateral Access DiverOer laterol Isolation Diverter
GS Running ToolString Installed Installed
(3.00" Lateral Drl([) (2.50" ID Mainbore DrIR)
'GS' Prohle for
Coil Connector /Running/Retneving ~ i i
(1.00' LengM)
Snap InlSnap Out ~
~Poaitive Loeating~
rBack Pressure Valve Collet
~1.80' Length)
Lateral Isolation ~'
~ Flow-Thru Swivel Seals
(135' Length) ~Lateral Divener
Hydraulic
' Ramp
' ~
Disconnect Isolation/ Mainbore~ I
('I.50' Length) Diverter Sleeve
~
en ~~
~SO'L
gth) Latenllsolation
'i I
6.85 ft Approx. Seals
OAL' ~
may De required in hig~ly devi ated 18.5' Oiverter LengN 78.5 Sleeve Length +1'
Guide Shoe
41/2" Liner Shoe, 71~, L-80 BTC
Set @ 18039' MD, 384j' ND
Seal Assembly
4.75" Seal OD
'A' Sand Undulatinc~Lateral
5-712" 15.5 # L~0 Slotted
~ Liner Every OMer Joint 5-~l]" Eccentric
1Guide Shoe
.
•
RE: IJ-122 Again
~
~
Subject: RE: 1J-122 Again
From: "Reilly, Patrick J" <Patrick.J.Reilly@conocophillips.com>
Date: Mon, 11 Jun 2007 10:15:25 -0800
To: Thomas Maunder <tom maunder@admin.state.ak.us>
Tom,
The LEM is tested to 2500 psi for 30 minutes if the well is an injector
and it is the uppermost LEM. I will change future permit applications
to reflect that instruction.
I apologize for the dimension discrepancy. The TVp of the Ll window is
supposed to read 3787 as you noted below. 3969 is the TVD for the
intermediate casing. 3787 is the value indicated on the Halliburton
paperwork and the Baker Oil Tools schematic.
Thanks.
Pat Reilly
ConocoPhillips Alaska Drilling & Wells
(907) 265-6048 WORK
(907) 244-5558 CELLULAR
(918) 662-8284 FAX TO E-MAIL
Patrick.J.Rei11y@conocophillips.com
-----Original Message-----
From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us]
Sent: Sunday, June 10, 2007 2:33 PM
To: Reilly, Patrick J
Subject: Re: 1J-122 Again
Pat,
Would you please check the tvd on the Ll window. The tvd listed on the
permit sheet is 3969 which is the same as the tvd of the casing shoe.
Lookinq at page 3 of 8 of the Halliburton document it would appear the
the correct tvd is 3787 at 10779.6 md. Would you please confirm?
Thanks,
Tom Maunder, PE
AOGCC
Thomas Maunder wrote, On 6/10/2007 2:07 PM:
Pat,
One quick question. when the LEM is run in step 38, is the casing x
DP annulus tested at that time? If so, that is an instruction that
should be mentioned.
Call or message with any questions.
Tom Maunder, PE
AOGCC
>
I 1 of 1 6/11/2007 1:08 PM
~
~
~'RA~YS1dII~'~'A~, L~T"'a"Ela C'H~CKLIST
WEi,L N~1:~[E - ~/~-~C ~od - ~ZZ ~.. Z~
P'd'D# ~ ~ - ~ ~ Z,,.
_____ Development ~Service Ex torat
lYoa-Coaventional Wett P °~'~ Stratigraphic "Test
Circle Appropriate Letter / Paragraphs [o be Inciud~d in 1'ransmitta( Letter
Ct-~CK
w'HAT
~PPLIES
ADD-ONS
(OPTION S)
~ ~ MliLTI LATERAL
r
i (IF (ast two digits
~ API rtumber
; between 60-69)
T'EXT FOR APPROVqL LETTER
i
! The permit i; for a new we{16ore segment of existing
~ weI! /`i~~ ~.J "/Z. Z ;
in I Permit : o..Z(~7 b
are ~ , •Z 7ZJAP[ No. ~0-6~- 2 3,3 _~ ~ j
shou[d cont i n u e t o b e r e p o r t e d a s a funcrion of the ~
; origina! 4P[ nurnber stated above.
