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;¿O 3 - 03'l Well History File Identifier
Organizing (done)
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1
R;PCAN
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DIGJAL DATA
jj2(óiskettes, No. ~
o Other, NolType:
OVERSIZED (Scannable)
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o Other Items Scannable by
a Large Scanner
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OVERSIZED (Non-Scannable)
o Other:
o Logs of various kinds:
NOTES:
Scanning Preparation
BY: Helen ~
:;}.. X 30 = (p()
o Other::
Date: U I ClQ' ',~ Isl /AA lJ
/ ~ I /~ vrv.
I
Date: L: d1. ð6 Isl VW 0
+ ~ = TOTAL PAGES b d-...
(Count rJo ~s not 'lclude cover sheet) IA Al ()
Date:L: ðC¡ D.ç /5/ vv rr
, I I I
BY:
Helen ~
Project Proofing
BY:
Helen ~
Production Scanning
Stage 1
~
Page Count from Scanned File: ,n "3 (Count does include cover sheet)
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Helen ~ Date if: !J1/06/sl W!P
If NO in stage 1, page(s) discrepancies were found: YES NO
BY:
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BY:
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Date: /51
11I1I
III
Date: 151
Quality Checked 1111111111111111111
Scanning is complete at this point unless rescanning is required.
ReScanned
BY:
Helen Maria
Comments about this file:
• •
""~=~ -
;~ ._..
w. .~
~~ _:": ':
~:
MICROFILMED
03!01 /2008
DO NOT PLACE
ANY NEW MATERIAL
UNDER THIS PAGE
F:~I.a~rFiche\CvrPgs_InsertsuVlicrofilm_Marker.doc
.
.
WELL LOG TRANSMITTAL
To: State of Alaska
Alaska Oil and Gas Conservation Cornrn.
Attn.: Librarian
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
November 14, 2006
RE: MWD Formation Evaluation Logs: 3S-03, 3S-06, 3S-06A, 3S-08_3S-08A_3S-08B, 3S-l4,
3S-15.
The technical data listed below is being submitted herewith. Please address any problems or
concerns to the attention of:
Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518
3S-03: d63 -oot / 1:1: ¡'"i~/~d
Digital Log Images:
50-103-20458-00
3S-06: 0:rC-- 803 -OS-? ~ t./LIê)3
Digital Log Images:
50-103-20454-00
scANINE.D FEB 0 1 2007
1 CD Rom
1 CD Rom
3S-06A: UJ:<!.- QO'3-ö<is''ð -lI: l'-IL/a.1
Digital Log Images:
50-103-20454-01
3S-08 3S-08A 3S-08B: dC>3 -Qd:;;l¡ dD3 -031' I dù3-043
Digital Log Im~ges: fÍ i 4..1 "IdS ¡L.IL¡ Q~ ¡ !...fL.1 d7
50-103-20450-00, 01, 02
1 CD Rom
1 CD Rom
3S-14: U:r.c. d6J-d!O ìI: 1l..¡L¡¿)O
Digital Log Images:
50-103-20439-00
1 CD Rom
3S-l5: dD8 -;)54 1:1. /L.IL/fJ'-/
Digital Log Images:
50-103- 20444-00
1 CD Rom
t
e
e
WELL LOG TRANSMITTAL
To: State of Alaska
Alaska Oil and Gas Conservation Comm.
Attn.: Howard Okland
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
February 12, 2004
)~LÌ>O(p
RE: MWD Formation Evaluation Logs 3S-08A,
AK-MW-23 06056
The technical data listed below is being submitted herewith. Please address any problems or concerns
to the attention of
Rob Kalish, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518
~: 3':::y-0<6A
Digital Log Images
50-103-20450-01
1 CD Rom
~~~-ö31
t'
~~
,,/I
/'1 P y1 )- 6 0 r
DATA SUBMITTAL COMPLIANCE REPORT
4/1/2005
Permit to Drill 2030370
Well Name/No. KUPARUK R/V UNIT 3S-08A
Operator CONOCOPHILLlPS ALASKA INC
5ì! é¿¿ I D tv'lv.... M"\)
API No. 50-103-20450-01-00
MD 8475·/ TVD 6116 / Completion Date 3/14/2003 ~ Completion Status P&A
REQUIRED INFORMATION
------
DATA INFORMATION
Mud Log No
Current Status P&A
UIC N
Samples No
Directional surve~
..~
Types Electric or Other Logs Run: GR/ReslDens-Neutron
Well Log Information:
(data taken from Logs Portion of Master Well Data Maint)
Log/
Data Digital
Type ~ed/Fnnt
~~---
c~
I
i
!
