Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout207-128 STATE OF ALASKA
ALEC OIL AND GAS CONSERVATION COM ION
REPORT OF SUNDRY WELL OPERATIONS
1.Operations Abandon E Plug Perforations r' Fracture Stimulate r Pull Tubing r Operations shutdown E
Performed:
Suspend r Perforate r Other Stimulate
p r Alter Casing n Change ApprovedJPrpgvram
Plug for Redrill r Perforate New Pool E Repair Well r Re-enter Susp Well E Other: GL to SPJ1pF
2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number:
ConocoPhillips Alaska, Inc. Development F Exploratory r 207-1280
3.Address: 6.API Number:
P. O. Box 100360,Anchorage, Alaska 99510 Stratigraphic " Service E 50-103-20554-00
7.Property Designation(Lease Number): 8.Well Name and Number:
ADL 380051, 380052, 380053 KRU 2L-330
9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s):
Kuparuk River Field I Tarn Oil Pool
11.Present Well Condition Summary:
Total Depth measured 11201 feet Plugs(measured) None
true vertical 5935 feet Junk(measured) None
Effective Depth measured 11094 feet Packer(measured) 10014, 10087, 10151
true vertical 5842 feet (true vertical) 5043, 5089, 5131
Casing Length Size MD TVD Burst Collapse
CONDUCTOR 70' 16 110' 110'
SURFACE 3288' 9 5/8 3319' 2398'
^R
PRODUCTION 10279' 7 10307' 5237' _ _
LINER 1090' 41/2 11198' 5932'
OCT 12 2015
. ri '+
Perforation depth: Measured depth: 10540-10555, 11020-11040 SCANNED FEE % hit, (C
True Vertical Depth: 5403-5414, 5783-5799
Tubing(size,grade,MD,and TVD) 3 1/2 ,0, 10151 MD, 5131 TVD
Packers&SSSV(type, MD,and TVD) NIPPLE=CAMCO'DS' NIPPLE w/2.875"profile(@ 519 MD and 518 TVD
SLEEVE= BAKER CMU SLIDING SLEEVE @ 10014 MD and 5043 TVD
NIPPLE=3-1/2" X 2.75"CAMCO'D' NIPPLE(OD 4.520"ID 2.750") NO-GO @ 10087 MD and 5089 TVD
SEAL SSY= BAKER 80-40 BONDED SEAL ASSEMBLY @ 10151 MD and 5131 TVD
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 Casing Pressure Tubing Pressure
Prior to well operation 125 345 63 1000 307
Subsequent to operation 132 347 61 2121 264
14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work:
Daily Report of Well Operations F Exploratory r Development F Service r Stratigraphic E
16.Well Status after work:
Copies of Logs and Surveys Run r Oil Gas E WDSPL E
Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP E SPLUG r
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:
N/A
Contact Darrell Humphrey Email: n1139@conocophillips.com
Printed Name Darrell Humphrey Title: NSK Production Engineering Specialist
Signature 4.1 ,` Phone:659-7535 Date / 0 . i/we Q . i/we
Form 10-404 Revised 5/i015 �• —,/�1 Submit Original Only
14Trr /0//9 /140 dr 0°d RBDMS (,V OCT 1 2 2016
' • 2L-330 •
DESCRIPTION OF WORK COMPLETED
SUMMARY
Date Event Summary
10/07/16 Convert to SPJP well. Well brought online
10/05/16 SET 2.81" C-LOCK&3" JET PUMP (SN # PH-1053) (RATIO: 8C) @ 10,013' RKB. SET 3" SLIP
STOP ON TOP OF JET PUMP @ 10,013' RKB. PUMPED 10 BBLS. DOWN IA. JOB
COMPLETE.
KUP PROD 2L-330
ConocoPhillips 1° Well Attributes Max Angle&MD TD
Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(1 MD(ftKB) Act Btm(ftKB)
.,,,,, mm 501032055400 TARN PARTICIPATING AREA PROD 68.94 4,648.25 11,201.0
""" Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date
DEVIATED-2L-330,10/7/20163'11'58 PM SSSV:NIPPLE 50 11/23/2015 Last WO: _ 35.60 12/4/2007
Vertical schematic(actual)
Annotation Depth(ftKB) End Date Annotation Last Mod By End Date
Last Tag:SLM 10,912.0 10/1/2016 Rev Reason:TAG,OPEN CMU,GLV C/O,SET pproven 10/7/2016
JET PUMP 8 SLIP STOP _
aeCasing Strings
HANGER;26.3- tat(IQ Casing Description 00(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread
IDIII CONDUCTOR 16 15.250 40.0 110.0 110.0 65.00 H-40 WELDED
:;°o, Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread
SURFACE 95/8 8.835 31.1 3,318.6 2,398.1 40.00 L-80 BTC
Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread
PRODUCTION 7 6.276 28.5 10,307.4 5,236.7 25.69 L-80 BTC-Mod
fay =j
Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread
LINER 41/2 3.958 10,108.5 11,198.0 5,932.2 12.60 L-80 IBT-Mod
hil
SCC
Liner Details
Nominal ID
Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in)
A.A./CONDUCTOR;40.0-110.0 10,108.5 5,103.0 50.02 PACKER "HR"ZXP LINER TOP PACKER 5.250
10,123.9 5,112.9 49.79 NIPPLE "RS"PACKOFF SEAL NIPPLE 4.270
NIPPLE;519.0 '
10,127.6 5,115.4 49.73 HANGER FLEX LOCK LINER HANGER 4.390
10,137.5 5,121.7 49.57 SBE 190-47 SEAL BORE EXTENSION 4.000
Tubing Strings
Tubing Description I String Ma...`ID(in) I Top(ftKB) I Set Depth(ft..'Set Depth(TVD)(...I Wt(lb/ft) I Grade I Top Connection
TUBING 31/21 2.992 26.3 10
, 1 5,139.9 9.30 L-80 EUEMOD
Completion Details
Nominal ID
Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in)
SURFACE;31.1-3,318.6 ' A 26.3 26.3 0.00 HANGER FMC TUBING HANGER w/2.60'pin X pin pup 2.992
519.0 518.5 5.70 NIPPLE CAMCO'DS'NIPPLE w/2.875"profile( 2.875
GAS LIFT;3,595.8E' 10,013.9 5,043.4' 52.74'Sliding Sleeve BAKER CMU SLIDING SLEEVE w/2.812"DS profile 2.812
-Open (OPENED 10/4/2016)
10,086.5 5,089.0 50.36 NIPPLE 3-1/2"X 2.75"Camco'D'Nipple(OD 4.520"ID 2.750")no 2.750
-90
10,125.0 5,113.6 49.77 LOCATOR BAKER NO GO LOCATOR 3.000
ar 10,151.4 5,130.8 49.23 SEAL SSY BAKER 80-40 BONDED SEAL ASSEMBLY 3.000
GAS LIFT;6,668.4 A. 10,165.1 5,139.8 48.89 WLEG BAKER WLEG w/HALF MULE SHOE 3.000
Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.)
Top(TVD) Top Incl
Top(ftKB) (ftKB) (°) Des Com Run Date ID(in)
10,011.5 5,041.9 52.88'SLIP STOP 3"SLIP STOP=18.5"on top of JET PUMP 10/5/2016
10,013.0 5,042.9 52.79'JET PUMP 3"JET PUMP(PUMP SN#PH-1053)(RATIO:8C)= 10/5/2016
CHEMICAL;7,309.1--1L c. 66"on 2.81"C LOCK
10,823.0 5,622.9 36.63 PLUG CEMENT PLUG 4/11/2008
GAS LIFT;8,698.9 Perforations&Slots
Shot
Dens
Top(NO) Btm(7110) (shots/f
GAS LIFT;9,932.5 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com
10,540.0 10,555.0 5,403.5 5,414.5 BERMUDA, 4/19/2008 6.0 APERF 2.5"HJ GUN,60 DEG
SLIP STOP;10,011.5 1 Iii
2L-330 RANDOM
f 11,020.0 11,040.0 5,782.8 5,799.3 ESKER,2L- 12/30/2007 6.0 IPERF HYPERJET,EH-0,43,
JET PUMP;10,013.0 MI
Skiing Sleeve-Open;10,013.9 0111 330 PENT-13.1"
I. 'iI
lit Stimulations&Treatments
W Min Top Max Btm
NIPPLE;10,086.5 Depth Depth Top(ND) Bim(Tee)
(ftKB) (ftKB) (ftKB) (ftKB) Stg R Type Date Com
11,020.0 11,040.0 5,782.8 5,799.3 1 FRAC 1/6/2008 ESKER SAND FRAC,87 168#1620 CARBOLITE,
' w/6ppa IN PERFS
P 10,540.0 10,555.0 5,403.5 5,414.5 FRAC 4/20/2008 BERMUDA SANDS FRAC 206133#16/20
L CARBOLITE w/10 PPA IN PERFS
Mandrel Inserts
LOCATOR;10,125.0 St
ati
1.
on Top(ND) Valve Latch Port Size TRO Run
1 Ill N Top(ftKB) (ftKB) Make Model OD(in) Saw Type Type (in) (psi) Run Date Com
1 3,595.8 2,506.7 CAMCO KBMG 1 Gas Lift DMY BK-5 0.000 0.0 5/13/2008 -
2 6,668.5 3,708.8 CAMCO KBMG 1 Gas Lift DMY BK-5 0.000 0.0 12/2/2007
a, 3 7,309.1 3,958.3 CAMCO KBMG- 1 GAS LIFT DMY BK 0.000 0.0 1/12/2016
SEAL SSY;10,151.4 i.... LTS
II CIM
1-I 4 8,698.9 4,493.9 CAMCO KBMG 1 Gas Lift DMY BK-5 ' 0.000 0.0 12/2/2007
5 9,932.5 4,996.9 CAMCO KBMG 1 Gas Lift DMY BK 0.000 0.0 10/2/2016
WLEG;10,185.1 at Notes:General&Safety
End Date Annotation
8/24/2008 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0
8/12/2011 NOTE:CIV MANDREL @ 7309-MODEL CM-40R,1400 PSI
PRODUCTION;28.5-10,307.4-4r
FRAC;10,540.0
APERF;10,540.0-10,555.0 I
PLUG;10,823.0 V A
IPERF;11,020.0-11,040.
FRAC;11,020.00
-\.__I I
LINER;10,108.5-11,198.0 -
•
Image f~rojee~ Well t~list~ary ~il+" ~c~ver Page
X!-tVZE
This page identifies those items that were not scanrtod during the initial production scanning phase.
They are available in the original file, may be scanned during a special rescan activity or are viewable
by direct inspection of the file.
~?C ~ ~ - ~ ~, ~ Well History File Identifier
Organizing (aone>
RES AN
Color Items:
^ Greyscale Items:
^ Poor Quality Originals:
^ Other:
NOTES:
BY: Maria -
Project Proofing
BY: Maria
Scanning Preparation
BY: Maria
~,~.eea iiiiuuuuiiiui
DIGI AL DATA
Diskettes, No. '
^ Other, No/Type:
Date: L J ~
Date:
~~ x30=
Date: ~ ~ Q
a~~a~~e~aee iiumimiuuu
OVERSIZED (Scannable)
^ Maps:
^ Other Items Scannable by
a Large Scanner
OVERSIZED (Non-Scannable)
^ Logs of various kinds:
^ Other::
/s/
IIIII~IIIIIIII IIIII
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+ ~~ =TOTAL PAGES ~ ~~
(Count does not include cover sheet)
/s!
Production Scanning
` ~ ' Illlllllllllll IIIII
Stage 7 Page Count from Scanned File: V/ (Count does include cover sheet)
Page Count Matches Number in Scanning Preparation: ~~YES NO
BY: Maria Date: ~ / ~ ~ /s/ ~/~ ~~
. ~ ~ ~' V
Stage 7 If NO in stage 1, page(s) discrepancies were found: YES NO
BY: Maria Date: /s/
Scanning is complete at this point unless rescanning is required. II I II'I II I II II IIIII
ReScanned II I N II II I I III I (III
BY: Maria Date: /s/
Comments about this file: Quality Checked III IIIII III II'I II
10/6/2005 Well History File Cover Page.doc
•
WELL LOG TRANSMITTAL
To: Alaska Oil and Gas Conservation Comm. June 29, 2011
Attn.: Howard Okland
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
RE: Gas Lift Survey: 2L -330
Run Date: 6/24/2011
The technical data listed below is being submitted herewith. Please address any problems or
concerns to the attention of:
Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518
2L -330
Digital Data in LAS format, Digital Log Image file 1 CD Rom
50- 103 - 20554 -00
P )
!,'„:., EL) SEP
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE
TRANSMITTAL LETTER TO THE ATTENTION OF:
Halliburton
Wireline & Perforating
Attn: Klinton Wood
6900 Arctic Blvd.
Anchorage, Alaska 99518
Office: 907 - 273 -3527
Fax: 907 - 273 -3535
klinton.wood@halliburton.com
Date: 2/2-2-720 C ( Signed: Rie ge.(44
-`,
~ ~.
~~~
<~`
,.,
~,;~~
~~
4
MICROFILMED.
.6/30/2010
DQ NOT PLACE
.ANY NEW MATERIAL
UNDER THIS PAGE
C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc
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: 2L-330
May 27, 2009
AK-MW-5232602
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
2L-330
2" x 5" MD TRIPLE COMBO Logs:
50-103-20554-00 ~~;~ _j~~,; ,~ ~~~
2" x 5" TVD TRIPLE COMBO Logs:
50-103-20554-00
Digital Log Images
50-103-20554-00
1 Color Log
1 Color Log
1 CD Rom
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE
TRANSMITTAL LETTER TO THE ATTENTION OF:
~b~-r~~s
l~,r~7
$ry on.com
`< :~,
Date: JUN ~ 0 2009 Signed:
Sperry Drilling
Attn: Bryan Burinda
6900 Arctic Blvd.
Anchorage, Alaska 99518
Office: 907-273-3536
Fax: 907-273-3535
~faska Gil ~ Gas Cons. Commission
Anchorage
a
DATA SUBMITTAL COMPLIANCE REPORT
12/3/2008
Permit to Drill 2071280 Well Name/No. KUPARUK RIV U TARN 2L-330 Operator CONOCOPHILLIPS ALASKA INC
MD 11201 TVD 5935 Completion Date 12/3/2007 Completion Status 1-OIL
REQUIRED INFORMATION
Mud Log No
DATA INFORMATION
Types Electric or Other Logs Run: GR / RES, DENSITY /NEUTRON, SCMT
Well Log Information:
Log/ Electr
Data Digital Dataset
Tye Med/Frmt Number Name
og Sonic
cCog Sonic
Asc Directional Survey
~! Rpt Directional Survey
pt Report: Final Well R
Log Log Run
Scale Media No
5 Col
5 Col
API No. 50-103-20554-00-00
Gurrent Status 1-OIL UIC N
Directional Survey Yes -
(data taken from Logs Portion of Master Well Data Maint
Interval OH /
Start Stop CH Received Comments
10121 10760 Case 12/21/2007 Fullbore Micro Imager,
Mast, FMI, PPC, GR 26-
Nov-2007
10121 10760 Case 12/21/2007 Sonic Scanner, MAST,
FMI, PPC, GR 26-Nov-2007
30
30
0
D C 15845 Report: Final Well R 0
~og See Notes 2 Col 80
~og See Notes 2 Col 80
/Cog See Notes 2 Col 80
vLog See Notes 2 Col 80
t,j/~og See Notes 2 Col 80
/Log See Notes 2 Col 80
Samples No
11201 Open 1/16/2008
11201 Open 1/16/2008
0 Open 1/31/2008 Final Well Report, Table of
Cont, Equip & Crew, Well
Data, Geo Data,
Pres/Form Stregth Data,
Drilling Data, Daily
Reports, and Formation
Logs
0 Open 1/31/2008 Final Well Report, Table of
Cont, Equip & Crew, Well
Data, Geo Data,
Pres/Form Stregth Data,
Drilling Data, Daily
Reports, and Formation
Logs w/LAS Files, PDF
Log Files, and DML Data.
10330 Open 1/31/2008 TVD Drilling Dynamics
10330 Open 1/31/2008 MD Drilling Dynamics.
10330 Open 1/31/2008 TVD Gas Ratio
10330 Open 1/31/2008 MD Gas Ratio
10330 Open 1/31/2008 MD Formation Log
10330 Open 1/31/2008 TVD Formation
DATA SUBMITTAL COMPLIANCE REPORT
12/3/2008
Permit to Drill 2071280 Well Name/No. KUPARUK RIV U TARN 2L-330 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20554-00-00
MD 11201 TVD 5935 Completion Date 12/3/2007 Completion Status 1-OIL Current Status 1-OIL UIC N
wog See Notes
See Notes
pt LIS Verification
~I
I~~ D C Li
tion/R
15859 ed
i
ti
it
s v
y
uc
es
s
og Cement Evaluation
Sonic
C Lis 16033 ~onic
og erforation
P
C Pds ~
C
16200-~erforation
Well Cores/Sampl es Information:
2 Col 80 10330 Open 1/31/2008 MD LWD Combo Log
2 Col 80 10330 Open 1/31/2008 TVD LWD Combo Log
152 11142 Open 1/31/2008 LIS Veri, RPD, RPX, RPM,
FET, RPS, GR, ROP,
FCNT, NCNT, NPHI,
RHOB,DRHO
152 11142 Open 1/31/2008 LIS Veri, RPD, RPX, RPM,
FET, RPS, GR, ROP,
FCNT, NCNT, NPHI,
RHOB,DRHO
5 Col 1 9880 11088 Case 1 /22/2008 CBL, SCMT-CB, Temp,
Pres 30-Dec-2007
5 Blu 10121 10760 Case 3/13/2008 Sonic Scanner, MAST,
FMI, PPC, GR 26-Nov-2007
10046 10751 Case 3/13/2008 LIS Veri, MAS, FMI
5 Blu 9932 10642 Case 5/5/2008 Perf, SBHPS 19-Apr-2008
9932 10642 Case 5/5/2008 Perf, SBHPS 19-Apr-2008
Sample
Interval Set
Name Start Stop Sent Received Number Comments
ADDITIONAL INFORMA~ON
Well Cored? Y Il^bV) Daily History Received? ~ N
Chips Received? ~~ Formation Tops 7 N
Analysis T
Received?
Comments:
Compliance Reviewed By:
Date:
~7
i
~~
y
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
1. Operations Performed: Abandon ^ Repair Well ^ Plug Pertorations ^ Stimulate Q Other ^
Alter Casing ^ Pull Tubing ^ Pertorate New Pool ^ Waiver ^ Time Extension ^
Change Approved Program ^ Operat. Shutdown^ Pertorate Q Re-enter Suspended Well ^
2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number:
COnocoPhillips Alaska, InC. Development 0 Exploratory ^ 207-128 /
3. Address: Stratigraphic ^ Service ^ 6. API Number.
P. O. Box 100360, Anchora e, Alaska 99510 50-103-20554-00
7. KB Elevation (ft): 9. Well Name and Number:
RKB 146' 2L-330 •
8. Property Designation: 10. Field/Pool(s):
ADL 380052, 380051, 380053 Kuparuk River Field / Tarn Oil Pool .
11. Present Well Condition Summary:
Total Depth measured 11201' ~ feet
true vertical 5935' feet Plugs (measured)
Effective Depth measured 10678' feet Junk (measured)
true vertical 5508' feet
Casing Length Size MD ND Burst Collapse
Structural
CONDUCTOR 80' 16" 110' 110'
SURFACE 3291' 9-5/8" 3319' 2398'
PRODUCTION 10279' 7" 10307' 5237'
LINER 1090' 4-1/2" 11198 5934'
QPctt-nvG1G ~y~ pc~^'-C
RG~eG~~~
Perforation depth: Measured depth: , 10540'-10555', 11020'-11040'--~'~c~~` ~h~ ~~~ ~ ~ lo~~
true vertical depth: 5403'-5414', 5783'-5800'
Alaska Oil & Gas Cony, Irommi~snr~
Tubing (size, grade, and measured depth) 3-1 /2" , L-80, 10165' MD. pI1ChOCa~
Packers & SSSV (type & measured depth) Baker'HR' ZXP pkr @ 10108'
Camco'DS" nipple @ 519'
12. Stimulation or cement squeeze summary:
Intervals treated (measured) not applicable
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 flowback testing --
Subsequent to operation 1320 ~ 1978 315 -- 410
14. Attachments 15. Well Class after work:
Copies of Logs and Surveys run _ Exploratory ^ Development ^~ Service ^
Daily Report of Well Operations ~X 16. Well Status after work:
Oi10 Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^
17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt:
none
Contact Guy Schwartz @ 265-6958
Printed Name Guy Schwa Title Wells Group Engineer
Signature ~ Phone Date S"Z Z "~~~
Pre red b Sharon 11 u -Drake 263-4612
Form 10-404 Revise 4/2006
~b S- ' ~
Submit Origin Onl ~~3"'0~.
~~
2L-330 Well Summary
DATE SUMMARY
4/9/08 PERFORMED SAND DUMP TO COVER ESKER PERF$ TOTAL. OF_3000#_20/40 RIVER
SAND PUMPED, REVERSED OUT DOWN TO 10800' CTMD, WELL LEFT SHUT IN AND
FREEZE PROTECTED WITH DIESEL TO 6000' MD, TURN OVER TO SLICKLINE.
4/10/08 TAG SAND PLUG Ca)_ 10824' SLM. RECOVERED SAMPLE. DUMP BAILED 2 GAL CEMENT
@ 10828' SLM. JOB IN PROGRESS. ,,
4/11/08 DUMPED CEMENT SLURRY FROM 10826' SLM TO 10823' SLM (5' OF CEMENT ON TOP
OF SAND PLUG). DRIFTED TBG WITH 20' X 2.73" DMY DRIFT & TAGGED CEMENT CcD.
..10823' SLM (**TIGHT FALLING THRU "D" NIP @ 10087' RKB**). SET 2.75" CAT
STANDING VLV @ 10087' RKB. PULLED 1"ORIFICE @ 9932' RKB (**MINOR FLOW CUT/
BAD CHECK VLV). PUMPED 116 BBLS OF 80 DEG DIESEL DWN TBG UP IA. JOB IN
PROGRESS.
4/12/08 LOAD WELL WITH 280 BBLS DIESEL. SET 1" HES-SPG (SER# 4032/ SET @ 14:OOhrs) @
9932' RKB. MIT-IA TO 3500#. LOST 250# IN 30 MIN. ***PASS***. MITT TO
3500#. LOST 150# IN 30 MIN. PASS. PULLED 2.75" CAT STANDING VLV @ 10087' RKB.
DRIFT TBG HANGER w/ 2.89" G.RING TO 50' SLM. ***READY FOR E-LINE***. JOB
COMPLETE.
4/13/08 ATTEMPTED TO PERFORATE 10540'-10555' COULD NOT WORK GUN STRING PAST
10150', HARD REPEATABLE TAG
4/14/08 TROUBLE SHOOT OBSTRUCTION @ 10154' SLM (AREA OF BAKER SEAL ASSY).
ATTEMPT TO PASS THRU OBSTRUCTION WITH 2.70",2.62" & 2.29" SWAGE DRIFT
ASSY'S (MULTIPLE LENGTHS & CONFIGURATIONS). OBTAINED 1/2 MOON
IMPRESSION ON 2.645" LIB. PULLED 1000# BINDS TO FREE TOOLS FROM
OBSTRUCTION. UNABLE TO GET MOVEMENT IN SEAL ASSY USING PRESSURE ON IA
(2000# & 3000#'s) IA HAS GOOD INTEGRITY/ NO LOSS IN PRESSURE. JOB IN
PROGRESS.
4/15/08 TROUBLE SHOOT OBSTRUCTION @ 10154' SLM. BAILED CEMENT @ 10154' SLM.
(***RECOVERED ~ 1.5 GAL CEMENT***). SUSPEND JOB DUE TO PHASE CONDITIONS.
JOB IN PROGRESS.
4/16/08 BAILED CEMENT FROM 10153' TO 10181' SLM_.(**RECOVERED ~1.6 GAL OF CEMENT &
RIVER SAND**). DRIFT TBG WITH 20' X 2.73" DMY GUN TO 10806' SLM. ***NO,
RESTRICTION IN BAKER SEAL ASSY @ 10151' RKB***. MADE DRIFT WITHOUT USING
ROLLER STEM.. ***1" HES-SPG SET ON 4-12-08 @ 9932' RKB HAS 7 DAYS
PROGRAMMING LEFT***. READY FOR E-LINE. JOB COMPLETE.
4/19/08 PERFORATED 10540' -10555', 6 SPF WITH A 2 1/2" HJ GUN, EH= 0.43", PENT= 13.1".
AFTER PERF SBHP READINGS AT 9932': PRESS= 3155.6 PSIA, TEMP= 128.7 DEGF AND
AT 10548': PRESS= 3431.7 PSIA, TEMP= 142.2 DEGF
4/20/08 COMPLETED BERMUDA SAND HYDRAULIC FRACT~IRE TREATMENT. PUMPED A
TOTAL OF 206,299# OF 16/20 CARBOLITE PLACING 206,133# BEHIND PIPE WITH 10
PPA ON FORMATION. FLUSHED TO COMPLETION WITH 43 BBLS OF SEAWATER AND
45 BBLS OF DIESEL FREEZE PROTECT. PUMPED A TOTAL OF 2856 BBLS OF SW @
AN AVERAGE TREATING PRESSURE OF 4301 PSI. POST FRAC ISIP= 1687#, FG = .76
PSI/FT, 15 MIN WHP = 1592 PSI. ****NOTE: 95% OF THE TREESAVER RUBBERS
ACCOUNTED FOR.****
4/21/08 CT FCO WITH 2" JSN DOWN TO 10.775 CTM>]_USING SSW & BIO SWEEPS. STAYED 50'
ABOVE SAND/CEMENT SLURRY PLUG @ 10820'. GOOD 1:1 RETURNS DURING ENTIRE
JOB, LIGHT SAND RETURNS TO SURFACE WITH FRAC GEL WHILE ON BOTTOM. EST.
220 FT OF CELLAR BELOW PERF ZONE (10,540 - 10,555). POOH JETTING GLM,
SLOWED SPEED FROM 5100' TO 2000' FOR WELL INCLINATION, HEAVIER SAND
RETURNS @ 2600' TO SURFACE. WELL FREEZE PROTECTED, SHUT IN WITH 1100
PSI. NOTIFY DSO, RIG DOWN CTU & PERFORM WEEKLY BOP TEST.
4/22/08 TAGGED ~ 10678' SLM. EST 123' RATHOLE. ATTEMPTED SET CATCHER SUB.
jOOLS STOPPED FALLING Cad ZB~~SLM~STUCK IN FRAC SAND. WORKED TOOLS
FREE. JOB SUSPENDED.
2L-330 Well Summary
4/26/08 SET 3.5 SS CATCHER @ 3696' SLM. PULLED DV @ 3596' RKB, ATTEMPTED SET OV.
IN PROGRESS.
4/27/08 SET 5/16" OV @ 3596' RKB. PULLED EMPTY CATCHER @ 3696' SLM. READY FOR
FLOW BACK.
5/13/08 SET CATCHER @ 10,087' RKB, PULLED SPG @ 9932' SLM & OV @ 3596' RKB, SET DV
@ 3596' RKB, OV @ 9932' RKB, PULLED CATCHER, COMPLETE.
,,, ~ .~.
(y„-^"3 +°~:^ Welllwre API/UWI Field Name Well Staha
501032055400 TARN PARTICIPATING AREA PROD
Comment H23 (ppm) Date Annotatlon End [
lJ LColifig DEVIATED-2L-330,4/2812 !NIPPLE ~ Last WO: '
~~~matic -Actual. _ Annotation Depth (mce) Entl Date Annotatbn
I Last Tag: 10,678.0 4/22/2008 Rev Reason: PERF, FRAC, GI
C/O, TAG
35.60
2L-330
Depth (ftKB)
11 201.0
Release Date
12/4/2008
)ate
4282008
WtI16sM)I Grade i Top TI
9.30'i L-80 EUE8rMOD
SSSV, 519
SURFACE
GAS LIFT, 3,596
GAS LIFT,
CHEMICAL,
GAS LIFT,
GAS LIFT,
SLEEVE-C,
10,014
NIP, 10,087
PACKER, 10,108
NIP, 10,124
LOCATOR,
10,125
HANGER, 10,120
SBE, 10,137
SEAL, 10,151
PRODUCTION
FRAC, 10,540
FRAC, 11,020
COLLAR, 11,095
8,699.0 GAS LIFT CAMCOIKBMGl1/DMY/BK-SI/! CommenT. 12122007 2.920
9,932.0 GAS LIFT CAMCOIKBMGl1/SPGIBEK/I/ Comment: 4/112008 2.920
10,014.0 SLEEVE-C BAKER CMU SLIDING SLEEVE w/2.813 DS PROFILE (CLOSED) 1212/2007 2.813
10,087.0 NIP CAMCO'D' NIPPLE w/NO GO PROFILE 12/212007 2.750
10,108.0 PACKER LINER BAKER'HR' ZXP LINER TOP PACKER 11/302007 4.400
10,124.0 NIP LINER BAKER'RS' PACKOFF SEAL NIPPLE 11/30/2007 4.270
10,125.0 LOCATOR BAKER NO GO LOCATOR 12/2/2007 3.000
10,128.0 HANGER LINER BAKER FLEXLOCK LINER HANGER 11130/2007 4.440
10,137.0 SBE LINER 190-07 SEAL BORE EXTENSION 11/30/2007 4.000
10,151.0 SEAL BAKER G22 LOCATOR SEAL ASSEMBLY 12122007 3.000
11,095.0 COLLAR LINER BOT LANDING COLLAR TYPE 1 w/CERAMIC INSERT 111302007 3.958
11,196.0 SHOE LINER SILVER BULLET
Top (ND) Btm (ND)
Top (ftKB) Bhn (ftKB) (ftKB) (ftKB) Type FLOAT SHOE 11/302007 3 458
s "'.;fir-.'.%. 'y'I, T ,.
Shot CaICa...
Dena Shot
Zone (ahol.. Total Date Comment
10,540.0 10,555.0 5,403.1 5,414.2 APERF 6.0 90 4/19/2008 2.5" HJ GUN, 60 DEG RANDOM
11,020.0 11,040.0 5,782.9 5.799.6 IPERF
. M t
Min Top Max Btm
Depth (ftKB) Depth (ftKB) Date Type 6.0 120 12/302008 HYPERJET, EH-0,43, PENT-13.1"
.... ~.,..n,.~. u~i~...~.
Comment
11,020.0 11,040.0 1/62008 FRAC ESKER SAND FRAC, 87 168# 1620 CARBOUTE, w/6ppa IN PERFS
SHOE, 11,198
LINER
TD, 11,201
,,
;f ,..
i
F,
~ NO. 4678
Schlumberger -DCS ,~ ~' °'
2525 Gambell Street, Suite 400 Company: Alaska Oil & Gas Cons Comm
Anchorage, AK 99503-2838 Attn: Christine Mahnken
ATTN: Beth 333 West 7th Ave, Suite 100
Anchorage, AK 99501
Field: Kuparuk
04/30/08
Well Job # Log Description Date BL Color CD
3K-102 NA PRODUCTION PROFILE 04/08/08 1 1
1 E-04 11996622 LDL ~ "'t p _ C( 04/16/08 1 1
2U-13 11996617 PRODUCTION PROFILE - a~f 04/10/08 1 1
2W-17 11996618 SFRT _ 04/12/08 1 1
2L-330 11970662 PERF/SBHP _ ~ 04/19/08 1 1
3F-18 11970666 LDL G` 04/23/08 1 1
1 D-130 11964595 LDL C' ~- 04/23/08 1 1
1Y-07 11964596 INJECTION PROFILE -~ / ~ 04/24/08 1 1
2T-217A 11970667 INJECTION PROFILE ...0 ((o (`1 04/24/08 1 1
1F-05 11964597 INJECTION PROFILE / ~Cj ~ 04/25/08 1 1
3K-102 12021157 MEM PROD PROFILE ( 04/26/08 1 1
i L-09 11970669 PRODUCTION PROFILE t( 04/26/08 1 1
Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you.
l
Schlumberger -DCS
2525 Gambell Street, Suite 400
Anchorage, AK 99503-2838
ATTN: Beth -s------
Well Job #
Log Description
Company: Alaska Oil & Gas Cons Comm
Attn: Christine Mahnken
333 West 7th Ave, Suite 100
Anchorage, AK 99501
Field: Kuparuk
Date BL Color CD
03/12/08
1 A-12 11964583 LDL ~~ (~ (;~~ 02/28/08 1
1 E-1126 SAND LATERAL 11978443 MEM INJECTION PROFILE 03/03/08 1
1R-04 11964585 USIT j. - 03/02/08 1
2L-330 11837544 OH EDIT (SONIC SCANNER) ' }.. ~ 11/27/07 1 1
31-01 11994626 LDL 03/06/08 1
2N-327 11994628 PRODUCTION PROFILE ~(f~-.~ 03/08/08 1
1Y-28 11994629 PRODUCTION PROFILE 03/10/08 1
3S-08C 40016310 OH MWD EDIT VISION SERVICE ~" ~( 01/17/08 1 1
•
Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you.
ConocoPhillips
March 4, 2008
Commissioner
State of Alaska
Alaska Oil & Gas Conservation Commission
333 West 7th Avenue Suite 100
Anchorage, Alaska 99501
Subject: Well Completion Report for 2L-330
Dear Commissioner:
Randy Thomas
Kuparuk Drilling Team Leader
Drilling & Wells
P. O. Box 100360
Anchorage, AK 99510-0360
Phone: 907-265-6830
~~~~~~~~
MAR 0 5 2008
pia Oil & Gas Cons• i~°n
~:...... A~rct-orage ..
ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the
recent drilling operations of the Kuparuk well 2L-330.
If you have any questions regarding this matter, please contact me at 265-6830 or
Mike Greener @ 263-4820
Sincerely,
\ - -
R. Thomas
Kuparuk Drilling Team Leader
CPAI Drilling
RT/skad
u~ , ~~~
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
~~~EIV~~
MAR 0 5 2008
WELL COMPLETION OR RECOMPLETION REP~c;dli~slommission
1a. Well Status: Oil ^/ - Gas Plugged Abandoned ^ Suspended
20AAC 25.105 20AAC 25.110 ~
GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. Well Class
Development O/ Exploratory ^
Service ^ Stratigraphic Test ^
2. Operator Name:
ConocoPhillips Alaska, Inc. 5. Date Comp., Susp.,
or Aband.: December 3, 2007 12. Permit to Drill Number.
207-128 / '
3. Address:
P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded:
November 4, 2007 13. API Number:
50-103-20554-00 '
4a. Location of Well (Governmental Section):
Surface: 236' FNL, 938' FEL, Sec. 22, T10N, R7E, UM 7. Date TD Reached:
November 24, 2007 ~ 14. Well Name and Number:
2L-330
Top of Productive Horizon:
1257' FNL, 860' FEL, Sec. 26, T10N, R7E, UM 8. KB (ft above MSL): 146' AMSL
Ground (ft MSL): 115' AMSL 15. Field/Pool(s):
Kuparuk River Field
Total Depth:
1665' FNL, 579' FEL, Sec. 26, T10N, R7E, UM 9. Plug Back Depth (MD + ND):
11094' MD / 5842' ND Tarn Oil Pool
4b. Location of Well (State Base Plane Coordinates):
Surface: x- 460713 ' y- 5927611 ~ Zone- 4 10. Total Depth (MD + ND):
11201' MD / 5935' ND 16. Property Designation:
ADL 380052, 380051, 380053
TPI: x- 466047 y- 5921285 Zone- 4
Total Depth: x- 466327 ~ - 5920876 ~ Zone- 4 11. SSSV Depth (MD + ND):
nipple @ 519' MD / 519' TVD 17. Land Use Permit:
4599, 4601
18. Directional Survey: Yes ^/ No^
(Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore:
N/A (ft MSL) 20. Thickness of Permafrost (lVD):
1174' TVD
21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071):
GR/Res, DensitylNeutron, SCMT
22. CASING, LINER AND CEMENTING RECORD
SETTING DEPTH MD SETTING DEPTH ND HOLE
TING REC AMOUNT
CASING SIZE
WT. PER FT.
GRADE
TOP
BOTTOM
TOP
BOTTOM
SIZE CEMEN
ORD
PULLED
16" 62.5# H-40 28' 110' 28' 110' 24" 8 sx High Early
9-5/8" 40# L-80 28' 3319' 28' 2398' 12.25" 57o sx Class G, 2 sx Class G
7" 26# L-80 28' 10307' 28' 5237' 8.75" 245 sx Class G
4.5" 12.6# L-80 10108.5' 11198' 5103' 5934' 6.125" 153 sx Class G
23. Open to production or injection? Yes Q No If Yes, list each 24. TUBING RECORD
Interval open (MD+ND of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET
3.5" 10165' 10109'
11020'-11040' MD 5783'-5800' TVD 6 spf
25. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED
11020'-11040' 87168# of 16/20 carbolite
26. PRODUCTION TEST
Date First Production
February 18, 2008 Method of Operation (Flowing, gas lift, etc.)
gas lift oil
Date of Test
2/24/2008 Hours Tested
21.5 hours Production for
Test Period -> OIL-BBL
0 GAS-MCF
1266 WATER-BBL
230 CHOKE SIZE
100% GAS-OIL RATIO
high
Flow Tubing
press. 261 psi Casing Pressure
1141 Calculated
24-Hour Rate -> OIL-BBL
0 GAS-MCF
1413 WATER-BBL
258 OIL GRAVITY -API (corn)
not available
27. CORE DATA Conventional Core(s) Acquired? Yes No ~ Sidewall Cores Acquired? Yes No
If Yes to either question, list formations and intervals cored (MD+ND of top and twttom 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.
L'C7ar'hL?~ i!ilE~
NONE ,p1~ 3.07
1FE~--~ ~ jj
l~
Form 10-407 Revised 2/2007 ~~ ~ ONTINUE EVERSE SIDE ~ ~.~/• ,!~•b~'j
,/ ~ ~( ! "
28. GEOLOGIC MARKERS (List all formations and mark encountered): 29. FORMATION TESTS
NAME MD TVD Well tested? ~ Yes ~ No If yes, list intervals and formations tested,
Permafrost -Top surface surface briefly summarizing test results. Attach separate sheets to this form, if
Permafrost -Bottom 1200' 1174' needed, and submit detailed test information per 20 AAC 25.071.
C80 3466' 2456'
C50 7063' 3866'
C40 7954' 4204'
T7 9659' 4869'
T-3.1 10391' 5297
T-3 10414' 5313'
T-2 10579' 5433'
C-35 10741' 5558'
K-3 10786' 5593'
Top Esker 10908' 5692' ~ N/A '
Formation at total depth: Bermuda
30. LIST OF ATTACHMENTS
Summary of Daily Operations, Directional Survey, schematic
31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike Greener @ 263-4820
Printed Name Ra Thomas Title: Drilling Team Leader
C
3 (`r ~~ 8
-.-..Phone ~ 5~- 6.~ 3 v Date
Signature
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 Disposal, Water Supply for
Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool
completely segregated. Each segregated pool is a completion.
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 TVD 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 well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show
the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately
produced, showing the data pertinent to such interval).
Item 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 detailed test and
analytical laboratory information required by 20 AAC 25.071.
Form 10-407 Revised 2/2007
~'~^~ KRU 2L-330
~~ Cnngc~-~'~~Ilp e4laska, tnc.
Halliburton Company
Survey Report
Compan}: ConnroPhiliips Alaska Inc. Date: 1216/2007 l~inxe: 12:04:22 Pa~c: 1
Field: Kuparuk River Unit Co-ordinate(~~'E1 Reference: Well; 2L-330, Tr ~ie North
Site: Kupanik 2L Pad Vertical (f~ t)> Re ference: 2L X30 146.1
~~ell: 2L-330 Sectiun i ~'S) KeCer euce.: Well (O.OON,0-O OE,145.OOAzi)
Wellpath: 2L-330 Sune}~ Caicufatiou Method: Minimum Curva ture Dh: Orade
Survey
J7n Incl ~zim ~F~'I) Sys T~"U ti%ti F:,'~V ~VIapN \9.apF: tbul
ft deg dey ft ft ft ft ft ft
___
30.65 0.00 0.00 30.65 ..
___
-115.40.
0.00 0.00
5927610.80 460712.60
TIE LINE
76.00 0.07 283.44 76.00 -70.05 0.01 -0.03 5927610.81 460712.57 CB-GYRO-SS
172.00 0.27 134.68 172.00 25.95 -0.14 0.08 5927610.66 460712.68 CB-GYRO-SS
263.00 1.16 161.74 262.99 116.94 -1.16 0.52 5927609.63 460713.11 CB-GYRO-SS
318.00 2.74 153.12 317.96 171.91 -2.87 1.29 5927607.93 460713.87 CB-GYRO-SS
408.89 3.57 147.34 408.71 262.66 -7.19 3.80 5927603.60 460716.36 MWD+IFR-AK-CAZ-SC
497.85 5.15 149.68 497.41 351.36 -12.96 7.31 5927597.80 460719.84 MWD+IFR-AK-CAZ-SC
590.40 7.54 156.02 589.39 443.34 -22.10 11.87 5927588.64 460724.36 MWD+IFR-AK-CAZ-SC
682.70 10.09 150.90 680.59 534.54 -34.70 18.27 5927576.01 460730.68 MWD+IFR-AK-CAZ-SC
~ 771.63 13.06 154.21 767.70 621.65 -50.56 26.43 5927560.11 460738.76 MWD+IFR-AK-CAZ-SC
867.64 17.16 159.04 860.38 714.33 -73.56 36.22 5927537.06 460748.43 MWD+IFR-AK-CAZ-SC
963.02 21.02 156.10 950.50 804.45 -102.35 48.19 5927508.21 460760.25 MWD+IFR-AK-CAZ-SC
1057.44 23.80 153.31 1037.78 891.73 -134.86 63.61 5927475.62 460775.50 MWD+IFR-AK-CAZ-SC
1152.11 25.47 147.87 1123.84 977.79 -169.17 83.02 5927441.21 460794.73 MWD+IFR-AK-CAZ-SC
1247.12 26.73 142.59 1209.17 1063.12 -203.45 106.87 5927406.81 460818.40 MWD+IFR-AK-CAZ-SC
1338.53 30.54 140.63 1289.39 1143.34 -237.75 134.10 5927372.38 460845.45 MWD+IFR-AK-CAZ-SC
1435.09 31.84 140.25 1371.99 1225.94 -276.30 165.95 5927333.67 460877.09 MWD+IFR-AK-CAZ-SC
1529.03 34.60 140.71 1450.57 1304.52 -316.00 198.69 5927293.80 460909.62 MWD+IFR-AK-CAZ-SC
1622.75 37.50 140.21 1526.34 1380.29 -358.52 233.81 5927251.10 460944.51 MWD+IFR-AK-CAZ-SC
1719.23 41.93 139.33 1600.53 1454.48 -405.56 273.63 5927203.86 460984.09 MWD+IFR-AK-CAZ-SC i
1814.84 45.18 137.66 1669.82 1523.77 -454.87 317.30 5927154.33 461027.49 MWD+IFR-AK-CAZ-SC
1908.20 47.01 138.61 1734.56 1588.51 -504.97 362.18 5927104.01 461072.11 MWD+IFR-AK-CAZ-SC
2001.40 50.06 137.52 1796.26 1650.21 -556.90 408.86 5927051.83 461118.51 MWD+IFR-AK-CAZ-SC
2097.94 53.10 136.60 1856.25 1710.20 -612.26 460.39 5926996.22 461169.75 MWD+IFR-AK-CAZ-SC
2190.62 54.85 135.75 1910.76 1764.71 -666.33 512.29 5926941.88 461221.37 MWD+IFR-AK-CAZ-SC
2286.18 57.36 136.33 1964.05 1818.00 -723.42 567.34 5926884.51 461276.12 MWD+IFR-AK-CAZ-SC
2378.88 58.42 138.41 2013.32 1867.27 -781.19 620.51 5926826.46 461328.98 MWD+IFR-AK-CAZ-SC
2471.20 60.08 138.72 2060.52 1914.47 -840.67 673.01 5926766.72 461381.16 MWD+IFR-AK-CAZ-SC
2566.90 63.06 137.89 2106.08 1960.03 -903.50 728.99 5926703.61 461436.81 MWD+IFR-AK-CAZ-SC
Field: Kuparuk River Unit
North Slope Alaska
United States
Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4
Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre
Sys Datum: Mean Sea Level Geomagnetic Model : bggm2007
WeII: 2L-330 Slot Name:
API 50-103-20554-00
Well Position: +N/-S -86.22 ft Northing: 5927610.80 ft Latitude: 70 12 47.424 N
+E/-W -364.91 ft Easting : 460712.60 ft Longitude: 150 19 0.642 W
Position Uncertainty: 0.00 ft
Wellpath: 2L-330 Drilled From: WeII Ref. Point
API 50-103-20554-00 Tie-on Depth: 30.65 ft
Current Datum: 2L-330 Height 146.05 ft Above System Datum: Mean Sea Level '
Magnetic Data: 11/3/2007 Declination: 22.69 deg
Field Strength: 57585 nT Mag Dip Angle: 80.67 deg
Vertica- Section: Depth From (TVD) +N/-S +E/-W Direction
ft ft ft deg
30.65 0.00 0.00 145.00
Survey Program for Definitive Wellpath
Date: 12/6/2007 Validated: Yes Version: 8
Actual From To Survey Toolcode Tool Name
ft ft
76.00 318.00 2L-330 Gyro (76.00-318.00) CB-GYRO-SS Camera based gyro single shot
408.89 11161.92 2L-330 IIFR+MS+SAG (408.89-111 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC
Halliburton Company
Survey Report
~'~ Company: ConocoPhillips Alaska Inc. Date: 12!6/2007 ~fime: 12:04:22 Pa~;c 2
Field: Kupanik River Unit Co-ordin>itetlVE)Reference: WeIL 2L-330, True North
Site: Kuparuk2! Pad VerCical{I'ti~D)Reiercncc: 2L-330146.1
~~'ell: 2L-330 Sec6on(VS}Referr~~cc: .Well (O.OON.O.OOE145.OOAzi)
~~cllpath: 2L-330 Survey Calculation ~lcthod: Minimum Curvature Db: Oracle i
.Survey
MD Intl Azim T~ D Sys "I'~~U N/S I~:~`W Vap~ Stapl: Fool
ft dey deg ft ft ft ft ft ft
- _._.