~ PILOT E{OLE
~ I j[n accordance with 20 A.~C 25.OU~(~, a!! record;, data and Io~s
~ acquired for the pilot hole m
t b
~ i us
e cleacly differentiated in both
; wel! narcie (
I ; r(~~- P[-n and API numbec
i
~ -_, from records, data and logs
, acquired for welt
' ~ SPACIlYG
; ; EXCEPTION ~
The permit is approved subje~t to full compliattce with 20 AAC +
25
Oi5
A
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~ ! ~
.
.
pprova
to pecforate and roduce / iai,ect is contingent ;
I upon issuan
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a conservatioa ocder approving a spacing ~
I exception.
'
~ ~ liabitity of any protest to the s pacin g e x c e p t i o n t h a t m a y o c c u rs ~e j
; DRY DCTCH
~ '
~ A!l dry ditch sample sets submitted to th
-E
i SAMPLE
' ~ e
ommission must be in ;
i no greater tl~an 3a' sample intervafs from be(ow the
f
~
~ ~
' ~
~ ~
rom whece samp(es are Frst caught and 14' sampie
R~en;als ;
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i
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j 1~ton-Conventionat
W' ~
i P~e~e note the fo!lowing speciai condition of thi;
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Production or production cesti
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zll
; ng o
I
coa! bed methane is not allowed ~
~ for (ciacne of weI!) until after (Cocnnanv 1V'ame~ has designed and I
~ ;
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; ore water quatity and
i
I
~ ~
~ quant
ty. (Companv 1Yame} must contact the
' 'C°g~ i
~ Commission to obtairi advance approva! of such wacer we(I testing ,
Rev: I 2~;06
C:~ joQy~transmitta!_checklist
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. •
Well History File
APPENDIX
InfoRnation of detailed nature that is not
parlicula~ly geRnane to the Well PeRnitting Process
but is part of the history file.
To improve the readability of the We~l History file and to
sim.plify finding information, information of this
nature is accumulaled at the end of the file under APPENDIX.
No special etiort has been made to chronologically
organize this category of information.
; i •
17122~20072520075SN.txt
Sperry-sun ~rillin services
LIS Scan Uti~ity
$Revision: 3 $
LisLib $Revision: 4 $
wed oct 03 12:12:01 2007
Reel Header
Service name .............LISTPE
~ate . ...................07/10/03
Ori 9in ...................STS
Reel Name. .... ........UNKNOWN
Continuation Number......01
Previous Reel Name.......UNKNOWN
Comments .................STS ~IS writing ~ibrary. Scientific Technical Services
Tape Header
Service name .............LISTPE
Date . ...................07/10/03
Origin ...................STS
Tape Name. .... ........UNKNOWN
Continuation Number......01
Previous Tape Name.......UNKNOWN
Comments .................sTS ~IS writing ~ibrary. Scientific Technical services
Physical EOF
Comment Record
TAPE HEADER
west Sak
MWD/MAD LOGS
#
WELL NAME:
API NUMBER:
OPERATOR:
LOGGING COMPANY:
TAPE CREATION DATE:
#
JOB DATA
JOB NUMBER:
LOGGING ENGINEER:
OPERATOR WITNESS:
JOB NUMBER:
LOGGING ENGINEER:
OPERATOR WITNESS:
#
SURFACE LOCATION
SECTION:
TOWNSHIP:
RANGE:
FNL:
FSL:
FEL:
FWL:
1J-122 L2
500292335961
ConocoPhillips Alaska, znc.
Sperry Drilling Services
03-OCT-07
MWD RUN 2 MWD RUN 3 MWD RUN 10
W-0005034903 w-0005034903 w-0005034903
P. ORTH T. GALVIN P. ORTH
G. WHITLOCK D. GLADDEN P. WILSON
MWD RUN 11
w-0005034903
T. GALVIN
D. GLADDEN
35
11N
lOE
1836
2347
Page 1
~b~ -o`~-a ~ r 53 ~Y
1
3 ~ ~
1J122L2007252007SSN.tXt
ELEVATION (FT FROM MSL O)
KELLY BUSHING:
DERRICK FLOOR: 109.00
GROUND LEVEL: 81.00
#
WELL CASING RECORD
OPEN HOLE CASING DRILLERS
BIT SIZE (IN) SIZE (IN) DEPTH (FT)
1ST STRING 12.250 13.375 3640.0
2ND STRING 8.500 9.625 10332.0
3RD STRING
PRODUCTION STRING
#
REMARKS:
1. ALL DEPTHS ARE MEASURED DEPTHS UNLE55 OTHERWISE
NOTED. THESE DEPTHS ARE
BIT DEPTHS.