I
I
~
~ D
.~
--------
Electr
Dataset
Number
Name
Directional Survey
11714 LIS Verification
Directional Survey
Directional Survey
Directional Survey
LIS Verification
Well Cores/Samples Infonnation:
Name
Well Cored?
ADDITIONAL INFORMATION
y~
Chips Received? ~
Analysis
Received?
----------
Comments:
- Y /1"
Log Log Run Interval OH/
Scale Media No Start Stop CH Received Comments
1 4279 8475 Open 4/22/2003
A Directional Survey Log is
required to be submitted.
This record automatically
created from Permit to Drill
Module on: 3/13/2003.
4246 8443 Open 5/13/2003
4279 8475 Open 4/22/2003 MWD
4279 8475 Open 4/22/2003
4279 8475 Open 4/22/2003 MWD
4246 8443 Open 5/13/2003
Sample
Interval Set
Start Stop Sent Received Number Comments
~
0>-,-,
Daily History Received?
ÐN
LPN
Formation Tops
DATA SUBMITTAL COMPLIANCE REPORT
4/1/2005
Permit to Drill 2030370
Well Name/No. KUPARUK RIV UNIT 3S-08A
Operator CONOCOPHILLlPS ALASKA INC
MD 8475
TVD 6116
Completion Date 3/14/2003
Completion Status P&A
Current Status P&A
--- - -- --- -------
--- - --~- ---~-
Compliance Reviewed By:
Date:
API No. 50-103-20450-01-00
UIC N
--'
----'
'l
)
WELL LOG TRANSMITTAL
To: State of Alaska
Alaska Oil and Gas Conservation Comm.
Attn.: Lisa Weepie
333 West 7tll Avenue, Suite 100
Anchorage, Alaska
RE:MWDFormation Evaluation Logs 3S-08A,
1 LDWG formatted Disc with verification listing.
llPI#: 50-103-20450-01
)
~o 3-03 7
I /7/tJ
April 30, 2003
AK-MW-23 06056
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL
LETTER TO THE ATTENTION OF:
Sperry-Sun Drilling Service
Attn: Rob Kalish
6900 Arctic Blvd.
Anchorage, Alaska 99518
Date:
Si~~r-
RECEIVED
MAY 13 2003
Alaska OJ¡' & Gas
)I... Cons. Commie....
rvld)OI'!ge ·..·..iJ9ft;n
) STATE OF ALASKA )
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
Plugged 0 Abandoned 0
20AAC 25.105
WDSPL 0 <"'~~!i9.~"~L2~,~e.~~ltions-
f~.¡:¡ ~ \~;ti'l:';.~ f~U'\!- I
, , ~ ~ ~"t.
ConocoPhillips Alaska, Inc. ~~ "_9.~~.~ 9..1 :
3. Address: ,~ V¡'::P'T 1''::''1 !
P. O. Box 100360, Anchorage, AK 99510-03.q __ ;!Ai-~- . ~' I
4a. Location of Well (Governmental Section): !¡''I'''''~' .,"'..,....."'~I_~ .
Surface: 2492' FNL, 954' FEL, Sec. 18, T12N, R8E, UM
At Top Productive
Horizon:
1a. Well Status: Oil 0
Gas U
GINJ 0
o
WINJ
2. Operator Name:
1395' FSL, 1135' FWL, Sec. 17, T12N, R8E, UM
Total Depth:
1391' FSL, 962' FWL, Sec. 17, T12N, R8E, UM
4b. Location of Well (State Base Plane Coordinates):
Surface: x- 476305 y-
TPI: x- 478395 y-
Total Depth: x- 478222 y-
18. Directional Survey: Yes 0 NoD
5993924
5992525
5992521
Zone-4
Zone-4
Zone-4
21. Logs Run:
GR/Res/Dens-Neutron
22.