I 2661.15 65.36 140.55 2147.09 2001.04 -967.76 784.39 5926639.06 461491.87 MWD+IFR-AK-CAZ-SC
2756.46 67.83 140.77 2184.95 2038.90 -1035.41 839.84 5926571.14 461546.95 MWD+IFR-AK-CAZ-SC
2849.88 68.77 140.74 2219.49 2073.44 -1102.63 894.75 5926503.64 461601.51 MWD+IFR-AK-CAZ-SC
2947.12 67.22 139.64 2255.92 2109.87 -1171.88 952.46 5926434.09 461658.86 MWD+IFR-AK-CAZ-SC
3042.71 67.61 139.80 2292.63 2146.58 -1239.21 1009.52 5926366.47 461715.56 MWD+IFR-AK-CAZ-SC
3137.91 68.65 138.56 2328.10 2182.05 -1306.07 1067.28 5926299.32 461772.96 MWD+IFR-AK-CAZ-SC
3232.92 66.45 139.18 2364.38 2218.33 -1372.20 1125.03 5926232.90 461830.37 MWD+IFR-AK-CAZ-SC
3284.24 67.07 138.71 2384.63 2238.58 -1407.76 1156.01 5926197.18 461861.15 MWD+IFR-AK-CAZ-SC
3327.28 66.79 139.04 2401.49 2255.44 -1437.59 1182.05 5926167.22 461887.04 MWD+IFR-AK-CAZ-SC
3420.01 67.01 138.68 2437.87 2291.82 -1501.82 1238.17 5926102.70 461942.81 MWD+IFR-AK-CAZ-SC
3514.48 66.93 138.20 2474.83 2328.78 -1566.88 1295.84 5926037.36 462000.14 MWD+IFR-AK-CAZ-SC
3609.44 66.95 138.38 2512.03 2365.98 -1632.10 1353.98 5925971.83 462057.93 MWD+IFR-AK-CAZ-SC
3635.25 66.82 138.27 2522.16 2376.11 -1649.83 1369.76 5925954.02 462073.62 MWD+IFR-AK-CAZ-SC
3705.06 67.96 137.22 2549.00 2402.95 -1697.53 1413.09 5925906.11 462116.70 MWD+IFR-AK-CAZ-SC
3799.31 67.87 138.91 2584.44 2438.39 -1762.49 1471.46 5925840.85 462174.72 MWD+IFR-AK-CAZ-SC
3893.73 68.40 139.61 2619.60 2473.55 -1828.89 1528.64 5925774.16 462231.56 MWD+IFR-AK-CAZ-SC
3988.83 68.45 139.96 2654.57 2508.52 -1896.42 1585.74 5925706.34 462288.30 MWD+IFR-AK-CAZ-SC
4082.65 68.62 140.70 2688.90 2542.85 -1963.63 1641.48 5925638.85 462343.68 MWD+IFR-AK-CAZ-SC
4175.47 68.61 140.05 2722.75 2576.70 -2030.20 1696.60 5925572.00 462398.45 MWD+IFR-AK-CAZ-SC
4270.09 68.68 140.16 2757.20 2611.15 -2097.81 1753.12 5925504.10 462454.61 MWD+IFR-AK-CAZ-SC
4365.04 68.48 140.47 2791.88 2645.83 -2165.83 1809.57 5925435.79 462510.69 MWD+IFR-AK-CAZ-SC
4459.99 68.49 140.27 2826.70 2680.65 -2233.86 1865.91 5925367.48 462566.68 MWD+IFR-AK-CAZ-SC
4554.29 68.71 139.84 2861.11 2715.06 -2301.18 1922.28 5925299.88 462622.69 MWD+IFR-AK-CAZ-SC
4648.25 68.94 140.37 2895.05 2749.00 -2368.40 1978.47 5925232.37 462678.53 MWD+IFR-AK-CAZ-SC
4742.26 66.76 140.22 2930.49 2784.44 -2435.38 2034.09 5925165.11 462733.80 MWD+IFR-AK-CAZ-SC
4834.64 66.80 140.21 2966.92 2820.87 -2500.62 2088.42 5925099.59 462787.78 MWD+IFR-AK-CAZ-SC
4930.69 66.98 136.23 3004.63 2858.58 -2566.48 2147.27 5925033.43 462846.27 MWD+IFR-AK-CAZ-SC
5024.64 66.94 136.56 3041.40 2895.35 -2629.08 2206.89 5924970.53 462905.57 MWD+IFR-AK-CAZ-SC
5121.94 66.95 135.98 3079.50 2933.45 -2693.78 2268.78 5924905.52 462967.11 MWD+IFR-AK-CAZ-SC
5214.40 67.00 135.81 3115.67 2969.62 -2754.88 2328.00 5924844.12 463026.01 MWD+IFR-AK-CAZ-SC ,
5309.00 67.25 135.65 3152.44 3006.39 -2817.29 2388.85 5924781.39 463086.52 MWD+IFR-AK-CAZ-SC
5403.07 65.73 137.35 3189.97 3043.92 -2879.85 2448.22 5924718.53 463145.57 MWD+IFR-AK-CAZ-SC
5496.11 65.70 137.24 3228.23 3082.18 -2942.17 2505.74 5924655.92 463202.75 MWD+IFR-AK-CAZ-SC
5590.71 65.48 139.79 3267.33 3121.28 -3006.70 2562.80 5924591.10 463259.47 MWD+IFR-AK-CAZ-SC
5685.98 65.54 138.38 3306.83 3160.78 -3072.21 2619.58 5924525.30 463315.90 MWD+IFR-AK-CAZ-SC
5782.05 65.53 138.51 3346.61 3200.56 -3137.65 2677.59 5924459.57 463373.56 MWD+IFR-AK-CAZ-SC
5874.03 65.35 138.28 3384.84 3238.79 -3200.20 2733.14 5924396.73 463428.78 MWD+IFR-AK-CAZ-SC
5969.16 65.42 139.19 3424.47 3278.42 -3265.21 2790.18 5924331.44 463485.47 MWD+IFR-AK-CAZ-SC
6063.54 65.66 138.41 3463.55 3317.50 -3329.85 2846.76 5924266.51 463541.72 MWD+IFR-AK-CAZ-SC
6159.91 65.83 137.90 3503.14 3357.09 -3395.30 2905.38 5924200.76 463599.99 MWD+IFR-AK-CAZ-SC
6254.48 66.40 139.83 3541.43 3395.38 -3460.43 2962.25 5924135.35 463656.52 MWD+IFR-AK-CAZ-SC
6352.79 66.59 139.83 3580.64 3434.59 -3529.32 3020.41 5924066.16 463714.31 MWD+IFR-AK-CAZ-SC
6445.80 66.60 139.47 3617.58 3471.53 -3594.37 3075.67 5924000.83 463769.23 MWD+IFR-AK-CAZ-SC
6541.55 65.81 140.67 3656.22 3510.17 -3661.55 3131.91 5923933.37 463825.11 MWD+IFR-AK-CAZ-SC
6636.33 65.37 140.86 3695.39 3549.34 -3728.40 3186.50 5923866.24 463879.34 MWD+IFR-AK-CAZ-SC
6730.26 64.94 140.61 3734.85 3588.80 -3794.39 3240.44 5923799.98 463932.94 MWD+IFR-AK-CAZ-SC
6825.25 66.45 141.37 3773.95 3627.90 -3861.66 3294.93 5923732.43 463987.07 MWD+IFR-AK-CAZ-SC
6921.45 66.46 141.34 3812.38 3666.33 -3930.54 3350.01 5923663.27 464041.78 MWD+IFR-AK-CAZ-SC
7016.17 68.45 139.87 3848.69 3702.64 -3998.13 3405.53 5923595.40 464096.95 MWD+IFR-AK-CAZ-SC
7110.79 68.01 140.02 3883.79 3737.74 -4065.39 3462.08 5923527.85 464153.14 MWD+IFR-AK-CAZ-SC
7205.87 67.91 139.99 3919.47 3773.42 -4132.91 3518.72 5923460.05 464209.42 MWD+IFR-AK-CAZ-SC
7296.88 67.93 139.71 3953.68 3807.63 -4197.37 3573.10 5923395.31 464263.46 MWD+IFR-AK-CAZ-SC
Halliburton Company
Survey Report
Cumpanc: ConoCOPhillips Alaska Inc. D>itc 12/6/2007 ~Iimc 12'04.22 Pa~c: 3
Field: KUpatukRiverUnit Cu-ordinate)AE:)keference: Well: 2L-330. True North
tiitc Kuparuk 2L Pad - ~crtical (Il'U) Reference 2L-330 146.1
1~cll: 2L-330 Sectiun (~~ti) Reference Well (0-OON.O.OOE,145.OOAzi)
1i'etlpath: 2L-330 Sunr}~ Calculation [Ylrthod: Minimum Curvature Dh: Oracle
__ _ _ __
tiui~c~
~1D Licl ~zim TVD Sy, "I'U'D \/5 F; N' Map~i ~tapl? Tool
ft deg deg ft ft ft ft ft ft
~ 7391.57 67.76 140.80 3989.39 3843.34 -4264.80 3629.17 5923327.60 464319.17 MWD+IFR-AK-CAZ-SC
~ 7489.02 67.53 140.48 4026.45 3880.40 -4334.48 3686.33 5923257.62 464375.96 MWD+IFR-AK-CAZ-SC
I 7579.69 67.42 140.82 4061.19 3915.14 -4399.25 3739.43 5923192.59 464428.72 MWD+IFR-AK-CAZ-SC
7674.52 67.78 138.89 4097.33 3951.28 -4466.26 3795.95 5923125.29 464484.89 MWD+IFR-AK-CAZ-SC
7769.03 67.75 139.27 4133.09 3987.04 -4532.37 3853.26 5923058.89 464541.84 MWD+IFR-AK-CAZ-SC
7866.22 67.35 139.37 4170.20 4024.15 -4600.48 3911.81 5922990.48 464600.03 MWD+IFR-AK-CAZ-SC
7960.95 67.10 139.46 4206.88 4060.83 -4666.82 3968.63 5922923.86 464656.50 MWD+IFR-AK-CAZ-SC
8055.53 67.40 138.54 4243.45 4097.40 -4732.64 4025.85 5922857.74 464713.38 MWD+IFR-AK-CAZ-SC I
8152.66 67.49 138.36 4280.71 4134.66 -4799.77 4085.35 5922790.31 464772.52 MWD+IFR-AK-CAZ-SC
8245.76 67.12 137.36 4316.63 4170.58 -4863.46 4142.98 5922726.33 464829.81 MWD+IFR-AK-CAZ-SC
8340.08 66.74 137.08 4353.59 4207.54 -4927.15 4201.91 5922662.34 464888.41 MWD+IFR-AK-CAZ-SC
8435.02 67.24 137.81 4390.70 4244.65 -4991.52 4261.01 5922597.66 464947.16 MWD+IFR-AK-CAZ-SC
8529.79 66.92 136.87 4427.61 4281.56 -5055.71 4320.16 5922533.17 465005.97 MWD+IFR-AK-CAZ-SC
8624.43 66.93 137.67 4464.70 4318.65 -5119.67 4379.24 5922468.92 4&5064.71 MWD+IFR-AK-CAZ-SC
8719.33 66.98 137.39 4501.85 4355.80 -5184.08 4438.20 5922404.20 465123.33 MWD+fFR-AK-CAZ-SC
8811.64 66.84 136.18 4538.05 4392.00 -5245.97 4496.34 5922342.02 465181.15 MWD+IFR-AK-CAZ-SC
8909.47 66.69 138.40 4576.65 4430.60 -5312.02 4557.31 5922275.66 465241.77 MWD+IFR-AK-CAZ-SC
9003.86 66.61 138.36 4614.06 4468.01 -5376.80 4614.87 5922210.59 465298.98 MWD+IFR-AK-CAZ-SC
9097.60 67.64 140.43 4650.50 4504.45 -5442.37 4671.08 5922144.73 465354.84 MWD+IFR-AK-CAZ-SC
9191.99 67.53 140.27 4686.50 4540.45 -5509.56 4726.75 5922077.27 465410.16 MWD+IFR-AK-CAZ-SC
9285.10 67.20 140.67 4722.33 4576.28 -5575.84 4781.45 5922010.71 465464.51 MWD+IFR-AK-CAZ-SC
9377.88 67.02 140.99 4758.42 4612.37 -5642.10 4835.44 5921944.17 465518.14 MWD+IFR-AK-CAZ-SC
9472.46 66.78 140.52 4795.53 4649.48 -5709.48 4890.48 5921876.51 465572.82 MWD+tFR-AK-CAZ-SC
9566.93 66.83 139.99 4832.73 4686.68 -5776.24 4946.00 5921809.47 465627.99 MWD+IFR-AK-CAZ-SC
9661.86 66.47 139.59 4870.36 4724.31 -5842.80 5002.26 5921742.62 465683.90 MWD+IFR-AK-CAZ-SC
~ 9757.38 62.84 140.06 4911.24 4765.19 -5908.75 5057.95 5921676.39 465739.24 MWD+IFR-AK-CAZ-SC
9850.79 61.11 139.60 4955.13 4809.08 -5971.76 5111.13 5921613.12 465792.09 MWD+IFR-AK-CAZ-SC
9947.36 56.72 138.92 5004.98 4858.93 -6034.41 5165.08 5921550.19 465845.71 MWD+IFR-AK-CAZ-SC
10042.61 51.02 142.13 5061.13 4915.08 -6093.71 5214.02 5921490.65 465894.33 MWD+IFR-AK-CAZ-SC
10135.90 49.61 142.71 5120.70 4974.65 -6150.60 5257.81 5921433.53 465937.82 MWD+IFR-AK-CAZ-SC
10231.36 47.25 143.44 5184.03 5037.98 -6207.68 5300.72 5921376.23 465980.43 MWD+IFR-AK-CAZ-SC
10290.11 45.49 143.65 5224.57 5078.52 -6241.88 5325.98 5921341.90 466005.51 MWD+IFR-AK-CAZ-SC
10334.64 44.15 144.33 5256.16 5110.11 X267.27 5344.44 5921316.42 466023.83 MWD+IFR-AK-CAZ-SC
10428.43 44.23 143.46 5323.41 5177.36 -6320.09 5382.96 5921263.41 466062.08 MWD+IFR-AK-CAZ-SC
10523.49 44.11 143.58 5391.59 5245.54 -6373.35 5422.34 5921209.95 466101.18 MWD+IFR-AK-CAZ-SC
~ 10617.83 39.86 145.20 5461.70 5315.65 -6424.62 5459.11 5921158.50 466137.67 MWD+IFR-AK-CAZ-SC
10712.50 38.35 145.24 5535.16 5389.11 -6473.66 5493.17 5921109.28 466171.47 MWD+IFR-AK-CAZ-SC
10806.81 36.83 146.20 5609.89 5463.84 -6521.19 5525.58 5921061.59 466203.63 MWD+IFR-AK-CAZ-SC
10901.95 35.64 146.13 5686.63 5540.58 -6567.90 5556.89 5921014.72 466234.69 MWD+IFR-AK-CAZ-SC I
10997.26 35.42 146.50 5764.19 5618.14 X613.99 5587.61 5920968.48 466265.17 MWD+IFR-AK-CAZ-SC
11092.19 32.64 145.64 5842.86 5696.81 -6658.07 5617.25 5920924.25 466294.58 MWD+IFR-AK-CAZ-SC
11161.92 32.25 146.24 5901.71 5755.66 -6689.06 5638.20 5920893.15 466315.36 MWD+IFR-AK-CAZ-SC
• 11201.00 32.25 146.24 5934.76 5788.71 -6706.40 5649.79 5920875.75 466326.86 • PROJECTED to TD
~'
Time Logs ____ __
Date From To Dur S De th E DEpth Phase Code Subcode T COM _
11/05/2007 00:00 17:00 17.00 733 2,309 SURFA DRILL DDRL P Drlg. 12 1/4"directional hole from 733'
MD to 2309' MD 1864' TVD. Up wt 97k
do 86k rot 90k pp 1950 psi 168 spm
500 gpm 25-30k wob max gas 2440
uni t 5150 on 3600 off.
17:00 21:00 4.00 2,309 2,309 SURFA RIGMN RGRP T Circ. & condition hole while working on
au er in shaker room.
21:00 22:30 1.50 2,309 2,309 SURFA DRILL TRIP P Run 2 stands back in hose.
22:30 00:00 1.50 2,309 2,456 SURFA DRILL DDRL P Drlg from 2309' MD to 2456' MD 2053'
TVD
11/06/2007 00:00 12:00 12.00 2,456 3,335 SURFA DRILL DDRL P Drlg f/ 2456' - 3335' MD (2404' TD).
SPP 2700 psi @ 202 spm. PU 95
klbs, SO 85 klbs, RotWt 88 klbs.
OBTork 6220 ft-Ibs, OFBTork 4330
ft-Ibs.
12:00 13:30 1.50 3,335 3,335 SURFA DRILL CIRC P Pump sweep @ 202 spm, SPP 2550
psi, Rot & recip while circulate for
short tri .
13:30 14:00 0.50 3,335 3,335 SURFA DRILL OWFF P Monitor well for flow w/ pumps off.
14:00 20:00 6.00 3,335 3,335 SURFA DRILL WPRT P PJSM, blow down top drive, POOH f/
3335' -surface. Clean stab, and BHA,
20:00 21:30 1.50 3,335 3,335 SURFA DRILL WPRT P PJSM, TIH f/surf - 1425' MD. Tag
obstruction at 1425, unable to work
throu h.
21:30 00:00 2.50 3,335 3,335 SURFA DRILL REAM T Attempt work through w/ highside, and
rotate in 90 deg increments, stacking
out. Worked pipe to 1450', bit is
~~ drilling off, indicate possible OH
sidetrack. Continue circulate out gas
w/ Notify town & develop plan forward.
Max as w/ workin 3550 units.
11/07/2007 00:00 02:30 2.50 3,335 3,335 SURFA DRILL WPRT T Start on redrill of surface hole section
~
,~,,,~ f/ 1425'. Drilled 175ft hole and
re-entered on final wellbore.
02:30 03:30 1.00 3,335 3,335 SURFA DRILL REAM T Backream through new cut hole
section to 1400 ft and trip back
through problem area w/pumps off
and tool oriented highside. Perform
routine x 3 to verify repeatability.
Pre are to TIH.
03:30 04:30 1.00 3,335 3,335 SURFA DRILL WPRT P TIH to 2665, note significant drag
slack-off. Break circulation and wash
ream throw h interval and CBU.
04:30 05:30 1.00 3,335 3,335 SURFA DRILL REAM P Wash Ream, f/ 2665' - 2705', CBU.
Max as 3720 w/ circ.
05:30 06:00 0.50 3,335 3,335 SURFA DRILL WPRT P Finish wiper trip f/ 2705' - 3335'.
06:00 10:00 4.00 3,335 3,335 SURFA DRILL CIRC P CBU and condition mud for running
casing. Pump sweep w/ circulating,
rotatin and reci rocatin i e.
10:00 12:30 2.50 3,335 3,335 SURFA DRILL TRIP P POOH f/ 3335' - 1390' t/ run surface
cs .
~~~~ 2 ~f't7
Time Logs _ _ _
Date From To Dur S. Depth E. De th Phase Code Subcod_e__ T COM
11/07/2007 12:30 15:30 3.00 3,335 3,335 SURFA DRILL REAM P Work thru tight spot at 1425'. kelly up
and back ream f/ 1675' - 1390' MD.
Additional tight spot located at 1365'.
Unable to pull through w/o rotating and
back reaming. Max gas w/ circ 2470
units
15:30 16:00 0.50 3,335 3,335 SURFA DRILL TRIP P Cont. POOH U 824' on levators.
16:00 17:00 1.00 3,335 3,335 SURFA DRILL REAM T Decide to run back to bottom and
check tight spots on way in hole. Tag
and stack out at 1425', attempt to
work through. Kelly up and orient and
work pipe to work through interval at
1425' (possible ledge). Same trouble
spot as before. Wash and ream U
1477'. Max as w/ circ 2750 units.
17:00 18:00 1.00 3,335 3,335 SURFA DRILL TRIP T Complete TIH f/ 1477' U 3335' on
elevators.
18:00 20:00 2.00 3,335 3,335 SURFA DRILL CIRC T Circulate out gas and check mud
rheology. Prepare to POOH f/ running
surface cs .
20:00 22:00 2.00 3,335 3,335 SURFA DRILL TRIP T POOH on elevators f/ 3335' - 1365'.
Hole condition good until 1365. Tight
at 1365, unable to pull through
conventional) .Kell u .
22:00 22:30 0.50 3,335 3,335 SURFA DRILL REAM T Back ream w/ low pump rate and slow
rotation. Work BHA through interval,
tight spot interval at 1365. Condition
cleared on 3rd ass.
22:30 00:00 1.50 3,335 3,335 SURFA DRILL TRIP P Finish POOH on elevators to top of
BHA. UD 2 stds 6 'ts HWDP.
11/08/2007 00:00 01:00 1.00 3,335 3,335 SURFA DRILL PULD P PJSM, LD NM DC's
01:00 01:30 0.50 3,335 3,335 SURFA DRILL OTHR P Download MWD.
01:30 03:00 1.50 3,335 3,335 SURFA DRILL PULD P Finish laying down BHA.
03:00 04:00 1.00 3,335 3,335 SURFA DRILL OTHR P Clear and clean floor and prepare to
RU for runnin cs .
04:00 07:00 3.00 3,335 3,335 SURFA CASIN RURD P PJSM, RU to run surface casing.
07:00 12:00 5.00 3,335 3,335 SURFA CASINC RNCS P PJSM, MU shoe track w/ "Silver
Bullet" shoe. RIH w/ 9 5/8" 40# BTC
cs U 1420'. PU 80 klbs, SO 60 klbs.
12:00 13:00 1.00 3,335 3,335 SURFA CASINC RNCS P Run csg, encounter ledge ~ 1425',
work throu h, Cont RCSG U 2078'.
13:00 14:00 1.00 3,335 3,335 SURFA CASINC CIRC P Break circulation, CBU w/
reci rocatin cs PU 120 klbs, SO
85 klbs. PPres 420 si 3 b m.
14:00 15:30 1.50 3,335 3,335 SURFA CASINC RNCS P Cont run csg f/ 2078' - 2820',
15:30 16:00 0.50 3,335 3,335 SURFA CASINC CIRC P Break circulation w/ recip csg. CBU
@ 6 bpm, 430 psi. PU 142 klbs, SO
95 klbs.
! Pa~~ 3 ref '17
~~
Time Logs __
Date From To Dur 5 De th E. De th Phase Code Subcode T CONt
11!08/2007 16:00 17:00 1.00 3,335 3,335 SURFA CASINC RNCS P Cont run csg f/ 2820' - 3286', MU csg
hgr & Idg jt. Total csg run: (1) Flt
shoe 2.28ft,(2)jts csg @ 85.87ft,(1)
Flt clr @1.45ft, (78) jts 9 5/8" 40# BTC
csg @ 3196.53ft, pup jt w/ Indg clr
@1.33ft. Turbolizer centralizers
installed on jts 2 - 14, 69 and B-spring
Cent on jts 79 and 80. Shoe track
Baker-Locked.
17:00 18:00 1.00 3,335 3,335 SURFA CASIN RURD P R/D fill-up tool, R/U & install cmt
head.
18:00 00:00 6.00 3,335 3,335 SURFA CASIN CIRC P Cir & condition mud f/ cmt job @ 6
bpm, 340 psi. PU 137 klbs, SO 110
klbs.
11/09/2007 00:00 00:30 0.50 3,335 3,335 SURFA CASINC CIRC P Circulate, prep f/ cmt job
00:30 03:30 3.00 3,335 3,335 SURFA CEME CIRC P PJSM, test lines / 3000 psi, perfom
surface cmt job. Pumped: 50 bbls
Chem Wash, 50 bbls 10.5 ppg mud
push w/ dye, dropped bot plug, pump
445 bbls 10.7 Lead Cmt, 75 bbls 12#
LiteCrete Tail, Drop bottom plug.
Pump 20 bbls displace w/ cmt pumps.
Swap over to rig pump for final
dis lace.
03:30 04:30 1.00 3,335 3,335 SURFA CEME DISP P Displace cmt w/ rig pump @ 6 bpm.
Start pump press 440 psi, final 500
psi. Bump plug @ 243 bbls act. Calc
disp 244 bbls. Hold 1020 psi on plug
f! 15 min. Bleed off, chk fits, OK.
Surface csg cmtd in place @ 0430
hrs. Had returns throughout job,
calculate 90 bbls total w/ 21 bbls
contaminated interface and 69 clean
~-
^
cmt returns 10.4
04:30 07:00 2.50 3,335 3,335 SURFA CEME RURD P RD cmt equipment
07:00 08:30 1.50 3,335 3,335 SURFA CASIN RURD P Clear /clean floor for next operations.
08:30 10:00 1.50 3,335 3,335 SURFA WELCT OTHR P Wash out diverter, blow down top
drive, ri down stack washer.
10:00 14:30 4.50 3,335 3,335 SURFA WELCT NUND P PJSM, nipple do diverter.
14:30 17:00 2.50 3,335 3,335 SURFA CASIN NUND P Install, orient, nipple up wellhead, test
seal U 1000 si, ok.
17:00 21:00 4.00 3,335 3,335 SURFA WELC NUND P Install /nipple up BOP.
21:00 00:00 3.00 3,335 3,335 SURFA WELCT BOPE P Test BOPE U 250 psi low / 3500 psi
hi h. All tested ood, no failures.
11/10/2007 00:00 03:00 3.00 3,335 3,335 SURFA WELC BOPE P Finish BOPE test, koomey drawdown,
OK. Pull test plug, RD test
e ui ment. Install wear bushin .
03:00 06:30 3.50 3,335 3,335 SURFA DRILL PULD P Load pipe shed w/ 5" Drillpipe, strap
and tall same.
06:30 10:00 3.50 3,335 3,335 SURFA DRILL TRIP P RIH w/ 5" DP singles t/ 2976'.
_~ _
~_ _
~~~~~m~
~~e 4 ~a#'~~
Time Logs
Date From To Dur S Depth E. Depth Phase Code Subcode T C_OM
11/11/2007 23:00 23:30 0.50 3,675 3,675 INTRM1 DRILL OTHR P Clear /clean floor for next operations.
23:30 00:00 0.50 3,675 3,675 INTRM1 DRILL RURD P PJSM, start RU of csg running eq f/
cs drl ro .
11/12/2007 00:00 01:00 1.00 3,675 3,675 INTRM1 DRILL RURD P Finish RU for/ csg drlg prog.
01:00 03:00 2.00 3,675 3,675 INTRM1 DRILL PULD P PU and RIH w/ csg drlg BHA
consisting of PDC bit, 15 jts of 7" 523
Hydril csg, xo's, circ sub and
remainin
03:00 03:30 0.50 3,675 3,675 INTRMI DRILL RURD P LD csg running eq, install pipe
elevators & ready to continue TIH w/
5" DP.
03:30 05:00 1.50 3,675 3,675 INTRMI DRILL TRIP P TIHt/shoe.
05:00 06:30 1.50 3,675 3,675 INTRM1 DRILL CIRC P Cont RIH t/ 3675ft, CBU f/ LOT #3.
06:30 07:00 0.50 3,675 3,675 INTRMI DRILL TRIP P PU f/ 3675' - 3237' to shoe.
07:00 08:00 1.00 3,675 3,675 INTRM1 DRILL RURD P BD Top drive, RU f/ LOT#3, Perform
LOT#3 on Cam Sand. LOT = 12.9 'f
w/ LO. RD test lines.
08:00 08:30 0.50 3,675 3,675 INTRM1 DRILL TRIP P RIH f/ 3237' - 3675'.
08:30 09:00 0.50 3,675 3,715 INTRM1 DRILL DRLG P MU Top Drive, drill ahead w/ 7" csg
BHA f/ 3675' - 3715'. ONBTrq 5660,
OFBTr 3680.
09:00 09:30 0.50 3,715 3,715 INTRM1 DRILL CIRC P CBU w/ recip & rotate, BD TD & RU f/
LOT #4
09:30 10:30 1.00 3,715 3,715 INTRM1 DRILL LOT P Perform LOT #4 on Cam Sand. LOT .~
= 13 w/ LO. RD test lines.
10:30 12:00 1.50 3,715 3,811 INTRM1 DRILL DRLG P Drill ahead w/ 7" csg BHA f/ 3715' -
3811' . 40 RPM, WOB 11 klbs, Flow
450 m.
12:00 13:00 1.00 3,811 3,811 INTRM1 DRILL LOT P Perform LOT #4 on Camp Sand. LOT
= 13 w/ O. RD test lines.
13:00 14:30 1.50 3,811 3,906 INTRMI DRILL DRLG P Drill ahead w! 7" csg BHA f/ 3811' -
3906' MD. 60 RPM, WOB 11klbs,
Flow 450 m.
14:30 15:30 1.00 3,906 3,906 INTRM1 DRILL LOT P Perform LOT #5 on Camp Sand. LOT
= 13 w/ LO. RD test lines.
15:30 17:00 1.50 3,906 4,000 INTRM1 DRILL DRLG P Drill ahead w/ 7" csg BHA f/ 3906' -
4000'. 60 RPM, WOB 11 klbs, Flow
450 m.
17:00 18:00 1.00 4,000 4,000 INTRM1 DRILL LOT P Perform LOT #6 on Camp Sand. LOT
= 12.8 w/ LO. RD test lines.
18:00 19:00 1.00 4,000 4,096 INTRM1 DRILL DRLG P Drill ahead w/ 7" csg BHA f! 4000' -
4096' MD w/introduction of WBS LCM
to mud system. 80 RPM, WOB
11klbs, FIow450 m.
19:00 20:30 1.50 4,096 4,096 INTRM1 DRILL LOT P Perform LOT #7 on Camp Sand. LOT
= 15.7 MWE No LO.
20:30 21:30 1.00 4,096 4,189 INTRM1 DRILL DRLG P Drill ahead w/ 7" csg BHA f/ 4096' -
4189' MD. 80 RPM, WOB 11klbs,
Flow 450 m.
21:30 22:30 1.00 4,189 4,189 INTRM1 DRILL LOT P Perform LOT #8 on Camp Sand. LOT
= 15.8 w/ no LO.
~~ m~~-
~...~._ ~a~te ~~ o~ 17
r'"
f
r~
l J
Time Logs
__I
__ _
Date From To Du
r S De th E. De th Ph se Code Subcode T COM
11/12!2007 22:30 00:00 _
1.50 4,189 4,286 INTRM1 DRILL DRLG P Drill ahead w/ 7" csg BHA f/ 4189' -
4286' MD. 100 RPM, WOB 11klbs,
Flow 450 m.
11/13/2007 00:00 01:00 1.00 4,286 4,286 INTRM1 DRILL LOT P Perform LOT #9 on Camp Sand. LOT
=1
01:00 02:00 1.00 4,286 4,380 INTRM1 DRILL DRLG P Driil ahead w/ 7" csg BHA f/ 4286 -
4380 MD. 100 RPM, WOB 11klbs,
Flow 450 m.
02:00 04:00 2.00 4,380 4,380 INTRM1 DRILL LOT P Perform LOT #10 on Camp Sand.
LOT results inconclusive. Problems
C.GS~ pp
^~U ~~`t i'w r
1 w/ LCM in pump valves. Decision
,.3 ~ ~ ~~ ~ t!'~~
~o~- made to abort and attempt w/ regular
Drl BHA after tri .
04:00 05:00 1.00 4,380 4,380 INTRM1 DRILL CIRC P Circulate sweep, returns clean, prep f/
TOH for BHA Chan e, um d 'ob.
05:00 08:30 3.50 4,380 4,380 INTRM1 DRILL TRIP P BD top drive, flow check well. POOH
5" DP for BHA swa .
08:30 11:00 2.50 4,380 4,380 INTRMI DRILL PULD P Stand bk BHA /jars. LD 7" csg /bit.
Grade bit, inspect assy, gauge
centralizers. All in au e.
11:00 12:30 1.50 4,380 4,380 INTRM1 DRILL RURD P Clear floor, RD csg tools, prep for
dretnl ass .
12:30 15:30 3.00 4,380 4,380 INTRM1 DRILL PULD P MU dretnl BHA, upload /orient MWD,
surface test same.
15:30 18:30 3.00 4,380 4,380 INTRM1 DRILL TRIP P RIH 5" DP in singles from shed t/
4380'..
18:30 19:00 0.50 4,380 4,380 INTRM1 DRILL CIRC P CBU @ 600 gpm, 1740 psi w /rot @
80 r m and reci i e.
19:00 00:00 5.00 4,380 4,380 INTRM1 EVALFI DLOG P MWD MAD pass over hole drilled w/
csg drilg f/ 4380' - 3871' @ 150 ft/hr
er eo.
11/14/2007 00:00 02:30 2.50 4,380 4,380 INTRM1 EVALF DLOG P Finish MWD MAD pass over Csg Drlg
Interval t/ 4380'.
02:30 14:30 12.00 4,380 5,443 INTRMI DRILL DDRL P Drill ahead w/ 8 3/4" Dir Assy f/ 4380' -
5443' MD w/ dir correction as needed.
Flow: nnn, SPP nnnn, ONTorq nnk
ft-Ibs, OFBTorq nnk ft-Ibs, PU nnnn,
SO nnnnn,
14:30 15:00 0.50 5,443 5,443 INTRM1 DRILL CIRC P Rotate and recip pipe w/ wtd sweep
circulate wtd swee .
15:00 00:00 9.00 5,443 6,391 INTRM1 DRILL DDRL P Drill ahead w/ 8 3/4" Air Assy f! 5443' -
6391' MD (3596' TVD) w/dir correction
as needed. Max Gas 59 units, Max
ECD's PU 160 klbs, SO 83 klbs,
RotWt 107 klbs. ONBTrq 8.9kft-Ibs,
OFBTr 9.5kft-Ibs.
11/15/2007 00:00 12:00 12.00 6,391 7,310 INTRM1 DRILL DDRL P Drill ahead w/ 8 3/4" bit f/ 6391' - 7310'
MD (3958' TVD). PU 183 klbs, SO 85
klbs, RotWt 115 klbs. ONBTrq
11.1kft-Ibs, OFBTr
12:00 00:00 12.00 7,310 8,406 INTRM1 DRILL DDRL P Drill ahead w/ 8 3/4" bit f/ 7310' - 8406'
MD (4379' TVD). PU 150 klbs, SO
103 klbs, RotWt 125 klbs. ONBTrq
7.3kft-Ibs, OFBTrq 6.5kft-Ibs. Max
Gas 109 units, Max ECD 11.46 ppg
MWE.
•
Time Logs
_
D to From To Dur S. De th E. De th Ph e Code Subcode T COM
11/16/2007 00:00 03:00 3.00 8,406 8,634 INTRM1 DRILL DDRL P Drill ahead f/ 8406' - 8634' MD (4468'
TVD) w/ 8 3/4" bit. PU 153k1bs, SO
127k1bs, RotWt 110KIbs. Pump 30
bbl Hi-vis swee .
03:00 03:30 0.50 8,634 8,634 INTRM1 DRILL CIRC P Circulatate off bottom w/ sweep in OH
w/ reciprocate pipe. Significant
cuttin s over shaker.
03:30 12:00 8.50 8,634 9,295 INTRMI DRILL DDRL P Drlg f/ 8634' - 9295' MD (4726' TVD).
PU 163 klbs, SO 110 klbs, RotWt 130
klbs. ONBTrq 8.4k ft-Ibs, OFBTrq
7.98k ft-Ibs, Max Gas 138 unints,
ECD' 11.32 MWE.
12:00 00:00 12.00 9,295 10,330 INTRM1 DRILL DDRL P Drl f/ 9295' - Int TD Cad 10330' MD
TVD 2 PU 183k1bs, SO 118
klbs, RotWt 145k1bs. ONBTrq
10kft-Ibs, OFBTrq 10kft-Ibs, Max Gas
64 units, ECD's 11.2 MWE.
11/17/2007 00:00 03:00 3.00 10,330 10,330 INTRM1 DRILL CIRC P CBU x 4 w/ sweeps while pumping @
645 gpm & 95 rpm. Hole condition
good, monitor well- no flow, pump dry
job, blow down top drive and prepare
for short tri to shoe.
03:00 09:00 6.00 10,330 10,330 INTRM1 DRILL WPRT P Wiper trip f/ csg, POOH to shoe. No
abnormal drag. No swab /gain /loss.
Correct hole fill.
09:00 09:30 0.50 10,330 10,330 INTRM1 DRILL OTHR P Clear floor.
09:30 11:00 1.50 10,330 10,330 INTRMI RIGMN SVRG P PJSM, Slip / cut drlg line.
11:00 12:30 1.50 10,330 10,330 INTRM1 RIGMN SVRG P PJSM, C/O worn saver sub (top drive)
12:30 13:00 0.50 10,330 10,330 INTRM1 RIGMN SVRG P Service rig /top drive.
13:00 16:30 3.50 10,330 10,330 INTRM1 DRILL WPRT P PJSM, RIH 5" DP (wiper trip) to 9887
ft.
16:30 18:30 2.00 10,330 10,330 INTRM1 DRILL REAM P Wash /ream 9887 - 10087 ft (6.8
dogleg) as precaution in prep for 7"
cs run.
18:30 19:00 0.50 10,330 10,330 INTRM1 DRILL WPRT P TIH f/ 10082' - 10272'
19:00 19:30 0.50 10,330 10,330 INTRM1 DRILL REAM P Finish short trip wash /ream to
bottom f/ 10272' - 10330'.
19:30 22:30 3.00 10,330 10,330 INTRM1 DRILL CIRC P CBU x 4 @ 630 gpm, rotate 100 rpm,
SPP 2800 psi. Pumped 2 Hi-vis
sweeps (1 weighted). Calc hole
washout at 0 %.both sweeps. Prep
for POOH w/ circulatin .
22:30 23:00 0.50 10,330 10,330 INTRM1 DRILL OTHR P Blow down top drive, monitorwefl f/
flow, PJSM f/ POOH & LD DP.
23:00 00:00 1.00 10,330 10,330 INTRMI DRILL OTHR P POOH w/ lay down 5" DP f/ 10330' -
9388'. PU 180 klbs, SO 103 klbs.
11/18!2007 00:00 14:30 14.50 10,330 10,330 INTRMI DRILL OTHR P POOH laying down 5" DP.
14:30 17:30 3.00 10,330 10,330 INTRM1 DRILL PULD P Flow check, LD HWDP, LD DCs /
dretnl assy, download MWD, LD
remainder BHA, remove from shed.
~~ge S ~~ ~7~
•
Time Logs
_
___ _
Date From To Dur S. D th E. De th Ph e Code Subcode T COM
11/20/2007 06:30 09:00 2.50 10,330 10,330 INTRM1 RPCO FRZP P RU /freeze protect well 7 X 9-5/8 ann
3318 ft. 2 bpm at 960 psi. Tot 100 bbls
diesel.
09:00 11:00 2.00 10,330 10,330 INTRM1 DRILL PULD P PJSM, load shed with 4" DP while
clear floor cs a ui with crane.
11:00 15:00 4.00 10,330 10,330 INTRM1 DRILL OTHR P PJSM, C/O saver sub, re-set top drv
torque to 4" specs. while install 5"
liners to um s. ---
15:00 19:00 4.00 10,330 10,330 INTRM1 WELCT BOPE P PU BOP flush tool, set test plug, C/O
rams to 4". ~"
19:00 20:30 1.50 10,330 10,330 INTRM1 WELCT BOPE P Rig up test equipment & test upper &
lower rams psi. Rig down
test a ui ment.
20:30 21:30 1.00 10,330 10,330 INTRM1 DRILL RURD P Change out rig tongs.
21:30 22:00 0.50 10,330 10,330 INTRM1 DRILL RURD P Set wear ring.
22:00 00:00 2.00 10,330 10,330 INTRM1 DRILL OTHR P Continue rack & tally 4"drill pipe.
11/21/2007 00:00 01:30 1.50 10,330 10,330 INTRM1 DRILL OTHR P Loading & strapping 4" drill pipe & rig
u eo-ta manifold.
01:30 04:30 3.00 10,330 10,330 INTRM1 DRILL PULD P PJSM-Make up BHA. Orient & upload.
04:30 07:30 3.00 10,330 10,330 INTRM1 DRILL DHEO P Pulse test MWD, fail test, C/O pulser.
07:30 09:00 1.50 10,330 10,330 INTRMI DRILL OTHR P PJSM, R/U, close blinds test 7" cs '
~
3000 si / 30 min. Test successful, no
re-tests. R/D test ui .
09:00 12:00 3.00 10,330 10,330 INTRM1 DRILL PULD P PJSM, MU remainder 6-1/8 dretnl
ass ,surface test same. RIH HWDP.
12:00 17:00 5.00 10,330 10,330 INTRM1 DRILL TRIP P PJSM, RIH 4" DP in singles from pipe
shed, rack bk to mast for drill out. PU
remainder in sin les to 7" float collar.
17:00 18:00 1.00 10,330 10,330 INTRM1 DRILL CIRC P Fill pipe. Circ. & test geo-span.
18:00 23:30 5.50 10,330 10,330 INTRM1 DRILL TRIP P RIH picking up 4" dp from 3257' to
9141'. U wt. 150k do 70k.
23:30 00:00 0.50 10,330 10,330 INTRM1 DRILL CIRC P Fill pipe & service top drive.
11/22/2007 00:00 01:30 1.50 10,330 10,330 INTRM1 DRILL TRIP P Finish picking up 4" DP & running in
hole to 10090'. MD
01:30 02:30 1.00 10,330 10,330 INTRM1 CEME DRLG P Wash down from 10090' to 10201' Tag
lu .
02:30 06:30 4.00 10,330 10,330 INTRM1 CEME DRLG P Drill plug & cement to float collar. Pick
up float collar @ estimated 10212'
DPM. & drlg. cement in shoe track.
150k Up 80k dn. rot 95k. 80 rpm 8k tq
245 m 2400 si.
06:30 08:00 1.50 10,330 10,330 INTRM1 DRILL CIRC P Torque build to high levels. Displace
well to new 10.5 drl fluids.
08:00 08:30 0.50 10,330 10,330 INTRM1 CEME DRLG P Resume drill cmt, guide shoe at 10298
ft.
08:30 09:00 0.50 10,330 10,370 INTRM1 DRILL DDRL P Drill ahead 6-1 /8 hole dretnl 10330 -
10370 ft for LOT.
09:00 10:00 1.00 10,370 10,370 INTRM1 DRILL CIRC P CBU for LOT, 6 bpm at 2100 psi.
~~ ~t3 of 57 ~
l I
l J
Time Logs _
Date From To Dur S. De th E. De th Phase Code Subcode T COM
11/22/2007 10:00 11:30 1.50 10,370 10,370 INTRM1 DRILL LOT P Flow check, PJSM, perform LOT at
10370 MD / 5282 TVD. Results =
1500 psi surface press / EMW 16 ppg.
No leak off.
11:30 00:00 12.50 10,370 10,581 PROD1 DRILL DDRL P Flow check, drill ahead 6-1 /8 hole
dretnl 10370 -10581'MD 5433' TVD.Up
wt 155k do 85k rot 110k tq on 8150
amp off 5940 amp spm 102 gpm 250
pp 2310 psi art 3.95 ast 2.3 max gas
1931 units ecd 12.5 (Problems
slidin
11/23/2007 00:00 05:30 5.50 10,581 10,731 PROD1 DRILL DDRL P Drlg. 6 1/8"directional hole from
10581' MD to 10731' MD.
05:30 06:00 0.50 10,731 10,731 PROD1 DRILL OTHR T Due to hi winds. Lost power on rig.
Electrician re aired roblem.
06:00 06:30 0.50 10,731 10,752 PROD1 DRILL DDRL P Drlg. 6 1/8"directional hole from
10731' MD to 10752. Up 160k do 80k
rot 105k rpm 60 wob 5ktq on 8500 off
5500 pp 2400 psi 250 gpm max gas
3440 units ecd 12.5
06:30 00:00 17.50 10,752 10,752 PROD1 DRILL WOW T W/O weather. Phase 3 conditions field
wide. Circ, re-ci i e.
11/24/2007 00:00 11:30 11.50 10,752 11,201 PROD1 DRILL DDRL P Drlg. 6 1/8"directional hole from
10752' to 11210 ft. (TD as determined
by CPAII Geo). ART = 7.14 hrs, AST
= 1.74 hrs. Normal drag /torque at
connections, no gain /loss. Conn gas
1100 units, back round 60 units.
11:30 14:00 2.50 11,201 11,201 PROD1 DRILL CIRC P C/C fluids, 6 bpm at 2500 psi. Shaker
.clean. No abnormal cuttings quantity /
ualit .Fluid tali er = au a hole.
14:00 15:30 1.50 11,201 11,201 PROD1 DRILL WPRT P Flow check, POH wiper trip to 7" shoe
10183 ft. No swab /gain /loss.
Correct hole fill.
15:30 17:00 1.50 11,201 11,201 PROD1 RIGMN SVRG P Flow check, slip / cut drlg line, service
ri .
17:00 19:30 2.50 11,201 11,201 PROD1 EVALVI~ DLOG P Flow check, RIH GEO Tap open hole
7" shot to TD at 11201 ft. (Take geo
sam les 10659 MD
19:30 21:00 1.50 11,201 11,201 PROD1 DRILL CIRC P Circ. @ 250 gpm 2490 psi pump 30
bbl. swee .
21:00 21:30 0.50 11,201 11,201 PROD1 DRILL CIRC P Monitor well & pump dry job.
21:30 00:00 2.50 11,201 7,243 PROD1 DRILL TRIP P POH for logs from 11201' to 7243' MD.
11/25/2007 00:00 03:00 3.00 11,201 11,201 PROD1 DRILL TRIP P POH for logs to BHA. No drag /swab /
ain /loss. Correct hole fill.
03:00 06:30 3.50 11,201 11,201 PROD1 DRILL PULD P Flow check, Handle BHA, download
MWD, LD dretnl assy.Unload pipe
shed.
06:30 07:30 1.00 11,201 11,201 PROD1 DRILL PULD T Well ercolating with slight
inter i nt flow. MU 6-1/8 cleanout
BHA, RIH same for circ.
07:30 10:00 2.50 11,201 11,201 PROD1 EVAL TRIP T Follow BHA with 4" DP to btm at
11201 ft. no ain /loss. No fill.
--- - P~~e 11 ~sf 1
i
•
I Time Logs
_
_ _
Date From To D r 5 De th E De th Ph e Code Suhcode T COM
11/27/2007 07:30 09:00 1.50 11,201 11,201 PROD1 EVALW RURD P PJSM with SLB Rig up wireline side
ent sub.
09:00 11:30 2.50 11,201 11,201 PROD1 EVALW OTHR P RIH with wire line to latch into wet
connect. Latch up & test. Blow down
to drive & install clam on wire.
11:30 15:00 3.50 11,201 11,201 PROD1 EVALW ELOG P RIH to shoe @ 10307' MD & log well
as directed by schlumberger to 10760'
MD. Made several attempts to get by
bridge @ 10760' MD. (SLB set 2500#
wireline wt. on bridge. Would not work
thru
15:00 16:30 1.50 11,201 11,201 PROD1 EVALW ELOG P Log well from 10757' MD to 10121'
MD.
16:30 18:00 1.50 11,201 11,201 PROD1 EVALW OTHR P Unsting & POH with wire line.
18:00 18:30 0.50 11,201 11,201 PROD1 EVALW TRIP P RIH with DP from 10121' MD to 10516'
MD.
18:30 21:30 3.00 11,201 11,201 PROD1 EVALW CIRC P Make up top drive &CBU. Condition
mud to 11.2#. Max as 350 units.
21:30 00:00 2.50 11,201 11,201 PROD1 EVALW TRIP P Blow down top drive & POH with
to in tools.
11/28/2007 00:00 03:30 3.50 11,201 11,201 PROD1 EVAL TRIP P PJSM-POH from 6830' MD to logging
tools.
03:30 05:00 1.50 11,201 11,201 PROD1 EVAL PULD P PJSM w/SLB & lay down logging
tools.
05:00 06:00 1.00 11,201 11,201 PROD1 DRILL PULD P Clean floor PJSM make up BHA for
clean out.
06:00 09:30 3.50 11,201 11,201 PROD1 DRILL TRIP P RIH w/ clean out assembly to 10300'
MD. U 125k do 75k.
09:30 11:30 2.00 11,201 11,201 PROD1 DRILL CIRC P CBU @ 4 bpm 1050 psi Circ out gas
max 600 units.
11:30 12:00 0.50 11,201 11,201 PROD1 DRILL TRIP P RIH from 10300' MD to 11201' MD.
12:00 12:30 0.50 11,201 11,201 PROD1 DRILL CIRC P Circ. Cond mud for liner. Packed off
while Circ. Circ. @ 2.3 bpm w/ partial
returns.
12:30 14:00 1.50 11,201 11,201 PROD1 DRILL TRIP T Back ream from 11201' to 10723' @
60 r m 5170 t 40 s m 780 si.
14:00 19:30 5.50 11,201 11,201 PROD1 DRILL CIRC T Rotate & reciprocate @ 70 rpm 60
s m 1060 si 5010 t . No losses.
19:30 20:30 1.00 11,201 11,201 PROD1 DRILL TRIP T Wash to bottom @ 11201' MD.
20:30 23:00 2.50 11,201 11,201 PROD1 DRILL CIRC P CBU. Rot & rec @ 70 rpm 4840 tq PP
1120 s m 60.
23:00 00:00 1.00 11,201 11,201 PROD1 DRILL TRIP P POH from 11201' spotting liner pill
while ullin i e to 10629'.
11/29/2007 00:00 00:30 0.50 11,201 11,201 PROD1 DRILL TRIP P Pump out to 10250' MD.
00:30 02:30 2.00 11,201 11,201 PROD1 GRILL OTHR P PJSM-Slip & cut drlg. line. Change out
bolt on deadline.
02:30 03:00 0.50 11,201 11,201 PROD1 DRILL CIRC P Pump dry job & drop 2.25" drift.
03:00 08:30 5.50 11,201 11,201 PROD1 DRILL TRIP P POH to run 4.5" production liner.