2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (ND).
3. THIS WELLBORE WAS DRILLED FROM A WHIPSTOCK, THE TOP
OF WHICH WAS AT
10332'MD/3689~ND, WITHIN THE RUN 3 INTERVAL OF THE
1J-122 WELLBORE. THE
WHIPSTOCK WAS POSITIONED, THE WINDOW WAS MILLED, AND
A 8IT OF RAT HOLE
WAS DRILLED DURING MWD RUN 10. ONLY SROP DATA ARE
PRESENTED FOR THIS RUN.
4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE
PRESENTED.
5. MWD RUNS 2,3,11 COMPRISED DIRECTIONAL, DUAL GAMMA RAY
(DGR) UTILIZING
GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE
RESISTIVITY PHASE-4
(EWR4), PRESSURE WHILE DRILLING (PWD), AND GEO-PILOT
ROTARY STEERABLE
BHA (GP). MWD RUN 11 ALSO INCLUDED AT-BIT GAMMA
(ABG). ABG DATA WERE
APPENDED TO THE DGR DATA FROM 18041.5~MD TO
18073.5'M~.
6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL,
DATED 12/16/04, FROM
M. WERNER (CPAI) TO R. KALISH (SDS). MWD DATA ARE
CONSIDERED PDC.
7. MWD RUNS 1-3,10,11 REPRESENT WELL 1J-122 L2 WITH
API#: 50-029-23359-61.
THIS WELL REACHED A TOTAL DEPTH (TD) OF
18078'MD/3797'TVD.
SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING.
SGRC = SMOOTHED GAMMA RAY COMBINED.
SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA
SHALLOW SPACING).
SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW
SPACING).
SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM
SPACING~.
SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP
Page 2
~ ~
1J122L2007252007SSN.txt
SPACING).
SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING).
$
File Header
Service name... ....:..STSLIB.001
Service Sub Level Name...
version Number. ........1.0.0
~ate of Generation.......07/10/03
Maximum Physical Record..65535
File Type. ............LO
Previous File Name.......STSLIB.000
Comment Record
FILE HEADER
FILE NUMBER:
EDITED MERGED MWD
~epth shifted and
DEPTH INCREMENT:
#
FILE SUMMARY
PBU TOOL CODE
GR
RPX
RPS
RPM
FET
RPD
ROP
$
1
clipped curves; all bit runs merged.
.5000
START DEPTH
3608.5
3630.0
3630.0
3630.0
3630.0
3630.0
3644.5
STOP DEPTH
18073.5
18033.0
18033.0
18033.0
18033.0
18033.0
18078.0
#
BASELINE CURVE FOR SHIFTS:
CURVE SHIFT DATA (MEASURED DEPTH)
--------- EQUIVALENT UNSHIFTED DEPTH ---------
BASELINE DEPTH
$
#
MERGED DATA SOURCE
PBU TOOL CODE
MWD
MWD
MWD
MWD
$
BIT RUN NO MERGE TOP MERGE BASE
2 3608.5 9721.0
3 9678.0 10332.0
10 10332.5 10391.0
11 10391.0 18078.0
#
REMARKS: MERGED MAIN PASS.
$
#
Data Format Specification Record
Data Record Type... ..........0
~ata Specification Block Type.....0
Log~ing Direction .................DOwn
optical log depth units...........Feet
~ata Reference Point ..............undefined
Frame Spacing ........ ............60 .lIN
Max frames per record .............undefined
,4bsent value ......................-999
~epth Units ................ .....