Suspended 0 WAG 0
20AAC 25.110
Other
5. Date Comp., Susp.,
or Aband.: March 14, 2003
6. Date Spudded:
March 10, 2003
7. Date TD Reached:
March 12, 2003
8. KB Elevation (ft):
RKB 23.5'
9. Plug Back Depth (MD + TVD):
6700' MD 14713' TVD
10. Total Depth (MD + TVD):
8475' MD 16116' TVD
11. Depth where SSSV set:
N/A feet MD
1 b. Well Class:
Development 0 Exploratory 0
Service 0 Stratigraphic Test 0
12. Permit to Drill Number:
203-037 I 303-086
13. API Number:
50-103-20450-01
14. Well Name and Number:
3S-08A
15. Field/Pool(s):
Kuparuk River Field
Kuparuk Oil Pool
16. Property Designation:
ADL 380107
17. Land Use Permit:
ALK 4624
19. Water Depth, if Offshore: 20. Thickness of
N/A feet MSL Permafrost: 1676' MD
-1/Jv~~ 'l3æ~'/hÞ
2~77"-rYb
CASING SIZE
GRADE
B
L-80
CASING, LINER AND CEMENTING RECORD
SETTING DEPTH MD
TOP BOTTOM
Surface 108'
Surface 4263'
30"x16"
WT. PER FT.
62.5#
40#
9.625"
23. Perforations open to Production (MD + TVD of Top and Bottom
Interval, Size and Number; if none, state "none"):
;~';,' ,~~:rt ,',. .~
',I ,,§,. ".,;,:t'!
"~< <''"I"''';;:
M,f." ~"'K'
ii,,~, ",. ,i
,~, ' 'I., "': ~~""'. r/: "
,1 1¡, ,; J','
" I.." '.'. ~1!' -.,' ~¡-:I
~:~~ ,. ,"~' ~,~'-:"I':r~.i~:~;~~~~:''''~~ .~~:~~.~;:
None
26.
Date First Production
N/A
Date of Test
N/A
Flow Tubing
Hours Tested
Casing Pressure
press.
psi
24-Hour Rate ->
42"
75 sx ArcticCrete
CEMENTING RECORD
AMOUNT PULLED
HOLE SIZE
664 sx AS Lite, 391 sx LiteCrete
cement plug #1: 7968' - 8475'
cement plug #2: 7300' - 6700'
TUBING RECORD
DEPTH SET (MD)
N/A
12.25"
24.
SIZE
N/A
PACKER SET (MD)
N/A
25. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED
plug #1: 7968' - 8475' 235 sx Class G
plug #2: 7300' - 6700' 316 sx Class G
GAS-MCF
W A TER-BBL
CHOKE SIZE
GAS-OIL RATIO
PRODUCTION TEST
Method of Operation (Flowing, gas lift, etc.)
Plugged and Abandoned
Production for OIL-BBL GAS-MCF WATER-BBL
Test Period ow>
Calculated OIL-BBL
OIL GRAVITY - API (corr)
27. ......-..... CORE DATA
Brief description of lithology, porosity, fractures, appfent diP~nd presence of oil, gas or water (attach separate sheet, if necessary).
SUbmitcoreChiPS;ifnOne~"none"", ~\o"'~ RECEIVED
.c:D:J 0-0 ~
.~. \ü~ ~ ;' " ~.-2§Y NONE APR 2 5 Z003
Z~~~G6t1bÀ)J
G4BDMS BFl
APR ,3 n ?OO~
C°tJ~ 1N~=N f{ L
Form 10-407 Revised 2/2003
Alaska Oil & Gas Cons. Commission
Anchorage
¡) f
lJ-
Submit in duplicate
'\
I
29.
)
FORMATION TESTS
TVD
Include and briefly summarize test ,esu1\S, List intervals tesled, and
attach detailed supporting data as necessary. If no tests were
conducted, state "None".
28.
GEOLOGIC MARKERS
MD
NAME
Top Kuparul<
Base Kuparuk
8168'
8186'
5862'
5877'
N/A
30. LIST OF ATTACHMENTS
summary of Daily operations, Directional survey
31 , I herebY certily thaI the lo,egoing is true and correct to the best of my knowledge,
RECEIVED
APR 2 5 2003
Alaska Oil & £ì'3S ConE Com . .