08:30 09:30 1.00 11,201 11,201 PROD1 DRILL PULD P Lay down BHA. Clean floor & unload
tools.
a _ ~ - - P~€~~ ~3 of 17~
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Time Logs
- --
Date From
To
Dur 5 De th E. De th Phase Code Subcode T COM ___
12!01/2007 __
20:30 _
21:30 1.00 11,201 11,201 COMPZ RPCO OTHR P Load pipe shed with all completion
com onents.
21:30 22:00 0.50 11,201 11,201 COMPZ RPCO SFTY P PJSM on running 3.5" Completion.
22:00 00:00 2.00 11,201 11,201 COMPZ RPCOh RCST P Run 3.5" completion to 1018' MD. Up
40k do 40k.
12/02/2007 00:00 02:30 2.50 11,201 11,201 COMPZ RPCOh RCST P Running in hole with 3.5" 9.3# L-80
IBTM completion from 1018' MD to
2844' MD. U 50k do 50k.
02:30 04:30 2.00 11,201 11,201 COMPZ RPCOh PULD P PJSM w/ crew & schlumberger. Rig up
3/8" SS chemical injection line to
KBMG-LTS CIM & test 5500 psi for 15
mins. OK.
04:30 16:00 11.50 11,201 11,201 COMPZ RPCOh RCST P Running in hole with 3.5" 9.3# L-80
IBTM completion from 2844' MD to
10129' MD. Making up 3/8" chemical
injection line & clam in same.
16:00 17:00 1.00 11,201 11,201 COMPZ RPCOR OTHR P Tag liner top@ 10122' MD No-Go
locator tagged @ 10131. Located
seals w/ 500 si & RIH to no- o to .
17:00 18:00 1.00 11,201 11,201 COMPZ RPCOh CIRC P Pump capacity of tbg. to flush out
same. 500 si.
18:00 19:30 1.50 11,201 11,201 COMPZ RPCOti HOSO P Space out. Pick up & make up hanger
& landing jt. up 98k do 56k. Pick up 2
10' u 'ts.
19:30 23:30 4.00 11,201 11,201 COMPZ RPCO CIRC P PJSM- Displace well to seawater @
300 gpm 1500 psi. & circ. bottoms up
X5 to ensure annulus is clean.
23:30 00:00 0.50 11,201 11,201 COMPZ RPCOh CIRC P Spot corrosion inhibitor & thread
chemical injection line thru han er.
12/03/2007 00:00 01:30 1.50 11,201 11,201 COMPZ RPCO HOSO P Test chemical injection line port on
FMC G-5 3.5" X 11" hanger to 5000
psi 10 mins. OK PJSM drain bops.
Land hanger & run in lock down
screws.
01:30 03:00 1.50 11,201 11,201 COMPZ RPCO DHEO P Rig up test lines. Pump down 3.5"
tubin & test 3.5" tubing to 2500 osi
for 15 mins.
annulus o en. Bleed 3.5" tubin down
to 1500 si & test 3.5" b 7"annulus
to 2500 si for 30 mins. & chart same.
Bleed pressure to'0' on 3.5" tubing &
shear valve set @ 2000 psi would not
shear. Pressure 3.5" X 7" annulus to
2800 si & sheared valve.
03:00 05:00 2.00 11,201 11,201 COMPZ RPCOti OTHR P Lay down 3.5" landing joint. SetCIW
"H" back pressure valve. Flush all
surface lines with safe surf.
05:00 06:30 1.50 11,201 11,201 COMPZ RPCOh OTHR P PJSM. Change Hydril blow out
preventer lower gate rams from 3.5" to
4.5" rams.
06:30 09:00 2.50 11,201 11,201 COMPZ RPCOh NUND P PJSM-Nipple down Hydril brand blow
out preventers double gate & annular
preventer drlg. nipple & flow line & set
back in cellar area.
~__.... ~ e ~'a~~ ~~ c~f't7
n
•
Time Loc~s_~ _
Date From To Dur 5 Depth E. De th Ph se Code Subcode T COM
12/03/2007 09:00 13:30 4.50 11,201 11,201 COMPZ RPCOh NUND P Clean well head, adapter & well tree.
Make up adapter & test void & packoff
seals to 5000 psi 15 mins. OK. Make
u well tree & dress same.
13:30 14:00 0.50 11,201 11,201 COMPZ RPCO NUND P Pull back pressure valve & set two
wa check valve.
14:00 15:30 1.50 11,201 11,201 COMPZ RPCO DHEQ P Test well tree 250 psi low pressure
test & 5000 si hi h ressure test.
15:30 16:00 0.50 11,201 11,201 COMPZ RPCOh RURD P Rig down all test equipment
associated with tests. Lines gauges
etc.
16:00 17:30 1.50 11,201 11,201 COMPZ RPCO RURD P Rig up little red services pump truck &
lines in preparation to freeze protect
well down 3.5" X 7" inner annulus with
135 bbls. diesel fuel @ 100 deg.
tem erature.
17:30 18:30 1.00 11,201 11,201 COMPZ RPCO FRZP P Little Red Services, pressure test lines
to 2500 psi begin pumping diesel
down 3.5" X 7" inner annulus @ 2 bpm
760 psi 100 deg. temperature &
pumped 135 bbls. Final pumping
ressure was 280 si. 2 b m.
18:30 20:00 1.50 11,201 11,201 COMPZ RPCO FRZP P Rig up tines for comunication from 3.5"
X 7" annulus to 3.5" tubing & allow
diesel fuel in annulus to'U' tube into
3.5" tubing. equalizing @ approximatly
3600' measured depth & 2515' total
verticle de th.
20:00 20:30 0.50 11,201 11,201 COMPZ RPCO NUND P Install CIW "H" back pressure valve in
back pressure profile & close swab
valve on well tree.
20:30 00:00 3.50 11,201 11,201 COMPZ RPCO OTHR P Clean mud tanks & surface lines in
preparation to take on seawater on
next well that is 2 micron.
Disassemble mud pumps for
inspection by Kent Kelly National
Oilwell representative. Inspected same
& reassemble mud pump 1 & 2.
Emsco 1000,s. (Final pressure on well
Tubing '0' Final pressure on 3.5" X 7"
annulus'0' Final pressure on 7" X 9
5/8" annulus 200 psi.) (9 5/8" X 7"
annulus was freeze protected prior to
drillin out 7" shoe.
12/04/2007 00:00 09:00 9.00 11,201 11,201 COMPZ RPCOti OTHR P Cleaning mud tanks in preparation
workover operations at KRU 2T pad.
Need to be clean enough to take on
seawater 2 micron.
09:00 11:00 2.00 11,201 11,201. COMPZ RPCO WOW T Phase III weather, activity restricted
due to reduced visibilit .
11:00 18:00 7.00 11,201 11,201 COMPZ RPCO OTHR P Cont cleaning pits, drain & clean rock
washer. Prep rig f/ move. Rig
released this date 12/4/07 @ 1800 hrs
for move to 2T ad.
~ ~~c~e 4' ~f 17
2L-330 Well Summary
DATE Summary
12/20/07 GAUGED TBG 2.70" TO 10967' SLM, MUD FROM 10400' TO 10967' SLM. SET CATCHER @
10087' RKB. PULLED 1" SOV @ 9932' RKB. DISPLACED TBG X IA WITH 350 BBLS DIESEL. JOB
IN PROGRESS.
12/22/07 SET 1" DMY VLV @ 9932' RKB. MITIA TO 2400#. PASSED. CATCHER PULLED. JOB
COMPLETE.
12/26/07 JETTED SLICK SEAWATER FROM SURFACE TO HARD TAG AT 11119' CTMD, JET WASHED
AREA OF FUTURE PERFS AT MAX RATE, DISPLACE WATER TO SLICK DIESEL FROM CT
TAG. WELL LEFT SHUT IN AND LOADED WITH DIESEL
12/27/07 DRIFT TO 11,093' SLM W/ 20' OF 2.6" DMY GUN W/ NO PROBLEMS. DRIFT TO 30' SLM W/
2.92" GAUGE RING, FOR TREE SAVER. JOB COMPLETE.
12/30/07 RAN A SCMT CEMENT BOND LOG
CEMENT QUALITY WAS GOOD FROM 11002' - 10724'
FAIR FROM 11088' - 11002' AND FAIR TO POOR 11724' TO 10167'
PERFORATED 11020' -11040', 6SPF HYPERJET, EH= 0,43, PENT= 13.1"
TAGGED BOTTOM AT 11096'
1/1/08 TAGGED @ 11,093' SLM, MEASURED BHP @ (11,030' RKB, 2508 PSI) GRADIENT @ (9932'
RKB,2226 PSI) IN PROGRESS.
1/3/08 PULLED DMY VLV @ 9932' RKB. REPLACED WITH 1" SPG. MITIA TO 3500#. PASSED. JOB
COMPLETE.
1/6/08 PUMP ESKER SAND FRACTURE TREATMENT USING 40# X-LINKED GEL AT 20 BPM.
PUMPED A TOTAL OF 87,168# OF 16/20 CARBOLITE PROPPANT PLACING 62,694# BEHIND
PIPE. FRAC SCREENED OUT WITH 6 PPA IN PERFS. PUMPED 550 BBL BRACKET FRAC
PRIOR TO SAND STAGES. RECOVERED 50% OF TREESAVER RUBBERS. WELL NOT
FREEZE PROTECTED.
1/18/08 Attempt Fill Clean Out, Cleaned out frac sand from surface to 7500 CTMD, Lost partial hyd pressure
for injector, POOH to repair, Will rtn in A.M.
1/19/08 Perform Fill Clean Out, Cleaned out frac sand from 7500 CTMD to hard tag of 11089 CTMD. Well is
freeze protected. Turned over to S/L.
1/20/08 TAG BOTTOM @ 11080' SLM. EST 56' OF RATHOLE. SET 2.8" CATCHER @ 10,071' SLM.
PULLED 1" BKSPG @ 9932' RKB. LDFN, JOB IN PROGRESS ""**"CATCHER STILL IN HOLE**"**
1/21/08 SET 1" OV @ 9932' RKB. DRAW DOWN TEST GOOD. PULLED EMPTY CATCHER @ 10,071'
SLM. JOB COMPLETE.
ConocoPhillips
Transmittal #722 Detail
Date: 1/31/2008
Transmittal Info:
Sent Via: Hand Delivery Tracking #:
Justification: 2L-330 AOGCC Compliance
Data Detail:
To (External Party):
Email: howard.okland@alaska.gov
First Name: Howard
Last Name: Okland
Phone (907) 793 -123 5
Number:
Company: AOGCC
Address: 333 W. 7th Ave., Ste. 100
City: Anchorage
State: AK
Zip Code: 99501
From (PAI Contact):
Email: richard.e.elgarico@conocophillips.com
First Name: Ricky
Last Name: Elgarico
Phone (907) 265-6580
Number:
Company: CPAI
Address: 700 G St. ATO-1484
City: Anchorage
State: AK
Zip Code: 99501
Type
Quantity Description
1 2L-330 Tarn Field Epoch Final Report with
enclosed color mudlog prints and CDROM
Attachments:
Filename: None Filesize: N/A
Received By:
Signature:
Approver:
Signature:
Alesk~ Ail & Gas Cons. CQ(TIt111S310~
Date:~e~
Date:
Report with CDROM
~~~EIVED
:1AN ~ ~ ~9Q~
ab~ - t2$
WELL LOG TRANSMITTAL
To: State of Alaska January 23, 2008
Alaska Oil and Gas Conservation Comm.
Attn.: Librarian
333 West 7~' Avenue, Suite 100
Anchorage, Alaska
RE: MWD Formation Evaluation Logs 2L-330 AK-MW-5232602
1 LDWG formatted CD Rom with verification listing.
API#: 50-103 -205 54-00
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
y~
f
Date. ' ~`~'~~'
Signed:
o2p'~- `'lo`w ~ l5`a5~'
174~1''#1~~~s~~r1-
Schlumberger -DCS
2525 Gambell Street, Suite 400
Anchorage, AK 99503-2838
ATTN: Beth
Well Job #
~.
Log Description
N0.4550
Company: Alaska Oil & Gas Cons Comm
Attn: Christine Mahnken
333 West 7th Ave, Suite 100
Anchorage, AK 99501
Field: Kuparuk
Date BL Color CD
01/11/08
1J-164 11964565 INJECTION PROFILE L 01104/08 1
3Q-22 11970623 PRODUCTION PROFILE - J 01/04/08 1
3R-21 11964567 LDL 01106/08 1
3J-12 11970620 INJECTION PROFILE Z j - ~ 01101108 1
3H-10B 11964562 PATCH EVALUATIONILDL {]ZC (~ -- ~ 01/01/08 1
1F-01AL1 11994591 FLOWING BHP SURVEY ~ 12/20/07 1
2N-342 11964561 OILPHASE SAMPLER "~- _ 12/31107 1
2L-330 11970618 SCMT - a 12/30/07 1
2A-20 10194199 RST - ~ 10/30/07 1 1
2X-19 11850441 RST '- ~ ~` ~ 07/09107 1 1
Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you.
n
~J
10-Jan-08
AOGCC
Attn: Christine Mahnken
333 W. 7th Ave. Suite 100
Anchorage, AK 99501
Re: Distribution of Survey Data for Well 2L-330
Dear Dear Sir/Madam:
Enclosed are 2 survey hard copy(s) and a disk with the *.PTT and *.PDF files.
Tie-on Survey: 30.65' MD
Window /Kickoff Survey: 0.00' MD (if applicable)
Projected Survey: 11,201.00' 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 ~ ~ ~ ~ ~ ~
n m ,
Date < ~ atho ~ Signed ~~`u'w-c~ l-~ ~'~~- `~
Please call me at 273-3534 if you have any questions or concerns.
Regards,
Timothy Allen
Survey Manager
Attachment(s)
~.~7~ ~ ~~
12/20/07
~~~~~~
N0.4532
Schlumberger -DCS ~ ~' ~° ~ ~ ~_ ~_-r~
2525 Gambell Street, Suite 400 `- Company: Alaska Oil & Gas Cons Comm
Anchorage, AK 99503-2838 Attn: Christine Mahnken
ATTN: Beth ~ ,9 a_ °~~ ~`. ~~ ~~ ~~~ ~ 333 West 7th Ave, Suite 100
Anchorage, AK 99501
Field: Kuparuk
Well Job # Log Description Date BL Color CD
•
1J-105 11837540 INJECTION PROFILE ~''~'1'~-Cl'~'~ 11120107 1
1A-06 11837542 _
RST WFL °~'t ~~~~ ;. 11/22/07 1
1Q-05 11837537 _
LDL ~ - ( 11117107 1
1B-12 11970607 INJECTION PROFILE 'i' 12/04/07 1
2N-327 11996582 OILPHASE SAMPLER Q~- (A 12115/07 1
1D-132 11994588 SBHP SURVEY ~(. - ~ 12/17107 1
3H-10B 11996580 PATCH EVALUATION 12/13107 1
3N-02A 11970609 LDL '$ - 12/05/07 1
1C-125 11964553 INJECTION PROFILE - 12/01107 1
2M-15 N/A PRODUCTION PROFILE r (" 12/10107 1
2M-11 NIA PRODUCTION PROFILE ~q - 12108/07 1
3A-03B 11970604 SCMT ( 12/01/07 1
2T-217A 11978431 SCMT 12/15107 1
2L-330 11837544 FULLBORE MICRO SCANNER 11127/07 1
2L-330 11837544 SONIC SCANNER 11/27/07 1
Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you.
Message ~ ~ Page 1 of 2
Maunder, Thomas E (DOA)
From: Thomas, Randy L [Randy.L.Thomas@conocophillips.com]
Sent: Tuesday, November 27, 2007 6:23 PM
To: Maunder, Thomas E (DOA)
Cc: Greener, Mike R.; Eggemeyer, Jerome C.; Thomas, Randy L
Subject: FW: BOP 2L-330 11-24-07 Contractor Rig No 11-14-07p (version 1).xls
Attachments: BOP test 11-24-07; 11-26. pdf; 11-23. pdf; 11-24.pdf; 11-25. pdf
A little more information. They reached TD of the well on the morning of 11/24, the same day they were due for
their 14 day BOP test. Knowing they could not be out of the hole and testing BOP before midnight, they
discussed the timing issue with John Crisp of AOGCC. His advice was that if they started testing some
components of the system on the 24th, they would be in compliance with the 14 day deadline. So they were
testing components such as the choke manifold while they were tripping out of the hole, with the intent to follow
up with testing the stack once they were out of the hole in the early morning hours of 11/25. After laying down
BHA, the well showed signs of gas cut mud at surface. They decided to run back in the hole to condition mud and
ensure the well was stable for testing the stack, logging and running liner. This delayed the final test of the stack
until late the night of 11/25. The initial tests of the manifold while tripping out were not noted on the WeIlView
morning reports, but were noted on both the BOP test report and the IADC tour sheets. The morning reports
focused on the core operations related to the well (i.e. tripping) and not on any operations done simultaneous with
tripping out of the hole.
Actions to take on our part include (1) ensuring that our morning reports record any operations related to
regulatory compliance and (2) ensuring our Drilling Supervisors look for opportunities to cover any BOP tests well
within the 14 day window and not exceed this window.
Give me a call if you need any further information.
Randy L. Thomas
Kuparuk Drilling Team Lead
907-265-6830 office
907-244-5205 cell
907-222-6088 home
Randy. L.Thomas@conocophillips. com
-----Original Message-----
From: Greener, Mike R.
Sent: Tuesday, November 27, 2007 4:14 PM
To: 'Maunder, Thomas E (DOA)'
Cc: Thomas, Randy L
Subject: RE: BOP 2L-330 11-24-07 Contractor Rig No 11-14-07p {version 1}.xls
A brief summary of the event:
1. The test started just before midnight on 11/24.
2. The test was stopped to RIH due to "gas cut mud at surface".
3. After running in and conditioning the hole, the rig POOH and the test resumed just
before midnight on 11125.
4. The test was finished at 03:30 on 11/26.
4/8/2008
Message ~ ~ Page 2 of 2
The BOP test form (attached) shows this scenario in the remarks section of the report.
MW on the 11//24 was 10.8 and increased to 11.1 to POOH. After going back to bottom
and circulating, the MW increased to 11.2 and we circulated out of the hole to the
intermediate shoe. This kept any gas from entering the wellbore and they were able to
POOH and then finish the BOP test without the well acting up.
Attached are the reports for this time interval.
If more information is needed, please reply.
From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov]
Sent: Tuesday, November 27, 2007 8:29 AM
To: Greener, Mike R.
Cc: Thomas, Randy L; Jim Regg
Subject: FW: BOP 2L-330 1i-24-07 Contractor Rig No 11-14-07p (version 1).xls
Mike,
Your name is on the permit application, so you get the message.
Attached is the 11/24 -11/26 BOP test report from Nordic 3 on 2L-330.
The following comment is included,
"Test started 11/24/07 @ 23:OOhrs, Stopped test, RIH due to gas cut mud at surface. Circulate and condition mud,
POOH continued test 11/25!07 @ 23:30. finished test 11/26/07 @ 03:30".
I am requesting further information on this event. Please include the daily reports from 11-23 to 11-26.
Call or message with any questions. 1 look forward to your reply.
Tom Maunder, PE
AOGCC
From: Nordic 3 Tour Pusher [mailto:n1614@conocophillips.com]
Sent: Monday, November 26, 2007 8:53 PM
To: Regg, James B (DOA); aogcc_prudhoe_bay@admin.state.ak.us; Fleckenstein, Robert J (DOA)
Subject: BOP 2L-330 11-24-07 Contractor Rig Na 11-14-07p (version 1).xls
4/8/2008
-----
Security Level: Development,
Daily Drilling Report
2L-330 ''
~ Report Number: 21 !,
tig: NORDIC 3 Report Date: 11/23/2007',
--E rV•.;a N~In T;f ~IG# - it v.rE •~,; ~,
1
e s(ftj
De 5t81(
ftK6) Dep
B)~
DFS
(
a
y
) Do
,DepthP~rogres
i
O
1
9
4
2
t O
O
2L
Development
330
iTARN PARTICIPATING AREA
10,752.0
_ _
Daily Mud Cost Cumulative Mud Cost TDally Cost Total ;Cumulative Cost
11,945.43 354,743.55
~ Actual Start Date Original Spud Date AFE Dur Total (days) j 147,599.43 3,693,585.55
i Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date
11/3/2007 11/4/2007 26.85 '; 40.64 -13.79 12/13/200715:22
Last Casing String Next Casing OD (in) Next Casing Set Depth (ftK6)
Intermediate, 10,307.4ftK6 4 1/2 11,191.00
Ops and Depth ~ Morning Report 24hr Forecast
Drlg 6 1/8"directional hole @ 10946' MD 5725' TVD
Last 24hr Summary Get released from phase 3 & drill to estimated TD @ 11201' MD.
Drilled hole from 10581' to 10752' MD. Hi winds phase 3. Shut down & Wai t on weather.
General Remarks ~ Weather i Head Count
No Accidents. No Spills.! Temp 19 deg. Wind E 26 gust 35 CF 1 deg. , 40.0
Dave Morns, Dnfliny Supervisor
Dink Heim, Drilling Supervisor
Ronnie Rice, Tool Pusher
Andy Anderson, Tour Pusher
Time Loy
>.art Ead =rug
~._ `ors ,nrs: F'r,i,r
~..icen~so, T r,:
Dulling Supernsor
~ Drilling Supervisor
!Tool Pusher
~TourPusher ~!
F:n~.a ^optn tit ;1 ~~o:h E~i 1
.-__ C:~I: i.t ~o~]e ~ IdT -. ~o~e '~rt~l 'I~s_, iitr;~; yin, ~ I
~r. r_r
IU:UU U5:3U 5.50 YKUU1 UKILL ~ UUKL IN
', 10,581.0 1U,731.U~Uflg.61/8"dlreCtlOnalh0letrom1U581'
MD to 10731' MD.
15:30 06:00 0.50 PROD1 I DRILL OTHR ' T ~ Non-rig Highline 10,731.0 10,731.0 Due to hi winds. Lost power on rig.
'Surface Eqp Power Electrician repaired problem.
16:00 06:30 0.50 PROD1 DRILL DDRL 'P ~', 10,731.0 10,752.0 Drlg. 6 1/8" directional hole from 10731'
i MD to 10752. Up 160k do 80k rot 105k
!rpm 60 wob 5ktq on 8500 off 5500 pp
2400 psi 250 gpm max gas 3440 units
ecd 12.5
16:30 00:00 17.50 PROD1 DRILL WOW - ~T Other Wait on~ ~ 10,752.0 L
10,752.01 W!O weather. Phase 3 conditions field
i Bather
W wide. Circ, re-cip pipe.
Mud Check Data
i','~:- . r n<e:, r ica;,,i
Water ~ 10,752.0, 10.701 ~ -~~,~ ,_~, ibin~2.• ~ 'ct .:~,.rt~~ itr ~~ irr: rt-~ ~~?tr
45~
14.0 j 27.000', 11.01 13.0 14.000 rn~i i:r r,~
1.3 ~ - __~~~
8.3
Based Mud
!
!
Water
10,752.0
10.701 I
441 16.0,1 27.0001 12.01 14.0
14.000
1.3
5.4
Based Mud
'
I
_ _
rill 5trin s: BMANo. 5 - 6 1/8" PRODUCTION ! Btt Run No. 3
__ __ g RZ - 4 1/2irr, HYCALOG. DS69~NPV, 202328
_ - ----
De th In ftKB De th Out ftKB TFA (incf Noz m Nozzles (!32"j IADC Bit Dull
10,370.0 10,752.0 0.02 ~
5 ~ ----
. Drill String Components _
_
-- _
t~:,~ r~ ~ ~r~„~ T~r ;,~; ~ ,~~~; T is ~ ;~ _ . ,
.Mud Motor-Beni Sub ~ 5.02 2.ts20i s 1r
Stabilizer 4.76 2.250; 3 1
i ;Float Sub 4.76 2.250 ~ 3 1
~i ;Float Sub
~ I 4.76, 2.2501 31
! MWD (Directional) 1 4 3/4 i 2.125 ~ 3 1
' MWD (Dir & Logging) I~ 4 3/41 2.125 3 1
I, MWD (Dir & Logging) !, 4 3/41 2.125 3 1
MWD (Dir & Logging) 4 3/4 2.125 3 1
MWD (Directional) 4 3/4 ~ 2.1251 3 1
~, Stabilizer 4 3/4! 2.625!, 3 1
,Drill Collar -Flex Non Mag 4.78; 2.688 j 3 1
Drill Collar -Flex Non Mag ' 4.65j 2.313, 3 1
Latest BOP Test Data
__
Oate , -,. ~ .-n ~ rn
11/10/2007 (Test ROPE [50 to / 3500 hi. No Failures NEXT BUF' TEbT: Y4-Nov-2007 AUCiGG witness
li Page 1/2
,~s~i: T,. ;~a~,~~ ;:~~~~r
~i °F;
9.5 ~ 10.O
I
!
9.6 ~, 10.O
String Wt (70001bf1
---
,~~ ~, ~.,n ~~ _~,~, ,
Z,IF ; z4A9~
2 IF j 29.62!
2'IF ~ 31.99
2'iIF 34.07;
2 j IF 42.97'!
21F 67.47!
2 IF 92.93,
2', IF 116.93 j
2 IF 128.21 '.
2!IF ~ 133.601
2 ~, I F 164.77
2' I F /
/
/
!
/
/
/
/
/
/
/
195.89
---
d by shuck 5hieve.
Report Printed: 11/27!2007!
~ ~
Security Level: Development
Daily Drilling Report
2L-330
tig: NORDIC 3
(Drill String Components
__. _.__
!~, ~~,~r-r i,~oor C'n ~-ni ~C;~,o; ~{[:n m.~~,,~,;i) rca m~a-~ u: r.; r:n ~Ftt
Dnll dollar -Flex Non Mag 4.81 2.6268 3 1/2 ~ IF ~ 22(1.94;
XO Sub 4 5/8 2.250 3 1/2( X7-39 j 228.231
HWDP 4 2.563 31/2 XT-39 258.67'
Drilling Jars -Hydraulic 4.79) 2.250 3 1/2 XT-39 287.49
HVVDP 4~ 2.563 3112 XT-39 409.11
Drilling Parameters
_ _.
Floar FaIB ~I
..I6f~ ~.ilh:" ~.;J ~, tb t! _.. -. CEprP~ (h C~.~~r . iili . une r~ 5 T iii: ihi. ,-P"i'1 ; !R~7 if`~ni ,F 4 s' 'r:'%~' 1Gi: I! r, Oul~h ~~ a,.in T~~ Dr,ll Ty
L 10 ,31 ii 10.'52 0 382 00 ~ 02 1.27 250 12 [ t;[ ?.310.0 155 1 1~i SS [, ~i40 0 '. 1°~[
0
'rrDrill Strings: BHA No. 6 - <Drill Strin g Name?> / Bit Run No. <Bit Run?> - <Drill Bit?>
Depth In (ftFBl Depth Out (ftKB TFA (incl Noz) (in') I Nozzles (/32") (ADC Bit Dull String Wt (10001bf)
10 U O 11,201.0 ~ i - ----
Drilling Parameters _ _ __
r._., .,_
un(1
~ lcr,; -f .~ra1 ~ ,If d.l l!. d .`_ ~ :.I -;fir ;~,1
t-c ~tt~r~ Erd ri~~; ~.u-r r,,,;ll~~, ~cr.,L,u lime (hr Tu
_:..~ ~, ~,% ,. ~e!Ibi ~~~`~' ~r[;[s~, 1ec51C r^,r~?. ~r.ri ~1~.~~~'Itq ,.f Btm Ty Ci-~>Ta
~1 i 5l'~I [ 10.-i1 0 40t0U 7.05 1 -8 25~) F. (? r0 3 au0 0 155 110 = GOn O 8 su[ 0~
' Wellbores
Wellbore Narne We llbore API/UWI ~
2L-330 5010320554
COND1 I~ 16 0.01 110.011/3/2007 1 11/3/2007
SURFAC !,
121/4
110.0(
3,335.011/4/2007
11/7!2007 i
i
INTRM1 I 8 3/4 3,318.0(, 10,330.0 11/11/2007 11/16/2007
'.
!PROD1 ~! 61/8( 10,330.0! 11,201.011/22/2007 11/24/2007 '
Survey Data
.
ra,~,ere; i~:a,`; -~m~~~ r._~,;i,~', aifr, ri;rrn F.:;rr,
n ~~o-:n~
10,617.83,
10,712.50'
Report Number: 21
Report Date: 11/23/2007
Page 2/2 Report Printed: 11/27!2007'
•
M
Daily Drilling Report
Security Level: Development
1 2L-330
~ Report Number: 22
~ Rig: NORDIC 3 Report Date: 11/24/2007
I. Type i z~a~o rJ~~ ~ T~~tal ~~.I-~ ~ c_ ~..ip
Drilling /0158757 I 5,551,85ti.Ot1
Wellbore Well Type Field Name DFS (days) DOL TDepth Progress (ft) ,Depth Start (ftKB) Depth End (ftKB)
2L-330 Development TARN PARTICIPATING AREA 20.42 22.0 '' 470.00 10,731.0 11,201.0
~
-
----
Daily Mud Cost Cumulative Mud Cost
Daily Cost Total
(Cumulative Cost
10,459.42 365,202.97 ~ 190,293.42 3,883,878.97 I
Actual Start Date Original Spud Date AFE Dur Totai (days) i Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date
11 /3/2007 11 /4/2007 26.85
_ i --- ' 41.64 _ ~ -14.79 ~ 12/14/2007 15:22 j
Last Casing String Next Casing OD (in)
Intermediate, 10,307.4ftK6 Next Casing Set Depth (ftKB)
i
Ops and Depth @ Morning Report 24hr Forecast
Downloading & laying down BHA. POH-test bope-rig up & run logs.
Last 24hr Summary
Finish drlg. to TD @ 11201' MD. Wiper trip. Take geo tap samples. CBU & poh for togs.
General Remarks Weather Head Count
No Accidents. No Spilis. Temp 18 de g. Wind ESE 14 CF 4 deg. 40.0 ,
Dave tviorns, Drilling Supervisor
Dink Heim, Drilling Supervisor
Ronnie Rice, Tool Pusher
Andy Anderson, Tour Pusher
Tirne Log
~~c e,ct c~
- ~ „r
u~~_~~~_~~ n~l~
! Dnlhng Supervisor
Drilling Supervisor
jTool Pusher
TourPusher
nn,= ~ n ~ :,i ad
I UU:UU
I 11:30 ! 11.5011'KUU1 !
I ~
i UKILL UUKL
I
i
i F' I
~
i li 1 U,75L.OI 11,ZU1.U Ung. 13 1/S" tllrectlonal Hole trom 10752'
I i to 11210 ft. (TD as determined by CPA( l
Geo). ART = 7.14 hrs, AST = 1.74 hrs.
I ', I Normal drag /torque at connections, no II
I, gain /loss. Conn gas 1100 units,
!,background 60 units. I
11:30
14.00 2.50 PROD1
DRILL
CIRC ~
P i 11201.01.11,201.0
+ ; C/C fluids, 6 bpm at 2500 psi. Shaker
I ~ I ;dean. No abnormal cuttings quantity /
' ; ;quality. Fluid caliper =gauge hole.
I
14:00
PROD1
15:30 1.50
DRILL
WPRT
P 11,201.01 Flow check, POH wiper trip to 7" shoe
11 201 0
~ 10183 ft. No swab /gain /loss. Correct
15 301
'
'-
17:00 1.50!, PROD1
~
RIGMNT
SVRG
-~ -------
P ! , ~ hole fill.
---- - ~ - - -- I
11,201.Oj 11,201.O~FIow check, slip /cut drlg line, service
~ , I rig
~
17001
`~ ~ - ~ -
1930: 2.50 PROD1 I ~
EVALWB -~
DLOG ~ --
P __
j Flow check, RIH GEO Tap open hole 7`' j
11,201.01 11 201.0
j L ~ ~ shot to TD at 11201 ft. (Take geo
9
0+ t
.
!
~~ samples 10659 MD)
I 1
0
~
'
1
3 21.00
1.501 PROD1
~ DRILL CIRC P 1,201.0
Circ. @ 250 gpm 2490 psi pump 30 bbl.
11,201.
1
! I sweep.
1
2.5p PROD1
0 DRILL CIRC P 11,201.OiMonitorwell&pumpdry job. j
±11,201.0
21 01 00:0
'
PROD1 DRILL ! TRIP P ~ 11,201.01 7,243.01 POH for logs from 11201' to 7243' MD.
Mud Check Data
I - I i n,, I ;r r~r I ~~i r -~,yr~~ F _ _ds -.
,e
I Depth (ftHFf r_ h~oa~ ~i.
_.~-
~ ~ 'q,; - r_,,:.- II' ,~_._ 1 ~br i .. It 7 rt. . ~1~.*t t.__,..t _r -,~ ~=i.
~
~
~Water
11,20 i.0 11.10 441 19.0 26.0001 10.0 13.0 14.000 1.b. 6.0~
9.5 !
11.1
;Based Mud ~
Water 11201.0~I 10.801
451 15.0
28.000
10.0 I I~
13.0 14.000, 181 6.71 9.5 i I
~ 10.0
Based Mud
~ ' ! I
'
( ~
i I
~ 1
,
r
Drrll Strings: BHA NO. 5 - 6 118" PRODUCTION 1 Bit
Run No. 3R I
R2 - 4 1/tin, HYCALOG, DS69FNPV, 202328
I Depth In (ftKB) ,Depth Out (ftKB) TFA (incl Noz) (in-) .,Nozzles (132") IADG Bit Dull I Stnng Wt (TOOOIbf)
! 10,370.0 I 10,752.0 0.02 5 ------
Drill String Components
,its L'-~-~ ~ ; c;u,ai ??G iu ~; a i~n7 I : p 7_ ,r i Sr ;i^~~ r ~~~ 'i a»rl ~'; ._~~c ~.f~
Niud Motor -Bent Sub ~ 0 ' 2.820; 3 1.z 111- ~ 24.u9'
Stabilizer a , ~ 2.2501 31/2~IF I 29.62
r - - -- - -_-- --- - - - -- - __
-- -- - __
Latest BOP Test Data
,rv .~:
111/1 (1/2007 Jlest.tiUNt2501o:/35UOhi._NOl=allures NEXI EiUPTt5T.24-Nov 2007 AUCis;Gwrtnesswawedbyc;huckShieve._ ___ ___ __~
Page 1/2 Report Printed: 11/27/2007~'I
Security Level: Development
Daily Drilling Report
2L-330
tig: NORDIC 3
(Drill Strin g Components
_. I'ein~ -r~~ptior :`C; [ink ~p rnl -- __~ ~
r, wn ~-~ ,.n, fnp -~itdd Cuin'_a^~`G
.
Float Sub ~ 4.76 1 2.2501 31/2~ IF 31.99
Float Sub 4.76 2.250 3 1/21 1F 34.07
MWD (Directional) 4 3/4! 2.1251 3 1/21 1F 42.97
MWD (Dir & Logging) 4 3/4 2.125; 31/21 1F 67.47
MWD (Dir & Logging) 4 3/41 2.125' 3 1!2 ( IF 92.93
MWD (Dir & Logging) 4 3/41 2.125; 3 1/2 j IF 116.93
MWD (Directional) 4 3/4 2.125 3 1/2 IF 128.21
Stabilizer 4 3/4 2.625; 3 1/2 IF 133.60
Drill Collar- Flex Non Mag 4.78 2.6881 3 1/2 IF 164.77
Drill Collar -Flex Non Mag 4.65 2.3131 3 1/2 IF I 195.89
Drill Collar -Flex Non Mag 4.81 2.68811 3 1/2 IF ( 226.94
XO Sub 4 5/8 2.2501 3 1/2 XT-39 228.23.
HWDP 4 2.5631 3 1/2 XT-39 258.67.
Drilling Jars -Hydraulic 4.79 2.2501, 3 1/2 XT-39 287.4£
l N WDP 4 2.563 I 3 1 /2 ~ XT-39 409.11
Dtill Strings; BHA No. 6 - <Drill Stnng Name?> / Bit Run No. <Bit Run?> - <Orill Bit?>
(Depth In (ftKB) Depth Out (ftKB) TFA (incl Noz) (in') Nozzles (132") (ADC Blt Dull String Wt (10001bf)
10,330.0 1 1 201 0 - --
Drilling Parameters
-
--
F~~ =:3~r
~;~t ftKF~.~ End ftKB '
C ~ ) C ~ ~-t -..unC Illirra :!. ~
~r~.r . ':-na ltr ~P~"~' ;2, I_~.^~ ~. rms. n. i.~:f ~;,~~~ L9 f1'
R`; ~~~Ita;
f GIi=~'q C~ r~ T~
~ 10.73LG~ 11,201.0 571.Ou, 14.1, 1.4~ 2501 5.0 ~Gi ~,400.u 1::,;., llui .`;5, S,SOO.ui 5,50u.01
Wellbores
~ Wellbore Name Wellbore API/UWI
2L-330 5010320554 ~
__,.,.i hn! ,~..-t 't kt;:~ A.ct 2.i rip'..; S.L ~f1a:q E`~,I Cate
C;UND1 I 1 Ei . 0.0 110.0 11 /312007 11 /3/2007
SURFAC 121/4 110.0 3,335.0
11/4/2007 11/7!2007
INTRM1 8 3/4~ 3,318.0 ,
10,330.0 11/11/2007 11/16/2007
PROD1 I 6 1 /8 10.330.0 11.201.0 11 /22/2007 11!24/2007
Survey Data
rn~~ rrrno~ ,
~ ~ „z n ; ~ r. ~ ~rw.~~~~, . ~ ~r~; ~~~ r„ _. ~~q C ~ i9rt~~
10,806 .$1
~i 36.831 14610
1 5,oG5.89 8,511.151 -b,521 .19; 5,525 .52f 1.73
10,901 .95'1 35.641 146.13 5,686.63 8,567.41: -6,567 .90; 5,556 .89 1.25
10,997 .26 35.4 146.50 5,764.19 8,622.781 -6,613 .99 5,587 .61 0.32
11,092 .19', 2
32.64. 145.641 5,842.86 8,675.891 -6,658 .071 5,617 .25 2.97
11,161 .921 32.251 146.24 5,901.71 8,713.30!. -6,689 .061 5,638 .20 0.73
-_ _ 11,201
____
.00
_ I 1
32 25',
__..__.
146.24
_. _____._ _-~_-_
5,934.76
8,734.15;
6,706
-- ____.
.40,_,_,_.__
. i 5,649
_ _ .79 0.00
Report Number: 22
Report Date: 11/24/2007
Page 2/2 Report Printed: 11!27/2007
A' _~ \
Daily Drilling Report
Security Level: Development
~
LL-JJV
~
~ Report Number: 23
Rig: NORDIC 3 Report Date: 11/25/2007
_~rp+; New orbJiDZ
Drilling 110198757
Wellbore Weil Type Field Name DFS (days) t -E+Sap
5,551,856.60
DOL Depth Progress (ft)
Depth Start (ftKB Depth End (ftKB)
2L-330 Development TARN PARTICIPATING AREA ! 21.42 23.0 0.00 11,201.0 ~ 11,201.0
-
Daily Mud Cost 'Cumulative Mud Cost Daily Cost Total iCumulative Cost
4,772.90 369,975.87 129,509.90 i 4,013,388.87 '
Actual Start Date Ori mal S ud Date AFE Dur Total da s i Pro'ected Job Duration da Job Da s Ahead da P eras cted Job End Date
9~ P ( Y) 1 ( Ys) Y ( Y) 1
11/3/2007 _ _ 11/4/2007 26.85 L._„__ ____ 42
Last Casing String Next Casing OD (in) .64 -15.79 12/15/200715:22
Next Casing Set Depth (ftKB)
Intermediate, 10,307.4ftK6 ~
Ops and Depth @ Morning Report
Rigging up Lubricator for E line logs. 42 h er orForF cast
~ Finish testing bope. Rig up lubricator & run E line logs. Rig down &
RIH for clean out run.
_
Last 24hr Summary
~ POH-run back in hole due to gas perculating. CBU raise mud wt. to 11.2. POH. Test bope.
I
~
I--- -- - --- -- -
,General Remarks
No Accidents. No Spills. {
_ I
Weather THead Count
Temp 5 deg. Wind ESE 8 CF -7 deq. i 40.0 ~
Dave Morris, Drilling Supervisor
Dink Heim, Drilling Supervisor
Ronnie Rice, Tool Pusher
Andv Anderson. Tour Pusher
Time Log
c~,d ~~,-
rr~- _i r , rCrs; N~tis~
Drilling Supervisor
Drilling Supervisor
Tool Pusher
TourPusher
C FL.~ Stmt .r~~-h 6.id
,r~~J-, ~='.p t --_.,_ '~~' 'itl ;;die TrC, _I -," iG!?; ~t ~: ii;
li 00:00 03:00 3.00 PROD1 DRILL ' TRIP P I 11,201.0 11,201.0 POH for logs to BHA. No drag !swab /
~ gain /loss. Correct hole fill.
003:00 06:301 3.50 PROD1 DRILL PULD iP ~ I 11,201.0 11,201.O~Ftow check, Handle BHA, download
06:30 07:301 1
00 PROD1 DRILL
'- -
PULD T ~1Nell Control Gas Cut 11
201
0 201 p MWD, LD dretnl assy.Unload pipe shed.
-
Well percolating with slight intermittent
11
.
I i Mud
~ I ,
. ,
flow. MU 6-1/8 cleanout BHA, RIH same
for circ.
107 30
10:00 2.50 -
PROD1
EVALWB ---
I --- - -- - ----- ----
TRIP ~T 'Well Control Gas Cut
11,201.0 ----
11,201.0 Follow BHA with 4" DP to btm at 11201
I Mud ft. no gain /loss. No fill.
10:00 13:00
3.00 PROD1 EVALWB CIRC
W tl Control Gas Cut 11,201.0 11,201.0 C/C fluids, increase density to 11.2 ppg.
i I
Mud I Flow check, well breathing slightly. Flow
back 4.5 bbl, lose 3.75 bbl, then stable.
~ 13:00
15:00 I 2.00
PROD1
EVALWB
TRIP I T 'Well Control Gas Cut
11,201.0 1
I
11,201.01 Flow check, POH, pump out to sh aeo s
i i Mud swab precaution. j
!,15:00 15:30 i 0.50 ~PROD1 EVALWB ~
TRIP T Well Control Gas Cut 11,201.0 11,201.0 Flow check at shoe, wellbore static. i
( _ Mud
-----._
r
Gas Cut
WellControli,
11,201.0
11,201.0; Resume POH 4" DP for E-logs to 4836'
199:00 19:30 0.50i PROD1 EVALWB I Mud
OTHR -~_'
11,201.0 MD
11,201.TPJSM-Load out geotap manifold & load
i
'
~
~ chemical injection line on floor w/ crane.
19.30
Ir .
22:30; 3.00 -
PROD1
EVALWB
TRIP T :Well Control IGas Cut
11,201.0 - --- _ - ---- - .--- ---
11,201.O~Finish POH 4" DP for E-line logs.
Mud
` ~ i
-
-
2:30
i
3:00 0.50
-! --
PROD1 -
EVALWB -
- -- - -
OTHR P I
11,201.0 --
-- -
11 201.O~CIean rig floor.
- - _ _._.__
- -~
I
23:00
1 3 30 0.50,
1 PROD1 EVALWB I OTHR i P
~ 11,201.0; 11,201.OiSuck fluid out of bops pull wear ring &
j ;
i I
~ set test plug.
23:30 f0000~ 0.50 PROD1 ~ EVALWB ', OTHR P !, 11,201.0 11,201.O,TestingBOPE. I
-Mud Check Data
,r '.a ?-1 10,~;;~ ~~ ~ :ro . ~~ S.u~'rl ~-ITH~=' FJ' ~' ~<. ? 1= ' J ~-. -'eiT
,. C'.: t ~~r t~ L~ r~_,-;i ;::_~[~ ._. ~ i.~;~~ ~.t
_
- - ;ibr '~~_fi,>~~ i~`i ;'d,-~ it^iC.,"!ft' ~.it=iil_,:i~ (rnL -,~ pN ~=. ~.~„
- ~ ~ -
~O
LSG1D 1 1 e~i
LO I t~ ~~ 1 1 ~ _i 26.000
r r ~ 10 0 12.0 15.000 5 i:) ~i ,°~ ~~ 4 5'~ r~ 1 1 7~
~
Drill Strings: BHA No. 6 - <Drill String i ~
Name?> ! Bit Run No. <Bit Run?> - <Drill Bit?>
Depth In (ftKB) Depth Out (ftKB) TFA (incl Noz) (in)
i ,Nozzles (l32) IADC Bit Dull ,String Wi (10001Df}
10,330.0 11,201.0
~
i - '
i
I __._ ____._ _.-_~ _ _ _ _--_ _--
'Latest BOP Test Data
, ~,-~ ~
-- - -- ---
~ 11r t u/ZUU7- Wiest BODE= 25U to / 35t)u hi No Failures NEX I ksUF i [_~ i . 24-Nov-2007. AOGCIi witness waived by Ghuck 5h~Qve.
Page 1/2 Report Printed: 11/27/20071
Daily Drilling Report
2L-330
Security Level: Development
' ` Report Number: 231,
i
Rig: NORDIC 3 Report Date: 11/25/2007
Welfbores
~Wellborc Name iWel fboreAPl/UWI
z~-33n 501032055a
__.._ ,~::Ir~n eini .,"io~,H4:Ei Aci Btrtt ~ft~N; ,-:rat Cate ~~~~d ~a!e
D
O 1
RF
AC
'SU 121/41 1100,1 3,335.0 11/4/2007 11/7/2007
INTRM1 ~ a 3/4 3,31 E.O, 10,330.0 11/11/2007 11!16/2007
PROD1 6 1/8 10,330.01, 11,201.0 11/22/2007 11/24!2007
Survey Data
~,_ er~~~ a~° _R~; r-~:~r~t<~. ;rn ra:~r~~ :i,n r ~cra
~~ 11,201.00 ____ 3'L.'25 146.24 5y.S476~ 8,734.15 -6,706.4__ 5,649.751 O.u~
I
Page 2/2 Report Printed: 11/27/2007'..
• •
Security Level: Development
Daily Drilling Report
2L-330
I
Report Number: 24
I
Rig:
NORDIC 3 Report Date: 11/26/2007
i Dnllmg I i 0158757 5,551,ti56.00
------
Wellbore Well Type
~2L-330 Development
Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftK8) Depth End (ftKB)
TARN PARTICIPATING AREA 22.42 24.0 0.00 11,201.0 11,201.0
IDaily Mud Cost Cumulatlve Mud Cost Daily Cost Total Cumulatlve Cost
369 975.87 91,809.00 4,105,197.87
Actual Start Date Orlglnal Spud Date AFE Dur Total (days} Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date
11/3/2007 11/4/2007 26 85 ~ 43.64 -16.79 12/16!2007 15:22
Last Casing String Next Casing OD (in) Next Casing Set Depth (ftK6)
Intermediate, 10,307.4ftKB
Ops and Depth ~ Morning Report
' 24hr Forecast
Circ. @ 10146
MD. Finish logging. Rig down & make clean out run.
-
Last 24hr Summary
------.._.._.__
--------------______ ------.._-- ----
Finish test BOPE. Nipple down riser. Nipple up shooting flange. Rig up SLB E line &RIH to 10350. No Go POH Rig down SLB change out riser. Rig up 8~ run
I
logs on 4" DP.
General Remarks
Weather Head Count
No Accidents. No Spills. Temp -9 deg. Wind SSE 7 CF -23 deg. 37.0
s~~~e
,-~_~~~ i ~-r
Dave Nioms, Dnlling Supernsor -
~ Dulling Supervisor
Dink Heim, Drilling Supervisor Drilling Supervisor I
Ronnie Rice, Tool Pusher Tool Pusher
Andy Anderson, Tour Pusher Tour Pusher
Time Log
-;.?C -r~~ Cvr Tir~~o C~F,~`i Star, L ~:h (-~.i~i
:r.~ Tu~i_ !hr51 F7a,_ F =..~. .~ ~ ,..-. F"-,d- 1 ._adc ~.. ~ly;, L_ tGi` :~~ ~..::n
u0:00 03:30 3.501 PkODi EVALWB OTHF2 ~Y 1 1,201.0 i 1,201.0 Testai180PE250-3500 psi. 1
03:30 05:00 1.50 PROD1 EVALWB OTHR ', P 11,201.0 11,201.0 Pull test plug. Set wear bushing &
monitor well.