~atum 5pecification Block sub-type...0
Name service order units Size Nsam Rep Code offset Channel
DEPT FT 4 1 68 0 1
RPD MWD OHMM 4 1 68 4 2
RPM MWD OHMM 4 1 68 8 3
Page 3
~ •
1J122L2007252007SSN.tXt
RPS MWD OHMM 4 1 68 12 4
RPX MWD OHMM 4 1 68 16 5
FET MWD HOUR 4 1 68 20 6
GR MWD API 4 1 68 24 7
ROP MWD FT/H 4 1 68 28 8
First Last
Name Service Unit Min Max Mean Nsam Reading Reading
DEPT FT 3608.5 18078 10843.3 28940 3608.5 18078
RPD MwD OHMM 2.69 2000 37.912 28807 3630 18033
RPM MwD OHMM 5.07 94.9 33.2822 28807 3630 18033
RPS Mw~ OHMM 3.81 1301.51 33.8223 28807 3630 18033
RPx MwD OHMM 1.27 264.97 37.2604 28807 3630 18033
FET MWD HOUR 0.12 597.74 1.34731 28807 3630 18033
GR MwD API 19 124.04 65.7831 28931 3608.5 18073.5
RoP MwD FT/H 0.1 504.03 240.535 28868 3644.5 18078
First Reading For Entire File..........3608.5
~ast Reading For Entire File...........18078
File Trailer
Service name... .......STSLIB.001
Service Sub Level Name...
version Number. ........1.0.0
oate of Generation.......07/10/03
Maximum Physical Record..65535
File Type ................LO
Next File Name...........STSLIB.002
Physical EOF
File Header
Service name... .......STSLIB.002
Service Sub Level Name...
version Number. ........1.0.0
~ate of Generation.......07/10/03
Maximum Physical Record..65535
File Type. ............LO
Previous File Name.......STSLIB.001
Comment rtecord
FILE HEADER
FILE NUMBER: 2
RAW MWD
Curves and log header data for each bit run in separate files.
BIT RUN NUMBER: 2
DEPTH INCREMENT: .5000
#
FILE SUMMARY
VENDOR TOOL CODE START DEPTH STOP DEPTH
GR 3608.5 9685.0
RPD 3630.0 9677.5
RPx 3630.0 9677.5
RPM 3630.0 9677.5
FET 3630.0 9677.5
RPS 3630.0 9677.5
ROP 3644.5 9721.0
Page 4
s
~
1J122L20072520075SN.txt
$
#
LOG HEADER DATA
DATE LOGGED: 27-JUN-07
SOFTWARE
SURFACE SOFTWARE VERSION: Insite
DOWNHOLE SOFTWARE VERSION: 74.11
DATA TYPE (MEMORY OR REAL-TIME): Memory
TD DRILLER (FT): 9721.0
TOP LOG INTERVAL (FT): 3643.0
BOTTOM LOG INTERVAL (FT): 9721.0
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
MINIMUM ANGLE: 69.4
MAXIMUM ANGLE: 79.3
#
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE TOOL NUMBER
DGR DUAL GAMMA RAY 132484
EWR4 ELECTROMAG. RESIS. 4 77613
$
#
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN): 12.250
DRILLER'S CASING DEPTH (FT): 3640.0
#
BOREHOLE CONDITIONS
MUD TYPE: Other
MUD DENSITY (LB/G): 9.50
MUD VISCOSITY (S): 49.0
MUD PH: 9.1
MUD CHLORIDES (PPM): 150
FLUID LOSS (C3): 4.9
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT): 3.800 72.0
MUD AT MAX CIRCULATING TERMPERATURE: 2.540 111.0
MUD FILTRATE AT MT: 5.000 72.0
MUD CAKE AT MT: 3.000 72.0
#
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
#
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
#
REMARKS:
$
#
Data Format Specification Record
Data Record Type... ..........0
Data specification Block Type.....0
Log~ing Direction .................DOwn
optical log depth units...........Feet
~ata Reference Point ..............undefined
Frame Spacing....... ............60 .lIN
Max frames per record .............undefined
Absent value ......................-999
Depth Units. . .. .. .....
~atum specification Block sub-type...0
Name service order units size Nsam Rep Code offset channel
Page 5
~ ~
1J122L2007252007SSN.tXt
DEPT FT 4 1 68 0 1
RPD MWD020 OHMM 4 1 68 4 2
RPM MWD020 OHMM 4 1 68 8 3
RPS MWD020 OHMM 4 1 68 12 4
RPX MWD020 OHMM 4 1 68 16 5
FET MWD020 HOUR 4 1 68 20 6
GR MWD020 API 4 1 68 24 7
ROP MWD020 FT/H 4 1 68 28 8
First Last
Name Service Unit Min Max Mean Nsam Reading Reading
DEPT FT 3608.5 9721 6664.75 12226 3608.5 9721
RPD MWD020 OHMM 2.69 2000 13.8095 12096 3630 9677.5
RPM MWD020 OHMM 5.07 51.95 11.6633 12096 3630 9677.5
RPS MwD020 OHMM 3.81 1301.51 11.377 12096 3630 9677.5
RPx MwD020 OHMM 1.27 45.01 9.60062 12096 3630 9677.5
FET MwD020 HOUR 0.12 104.12 0.744482 12096 3630 9677.5
GR Mw~020 API 19 118.52 63.2932 12154 3608.5 9685
ROP MwD020 FT/H 6.45 504.03 226.4 12154 3644.5 9721
First Reading For Entire File..........3608.5
~ast Reading For Entire File...........9721
File Trailer
Service name... .......STSLIB.002
Service Sub Level Name...