. Im~~IUII
Anchorage
contact: Scott Lowry 265-6869
printed Na~ . .~' Thomas Trtle:
Signature . \ ~\ '\. \.A...v----'. ____Phone
Kuparuk Drilling Team Leader
Date
(t/¿';,/ð3
Prepared by 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.
\NSTRUCT\ONS
Item 1a: Classification ot Service weils: Gas Injection, water injection, Water-Altemating-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 tram each pool completelY segregated, Each segregated pool is a completion,
Item 4b: TPI (ToP of Producing Interval).
Item 8: the Kelly Bushing elevation in feet abOur mean low low water, use same as reference lor 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: True vertical thickness.
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 trom 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 intervai),
Item 26: Method of operation: Flowing, Gas Lift, Rod pump, Hydraulic pump, submersibie, Water Injection, Gas Injection,
Shut-in, Other (explain).
Item 27: If no cores taken, indicate "none".
Item 29: list all test information. If none, state "None".
OR\G\Nf\L
Form 10-407 Revised 2/2003
) )
ConocoPhillips Alaska Page 1 of 12
Operations Summary Report
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
38-08
38-08
ROT - DRILLING
N 1268 @ ppco.com
Nabors 7ES
2/24/2003
2/25/2003
2/26/2003
2/27/2003
Rig down & blow down ball mill & mud pits
PJSM, Move Injection skid & Ball Mill away from Sub Module
Move Sub Module off of 3S-22 and in front of 3S-08
Spot wellhead equip. & Herculite on 3S-08, Spot rig on 3S-08
Center rig over hole.
Set matting boards and spot mud pits.
Lay herculite and spot ball mill, injection skid and auxiliary equipment.
Connected service lines and take on water in pits.
Accepted Rig @ 0500 hours.
Install valves on 4" Conductor outlets, NU riser, install burms around
cellar, Ball mill and Injection skid. Take on spud mud.
Install 16" divertor line and tunbuckles on stack.
Address housekeeping issues in cellar, move BHA #1 xo's and stabs to
rig floor.
PJSM with Halliburton slickline operator.
RU HES slickline for Qyro surveys.
PU and stand back 3 flex collars - MU bha #1 moter set @ 1.5 degrees.
Perform Divertor and Accumulator test - Chuck Scheve (AOGCC)
waived witnessing tests.
Fill conductor and check for leaks - pressure test mud lines to 3000 psi.
Spud well @ 1730 hours, drill from 109' to 176'.
Lost scribe mark - set back flex collars - scribe tools - RIH with flex
colars.
Gyro survey @ 87', MU Top drive and pump up MWD survey.
Drill from 176' to 539', survey with MWD. (oa) AST=2.3 ART=1.6
450 gpm I 900 psi
PUW I SOW I ROT WT = 50K.
Torque on I off = 3K 12K
12.00 DRILL DRLG SURFAC Drill 121/4" hole from 539' to 1474' (1395' tvd). ART=1.55 AST=6.65
460 gpm 11000 psi 25-35K WOB
PUW 90K SOW 75K ROT 80K
Torque onloff 6K /3K @ 80 RPM
9.00 DRILL DRLG SURFAC Drill from 1474' to 2044' (1742' tvd). ART=1.56 AST=4.6
460 gpm /1050 psi
PUW 90K SOW 70K ROT 85K (after sweep)
Torque onloff 6-7k 14K
While backreaming prior to connection @ 1948' torque increased to
8-10k, PUW 95k SOW 65K. Slid from 1948' to 1917' while mixing 40
bbls .2 ppb Baralift sweep. Pumped sweep while rotating last 30' of
stand - 85 rpm - increased rate from 460 gpm to 500 gpm.
0.50 DRILL CIRC SURFAC Pumped sweep around and circ to clean up hole. Observed increase in
cuttings with pipe rotation, additional moderate increase with sweep
back. Circulate untill cuttings began to reduce across shakers.