05:00 07:00 2.00 PROD1 EVALWB RURD ' P ~ 11,201.0 11,201.0 Pull riser & rig up lubricator for E line
', logs. Flange up top annular, connect riser
to floor.
-------.--- -- ---- - ...._--x--------
07:00 15:00 8.00 PROD1 EVALWB ELOG ', P 11,201.0 11,201.0 PJSM, MU E-log tools, RIH wireline to
~ 10350 ft. Can not pass 10350 (43 ft out
' i, , I ~ of 7" shoe). POH wireline for DP j
conveyed logs. i
-j
15:00 17:00 2.00 PROD1 EVALWB PULD I, P ~ 11,201.0 11,201.0 LD E-log equip, clear floor all related
17:00
19:00
2.00 i
PROD1
EVALWB ; I
RURD I' P ; I
11,201.0
11,201.Ot equip.
PJSM, ND annular flanged riser, NU drlg
~ ~ j I i riser / flowline.
19:00 20:30 1.50 PROD1 EVALWB RURD 'P r
~ 11,201.0 11,201.O~ PJSM-Make up SLB logging assembly
- _ -! (Gamma Sonic & FMI) on 4" DP.
20:30 22:30 2.00 PROD1 ( EVALWB ! ;TRIP P ~ 11,201.0 11,201.0 PJSM-RIHw/logging assembly to293T
I ~ ( MD.
22:30 23:00 0.50 PROD1 EVALWB ~ CIRC P 11,201.0 11,201.0 Make up Circ. head & CBU @ 5 bpm 350
psl as per schlumberger Rep.
23:00 00:00 1.00 PROD1 EVALWB S TRIP ,P 11,201.0 11,201.0 Continue running in hole from 2937 MD I
~ I to 4555' MD. ~
Mud Check Data
_ ~ ; ~;~~,~.
,_
i ~ i s, i ~enl L_I,r ~~u
,
~ ~~ ~rn ~_~-.
~ -
,
jC~~- ~la~~~l ,..Kt~l [ ;=,1 IS iS!~I; ...~.~i._ II 1. `J II' -t ;IYI"~. ,f' ~;'1 III I~'~. ~`; `y~r;; ~'I.1I1 !I'lL '_I'~iln; ~;H F~
. of 1
LSf1C~ 1 1 ~U 1 0 l l ~i) ~,' 15 J 2~; U!ii 1 1 1=i l;'.0 l~ ~ii(1 t; ?, ~ r3 i i5 i>,g 11 11.3.
i
Wellbores -- - -
Wellbore Name Wellbore API/UWI
!I (1 ~,i111 ,Lrl`~,,q
s~as;i~ _ ~r; -.atop ~,-'reS -_? ~ ,i fa:5~ ~~~,~ i ~,., _r.-i Ca~Sz
COND1 ib~
0.01
11Q0~11id/1G07
i 1r~i2007
SURFAC ~
121/4, 110.0. 3,335.Oj11/4/2007 !11/7/2007
I NTRM1 ~
~I 8 3/4', 3,318.0', 10,330.0 j 11 /11 /2007 1,11 /16/2007 I
PROD1--- ---- ----- - - _ _
1 6 1 /8,
10,330.0 ~ -- 11,201.01 11/22/2007
---~ - 111/24/2007 ~
-= -- _ - - --_ I
' Latest BOP Test Data ~!
11.1116/'1007 _ _LTest bode 250-3500 psi AOGGC: witness waived bYJohn Cns~
Page 1/2 Report Printed: 11/27/2007'
• •
Survey Data
ntn i~,.i
11,201.00 ~
tig: NORDIC 3
ic~-i ~~, ,r, r,
32.251 146.24
Daily Drilling Report
2L-330
__ .
5,934.761 8,734.15 -6,70t3.40
Page 2/2
Security Level: Development
Report Number: 24
Report Date: 11/26/2007
E.: ~ ~~ ~x~r~
5,645.791 OAO
Report Printed: 11/27/2007',
• ~ Page 1 of 1
Maunder, Thomas E (DOA)
From: Greener, Mike R. [Mike.R.Greener@conocophillips.com~
Sent: Tuesday, November 27, 2007 4:00 PM
To: Maunder, Thomas E (DOA)
Subject: RE: BOP 2L-330 11-24-07 Contractor Rig No 11-14-07p (version 1).xls
Still putting the reports together for you. I haven't forgot. We have lost communications
with the rig. Should have all info by morning.
From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov]
Sent: Tuesday, November 27, 2007 8:29 AM
To: Greener, Mike R.
Cc: Thomas, Randy L; Jim Regg
Subject: FW: BOP 2L-330 11-24-07 Contractor Rig No 11-14-07p (version i).xls
Mike,
Your name is on the permit application, so you get the message.
Attached is the 11/24 -11/26 BOP test report from Nordic 3 on 2L-330.
The following comment is included,
"Test started 11/24/07 @ 23:OOhrs, Stopped test, RIH due to gas cut mud at surface. Circulate and condition mud,
POOH continued test 11/25/07 @ 23:30. finished test 11/26/07 @ 03:30".
I am requesting further information on this event. Please include the daily reports from 11-23 to 11-26.
Call or message with any questions. I look forward to your reply.
Tom Maunder, PE
AOGCC
From: Nordic 3 Tour Pusher [mailto:n1614@conocophillips.com]
Sent: Monday, November 26, 2007 8:53 PM
To: Regg, James B (DOA); aogcc~rudhoe_bay@admin.state.ak.us; Fleckenstein, Robert J (DOA)
Subject: BOP 2L-330 11-24-07 Contractor Rig No 11-14-07p (version 1).xls
4/8/2008
•
Maunder, Thomas E (DOA)
From: Greener, Mike R. [Mike.R.Greener@conocophillips.com]
Sent: Tuesday, November 27, 2007 9:07 AM
To: Maunder, Thomas E (DOA)
Cc: Thomas, Randy L; Regg, James B (DOA)
Subject; RE: BOP 2L-330 11-24-07 Contractor Rig No 11-14-07p (version 1}.xls
Page 1 of 1
We talked about it this morning in the morning meeting. I am in the process of collecting
the information now. Should have it to you shortly.
From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov]
Sent: Tuesday, November 27, 2007 8:29 AM
To: Greener, Mike R.
Cc: Thomas, Randy L; ]im Regg
Subject: FW: BOP 2L-330 11-24-07 Contractor Rig No 11-14-07p (version 1).xls
Mike,
Your name is on the permit application, so you get the message.
Attached is the 11/24 - 11/26 BOP test report from Nordic 3 on 2L-330.
The following comment is included,
"Test started 11/24/07 @ 23:OOhrs, Stopped test, RIH due to gas cut mud at surface. Circulate and condition mud,
POOH continued test 11/25/07 @ 23:30. finished test 11/26!07 @ 03:30".
am requesting further information on this event. Please include the daily reports from 11-23 to 11-26.
Call or message with any questions. I look forward to your reply.
Tom Maunder, PE
AOGCC
From: Nordic 3 Tour Pusher [mailto:n1614@conocophillips.com]
Sent: Monday, November 26, 2007 8:53 PM
To: Regg, James B (DOA); aogcc_prudhoe bay@adminstate.ak.us; Fleckenstein, Robert 7 (DOA)
Subject: BOP 2L-330 11-24-07 Contractor Rig No i1-14-07p (version 1).xls
4/8/200$
Maunder, Thomas E (DOA)
From: Regg, James B (DOA)
Sent: Tuesday, November 27, 2007 7:57 AM
To: Maunder, Thomas E (DOA)
Subject: FW: BOP 21-330 11-24-07 Contractor Rig No 11-14-07p (version 1).xls
Attachments: BOP 2L-330 11-24-07 Contractor Rig No 11-14-07p (version 1).xls
Had to suspend BOPE test due to gas cut mud at surface
Jim Regg
AOGCC
333 W.7th Avenue, Suite 100
Anchorage, AK 99501
phone: 907-793-1236
fax: 907-276-7542
Page 1 of 1
From: Nordic 3 Tour Pusher [mailto:n1614@conocophillips.com]
Sent: Monday, November 26, 2007 8:53 PM
To: Regg, James 8 (DOA); aogcc prudhoe_bay@admin.state.ak.us; Fleckenstein, Robert J (DOA)
Subject: BOP 2L-330 11-24-07 Contractor Rig No 1i-14-07p (version 1).xls
4/8/2008
STATE OF ALASKA
1/14/07 OIL AND GAS GONSERVATION COMMISSION
ROPE Test Report
Submit to:
Contractor: Nordic Rig No.: 3
Rig Rep.: Rice /Anderson Rig Phone: 659-7438
Operator: CPAI Op. Phone: 659-7446
Rep.: Morris / Heim
Field/Unit 8 Well No.: 2L-330 PTD ~ 207-128
Operation: Drlg: X Workover:
Test: Initial: Weekly:
Test Pressure: Rams: 250/3500 Arxx~ar: 250!3500
TEST DATA
MISC. INSPECTIONS:
Test Result Test Result
Location Gen.: P Weti Sim P
Housekeeping: P Dri. Rig P
PTD On Location P Hazard Sec. P
Standing Order Posted P
BOP STACK:
Quantify Size Test Result
Annular Preventer 1 11 P
Pipe Rams 9 4 P
Lower Pipe Rams 1 4 P
Blind Rams 1 BNr~d P
Choke Ln. Valves 1 3118" P
HCR Valves 1 31/8" P
Kill Line Valves 2 3 1/8" P
Check Valve 0 NA
MUD SYSTEM:
Trip Tank
Pit Level Indicators
Visual Test Alarm Test
P P
P P
--_ -- ---
Flow Indicator P P
Meth Gas Detector P P
H2S Gas Detector P P
Test Results
DATE: 11/24/2007
Rig Fax: 659-7566
Op. Fax: 659-7566
Explor.:
Bi-Weekly X
Valves: 250/3500
FLOOR SAFETY VALVES:
Quantdy Test Result
Upper Kelly 1 P
Lower Kelly 1 P
Ball Type 1 P
Inside BOP 1 P
CHOKE MANIFOLD:
Quantity Test Result
No. Valves 12 P
Manual Chokes 1 P
Hydraulic Chokes 1 P
ACCUMULATOR SYSTEM:
Time/Pressure Test Result
System Pressure 3050 P
Pressure After Closure 1900 P
200 psi Attained 19 sec P
Futi Pressure Attained 1 min 34 sec P
Blind Switch Covers: All stations P
Niter. Battles (avg): 4 ~ 2250
Number of Failures: 0 Test Time: 5 Hours Comaonents tested All
Repair or replacement of equipment w~ tie made witltk- 0 days. Notify the North Slope
Inspector 659-3607, follow with written confrmation to Supervises at:
Remarks: Test started 11!24!07 Cat 23:OOlus Storwed test, RIH due to ~s cut mtrd at surface. Circulate and
condition mud, POOH continued #est 11/25/07 Ccit 23:30. fxrished test 19!26/0718103:30
24 HOUR NOTICE
YES X NO
Date
start
BOP Test (for rigs)
BFL 11/14/07
11/23/07 Time 16:30
Finish
By _ John
Witr~ess Moms /Rice
BOP 2L-330 11-24-07 Contractor Rig No 11-14-07p (version 1).xls
r
•
d a d a
O SARAH PALIN, GOVERNOR
AiILS-7~ O~ ~ ~ 333 W. 7th AVENUE, SUITE 100
COI~TSERQA~'I011T COl~ir-IISSIOIQ ANCHORAGE, ALASKA 99501-3539
PHONE (907) 279-1433
FAX (907) 278-7542
Randy Thomas
Drilling Team Leader
ConocoPhillips Alaska, Inc.
PO Box 100360
Anchorage, AK 99510-0360
Re: Kupaurk River Field, Kuparuk River Oil Pool, 2L-330
ConocoPhillips Alaska, Inc.
Permit No: 207-128
Surface Location: 236' FNL, 938' FEL, SEC. 22, TlON, R7E, UM
Bottomhole Location: 3635' FSL, 590' FEL, SEC. 26, T10N, R7E, UM
Dear Mr. Thomas:
Enclosed is the approved application for permit to drill the above referenced
development well.
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 permits and
approvals have been issued. In addition, the Commission reserves the right to
withdraw the permit in the event it was erroneously issued.
Operations must be conducted in accordance with AS 31.05 and Title 20,
Chapter 25 of the Alaska Administrative Code unless the Commission
specifically authorizes a variance. Failure to comply with an applicable
provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code,
or a Commission order, or the terms and conditions of this permit may result
in the revocation or suspension of the permit. 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).
Sincerel
Dan T. Seamount
Commissioner
DATED this Z- day of October, 2007
cc: Department of Fish 8v Game, Habitat Section w/o encl.
Department of Environmental Conservation w/o encl.
n
U
Post Office Box 100360
Anchorage, Alaska 99510-0360
Randy Thomas
Phone (907) 265-6830
Email: Randy.L.Thomas@conocophillips.com
September 5, 2007
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
~~ ~~1
~~ V ~I~
~~~ 0 6 2007
AiosiC~ llil ~ Gas Cons. Commission
RE: Application for Permit to Dri112L-330
Anchorage
Dear Commissioners,
ConocoPhillips Alaska, Inc hereby applies for a Permit to Drill for the onshore production we112L-330.
The well will be drilled and completed using Nordic Rig #3. The planned spud date for 2L-330 is October
10th, 2007.
Please fmd attached for the review of the Commission forms 10-401 and the information required by 20
ACC 25.005 for this well bore.
If you have any questions or require further information, please contact Mike Greener at 907-263-4820.
Sincerely,
Randy Thomas
Kuparuk Drilling Team Leader
• C
STATE OF ALASKA ~ ~ ~ ~C ~'
ALASKA OIL AND GAS CONSERVATION COMMISSION ~~P ~ ~
PERMIT TO DRILL z~Q~
20 AAC 25.005 ~iaska Oil ~ Gas Conc ,~~mm:_.
1 a. Type of Work:
Drill Q ~ Re-drill ^
Re-entry ^ 1 b. Current Well Class: Exploratory ^ Development Oil Q
Stratigraphic Test ^ Service ^ Development Gas ^
Multiple Zone^ Single Zone ^ 1 a Specify if well is propos~E}~Ora
Coalbed Methane ^ Gas Hydrates ^
Shale Gas ^
2. Operator Name:
ConocoPhillips Alaska, Inc. 5. Bond: ~ Blanket Single Well
Bond No. 59-52-180 11. Well Name and Number:
2L-330
3. Address:
P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth:
MD: 11201' ~ ND: 5930' 12. Field/Pool(s):
Kuparuk River Field
4a. Location of Well (Governmental Section):
Surface: 236' FNL, 938' FEL, Sec. 22, T10N, R7E, UM ~ (~ 7. Pr~erty Designation:
~ ADL 380051, 380053
Tarn Oil Pool
Top of Productive Horizon: ~i b7
1284' FNL, 843' FEL, Sec. 26, T10N, R7E, UM q.(¢ 8. Land Us Permit:
ALK 4599, 4601 13. Approximate Spud Date:
10/10/2007
Total Depth:
3635' FSL, 590' FEL, Sec. 26, T10N, R7E, UM 9. Acres in Property:
2560 14. Distance to ~ / lccr/~ •'
Nearest Property: ttom KRU
.bo~trt ~a
4b. Location of Well (State Base Plane Coordinates):
Surface: x- 460713 ~ y- 5927611 Zone- 4 10. KB Elevation
J
(Height above GL): 147' RKB feet 15. Distance to Nearest ~/, ~. Z ,
Well within Pool: 2L-323 ~ 9949' , 1640'
16. Deviated wells: Kickoff depth: 300' ' ft.
Maximum Hole Angle: 67°~ deg 17. Maximum Anticipated Pressures in psig (see 20 aAC 25.035) ^ f~
Downhole:~ps~~ Surface: psig
18. Casing Program
if
ti
S Setting Depth Quantity of Cement
Size ica
ons
pec Top Bottom c. f. or sacks
Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data)
24" 16" 62.5# H-40 Welded 80' 30' 30' 120' 120' Pre-installed
12.25" 9.625" 40# L-80 BTC 3302' 30' 30' 3302' ~ 2400' ~ 550 sx AS Lite, 170 sx DeepCRETE
8.75" 7" 26# L-80 BTCM 10330' 30' 30' 10330' ~ 5236' ~ 210 sx GasBLOK w/Class G
6.125" 4.5" 12.6# L-80 IBTM 1071' 10130' 5102' 11201' . 5930' 150 sx GasBLOK w/Class G
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 DeptheND (ft): Junk (measured)
Casing Length Size Cement Volume MD TVD
Conductor/Structu ra I
Surface
Intermediate
Production
Liner
Perforation Depth MD (ft): Perforation Depth ND (ft):
20. Attachments: Filing Fee ^ BOP Sketch^ Drilling Program^ Time v. Depth Plot ^ Shallow Hazard Analysis ~
Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ^/ 20 AAC 25.050 requirements Q
21. Verbal Approval: Commission Representative: Date:
22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mike Greener @ 263-4820
Printed Name Randy Thomas Title Drilling Team Leader
Signature ~ '~ ~"'~~~~ Phone ~~' (~ -~ ~ ~, Date ~ ~~lo ~
h I k
Commission Use Only
Permit to Drill
Number: ~~''l~ API Number: ^h
50- ! ~ ~' r~~~~~w Permit Approval
Date: • a• ~~ See cover letter
for other requirements
Conditions of approval : If box is checked, well may not be used to explore for, test, or produce Coalbed m thane, gas hydrates, or gas contained in shales:
Samples req'd: Yes ^ No ~ Mud log req'd: Yes ^ No [•~
Other: ~~~t ~~ V~`t,.i~~1 ~ i f~Q.~~F12S measures: Yes [r]~No ^ Directional svy req'd: Yes [,~ No ^
/ ~~~ ~ APPROVED BY THE COMMISSION
DATE: ,COMMISSIONER
~~
77
`"
\~
y~
Y'~
Form 10-401 Revised 12/2005 ,`°~ t ~ ~ v ~ ~ ~ ~ ~ ~~ Submit in Duplicate
A~ation for Permit to Drill, Well 2L-330
Saved: 5-Sep-07
Permit It - Kuparuk We112L-330 • ~ ,,,
Application for Permit to Drill Document ''~
x +» x
W„~-t! e~l~~
Table of Contents
1. Well Name .................................................................................................................................2
Requirements of 20 AAC 25.005 (~ .....................................................................................................:.................. 2
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 ZD AAC 25.OOS(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.OOS(c)(6) ................................................................................................................... 4
7. Diverter System Information .................................................................................................. 4
Requirements of 20 AAC 25.OOS(c)(7) ................................................................................................................... 4
8. Drilling Fluid Program ............................................................................................................ 4
Requirements of 20 AAC 25.005(c)(8) ................................................................................................................... 4
9. Abnormally Pressured Formation Information .................................................................... 5
Requirements of 20 AAC 25.005 (c)(9) .................................................................................................................. S
10. Seismic Analysis ....................................................................................................................... 5
Requirements of 20 AAC 25.005 (c)(10) ................................................................................................................ S ..
11. Seabed Condition Analysis ...................................................................................................... 5
Requirements of 20 AAC 25.005 (c)(11) ................................................................................................................ S
12. Evidence of Bonding ................................................................................................................5
Requirements of 20 AAC 25.005 (c)(12) ................................................................................................................ S
13. Proposed Drilling Program .....................................................................................................5
Requirements of 20 AAC 25.005 (c)(13) ................................................................................................................ S
2L-330 APD
Page 1 of 7
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OR161NAL
A~ation for Permit to Drill, Well 2L-330
Saved: 5-Sep-07
-~
14. Discussion of Mud and Cuttings Disposal and Annular Disposal .......................................6
Requirements of 20 AAC 25.005 (c)(14) ................................................................................................................ 6
15. Attachments ..............................................................................................................................6
Attachment 1 Directional Plan .............................................................................................................................. 6
Attachment 2 Drilling Hazards Summary ............................................................................................................. 6
Attachment 3 Well Schematic ................................................................................................................................ 6
Attachment 4 Cement Summary ............................................................................................................................. 6
1. Well Name
Requirements of 20 AAC 25.005 (~
Each well must be identified by a unique name designated by the operator mzd a unique API number assigned by the comna.ission under 20 AAC
25.040(6). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix
to the name designated for the well by the operator and to the number assigned to the well by the commission.
The well for which this application is submitted will be designated as 2L-330.
2. Location Summary
Requirements of 20 AAC 25.005(c) (2)
An application for a Permit to Drill must be accompanied by each of the following items, except for an item already ovr file with the commission
and identified in the application:
(2) a plat identifying the property and the property's oiamers and shrnving
(A)che coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to
governmental section lines.
(B) dze coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained
by the National Geodetic Survey in the National Oceanic and Atmospheric administration;
(C) the proposed depth of the well at the top of each objective formation and at total depth;
Location at Surface 236' FNL, 938' FEL, Sed 22, T10N, R7E, UM '
NGS Coordinates RKB Elevation 147.1' AMSL '
Northings: 5,927,611 ~ Eastings: 460,713 Pad Elevation 117.1' AMSL
Location at Top of Productive Interval
(Bermuda 1,284' FNL, 843' FEL, Sec 26, T10N, R7E, UM
.NGS Coordinates Measured De th, RKB: 10,455'
Northings: 5,921,258 Eastings: 466,064 Total Vertical Depth, RKB: 5,330'
Total Vertical Depth, SS: 5,184'
Location at Total De th 3,635' FSL, 590' FEL, Sec 26, T10N, R7E, UM
NGS Coordinates Measured De th, RKB: 11,201'
Northings: 5,920,896 Eastings: 466,315 Total Vertical De th, RKB: 5,930'
Total Vertical De th, SS: 5,785'
arad
(D) other information required by 20 AAC 25.050(6);
Requirements of 20 AAC 25.050(6)
If a~ivell is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) must
(1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any
portion of the proposed ia~ell;
Please see Attachment 1: Directional Plan
and
(2) for all ia~ells within 200 feet of the proposed wellbore
(A) list tlae names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that
each named operator has been furnished a copy of the application by cert f ed mail; or
(B) state that the applicant is the only affected rnvner.
2L-330 APD
Page 2 of 7
Printed: 5-Sep-07
~R161NAL
The Applicant is the only affected owner. `
A~tion for Permit to Drill, Well 2L-330
Saved:5-Sep-07
3. Blowout Prevention Equipment Information
Requirements of 20 AAC 25.005(c)(3)
An application for a Permit fio Drill must be accompmvied by each of the following items, except for an item already on file with the commission
and identified an the application:
(3) a diagram and description of the blowout prevention equipment (HOPE) as reguired by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037,
as applicable;
Please reference BOP schematics on file for Nordic 3.
4. Drilling Hazards Information
Requirements of 20 AAC 25.005 (c) (4)
An application for a Permit to Drill must be accompanied by each of the folloia~ing items, except for an item already on file with the commission
and identified in the application:
(4) information on drilling hazards, including
(A) the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on
a methane gradient;
The closest offset well data shows a max BHP of 3,151 psi at 5,489' TVD.
_-.
--- __--
Equivalent Mud Weight@TD = 3,151 / (5,489*.052 ° 11 ppg /'
The maximum potential surface pressure (MPSP) while ' ling 2L-330 is calirulated using the predicted 3,151 psi
reservoir pressure, a 0.11 psi/ft gs 6g~adient, and an Bermuda top TV~ of 5,265'.`'
UU '~_ .... ..... .....
MPSP = (5,265 TVD)*(0,~' 0.11 psi/ft) _
= 1 psi S~ Q..~
5'>a ~` ~
ct'a~
(B) data on potential gas pones;
The well bore is not expected to penetrate any gas zones. '
aazd
(C) data concerning potential causes of hole problems such as abnorna~ally geo pressured strata, lost circulation pones, and pones that have a
propensity for d fferential sticking; ?
Please see Attachment 2 -Drilling Hazards Summary
5. Procedure for Conducting Formation Integrity Tests
Requirements of 20 AAC 25.005 (c)(S)
An application for a Permit to Drill must be accompanied by each of tlae following items, except for an item already on fate with the commission
and identified in the application:
(5) a description of tlae procedure for conductiaag formation integrity tests, as required under 20 AAC 25.0300;
Drill out surface casing shoe and perform LOT test or FIT in accordance with the Kuparuk LOT /FIT procedure that
ConocoPhillips Alaska has on file with the Commission.
2L-330 APD
Page 3 of 7
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OR161NAL
A~ation for Permit to Drill, Well 2L-330
Saved: 5-Sep-07
-~,
6. Casing and Cementing Program
Requirements of 20 AAC 25.005(c)(6)
An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission
and identified in the application:
(6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of arty slotted liner, pre perforated
liner, or screen to be installed;
Casin and Cementin Pro ram
Hole Top Btm
Csg/Tbg Size Weight Length MDlND MD/TVD
OD in) (in Ib/ft Grade Conn. ft (ft) (ft) Cement Pro ram
Driven
16 24 62.5 H-40 Welded 80' Surf 120' / 120'
Cemented to Surface with
9-5/8 12-1/4 40.0 L-80 BTC 3,302' Surf 3,302' / 2,400' 550 sx ASLite Lead,
170 sx Dee CRETE Tail
Cement Top planned @ 9,330' MD /
7 8-3/4" 26.0 L-80 BTCM 10,330' Surf 10,330' / 5,236' 4,735' ND. Cemented w/
210 sx GasBLOK w/ Class "G"
Cement Top planned @ 9,930' MD /
4-1/2 6-1/8 12.6 L-80 IBTM 1,071' 10,130' / 5,102' 11,201' / 5,930' 4,975' ND. Cemented w/
150 sx GasBLOK w/ Class "G"
7. Diverter System Information
Requirements of 20 AAC 25.005(c) (7)
An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission
and identified in the application:
(7) a diagram and description of the diverter system as regzired by ~0 AAC 25.035, unless this requirement is waived by the commission under
20 AAC 25.035(1x)(2);
Please reference diverter schematic on file for Nordic 3.
8. Drilling Fluid Program
Requirements of 20 AAC 25.005(c)(8)
An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission
and ident f ed in the application.•
(8) a drilling fluid program, including a diao am and description of the drilling fluid system, as required by 20 AAC 25.033;
Drilling will be done using mud systems having the following properties:
Sur ace Interval Intermediate Interval Production Interval
Mud Tye Spud Mud LSND LSND
Density 8.5 - 10.2 9.5 - 10 9.6 - 11
Funnel Viscosi (sec) 150 - 250* 45 - 55 45 - 55
Yield Point (cP 30 - 45 18 - 22 17 - 22
Plastic Viscosity (lb/100 s~ 20 - 60 14 - 25 14 - 25
IOsec.Gel(Ib/100s 10-35 5-9 5-9
API Filtrate (cc) NC - 6 4 - 6 < 4
H 8.5-9.5 9-10 9-10
Solids % +/- 10 < 5% < 5%`
*Spud mud should be adjusted to a FV between 150-250 sec/qt to drill gravel beds
Diagram of Nordic 3 Mud System on file.
Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033.
2L-330 APD
Page 4 of 7
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Agp~ation for Permit to Drill, Well 2L-330
Saved:5-Sep-07
9. Abnormally Pressured Formation Information
Requirements of 20 AAC 25.005 (c)(9)
An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission
and identified in the application:
(9) for an exploratory or stratigraphic test ~~~ell, a tabulation setting out the depths of predicted abnormally geo pressured strata as regulred by
20 AAC 25.0330;
N/A -Application is not for an exploratory or stratigraphic test well.
10. Seismic Analysis
Requirements of 20 AAC 25.005 (c)(10)
An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission
and identified in the application:
(10) for an exploratory or stratigraphic test welt, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a);
N/A -Application is not for an exploratory or stratigraphic test well.
11. Seabed Condition Analysis
Requirements of 20 AAC 25.005 (c)(11)
An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission
and ident~ed in the application:
(11) for a well drilled from an. offshore platform, mobile bottom founded structure, jack-up rig, or floating drilling vessel, ran analysis of seabed
conditions as required by 20 AAC 25.061(6);
N/A -Application is not for an offshore well.
12. Evidence of Bonding
Requirements of ZO AAC 25.005 (c)(12)
An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission
a~ad identified in the application:
(12) evidence showing that the requirements of 20 AAC 25.025 {Bonding}have been met;
Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission.
13. Proposed Drilling Program
Requirements of 20 AAC 25.005 (c)(13)
An application for a Permit to Drill must be accompanied by each of the following iterns, except for an item already on file with the commission
and ident~ed in the application:
The proposed drilling program is Listed below. Please refer to Attachment 3: Well Schematic.
1. MIRU Nordic 3 on 2L-330 Conductor.
2. NU and function test diverter system and prepare spud mud.
3. Place warning signs on location indicating the rig has diverter equipment rigged up.
4. Spud and directionally drill 12-1/4" hole to 9-5/8" surface casing point (3,302' MD/ 2,400' TVD) according to
directional plan. Run MWD / LWD logging tools in drill string as required for directional monitoring and
formation data gathering.
5. Run and cement 9-5/8" 40.0# L-80 BTCM casing to surface. Adequate excess cement will be pumped to ensure
cement reaches the surface during the cement job. Displace cement with mud. Perform top job if required to
bring cement to surface. ~~+~y ~OG~CC i ~ ~ ~~~'~~
6. Nipple down diverter, remove warning signage, and install wellhead and test to 5000 psi.. Nipple up BOPS and
~~
test to required pressure as per AOGCC approved permit to drill. Record results.
7. Shut in BOP's and pressure test casing to 3000 psi per AOGCC regulations. Record results.
8. Drill out cement and 20' minimum to 50' maximum of new hole. Perform LOT.
9. Directionally drill 8-3/4" hole to 10,330' MD / 5,236' TVD. Run MWD/LWD logging tools in drill string as
required for directional monitoring and formation data gathering.
10. Run 7" 26# L-80 BTCM casing to 10,330' MD / 5,236' TVD. Pump cement and displace with mud, land
casing hanger and bump plug.
2L-330 APD
Page 5 of 7
Printed: 5-Sep-07
ORIGINAL
A~tion for Permit to Drill, Well 2L-330
Saved: 5-Sep-07
11. PU 4-3/4" packed drilling assembly and 6-1/8" bit and clean out to shoe. Shut in BOP and test casing to 3,000
psi. Record results. Drill 20' minimum to 50' maximum of new hole. Perform LOT.
12. Directionally dri116-1/8" hole to 11,201' MD / 5,930' TVD. Run MWD/LWD logging tools in drill string as
13. POOH and lay down BHA.
14. Log well with FMI and Sonic Scanner. ,
15. Run 4-1/2" liner completion with +/- 200' overlap into intermediate casing and cement same.
16. Run 3-1/2" tubing with GLMs and chemical injection mandrel with control line attached for paraffm inhibition)
to OD of tbg. Land 3-1/2" completion tubing string in the seal bore in the 4-1/2" liner top and pressure test to
3000 psi. Record results.
17. Pull landing joint. Install BPV. Nipple down BOP stack, and nipple up production tree. Pull BPV. Install test
plug. Pressure test production tree. Pull test plug. Secure well.
18. Pressure up to shear out valve in lowest GLM and freeze protect outer annulus with diesel to below the
permafrost. Set BPV. Release rig.
19. Clean location and RDMO.
20. MIRU coiled tubing. Displace mud from well with brine.
21. RU E-Line, perforate well. Flow test well.
22. RU Dowell, frac well.
23. RD Dowell, secure well, handover to production
14. Discussion of Mud and Cuttings Disposal and Annular Disposal
Requirements of 20 AAC 25.005 (c)(14)
An application for a Permit to~ Drill mustc be accompanied by each of the following items, except for an item already on~le with the commission
and identified in the application:
(14) a general description of haw the operator plans to dispose of drilling mud and cuttings a~ul a statement of whether the operator intends to
request autho~•i=anon under 20 AAC 25.080 for an annular disposal operation in the well.;
Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II
disposal well. All cuttings generated will be 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 used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska.
ConocoPhillips Alaska does intend to request authorization for the use of this well for annular disposal operations at
a later date provided the well meets the regulatory requirements.
15. Attachments
Attachment 1 Directional Plan
Attachment 2 Drilling Hazards Summary
Attachment 3 Well Schematic
Attachment 4 Cement Summary
2L-330 APD
Page 6 of 7
Printed: 5-Sep-07
ORIGINAL
~onocoPhillips Alaska, InL!
CPAI Plan Report
r
Company: ConocoPhillips Alaska Inc. Date: 8/31/2007 Time: 11:21:31 Page: I
Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: Plan: 2L-330, True North
Site: Kuparuk 2L Pad Vertical (TVD) Reference: Plan 2L-330 145.4
Well: Plan: 2L-330 Section (VS) Reference: Well (O.OON,O.OOE,145.OOAzi)
Wellpath: Plan: 2L-330 Survey Calculation Method: Minimum Curvature Db: Oracle
Plan Section Information
;17D Incl Azim TVD +N/-S +E/-W DLS Build Turn "CFO Target
ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg
30.00 0.00 0.00 30.00 0.00 0.00 0.00 0.00 0.00 0.00
300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00
700.00 10.00 150.00 697.97 -30.15 17.41 2.50 2.50 0.00 150.00
2613.17 67.20 139.12 2132.77 -916.14 738.94 3.00 2.99 -0.57 -11.92
9668.24 67.20 139.12 4866.78 -5833.73 4995.27 0.00 0.00 0.00 0.00
10456.45 40.00 145.00 5330.40 -6325.48 5385.92 3.50 -3.45 0.75 171.83 2L-330wp03 T3 Gemini
11201.23 32.55 145.00 5930.40 -6686.20 5638.49 1.00 -1.00 0.00 180.00
Plan: 2L-330wp03 Date Composed: 1/11/2007
Gemini Version: 8
Principal: Yes Tied-to: From Well Ref. Point
Field: Kuparuk River Unit
North Slope Alaska
United States
Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4
Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre
Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007
Site: Kuparuk 2L Pad
Site Position: Northing: 5927695.13 ft Latitude: 70 12 48.272 N
From: Map Easting: 461077.91 ft Longitude: 150 18 50.048 W
Position Uncertainty: 0.00 ft North Reference: True
Ground Level: 0.00 ft Grid Convergence: -0.30 deg
Well: Plan: 2L-330 Slot Name:
Well Position: +N/-S -86.22 ft Northing: 5927610.80 ft Latitude: 70 12 47.424 N
+E/-W -364.91 ft Easting : 460712.60 ft Longitude: 150 19 0.642 W
Position Uncertainty: 0.00 ft
Wellpath: Plan: 2L-330 Drilled From: Well Ref. Point
Current Datum: Plan 2L-330 Height 145.40 ft Tie-on Depth:
Above System Datum: 30.00 ft
Mean Sea Level
Magnetic Data: 1/17/2006 Declination: 23.64 deg
Field Strength: 57556 nT Mag Dip Angle: 80.66 deg
Vertical Section: Depth From (TVD) +N/-S +E/-W Direction
ft ft ft deg
30.00 0.00 0.00 145.00
Survey Program for Definitive Wellpath
Date: 1/10/2007 Validated: No Version: 2
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~onocoPhillips Alaska, In~
CPAI Plan Report
Company: --- __
ConocoPhillips Alaska Inc. - _ - __ -
llate: 8/31/2007 _
Time: 11:21:31 - Page: 2
~ Fieid:
Kuparuk River Unit
Co-ordinate
(NE) Refe
rence:
Well: Pl
an: 2L-330, True North
I
Site: Kuparuk 2L Pad Vertical (T~ 'D) Refere nce: Plan 2L -330 145. 4
Nell: Plan : 2L -330 Section (VS) Reference: Well (O. OON,O.OO E,145.OOAzi)
1i'ellpath: Plan : 2L-330 Survey Calc ulation Method: Minimum Curvature Db: Oracle
Sur~~e~
~
~ -
D1D
lncl --- -
Azim
TVD
Sys TV
D
\/S
E/1V
MapN
MapE
DLS
TFO
Comme
t
ft deg deg ft ft ft ft ft ft deg/100ft deg
-
-
30. 00 0. 00 -_ _
0.00 30. 00 -115. 40 0. 00 0.00 5927610. 80 460712.60 0.00 0.00
100. 00 0. 00 0.00 100. 00 -45. 40 0. 00 0.00 5927610. 80 460712.60 0.00 0.00
200. 00 0. 00 0.00 200. 00 54. 60 0. 00 0.00 5927610. 80 460712.60 0.00 0.00
300. 00 0. 00 0.00 300. 00 154. 60 0. 00 0.00 5927610. 80 460712.60 0.00 0.00 KOP ~
400. 00 2. 50 150.00 399. 97 254. 57 -1. 89 1.09 5927608. 91 460713.68 2.50 0.00
500. 00 5. 00 150.00 499. 75 354. 35 -7. 55 4.36 5927603. 23 460716.92 2.50 0.00
600. 00 7. 50 150.00 599. 14 453. 74 -16. 98 9.80 5927593. 77 460722.31 2.50 0.00
700. 00 10. 00 150.00 697. 97 552. 57 -30. 15 17.41 5927580. 56 460729.85 2.50 0.00
800. 00 12. 95 147.24 795. 96 650. 56 -47. 10 27.82 5927563. 56 460740.17 3.00 348.08
900. 00 15. 92 145.49 892. 80 747. 40 -67. 83 41.65 5927542. 77 460753.90 3.00 350.79
1000. 00 18. 90 144.28 988. 21 842. 81 -92. 28 58.88 5927518. 23 460771.00 3.00 352.49
1100. 00 21. 88 143.38 1081. 93 936. 53 -120. 39 79.46 5927490. 01 460791.42 3.00 353.64
1200. 00 24. 87 142.70 1173. 71 1028. 31 -152. 08 103.32 5927458. 20 460815.12 3.00 354.48
1300. 00 27. 86 142.15 1263. 30 1117. 90 -187. 26 130.40 5927422. 88 460842.01 3.00 355.11
1400. 00 30. 85 141.70 1350. 45 1205. 05 -225. 84 160.64 5927384. 15 460872.04 3.00 355.60
1500. 00 33. 84 141.33 1434. 93 1289. 53 -267. 71 193.93 5927342. 11 460905.12 3.00 355.99
1600. 00 36. 84 141.00 1516. 49 1371. 09 -312. 76 230.21 5927296. 88 460941.16 3.00 356.31
1700. 00 39. 83 140.72 1594. 92 1449. 52 -360. 86 269.36 5927248. 58 460980.05 3.00 356.57
1800. 00 42. 83 140.48 1670. 00 1524. 60 -411. 89 311.27 5927197. 34 461021.69 3.00 356.79
1900. 00 45. 82 140.26 1741. 53 1596. 13 -465. 69 355.84 5927143. 31 461065.98 3.00 356.98
2000. 00 48. 82 140.06 1809. 31 1663. 91 -522. 13 402.94 5927086. 63 461112.78 ~ 3.00 357.13
2100. 00 51. 82 139.88 1873. 15 1727. 75 -581. 05 452.44 5927027. 46 461161.97 3.00 357.27
2200. 00 54. 81 139.71 1932. 89 1787. 49 -642. 28 504.21 5926965. 96 461213.41 3.00 357.39
2300. 00 57. 81 139.55 1988. 35 1842. 95 -705 .67 558.10 5926902 .30 461266.96 3.00 357.49
2400. 00 60. 81 139.41 2039. 38 1893. 98 -771 .03 613.96 5926836 .66 461322.48 3.00 357.57
2500. 00 63. 81 139.27 2085. 85 1940. 45 -838. 19 671.65 5926769. 21 461379.82 3.00 357.65
2600. 00 66. 80 139.14 2127. 62 1982. 22 -906 .97 731.01 5926700 .13 461438.81 3.00 357.71
2613. 17 67. 20 139.12 2132. 77 1987. 37 -916 .14 738.94 5926690 .92 461446.70 3.00 357.76
2700. 00 67. 20 139.12 2166. 41 2021. 01 -976 .66 791.33 5926630 .13 461498.76 0.00 0.00
2800. 00 67. 20 139.12 2205. 17 2059. 77 -1046 .36 851.66 5926560 .13 461558.72 0.00 0.00
2900 .00 67. 20 139.12 2243 .92 2098. 52 -1116 .06 911.99 5926490 .12 461618.68 0.00 0.00
3000 .00 67. 20 139.12 2282 .67 2137. 27 -1185 .77 972.32 5926420 .11 461678.64 0.00 0.00
3100 .00 67. 20 139.12 2321 .42 2176. 02 -1255 .47 1032.65 5926350 .10 461738.60 0.00 0.00
3200 .00 67. 20 139.12 2360. 18 2214. 78 -1325 .17 1092.98 5926280 .09 461798.56 0.00 0.00
3300 .00 67. 20 139.12 2398. 93 2253. 53 -1394 .88 1153.31 5926210 .08 461858.52 0.00 0.00
3302 .77 67. 20 139.12 2400 .00 2254. 60 -1396 .80 1154.98 5926208 .14 461860.18 0.00 0.00 9 5/8" x 12 1/4"
3400 .00 67. 20 139.12 2437 .68 2292. 28 -1464 .58 1213.64 5926140 .07 461918.48 0.00 0.00
3483 .40 67. 20 139.12 2470 .00 2324. 60 -1522 .71 1263.95 5926081 .68 461968.49 0.00 0.00 C80 (K10)
3500 .00 67. 20 139.12 2476 .43 2331 .03 -1534 .28 1273.97 5926070 .06 461978.44 0.00 0.00
3600 .00 67. 20 139.12 2515 .19 2369 .79 -1603 .98 1334.30 5926000 .05 462038.40 0.00 0.00
3638 .23 67. 20 139.12 2530 .00 2384. 60 -1630 .63 1357.36 5925973 .29 462061.33 0.00 0.00 "Camp" sand
3700 .00 67. 20 139.12 2553 .94 2408 .54 -1673 .69 1394.63 5925930 .04 462098.36 0.00 0.00
3800 .00 67. 20 139.12 2592 .69 2447 .29 -1743 .39 1454.96 5925860 .03 462158.32 0.00 0.00
3900 .00 67. 20 139.12 2631 .44 2486 .04 -1813 .09 1515.29 5925790 .02 462218.29 0.00 0.00
4000 .00 67. 20 139.12 2670 .20 2524 .80 -1882 .80 1575.62 5925720 .02 462278.25 0.00 0.00
4100 .00 67 .20 139.12 2708 .95 2563 .55 -1952 .50 1635.95 5925650 .01 462338.21 0.00 0.00
4200 .00 67 .20 139.12 2747 .70 2602 .30 -2022 .20 1696.28 5925580 .00 462398.17 0.00 0.00
4300 .00 67 .20 139.12 2786 .45 2641 .05 -2091 .91 1756.61 5925509 .99 462458.13 0.00 0.00
4400 .00 67 .20 139.12 2825 .21 2679 .81 -2161 .61 1816.94 5925439 .98 462518.09 0.00 0.00
4500 .00 67 .20 139.12 2863 .96 2718 .56 -2231 .31 1877.27 5925369 .97 462578.05 0.00 0.00
4600 .00 67 .20 139.12 2902 .71 2757 .31 -2301 .02 1937.60 5925299 .96 462638.01 0.00 0.00
4700 .00 67 .20 139.12 2941 .46 2796 .06 -2370 .72 1997.93 5925229 .95 462697.97 0.00 0.00
4800 .00 67 .20 139.12 2980 .22 2834 .82 -2440 .42 2058.26 5925159 .94 462757.93 0.00 0.00
ORIGINAL
~onocoPhillips Alaska, In~
CPAI Plan Report
Compam~: ConocoPhillips Alaska Inc. Date: 8/31/2007 'time: 11:21:31 Pa~c: 3
Field: Kuparuk River Unit Co-or dinate(NF.) Refe rence: Wel l: Pl an: 2L-330, True North
Site: Kuparuk 2L Pad Vertical (TV D) Reference: Plan 2L-330 145.4
V1'ell: Plan : 2L-33 0 Section (VS) Referenc e: WeI I (O. OON,O.OOE ,145.OOAzi)
~i'ellpath: Plan : 2L-330 Surre y Calc ulation !17 ethod: Mini mu m Curvature Db: Oracle
Survey
~1ll [ncl Azim TVD Sys T~~~ N/S E/W ~1apN MapE llLS f1:0 Comme t
ft deg deg ft ft ft ft ft ft deg/100ft deg
__-
4900.
00 -
67. -
20
139.12
3018.
97
2873.
57
-2510.
12
2118.
59
5925089.
93
462817.