version Number. ........1.0.0
~ate of Generation.......07/10/03
Maximum Physical Record..65535
File Type ................~o
Next File Name...........STSLIB.003
Physical EOF
File Header
Service name... .......STSLIB.003
Service Sub Level Name...
version Number. ........1.0.0
~ate of Generation.......07/10/03
Maximum Physical Record..65535
File Type. ............~0
Previous File Name.......STSLIB.002
Comment Record
FILE HEADER
FILE NUMBER: 3
RAW MWD
Curves and log header data for each bit run in separate files.
BIT RUN NUMBER: 3
DEPTH INCREMENT: .5000
#
FILE SUMMARY
VENDOR TOOL CODE START DEPTH
FET 9678.0
RPx 9678.0
RPM 9678.0
RPS 9678.0
STOP DEPTH
10332.0
10332.0
10332.0
10332.0
Page 6
~
~~
1J122L20072520075SN.txt
RPD 9678.0 10332.0
GR 9685.5 10332.0
ROP 9721.5 10332.0
$
#
LOG HEADER DATA
DATE LOGGED: 29-JUN-07
SOFTWARE
SURFACE SOFTWARE VERSION: Insite
DOWNHOLE SOFTWARE VERSION: 74.11
DATA TYPE (MEMORY OR REAL-TIME): Memory
TD DRILLER (FT): 10332.0
TOP LOG INTERVAL (FT): 9721.0
BOTTOM LOG INTERVAL (FT): 10332.0
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
MINIMUM ANGLE: 77.6
MAXIMUM ANGLE: 85.3
#
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE TOOL NUMBER
DGR DUAL GAMMA RAY 132484
EWR4 ELECTROMAG. RESIS. 4 77613
$
#
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN): 12.250
DRILLER'S CASING DEPTH (FT): 3640.0
#
BOREHOLE CONDITIONS
MUD TYPE: Other
MUD DENSITY (LB/G): 9.50
MUD VISCOSITY (S): 43.0
MUD PH: 9.0
MUD CHLORIDES (PPM): 50
FLUID LOSS (C3): 4.5
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT): 3.800 72.0
MUD AT MAX CIRCULATING TERMPERATURE: 2.460 115.0
MUD FILTRATE AT MT: 5.000 72.0
r~Ufl CAKE AT n~: 3.000 72.0
#
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
#
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
#
REMARKS:
$
#
Data Format Specification Record
Data Record Type... ..........0
Data Specification Block Type.....0
Log~ing Direction .................DOwn
Optical log depth units...........Feet
~ata Reference Point ..............undefined
Frame Spacing....... ............60 .lzw
Max frames per record .............undefined
absent value ......................-999
~epth units .......................
Page 7
• .
1J122L2007252007SSN.tXt
~atum Spe cificat ion Block sub-type...0
Name service order units size Nsam Rep Code offset Channel
DEPT FT 4 1 68 0 1
RPD MWD030 OHMM 4 1 68 4 2
RPM MWD030 OHMM 4 1 68 8 3
RPS MWD030 OHMM 4 1 68 12 4
RPX MWD030 OHMM 4 1 68 16 5
FET MWD030 HOUR 4 1 68 20 6
GR MWD030 API 4 1 68 24 7
ROP MWD030 FT/H 4 1 68 28 8
First Last
Name Service Unit Min Max Mean Nsam Reading Reading
DEPT FT 9678 10332 10005 1309 9678 10332
RPD MwD030 OHMM 5.32 16.29 8.73945 1309 9678 10332
RPM MwD030 OHMM 5.12 17.54 8.61522 1309 9678 10332
RPS MwD030 OHMM 4.95 17.93 8.39052 1309 9678 10332
RPX MwD030 OHMM 4.54 16.91 7.73187 1309 9678 10332
FET MwD030 HOUR 0.18 31.3 2.45105 1309 9678 10332
GR MWD030 API 28.72 124.04 82.1637 1294 9685.5 10332
rtoP Mw~030 FT/H 38.29 352.67 208.99 1222 9721.5 10332
First Reading For Entire File..........9678
~ast tteading For Entire File...........10332
File Trailer
Service name... .......STSLIB.003
Service Sub Level Name...