2.50 DRILL DRLG SURFAC Drill from 2044' to 2330' (1865 tvd). ART =.92 AST =.92
PUW 90K SOW 68k ROT 85K
504 gpm 11300 psi
Torque onloff 6-7k /4K
12.00 DRILL DRLG SURFAC Drill from 2330' to 3185' (2216' tvd) ART =5.96 AST =1.09
550 gpm /1950 psi
PUW 100K SOW 75K ROT 80K
Torque on/off 7K /5K
Had difficulty sliding from 2420' to 2475' do to sticky clays, average
'S(¡jþ .... PDª$ø}
'¢()ø~···· .
18:00 . 20:00 2.00 MOVE MOVE MOVE
20:00 - 21 :30 1.50 MOVE MOVE MOVE
21 :30 - 23:00 1.50 MOVE MOVE MOVE
23:00 - 00:00 1.00 MOVE MOVE MOVE
00:00 - 01 :00 1.00 MOVE POSN MOVE
01 :00 - 02:00 1.00 MOVE MOVE MOVE
02:00 - 05:00 3.00 MOVE MOVE MOVE
05:00 - 09:00 4.00 MOVE RURD RIGUP
09:00 - 11 :00 2.00 MOVE RURD RIGUP
11 :00 - 13:30 2.50 MOVE RURD RIG UP
13:30 - 13:45 0.25 MOVE SFTY RIGUP
13:45 - 14:00 0.25 MOVE RURD RIGUP
14:00 - 16:30 2.50 MOVE RURD RIG UP
16:30 - 17:00 0.50 MOVE RURD RIGUP
17:00 - 17:30 0.50 MOVE RURD RIGUP
17:30 - 18:45 1.25 DRILL DRLG SURFAC
18:45 - 19:00 0.25 DRILL DRLG SURFAC
19:00 - 19:45 0.75 DRILL SURV SURFAC
19:45 - 00:00 4.25 DRILL DRLG SURFAC
00:00 - 12:00
12:00 - 21 :00
21 :00 - 21 :30
21 :30 - 00:00
00:00 - 12:00
Start: 2/24/2003
Rig Release:
Rig Number:
Spud Date: 2/25/2003
End:
Group:
Printed: 4/3/2003 9:40:39 AM
)
)
ConocoPhillips Alaska.
Page 20f 12
12.00 DRILL DRLG SURFAC Rap 40 fph.Treated mud with BDF 263 and Con Det.
Pumped 40 bbls 11.2 ppg sweep with 0.25 ppb Baralift @ 2542',
observed moderate increase in cuttings with sweep back.
12.00 DRILL DRLG SURFAC Drill from 3185' to 4070' (2582' tvd). ART=8.0 AST=0.75
550 gpm I 2150 psi
PUW 105K SOW 73K ROT 85K
Torque onloff 9-10K 16-7K
Pumped 40 bbls 0.25 ppb Baralift sweep @ 3470', observed strong
increase in cuttings with sweep back.
Pumped 40 bbls 0.25 ppb Baralift sweep @ 3560', observed moderate
increase in cuttings with sweep back.
2.50 DRILL DRLG SURFAC Drill from 4070' to 4276' casing point (2667'*tvd). ART =1.67 AST =0
550 gpm I 2150 psi PUW 120K SOW 80K ROT 85K
Torque onloff 9K 1 7K @ 90 RPM
3.00 DRILL CIRC SURFAC Pumped 40 bbls sweep with 0.25 ppb Baralift, circ and cond mud 550
gpm 12100 psi, moderate increase in cuttings with sweep back.
Pumped 35 bbls 12.8 ppg wt (3.3 ppg over mud wt) sweep with 0.25
ppb Baralift increased rate to 600 gpm I 2250 psi observed large
increase in cuttings back with sweep. Both sweeps back @ gauge hole
volumes. Circ until! shakers clean.
Monitor well - static.
POH from 4276' to 2044' mostly 5-15K over, tight spots @ 4100' and
4050' 35k, wiped clean. Began swabbing well on last stand pulled 2140'
to 2044'. Actual time 0900 hrs.
Had several interuptions pulling pipe due to trip tank unable to keep
hole full. Trip tank continued to operate after keeping it completely full
by refilling after each five stands pulled.