89
0.00
0.00
5000. 00 67. 20 139.12 3057. 72 2912. 32 -2579. 83 2178. 92 5925019. 92 462877. 85 0.00 0.00
5100. 00 67. 20 139.12 3096. 47 2951. 07 -2649. 53 2239. 25 5924949. 91 462937. 81 0.00 0.00
5200. 00 67. 20 139.12 3135. 23 2989. 83 -2719. 23 2299. 58 5924879. 91 462997. 78 0.00 0.00
5300. 00 67. 20 139.12 3173. 98 3028. 58 -2788. 94 2359. 91 5924809. 90 463057. 74 0.00 0.00
5400. 00 67. 20 139.12 3212. 73 3067. 33 -2858. 64 2420. 24 5924739. 89 463117. 70 0.00 0.00
5500. 00 67. 20 139.12 3251. 48 3106. 08 -2928. 34 2480. 57 5924669. 88 463177. 66 0.00 0.00
5600. 00 67. 20 139.12 3290. 24 3144. 84 -2998. 05 2540. 90 5924599. 87 463237. 62 0.00 0.00
5700. 00 67. 20 139.12 3328. 99 3183. 59 -3067. 75 2601. 23 5924529. 86 463297. 58 0.00 0.00
5800. 00 67. 20 139.12 3367. 74 3222. 34 -3137. 45 2661. 56 _ 5924459. 85 463357. 54. 0.00 0.00
5900. 00 67. 20 139.12 3406. 49 3261. 09 -3207. 15 2721. 89 5924389. 84 463417. 50 0.00 0.00
6000. 00 67. 20 139.12 3445. 25 3299. 85 -3276. 86 2782. 22 5924319. 83 463477. 46 0.00 0.00
6100. 00 67. 20 139.12 3484. 00 3338. 60 -3346. 56 2842. 55 5924249. 82 463537. 42 0.00 0.00
6200. 00 67. 20 139.12 3522. 75 3377. 35 -3416. 26 2902. 88 5924179. 81 463597. 38 0.00 0.00
6300. 00 67. 20 139.12 3561. 50 3416. 10 -3485. 97 2963. 21 5924109 .81 463657. 34 0.00 0.00
6400. 00 67. 20 139.12 3600. 26 3454. 86 -3555 .67 3023. 54 5924039 .80 463717. 30 0.00 0.00
6500. 00 67. 20 139.12 3639. 01 3493. 61 -3625 .37 3083. 87 5923969 .79 463777. 26 0.00 0.00
6600. 00 67. 20 139.12 3677. 76 3532. 36 -3695. 08 3144. 20 5923899. 78 463837. 23 0.00 0.00
6700. 00 67. 20 139.12 3716. 51 3571. 11 -3764 .78 3204. 53 5923829 .77 463897. 19 0.00 0.00
6800. 00 67. 20 139.12 3755. 27 3609. 87 -3834 .48 3264. 86 5923759 .76 463957. 15 0.00 0.00
6900. 00 67. 20 139.12 3794. 02 3648. 62 -3904 .19 3325. 19 5923689 .75 464017. 11 0.00 0.00
7000. 00 67. 20 139.12 3832. 77 3687. 37 -3973 .89 3385. 52 5923619 .74 464077. 07 0.00 0.00
7005 .75 67. 20 139.12 3835. 00 3689. 60 -3977 .90 3388. 99 5923615 .72 464080. 52 0.00 0.00 C50
7100 .00 67. 20 139.12 3871. 52 3726. 12 -4043 .59 3445. 85 5923549 .73 464137. 03 0.00 0.00
7200. 00 67. 20 139.12 3910. 28 3764. 88 -4113 .29 3506. 18 5923479 .72 464196. 99 0.00 0.00
7300. 00 67. 20 139.12 3949. 03 3803. 63 -4183 .00 3566. 51 5923409 .71 464256. 95 0.00 0.00
7400 .00 67. 20 139.12 3987, 78 3842. 38 -4252 .70 3626. 84 5923339 .70 464316. 91 0.00 0.00
7500 .00 67. 20 139.12 4026 .53 3881. 13 -4322 .40 3687. 17 5923269 .70 464376. 87 0.00 0.00
7600 .00 67. 20 139.12 4065 .29 3919. 89 -4392 .11 3747. 50 5923199 .69 464436. 83 0.00 0.00
7700 .00 67. 20 139.12 4104 .04 3958. 64 -4461 .81 3807. 83 5923129 .68 464496. 79 0.00 0.00
7800 .00 67. 20 139.12 4142 .79 3997 .39 -4531 .51 3868. 16 5923059 .67 464556. 75 0.00 0.00
7900 .00 67. 20 139.12 4181 .54 4036 .14 -4601 .22 3928. 49 5922989 .66 464616. 71 0.00 0.00
7947 .62 67. 20 139.12 4200 .00 4054. 60 -4634 .41 3957. 23 5922956 .32 464645. 27 0.00 0.00 C40
8000 .00 67. 20 139.12 4220 .30 4074. 90 -4670 ,92 3988. 82 5922919 .65 464676. 68 0.00 0.00
8100 .00 67. 20 139.12 4259 .05 4113 .65 -4740 .62 4049. 15 5922849 .64 464736. 64 0.00 0.00
8200 .00 67. 20 139.12 4297 .80 4152 .40 -4810 .32 4109. 48 5922779 .63 464796. 60 0.00 0.00
8300 .00 67. 20 139.12 4336 .56 4191 .16 -4880 .03 4169. 81 5922709 .62 464856. 56 0.00 0.00
8400 .00 67. 20 139.12 4375 .31 4229 .91 -4949 .73 4230. 14 5922639 .61 464916. 52 0.00 0.00
8500 .00 67. 20 139.12 4414 .06 4268 .66 -5019 .43 4290. 48 5922569 .60 464976. 48 0.00 0.00
8502 .43 67. 20 139.12 4415 .00 4269 .60 -5021 .12 4291. 94 5922567 .91 464977. 93 0.00 0.00 C37
8600 .00 67. 20 139.12 4452 .81 4307 .41 -5089 .14 4350. 81 5922499 .59 465036. 44 0.00 0.00
8700 .00 67. 20 139.12 4491 .57 4346 .17 -5158 .84 4411. 14 5922429 .59 465096. 40 0.00 0.00
8800 .00 67 .20 139.12 4530 .32 4384 .92 -5228 .54 4471. 47 5922359 .58 465156. 36 0.00 0.00
8900 .00 67 .20 139.12 4569 .07 4423 .67 -5298 .25 4531. 80 5922289 .57 465216. 32 0.00 0.00
9000 .00 67 .20 139.12 4607 .82 4462 .42 -5367 .95 4592. 13 5922219 .56 465276. 28 0.00 0.00
9100 .00 67 .20 139.12 4646 .58 4501 .18 -5437 .65 4652 .46 5922149 .55 465336. 24 0.00 0.00
9200 .00 67 .20 139.12 4685 .33 4539 .93 -5507 .36 4712 .79 5922079 .54 465396 .20 0.00 0.00
9300 .00 67 .20 139.12 4724 .08 4578 .68 -5577 .06 4773. 12 5922009 .53 465456. 16 0.00 0.00
9400 .00 67 .20 139.12 4762 .83 4617 .43 -5646 .76 4833 .45 5921939 .52 465516. 13 0.00 0.00
9500 .00 67 .20 139.12 4801 .59 4656 .19 -5716 .46 4893 .78 5921869 .51 465576 .09 0.00 0.00
9600 .00 67 .20 139.12 4840 .34 4694 .94 -5786 .17 4954 .11 5921799 .50 465636 .05 0.00. 0.00
9668 .24 67 .20 139.12 4866 .78 4721 .38 -5833 .73 4995 .27 5921751 .73 465676 .96 0.00 0.00
0,^.IGINAL
~onocoPhillips Alaska, In~
CPAI Plan Report
Company: ConocoPhillips Alaska Inc.
Date: 8/31/2007
Time: 11:21:31 _-
Yage: 4
Field: K uparuk Ri ver Unit Co-ordinate(NE) Reference: Well: Pl an: 2L-330, True North
Site: K uparuk 2L Pad Vertical ( TVD) Reference: Plan 2L -330 145.4
R'ell: P lan: 2L-330 Section (VS) Reference: Well (O. OON,O.OOE,145.OOAzi)
~~ ellpaNi: P lan: 2L-330 Survey C alculation Method: Minimu m Curvature Db: Oracle
Survey
~4ll
Incl
Azim
TVD
Sys TVD
N/S
E/1'V
MapN
MapE
ULS -__
TFO Comme t
ft deg deg ft ft ft ft ft ft deg/10 0ft deg
9676.49
66.91
139.17
4870.00
4724.60
-5839.48
5000.25 -.
5921745.96
465681.91
3.50
171.83 T7
9700.00 66.10 139.30 4879.37 4733.97 -5855.81 5014.32 5921729.56 465695.90 3.50 171.81
9800.00 62.64 139.86 4922.62 4777.22 -5924.43 5072.78 5921660.64 465753.99 3.50 171.76
9900.00 59.18 140.46 4971.24 4825.84 -5991.51 5128.76 5921593.27 465809.61 3.50 171.52
10000.00 55.72 141.11 5025.04 4879.64 -6056.80 5182.05 5921527.72 465862.56 3.50 171.22
10100.00 52.26 141.81 5083.82 4938.42 -6120.05 5232.45 5921464.21 465912.63 3.50 170.88
10200.00 48.82 142.58 5147.37 5001.97 -6181.03 5279.78 5921402.99 465959.63 3.50 170.46
10300.00 45.37 143.43 5215.44 5070.04 -6239.52 5323.86 5921344.28 466003.40 3.50 169.97
10369.12 43.00 144.09 5265.00 5119.60 -6278.36 5352.34 5921305.29 466031.68 3.50 169.39 T4
10400.00 41.94 144.40 5287.78 5142.38 -6295.28 5364.53 5921288.31 466043.77 3.50 168.92
10455.92 40.02 144.99 5330.00 5184.60 -6325.21 5385.72 5921258.28 466064.81 3.50 168.69 T3 Top Rese i
10456.45 40.00 145.00 5330.40 5185.00 -6325.48 5385.92 5921258.00 466065.00 3.50 168.24 2L-330wp03 T3 i
10500.00 39.56 145.00 5363.87 5218.47 -6348.31 5401.90 5921235.09 466080.87 1.00 180.00
10600.00 38.56 145.00 5441.51 5296.11 -6399.93 5438.05 5921183.29 466116.74 1.00 180.00
10680.74 37.76 145.00 5505.00 5359.60 -6440.80 5466.66 5921142.28 466145.14 1.00 180.00 T2 Base Rese
10700.00 37.56 145.00 5520.24 5374.84 -6450.44 5473.41 5921132.61 466151.84 1.00 180.00
10787.49 36.69 145.00 5590.00 5444.60 -6493.70 5503.70 5921089.19 466181.90 1.00 180.00 C35 base (K3)
10800.00 36.56 145.00 5600.04 5454.64 -6499.81 5507.98 5921083.06 466186.15 1.00 180.00
10900.00 35.56 145.00 5680.87 5535.47 -6548.03 5541.75 5921034.67 466219.66 1.00 180.00
10917.35 35.39 145.00 5695.00 5549.60 -6556.28 5547.52 5921026.39 466225.39 1.00 180.00 Top Albian ss
11000.00 34.56 145.00 5762.72 5617.32 -6595.09 5574.70 - 5920987.44 466252.36 ~ 1.00 180.00
11100.00 33.56 145.00 5845.56 5700.16 -6640.97 5606.82 5920941.40 466284.24 1.00 180.00
11200.00 32.56 145.00 5929.37 5783.97 -6685.66 5638.12 5920896.55 466315.30 1.00 180.00
11201.23 i 32.55 145.00 5930.40 • 5785.00 -6686.20 5638.49 5920896.01 466315.68 1.00 180.00 4 1/2" x 6 1/8"
Targets
_ _
_ -
_. _ hlap ;bta p <---- Latitu de ----> <-- Longitude --->
Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg I11in Scc
Dip. Dir. ft ft ft ft ft
2L-330wp03 T3 Gemini 5330.40 -6325.48 5385.92 5921258.00 46606 5.00 70 11 45. 194 N 150 16 24.418 W
-Circle (Radius: 100)
-Plan hit target
Annotation
11D T~~D
ft ft
300.00 300.00 KOP
Casing Points
119D TVD Diame ter hole Size Namc - _
ft
ft
in
in J
-
3302.77 2400.00 9.625 1 --
2.250 -
9 5/8" x 12 1/4" - - -
10456.45 5330.40 7.000 8.750 7"x 8 3/4"
11201.23 5930.40 4.500 6.125 4 1/2" x 6 1/8"
Formations
:1LD F~'ll Formations Lithology ll ip Angle Dip Direction ~
ft ft deg deg J
3483.40 2470.00 C80 (K10) 0.00 0.00
3638.23 2530.00 "Camp" sand 0.00 0.00
7005.75 3835.00 C50 0.00 0.00
7947.62 4200.00 C40 0.00 0.00.
8502.43 4415.00 C37 0.00 0.00
9676.49 4870.00 T7 0.00 0.00
10369.12 5265.00 T4 0.00 0.00
10455.92 5330.00 T3 Top Reservoir 0.00 0.00
nini
o~I~iNa~
~onocoPhillips Alaska, In~
CPAI Plan Report
I Company: ConocoPhillips Alaska Inc.
Field: Kuparuk River Unit
Site: Kuparuk 2L Pad
Nell: PIan:2L-330
~>'ellpath: PIan:2L-330
Formations
I11D TVD Formations
ft ft
10680.74 5505.00 T2 Base Reservoir
10787.49 5590.00 C35 base (K3)
10917.35 5695.00 Top Albian ss
Uate: 8/31/2007 Time: 11:21:31 Page: 5
Co-ordinate(NE) Reference: WeII: Plan: 2L-330, True North
Vertical (TVD) Reference: Plan 2L-330 145.4
Section (VS) Reference: Well (O.OON,O.OOE,145.OOAzi)
Sun°ey Calculation Method: Minimum Curvature Db: Oracle
Lithology
Dip Angle Uip Direction
deg deg
0.00 0.00
0.00 0.00
0.00 0.00
ORIGINAL
~onocoPhillips Alaska, In~
Anticollision Report
o
illips Alaska Inc.
Company: Co D
t
O
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1 Time te• 1
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Field. Ku aruk River Unit ~
o~
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Reference Site. Kupa u L Pad di
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Refer
) ence. Pl
ell n: 2L-330, True North
Reference Well: Plan: 2L-330 Vertical (TV D) Reference: Plan 2L-330 145.4
Reference Wellpath: Plan: 2L-330 Db: Oracle
GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Plan: 2L-330wp03 & NOT PLANNED PR
Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse
Depth Range: 30.00 to 11201.23 ft Scan Method: Trav Cylinder North
Maximum Radius: 1317.12 ft Error Surface: Ellipse + Casing
Casing Points
MD TVD -__
Diameter
Hole Sizc - _
Name __
ft ft in in
-
3302.77 2400.00
9.625
12.250 __
9 5/8" x 12 1/4" _
10456.45 5330.40 7.000 8.750 7"x 8 3/4"
11201.23 5930.40 4.500 6.125 4 1/2" x 6 1/8"
Plan: 2L-330wp03 Date Composed: 1/11/2007
Gemini Version: 8
Principal: Yes Tied-to: From Well Ref. Point
Summary
- - -
<_ ______________ Offset ~i'ellpath
---- ------------>
Reference _
Offset -
Ctr-Ctr -
No-Go
Allowable
Site ~~'cll Wellpath MD MD Distance Area Deviation Warning
ft ft ft ft ft
_
Kuparuk 2L Pad 2L-311 -
2L-311 VO -- - 277.09 275.00 285.62 4.73 280.89 Pass: Major Risk
Kuparuk 2L Pad 2L-313 2L-313 V2 734.71 725.00 249.90 9.99 239.91 Pass: Major Risk
Kuparuk 2L Pad 2L-315 2L-315 V2 860.91 850.00 218.40 12.96 205.45 Pass: Major Risk
Kuparuk 2L Pad 2L-317 2L-317 V2 267.58 275.00 195.81 4.80 191.01 Pass: Major Risk
Kuparuk 2L Pad 2L-317 2L-317A V6 267.58 275.00 195.81 4.80 191.01 Pass: Major Risk
Kuparuk 2L Pad 2L-321 2L-321 V2 1906.38 1925.00 159.93 52.11 107.82 Pass: Major Risk
Kuparuk 2L Pad , 2L-323 2L-323 V2 700.53 , 700.00 102.46 9.36 93.10 Pass: Major Risk
Kuparuk 2L Pad 2L-325 2L-325 V2 699.50 700.00 65.38 9.09 56.29 Pass: Major Risk
Kuparuk 2L Pad 2L-327 2L-327 V2 623.60 625.00 45.06 8.41 36.65 Pass: Major Risk
Kuparuk 2L Pad 2L-329 2L-329 V2 474.14 475.00 15.96 6.91 9.05 Pass: Major Risk
Kuparuk 2L Pad 2L-329 2L-329A V2 474.14 475.00 15.96 6.91 9.05 Pass: Major Risk
Kuparuk 2L Pad Plan: 2L-319 Plan: 2L-3 19 V1 Plan: 402.05 400.00 165.63 8.10 157.53 Pass: Major Risk
Kuparuk 2L Pad Plan: 2L-319 Prelim: 2L-319ST V1 PI 403.37 400.00 165.64 8.10 157.54 Pass: Major Risk
Kuparuk 2L Pad Plan: 2L-322 Plan: 2L-322 VO Plan: 1543.58 1550.00 62.85 22.33 40.53 Pass: Major Risk
Kuparuk 2L Pad Plan: 2L-330 Prelim: 2L-330 V3 Plan 3549.99 3550.00 0.76 92.18 -91.42 FAIL: Major Risk
Site: Kuparuk 2L Pad
Well: 2L-311 Rule Assigned: Major Risk
Wellpath: 2L-311 VO Inter-Site Error: 0.00 ft
Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable
MD TVD MD TVD Rcf Offset TFO+A ZI TFO-HS Casing/
i HSDistance Area
ft ft Deviation
ft Warning
ft ft ft ft ft ft deg deg n
145.40 145.40 143.30 143.30 0.18 0.00 76.69 76.69 285.03 2.54 282.49 Pass
152.10 152.10 150.00 150.00 0.20 0.00 76.69 76.69 285.03 2.65 282.37 Pass
177.10 177.10 175.00 175.00 0.25 0.02 76.69 76.69 285.01 3.08 281.92 Pass
202.10 202.10 200.00 200.00 0.31 0.03 76.69 76.69 284.96 3.52 281.45 Pass
227.10 227.10 225.00 225.00 0.37 0.04 76.70 76.70 285.00 3.92 281.07 Pass
252.10 252.10 250.00 250.00 0.42 0.04 76.73 76.73 285.21 4.33 280.89 Pass
277.09 277.09 275.00 274.99 0.48 0.04 .76.77 76.77 285.62 4.73 280.89 Pass
302.16 302.16 300.00 299.98 0.53 0.05 76.84 286.84 286.20 5.14 281.06 Pass
328.09 328.09 325.00 324.97 0.54 0.06 76.89 286.89 286.82 5.44 281.38 Pass
354.03 354.03 350.00 349.96 0.54 0.08 76.90 286.90 287.41 5.75 281,66 Pass
379.97 379.96 375.00 374.94 0.55 0.09 76.86 286.86 287.96 6.06 281.90 Pass
405.91 405.87 400.00 399.92 0.54 0.12 76.79 286.79 288.49 6.36 282.12 Pass
431.84 431.76 425.00 424.89 0.50 0.14 76.68 286.68 289.05 6.59 282.45 Pass
457.75 457.63 450.00 449.86 0.46 0.17 76.54 286.54 289.64 6.82 282.82 Pass
483.66 483.46 475.00 474.82 0.42 0.20 76.36 286.36 290.27 7.05 283.22 Pass
509.54 509.25 500.00 499.76 0.40 0.23 76.15 286.15 290.97 7.31 283.66 Pass
535.41 535.00 525.00 524.69 0.39 0.26 75.91 285.91 291.76 7.62 284.14 Pass
561.25 560.69 550.00 549.61 0.38 0.29 75.65 285.65 292.63 7.93 284.70 Pass
587.07 586.32 575.00 574.51 0.37 0.32 75.35 285.35 293.61 8.25 285.36 Pass
612.86 611.89 600.00 599.39 0.39 0.35 75.02 285.02 294.66 8.62 286.04 Pass
RAM
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AN'I'1-COLLISION S[:"I'TINCS
Inlcrpolalion Nlcthod:Nlp Inlcrval: 100.(10
Depth Ranhc prom: 30.00 1'0: 1120L23
Alaximuu- Range: 131.7.12 Reference: Plan: 2L-330wp03
150
125
100
75
21Z13~
2L-322 (Plan: 2L-322
0
2
0 2i.-323 (2i.-3231
Tool
CB-CYRO-SS
From Colour To MD
30 250
250 500
500 750
750 1000
1000 1250
3 50
- ~00 1500
1750
1750 2000
2000 2500
2500 3000
3000 3.
n: ~~1 9 PFe~iidi4500 9c
4500 5000
5000 6000
6000 7000
7000 8000
8000 9000
9000 10000
10000 12000
12000 14000
14000 16000
16000 18000
18000 20000
20000 25000
•
00
150
70
SURVEY PROGRAM
Fm Depth To Survey/Plan
1000.00 Planned: 2L-330wp03 VS
D 11201.23 Planned: 2L-330wp03 VS
Travelling Cylinder Azimuth (TFO+AZI) (deg vs Centre to Centre Separation ~SOft/in~
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Closest in POOL
Closest Approach: Reference Well: 2L-330wp03 Plan Offset Well: 2L-323
Coords. - Coords. -
ASP ASP
3-D ctr-ctr Meas. Incl. Subsea N(+)/S(-) View VS Meas. Incl. Subsea N(+)/S(-) View VS
Distance. Depth Angle TRUE Azi. ND E(+)/W(-) (145°) Comments Depth Angle TRUE Azi. ND E(+)/W(-) (145°) Comments
POOL Min Distance POOL Min Distance
(1639.85 ft) in POOL (1639.85 ft) in
~"
(5174 - 5370 NDss)
(5174 - 5370
"'~
to 2L-323-(5174 - to 2L-330wp03 Plan
1639.85 10455 40.02 144.9 5184.231 5921260 466067.7 8269.437 5370 NDss) 9949 55.93 131.09 5381.08 5922824 466521.2 7203.18 (5174 - 5370 NDss)
Closest Approac h: Reference Well: 2L-330wp03 Plan Offset Well: 2L-3 21
Coords. - Coords. -
ASP ASP
3-D ctr-ctr Meas. Incl. Subsea N(+)/S(-) View VS Meas. Incl. Subsea N(+)/S(-) View VS
Distance. Depth Angle TRUE Azi. ND E(+)/W(-) (145°) Comments Depth Angle TRUE Azi. ND E(+)/W(-) (145°) Comments
POOL Min Distance POOL Min Distance
(2001.19 ft) in POOL (2001.19 ft) in POOL
(5174 - 5370 NDss) (5174 - 5370 NDss)
to 2L-321 (5174 - to 2L-330wp03 Plan
°~ 2001.19 10680 37.76 145 5359.362 5921144 466148.1 8410.674 5370 NDss) 11373 55.96 129.58 5166.67 5921806 468027 8886.45 (5174 - 5370 NDss)
"Closest Approac h: Reference Well: 2L-330wp03 Plan Offset Well: 2L-3 25
Coords. - Coords. -
ASP ASP
3-D ctr-ctr Meas. Incl. Subsea N(+)/S(-) View VS Meas. Incl. Subsea N(+)/S(-) View VS •
Distance. Depth Angle TRUE Azi. ND E(+)/W(-) (145°) Comments Depth Angle TRUE Azi. ND E(+)/W(-) 145°) Comments
POOL Min Distance POOL. Min Distance
(2061 ft) in POOL (2061 ft) in POOL
(5174 - 5370 NDss) (5174 - 5370 NDss)
to 2L-325 (5174 - to 2L-330wp03 Plan
2061 ~?, '~ s:.w 10455 40.02 144.9 5184.231 5921260 466067.7 8269.437 5370 NDss) 8871 56.09 144.98 5370.12 5922548 464469.3 6272.93 (5174 - 5370 NDss)
2L-330wp03 PoolSummary.xls 8/31/2007 2:11 PM
ppep(«, Cen•coYMllpr Alerka lnc. Gdd CwncNOn: ~O.w lob N•:
lldd Nupwk tlv« OMI MapneNC D•cllnoNOn: xS.N AEE Ne:
WeN: xl-]JOwpol qP: A% NO:
%Y: EN/A Dople9 per 100 II SYaI•m (iVD) Nel«enc«
1«a.e(peenen Orlglnal VS Plane: 145.00 E•r.nlw.n:
^: usns.ao n Vlew VS Plane: 145.00 nce N.INkr.
r, ssxma.w n °n0 srnem:
Semen (VS) Selerenc e:
Comments:
POOL:
2L-330wp03 Plan: 5174' to 5370' TVDss
2L-325: 5174' to 5370' TVDss
2L-323: 5174' to 5370' TVDss
2L-321: 5174' to 5370' TVDss
Plan View
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Vertical Section along "View VS Plane"
Combo Preview Page 1 of 1 (2L-330wp03 Toolbox.xls)
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8/31/2007 2:06 PM
•
2L-330 Drilling Hazards Summary
Surface Hole Risks
Event Risk Level Miti ation Strate /Contin enc
Broach of conductor Low Monitor cellar & ad continuousl during interval
Gas Hydrates Moderate Minimum mud weight of 10.0 ppg. If observed -
/ control drill, reduce pump rates, reduce drilling fluid
tem eratures, addition of Lecithin
Running sands & gravel Moderate Maintain planned mud parameters, Increase mud
weightlviscosity, Use weighted sweeps, monitor fill
on connections
Hole swabbing/Tight hole on Moderate Circulate hole clean prior to trip, proper hole filling
tri s (use of tri sheets), um in out of hole as needed
Production Hole Risks
Event Risk Level Miti ation Strate /Contin enc
Insufficient or undetermined Low Importance of LOT communicated to all parties, all
LOT parties familiar with LOT procedure. Test will be
carried out until leak off is observed or to an FIT of
16 MW a uivalent
Swabbing Campaignian sands ` Moderate Minimum mud weight of 9.6 ppg, mandatory flow`
(50 ft TVD below C-80) check above sands on all tri s
Low OH LOT /High reservoir Low Open hole LOT to be performed before drilling into
pressure the Bermuda, wellbore strengthening can be
performed if OH LOT is not sufficient to drill into
Bermuda. 7" contingency top set available if WBS
is not successful
High ECD /Tight hole on trips/ Moderate Condition mud & clean hole prior to trips. Monitor
Swabbing ECDs with PWD tool while drilling across reservoir
interval. Hole cleaning best practices. Backream out
on trips as a last resort, proper hole filling (use of
tri sheets)
Lost circulation Moderate Keep hole clean -use PWD to monitor hole
cleaning. If losses occur -reduce pump rates and
mud rheolo ,use LCM
ORIGINAL
•
2L-330 Producer Top Set
'~' ,.
~~QI'1t?~t]~ ~ ~ I ~5
3-1 /2" Completion String
3 ''/z" Camco 'DS' nipple w/ 2.875" No-Go Profile
30" x 16" 62.6# 3 '/z" x 6' L-80 EUE 8rd handling pups installed above and below,
set at +/- 500' MD
Complcti~m. from hanger to 'DS' nipple, to be he drifted to 2.91 ".
3 ''/z" x 1 "Camco 'KBMG' mandrels with dummy valves 3 ''/z" x 6' L-80
with EUE 8rd handling pups installed above and below.
9-5/8" 40# L-80 BTC
+/- 3,302' MD / 2,400' TVD
Camco Chemical Inj Mandrel at two jts above lowest GLM
GLM #5 (?) at two joints above sliding sleeve
Lowest 3 ''/z" x 1" Camco 'KBMG' mandrel w/ 1" DCK-2 shear valve,
pinned for 2000 psi casing to tubing shear two jts above sleeve. Load rest
of GLMs with dummy valves
3 ''/z" Baker'CMU' sliding sleeve (closed position)
w/ 2.813" Camco DS profile EUE 8rd, with 3 ''/z" x 6' L-80 EUE 8rd
handling pups installed two jts above 2.75" no-go profile
3 ''/z" Camco 'D' nipple w/ 2.75" No-Go Profile. 3 ''/z" x 6' L-80 EUE 8rd
handling pups installed above and below, set at one jt above seals
3 ''/z" Baker 80-40 GBH-22 casing seal assembly w/ I S' stroke, 3 ''/z" x
6' L-80 EUE 8rd crossover handling pup installed on top
7" 26# L-80 BTCM I
@ 10,330' MD / 5,236' TVD
Baker Seal Liner top, with ZXP packer and SBE set at +/- 200' MD
above 7" casing shoe
Production Liner
4'/z" 12.6# L-80 IBT Mod
+/- 11,201' MD / 5,930' TVD
ORIGINAL
Schlumberger
CemCADE Preliminary Job Design
4 1/2" Liner
Preliminary Job Design based on limited input data. For estimate purposes only.
Rig: Nordic 3
Location: Tarn
Client: ConocoPhillips Alaska
Revision Date: 9/4/2007
Prepared by: Maureen Torrie
Location: Anchorage, AK
Phone: (907) 265-6336
Mobile: (907) 952-0445
email: mtorrie@slb.com
Top of Tail at
< 9,930' MD
< Liner Top at
10,130' MD
Previous Csg.
7", 26.0# casing
at 10,330' MD
< 4 1/2", 12.6# casing
in 6 1/8" OH
TD at 11,201' MD
(5,930' TVD)
Mark of Schlumberger
Volume Calculations and Cement Systems
Volumes are based on 50% excess. Displacement is calculated with a 4.5"- 16.6# drill
string. Cement job is designed to seal off liner top by bringing cement 200' above liner
top, with 15.8 ppg G cement (cement type as per client's request). Maximum dynamic
pressure experienced during cement job is expected to be 14.6 ppg.
Tail Slurry Minimum thickening time: 160 min. (pump time plus 120 min.)
GasBLOK w/ Class G + 2 gps D600G + 0.1 % B155 + 0.2 gps D047 + 0.35% D065 @
15.8 ppg - 1.17 ft3/sk
Liner Cap:
0.1044 ft3/ft x 200' x 1.00 (no excess) = 20.9 ft3
Liner Lap:
0.1044 ft3/ft x (10330' - 10130') x 1.00 (no excess) = 20.9 ft3
Annular Volume:
0.0942 ft3/ft x (11201' - 10330') x 1.50 (50°/t, excess} = 123.1 ft3
Shoe Volume:
0.0854 ft3/ft x 80' x 1.00 (no excess) = 7.7 ft3
Totals:
20.9 ft3+20.9 ft3+123.1 ft3+7.7ft3= 172.6 ft3
172.6 ft3/ 1.17 ft3/sk = 147.5 sks
Round up to 150 sks
BHST = 127, Estimated BHCT = 104.
(BHST calculated using a gradient of 2.2/100 ft. below the permafrost)
PUMP SCHEDULE
Pump Rate Stage Stage Time Cumulative
Stage Volume Time
(bpm) (bbl) (min) (min)
Pressure Test 10.0 -
MudPUSH II 5 15 3.0 3.0
Tail Slurry 5 31 6.2 9.2
Drop Top Plug 3.0 12.2
Displacement 5 159 31.8 44.0
MUD REMOVAL
Recommended Mud Properties: 11 ppg, Pv < 15, TY < 22. As thin and light as possible to
aid in mud removal during cementing.
Spacer Properties: 11.5 ppg MudPUSH" II, Pv = 19-22, TY = 22-29
Centralizers: Recommend 2 per joint for proper cement placement.
ORIGINAL
Schlumberger
CemCADE Preliminary Job Design
7" Intermediate Casin
Preliminary Job Design based on limited input data. For estimate purposes only.
Rig: Nordic 3
Location: Tarn
Client: ConocoPhillips Alaska, Inc.
Revision Date: 8/17/2007
Prepared by: Maureen Torrie
Location: Anchorage, AK
Phone: (907) 265-6336
Mobile: (907) 952-0445
email: mtorrie@slb.com
Previous Csg.
< 9 5/8", 40.0# casing
at 3,302' MD
< Top of Tail at
9,330' MD
< 7", 26.0# casing
in 8 3/4" OH
TD at 10,330' MD
(5,236' TVD)
Volume Calculations and Cement Systems
Volumes are based on 50% excess. Tail slurry is designed for 1000' MD above the
intermediate casing shoe (cement type as per client's request). Maximum dynamic
pressure experienced during cement job is expected to be 14.7 ppg.
Tail Slurry Minimum thickening time: 220 min. (Pump time plus 120 min.)
GasBLOK w/ Class G + 2 gps D600G + 0.1 % B155 + 0.2 gps D047 + 0.35% D065
15.8 ppg - 1.17 ft3/sk
0.1503 ft3/ft x 1000' x 1.50 (50% excess) = 225.5 ft3
0.2148 ft3/ft x 80' (Shoe Joint) = 17.2 ft3
225.5 ft3 + 17.2 ft3 = 242.7 ft3
242.7 ft3/ 1.17 ft3/sk = 207.4 sks
Round up to 210 sks
BHST = 112, Estimated BHCT = 75~.
(BHST calculated using a gradient of 2.2`F/100 ft. below the permafrost)
PUMP SCHEDULE
Pump Rate Stage Stage Time Cumulative
Stage Volume Time
(bpm) (bbp (min) (min)
Drop Bottom Plug 10.0 10.0
MudPUSH II 5 25 5.0 15.0
Tail Slurry 6 44 7.3 22.3
Drop Top Plug 5.0 27.3
Pump Water 4 20 5.0 32.3
Switch to Rig
Pum 5.0 37.3
Displacement 5 322 64.4 101.7
Slow Rate 3 50 16.7 118.4
MUD REMOVAL
Recommended Mud Properties: 10 ppg, Pv < 15, TY < 22. As thin and light as possible to
aid in mud removal during cementing.
Spacer Properties: 13.0 ppg MudPUSH* II, Pv = 19-22, TY = 22-29
Centralizers: Recommend 2 per joint across zones of interest for proper cement
placement.
ORIGINAL
Schhmberger
CemCADE Preliminary Job Design
9 5/8" Surface
Preliminary Job Design based on limited input data. For estimate purposes only.
Rig: Nordic 3
Location: Tarn
Client: ConocoPhillips Alaska, Inc.
Revision Date: 8/17/2007
Prepared by: Maureen Torrie
Location: Anchorage, AK
Phone: (907) 265-6336
Mobile: (907) 952-0445
email: mtorrie@slb.com
< TOC at Surface
Previous Csg.
< 20", 91.5# casing
at 80' MD
f
< Base of Permafrost at
1,560' MD (1,500' TVD)
i
i
< Top of Tail at
2,502' MD
< 9 5/8", 40.0# casing
in 12 1/4" OH
TD at 3,302' MD
(2,400' TVD)
Mark of Schlumberger
Volume Calculations and Cement Systems
Volumes are based on 300% excess in the permafrost and 50% excess below the
permafrost. The top of the tail slurry is designed to be at 2,502' MD.
Lead Slurry Minimum pump time: 250 min. (pump time plus 120 mirr.)
ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk
1.4895 ft3/ft x (80') x 1.00 (no excess) = 119.2 ft3
0.3132 ft3/ft x (1560' - 80') x 4.00 (300% excess) = 1854.1 ft3
0.3132 ft3/ft x (2502' - 1560') x 1.50 (50% excess) = 442.6 ft3
119.2 ft3 + 1854.1 ft3+ 442.6 ft3 = 2415.9 ft3
2415.9 ft3 / 4.45 ft3/sk = 542.9 sks
Round up to 550 sks
Have 290 sks of additional Lead on location for Top Out stage, if necessary.
Tail Slurry Minimum pump time: 190 min. (pump time plus 120 min.)
DeepCRETE @ 12.0 ppg - 2.47 ft3/sk
0.3132 ft3/ft x (3302' - 2502') x 1.50 (50% excess) = 375.8 ft3
0.4257 ft3/ft x 80' (Shoe Joint) = 34.1 ft3
375.8 ft3 + 34.1 ft3 = 409.9 ft3
409.9 ft3/ 2.47 ft3/sk = 166 sks
Round up to 170 sks
BHST = 50~, Estimated BHCT = 65`F.
(BHST calculated using a gradient of 2.2`F/100 ft. below the permafrost)
PUMP SCHEDULE
Pump Rate Stage Stage Time Cumulative
Stage Volume Time
(bPm) (bbll (min) (min)
CW 100 5 50 10.0 10.0
Drop Bottom Plug 15.0 25.0
MudPUSH II 6 50 8.3 33.3
Lead Slurry 7 436 62.3 95.6
Tail Slurry 7 75 10.7 106.3
Drop Top Plug 5.0 111.3
Water 5 20 4.0 115.3
Switch to Rig
Pumps 5.0 120.3
Displacement 6 204 34.0 154.3
Slow Rate 3 20 6.7 161.0
MUD REMOVAL
Recommended Mud Properties: 9.5 ppg, Pv < 15, TY < 15. As thin and light as possible
to aid in mud removal during cementing.
Spacer Properties: 10.5 ppg MudPUSH* II, Pv = 17-21, TY = 20-25
Centralizers: Recommend 1 per joint across zones of interest, and 2 per joint for bottom
8 joints for proper cement placement.
ORIGINAL
Page 1 of 1
Maunder, Thomas E {DOA)
From: Greener, Mike R. [Mike.R.Greener@conocophillips.com]
Sent: Friday, September 28, 2007 1:39 PM
To: Maunder, Thomas E (DOA)
Subject: RE: 2L-330
Using the predicted 3,151 psi reservoir pressure I believe the formula should be:
MPSP = (5,265 ft TVD)*(.60-.I 1 psi/ft)
MPSP = 2,572 psi.
My mistake in the calculation. Thanks for catching it.
-----Original Message-----
From: Maunder, Thomas E (DOA) [mailtoaom.maunder@alaska.gov]
Sent: Friday, September 28, 2007 1:33 PM
To: Greener, Mike R.
Subject: 2t_-330
Mike,
1 am reviewing the permit application. Would you please check your MASP calculation (page 3)?
It appears that a water gradient has been used in the calculation rather than the formation pressure
gradient.
Call or message with any questions.
Tom Maunder, PE
AOGCC
9/28/2007
6050000
6000000
5950000
5900000
5850000
EPA Aquifer Exemption - 40 CFR 147.102 (b)(3)
400000
500000
600000
700000
800000
TRANSMITTAL~L~ETTER CHECKLIST
WELL NAME ~'~-/C- ~ ` ~~~~
PTD# Z~ ~ , ~~-~
P p ry
Develo meat Service Ex lorato Stratigraphic Test
Non-Conventional Well
Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter
CHECK ADD-ONS TEXT FOR APPROVAL LETTER
WHAT (OPTIONS)
APPLIES
MULTI LATERAL The permit is for a new wellbore segment of existing
well
(If last two digits in permit No. ,API No. 50- - -
API number are
between 60-69)
Production should continue to be reported as a function of the
original API number stated above.
PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs
acquired for the pilot hole must be clearly differentiated in both
well name ( PH) and API number
(50- - -_) from records, data and logs
acquired for well
SPACING The permit is approved subject to full compliance with 20 AAC
EXCEPTION 25.055. Approval to perforate and produce /inject is contingent
upon issuance of a conservation order approving a spacing
exception. , assumes the
liability of any protest to the spacing exception that may occur.
DRY DITCH All dry ditch sample sets submitted to the Commission must be in
SAMPLE no greater than 30' sample intervals from below the permafrost or
from where samples are first caught and t0' sample intervals
through target zones.
Please note the following special condition of this permit:
Non-Conventional production or production testing of coal bed methane is not allowed
Well for name of well) until after (Company Name) has designed and
implemented a water well testing program to provide baseline data
on water quality and quantity. Company Name) must contact the
Commission to obtain advance approval of such water well testing
ro ram.
Rev: 7/13/2007
•
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Well History File
APPENDIX
Information of detailed nature that is not
•
particularly germane io the Well Permitting Process
but is part of the history file.
To improve the readability of the Wefl History file and to
simplify finding information, information of this
nature is accumulated at the end of the file under APPENpIX.
No special effort has been made to chronologically
organize this category of information.
21-330.tapx
Sperry-Sun Drilling Services
LIS Scan Utility
$Revision: 3 $
LisLib $Revision: 4 $
Tue Jan 22 14:40:21 2008
Reel Header
Service name .............LISTPE
Date . ...................08/01/22
Origin ...................STS
Reel Name. .... ........UNKNOWN
Continuation Number......01
Previous Reel Name.......UNKNOWN
Comments .................STS LIS writing Library. scientific Technical services
Tape Header
Service name .............LISTPE
Date . ...................08/01/22
Origin ...................STS
Tape Name. .... ........UNKNOWN
Continuation Number......01
Previous Tape Name.......UNKNOWN
Comments .................STS LIS Writing Library. Scientific Technical Services
Physical EOF
Comment Record
TAPE HEADER
Tarn
MWD/MAD LOGS
WELL NAME: 2L-330
aP2 NUMBER: 501032055400
OPERATOR: ConocoPhillips Alaska Inc.
LOGGING COMPANY: Sperry Drilling Services
TAPE CREATION DATE: 22-JAN-08
JOB DATA
MWD RUN 1 MWD RUN 2 MWD RUN 3
Job NUMBER: w-0005232602 w-0005232602 w-0005232602
LOGGING ENGINEER: 0. OBI 0. OBI O. OBI
OPERATOR WITNESS: D. BREEDEN D. BREEDEN D. MORRIS
MWD RUN 4
JOB NUMBER: w-0005232602
LOGGING ENGINEER: A. MENEZES
OPERATOR WITNESS: D. MORRIS
SURFACE LOCATION
SECTION: 22
TOWNSHIP: lON
RANGE: 7E
FNL: 237
FSL:
FEL: 938
FWL:
Page 1
ELEVATION (FT FROM MSL O)
KELLY BUSHING:
DERRICK FLOOR:
GROUND LEVEL:
WELL CASING RECORD
OPEN HOLE
BIT SIZE (IN)
1ST STRING 12.250
2ND STRING 8.750
3RD STRING 6.125
PRODUCTION STRING
REMARKS:
21-330.tapx
146.07
.115.40
CASING DRILLERS
SIZE (IN) DEPTH (FT)
16.000 80.0
10.375 3318.0
7.000 10307.0
•
1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE
NOTED. THESE DEPTHS
ARE BIT DEPTHS.
2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD).
3. MWD RUNS 1-4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY
(DGR) UTILIZING
GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC
WAVE RESISTIVITY
PHASE-4 (EWR4). MWD RUNS 2-4 ALSO INCLUDED PRESSURE
WHILE DRILLING (PWD).
ADDITIONALLY, MWD RUN 4 INCLUDED AZIMUTHAL
LITHO-DENSITY (ALD), COMPENSATED
THERMAL NEUTRON (CTN), AND GEOTAP FORMATION TESTER.
MAD DATA OVER THE
INTERVAL 4374'-3644'MD (CORRECTED BIT DEPTHS)
ACQUIRED WHILE RIH FOR MWD
RUN 3 WERE MERGED WITH MWD RUN 3 DATA.
4. MWD RUNS 3 & 4 WERE DEPTH CORRECTED TO RUN 2, PER
E-MAIL EXCHANGE BETWEEN
DERIK KLEIBACKER (CPAI) AND ROB KALISH (SDS). LOG
HEADER DATA RETAIN
ORIGINAL DRILLER'S DEPTH REFERENCES. THE
DEPTH-CORRECTED DATASET IS
CONSIDERED PDC.
5. MWD RUNS 1-4 REPRESENT WELL 2L-330 WITH API#:
50-103-20554-00. THIS WELL
REACHED A TOTAL DEPTH (TD) OF 11201'MD/5935'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
SPACING).
SFXE = SMOOTHED FORMATION EXPOSURE TIME - DEEP
RESISTIVITY.
TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE
MATRIX,FIXED HOLE SIZE).
CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE.
CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE.
Page 2
~ r
21-330.tapx
SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT
BIN).
SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN).
SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC
ABSORPTION FACTOR
(LOW-COUNT BIN).
SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS.
DENSLIDE = NON-ROTATED INTERVALS ADJUSTED FOR
BIT-TO-SENSOR DISTANCE.
PARAMETERS USED IN POROSITY LOG PROCESSING:
HOLE SIZE: FIXED (6.125~~ BIT)
MUD WEIGHT: 10.5-10.8 PPG
MUD SALINITY: 200-300 PPM CHLORIDES
FORMATION WATER SALINITY: 19149 PPM CHLORIDES
FLUID DENSITY: 1.0 G/CM3
MATRIX DENSITY: 2.65 G/CM3
LITHOLOGY: SANDSTONE
File Header
service name... .......STSLIB.001
Service Sub Level Name...
version Number. ........1.0.0
Date of Generation.......08/01/22
Maximum Physical Record..65535
File Type. ............LO
Previous File Name.......STSLI6.000
Comment Record
FILE HEADER
FILE NUMBER: 1
EDITED MERGED MWD
Depth shifted and clipped curves; all bit runs merged.
DEPTH INCREMENT: .5000
FILE SUMMARY
PBU TOOL CODE START DEPTH STOP DEPTH
RPD 152.5 11142.5
RPX 152.5 11142.5
RPM 152.5 11142.5
FET 152.5 11142.5
RPS 152.5 11142.5
GR 161.5 11135.5
ROP 216.5 11194.5
FONT 10237.5 11107.5
NCNT 10237.5 11107.5
NPHI 10237.5 11107.5
RHOS 10252.0 11122.5
DRHO 10252.0 11122.5
PEF 10252.0 11122.5
BASELINE CURVE FOR SHIFTS:
CURVE SHIFT DATA (MEASURED DEPTH)
--------- EQUIVALENT UNSHIFTED DEPTH ---------
BASELINE DEPTH
MERGED DATA SOURCE
PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE
MwD 1 152.5 3335.0
Page 3
MWD 2
MWD 3
MWD 4
REMARKS: MERGED MAIN PASS.
21-330.tapx
3335.0 4374.0
4374.0 10323.5
10323.5 11194.5
Data Format Specification Record
Data Record Type... ..........0
Data specification Block Type.....0
Loping Direction .................DOwn
optical log depth units...........Feet
Data Reference Point ..............undefined
Frame Spacing....... ............60 .lIN
Max frames per record .............undefined
Absent value ......................-999
Depth units. .. .. .....
Datum Specification Block sub-type...0
Name service order units size Nsam Rep Code offset Channel
DEPT FT 4 1 68 0 1
FCNT MWD CP30 4 1 68 4 2
NCNT MWD CP30 4 1 68 8 3
RHOB MWD G/CC 4 1 68 12 4
DRHO MWD G/CC 4 1 68 16 5
RPD MWD OHMM 4 1 68 20 6
RPM MWD OHMM 4 1 68 24 7
RPS MWD OHMM 4 1 68 28 8
RPX MWD OHMM 4 1 68 32 9
FET MWD HR 4 1 68 36 10
GR MWD API 4 1 68 40 11
PEF MWD B/E 4 1 68 44 12
ROP MWD FPH 4 1 68 48 13
NPHI MWD PU-S 4 1 68 52 14
First Last
Name Service Unit Min Max Mean Nsam Reading Reading
DEPT FT 152.5 11194.5 5673.5 22085 152.5 11194.5
FCNT MWD CP30 88.34 1496.56 358.674 1741 10237.5 11107.5
NCNT MwD cP30 12037.8 39814.8 22263.9 1741 10237.5 11107.5
RHOB MwD G/CC 1.08 2.721 2.44879 1742 10252 11122.5
DRHO MWD G/CC -1.974 0.444 0.0855769 1742 10252 11122.5
RPD MWD OHMM 0.85 2000 48.1138 21981 152.5 11142.5
RPM MWD OHMM 0.95 2000 38.6034 21981 152.5 11142.5
RPS MWD OHMM 0.82 2000 27.6694 21981 152.5 11142.5
RPX MWD OHMM 0.06 1854.53 12.5723 21981 152.5 11142.5
FET MWD HR 0.07 132.44 4.2846 21981 152.5 11142.5
GR MWD API 14.28 227.36 115.094 21949 161.5 11135.5
PEF MWD B/E 2.79 16.41 6.37717 1742 10252 11122,5
ROP MWD FPH 0.04 5496.65 144.222 21957 216.5 11194,5
NPHI MWD Pu-S 12.72 62.32 32.4198 1741 10237.5 11107.5
First Reading For Entire File..........152.5
Last Reading For Entire File...........11194
File Trailer
Service name... .......STSLIB.001
service sub Level Name...
Page 4
~ ~
21-330.tapx
version Number. ........1.0.0
Date of Generation.......08/01/22
Maximum Physical Record..65535
File Ty ~e ................L0
Next File Name...........STSLIB.002
Physical EOF
File Header
Service name... .......STSLI6.002
service sub Level Name...
version Number. ........1.0.0
Date of Generation.......08/01/22
Maximum Physical Record..65535
File Type. ............LO
Previous File Name.......STSL26.001
Comment Record
FILE HEADER
FILE NUMBER: 2
RAW MWD
Curves. and log header data for each bit run in separate files.
BIT RUN NUMBER: 1
DEPTH INCREMENT: .5000
FILE SUMMARY
VENDOR TOOL CODE START DEPTH STOP DEPTH
FET 152.5 3271.5
RPD 152.5 3271.5
RPX 152.5 3271.5
RPS 152.5 3271.5
RPM 152.5 3271.5
GR 161.5 3279.0
RoP 216.5 3335.0
LOG HEADER DATA
DATE LOGGED: 06-NOV-07
SOFTWARE
SURFACE SOFTWARE VERSION: Incite
DOWNHOLE SOFTWARE VERSION: 74.11
DATA TYPE (MEMORY OR REAL-TIME): Memory
TD DRILLER (FT): 3335.0
TOP LOG INTERVAL (FT): 161.5
BOTTOM LOG INTERVAL (FT): 3335.0
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
MINIMUM ANGLE: .1
MAXIMUM ANGLE: 68.8
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE TOOL NUMBER
DGR DUAL GAMMA RAY 134429
EWR4 ELECTROMAG. RESIS. 4 63122
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN): 12.250
DRILLER'S CASING DEPTH (FT): .O
BOREHOLE CONDITIONS
Page 5
21-330.tapx
MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S):
MUD PH:
MUD CHLORIDES (PPM):
FLUID LOSS (C3):
RESISTIVITY (OHMM) AT TEMPERATURE (DEG F)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TERMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
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~iny Direction .................Down
optical log depth units...........Feet
Data Reference Point ..............undefined
Frame Spacing....... ............60 .lIN
Max frames per record .............undefined
Absent value ......................-999
Depth units. .. .. .....