version Number. ........1.0.0
Date of Generation.......07/10/03
Maximum Physical Record..65535
File Type ................LO
Next File Name...........5T5LIB.004
Physical EOF
File Header
Service name... .......STSLIB.004
Service Sub Level Name...
version Number. ........1.0.0
~ate of Generation.......07/10/03
Maximum Physical Record..65535
File Type. ............LO
Previous File Name.......STSLIB.003
comment Record
FILE HEADER
FILE NUMBER: 4
RAW MWD
Curves and log header data for each bit run in separate files.
BIT RUN NUMSER: 10
DEPTH INCREMENT: .5000
#
FILE SUMMARY
VENDOR TOOL CODE START DEPTH STOP DEPTH
ROP 10332.5 10391.0
Page 8
• ~
1J122L200725200755N.tXt
$
#
LOG HEADER DATA
DATE LOGGED: 22-JUL-07
SOFTWARE
SURFACE SOFTWARE VERSION: Insite
DOWNHOLE SOFTWARE VERSION: 72.13
DATA TYPE (MEMORY OR REAL-TIME): Memory
TD DRILLER (FT): 10391.0
TOP LOG INTERVAL (FT): 10332.0
BOTTOM LOG INTERVAL (FT): 10391.0
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
MINIMUM ANGLE: .O
MAXIMUM ANGLE: .O
#
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE TOOL NUMBER
$
#
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN): 8.500
DRILLER'S CASING DEPTH (FT): 10332.0
#
BOREHOLE CONDITIONS
MUD TYPE: Mineral Oil Base
MUD DENSITY (LB/G): 8.35
MUD VISCOSITY (S): 85.0
MUD PH: .O
MUD CHLORIDES (PPM): 25000
FLUID LOSS (C3): 3.5
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT): .000 .O
MUD AT MAX CIRCULATING TERMPERATURE: .000 98.0
MUD FILTRATE AT MT: .000 .O
MUD CAKE AT MT: .000 .O
#
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
#
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
#
REMARKS:
$
#
Data Format Specification Record
Data Record Type... ..........0
~ata specification Block Type.....0
Log~ing DireCtion .................Down
Optical log depth units...........Feet
Data Reference Point ..............undefined
Frame Spacing....... ............60 .1zN
Max frames per record .............undefined
Absent value ......................-999
Depth Units ............ .........
~atum specification alock sub-type...0
Name service order units size Nsam Rep Code offset Channel
DEPT FT 4 1 68 0 1
ROP MWD100 FT/H 4 1 68 4 2
Page 9
~ ~
1J122L2007252007SSN.tXt
First Last
Name service unit Min Max Mean Nsam Reading rteading
DEPT FT 10332.5 10391 10361.8 118 10332.5 10391
ROP MwD100 FT/H 0.23 26.97 15.3346 118 10332.5 10391
First Reading For Entire File..........10332.5
~ast rteading For Entire File...........10391
File Trailer
Service name... .......STSLIB.004
Service Sub Level Name...
version Number. ........1.0.0
Date of Generation.......07/10/03
Maximum Physical Record..65535
File Type ................LO
Next File Name...........STSLIB.005
Physical EOF
File Header
Service name... .......STSLIB.005
service sub ~evel Name...
version Number. ........1.0.0
Date of ~eneration.......07/10/03
Maximum Physical Record..65535
File Type. ............LO
Previous File Name.......STSLIB.004
Comment Record
FILE HEADER
FILE NUMBER: 5
RAW MWD
Curves and log header data for each bit run in separate files.