Backream slowly from 2140' to 2044' 500 gpm 11500 psi 190 rpm
moderate cuttings across shakers through 1.5 x BU.
POH 10/20 K over from 1860' to 1700' , 0-5k over to 86'. Flow check
well at HWDP, static.
Lay down remainder of BHA, clear tools from rig floor.
RU 95/8" slips, elevator,fiII up tool, long bails and GBR tongs.
Held safety and opts meeting with crew.
Mu 9 5/8" shoe track and circ to check floats, all joints 40#, L-80 BTC
casing. PUW 100K SOW 70K. RIH, set down 20K @ 1790' (46 jts ran)
Wash down from 1775' to 2006' - 308 gpm 1387 psi slight effort except
for 1964' to 1966' - 30 min to wash 2'. PUW 105K SOW 70K.
RIH to 4002' @ midnight (104) jts total - no problems.
Run casing to 4235', MU landing joint and land casing in wellhead.
Lay down fill up tool and MU cement head.
Establish circ @ 3 bpm 1 360 psi, staged pumps up to 8 bpm 1 660 psi,
Circ and cond mud for cementing - reduced wt. fl 9.7ppg V 9.5 ppg, vis
fl 248 to 49, PV f/28 V 22, yp f/52 V 16. Final circ rate 8.0 bpm 1500
psi last 100 bbls pumped with nutplug marker. PJSM with all parties.
2.25 CEMENT PUMP SURFAC Line up to cementers - pumped 5 bbls of CW 100 - tested lines to 3000
psi. Pumped 45 bbls of CW 100 - dropped botton plug. Pumped 46 bbls
of 10.5 ppg Mudpush XL with 2 gals of dye marker - 506 bbls of 10.8
ppg ASLite lead slurry and 156 bbls of 12.0 ppd Lite Crete tail slurry.
1.00 CEMENT DISP SURFAC Dropped top plug - dislpaced with 20 bbls of FW from cementers -
switched to rig pups and displaced with 9.5 ppg mud - 279 bbls @ 8.0
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
38-08
38-08
ROT - DRILLING
N1268@ppco.com
Nabors 7ES
',' ......:...: ..........., S' b
'Þ:fÔrÌJ+'mÖ¡::JâQµf$ .11¢Þdè ...·¢ø\~ '¡ '~hªsß:
2/27/2003
00:00 - 12:00
12:00 - 00:00
2/28/2003
00:00 - 02:30
02:30 - 05:30
05:30 - 05:45 0.25 DRILL OBSV SURFAC
05:45 - 08:00 2.25 DRILL TRIP SURFAC
08:00 - 09:00 1.00 RIGMNT OTHR SURFAC
09:00 - 09:45 0.75 DRILL REAM SURFAC
09:45 - 13:00 3.25 DRILL TRIP SURFAC
13:00 - 14:00 1.00 DRILL PULD SURFAC
14:00 - 15:30 1.50 CASE RURD SURFAC
15:30 - 15:45 0.25 CASE SFTY SURFAC
15:45 - 19:00 3.25 CASE RUNC SURFAC
19:00 - 20:30 1 .50 CASE OTHR SURFAC
20:30 - 00:00 3.50 CASE RUNC SURFAC
3/1/2003 00:00 - 00:45 0.75 CASE RUNC SURFAC
00:45 - 01 :15 0.50 CEMENT PULD SURFAC
01 :15 - 04:30 3.25 CEMENT CI RC SURFAC
04:30 - 06:45
06:45 - 07:45
Start: 2/24/2003
Rig Release:
Rig Number:
Spud Date: 2/25/2003
End:
Group:
Printed: 4/3/2003 9:40:39 AM
) )
ConocoPhillips Alaska Page 3 of 12
Operations Summary Report
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
38-08
38-08
ROT - DRILLING
N1268@ppco.com
Nabors 7ES
Start: 2/24/2003
Rig Release:
Rig Number:
Spud Date: 2/25/2003
End:
Group:
3/1/2003 06:45 - 07:45 1.00 CEMENT DISP SURFAC bpm 1230·838 psi - 11 bbls @ 6.0 bpm I 675 psi· 8 bbls @ 4.0 bpm I
541 psi. Bumped plugs to 1100 psi - floats held - CI P @ 0730. Had
good returns throughout with 160 bbls of 10.8 ppg cement returns to
surface.