Datum specification Block sub-type...0
Native/spud Mud
9.80
220.0
9.1
150
9.5
7.000 70.0
4.930 102.2
6.000 70.0
5.000 70.0
Name service order units size Nsam Rep code offset Channel
DEPT FT 4 1 68 0 1
RPD MWDO10 OHMM 4 1 68 4 2
RPM MWDO10 OHMM 4 1 68 8 3
RPS MWDO10 OHMM 4 1 68 12 4
RPX MWDO10 OHMM 4 1 68 16 5
FET MWDO10 HR 4 1 68 20 6
GR MWDO10 API 4 1 68 24 7
RoP MWDO10 FPH 4 1 68 28 8
First Last
Name Service Unit Min Max Mean Nsam Reading Reading
DEPT FT 152.5 3335 1743.75 6366 152.5 3335
RPD MWDO10 OHMM 3.02 2000 139.958 6239 152.5 3271.5
RPM MWDO10 OHMM 2.85 2000 119.283 6239 152.5 3271.5
RPS MWDO10 OHMM 3.07 2000 79.8691 6239 152.5 3271.5
RPX MWDO10 OHMM 2.93 1656.06 31.9176 6239 152.5 3271.5
FET MwD010 HR 0.07 5.66 0.884728 6239 152.5 3271.5
GR MWDO10 API 14.28 152.68 83.8869 6236 161.5 3279
ROP MWDO10 FPH 0.99 5496.65 156.568 6238 216.5 3335
First Reading For Entire File..........152.5
Last Reading For Entire File...........3335
Page 6
21-330.tapx
File Trailer
Service name... .......STSLIB.002
service sub Level Name...
version Number. ........1.0.0
Date of Generation.......08/01/22
Maximum Physical Record..65535
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service sub Level Name...
version Number. ........1.0.0
Date of Generation.......08/01/22
Maximum Physical Record..65535
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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: 2
DEPTH INCREMENT: .5000
FILE SUMMARY
VENDOR TOOL CODE START DEPTH STOP DEPTH
RPS 3272.0 3621.5
RPD 3272.0 3621.5
RPX 3272.0 3621.5
FET 3272.0 3621.5
RPM 3272.0 3621.5
GR 3279.5 3629.5
RoP 3335.5 4374.0
LOG HEADER DATA
DATE LOGGED: 11-NOV-07
SOFTWARE
SURFACE SOFTWARE VERSION: Insite
DOWNHOLE SOFTWARE VERSION: 74.11
DATA TYPE (MEMORY OR REAL-TIME): Memory
TD DRILLER (FT): 4380.0
TOP LOG INTERVAL (FT): 3335.0
BOTTOM LOG INTERVAL (FT): 4380.0
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
MINIMUM ANGLE: 66.8
MAXIMUM ANGLE: 67.0
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE TOOL NUMBER
DGR DUAL GAMMA RAY 119546
EWR4 ELECTROMAG. RESIS. 4 127479
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN): 8.750
Page 7
21-330.tapx
DRILLER'S CASING DEPTH (FT ): 3318.0
BOREHOLE CONDITIONS
MUD TYPE: Fresh Water Gel
MUD DENSITY (LB/G): 9.60
MUD VISCOSITY (S): 55.0
MUD PH: 9,5
MUD CHLORIDES (PPM): 200
FLUID LOSS (C3):
RESISTIVITY (OHMM) AT TEMP ERATURE (DEG F)
MUD AT MEASURED TEMPERATURE (MT): 1.400 71.0
MUD AT MAX CIRCULATING TERMPERATURE: 1.070 95.0
MUD FILTRATE AT MT: 1.600 71.0
MUD CAKE AT MT: 1.350 71.0
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
Logging Direction ............ .....Down
optical log depth units...... .....Feet
Data Reference Point ......... .....undefined
Frame Spacing....... ....... .....60 .lIN
Max frames per record ........ .....undefined
Absent value ................. .....-999
Depth units. .. .. .....
Datum specification Block sub -type...0
Name service Order units Size N sam Rep Code Offset Channel
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 HR 4 1 68 20 6
GR MWD020 API 4 1 68 24 7
ROP MWD020 FPH 4 1 68 28 8
First Last
Name service unit Min Max Mean Nsam Reading Reading
DEPT FT 3272 4374 3823 2205 3272 4374
RPD MWD020 OHMM 2.86 2000 117.319 700 3272 3621.5
RPM MWD020 OHMM 2.35 2000 12.7364 700 3272 3621.5
RPS MWD020 OHMM 2.25 2000 14.7954 700 3272 3621.5
RPX MWD020 OHMM 0.06 7.49 4.65946 700 3272 3621.5
FET MWD020 HR 0.29 120.27 22.5737 700 3272 3621.5
GR MWD020 API 56.82 145.54 108.552 701 3279.5 3629.5
ROP MWD020 FPH 0.4 449.91 139.621 2078 3335.5 4374
First Reading For Entire File..........3272
Page 8
21-330.tapx
Last Reading For Entire File...........4374
File Trailer
Service name... .......STSLIB.003
service sub Level Name...
version Number. ........1.0.0
Date of Generation.......08/01/22
Maximum Physical Record..65535
File Type ................LO
Next File Name...........STSLIB.004
Physical EOF
File Header
Service name... .......STSLIB.004
Service sub Level~Name...
version Number. ........1.0.0
Date of Generation.......08/01/22
Maximum Physical Record..65535
File Type. ............LO
Previous File Name.......sTSLI6.003
Comment Record
FILE HEADER
FILE NUMBER: 4
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 STOP DEPTH
RPS 3622.0 10271.0
RPM 3622.0 10271.0
RPX 3622.0 10271.0
FET 3622.0 10271.0
RPD 3622.0 10271.0
GR 3630.0 10278.5
ROP 4374.5 10323.5
LOG HEADER DATA
DATE LOGGED: 16-NOV-07
SOFTWARE
SURFACE SOFTWARE VERSION: Insite
DOWNHOLE SOFTWARE VERSION: 74.11
DATA TYPE (MEMORY OR REAL-TIME): Memory
TD DRILLER. (FT): 10330.0
TOP LOG INTERVAL (FT): 4380.0
BOTTOM LOG INTERVAL (FT): 10330.0
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
MINIMUM ANGLE: 45.5
MAXIMUM ANGLE: 68.9
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE TOOL NUMBER
DGR DUAL GAMMA RAY 119546
EWR4 ELECTROMAG. RESIS. 4 127479
Page 9
•
21-330.tapx
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN): 8.750
DRILLER'S CASING DEPTH (FT): 3318.0
BOREHOLE CONDITIONS
MUD TYPE: Fresh Water Gel
MUD DENSITY (LB/G): 9.60
MUD VISCOSITY (S): 42.0
MUD PH: 9,2
MUD CHLORIDES (PPM): 200
FLUID LOSS (C3): 4.3
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT): 1.900 70.0
MUD AT MAX CIRCULATING TERMPERATURE: 1.110 125.0
MUD FILTRATE AT MT: 2.400 70.0
MUD CAKE AT MT: 1.600 70.0
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
Logging Direction .................DOwn
Optical log depth units...........Feet
Data Reference Point ..............undefined
Frame Spacing....... ............60 .lIN
Max frames per record .............undefined
Absent value ......................-999
Depth units. .. .. .....
Datum Specification 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 HR 4 1 68 20 6
GR MWD030 API 4 1 68 24 7
ROP MwD030 FPH 4 1 68 28 8
First Last
Name service unit Min Max Mean Nsam Reading Reading
DEPT FT 3622 10323.5 6972.75 13404 3622 10323.5
RPD MWD030 OHMM 1.85 71.76 4.7262 13299 3622 10271
RPM MwD030 OHMM 1.8 42.15 4.54197 13299 3622 10271
RPS MWD030 OHMM 1.6 22.18 4.30038 13299 3622 10271
RPX MWD030 OHMM 1.29 20.03 4.15487 13299 3622 10271
FET MWD030 HR 0.26 59.19 4.0293 13299 3622 10271
GR MwD030 API 60.38 227.36 129.195 13298 3630 10278.5
RoP MwD030 FPH 1.25 538.57 155.602 11899 .4374.5 10323.5
Page 10
21-330.tapx
First Reading For Entire File..........3622
Last Reading For Entire File...........10323.5
File Trailer
Service name... .......STSLIB.004
service sub Level Name...
version Number. ........1.0.0
Date of Generation.......08/01/22
Maximum Physical Record..65535
File Type ................L0
Next File Name...........STSLIB.005
Physical EOF
File Header
service name... .......STSLI6.005
service sub Level Name...
version Number. ........1.0.0
Date of Generation.......08/01/22
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: 4
DEPTH INCREMENT: .5000
FILE SUMMARY
VENDOR TOOL CODE START DEPTH STOP DEPTH
NPHI 10237.5 11107.5
NCNT 10237.5 11107.5
FCNT 10237.5 11107.5
PEF 10252.0 11122.5
RHOB 10252.0 11122.5
DRHO 10252.0 11122.5
RPx 10271.5 11142.5
RPM 10271.5 11142.5
FET 10271.5 11142.5
RPD 10271.5 11142.5
RPS 10271.5 11142.5
GR 10279.0 11135.5
ROP 10324.0 11194.5
LOG HEADER DATA
DATE LOGGED: 24-NOV-07
SOFTWARE
SURFACE SOFTWARE VERSION: Insite
DOWNHOLE SOFTWARE VERSION: 74.11
DATA TYPE (MEMORY OR REAL-TIME): Memory
TD DRILLER (FT): 11201.0
TOP LOG INTERVAL (FT): 10330.0
BOTTOM LOG INTERVAL (FT): 11201.0
BIT ROTATING SPEED (RPM):
Page 11
• i
21-330.tapx
HOLE INCLINATION (DEG
MINIMUM ANGLE: 32.3
MAXIMUM ANGLE: 44.2
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE TOOL NUMBER
DGR DUAL GAMMA RAY 203301
CTN COMP THERMAL NEUTRON 239974
EwR4 Electromag Resis. 4 159436
ALD Azimuthal Litho-Dens 10859715
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN): 6.125
DRILLER'S CASING DEPTH (FT): 10307.0
BOREHOLE CONDITIONS
MUD TYPE: Fresh Water Gel
MUD DENSITY (LB/G): 10.60
MUD VISCOSITY (S): 50.0
MUD PH: 9,9
MUD CHLORIDES (PPM): 300
FLUID LOSS (C3): 9.0
RESISTIVITY (OHMM) AT TEMPERATURE (DEG F)
MUD AT MEASURED TEMPERATURE (MT): 2.100 71.0
MUD AT MAX CIRCULATING TERMPERATURE: 1.220 127.0
MUD FILTRATE AT MT: 1.960 71.0
MUD CAKE AT MT: 2.800 71.0
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
Logging Direction .................DOwn
optical log depth units...........Feet
Data Reference Point ..............undefined
Frame Spacing....... ............60 .lIN
Max frames per record .............undefined
Absent value ......................-999
Depth Units. .. .. .....
Datum Specification Block sub-type...0
Name service Order units Size Nsam Rep Code offset Channel
DEPT FT 4 1 68 0 1
FCNT MWD040 CP30 4 1 68 4 2
NCNT MWD040 CP30 4 1 68 8 3
RHOB MWD040 G/CC 4 1 68 12 4
DRHO MWD040 G/CC 4 1 68 16 5
RPD MWD040 OHMM 4 1 68 20 6
RPM MWD040 OHMM 4 1 68 24 7
RPS MWD040 OHMM 4 1 68 28 8
RPX MWD040 OHMM 4 1 68 32 9
FET MWD040 HR 4 1 68 36 10
Page 12
21-33 0.tapx
GR MWD040 API 4 1 68 40 11
PEF MWD040 B/E 4 1 68 44 12
ROP MwD040 FPH 4 1 68 48 13
NPHI MwD040 PU-S 4 1 68 52 14
Fi rst Last
Name Service Unit Min Max Mean Nsam Reading Reading
DEPT FT 10237.5 11194.5 10716 1915 10237.5 11194.5
FONT MWD040 CP30 88.34 1496.56 358.674 1741 10237.5 11107.5
NCNT MWD040 CP30 12037.8 39814.8 22263.9 1741 10237.5 11107.5
RHOB MWD040 G/CC 1.08 2.721 2.44879 1742 10252 11122.5
DRHO MWD040 G/CC -1.974 0.444 0.0855769 1742 10252 11122.5
RPD MwD040 OHMM 0.85 2000 22.6136 1743 10271.5 11142.5
RPM MwD040 OHMM 0.95 2000 20.088 1743 10271.5 11142.5
RPS MWD040 OHMM 0.82 2000 24.298 1743 10271.5 11142.5
RPX MWD040 OHMM 0.82 1854.53 10.7288 1743 10271.5 11142.5
FET MwD040 HR 0.84 132.44 11.0572 1743 10271.5 11142.5
GR MWD040 API 32.72 214.51 121.912 1714 10279 11135.5
PEF MWD040 B/E 2.79 16.41 6.37717 1742 10252 11122.5
ROP MWD040 FPH 0.04 216.49 27.7666 1742 10324 11194.5
NPHI MwD040 PU-s 12.72 62.32 32.4198 1741 10237.5 11107.5
First Reading For Entire File..........10237.5
Last Reading For Entire File...........11194.5
File Trailer
Service name... .......sTSLI6.005
service sub Level Name...
version Number. ........1..0.0
Date of Generation.......08/01/22
Maximum Physical Record..65535
File Type ................LO
Next File Name...........STSLIB.006
Physical EOF
Tape Trailer
Service name .............LISTPE
Date . ...................08/01/22
Origin......... .........STS
Tape Name. .... ........UNKNOWN
Continuation Number......01
Next Tape Name...........UNKNOWN
Comments .................STS LIS
Reel Trailer
service name .............LISTPE
Date . ...................08/01/22
Ori9in ...................STS
Reel Name. .... ........UNKNOWN
Continuation Number......01
Next Reel Name...........UNKNOWN
Comments .................STS LIS
writing Library. scientific Technical services
writing Library.
Page 13
scientific Technical services
•
21-330.tapx
Physical EOF
Physical EOF
End Of LIS File
Page 14
~ ConocoPhillips q,aska
FINAL WELL REPORT
ConocoPhillips Alaska, Inc.
TARN 2L-330
150' FNL, 573' FEL
Sec 26 - T10N - R7E, UM
North Slope, Alaska
Compiled by:
Ryan Massey
Nic Moir
November 29t" 2007
•
~b~-~a ~ ~ , 5~~5~
~~ EPOCH
ConocoPhillips Tarn 2L 330
•
TABLE OF CONTENTS
1 MUDLOGGING EQUIPMENT &CREW ...................................................................3
1.1 Equipment Summary .....................................................................................3
1.2 Crew ................................................................................................................4
2. GENERAL WELL DETAILS .....................................................................................5
2.1 Objectives .......................................................................................................5
2.2 Well Summary ................................................................................................7
3. GEOLOGICAL DATA .............................................................................................10
3.1 Lithostratigraphy .........................................................................................10
3.2 Mudlog Summary .........................................................................................12
3.3 Sampling Program /Sample Dispatch .......................................................30
3.4 Cali Bond Gas Bag Sample and IsoTube Inventory ..................................31
4. PRESSURE /FORMATION STRENGTH DATA ....................................................32
4.1 Formation Integrity/Leak Off Tests ............................................................32
4.2 Pore Pressure Evaluation Introduction .....................................................32
4.3 Pore Pressure Summary .............................................................................34
5. DRILLING DATA ....................................................................................................35
5.1 Daily Activity Summary ...............................................................................35
5.2 Bit Record .....................................................................................................38
5.3 Survey Record .............................................................................................39
5.4 Mud Record ..................................................................................................43
Enclosures
2"=100' Scale
2"=100' Scale
2"=100' Scale
2"=100' Scale
Mudlog
LWD Combo Log
Gas Ratio Log
Drilling Dynamics Log
E~ EPOCH
2
• • •
MUDLOGGING EQUIPMENT & CREW
1.1 Equipment Summary
ConotoPhillips Tarn 2L 330
Parameter Equipment Type /Position Total
Downtime Comments
Ditch gas
QGM electric gas trap
Flame ionization total & chromato ra h detector
30 mins QGM gas trap repaired twice from
permafrost pebble damage.
H2S Detector (H2S) Variable resistivity cell. Sample line, drill floor,
mud its & shakers - No Epoch H2S detector installed
Rate of penetration (ROP) BEI Encoder- Primary draw works block position
indicator -
Pum stroke counter SPM RIGWATCH Turck Ma netic roximit sensor - Minor ad~ustments
Hook Load HLKD / Wei ht on bit WOB RIGWATCH Ametek H draulic ressure cell -
Tor ue RTOQ To Drive Feed - Not receivin Tor ue si nal from Totco
To drive rota RPM To Drive Feed - Totco Wits feed
Stand i e & casin ressure SPP/CSIP Totco H draulic ressure cell -
Mud flow out FLOW Totco Flow Paddle - Totco Wits Feed
Pit levels x 6 Ball Float sensors in all its & tri tank - Totco Wits Feed
Mud to in unit com uter s stem Com ac Pentium III -
Geolo fist's workstation Com ac Pentium III Totco Workstation
Com an Man's workstation Com ac Pentium III - Totco Workstation
Tool usher's workstation Com ac Pentium III - Totco Workstation
Driller's workstation E och Azonix Touch Screen Class I Div II - Totco Workstation
E~ EPOCH
• • •
1.2 Crew
Unit Type Arctic
Unit Number : ML012
ConocoPhillips Tarn 2L 330
Mudloggers Years
~~ Days
On
Pad Geotechnicians Years Days
On
Pad Technician Trainees
Ryan Massey 1 29 Allen Williams 1 21
Mainuddin Chowdhury 1 14 Teresa Downey 1 3
Nic Moir 1 29
Y' Years experience as Mudlogger
Additional Comments
Two spare poly-flow gas lines were run through a heated umbilical to insure non freezing for the gas lines and rig air lines to the unit. The QGM gas trap
was routinely cleaned of drilling mud and the gas lines blown back with rig air during connections and bit trips. Pump Pressure was calibrated relative to
Totco. Block height was recalibrated to ensure accuracy after every cut and slip, and after casing runs. Calibration of Gas Detection and
Chromatograph was checked and recalibrations performed if necessary to confirm accuracy. Calibrations on all equipment held extremely well
throughout the well.
€~ EPOCH 4
ConocoPhillips Tarn 2L 330
i
2. GENERAL WELL DETAILS
2.1 Objectives
2L-330 is a planned producer in the Bermuda interval of Tarn and is proposed to
capture rare and reserves in this area between 2N and 2L pads. With the nearby
control from 2L-321, 2L-323, and 2L-325 plus 2N-302 the Bermuda reservoir sands
should be close to prognoses depths and of similar quality. At this target location the
estimated Gross (T3 to T2 interval) is 175'. Potential risks in order of concern are;
Reservoir quality and thickness
Lateral continuity or compartmentalization that would impact sweep and pressure
support from offset injectors
Lost circulation while drilling
The well design consists of 9-5/8"surface casing, 7" intermediate casing set above
the Bermuda pay interval, and a 4-1l2" cemented production liner. The completion
is 3-1/2"tubing with gas lift mandrels and one chemical injection mandrel with a 3/8"
encapsulated control line clamped on the outside of the tubing.
Surface Hole: (3,302' MD / 2,400' TVD)
While drilling the surface hole there will be signage on the pad (adjacent to the 75'
perimeter measured from the end of the diverter line) indicating the rig has diverter
equipment rigged up. There will be no admittance within the 75' perimeter without
approval of the rig supervisor. This will apply to all personnel, including the drill site
operators, while the rig has the diverter equipment in place. Although remote,
should the diverter equipment be used, apre-assigned rig crew member will be
stationed at the pad entrance to prevent non-essential personnel from accessing
the pad. The rig crew member will mobilize to the pad access road at the company
mans discretion.
There is some concern in the surface hole regarding hydrates which have occurred
in prior wells drilled at Tarn from just below permafrost at 1,100' TVD. The mud
weight should be at 10.0-10.2 ppg by the time 1,100' TVD is reached to
mitigate/limit any gas flows from hydrates.
There. have been two instances where cement was unable to be circulated to
surface on the primary job (2L-305, 2N-326).
TD of the surface hole (3,302' MD / 2,400' TVD) is based on being above the
. potentially gas-bearing C-80 interval which is prognoses to be at 3,483' MD / 2,470'
TVD. The BOP stack needs to be on the well when the C-80 is drilled.
~~ EPOCH 5
ConocoPhillips Tarn 2L 330
Intermediate Hole: (10,330' MD / 5,236' TVD)
The intermediate hole will be drilled with an 8-3/4" bit instead of 8-1/2". The 9-5/8"
40# surface casing and the 9-5/8" hanger with pup shall be drifted to 8-3/4" to allow
for the 8-3/4" bit. The slightly larger hole size will reduce ECD's slightly and will also
decrease the chance of clay pack-offs around the BHA. The casing point will need
to be verified by geologists but the goal is to stop about 100' above the potentially
over-pressured Bermuda and set casing.
NOTE: A casing "smear" test will be performed after drilling out the surface shoe
and drilling to just below
the Campanian sand.
Production Hole: (11,201' MD / 5,930' TVD)
A 10.5 -11 ppg EMW reservoir pressure will be expected for 2L-330. Therefore, the
planned mud weight for the 2L-330 production hole will be 10.5 ppg or greater. THE
PLAN IS TO DRILL WITH A MW THAT IS SLIGHTLY ABOVE RESERVOIR
PRESSURE TO AVOID WELL BREATHING.
•
E~ EPOCH 6
• • •
2.2 Well Summa
ConocoPhillips Tarn 2L 330
Well 2L-330 AFE Classification Producer Block N/A
Rig Name / Nordic Drilling/ Land Surface 150' FNL, 573' FEL, KB Elevation 147' above Pad Elevation 115.4'
T e Nordic #3 Co-Ordinates S 22, T10N, R7E GL
Primary Target Bermuda T-3 Primary Target 10,455'/ Secondary N/q Secondary N/A
De th 5,330' TVD Tar et Tar et De th
Spud Date 11/03/07 TD Depth 11424' MD/ TD Formation C-35 TD Date 11/24/07
-6144.08 SS TVD
Completion N/A Suspension N/A Days Drilling 21 Days Testing NA
Status Date
Hole Maximum De nth TD Formation Mud Weight Deviation Coring Casing Shoe De th FIT
Section
MDRT
(ft)
TVDSS
(ft (ppg) (°inc) /
Liner
MDRT
(ft
TVDSS
ft (ppg)
12.25" 3332' -2558' C-80 9.7 - 10.4 66° none 9-5/8" 3318' -2398' 16
8.75" 10307' -5090' T-7 10.0-10.1 33.62° none 7" 10307' -5090'
6.125" 11201' -5789' Esker 10.7-11.1 32° none 4-1/2" 11201' 5789'
E~ EPOCH
.~
ConocoPhillips Tarn 2L 330
Additional Comments:
Epoch commenced logging the 2L-330 on 11/04/07 at 80' drilling out of 16" conductor pipe.
Samples were caught at 50' intervals to 10,330' (approximately 100'above the Bermuda
formation) with Gas Bags were collected at 300' intervals and at gas kicks to a depth of
10,000'. Sample catchers were used throughout the well. Isotubes were collected in 30'
intervals through Bermuda reservoir zone starting from 100' above the Bermuda Formation
(10,330') and a 10' sampling/cuttings program was started with ditch cuttings, alternating to
30' while drilling rat hole.
Mud weight was 9.8 ppg at surface with an increase to 10.2 by 1958', increased to 10.5 at
3335' and held. Surface casing was run to 3318'. An FIT was run with an EMW of 16.0
ppg, and the mud system was swapped from Spud mud to LSND at 3675'. Mud weight
was 9.6 beneath surface casing, and raised to 10.5 at approximately 10,400', above the
Iceberg Formation.
Drilling commenced with an inclination of 0° (drilling with a Geo-Pilot). The hole was kicked
off at approximately 263' and the inclination was 66° by 3300' (surface casing). The
inclination was held to 9661', in which angle was dropped to 32.25° at 11201'.
No hole problems were encountered drilling the surface hole. Permafrost gravel caused
minor problems with the gas trap (300' - 700'), with gravel being caught in the agitator
spindles. The spindles were replaced several times as drilling continued under the
Permafrost. Rig crew hands were consistently washing down the shale shakers to
enhance sample recovery and keep from losing drilling mud fluids off the shale shakers.
Running sands and gravel were limited in scope with maintained mud parameters. Sample
Catchers checked and cleared the gas trap of clay accumulation at each sample interval,
and whenever a change in gas or lithology was noted.
Gas hydrates flows displayed a maximum recording of 3156 units. Initial hydrates were
recorded from 1320' to 1575' (mud weights between 10.2 and 10.3 and mud temperature
of approximately 68 degrees). Background gases and increased connection gases were
noted from 1625' to 3318' from hydrates. The flow line temperature increased from 68°
(1958') to a maximum of 80° (3335') likely causing further eroding of the hydrates.
No hole problems were encountered while drilling from 3440' to the top of the Bermuda
(10,354') (Intermediate Hole Section). Good hole cleaning techniques were used drilling
the deviated hole with high viscosity sweeps and good flow rates. Each connection
allowed circulating time to clean the hole of cuttings above the BHA. All hole trips showed
no drag or sticking. Slower trip and connection speeds prevented swab/surge damage to
the hole. Good maximum ROP effective rates were obtained to clean the angled hole with
assistance of using torque and drag trends, ECD and shale shakers productivity to
establish a clean hole baseline.
E~ EPOCH
C,
•
ConocoPhillips Tarn 2L 330
The production hole section drilled with no hole or drilling problems. No lost circulating or
hole sticking was encountered. The drill string was kept moving whenever possible to avoid
sticking. The ROP was controlled to 50 ft/hr to record good ditch cuttings throughout the
production zone. A 3% mud lubricant was added while drilling the production hole,
contaminating some pay zone samples. Additionally, care and attention was taken to avoid
over washing.
~ EPOCH
9
• • •
3. GEOLOGICAL DATA
3.1 Lithostrati rq aph_y
ConocoPhillips Tarn 2L 330
Drilling picks & actual wireline tops refer to provisional picks provided by the wellsite Geologist.
To /Marker
MD
ro nosis
TVD
ro nosis TVDSS
Prognosi
s
MD
actual
TVD
actual
TVDSS +/- to
Prognosi
s
12-1 /4" Surface.Casing .Borehole:
Permafrost
..................
..
.
.............
..
.................................................................
.
..
..............................................
.
W. Sak Sands (Top)
..................................................................................................
W. Sak Sands Base)
9 5/8" Casin Shoe 3,302' 2,400' -2,254' 3,318' 2,398' -2,252' -2
C80 3,483' 2,470' -2,325' 3,465' 2,455' -2,309' -15'
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Campanian Sand (Top)
3,638'
2,530'
-2,385'
3,636'
2,522'
-2,376'
-8'
C50 7,005' 3,835' -3,690' 6,968' 3,830' -3,684' -5'
C40
.
.
. . . . . . . .
. .
.
. . . . . . . . . . . . 7,947' 4,200' -4,055' 7,951' 4,203' -4,057' 3'
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . .
.
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
.
.
C37 8,502' 4,415' -4,270' 8,412' 4,382' -4,236' -33'
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
T7
. . .
.
9,676'
4,870'
-4,725'
9,721'
4,896'
-4,750'
26'
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
.
7_" Casing Shoe.. 10,330' 5,236' -5,090' 10,307' 5,236' -5,090' 0'
T4
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
.
. 10,369' 5,265' -5,119' 10,344' 5,263' -5,117' -2'
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . . . . . . . . . . . . . . . . . . . . . . . . .
. .
T3 (Top Reservoir) 10,455' 5,330' -5,184' 10,480' 5,360' -5,214' 30'
T2 Base Reservoir 10,680' 5,505' -5,359' 10,670' 5,501' -5,355' -4'
C35
.
. . . . .
. .
. . . .
. . .
. . . . . . . . . . . . . . . . 10,787' 5,590' -5,444' 10,728' 5,547' -5,401' -43'
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
. . .
. .
.
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
.
K-3
Not Prognose
d
10,803'
5,607'
-5,461'
Esker (To)
Not Prognose
d
10,920'
5,701'
-5,555'
Esker (Base
Not Prognose
d
11,103'
5,852'
-5,706'
E~ EPOCH l o
~ . •
ConocoPhillips Tarn 2L 330
TD 11,201' 5,930' -5,784' 11,201' 5,935' -5,789 5' _
~~ EPOCH i i
ConocoPhillips Tarn 2L 330
3.2 Mudlog Summary
The following text provides a brief summary of the defining lithological and drilling
characteristics for that part of the well, over which drill cuttings were collected.
Surface to 9 5/8" Surface Casing Point
80' to 3318' MDRT (80' to -2252' TVDSS)
The surface interval includes sand, claystone, and conglomeratic sands and conglomerate,
and some siltstone. Conglomeratic sand, conglomerate and claystone is the dominant
lithology until approximately 900', and then sand and claystone, with occasional
conglomeratic sand, from 750' until casing point. Some shale, siltstone and minor coal was
noted in the Permafrost.
Conglomeratic sand and conglomerate were predominantly light to medium light gray
with variable secondary hues. This entire section was poorly to moderately sorted in all
grain sizes, grading locally from conglomeratic sand to pebble/cobble conglomerate.
The formations were generally loosely consolidated or unconsolidated, with silica
cement becoming more predominant with increased depth. The conglomeratic sands
were observed to be primarily grain supported with some fine interbeds displaying trace
amounts of clay matrix, and the conglomerates assumed to have increasing matrix with
poorer sorting. Given the local, the material should be considered as having had a
permafrost matrix, at least in the upper sections. Sand size grains were primarily
smokey gray to translucent quartz with minor chert and lithic grains. Pebble/cobble
material was primarily black lithics at the surface grading to varicolored lithics and clear
to translucent quartz/quartzite/chert with increasing depth. Sand was generally angular
to sub angular, and sub spheroidal, with some degree of frosting. Pebbles were
generally mature with common chatter marks and chips. Pebble fragments result from
bit action and are not characteristic of the formation.
Sands were light gray to medium gray with pale secondary hues varying from olive
green to light brown. The formations were predominantly unconsolidated, and primarily
grain supported, with rare cohesive lithified well cemented fragments at depth. Grains
were moderately to poorly sorted, and angular to subangular to subrounded with good
to moderate sphericity. Grains were mostly clear to smokey gray quartz, with chert and
dark metamorphic and igneous lithic grains in locally variable quantities.
Claystone was logged as very light gray to medium dark gray with some darker
secondary hues. Claystone was highly reactive in the mud system, lumpy to mushy to
pasty on the shakers and in samples, and commonly hydrophilic, especially noted in
massive clays. The claystone was non calcareous, with a dull earthy luster; and clayey
to ashy texture, occurred as massive beds, to gradational to conglomeratic sand and
E~ EPOCH
12
•
ConocoPhillips Tarn 2L 330
sand, and in part as matrix for loose sands. Occasional traces of shell fragments were
noted below 1300'.
Drill Rate ftlhr) Total Gas (%)
Maximum Minimum Avera a Maximum Minimum Avera e
353 0 126 3156 0 576
€~i EPOCH 13
ConocoPhillips Tarn 2L 330
Surface Casing to C-80
3318' to 3465' MDRT (-2452' to -2309' TVDSS)
The new bit broke formation into siltstone and claystone, light gray to medium dark grey.
The claystone appeared soluble in the mud system and therefore structureless, and mushy
and pasty in samples. Fragmented siltstone appeared to have a developed bedded
structure with very thin laminar bedding of organic mud. Some grainsize grading was also
observed. The formation was composed of overall 50% clay and 50% silts and detrital
material, such as carbon silts and relic shards, and exhibiting an ashy to silty texture.
Drill Rate ft/hr Total Gas
Maximum Minimum Avera a Maximum Minimum Avera e
353 0 160 2499 14 236
C-80 to C-50
3465' to 6968' MDRT (-2309' to -3684' TVDSS)
This section is dominantly claystone, siltstone, and some very fine sandstone down to
5900', with a notable exception of an oil bearing conglomeratic sand (Campanian Sand)
from 3990-4000', and some minor ash. Below 5900' to the C-50 marker is mostly
sandstone, with some interbedded siltstone and claystone.
The Campanian Sand is medium dark gray to light olive gray, pebble to medium lower
grains, angular to subrounded, poorly sorted and poorly consolidated with dominant matrix
support, and very poor visible porosity. The composition is dominantly dark lithics and
quartz poor, with a trace of pyrite accretions on some pebbles. The samples exhibited
25% moderate to bright yellow fluorescence, with very slight light brown oil stain visible on
clay matrix, a slight instantaneous to slow diffuse milky blue white cut, and very faint
residue.
claystone and siltstone varied from light to medium gray, with common brownish hues to
light brownish gray, with thin beds of light gray ash, very fine grained sand lenses and
organic mud. The claystone tended to be very soft mushy and massive. While siltstone in
apparent throughout the C-80 formation, it dominates the lithology at depths of 5500' and
greater. It consists of fine beds of silt grading to very fine grains sand interbedded with
organic mud becoming carbonaceous shale with depth. Composition included trace to
abundant silt sized quartz to locally very fine grains, grading sandstone, very slight to slight
pervasive black to dark brown carbon silts and fines, often partially lineated to local
partings of flakes and fines, trace to lightly scattered micro pyrite, micro micas, and
occasional pyrite clusters, and some traces of glauconite.
Sandstone varied from light gray to medium gray with a green to brown secondary hues.
~~ EPOCH 14
ConocoPhillips Tarn 2L 330
Very fine to medium grained, and subangular to subrounded. Very fine grained sandstone
grading from siltstone, was mostly poorly to moderately sorted, poorly consolidated, and
grain and matrix supported with a sometimes slightly argillaceous (organic) but
predominantly silica matrix. Sandstone with a preponderance of fine grains, was mostly
moderately to moderately well sorted, and mostly grain supported with a light gray matrix,
and moderately consolidated with a siliceous cement. Composition was similar to siltstone,
including 80-85% quartz, 10-15% carbon flakes and fines; 0-5% tan to white partially
calcareous interstitial matter, 0-5% glauconite, and trace pyrite clusters. Visible porosities
were overall very poor to poor.
Drill Rate (ft/hr) Total Gas
Maximum Minimum Avera a Maximum Minimum Avera e
1008 0 152 304 0 24
C-50 to C-40
6968' to 7951' MDRT (-3684' to -4057' TVDSS)
This interval included claystone, siltstone, and a fine grained sandstone.
Well structured siltstone, displaying a grading from silt to very fine grained sand, was
medium light gray to medium, poorly indurated and partially hydrated, to some moderately
indurated, and overall non calcareous. Very soft loosely cohesive claystone appeared
massive with some sandstone and siltstone clast inclusions. The claystone appeared
soluble in the mud system and therefore structure less, and mushy and pasty in samples.
Drill Rate (ft/hr Total Gas (%)
Maximum Minimum Avera a Maximum Minimum Avera e
248 14 140 109 9 30
C-40 to C-37
7951' to 8412' MDRT (-4057' to -4236' TVDSS)
C7
This interval is a continuation of the overlying interval with similar sequences of siltstone
and claystone, and siltstone, occasionally grading to very fine grained sandstone.
Drill Rate ft/hr Total Gas
Maximum Minimum Avera a Maximum Minimum Avera e
285 60 166 91 17 59
~ EPOCH 15
ConocoPhillips Tarn 2L 330
C-37 toT-7
8412' to 9721' MDRT (-4236' to -4750' TVDSS)
This interval is mostly siltstone, grading to or interlaminated with very fine sandstone, and
some shale to 8700'. Below 8700' the T7 sees an increase in sandstone and sand,
including silt and very fine to coarse lower grains.
siltstone, sandstone, shale, and very fine sandstone were gradational to interlaminated,
very poorly to moderately indurated, non to slightly calcareous, and with color varying from
light to medium dark gray with a olive green to light brownish gray, depending on organic
content of clay. The shale was overall darker than the siltstone and sandstone, and notably
more indurated than in overlying zones, especially when slightly calcareous. Common
accessories, especially claystone and siltstone, included trace to slight carbon silts and
fines, trace to slight scattered micro pyrite, glauconite and possible micro micas. Some
very fine grain supported sandstone and cohesive siltstone and occurred as inclusions in
claystone. Sandstone tended to be moderately consolidated and predominantly grain
supported, with rare poorly consolidated matrix supported sandstone.
Sand and the coarser sandstone in the C-37 were light gray to medium gray, with very
pale brown to faint olive green hues, very fine to coarse lower grains, especially fine to
medium lower, subrounded to subangular, and well to moderately sorted. Samples
appeared as loose grains, to moderately consolidated brittle sandstone with calcareous
cement. Composition was 75% quartz; 15-25% dark gray to black to gray to bluish gray
to dark green to amber grains including silicates and minor siliceous lithics, of possible
volcanic origin in part; and occasional clusters of pyrite. Porosities were estimated at
fair to good porosity, but no oil was indicated.
Drill Rate (ft/hr) Total Gas
Maximum Minimum Avera a Maximum Minimum Avera e
365 0 155 101 13 36
•
~ EPOCH i 6
Conoco hillips Tarn 2L 330
T-7 to T-4 (Iceberg)
9721' to 10344' MDRT (-4750' to -5117' TVDSS)
Shale, siltstone, and some carbonaceous shale and siltstone are the dominant lithologies,
occasionally grading to very fine grained sandstone. Shale and siltstone is light gray to
medium gray, with brown secondary hues depending on the shale content. Poorly to
moderately indurated, and non calcareous, with slight silts and fines of carbon matter
scattered throughout, and some interlaminated dark brown organic siltstone and claystone.
Carbonaceous shale and siltstone is dusky brown to black to brownish black occurring as
thin beds and laminations.
Drill Rate ft/hr Total Gas
Maximum Minimum Avera a Maximum Minimum Avera e
279 31 142 84 5 37
T-4 to T-3 (Top of Production)
10344' to 10480' MDRT (-5117' to -5214' TVDSS)
This interval contains siltstone, sandstone with some carbonaceous shale and clay. The
interval begins as a dominant siltstone than grades into sandstone at 10,420' and at
10,435' the interval grades into a siltstone.
siltstone is medium gray becoming dark gray and the grain size varying from silt to lower
very fine grained sand. The cuttings are easily friable with a blocky brittle fracture. The
clasts are flaky tabular; bedding is present in structure predominantly grading of silt to fine
grained sand visible in bedding; hard lithified sandstone inclusions. Very fine laminar beds
and fragments of shale/organic mud are present. Trace sandstone clasts becoming
common at approximately 10420'. Angular clasts are hard to very hard and well lithified.
Grain supported with trace calcareous cement matrix. Trace fluorescence is present along
with a very faint milky solvent cut. Estimate poor to moderate porosity and permeability.
Sandstone is fight gray to medium gray with slight olive green secondary hues. Grain size
ranges from upper fine to upper medium. Sample appears as highly lithified sandstone
clasts. Grains are hard to very hard and have brittle fracture. Grain supported with a
calcareous cement matrix. Trace cohesive siltstone interbedded throughout. Sandstone
appears in sample as flaky tabular fragments with distinctive bedded structure. Trace
fluorescence present.
•
Drill Rate (ft/hr) Total Gas (%
Maximum Minimum Avera a Maximum Minimum Avera e
87 4 48 56 8 19
~ EPOCH 1 ~
ConocoPhillips Tarn 2L 330
T-3 (Bermuda) to T2 (Base Reservoir)
10480' to 10670' MDRT (-5214' to -5355' TVDSS)
The top reservoir of the Bermuda contains sandstone with interbedded siltstone. The
sandstone is most dominate at 10,500'.
The sandstone is light gray to medium gray with occasional faint dark greenish
secondary hues. Clasts size ranges from upper fine to upper medium grained.
Sample appears as highly lithified sandstone Clasts. Cuttings range from hard to very
hard with brittle fracture. Grain supported with a calcareous cement matrix. Trace
cohesive siltstone interbedded throughout. Fragments appear as flaky tabular
fragments with distinctive bedded structure. Trace fluorescence is present.
Composition is 95% translucent quartz, 5% darker colored lithics including pyrite,
carbonaceous material and calcite. Moderate to porosity and permeability is The
samples are heavily contaminated with tube in mud making it extremely difficult to
differentiate oil indicators with accuracy.
siltstone is light gray becoming medium gray. Grain size varies from silt to lower very
fine grained sand. Sample is firmly friable with a blocky brittle fracture. Clasts are flaky
tabular. Bedding is present in the structure and is evident by the grading of silt to fine
grained sand. Clasts appear to be angular and are hard to very hard. In addition they
are well lithified. The sample is dominantly grain supported with trace calcareous
cement matrix. Trace fluorescence is present with very faint milky solvent cut.
Moderate porosity and permeability is estimated.
Drill Rate ft/hr) Total Gas %)
Maximum Minimum Avera a Maximum Minimum Avera e
334 7 46 3404 3 126
•
~~ EPOCH 18
•
•
LJ
~~ EPOCH
19
ConocoPhillips Tarn 2L 330
n
U
•
~~ EPOCH
20
ConocoPhillips Tarn 2L 330
ConocoPhi~~~s
n
LJ
•
to C35 (K-3)
T_2 (Base of Reservoir) 5355' to -5789' TVDSS tendency
10670' to 10728' MDRT ra with a
ne dominated rock howevesha e O a00 daD g y
ins as sandsto Carbonaceous
This interval beg siltstone with clay.
ear in the same area and increases to 20°°~ a
develops to increasing hues at
brownish hue also app ra with slight dark brown second ry
e g ~ riable and has brittle fractures Predominant y
is li ht gray to medium dark g Y f redominantly
The sandston 10740, The sandstone is f rite. Trace
a proximately alcareous cement matrix. Sdarker~i hics and pY, ere is
p orted with a c 10740. Th
grain suPp uartz grains with some
arent to smokey gray q osition to 40% at approximately
transp aceous shale is also present in bedding and
siltstone increasing in overall comp ~ Sandstone shows
structure evident. Carbon roximately 10750 .
moderate bedding osition to about 30 /o at apP contaminated with lube in mud.
increa f uorescenclec a though sample is heavily
trace
Total Gas ial
Avera e
Drill Rate ftlhr Minimum 285
Avera e Maximum 32
Minimum 50 2420
Maximum 28
67
• 21
~~ EPOCH
•
•
•
~~ EPOCH
22
ConocoPhillips Tarn 2L 330
•
•
.7
~~ EPOCH
23
ConocoPhillips Tarn 2L 330
ConocoPhillips Tarn 2L 330
C-35 (K-3) to TD
10728' to 11201' MDRT (-5401' to -5789' TVDSS)
The top of the interval is a carbonaceous shale and carbonaceous siltstone, light brownish
gray to brownish gray to light gray, with variably organic ashy laminations of claystone and
siltstone, separated by moderate to abundant dark brown carbon micro partings.
Disseminated micro pyrite is scattered throughout, most cuttings had a trace of pin point
effervescence in 10% HCL, except rare cuttings were calcareous.
The lower part of the interval to above the Esker appears overall of similar character to the
above shales and siltstone, although more prominently silty and less organic, with overall
lightly scattered micropartings of carbon matter, and increases in readily identifiable
disseminated micro mica.
This interval includes siltstone, sandstone, and carbonaceous shale, including some oil
bearing thin sandstone intervals. The character and composition of the sandstone cuttings
is similar to the Bermuda, and an increase in sample fluorescence indicates the cuttings
are at least in part Esker cuttings but also cuttings lagging up late from the Bermuda.
Sandstone increases at 10950' and begin to lessen at 11005'.
The sandstone is light gray to medium gray with some slight light brownish hue. Grain size
varies from lower very fine to lower fine. Appears to be well lithified but has a brittle
fracture. The interval seems to be a massively bedded structure with no apparent grain
size grading but may be due to contamination for upper formation. Very tight grain
supported with little matrix. There is an oily sheen apparent on samples with some very
slight oil staining at approximately 11040'. Abundant fluorescence that displays very weak
diffuse slow solvent cut in sample. Estimate poor to moderate porosity and permeability.
Trace siltstone increasing in overall composition to about 60% at approximately 11110'.
siltstone, grading to or interlaminated with some very fine grained sandstone and shale,
was light gray to light brownish gray to gray, with velvety to silty to clayey to earthy textures,
dominantly ashy, and non to variably organic, with a trace to very slight pin point
effervescence in 10%HCL. Carbon partings were lightly scattered to abundant, although
cuttings with moderate to abundant micro partings are likely from overlying formations.
Drill Rate ft/hr) Total Gas (%)
Maximum Minimum Avera a Maximum Minimum Avera e
131 11 53 776 22 64
L'
E~ EPOCH 2 4
•
10'
~~ EPOCH
25
ConocoPhillips Tarn 2L 330
ConocoPhN6ps Tarn 2L 330
""'~
'~~~~~
~-
°.~' -4
~.~
`~ -.. °*
~~ , ~ a
~ .~
,~ ~ ti
~.
~ ~
•
~b820'
~u
26
•
~~ EpOCH
•
•
•
~~ EPOCH
27
ConocoPhillips Tarn 2L 330
•
•
•
ConocoPhillips Tarn 2L 330
~~ EPOCH
28
ConocoPhillips Tarn 2L 330
EPOCH SHOW REPORT NO. 1
COMPANY ConocoPhillips
WELL# Tarn 2L-330
LOCATION North Slope Borough, AK
DEPTH INTERVAL: 10480' TO 10670' (MD) TOTAL FTG: 190'
55360' TO 55501' (TVD)
BIT INFORMATION: BIT TYPE: Hycalog DS69FNPV BIT HOURS: 93:20: (total)
AVERAGES: BEFORE DURING AFTER MAXIMUM
ROP (fph) 48 (control drill) 46 (control drill) 50 334
WOB 34 34 17 72
RPM (with mud motor)
MUD WT OUT 9.8 10.5 10.7 10,7
CHLORIDES 200 300 300 300
OTAL GAS 18 126 64 3404
~1(ppm) 3056 6858 8095 141412
C2(ppm) 265 1042 909 24181
C3(ppm) 174 631 714 22375
C4(ppm) 45 504 635 21560
C5(ppm) 10 241 402 16816
Light yellowish
CUTTINGS FLUORESCENCE%: 40-50% COLOR: green
Mod to Slow hazy diffuse
INTENSITY: bright Even to patchy CUT: dull milky cut.
MUD FLUORESCENCE: Dull preen: possible from mud chemicals (under UV light
FORMATION DESCRIPTION:
Sandstone 70% Sandstone =light gray to medium gray, clast sizes range from upper fine to upper medium; angular clasts;
Sand 10% highly lithified; hard to very hard; brittle fracture; appeared grain supported with a calcareous cement matrix;
Siltstone 20% Predominantly quartz grains with some trace dark colored lithics; trace bright yellow to light green
Fluorescence; slight petroleum odor; slight oil staining; sheen present on sample; produces a very slow
Trace Siltstone and carbonaceous shale at end of formation increasing in overall composition with
Depth.
LOGGING GEOLOGIST(S):
Nic Moir, Ryan Massey
~ EPOCH a 9
• • •
3.3 Samplin_ Program /Sample Dispatch
COnoCOPhillip5 Tarn 2L 330
Set T pe I Purpose Interval Fre uenc Dis atched to
1 Unwashed (WET) Bayview Lab
No wet samples collected ConocoPhillips Alaska, Inc.
619 Ship Creek Ave., Ste. 100
Anchorage, AK 99501
Attn: D. Przywojski
(907)-263-4859
Bayview Lab
1 Washed, screened & dried 80' - 10400' S0' ConocoPhillips Alaska, Inc.
Dry Samples 619 Ship Creek Ave., Ste. 100
10400' -11130' 10' Anchorage, AK 99501
Box Set A Attn: D. Przywojski
11130' - 11201' 30' (907)-263-4859
1 Washed, screened & dried 80' - 10400' S0' Bayview Lab
Dry Samples ConocoPhillips Alaska, Inc.
10400' - 11130' 10' 619 Ship Creek Ave., Ste. 100
Box Set B Anchorage, AK 99501
11130' - 11201' 30' Attn: D. Przywojski
(907)-263-4859
1 Gas Bags ISOTECH LABORATORIES
Box "1" 3675' - 6600' 300' or gas 1308 Parkland Court
Box "2" 6900' - 10330' kicks Champaign, IL. 61821
1 217-398-3490/FAX 217-398-3493
IsoTubes 10410' - 11201' 30' or gas kicks mail@isotechlabs.com
One box of 25 + 5
Sample frequency was locally altered according to drill rate constraints.
~ EPOCH 3 0
•
f.