BIT RUN NUMBER: 11
DEPTH INCREMENT: .5000
#
FILE SUMMARY
VENDOR TOOL CODE START DEPTH STOP DEPTH
RPx 10332.5 18033.0
RPD 10332.5 18033.0
RPM 10332.5 18033.0
GR 10332.5 18073.5
FET 10332.5 18033.0
RPS 10332.5 18033.0
ROP 10391.5 18078.0
S
#
LOG HEADER DATA
DATE LOGGED: 25-JUL-07
SOFTWARE
SURFACE SOFTWA RE VERSION: Insite
DOWNHOLE SOFTWARE VERSION: 72.13
DATA TYPE (MEMORY OR REAL-TIME): Memory
TD DRILLER (FT): 18078.0
TOP LOG INTERVAL (FT): 10391.0
BOTTOM LOG INTERVAL (FT): 18078.0
Page 10
•
C~
1J122L2007252007SSN.tXt
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
MINIMUM ANGLE: 81.9
MAXIMUM ANGLE: 94.0
#
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE TOOL NUMBER
DGR DUAL GAMMA RAY 119546
EWR4 ELECTROMAG. RESIS. 4 81390
$
#
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN): 8.500
DRILLER'S CASING DEPTH (FT): 10332.0
#
BOREHOLE CONDITIONS
MUD TYPE: Mineral Oil Base
MUD DENSITY (LB/G): 8.40
MUD VISCOSITY (S): 71.0
MUD PH: ,Q
MUD CHLORIDES (PPM): 22500
FLUID LOSS (C3): 10.6
RESISTIVITY (OHMM) AT TEMPERATU RE (DEGF)
MUD AT MEASURED TEMPERATURE (MT): .000 .O
MUD AT MAX CIRCULATING TERMPERATURE: .000 125.0
MUD FILTRATE AT MT: .000 .O
MUD CAKE AT MT: .000 .O
#
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
#
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
#
REMARKS:
$
#
Data Format Specification Record
Data Record Type... .......... 0
Data Specification Block Type..... 0
Log~ing Direction ................. DOwn
optical log depth units........... Feet
~ata Reference Point .............. undefined
Frame Spacing....... ............ 60 .1zN
Max frames per record ............. undefined
absent value ...................... -999
~epth units. . .. .. .....
~atum specification Block sub-type...0
Name Service Order units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1
RPD MWD110 OHMM 4 1 68 4 2
RPM MWD110 OHMM 4 1 68 8 3
RPS MWD110 OHMM 4 1 68 12 4
RPX MWD110 OHMM 4 1 68 16 5
FET MWD110 HOUR 4 1 68 20 6
GR MWD110 API 4 1 68 24 7
ROP MWD110 FT/H 4 1 68 28 8
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1J122L200725200755N.txt
First Last
Name Service Unit Min Max Mean Nsam Reading Reading
DEPT FT 10332.5 18078 14205.3 15492 10332.5 18078
RPD MWD110 OHMM 13.16 101.25 59.3203 15402 10332.5 18033
RPM MwD110 OHMM 12.79 94.9 52.3572 15402 10332.5 18033
RPS MWD110 OHMM 12.09 136.14 53.6112 15402 10332.5 18033
RPx Mwo110 OHMM 10.65 264.97 61.4927 15402 10332.5 18033
FET MwD110 HOUR 0.12 597.74 1.72693 15402 10332.5 18033
GR Mw~110 API 42.66 99.1 66.3687 15483 10332.5 18073.5
RoP Mw~110 FT/H 0.1 431.28 255.945 15374 10391.5 18078
First Reading For Entire File..........10332.5
~ast rteading For Entire File...........18078
File Trailer
Service name... .......STSLIB.005
Service Sub Level Name...
version Number. ........1.0.0
~ate of Generation.......07/10/03
Maximum Physical Record..65535
File TyL~ e ................LO
Next File Name...........STSLIB.006
Physical EOF
Tape Trailer
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~ate . ...................07/10/03
Origin ...................5T5
Tape Name. .... ........UNKNOWN
Continuation Number......01
Next Tape Name...........UNKNOWN
Comments .................STS LIS Writing
~ibrary. scientific Technical services
Reel Trailer
Service name .............LISTPE
~ate . ...................07/10/03
Ori 9in ...................5T5
Reel Name. .... ........UNKNOWN
Continuation Number......01
Next Reel Name...........UNKNOWN
Comments .................STS LIS Writing Library.
Physical EOF
Physical EOF
End Of LIS File
scientific Technical services
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