Pipe hung up with 260 bbls of lead cement around shoe, unable to land
hanger per plan· 3' high - FS @ 4263', FC @ 4182.
07:45 - 08:45 1.00 CEMENT PULD SURFAC Flush Conductor and flowline RD cement head.
08:45 - 09:15 0.50 CASE SFTY SURFAC Held safety meeting in preparation for setting slips on casing.
09:15 - 11 :30 2.25 CASE NUND SURFAC Disconnect dresser sleeve and cut 14 inches off of 20" riser to provide
clearance for slip installation.
11 :30 - 15:00 3.50 CASE OTHR SURFAC PU surface stack - center pipe and install slips - set slips with 120K
string wt. Rough cut 9 5/8" casing - set stack down and LD landing jt-
casing hanger and cuttoff joint.
15:00·16:30 1.50 CASE NUND SURFAC ND 20" Diverer system and riser.
16:30 - 17:30 1.00 CASE OTHR SURFAC Assist welder in cellar untill 9 5/8" transition nipple in place on casing.
17:30 - 20:30 3.00 DRILL PULD SURFAC Clear casing equipment from rig floor· change out long bails to drilling
bails - install 13 5/8" drip pan extension. Changing pump liners to 5".
20:30 . 22:30 2.00 DRILL PULD SURFAC PU and stand back 45 joints of drill pipe, Actual time midnight.
22:30 . 00:00 1.50 DRILL PULD SURFAC Loss of efficiency due to using mousehole by ironroughneck because of
cooling transition nipple in cellar.
3/2/2003 00:00 - 02:00 2.00 DRILL PULD SURFAC PU and stand back 48 jts of 5" drill pipe. Installed casing head and
tubing spool onto transition nipple while picking up drill pipe.
02:00 - 02: 15 0.25 WELCTL SFTY SURFAC PJSM - NU BOPE.
02:15 - 05:30 3.25 WELCTL NUND SURFAC NU BOPE and riser, tested M/M seal on wellhead to 1000 psi - 10 min.
05:30 - 09:00 3.50 WELCTL BOPE SURFAC Test BOPE: Annular Preventer 250/3500 psi. Pipe and Blind rams,
choke and kill line, manifold, TD, and floor safety valves 250/5000.
**Tested choke manifold valves while NU BOP stack.
John Crisp witnessed BOP and gas alarm tests.
09:00 - 09:30 0.50 DRILL PULD SURFAC Lay down test plug and install wear bushing.
09:30 - 10:30 1.00 DRILL OTHR SURFAC Set in mousehole, pick up tools and clean up rig floor.
10:30 - 12:30 2.00 DRILL PULD SURFAC PU and stand back 24 jts of drill pipe - LD 6 jts hwdp.
12:30 - 15:30 3.00 DRILL PULD SURFAC MU BHA #3 - initialize tools.
15:30 - 17:00 1.50 DRILL TRIP SURFAC Shallow test tools - PJSM - load sources - RIH with Flex collars and
hwdp.
17:00 - 20:30 3.50 DRILL TRIP SURFAC RIH -PU 108 joints of drill pipe, set down 10K @ 4134'.
20:30 - 21 :00 0.50 CEMENT COUT SURFAC MU Top drive and wash down to 4156'.
21 :00 - 21 :30 0.50 CASE CIRC SURFAC Circ and cond cement cotaminated mud - 450 gpm 11050 psi 160 rpm.
21 :30 - 23:00 1.50 CASE DEQT SURFAC Set back one stand - RU and test casing to 2500 psi - RD test manifold
- blow down lines.
23:00 - 00:00 1.00 CEMENT DSHO SURFAC Clean out cement, drill wiper plugs and float collar @ 4182', drill out
cement to 4184'.
3/3/2003 00:00 - 01 :00 1.00 CEMENT DSHO SURFAC Drill out cement from 4184' - shoe @ 4263', clean out rathole and drill
20' of new hole to 4296'.
01 :00 - 02:00 1.00 DRILL CIRC SURFAC CBU, change well over to 8.9 ppg LSND mud 550 gpm 1 1650 psi I 60
rpm
02:00 - 03:00 1.00 CEMENT LOT SURFAC RU and perform LOT = 17.9 ppg. RD, blow down lines.