•
ConocoPhillips Tarn 2L 330
3.4 Cali Bond Gas Baq Sample and IsoTube Inventory
Gas Ba # De th Gas Units IsoTube # De th Gas Units
1 3675' 120 1 10410 15
2 3675' 70 2 10440 15
3 3700' 28 3 10470 30
4 3900' 27 4 10500 9
5 4200' 19 5 10520 120
6 4500' 35 6 10530 211
7 4800' 30 7 10560 113
8 5100' 31 8 10590 47
9 2400' 30 9 10620 82
10 5700' 29 10 10632 1341
11 6000' 25 11 10650 97
12 6300' 22 12 10680 64
13 6600' 28 13 10710 56
14 6900' 42 14 10740 71
15 7200' 27 15 10770 59
16 7500' 25 16 10800 45
17 7800' 15 17 10830 39
18 8100' 52 18 10860 42
19 8400' 57 19 10890 36
20 8700' 35 20 10920 31
21 9000' 43 21 10950 37
22 9300' 33 22 10980 81
23 9600' 33 23 11010 73
24 9900' 29 24 11040 50
25 10200' 43 25 11070 38
26 10330 140 26 11100 48
27 11130 56
28 11160 49
29 11190 70
30 11200 30
~~ EPOCH
31
• ConocoPhillips Tarn 2L 330
4. PRESSURE /FORMATION STRENGTH DATA
4.1 Formation Integrity/Leak Off Tests
All formation integrity/leak off test data was provided by the well site geologist.
MDRT
ft TVDSS
ft LOT /FIT
EMW FORMATION
3318 -2252 16 CSG SHOE
3675 unknown 12.9 Campanian Sand
3715 -2406 13.0 Campanian Sand
3811 -2442 13.1 Campanian Sand
3907 -2478 12.7 Campanian Sand
4000 -2512 15.7 Campanian Sand
4095 -2547 15.8 Campanian Sand
4190 -2582 15.8 Campanian Sand
4285 -2616 15.8 Campanian Sand
4380 -2651 Test Failed Campanian Sand
2L-330 Casing "Smear" Test
• 16.5
15.5
W 14.5
F
O
J
13.5
12.5
I Smear Test LOT #4, 15 7~
'~~Smear Test LOT #5, 15.81
1 Smear Test LOT #3, 12.7
(Camp Sand LOT, 12.9
Smear Test LOT #2, 13.1
11.5 7 r
3100 3300 3500 3700 3900 4100
Depth ~n~
easing LOT ^ Camp Sand LOT ~-Smear Test LOT
4.2 Pore Pressure Evaluation Introduction
•
Smear Test LOT #\1, 13.0
4300 4500
~~ EPOCH 3 2
•
Trend Indicators
ConocoPhillips Tarn 2L 330
The following pore pressure parameters are considered to provide reliable indicators for
pore pressure trends during the drilling of this well;
Background Gas (BG)
Corrected D exponent (DXC) 1
Wireline Density (WDEN)
Pressure Tests (RFT)
Connection Gas (CG)
Mud Weight (MW)
Resistivity (RES)
Trip Gas (TG)
Hole Conditions (HC)
Sonic (SON)
E~ EPOCH
33
• • •
ConocoPhillips Tarn 2L 330
4.3 Pore Pressure Summa
Equivalent mud weight (EMW) is calculated from rotary table (RT).
Formation Primary Interval To s Pore Pressure EMW Trend Indicators Source of Quantitative
Interval Lithology Estimate
MDRT TVDSS Min Max Trend
ft ft
COMMENCE DRILLING 8.6 9.5 UP-DN BG Gas H drates below Perm
C80 CLST 3465 -2309 8.8 8.8 EVEN BG/WGITG Minor tri ases
Slight Flow in Campanian
C50 CLST/BETSY 6968 -3684 8.8 9.5 UP-DN BG/CG/TG/HC SS
Gas increases from back-
C40 SLTSTlCLAY 7g51 -4057 9.2 9.2 EVEN BG/CGJWG reaming before
connection
C37 SLTST/CLAY 8412 -4236 9.2 8.8 DECR BG Gas decreasin , no CG
T7 SLTST/CLAY 9721 -4750 8.8 9.0 INCR BG Gas increasin , no CG
SLTST/CLAY/
T4 ICEBERG SD 10344 -5117 8.8 9.5 INCR BG/CG Hi h CG
T3 TOP RESEVOIR SS 10480 -5214 7 g.3 DN-UP gG/CG Mud losses 10,508'
SS/SLTST/
T2 BASE CLAY/SH 10670 -5355 9.3 9.5 INCR BG/CG Hi hest CG
SLTST/CLAY/
C35 SS 10728 -5401 9.5 9.5 EVEN BG/CG No noteworth than es
TD SLST/SH/SS 11201 -5789
R Refer to Section 4.3 for explanation of abbreviations used.
~~ EPOCH
34
•
COnoCOPhillip5 Tarn 2L 330
5. DRILLING DATA
5.1 Daily Activity Summary
11 /6/2007
Continue drilling to 3335' MD/2404' TVD, pumped weighted sweep and two times bottoms
up, pull out of hole wiper trip to surface. Clean BHA and run in hole to 1439', unable to
pass through with drilling assembly. Pull up to 1424' waited on orders. Max gas was 3163
units.
11 /7/2007
Drill out from 1425' to 1600', re-entered original hold. Continue trip into 1864', pull out of
hole to 1390' and work tight spot. Trip in hole to 3335; circulate bottoms up and sweep
hole. Pull out of hole to 824', run in hold and tag up at 1425'(tight spot). Wash through
and run in hole to 3335' and ream as required. Pull out of hole to 184'. Max gas was 3700
units.
11 /8/2007
Continued to pull out of hole and laid down BHA. Rig up and run 9.625" casing down to
bottom. Circulated and conditioned mud for cement run. Max gas was 1380 units.
11 /9/2007
Continued to circulate for cement job, land casing and cement as per program. Pumped
3160 strokes to bump plug with rig pump. Rig down cement and casing equipment, nipple
down diverter, and nipple up well head/BOP test. Max gas was 200 units.
•
11 /10/2007
Continue test BOP, rig up and run in hole with singles and rack back in derrick. Make up
and run in the hole with BHA number 2/ 8.75" drilling assembly. Testing casing at report
time. Max gas 0 units.
11 /11 /2007
Drill to 3365' and displace mud to 9.6 ppg LSND and FIT to 16.0 ppg EMW. Drill ahead to
3675' MD/2538' TVD, pumped sweep, pulled up to 3271' and performed FIT. Pull out of
hole to surface, pickup 7" casing to run in hole, continue drilling as per program. Max gas
303 units.
11 /12/2007
Rig up casing tools, pick up 7" casing drill assembly. Run in the hole to 3765' and pick up
3237' perform leak off test #3. Continue drilling ahead as per program for Smear Test,
4376'MD. Max gas was 280 units.
E~ EPOCH 3 5
ConocoPhillips Tarn 2L 330
11 /13/2007
Pull out of hole and lay down 7" casing. Make up BHA #4. Run in hole and pull up drill pipe.
Run in hole to 4380' and mad to 3871' at report time. Max gas was 66 units.
11 /14/2007
Completed MAD pass and drilled ahead to present depth, 6343' MD. Pumped sweep at
5442', 6118', and 6345', by pass out to rock washer. Max gas was 47 units.
11 /15/2007
Continue drilling ahead at report time. Max gas was 109 units.
11 /16/2007
Drilled ahead to 10,330' MD / 5251' TVD, circulating for short trip at time of report. Max gas
was 138 units.
11 /17/2007
Pulled out of hole to the shoe, cut and slipped the drill line. Service the tip drive. Run in the
hole to TD, sweep hole with hi-viscosity / hi-weight with nut plug marker to gauge hole.
Circulated four bottoms up and pumped dry job. Pulling out of hole at report time for
casing. Max gas was 138 units.
11 /18/2007
Finished pulling out of the hole laying down 5"drill pipe. Begin rig up to run 7" casing string.
Max gas was 0 units.
11 /19/2007
Run 7" casing. Max gas was 132 units.
11 /20/2007
Pump cement into place at 02:30 hours. Flush and freeze protect 9 5/8 X 7" annulus. Put
270 barrels of 10.5 mud into 3-4. Pumps were not turned on today. Max gas 0 units.
11 /21 /2007
Trip in the hole with BHA #5. Bit run #3. Max gas 0 units.
11 /22/2007
Finished tripping into hole. Drilled out float and shoe track. Drilling and sliding at report
time. Max gas was 1931 units after a connection.
11 /23/2007
Drilled ahead to 10752'. At 0630 hr Phase 3 called and rig then began circulating and
waiting on weather to improve. Brought mud weight up to 10.8 and commenced drilling
around midnight. Max gas was 3404 units.
~~ EPOCH 3 6
ConocoPhillips Tarn 2L 330
11 /24/2007
Drilled to total depth of 11201'MD/5935'TVD. Performed short trip and ran geo logs.
Pumped weighted sweep (12.8 mud weight) to clean hole. Cleaned hole and began to trip
out of hole to run production string. Max gas was 3043 units.
11 /25/2007
Pulled out of the hole and monitored hole conditions. The hole was boiling and mud was
weighted up to 11.2. TOOH for logs. When the logs are complete, trip in the hole for clean
up run. Then spot 1000' pill for production tubing. Max gas was 2074 units.
11 /26/2007
Schlumberger logging well. Trip in hole and condition. Max gas was 1384 units.
11 /27/2007
Trip out of hole and lay down all logging tools
weight. Max gas was 3188 units.
Circulated before tripping out with 11.2 mud
11 /28/2007
Circulated DYNA RED MED, nut plug, G-Seal due to formation swelling. Pumped 100
barrels with 20 pounds of LCM and chased with 30 barrels of 11.2 mud. Pumped out of
open, pumped dry job and began to trip out of hole. Gas trap was assembled with rubber
hose that is suspected to have given incorrect gas readings, the hose was removed and
gas readings returned to a normal range. Max gas was 3226 units.
11 /29/2007
Lay down BHA and pulled wear bushing. Made up liner packer, SBE and Hanger, and run
in with Packer. SBE assembly on 4" drill pipe and circulated liner volume of PP 360 @ 85
spm. Continued to run in hole with Packer. When pumps turned on, gas commonly spiked
to over 4000 units and would slowly fall down. Max gas was 4819 units.
11 /30/2007
Finished running in hole with liner then cemented liner. Bumped plugs and set hanger.
Released set tool and set liner top packer. Circulated for approximately 5 hours. Epoch
released and began rig down. Max gas 4915 units.
•
E~ EPOCH 37
• • •
5.2 Bit Record
ConocoPhillips Tarn 2L 330
Bit /
Run Make Type Jets /Size Depth
In
ft Total
Footage Bit
Hrs Av.
ROP
(ft/h r WOB
(klbs) RPM PP
(psi) Wear BHA
12.25" HOLE
1 Hughes MXL-1 1x13, 3x15 1' 3335' 23.16 160 20 44 NA 1
8.75" HOLE
2 PDC 5x14 3318' 88' 0.22 160 6 68 NA 2
3 Hycalog DTX619M-
D2 3x16 3406' 6901' 50.11 150 17 84 NA 3 + 4
6.125" HOLE
4 Hycalog DS69FNPV 5x10 10307' 894' 19.84 55 28 60 NA 5
~ EPOCH 3 8
~ • •
5.3 Survey Record
ConocoPhillips Tarn 2L 330
Measured
De th Inclination Azimuth TVD Coordinates Dog Leg
Feet Degrees Degrees Depth N / S E / W Degrees/
100 ft
30.34 0.00 0.00 30.34 0.00 0.00 TIE-IN
76.00 0.07 283.44 76.00 0.01 0.03 0.15
172.00 0.27 134.68 172.00 0.14 0.08 0.35
263.00 1.16 161.74 262.99 1.16 0.52 1.02
318.00 2.74 153.12 317.96 2.87 1.29 2.91
408.89 3.57 147.34 408.71 7.19 3.80 0.98
497.85 5.15 149.68 497.41 12.96 7.31 1.79
590.40 7.54 156.02 589.39 22.10 11.87 2.69
682.70 10.09 150.90 680.59 34.70 18.27 2.89
771.63 13.06 154.21 767.70 50.56 26.43 3.42
867.64 17.16 159.04 860.38 73.56 36.22 4.46
963.02 21.02 156.10 950.50 102.35 48.19 4.17
1057.44 23.80 153.31 1037.78 134.86 63.61 3.15
1152.11 25.47 147.87 1123.84 169.17 83.02 2.97
1247.12 26.73 142.59 1209.17 203.45 106.87 2.78
1338.53 30.54 140.63 1289.39 237.75 134.10 4.29
1435.09 31.84 140.25 1371.99 276.30 165.95 1.36
1529.03 34.60 140.71 1450.57 316.00 198.69 2.95
1622.75 37.50 140.21 1526.34 358.52 233.80 3.11
1719.23 41.93 139.33 1600.53 405.56 273.63 4.63
1814.84 45.18 137.66 1669.82 454.87 317.30 3.61
1908.20 47.01 138.61 1734.56 504.97 362.18 2.09
2001.40 50.06 137.52 1796.26 556.90 408.86 3.39
2097.94 53.10 136.60 1856.25 612.26 460.38 3.24
2190.62 54.85 135.75 1910.76 666.33 512.29 2.03
2286.18 57.36 136.33 1964.04 723.42 567.34 2.67
2378.88 58.42 138.41 2013.32 781.19 620.51 2.22
~~ EPOCH 3 9
~ • •
ConocoPhillips Tarn 2L 330
Measured
De th Inclination Azimuth TVD Coordinates Dog Leg
Feet Degrees Degrees Depth N / S E / W Degrees/
100 ft
2471.20 60.08 138.72 2060.52 840.68 673.01 1.82
2566.90 63.06 137.89 2106.08 903.50 728.99 3.21
2661.15 65.36 140.55 2147.09 967.76 784.39 3.52
2756.46 67.83 140.77 2184.95 1035.41 839.83 2.60
2849.88 68.77 140.74 2219.49 1102.63 894.75 1.01
2947.12 67.22 139.64 2255.92 1171.88 952.46 1.91
3042.71 67.61 139.80 2292.63 1239.21 1009.52 0.44
3137.91 68.65 138.56 2328.10 1306.07 1067.28 1.63
3232.92 66.45 139.18 2364.38 1372.20 1125.03 2.39
3284.24 67.07 138.71 2384.63 1407.76 1156.00 1.47
3327.28 66.79 139.04 2401.49 1437.59 1182.05 0.96
3420.01 67.01 138.68 2437.87 1501.82 1238.16 0.43
3514.48 66.93 138.20 2474.83 1566.88 1295.84 0.48
3609.44 66.95 138.38 2512.03 1632.10 1353.97 0.18
3635.25 66.82 138.27 2522.16 1649.84 1369.76 0.64
3705.06 67.96 137.22 2549.00 1697.53 1413.09 2.14
3799.31 67.87 138.91 2584.44 1762.50 1471.45 1.66
3893.73 68.40 139.61 2619.60 1828.89 1528.64 0.89
3988.83 68.45 139.96 2654.57 1896.42 1585.74 0.35
4082.65 68.62 140.70 2688.90 1963.63 1641.48 0.76
4175.47 68.61 140.05 2722.75 2030.20 1696.60 0.65
4270.09 68.68 140.16 2757.20 2097.81 1753.12 0.13
4365.04 68.48 140.47 2791.88 2165.83 1809.56 0.37
4459.99 68.49 140.27 2826.70 2233.87 1865.91 0.20
4554.29 68.71 139.84 2861.11 2301.18 1922.28 0.48
4648.25 68.94 140.37 2895.05 2368.40 1978.47 0.58
4742.26 66.76 140.22 2930.49 2435.38 2034.09 2.32
4834.64 66.80 140.21 2966.91 2500.62 2088.42 0.04
4930.69 66.98 136.23 3004.63 2566.48 2147.26 3.82
5024.64 66.94 136.56 3041.40 2629.09 2206.89 0.33
5121.94 66.95 135.98 3079.50 2693.78 2268.78 0.55
5214.40 67.00 135.81 3115.67 2754.88 2328.00 0.18
~~ EPOCH 4 0
• • ~
Conoc Phillips Tarn 2L 330
Measured
De th Inclination Azimuth TVD Coordinates Dog Leg
Feet Degrees Degrees Depth N / S E / W Degrees/
100 ft
5309.00 67.25 135.65 3152.44 2817.29 2388.84 0.31
5403.07 65.73 137.35 3189.96 2879.86 2448.22 2.31
5496.11 65.70 137.24 3228.23 2942.18 2505.74 0.11
5590.71 65.48 139.79 3267.33 3006.70 2562.80 2.47
5685.98 65.54 138.38 3306.82 3072.22 2619.58 1.35
5782.05 65.53 138.51 3349.61 3137.65 2677.58 0.12
5874.03 65.35 138.28 3384.84 3200.21 2733.13 0.30
5969.16 65.42 139.19 3424.47 3265.22 2790.17 0.87
6063.54 65.66 138.41 3463.54 3329.85 2846.76 0.79
6159.91 65.83 137.90 3503.13 3395.31 2905.37 0.51
6254.48 66.40 139.83 3541.43 3460.43 2962.25 1.96
6352.79 66.59 139.83 3580.64 3529.32 3020.41 0.19
6445.80 66.60 139.47 3617.58 3594.37 3075.67 0.36
6541.55 65.81 140.67 3656.22 3661.55 3131.90 1.41
6636.33 65.37 140.86 3695.38 3728.40 3186.49 0.50
6730.26 64.94 140.61 3734.85 3794.39 3240.44 0.52
6825.25 66.45 141.37 3773.95 3861.66 3294.93 1.75
6921.45 66.46 141.34 3812.38 3930.54 3350.00 0.03
7016.17 68.45 139.87 3848.69 3998.13 3405.52 2.54
7110.79 68.01 140.02 3883.78 4065.39 3462.07 0.49
7205.87 67.91 139.99 3919.46 4132.91 3518.72 0.11
7296.88 67.93 139.71 3953.67 4197.37 3573.09 0.29
7391.57 67.76 140.80 3989.38 4264.80 3629.17 1.08
7489.02 67.53 140.48 4026.45 4334.49 3686.32 0.38
7579.69 67.42 140.82 4061.18 4399.25 3739.43 0.37
7674.52 67.78 138.89 4097.32 4466.27 3795.95 1.92
7769.03 67.75 139.27 4133.09 4532.37 3853.25 0.37
7866.22 67.35 139.37 4170.20 4600.49 3911.80 0.42
7960.95 67.10 139.46 4206.87 4666.82 3968.63 0.28
8055.53 67.40 138.54 4243.45 4732.65 4025.85 0.95
8152.66 67.49 138.36 4280.70 4799.78 4085.34 0.19
8245.76 67.12 137.36 4316.63 4863.47 4142.97 1.07
€~ EPOCH 41
• • •
ConocoPhillips Tarn 2L 330
Measured
De th Inclination Azimuth TVD Coordinates Dog Leg
Feet Degrees Degrees Depth N / S E / W Degrees/
100 ft
8340.08 66.74 137.08 4353.58 4927.16 4201.91 0.49
8435.02 67.24 137.81 4390.70 4991.53 4261.01 0.88
8529.79 66.92 136.87 4427.60 5055.72 4320.15 0.97
8624.43 66.93 137.67 4464.70 5119.68 4379.23 0.78
8719.33 66.98 137.39 4501.85 5184.09 4438.20 0.28
8881.64 66.84 136.18 4538.05 5245.97 4496.34 1.22
8909.47 66.69 138.40 4576.65 5312.02 4557.31 2.09
9003.86 66.61 138.36 4614.06 5376.81 4614.87 0.09
9097.60 67.64 140.43 4650.50 5442.38 4671.07 2.31
9191.99 67.53 140.27 4686.49 5509.56 4726.75 0.20
9285.10 67.20 140.67 4722.33 5575.85 4781.45 0.53
9377.88 67.02 140.99 4758.42 5642.11 4835.44 0.37
9472.46 66.78 140.52 4795.52 5709.49 4890.47 0.52
9566.93 66.83 139.99 4832.73 5776.25 4945.99 0.52
9661.86 66.47 139.59 4870.36 5842.81 5002.26 0.54
9757.38 62.84 140.06 4911.24 5908.76 5057.94 3.83
9850.79 61.11 139.60 4955.13 5971.76 5111.13 1.90
9945.54 57.06 138.70 5003.80 6033.25 5164.27 4.35
10042.61 51.02 142.13 5060.78 6093.70 5214.38 6.85
10135.90 49.61 142.71 5120.35 6150.59 5258.16 1.59
10231.36 47.25 143.44 5183.69 6207.68 5301.07 2.54
10290.11 45.49 143.65 5224.57 6241.89 8167.91 3.01
10334.64 44.15 144.33 5256.15 6267.28 5344.43 3.20
10428.43 44.37 143.46 5323.32 6320.16 5383.01 0.69
10523.49 44.27 143.58 5391.33 6373.56 5422.49 0.14
10617.83 39.86 145.20 5461.70 6424.62 5459.10 4.65
10712.50 38.35 145.24 5535.16 6473.67 5493.16 1.60
10806.81 36.83 146.20 5609.89 6521.20 5525.57 1.73
10901.95 35.64 146.13 5686.63 6567.91 5556.88 1.25
10997.26 35.42 146.50 5764.19 6614.00 5587.60 0.32
11092.19 32.64 145.64 5842.86 6658.08 5617.24 2.97
11161.92 32.25 146.24 5901.70 6689.07 5638.19 0.73
11201.00 32.35 146.24 5934.75 6706.41 5649.78 0.00
~~ EPOCH 4 2
•
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ConocoPhillips Tarn 2L 330
5.4 Mud Record
Contractor: M-I Drilling Fluids
Mud Type: SPUD MUD to 3,335' Mud Type: LSND to 10,330'
Date Depth MW Vis PV YP Gels API FL Solids Oil/Water Sand PH CI Ca
11/4/2007 733' 9.8 220 28 58 31/52/54 9.5 8.5 TR/92 TR 9.1 150 TR
11 /5/2007 2456' 10.3 110 27 50 24/76/80 5.7 12 1 /88 0.5 9.5 200 60
11 /6/2007 3335' 10.4 130 30 49 20/62/88 5.8 12 1 /88 1 9.2 200 40
11 /7/2007 3335' 10.5 240 26 68 30/72/82 5.5 13 1 /87 0.5 9.6 200 60
11/8/2007 3335' 10.6 55 22 19 5/11/14 6 13 /87 0.5 9.0 200 40
11/9/2007 3335' 10.5 55 22 18 5/8/10 6 12 /88 TR 9.5 200 40
11/10/2007 3335' 10.5 55 23 16 6/8/10 6 12 /88 TR 9.5 200 40
11/11/2007 3675' 9.6 40 8 19 5/7/8 6 7 0/93 TR 9.5 200 60
11/12/2007 4286' 9.7 44 10 20 7/10/11 5.5 9 0/91 TR 9.5 200 20
11/13/2007 4380' 9.7 43 10 21 7/10/11 5.4 7 0/93 TR 9.5 200 40
11/14/2007 6391' 9.6 42 11 20 7/11/14 5 8 TR/92 0.5 9.5 200 20
11/15/2007 8406' 9.6 44 12 22 8/10/11 5 6 3/92 0.25 9.7 200 40
11/16/2007 10330' 9.6 42 9 20 8/11/12 5 8 3/89 TR 9.6 200 40
11/17/2007 10330' 9.7 43 10 18 7/8/10 4.4 8 3/89 TR 10.1 200 40
11/18/2007 10330' 9.7 44 9 18 7/11/14 4 8 3/89 TR 10.0 200 40
11/19/2007 10330' 9.7 43 8 17 7/12/13 4.2 8.7 3/89 TR 9.3 200 40
11/20/2007 10330' 9.7 43 7 18 8/11/13 4.2 8 2/90 TR 10.1 200 40
11/21/2007 10330' 9.8 43 9 16 7/10/13 4.6 8 2/90 TR 9.9 200 40
11/22/2007 10580' 10.5 53 14 21 9/12/14 4.9 8.5 2/90 TR 10.0 200 40
11/23/2007 10572' 10.7 47 16 27 12/14/14 4.4 10 4/89 TR 9.6 300 60
11/24/2007 11201' 11.1 46 19 26 10/13/14 3.1 11.1 3/85.9 TR 9.5 300 60
11/25/2007 11201' 11.2 51 15 26 10/12/15 4 12 3/85 TR 9.4 300 60
11/26/2007 11201' 11.2 53 15 26 11/12/12 3.9 10 3/87 TR 9.3 350 80
11/27/2007 11201' 11.2 53 13 27 9/11/11 3.8 12 3/86 TR 9.5 300 80
11/28/2007 11201' 11.2 52 14 26 9/10/12 3 11.5 3/86 TR 9.7 320 80
11/29/2007 11201' 11.2 59 16 30 11/13/13 2.4 10 2/88 TR 9.6 330 80
E~ EPOCH 4 3
Daily Report
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Page 1 of 1
Conoco Phillips
Tarn DAILY WELLSITE REPORT EPOCH
2L-319
REPORT FOR Morris
DATE Nov 05, 2007 DEPTH 2362 PRESENT OPERATION Drilling Ahead
TIME 23:51:43 YESTERDAY 80
24 HOUR FOOTAGE 2282
CASING INFORMATION
DEPTH INCLINATION AZIMUTH VERTICAL DEPTH
2190 54.85 135.75 1910.76
SURVEY DATA 2097 53.10 136.60 1856.25
2001 50.06 137.52 1796.26
1908 47.01 138.61 1734.56
1814 45.18 137.66 1669.82
BIT INFORMATION INTERVAL CONDITION REASON
NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED
1 12.25 Hughs MXL-1 5130687 0 2362 14.5
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION 0.0 @ 2362.00000 0 @ 2362.00000 0.0 137.89406 FT/HR
SURFACE TORQUE 0 @ 2362.00000 0 @ 2362.00000 0.0 5.62334 AMPS
WEIGHT ON BIT 0 @ 2362.00000 0 @ 2362.00000 0.0 14.26245 KLBS
ROTARY RPM 0 @ 2362.00000 0 @ 2362.00000 0.0 80.00000 RPM
PUMP PRESSURE 0 @ 2362.00000 0 @ 2362.00000 0.0 35.00000 PSI
DRILLING MUD REPORT DEPTH 733
MW 9.8 VIS 220 PV 28 YP 58 FL 9.5 Gels 31/52/54 CL- 150
FC 1/ SOL 8.5 SD tr OIL tr/92 MBL 22.5 pH 9.1 Ca+ tr CCI
MWD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY (units) HIGH LOW AVERAGE
DITCH GAS 0 @ 2362.00000 0 @ 2362.00000 0.0 TRIP GAS
GUTTING GAS 0 @ 2362.00000 0 @ 2362.00000 0.0 WIPER GAS
CHROMATOGRAPHY(ppm) SURVEY
METHANE (C-1) 0 @ 2362.00000 0 @ 2362.00000 0.0 CONNECTION GAS HIGH 2480
ETHANE (C-2) 0 @ 2362.00000 0 @ 2362.00000 0.0 AVG 1800
PROPANE (C-3) 0 @ 2362.00000 0 @ 2362.00000 0.0 CURRENT 319
BUTANE (C-4) 0 @ 2362.00000 0 @ 2362.00000 0.0 CURRENT BACKGROUND/AVG 300
PENTANE (C-5) 0 @ 2362.00000 0 @ 2362.00000 0.0
HYDROCARBON SHOWS
INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION
LITHOLOGY 45% Sand, 45% Clay/Claystone, 10% Conglomeratic Sand and trace Carbonaceous Shale
PRESENT LITHOLOGY 80% Sand, 10% Clay/Claystone and 10% Carbonaceous Shale.
DAILY ACTIVITY Make up BHA, clean out conductor and drill ahead to 216' MD, POOH to finish BHA. Run in hole
shallow
SUMMARY test MWD, drill ahead to 2362' ,
EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335
REPORT BY Nic Moir
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CONOCO PHILLIPS
TARN DAILY WELLSITE REPORT EPQrCH
2L-330
REPORT FOR BREEDEN/VAAGEN
DATE Nov 06, 2007 DEPTH 3332.00000 PRESENT OPERATION CIRCULATING FOR CASING
TIME 12:25:18 YESTERDAY 2427.00000
24 HOUR FOOTAGE 905
CASING INFORMATION
DEPTH INCLINATION AZIMUTH VERTICAL DEPTH
1908.20' 47.01 138:61 1734.56'
SURVEY DATA 2001.40' 50.06 137.52 1796.26'
2097.94' 53.10 136.60 1856.25'
2190.62' 54.85 135.75 1910.76'
2286.18' 57:36 136.33 1964.04'
BIT INFORMATION INTERVAL CONDITION REASON
NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED
1 12.25 Hughs MXL-1 5130687 3332' 14.5
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION 264.3 @ 2651.00000 7.8 @ 2848.00000 118.7 116.13278 FT/HR
SURFACE TORQUE 6 @ 3176.00000 0 @ 2537.00000 4.4 5.99455 AMPS
WEIGHT ON BIT 29 @ 3204.00000 -2 @ 3281.00000 17.3 18.41153 KLBS
ROTARY RPM 83 @ 2461.00000 1 @ 2902.00000 63.6 79.00000 RPM
PUMP PRESSURE 35 @ 2427.00000 35 @ 3332.00000 34.9 35.00000 PSI
DRILLING MUD REPORT DEPTH 3335'
MW 10.4 VIS 130 PV 30 YP 49 FL 5.8 Gels 20/62/88 CL- 200
FC 2/N/A SOL 12 SD 1 OIL 1 MBL 25 pH 9.2 Ca+ 40 CCI
MWD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY (units) HIGH LOW AVERAGE
DITCH GAS 3156 @ 3075.00000 2 @ 2991.00000 941.8 TRIP GAS 3163
CUTTING GAS 0 @ 3332.00000 0 @ 3332.00000 0.0 WIPER GAS 3163
CHROMATOGRAPHY(ppm) SURVEY
METHANE (C-1) 571951 @ 3075.00000 21 @ 2991.00000 45565.0 CONNECTION GAS HIGH 3000
ETHANE (C-2) 0 @ 3332.00000 0 @ 3332.00000 0.0 AVG
PROPANE (C-3) 0 @ 3332.00000 0 @ 3332.00000 0.0 CURRENT 376
BUTANE (C-4) 0 @ 3332.00000 0 @ 3332.00000 0.0 CURRENT BACKGROUND/AVG 376
PENTANE (C-5) 0 @ 3332.00000 0 @ 3332.00000 OA
HYDROCARBON SHOWS
INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION
LITHOLOGY CLAYSTONE, SILTSTONE, SAND, CONGLOMERATE SAND.
PRESENT LITHOLOGY 50% CLAY STONE, 30% SILTSTONE, 10% SAND, 10% CONGLOMERATE SAND.
DAILY CONTINUE DRILLING TO 3335' MD/ 2404 TVD, PUMPED WEIGHTED SWEEP AND 2X BOTTOMS UP
PULL
ACTIVITY OUT OF HOLE W ,
IPER TRIP TO SURFACE. CLEAN BHA AND RUN IN HOLE TO 1439', UNABLE TO PASS
SUMMARY THROUGH WITH DRILLING ASSEMBLY. PULL UP TO 1424' WAIT ON ORDERS, AT REPORT TIME. MAX GAS
3163u
• EPOCH PERSONNEL ON BOARD 4 DAILY COST 3335
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Daily Report
REPORT BY RYAN MASSEY
Page 2 of Z
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CONOCO PHILLIPS
TARN DAILY WELLSITE REPORT EPOCH
2L-330
REPORT FOR BREEDEN/VAAGEN
DATE Nov 07, 2007 DEPTH 3332.00000 PRESENT OPERATION PULL OUT OF HOLE FOR CASING
TIME 12:25:18 YESTERDAY 3332.0000
24 HOUR FOOTAGE 0
CASING INFORMATION
SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH
BIT INFORMATION INTERVAL CONDITION REASON
NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED
1 12.25 HUGHES MXL-1 5130687 3332'
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION 264.3 @ 2651.00000 7.8 @ 2848.00000 118.7 116.13278 FT/HR
SURFACE TORQUE 6 @ 3176.00000 0 @ 2537.00000 4.4 5.99455 AMPS
WEIGHT ON BIT 29 @ 3204.00000 -2 @ 3281.00000 17.3 18.41153 KLBS
ROTARY RPM 83 @ 2461.00000 1 @ 2902.00000 63.6 79.00000 RPM
PUMP PRESSURE 35 @ 2427.00000 35 @ 3332.00000 34.9 35.00000- PSI
DRILLING MUD REPORT DEPTH 3335'
MW 10.5 VIS 240 PV 26 YP 68 FL 5.5 Gels 30/72/82 CL- 200
FC 2/N/A SOL 13 SD 0.5 OIL 1 MBL 25 pH 9.6 Ca+ 60 CCI
MWD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY (units) HIGH LOW AVERAGE
DITCH GAS 3156 @ 3075.00000 2 @ 2991.00000 941.8 TRIP GAS 3700u
CUTTING GAS 0 @ 3332.00000 0 @ 3332.00000 0.0 WIPER GAS 3500u
CHROMATOGRAPHY(ppm) SURVEY
METHANE (C-1) 571951 @ 3075.00000 21 @ 2991.00000 45565.0 CONNECTION GAS HIGH
ETHANE (C-2) 0 @ 3332.00000 0 @ 3332.00000. 0.0 AVG
PROPANE (C-3) 0 @ 3332.00000 0 @ 3332.00000 0.0 CURRENT Ou
BUTANE (C-4) Ou @ 3332.00000 0 @ 3332.00000 0.0 CURRENT BACKGROUND/AVG Ou
PENTANE (C-5) 0 @ 3332.00000 0 @ 3332.00000 0.0
HYDROCARBON SHOWS
INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION
LITHOLOGY CLAYSTONE, SILTSTONE, SAND, CONGLOMERATE SAND
PRESENT LITHOLOGY 50% CLAYSTONE, 30% SILTSTONE, 10% SAND, 10% CONGLOMERATE SAND
DRILL OUT FROM 1425' TO 1600', RE-ENTERD ORIGINAL HOLD. CONTINUE TRIP INTO 1864', PULL OUT OF
DAILY HOLE TO 1390' WORK TIGHT SPOT. TRIP IN HOLE TO 3335' CIRCULATE BOTTOMS UP AND SWEEP HOLE,
ACTIVITY PULL OUT OF HOLE TO 824', RUN IN HOLE AND TAG UP AT 1425'(TIGHT SPOT). WASH THROUGH, AND RUN
SUMMARY IN HOLE TO 3335' WASH AND REAM AS REQUIRED. PULL OUT OF HOLE TO 184' AT REPORT TIME FOR
CASING. MAX GAS 3700u
EPOCH PERSONNEL ON BOARD 4 DAILY COST 3335
REPORT BY RYAN MASSEY
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Daily Report
Page 1 of 1
CONOCO PHILLIPS
TARN DAILY WELLSITE REPORT EPOCH
2L-330
REPORT FOR BREEDEN/VAAGEN
DATE Nov 08, 2007 DEPTH 3332.00000 PRESENT OPERATION CIRCULATING FOR CEMENT
TIME 12:25:18 YESTERDAY 3332.00000
24 HOUR FOOTAGE 0
CASING INFORMATION
SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH
BIT INFORMATION INTERVAL CONDITION REASON
NO, SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED
1 12.25 HUGHES MXL-1 5130687 3332'
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION 264.3 @ 2651.00000 7.8 @ 2848.00000 118.7 116.13278 FT/HR
SURFACE TORQUE 6 @ 3176.00000 0 @ 2537.00000 4.4 5.99455 AMPS
WEIGHT ON BIT 29 @ 3204.00000 -2 @ 3281.00000 17.3 18.41153 KLBS
ROTARY RPM 83 @ 2461.00000 1 @ 2902.00000 63.6 79.00000 RPM
PUMP PRESSURE 35 @ 2427.00000 35 @ 3332.00000. 34.9 35.00000 PSI
DRILLING MUD REPORT DEPTH 3335'
MW 10.6 VIS 55 PV 22 YP 19 FL 6 Gels 5111/14 CL- 200
FC 1/N/A SOL 13 SD 0.5 OIL 0 MBL 25 pH 9.0 Ca+ 40 CCI
MWD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY (units) HIGH LOW AVERAGE
DITCH GAS 3156 @ 3075.00000 2 @ 2991.00000 941.8 TRIP GAS 1380u
CUTTING GAS 0 @ 3332.00000 0 @ 3332.00000 0.0 WIPER GAS
CHROMATOGRAPHY(ppm) SURVEY
METHANE (C-1) 571951 @ 3075.00000 21 @ 2991.00000 45565.0 CONNECTION GAS HIGH N/A
ETHANE (C-2) 0 @ 3332.00000 0 @ 3332.00000 0.0 AVG
PROPANE (C-3) 0 @ 3332.00000 0 @ 3332.00000 0.0 CURRENT Ou
BUTANE (C-4) 0 @ 3332.00000 0 @ 3332.00000 0.0 CURRENT BACKGROUND/AVG Ou
PENTANE (C-5) 0 @ 3332.00000 0 @ 3332.00000 0.0
HYDROCARBON SHOWS
INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION
LITHOLOGY CLAYSTONE, SILTSTONE, SAND, CONGLOMERATE SAND
PRESENT LITHOLOGY 50% CLAYSTONE, 30% SILTSTONE, 10% SAND, 10% CONGLOMERATE SAND
DAILY ACTIVITY CONTINUE PULL OUT OF HOLE, LAY DOWN BHA. RIG UP AND RUN 9.625" CASING
DOWN TO
,
SUMMARY BOTTOM, CIRCULATE AND CONDITION MUD TO CEMENT AT REPORT. MAX 1380u
EPOCH PERSONNEL ON BOARD 4 DAILY COST 3335
REPORT BY RYAN MASSEY
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CONOCO PHILLIPS
TARN .DAILY WELLSITE REPORT EPOCH
2L-330
REPORT FOR BREEDEN/VAAGEN
DATE Nov 09, 2007 DEPTH 3332.00000 PRESENT OPERATION NIPPLE UP, BOP, AND TEST
TIME 12:25:18 YESTERDAY 3332.00000
24 HOUR FOOTAGE 0
CASING INFORMATION 3335' 9.626 CASING
SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH
BIT INFORMATION INTERVAL CONDITION REASON
NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED
1 12.25 HUGHES MXL-1 5130687 3332'
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION 264.3 @ 2651.00000 7.8 @ 2848.00000 118.7 116.13278 FT/HR
SURFACE TORQUE 6 @ 3176.00000 0 @ 2537.00000 4.4 5.99455 AMPS
WEIGHT ON BIT 29 @ 3204.00000 -2 @ 3281.00000 17.3 18.41153 KLBS
ROTARY RPM 83 @ 2461.00000 1 @ 2902.00000 63.6. 79.00000 RPM
PUMP PRESSURE 35 @ 2427.00000 35 @ 3332.00000 34.9 35.00000 PSI
DRILLING MUD REPORT DEPTH 3335'
MW 10.5 VIS 55 PV 22 YP 18 FL 6 Gels 5/8/10 CL- 200
FC 1!N/A SOL 12 SD TR OIL 0 MBL 25 pH 9.5 Ca+ 40 CCI
MWD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY (units) HIGH LOW AVERAGE
DITCH GAS @ @ TRIP GAS 200u
CUTTING GAS @ @ WIPER GAS N/A
CHROMATOGRAPHY (ppm) SURVEY
METHANE (C-1) 571951 @ 3332.0000 21 @ 2991.00000 45565.0 CONNECTION GAS HIGH N/A
ETHANE (C-2) 0 @ 3332.00 0 @ 3332.00000 0.0 AVG
PROPANE (C-3) 0 @ 3332.00000 0 @ 3332.00000 0.0 CURRENT Ou
BUTANE (C-4) 0 @ 3332.00000 0 @ 3332.00000 0.0 CURRENT BACKGROUND/AVG Ou
PENTANE (C-5) 0 @ 3332.00000 0 @ 3332.00000 0.0
HYDROCARBON SHOWS
INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION
LITHOLOGY CLAYSTONE, SILTSTONE, SAND, AND CONGLOMERATE SAND
PRESENT LITHOLOGY 50% CLAYSTONE, 30% SILTSTONE, 10%SAND, 10% CONGLOMERATE SAND
DAILY ACTIVITY CONTINUE CIRCULATE FOR CEMENT JOB, LAND CASING AND CEMENT AS PER PROGRAM. PUMPED
SUMMARY 3160 STROKES TO BUMP PLUG WITH RIG PUMP. RIG DOWN CEMENT AND CASING EQUIPMENT, NIPPLE
DOWN DIVERTER, NIPPLE UP WELL HEAD/ BOP TEST AT REPORT. MAX GAS 200u
EPOCH PERSONNEL ON BOARD 4 DAILY COST 3335
REPORT BY RYAN MASSEY
C7
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Daily Report
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CONOCO PHILLIPS
TARN DAILY WELLSITE REPORT EPOCH
2L-330
REPORT FOR BREEDEN/VAAGEN
DATE Nov 10, 2007 DEPTH 3332.00000 PRESENT OPERATION TEST CASING
TIME 12:25:18 YESTERDAY 3332.00000
24 HOUR FOOTAGE 0
CASING INFORMATION 3335' 9.626 CASING
SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH
BIT INFORMATION INTERVAL CONDITION REASON
NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/6/C PULLED
2 8.75
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION 264.3 @ 2651.00000 7.8 @ 2848.00000 118.7 116.13278 FT/HR
SURFACE TORQUE 6 @ 3176.00000 0 @ 2537.00000 4.4 5.99455 AMPS
WEIGHT ON BIT 29 @ 3204.00000. -2 @ 3281.00000 17.3 18.41153 KLBS
ROTARY RPM 83 @ 2461.00000 1 @ 2902.00000 63.6 79.00000 RPM
PUMP PRESSURE 35 @ 2427.00000 35 @ 3332.00000 34.9 35.00000 PSI
DRILLING MUD REPORT DEPTH 3335'
MW 10.5 VIS 55 PV 23 YP 16 FL 6 Gels 6/8/10 CL- 200
FC 1/N/A SOL 12 SD TR OIL 0 MBL 25 pH 9.5 Ca+ 40 CCI
MWD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY (units) HIGH LOW AVERAGE
DITCH GAS @ @ TRIP GAS N/A
CUTTING GAS @ @ WIPER GAS N/A
CHROMATOGRAPHY(ppm) SURVEY
METHANE (C-1) 571951 @ 3332.0000 21 @ 2991.00000 45565.0 CONNECTION GAS HIGH N/A
ETHANE (C-2) 0 @ 3332.00 0 @ 3332.00000 0.0 AVG
PROPANE (C-3) 0 @ 3332.00000 0 @ 3332.00000 0.0 CURRENT Ou
BUTANE (C-4) 0 @ 3332.00000 0 @ 3332.00000 0.0 CURRENT BACKGROUND/AVG Ou
PENTANE (C-5) 0 @ 3332.00000 0 @ 3332.00000 0.0
HYDROCARBON SHOWS
INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION
LITHOLOGY CLAYSTONE, SILTSTONE, SAND, AND CONGLOMERATE SAND
PRESENT LITHOLOGY 50% CLAYSTONE, 30% SILTSTONE, 10%SAND, 10% CONGLOMERATE SAND
DAILY ACTIVITY Continue test BOP, rig up and run in hole with singles and rack back in derrick. Make up and run in the hole with
SUMMARY BHA number 2! 8.75" drilling assembly. Testing casing at report time. Max gas 0 units.
EPOCH PERSONNEL ON BOARD 4 DAILY COST 3335
REPORT BY RYAN MASSEY
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Daily Report
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CONOCO PHILLIPS
TARN DAILY WELLSITE REPORT EP~~H
2L-330
REPORT FOR BREDDEN/VAAGEN
DATE Nov 11, 2007 DEPTH 3673.00000 PRESENT OPERATION CASING DRILL 8.75"
TIME 15:39:20 YESTERDAY 3333.00000
24 HOUR FOOTAGE 340
CASING INFORMATION
SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH
BIT INFORMATION INTERVAL CONDITION REASON
NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED
2 8.75
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION 353.6 @ 3373.00000 46.1 @ 3367.00000 172.0 149.09920 FT/HR
SURFACE TORQUE 7 @ 3597.00000 4 @ 3405.00000 5.9 6.18964 AMPS
WEIGHT ON BIT 13 @ 3358.00000 0 @ 3559.00000 5.2 5.44566 KLBS
ROTARY RPM 103 @ 3623.00000 38 @ 3375.00000 87.0 99.00000 RPM
PUMP PRESSURE 35 @ 3336.00000 35 @ 3673.00000. 34.8 35.00000 PSI
DRILLING MUD REPORT DEPTH 3675'
MW 9.6 VIS 40 PV 8 YP 19 FL 6 Gels 5/7/8 CL- 200
FC 1/N/A SOL 7 SD TR OIL 0 MBL 3 pH 9.5 Ca+ 60 CCI
MWD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY (units) HIGH LOW AVERAGE
DITCH GAS 303 @ 3618.00000 14 @ 3346.00000 66.7 TRIP GAS N/A
CUTTING GAS 0 @ 3673.00000 0 @ 3673.00000 0.0 WIPER GAS N/A
CHROMATOGRAPHY (ppm) SURVEY
METHANE (C-1) 56212 @ 3617.00000 312 @ 3346.00000 9575.3 CONNECTION GAS HIGH 303u
ETHANE (C-2) 679 @ 3617.00000 0 @ 3333.00000 69.9 AVG
PROPANE (C-3) 91 @ 3617.00000 0 @ 3585.00000 2.1 CURRENT Ou
BUTANE (C-4) 34 @ 3617.00000 0 @ 3585.00000 0.8 CURRENT BACKGROUND/AVG Ou
PENTANE (C-5) 0 @ 3673.00000 0 @ 3673.00000 0.0
HYDROCARBON SHOWS
INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION
LITHOLOGY CLAYSTONE, SILTSTONE, SAND, AND SANDSTONE
PRESENT LITHOLOGY 10% CLAYSTONE, 10% SILTSTONE, 50% SAND, 30% SANDSTONE
DAILY ACTIVITY Drill to 3365' and displace mud to 9.6 ppg LSND and FIT to 16.0 ppg EMW. Drill ahead to 3675' MD/2538' TVD,
SUMMARY Pumped sweep, pulled up to 3271' and performed FIT. Pull out of hole to surface, pick up 7" casing to run in hole,
continue drilling as per program. Max gas 303 units.
EPOCH PERSONNEL ON BOARD 4 DAILY COST 3335'
REPORT BY RYAN MASSEY
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Daily Report
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CONOCO PHILLIPS
TARN DAILY WELLSITE REPORT ~ ~PQ~H
2L-330
REPORT FOR BREEDENNAAGEN
DATE Nov 12, 2007 DEPTH 4271.00000 PRESENT OPERATION CASING DRILL 9.75"
TIME 00:38:03 YESTERDAY 3674.00000
24 HOUR FOOTAGE 597
CASING INFORMATION 9.625"
SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH
BIT INFORMATION INTERVAL CONDITION REASON
NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED
8.75" HYCALOG DTX619M
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION 171.1 @ 4100.00000 23.6 @ 3676.00000 89.3 55.84166 FTlHR
SURFACE TORQUE 7 @ 4199.00000 4 @ 3745.00000 5.8 6.10295 AMPS
WEIGHT ON BIT. 12 @ 3699.00000 6 @ 3812.00000 10.6 11.66928 KLBS
ROTARY RPM 99 @ 4186.00000 38 @ 3806.00000 66.8 98.00000 RPM
PUMP PRESSURE 35 @ 3674.00000 35 @ 4271.00000 35.1 35.00000 PSI
DRILLING MUD REPORT DEPTH 4286'
MW 9.7 VIS 44 PV 10 YP 20 FL 5.5 Gels 7/10/11 CL- 200
FC 1/N/A SOL 9 SD TR OIL 0 MBL 5 pH 9.5 Ca+ 20 CCI
MWD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY (units) HIGH LOW AVERAGE
DITCH GAS 41 @ 4077.00000 0 @ 3804.00000 22.8 TRIP GAS 280u
CUTTING GAS 0 @ 4271.00000 0 @ 4271.00000 0.0 WIPER GAS N/A
CHROMATOGRAPHY (ppm) SURVEY
METHANE (C-1) 11795 @ 3933.00000 199 @ 3804.00000 5221.6 CONNECTION GAS HIGH 41u
ETHANE (C-2) 99 @ 3933.00000 2 @ 3804.00000 47.3 AVG
PROPANE (C-3) 1 @ 3678.00000 0 @ 3708.00000 0.0 CURRENT 13u
BUTANE (C-4) 0 @ 3678.00000 0 @ 3708.00000 0.0 CURRENT BACKGROUND/AVG 13u
PENTANE (C-5) 0 @ 4271.00000 0 @ 4271.00000 0.0
HYDROCARBON SHOWS
INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION
LITHOLOGY SAND, SANDSTONE, SILTSTONE, CLAYSTONE
PRESENT LITHOLOGY 30% SANDSTONE, 10% SAND, 40% SILTSTONE, 20% CLAYSTONE
DAILY ACTIVITY Rig up casing tools, pickup 7" casing drill assembly. Run in the hole to 3765' and pick up 3237' pertorm leak off
SUMMARY test #3. Continue drilling ahead as per program for Smear Test, 4376'MD. Max gas was 280 units.
EPOCH PERSONNEL ON BOARD 4 DAILY COST 3335
REPORT BY RYAN MASSEY
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CONOCO PHILLIPS
TARN DAILY WELLSITE REPOR T ~PQ~;H
2L-330
REPORT FOR MORRIS/VAAGEN
DATE Nov 13, 2007 DEPTH 4381.00000 PRESENT OPERATION DRILL 8.75"
TIME 02:23:09 YESTERDAY 4271.00000
24 HOUR FOOTAGE 110
CASING INFORMATION 9.625"@3335'
SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH
BIT INFORMATION INTERVAL CONDITION REASON
NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED
8.75" HYCALOG DTX 619M
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION 136.7 @ 4290.00000 40.6 @ 4342.00000 78.9 62.15899 FT/HR
SURFACE TORQUE 7 @ 4315.00000 5 @ 4296.00000 6.6 7.23928 AMPS
WEIGHT ON BIT 12 @ 4274.00000 9 @ 4347.00000 11.0 10.89133 KLBS
ROTARY RPM 101 @ 4338.00000 93 @ 4327.00000 100.0 97.00000 RPM
PUMP PRESSURE 35 @ 4271.00000 35 @ 4378.00000 35.3 35.00000 PSI
DRILLING MUD REPORT DEPTH 4380'
MW 9.7 VIS 43 PV 10 YP 21 FL 5.4 Gels 7/10/11 CL- 200
FC 1/N/A SOL 7 SD TR O-L 0 MBL 12 pH 9.5 Ca+ 40 CCI
MWD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY (units) HIGH LOW AVERAGE
DITCH GAS 18 @ 4329.00000 5 @ 4332.00000 14.4 TRIP GAS 66u
CUTTING GAS 0 @ 4378.00000 0 @ 4378.00000 0.0 WIPER GAS N/A
CHROMATOGRAPHY(ppm) SURVEY
METHANE (C-1) 4273 @ 4329.00000 1157 @ 4332.00000 2970.1 CONNECTION GAS HIGH N/A
ETHANE (C-2) 44 @ 4329.00000 11 @ 4332.00000 30.9 AVG
PROPANE (C-3) 0 @ 4378.00000 0 @ 4378.00000 0.0 CURRENT Ou
BUTANE (C-4) 0 @ 4378.00000. 0 @ 4378.00000 0.0 CURRENT BACKGROUND/AVG Ou
PENTANE (C-5) 0 @ 4378.00000 0 @ 4378.00000 0.0
HYDROCARBON SHOWS
INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION
LITHOLOGY SAND, SANSTONE, SILTSTONE, CLAYSTONE
PRESENT LITHOLOGY 30% SANDSTONE, 10% SAND, 40% SILTSTONE, 20% CLAYSTONE
DAILY ACTIVITY Pull out of hole and lay donw 7" casing. Make up BHA #4. Run in hole and pull up drill pipe. Run in hole to
SUMMARY 4380' and mad to 3871' at report time. Max gas was 66 units.
EPOCH PERSONNEL ON BOARD 4 DAILY COST 3335
REPORT BY RYAN MASSEY
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CONOCO PHILLIPS
TARN DAILY WELLSITE REPORT ~,~QC;~
2L-330
REPORT FOR MORRIS/VAAGE N
DATE Nov 14, 2007 DEPTH 6343.00000 PRESENT OPERATION DRILL 8.75"
TIME 23:59:02 YESTERDAY 4379.00000
24 HOUR FOOTAGE 1964
CASING INFORMATION 9.625" @ 3335'
DEPTH INCLINATION AZIMUTH VERTICAL DEPTH
6063.54' 65.66 138.41 3463.54'
6159.91' 65.83 137.90 3503.13'
SURVEY DATA
6254.48' 66.40 139.83 3541.43'
6352.79' 66.59 139.83 3580.32'
6445.80' 66.60 139.47 3617.58'
BIT INFORMATION INTERVAL CONDITION REASON
NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED
8.75" HYCALOG DTX 619M
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION 1009.0 @ 4968.00000 42.8 @ 4379.00000 171.2 125.28712 FT/HR
SURFACE TORQUE 10 @ 6239.00000 0 @ 4881.00000 7.2 8.85952 AMPS
WEIGHT ON BIT 41 @ 4609.00000 3 @ 5812.00000 15.8 11.09161 KLBS
ROTARY RPM 102 @ 4527.00000 1 @ 5345.00000 87.3 99.00000 RPM
PUMP PRESSURE 35 @ 4379.00000 35 @ 6343.00000 34.9 35.00000 PSI
DRILLING MUD REPORT DEPTH 6391'
MW 9.6 VIS 42 PV 11 YP 20 FL 5 Gels 7/11/14 CL- 200
FC 1/N/A SOL 8 SD 0.5 OIL TR MBL 18 pH 9.5 Ca+ 20 CCI
MWD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY (units) HIGH LOW AVERAGE
DITCH GAS 47 @ 4842.00000 0 @ 5582.00000 25.4 TRIP GAS N/A
CUTTING GAS 0 @ .6343.00000 0 @ 6343.00000 OA WIPER GAS N/A
CHROMATOGRAPHY(ppm) SURVEY
METHANE (C-1) 20504 @ 4417.00000 44 @ 5489.00000 6322.7 CONNECTION GAS HIGH 27u
ETHANE (C-2) 250 @ 5975.00000 0 @ 5582.00000 88.4 AVG
PROPANE (C-3) 133 @ 6069.00000 0 @ 5997.00000 4.0 CURRENT 31u
BUTANE (C-4) 0 @ 6343.00000 0 @ 6343.00000 0.0 CURRENT BACKGROUND/AVG 31u
PENTANE (C-5) 0 @ 6343.00000 0 @ 6343.00000 0.0
HYDROCARBON SHOWS
INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION
LITHOLOGY CLAYSTONE, SILTSTONE, SANDSTONE
PRESENT LITHOLOGY 10% CLAYSTONE, 20% SANDSTONE, 70% SILTSTONE
DAILY ACTIVITY Completed MAD pass adn drilled ahead to present depth, 6343' MD. Pumped sweep at 5442', 6118', and
SUMMARY 6345', by pass out to rock washer. Max gas was 47 units.
EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335
REPORT BY RYAN MASSEY
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CONOCO PHILLIPS
TARN DAILY WELLSITE REPORT E~Q~~
2L-330
REPORT FOR MORRIS/VAAGEN
DATE Nov 15, 2007 DEPTH 8343.00000 PRESENT OPERATION DRILLING
TIME 11:59:13 YESTERDAY 6343.00000
24 HOUR FOOTAGE 2000
CASING INFORMATION 9.625" @ 3335'
DEPTH INCLINATION AZIMUTH .VERTICAL DEPTH
8055.53' 67.40 138.54 4243.45'
8152.66' 67.49 138.36 4280.70'
SURVEY DATA 8245.76' 67.12 137.36 4316.63'
8340.08' 66.74 137.08 4353.58'
8435.02' 67.24 137.81 4390.70'
BIT INFORMATION INTERVAL CONDITION REASON
NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED
8.75" HYCALOG DTX619M
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION 331.9 @ 6486.00000 14.2 @ 7326.00000 152.3 .156.26357 FT/HR
SURFACE TORQUE 12 @ 6496.00000 0 @ 6775.00000 8.6 6.76672 AMPS
WEIGHT ON BIT 73 @ 6795.00000 1 @ 6460.00000 25.1 .16.95959 KLBS
ROTARY RPM 112 @ 6934.00000 6 @ 7615.00000 93.1 101.00000 RPM
PUMP PRESSURE 35 @ 6343.00000 35 @ 8343.00000 35.0 35.00000 PSI
DRILLING MUD REPORT DEPTH 8406'
MW 9.6 VIS 44 PV 12 YP 22 FL 5 Gels 8/10/11 CL- 200
FC 1/NIA SOL 6 SD 0.25 OIL 3 MBL 11 pH 9.7 Ca+ 40 CCI
MWD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY (units) HIGH LOW AVERAGE
DITCH GAS 109 @ 7875.00000 8 @ 7469.00000 35.4 TRIP GAS N/A
CUTTING GAS 0 @ 8343.00000 0 @ 8343.00000 0.0 WIPER GAS N/A
CHROMATOGRAPHY (ppm) SURVEY
METHANE (C-1) 2 2908 @ 7875.00000 91 @ 7800.00000 7469.0. CONNECTION GAS HIGH 61u
ETHANE (C-2) 727 @ 7875.00000 2 @ 7800.00000 201.7 AVG
PROPANE (C-3) 192 @ 8338.00000 0 @ 7793.00000 51.6 CURRENT 45u
BUTANE (C-4) 70 @ 8156.00000 0 @ 7123.00000 6.0 CURRENT BACKGROUND/AVG 45u
PENTANE (C-5) 0 @ 8343.00000 0 @ 8343.00000 0.0
HYDROCARBON SHOWS
INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION
LITHOLOGY RS10CT10SS20ST60 CARBONACEOUS SHALE, CLAY, SANDSTONE, SILTSTONE
PRESENT LITHOLOGY 10% CARBONACEOUS SHALE, 10% CLAY, 20% SANDSTONE, 60% SILTSTONE
DAILY ACTIVITY SUMMARY Continue drilling ahead at report time. Max gas 109 units.
EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335
REPORT BY RYAN MASSEY
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CONOCO PHILLIPS
TARN DAILY WELLSITE REPORT ~,~~CH
2L-330
REPORT FOR MORRIS/VAAGEN
DATE Nov 16, 2007 DEPTH 10328.00000 PRESENT OPERATION CIRCULATING AT TD
TIME 23:59:30 YESTERDAY 8343.00000
24 HOUR FOOTAGE 1985
CASING INFORMATION 9.625" @ 3335'
DEPTH INCLINATION AZIMUTH VERTICAL DEPTH
9850.79' 61.11 139.60 4955.13'
SURVEY DATA 9945.54' 57.06 138.70 5003.80'
10042.62' 51.02 142.13 5060.78'
10135.90' 49.61 142.71 5120.35'
10231.36' 47.25 143.44 5183.69'
BIT INFORMATION INTERVAL CONDITION REASON
NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED
8.75" HYCALOG DTX619M
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION 365.3 @ 8569.00000 31.2 @ 10042.00000 152.1 154.99870 FT/HR
SURFACE TORQUE 11 @ 10128.00000 0 @ 9838.00000 6.2 10.29554 AMPS
WEIGHT ON BIT 45 @ 8599.00000 -6 @ 10214.00000 17.7 8.48505 KLBS
ROTARY RPM 104 @ 8454.00000 1 @ 10179.00000 71.6 94.00000 RPM
PUMP PRESSURE 35 @ 8343.00000 35 @ 10328.00000 34.9 35.00000 PSI
DRILLING MUD REPORT DEPTH 10330'
MW 9.6 VIS 42 PV 9 YP 20 FL 5 Gels 8/11/12 CL- 200
FC 1/N/A SOL 8 SD TR OIL 3 MBL 17 pH 9.6 Ca+ 40 CCI
MWD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY (units) HIGH LOW AVERAGE
DITCH GAS 101 @ 8984.00000 5 @ 9813.00000 36.5 TRIP GAS N/A
CUTTING GAS 0 @ 10328.00000 0 @ 10328.00000 0.0 WIPER GAS N/A
CHROMATOGRAPHY(ppm) SURVEY
METHANE (C-1) 20489. @ 8984.00000 265 @ 9813.00000 6756.5 CONNECTION GAS HIGH 138u
ETHANE (C-2) 1251 @ 8550.00000 40 @ 9813.00000 358.2 AVG
PROPANE (C-3) 610 @ 10313.00000 13 @ 9813.00000 141.6 CURRENT Ou
BUTANE (C-4) 271 @ 8550.00000 0 @ 9323.00000 42.6 CURRENT BACKGROUND/AVG Ou
PENTANE (C-5) 87 @ 10313.00000 0 @ 10272.00000 1.1
HYDROCARBON SHOWS
INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION
LITHOLOGY CARBONACEOUS SHALE, CLAYSTONE, SAND, SANDSTONE, AND SILTSTONE
PRESENT LITHOLOGY 10% CLAYSTONE, 10% CARBONACEOUS SHALE, 10% SAND, 20 % SANDSTONE, 50% SILTSTONE
DAILY ACTIVITY Drilled ahead to 10,330' MD / 5251' TVD, circulating for short trip at time of report. Max gas was 138
SUMMARY units.
EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335
REPORT BY RYAN MASSEY
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CONOCO PHILLIPS
TARN DAILY WELLSITE REPORT EPQCH
2L-330
REPORT FOR MORRISNAAGEN
DATE 11/17/2007 DEPTH 10328.00000 PRESENT OPERATION TRIP OUT FOR CASING
TIME 11:59:21 YESTERDAY 10328.00000
24 HOUR FOOTAGE 0
CASING INFORMATION 9.625" @ 3335'
SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH
BIT INFORMATION INTERVAL CONDITION REASON
NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED
8.75" HYCALOG DTX619M
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION @ @ FT/HR
SURFACE TORQUE @ @ AMPS
WEIGHT ON BIT @ @ KLBS
ROTARY RPM @ @ RPM
PUMP PRESSURE @ @ PSI
DRILLING MUD REPORT DEPTH 10330'
MW 9.7 VIS 43 PV 10 YP 18 FL 4.4 Gels 7/8/10 CL- 200
FC 1/N/A SOL 8 SD TR OIL 3 MBL 19 pH 10.1 Ca+ 40 CCI
MWD SUMMARY
INTERVAL. TO
TOOLS
GAS SUMMARY (units) HIGH LOW AVERAGE
DITCH GAS @ @ TRIP GAS 138u
CUTTING GAS @ @ WIPER GAS
CHROMATOGRAPHY(ppm) SURVEY
METHANE (C-1) 13145.000 @ 10,320' @ CONNECTION GAS HIGH N/A
ETHANE (C-2) 1062.892 @ 10,320' @ AVG
PROPANE (C-3) 531.282 @ 10,320' @ CURRENT Ou
BUTANE (C-4) 226.205 @ 10,320' @ CURRENT BACKGROUND/AVG Ou
PENTANE (C-5) 80.100 @ 10,320' @
HYDROCARBON SHOWS
INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION
LITHOLOGY CARBONACEOUS SHALE, CLAYSTONE, SAND, SANSTONE, AND SILTSTONE
PRESENT LITHOLOGY 10% CLAYSTONE, 10% CARONACEOUS SHALE, 10% SAND, 20% SANDSTONE, AND 50% SILTSTONE
DAILY ACTIVITY Pulled out of hole to the shoe, cut and slipped the drill line. Service the tip drive. Run in the hole to TD, sweep hole
SUMMARY with hi-viscosity / hi-weight with nut plug marker to gauge hole. Circulated four bottoms up and pumped dry job.
Pulling out of hole at report time for casing.
EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335
REPORT BY RYAN MASSEY
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CONOCO PHILLIPS
TARN DAILY WELLSITE REPORT E+PQ~~
2L-330
REPORT FOR MORRIS/VAAGEN
DATE 11/18/2007 DEPTH 10328.00000 PRESENT OPERATION RIG UP TO RUN CASING
TIME 11:59:21 YESTERDAY 10328.00000
24 HOUR FOOTAGE 0
CASING INFORMATION 9.625" @ 3335'
SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH
BIT INFORMATION INTERVAL CONDITION REASON
NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HO URS T/B/C PULLED
8.75" HYCALOG DTX619M
DRILLING PARAMETERS HIGH -LOW AVERAGE CURRENT AVG
RATE OF PENETRATION @ @ FT/HR
SURFACE TORQUE @ @ AMPS
WEIGHT ON BIT @ @ KLBS
ROTARY RPM @ @ RPM
PUMP PRESSURE @ @ PSI
DRILLING MUD REPORT DEPTH 10330'
MW 9.7 VIS 44 PV 9 YP 18 FL 4 Gels 7/11/14 CL- 200
FC 1/N/A SOL 8 SD TR OIL 3 MBL 19 pH 10.0 Ca+ 40 CCI
MWD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY (units) HIGH LOW AVERAGE
DITCH GAS @ @ TRIP GAS N/A
CUTTING GAS @ @ WIPER GAS
CHROMATOGRAPHY(ppm) SURVEY
METHANE (C-1) 13145.000 @ 10,320' @ CONNECTION GAS HIGH N/A
ETHANE (C-2) 1062.892 @ 10,320' @ AVG
PROPANE (C-3) 531.282 @ 10,320' @ CURRENT Ou
BUTANE (C-4) 226.205 @ 10,320' @ CURRENT BACKGROUND/AVG Ou
PENTANE (C-5) 80.100 @ 10,320' @
HYDROCARBON SHOWS
INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION
LITHOLOGY CARBONACEOUS SHALE, CLAYSTONE, SAND, SANSTONE, AND SILTSTONE
PRESENT LITHOLOGY 10% CLAYSTONE, 10% CARONACEOUS SHALE, 10% SAND, 20% SANDSTONE, AND 50% SILTSTONE
DAILY ACTIVITY Finished pulling out of the hole laying down down 5" drill pipe. Begin rig up to run 7" casing string. Max
SUMMARY gas was 0 units.
EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335
REPORT BY RYAN MASSEY
C.
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CONOCO PHILLIPS
TARN DAILY WELLSITE REPORT ~. EI'QCH
2L-330
REPORT FOR MORRIS/VAAGEN
DATE 11/19/2007 DEPTH 10328.00000 PRESENT OPERATION Cementing Casing
TIME 11:59:21 YESTERDAY 10328.00000
24 HOUR FOOTAGE 0
CASING INFORMATION 9.625" @ 3335'
SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH
BIT INFORMATION INTERVAL CONDITION REASON
NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED
8.75" HYCALOG DTX619M
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION @ @ FT/HR
SURFACE TORQUE @ @ AMPS
WEIGHT ON BIT @ @ KLBS
ROTARY RPM @ @ RPM
PUMP PRESSURE @ @ PSI
DRILLING MUD REPORT DEPTH 10330'
MW 9.7 VIS 43 PV 8 YP 17 FL 4.2 Gels 7/12/13 CL- 200
FC 1/N/A SOL 8.7 SD TR OIL 3 MBL 20 pH 9.3 Ca+ 40 CCI
MWD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY (units) HIGH LOW AVERAGE
DITCH GAS @ @ TRIP GAS 132u
CUTTING GAS @ @ WIPER GAS
CHROMATOGRAPHY(ppm) SURVEY
METHANE (C-1) 13145.000 @ 10,320' @ CONNECTION GAS HIGH N/A
ETHANE (C-2) 1062.892 @ 10,320' @ AVG
PROPANE (C-3) 531.282 @ 10,320' @ CURRENT Ou
BUTANE (C-4) 226.205 @ 10,320' @ CURRENT BACKGROUND/AVG Ou
PENTANE (C-5) 80.100 @ 10,320' @
HYDROCAR80N SHOWS
INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION
LITHOLOGY CARBONACEOUS SHALE, CLAYSTONE, SAND, SANSTONE, AND SILTSTONE
PRESENT LITHOLOGY 10% CLAYSTONE, 10% CARONACEOUS SHALE, 10% SAND, 20% SANDSTONE, AND 50% SILTSTONE
DAILY ACTIVITY SUMMARY Run 7" casing. Max gas was 132 units.
EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335
REPORT BY RYAN MASSEY
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CONOCO PHILLIPS
TARN DAILY WELLSITE REPORT EPQ~;H
2L-330
REPORT FOR MORRIS/VAAGEN
DATE 11/19/2007 DEPTH 10328.00000 PRESENT OPERATION Cementing Casing
TIME 11:59:21 YESTERDAY 10328.00000
24 HOUR FOOTAGE 0
CASING INFORMATION 9.625" @ 3335'
SURVEY DATA DEPTH INCLINATION AZIMUTH .VERTICAL DEPTH
BIT INFORMATION INTERVAL CONDITION REASON
NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED
8.75" HYCALOG DTX619M
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION @ @
SURFACE TORQUE FT/HR
@ @
WEIGHT ON BIT AMPS
@ @
ROTARY RPM KLBS
@ @
PUMP PRESSURE RPM
@ @
PSI
DRILLING MUD REPORT DEPTH 10330'
MW 9.7 VIS 43 PV 8 YP 17 FL 4.2 Gels 7112/13 CL- 200
FC 1/N/A SOL 8.7 SD TR OIL 3 MBL 20 pH 9.3 Ca+ 40 CCI
MWD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY (units) HIGH LOW AVERAGE
DITCH GAS @ @
CUTTING GAS TRIP GAS 132u
@ @
WIPER GAS
CHROMATOGRAPHY(ppm) SURVEY
METHANE (C-1) 13145.000 @ 10,320' @ CONNECTION GAS HIGH N/A
ETHANE (C-2) 1062.892 @ 10,320' @
PROPANE (C-3) AVG
531.282 @ 10,320' @
BUTANE (C-4) CURRENT Ou
226.205 @ 10,320' @ CURRENT BACKGROUND/AVG Ou
PENTANE (C-5) 80.100 @ 10,320' @
HYDROCARBON SHOWS
INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION
LITHOLOGY CARBONACEOUS SHALE, CLAYSTONE, SAND, SANSTONE, AND SILTSTONE
PRESENT LITHOLOGY 10% CLAYSTONE, 10% CARONACEOUS SHALE, 10% SAND, 20% SANDSTONE, AND 50% SILTSTONE
DAILY ACTIVITY SUMMARY Run 7" casing. Max gas was 132 units.
EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335
REPORT BY RYAN MASSEY
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CONOCO PHILLIPS
TARN DAILY WELLSITE REPORT EPpCH
2L-330
REPORT FOR MORRIS/HEIM
DATE 11/21/2007 DEPTH 10328.00000 PRESENT OPERATION P/U DRILL PIPE
TIME 11:59:21 YESTERDAY 10328.00000
24 HOUR FOOTAGE 0
CASING INFORMATION 9.625" @ 3335' 7" @ 10307'
SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH
BIT INFORMATION INTERVAL CONDITION REASON
NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED
8.75" HYCALOG DTX619M
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION @ @
SURFACE TORQUE @ @ FT/HR
WEIGHT ON BIT @ @ AMPS
ROTARY RPM @ @ KLBS
PUMP PRESSURE @ @ RPM
PSI
DRILLING MUD REPORT DEPTH 10330'
MW 9.7 VIS 43 PV 7 YP 18 FL 4.2 Gels 8/11/13 CL- 200
FC 1/N/A SOL 8 SD TR OIL 2 MBL 18 pH 10.1 Ca+ 40 CCI
MWD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY (units) HIGH LOW AVERAGE
DITCH GAS @ @
CUTTING GAS @ @ TRIP GAS N/A
WIPER GAS
CHROMATOGRAPHY(ppm) SURVEY
METHANE (C-1) 13145.000 @ 10,320' @ CONNECTION GAS HIGH N/A
ETHANE (C-2) 1062.892 @ 10,320' @
PROPANE (C-3) 531.282 @ 10,320' @ AVG
BUTANE (C-4) 226.205 @ 10,320' @ CURRENT Ou
CURRENT BACKGROUND/AVG Ou
PENTANE (C-5) 80.100 @ 10,320' @
HYDROCARBON SHOWS
INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION
LITHOLOGY CARBONACEOUS SHALE, CLAYSTONE, SAND, SANSTONE, AND SILTSTONE
PRESENT LITHOLOGY 10% CLAYSTONE, 10% CARONACEOUS SHALE, 10% SAND, 20% SANDSTONE, AND 50% SILTSTONE
DAILY ACTIVITY Pump cement into place at 02:30 hours. Flush and freeze protect 9 5/8 X 7" annulus. Put 270 barrels of 10
5
SUMMARY
mud into 3-4: Pumps were not turned on today. Max gas 0 units. .
EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335
REPORT BY RYAN MASSEY
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file://C:\Doeuments and Settings\RigUser\My Documents\My Wells\ConocoPhillips\200... 11/21/2007
Daily Report
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Page 1 of 1
CONOCO PHILLIPS
TARN DAILY WELLSITE REPORT El'~CH
2L-330
REPORT FOR MORRIS/HEIM
DATE Nov 22, 2007 DEPTH 10573.00000 PRESENT OPERATION DRILLING/ SLIDING
TIME 11:59:30 YESTERDAY 10329.00000
24 HOUR FOOTAGE 244
CASING INFORMATION
DEPTH INCLINATION AZIMUTH VERTICAL DEPTH
10290.11' 45.49 143.65 5224.57
SURVEY DATA 10334.64' 44.15 144.33 5256.15'
10428.43' 44.37 143.46 5323.32'
10523.49' _44.27 143.58 6373.56'
BIT INFORMATION INTERVAL CONDITION REASON
NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED
6.125" PDC DS69FNPV
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION 152.3 @ 10569.00000 4.6 @ 10479.00000 48.6 87.55502 FT/HR
SURFACE TORQUE 10 @ 10442.00000 0 @ 10486.00000 6.5 0.05215 AMPS
WEIGHT ON BIT 72 @ 10476.00000 27 @ 10540.00000 37.3 61.64511 KLBS
ROTARY RPM 66 @ 10527.00000 1 @ 10477.00000 44.2 0.00000 RPM
PUMP PRESSURE 35 @ 10329.00000 35 @ 10573.00000 35.1 35.00000 PSI
DRILLING MUD REPORT DEPTH 10580'
MW 10.5 VIS 53 PV 14 YP 21 FL 4.9 Gels 9/12/14 CL- 200
FC 1/1 SOL 8.5 SD TR OIL 2 MBL 18 pH 10.0 Ca+ 40 CCI
MWD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY (units) HIGH LOW AVERAGE
DITCH GAS 365 @ 10527.00000 2 @ 10493.00000 43.4 TRIP GAS N/A
CUTTING GAS 0 @ 10573.00000 0 @ 10573.00000 0.0 WIPER GAS
CHROMATOGRAPHY(ppm) SURVEY
METHANE (C-1) 53555 @ 10556.00000 149 @ 10493.00000 3801.0 CONNECTION GAS HIGH 461u
ETHANE (C-2) 5342 @ 10556.00000 18 @ 10493.00000 384.3 AVG
PROPANE (C-3) 2793 @ 10556.00000 34 @ 10441.00000 252.1 CURRENT 42u
BUTANE (C-4) 1512 @ 10556.00000 0 @ 10505.00000 100.3 CURRENT BACKGROUND/AVG 42u
PENTANE (C-5) 570 @ 10556.00000 0 @ 10347.00000 34.1
HYDROCARBON SHOWS
INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION
LITHOLOGY SANDSTONE, SAND, SILTSTONE
PRESENT LITHOLOGY 10% SILTSTONE, 10% SAND, 80% SANDSTONE
DAILY ACTIVITY Finished tripping in the hole. Drilled out float and shoe track. Drilling
SUM and sliding at report time
Max gas was
MARY 1931 units after a connection. .
EPOCH PERSONNEL ON 80ARD 4 DAILY COST $3335
REPORT BY RYAN MASSEY
file://C:\Documents and Settings\RigUser\My Documents\My Wells\ConocoPhillips\200... 11/23/2007
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Daily Report
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CONOCO PHILLIPS
TARN DAILY WELLSITE REPORT ~,PQC~
2L-330
REPORT FOR MORRIS/HEIM
DATE Nov 23, 2007 DEPTH 10749.00000 PRESENT OPERATION CIRCULATING AND BACK REAMING
TIME 11:59:30 YESTERDAY 10573.00000
24 HOUR FOOTAGE 176
CASING INFORMATION 9.625" @3318 ft 7" @10307 ft
SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH
BIT INFORMATION INTERVAL CONDITION REASON
NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED
6.125" PDC DS69FNPV
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION 334.8 @ 10575.00000 11.9 @ 10632.00000 48.1 41.39073 FT/HR
SURFACE TORQUE 9 @ 10676.00000 0 @ 10584.00000 4.9 6.41172 AMPS
WEIGHT ON BIT 67 @ 10576.00000 -18 @ 10639.00000 23.9 16.99611 KLBS
ROTARY RPM 63 @ 10729.00000 1 @ 10637.00000 38.2 61.00000 RPM
PUMP PRESSURE 35 @ 10573.00000 35 @ 10749.00000 35.2 35.00000 PSI
DRILLING MUD REPORT DEPTH 10572'
MW 10.7 VIS 47 PV 16 YP 27 FL 4.4 Gels 12/14/14 CL- 300
FC 1/1 SOL 10 SD TR OIL 4 MBL 3.75 pH 9.6 Ca+ 60 CCI
MWD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY (units) HIGH LOW AVERAGE
DITCH GAS 3404 @ 10635.00000 32 @ 10697.00000 196.2 TRIP GAS 3404u
CUTTING GAS 0 @ 10749.00000 0 @ 10749.00000 0.0 WIPER GAS
CHROMATOGRAPHY(ppm) SURVEY
METHANE (C-1) 141412 @ 10722.00000 904 @ 10656.00000 8917.8 CONNECTION GAS HIGH
ETHANE (C-2) 24181 @ 10722.00000 159 @ 10664.00000 1643.0 AVG
PROPANE (C-3) 22375 @ 10722.00000 112 @ 10656.00000 1312.4 CURRENT 40u
BUTANE (C-4) 24560 @ 10722.00000 93 @ 10656.00000 1373.8 CURRENT BACKGROUND/AVG 40u
PENTANE (C-5) 16816 @ 10722.00000 55 @ 10656.00000 880.7
HYDROCARBON SHOWS
INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION
LITHOLOGY CARBONACEOUS SHALE, CLAYSTONE, SANDSTONE, SILTSTONE
PRESENT LITHOLOGY 30% CARBONACEOUS SHALE, 10% CLAY, 20% SANDSTONE, 40% SILTSTONE
DAILY ACTIVITY Drilled ahead to 10752'. At 0630 hr Phase 3 called and rig then began circulating and waiting on weather to
SUMMARY improve. Brought mud weight up to 10.8 and commenced drilling around midnight. Max gas was 3404 units.
EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335
REPORT BY RYAN MASSEY
file://C:\Documents and Settings\RigUser\My Documents\My Wells\ConocoPhillips\200... 11/24/2007
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CONOCO PHILLIPS
TARN DAILY WELLSITE REPORT EPOCH
2L-330
REPORT FOR MORRIS/HEIM
DATE Nov 24, 2007 DEPTH 11201.00000 PRESENT OPE RATION TRIPPING OUT OF HOLE
TIME 11:59:30. YESTERDAY 10750.00000
24 HOUR FOOTAGE 449
CASING INFORMATION 9.625" @ 3318' 7" @ 10307'
SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH
BIT INFORMATION INTERVAL CONDITION .REASON
NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED
6.125" PDC DS69FNPV
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION 130.6 @ 10751.00000 10.6 @ 10766.00000 54.0 59.67972 FT/HR
SURFACE TORQUE 5 @ 11188.00000 0 @ 11047.00000 4.3 5.17502 AMPS
WEIGHT ON BIT 39 @ 10756.00000 9 @ 11193.00000 16.2 12.32840 KLBS
ROTARY RPM 70 @ 11129.00000 1 @ 11063.00000 54.2 63.00000 RPM
PUMP PRESSURE 35 @ 10750.00000 35 @ 11199.00000 34.8 35.00000 PSI
DRILLING MUD REPORT DEPTH 11201'
MW 11.1 VIS 46 PV 19 YP 26 FL 3.1 Gels 10/13/14 CL- 300
FC 1/1 SOL 11.1 SD TR OIL 3 MBL 4.5 pH 9.5 Ca+ 60 CCI
MWD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY (units) HIGH LOW AVERAGE
DITCH GAS 776 @ 11125.00000 21 @ 10852.00000 64.4 TRIP GAS 3043u
CUTTING GAS 0 @ 11199.00000 0 @ 11199.00000 0.0 WIPER GAS
CHROMATOGRAPHY(ppm) SURVEY
METHANE (C-1) 88998 @ 11125.00000 1837 @ 10852.00000 7130.6 CONNECTION GAS HIGH
ETHANE (C-2) 8684 @ 11125.00000 197 @ 10852.00000 670.0 AVG
PROPANE (C-3) 6250 @ 11125.00000 123 @ 10943.00000 474.0 CURRENT Ou
BUTANE (C-4) 4299 @ 11125.00000 123 @ 10946.00000 355.9 CURRENT BACKGROUND/AVG Ou
PENTANE (C-5) 2169 @ 11125.00000 57 @ 10973.00000 203.3
HYDROCARBON SHOWS
INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION
LITHOLOGY CARNONACEOUS SHALE, SANDSTONE, SILTSTONE,
PRESENT LITHOLOGY 20% SANDSTONE, 10% SANDSTONE, 70% SILTSTONE
DAILY ACTIVITY Drilled to total depth of 11201'MD/5935'TVD. Pertormed short trip and ran geo logs. Pumped weighted swee
SUMMARY 12.8 to clean hole. Cleaned hole and began to trip out of hole to run prod p
uction string
Max gas was 3043 units
.
.
EPOCH PERSONNEL ON BOARD 4 DAILY COST $3335
REPORT BY RYAN MASSEY
Lr- ~I
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file://C:\Documents and Settings\RigUser\My Documents\My Wells\ConocoPhillips\200... 11/25/2007
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Daily Report
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CONOCO PHILLIPS
TARN DAILY WELLSITE REPORT EPOCH
2L-330
REPORT FOR MORRIS/HEIM
DATE Nov 25, 2007 DEPTH 11201.00000 PRESENT OPERATION TRIP IN HOLE TO KILL TOOH LOG
TIME 11:59:30 YESTERDAY 11201.00000
24 HOUR FOOTAGE 449
CASING INFORMATION 9.625" @ 3318' 7" @ 10307
SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH
BIT INFORMATION INTERVAL CONDITION REASON
NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED
6.125" PDC DS69FNPV
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION 0@ 0 0@ 0 0 0 FT/HR
SURFACE TORQUE 0@ 0 0@ 0 0 0 AMPS
WEIGHT ON BIT 0@ 0 0@ 0 0 0 KLBS
ROTARY RPM 0@ 0 0@ 0 0 0 RPM
PUMP PRESSURE 0@ 0 0@ 0 0 0 PSI
DRILLING MUD REPORT DEPTH 11201'
MW 11.2 VIS 51 PV 15 YP 26 FL 4 Gels 10/12/15 CL- 300
FC 1/1 SOL 12 SD TR OIL 3 MBL 5 pH 9.4 Ca+ 60 CCI
MWD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY (units) HIGH LOW AVERAGE
DITCH GAS 776 @ 11125.00000 21 @ 10852.00000 64.4 TRIP GAS 2074u
CUTTING GAS 0 @ 11199.00000 0 @ 11199.00000 0.0 WIPER GAS
CHROMATOGRAPHY(ppm) SURVEY
METHANE (C-1) 88998 @ 11125.00000 1837 @ 10852.00000 7130.6 CONNECTION GAS HIGH
ETHANE (C-2) 8684 @ 11125.00000 197 @ 10852.00000 670.0 AVG
PROPANE (C-3) 6250 @ 11125.00000 123 @ 10943.00000 474.0 CURRENT Ou
BUTANE (C-4) 4299 @ 11125.00000 123 @ 10946.00000 355.9 CURRENT BACKGROUND/AVG Ou
PENTANE (C-5) 2169 @ 11125.00000 57 @ 10973.00000 203.3
HYDROCARBON SHOWS
INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION
LITHOLOGY CARNONACEOUS SHALE, SANDSTONE, SILTSTONE,
PRESENT LITHOLOGY 20% SANDSTONE, 10% SANDSTONE, 70% SILTSTONE
DAILY ACTIVITY Pulled out of the hole and monitored hole conditions. The hole was boiling and mud was weighted up to 11.2.
SUMMARY TOOH for logs. When the logs are complete, trip in the hole for clean up run. Then spot 1000' pill for production
tubing. Max gas was 2074 units.
EPOCH PERSONNEL ON BOARD 3 DAILY COST $3335
REPORT BY RYAN MASSEY
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file://C:\Documents and Settings\RigUser\My Documents\My Wells\ConocoPhillips\200... 11/26/2007
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CONOCO PHILLIPS
TARN DAILY WELLSITE REPORT EPOCH
2L-330
REPORT FOR MORRIS/HEIM
DATE Nov 26, 2007 DEPTH 11201.00000 PRESENT OPERATION TRIP IN AND CLEAN HOLE
TIME 11:59:30 YESTERDAY 11201.00000
24 HOUR FOOTAGE 449
CASING INFORMATION 9.625" @ 3318' 7" @ 10307'
SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH
BIT INFORMATION INTERVAL CONDITION REASON
NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED
6.125" PDC DS69FNPV
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION 0@ 0 0@ 0 0 0 FT/HR
SURFACE TORQUE 0@ 0 0@ 0 0 0 AMPS
WEIGHT ON BIT 0@ 0 0@ 0 0 0 KLBS
ROTARY RPM 0@ 0 0@ 0 0 0 RPM
PUMP PRESSURE 0@ 0 0@ 0 0 0 PSI
DRILLING MUD REPORT DEPTH 11201'
MW 11.2 VIS 53 PV 15 YP 26 FL 3.9 Gels 11/12/12 CL- 350
FC 1/1 SOL 10 SD TR OIL 3 MBL 6.25 pH 9.3 Ca+ 80 CCI
MWD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY (units) HIGH LOW AVERAGE
DITCH GAS 776 @ 11125.00000 21 @ 10852.00000 64.4 TRIP GAS 1384u
CUTTING GAS 0 @ 11199.00000 0 @ 11199.00000 0.0 WIPER GAS
CHROMATOGRAPHY(ppm) SURVEY
METHANE (C-1) 88998 @ 11125.00000 1837 @ 10852.00000 7130.6 CONNECTION GAS HIGH
ETHANE (C-2) 8684 @ 11125.00000 197 @ 10852.00000 670.0 AVG
PROPANE (C-3) 6250 @ 11125.00000 123 @ 10943.00000 474.0 CURRENT 42u
BUTANE (C-4) 4299 @ 11125.00000 123 @ 10946.00000 355.9 CURRENT BACKGROUND/AVG 42u
PENTANE (C-5) 2169 @ 11125.00000 57 @ 10973.00000 203.3
HYDROCARBON SHOWS
INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION
LITHOLOGY CARNONACEOUS SHALE, SANDSTONE, SILTSTONE,
PRESENT LITHOLOGY 20% SANDSTONE, 10% SANDSTONE, 70% SILTSTONE
DAILY ACTIVITY SUMMARY TRIP IN HOLE AND CONDITION. MAX GAS WAS 1384 units.
EPOCH PERSONNEL ON BOARD 2 DAILY COST $3085
REPORT BY RYAN MASSEY
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file://C:\Documents and Settings\RigUser\My Documents\My Wells\ConocoPhillips\200... 11/27/2007
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CONOCO PHILLIPS
TARN DAILY WELLSITE REPORT ®EPC~CH
2L-330
REPORT FOR MORRIS/HEIM
DATE Nov 27, 2007 DEPTH 11201.00000 PRESENT OPERATION TRIP OUT OF HOLE
TIME 11:59:30 YESTERDAY 11201.00000
24 HOUR FOOTAGE 0
CASING INFORMATION 9.625" @ 3318' 7" @ 10307'
DEPTH INCLINATION AZIMUTH VERTICAL DEPTH
SURVEY DATA
BIT INFORMATION INTERVAL CONDITION REASON
NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T!B/C PULLED
6.125" PDC DS69FNPV
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION 0@ 0 0@ 0 0 0 FT/HR
SURFACE TORQUE 0@ 0 0@ 0 0 0 AMPS
WEIGHT ON BIT 0@ 0 0@ 0 0 0 KLBS
ROTARY RPM 0@ 0 0@ 0 0 0 RPM
PUMP PRESSURE 0@ 0 0@ 0 0 0 PSI
DRILLING MUD REPORT DEPTH 11201'
MW 11.2 VIS 53 PV 13 YP 27 FL 3.8 Gels 9/11/11 CL- 300
FC 1/1 SOL 12 SD TR OIL 3 MBL 6 pH 9.5 Ca+ 80 CCI
MWD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY (units) HIGH LOW AVERAGE
DITCH GAS 776 @ 11125.00000 21 @ 10852.00000 64.4 TRIP GAS 3188u
CUTTING GAS 0 @ 11199.00000 0 @ 11199.00000 0.0 WIPER GAS
CHROMATOGRAPHY (ppm) SURVEY
METHANE (C-1) 88998 @ 11125.00000 1837 @ 10852.00000 7130.6 CONNECTION GAS HIGH
ETHANE (C-2) 8684 @ 11125.00000 197 @ 10852.00000 670.0 AVG
PROPANE (C-3) 6250 @ 11125.00000 123 @ 10943.00000 474.0 CURRENT Ou
BUTANE (C-4) 4299 @ 11125.00000 123 @ 10946.00000 355.9 CURRENT BACKGROUND/AVG Ou
PENTANE (C-5) 2169 @ 11125.00000 57 @ 10973.00000 203.3
HYDROCARBON SHOWS
INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION
LITHOLOGY CARNONACEOUS SHALE, SANDSTONE, SILTSTONE,
PRESENT LITHOLOGY 20% SANDSTONE, 10% SANDSTONE, 70% SILTSTONE
DAILY ACTIVITY Trip out of hole and lay down all logging tools. Circulated before tripping out with 11.2 mud weight. Max
SUMMARY gas was 3188 units.
EPOCH PERSONNEL ON BOARD 2 DAILY COST $3085
REPORT BY RYAN MASSEY
r
file://C:\Documents and Settings\RigUser\My Documents\My Wells\ConocoPhillips\200... 11/28/2007
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Daily Report
Page 1 of 1
CONOCO PHILLIPS
TARN DAILY WELLSITE REPORT EPOCH
2L-330
REPORT FOR MORRIS/HEIM
DATE Nov 28, 2007 DEPTH 11201.00000 PRESENT OPERATION TRIP OUT OF HOLE
TIME 11:59:30 YESTERDAY 11201.00000
24 HOUR FOOTAGE 0
CASING INFORMATION 9.625" @ 3318' 7" @ 10307
SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH
BIT INFORMATION INTERVAL CONDITION REASON
NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED
6.125" PDC DS69FNPV
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION 0@ 0 0@ 0 0 0 FT/HR
SURFACE TORQUE 0@ 0 0@ 0 0 0 AMPS
WEIGHT ON BIT 0@ 0 0@ 0 0 0 KLBS
ROTARY RPM 0@ 0 0@ 0 0 0 RPM
PUMP PRESSURE 0@ 0 0@ 0 0 0 PSI
DRILLING MUD REPORT DEPTH 11201'
MW 11.2 VIS 52 PV 14 YP 26 FL 3 Gels 9/10/12 CL- 320
FC 1/1 SOL 11.5 SD TR OIL 3 MBL 6 pH 9.7 Ca+ 80 CCI
MWD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY (units) HIGH LOW AVERAGE
DITCH GAS 776 @ 11125.00000 21 @ 10852.00000 64.4 TRIP GAS 3226u
CUTTING GAS 0 @ 11199.00000 0 @ 11199.00000 0.0 WIPER GAS
CHROMATOGRAPHY (ppm) SURVEY
METHANE (C-1) 88998 @ 11125.00000 1837 @ 10852.00000 7130.6 CONNECTION GAS HIGH
ETHANE (C-2) 8684 @ 11125.00000 197 @ 10852.00000 670.0 AVG
PROPANE (C-3) 6250 @ 11125.00000 123 @ 10943.00000 474.0 CURRENT Ou
BUTANE (C-4) 4299 @ 11125.00000 123 @ 10946.00000 355.9 CURRENT BACKGROUND/AVG Ou
PENTANE (C-5) 2169 @ 11125.00000 57 @ 10973.00000 203.3
HYDROCARBON SHOWS
INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION
LITHOLOGY CARNONACEOUS SHALE, SANDSTONE, SILTSTONE,
PRESENT LITHOLOGY 20% SANDSTONE, 10% SANDSTONE, 70% SILTSTONE
DAILY Circulated DYNA RED MED, nut plug, G-Seal due to formation swelling. Pumped 100 barrells with 20 pounds of
ACTIVITY LCM and chased with 30 barrells of 11.2 mud. Pumped out of open, pumped dry job and began to trip out of hole.
SUMMARY Gas trap was assembled with rubber hose that is suspected to have given incorrect gas readings, the hose was
removed and gas readings returned to a normal range. Max gas was 3226 units.
EPOCH PERSONNEL ON BOARD 2 DAILY COST $3085
REPORT BY RYAN MASSEY
C.
file://C:\Documents and Settings\RigUser\My Documents\My Wells\ConocoPhillips\200... 11/29/2007
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Daily Report
Page 1 of 1
CONOCO PHILLIPS
TARN DAILY WELLSITE REPORT ~+POCH
2L-330
REPORT FOR BREEDEN/HEIM
DATE Nov 29, 2007 DEPTH 11201.00000 PRESENT OPE RATION RUN IN WITH 4.5" LINER
TIME 11:59:30 YESTERDAY 11201.00000
24 HOUR FOOTAGE 0
CASING INFORMATION 9.625" @ 3318' 7" @ 10307'
SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH
BIT INFORMATION INTERVAL CONDITION REASON
NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HO URS T/B/C PULLED
6.125" PDC DS69FNPV
DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG
RATE OF PENETRATION 0@ 0 0@ 0 0
SURFACE TORQUE 0@ 0 0@ 0 0 0 FT/HR
WEIGHT ON BIT 0@ 0 0@ 0 0 0 AMPS
0
ROTARY RPM 0@ 0 0@ 0 0 KLBS
0
PUMP PRESSURE 0@ 0 0@ 0 0 RPM
0 PSI
DRILLING MUD REPORT DEPTH 11201'
MW 11.2 VIS 59 PV 16 YP 30 FL 2.4 Gels 11/13/13 CL- 330
FC 111 SOL 10 SD TR OIL 2 MBL 6.25 pH 9.6 Ca+ 80 CCI
MWD SUMMARY
INTERVAL TO
TOOLS
GAS SUMMARY (units) HIGH LOW AVERAGE
DITCH GAS 776 @ 11125.00000. 21 @ 10852.00000 64.4 TRIP GAS 4819u
CUTTING GAS 0 @ 11199.00000 0 @ 11199.00000 0.0 WIPER GAS
CHROMATOGRAPHY(ppm) SURVEY
METHANE (C-1) 88998 @ 11125.00000 1837 @ 10852.00000 7130.6 CONNECTION GAS HIGH
ETHANE (C-2) 8684 @ 11125.00000 197 @ 10852.00000 670.0 AVG
PROPANE (C-3) 6250 @ 11125.00000 123 @ 10943.00000 474.0 CURRENT Ou
BUTANE (C-4) 4299 @ 11125.00000 123 @ 10946.00000 355.9 CURRENT BACKGROUND/AVG Ou
PENTANE (C-5) 2169 @ 11125.00000 57 @ 10973.00000 203.3
HYDROCARBON SHOWS
INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION
LITHOLOGY CARNONACEOUS SHALE, SANDSTONE, SILTSTONE,
PRESENT LITHOLOGY 20% SANDSTONE, 10% SANDSTONE, 70% SILTSTONE
DAILY Lay down BHA and pulled wear bushing. Made up liner packer, SBE and Hanger, and run in with Packer
SBE
ACTIVITY assembly on 4"drill pipe and circulated liner volume of PP 360 @ 85 spm. C .
ontinued to run in hole with Packer
SUMMARY When pumps turned on, gas commonly spiked to over 4000 units and would .
slowly fall down. Max gas was 4819
units.
EPOCH PERSONNEL ON BOARD 2 DAILY COST $3085
REPORT BY RYAN MASSEY
•
file://C:\Documents and Settings\RigUser\My Documents\My Wells\ConocoPhillips\200... 11/30/2007