03:00 - 12:00 9.00 DRILL DRLG INTRM1 Drill from 4296' to 5011' (2977' tvd). ART =4.69 AST =0.23 PUW 145K
SOW 60K ROT 90K
550 gpm 1 1600 psi MWT =8.9 ECD=10.9
Torque on/off 10K 19K
Pumped 40 bbls 11.9 ppg sweep @ 4726', large increase in cuttings
back with sweep.
12:00 - 00:00 12.00 DRILL DRLG INTRM1 Drill from 5011' to 6153' (3455' tvd) ART =7.29 AST =0.37 PUW 160K
Printed: 4/3/2003 9:40:39 AM
.)
)
~~l~' Phase!
12.00 DRILL DRLG INTRM1 SOW 64K ROT 95K
550 gpm 12100 psi MWT =9.0 ppg ECD=11.3 ppg
Torque onloff 12K 111 K
Pumped 40 bbls sweeps, 3 ppg over MWT @ 5125', 5583', and 6058'.
Sweeps @ 5125' and 5583' had a large increase in cuttings back.
Sweep @ 6058' had a moderate increase in cuttings with sweep back.
17.25 DRILL DRLG INTRM1 Drill, Slide & Survey Per Directional Plan from 6,153' to 7,675'MDI
4,082' TVD (1,552') ART 9.27 Hrs, AST .52 Hrs. 1 0-25K WOB, 115
Rpm's, 535 Gpm's, Off Btm Press 2,100 Psi, On Btm 2,250 Psi, Off
Btm Torque 11.5K Ft#'s, On Btm 12K Ft#'s, Rot Wt 102K, PU Wt 185K,
On Wt 70K, Ave BGG 80 Units, Pumped Wt'd Sweeps at 3 ppg over
MW @ 6,438',7,010' with Large Amount of Cuttings Back, 70-80%
Increase on Both Sweeps, Pumped Sweep @ 7,580' with 30% Increase
in Cuttings
0.50 DRILL OTHR INTRM1 Shakers Blinding Off Due to EP Mud Lube, Worked Pipe, Reduced Circ
Rate And Cleaned Off Shakers
6.25 DRILL DRLG INTRM1 Drill & Survey from 7,675' to 8,246' MD/4,326' TVD (571') ART 3.03
Hrs, -0- Hrs Sliding, 10-25K WOB, 100-115 Rpm's, 535 Gpm's, Off Btm
Press 2,250 Psi, On Btm 2,350 Psi, Off Btm Torque 12.5K Ft#'s, On
Btm 13K Ft#'s, Rot Wt 11 OK, PU Wt 185K, On Wt 75K, Ave Bgg 90
Units,· Max Gas 170 Units, Pumped Wt'd Sweep at 3 ppg Over Mw @
8,090' and had 70-80% Increase in Cuttings, Raised Mw from 9.3 ppg
to 10.0 ppg per Mud Wt Up schedule
Drill, Slide & Survey from 8,246' to 8,532' MD/4,440' TVD (286') ART
1.29 Hrs, AST .17 Hrs
Repaired Epoch PVT Unit, Found Loose Conn on Back of Unit,
Rebooted Computer
Drill, Slide & Survey from 8,532' to 10,214' MD/5, 151' TVD (1,682')
ART 8.36 Hrs, AST 1.15 Hrs 1 0-25K WOB 100 Rpm's, 540 Gpm, Off
Btm Press 2,500 Psi, On Btm 2,850 Psi, Off Btm Torque 17K Ft#'s, On
Btm 18K Ft#'s, Rot Wt 123K, PU Wt 220K, On Wt 80K, Ave BGG 100
Units, Pumped Wt'd Sweeps 3 ppg Over MW at 9,007' with 70-80%
Increase in Cuttings and at 9,958' with 50% Increase in Cuttings, Began
Raising MW to 10.6 ppg Per Wt Up Schedule
0.50 DRILL CIRC INTRM1 Circ and cond flocculated mud 550 gpm 12950 psi 1115 rpm - mud out
200+ vis - treated mud with water, Carbonex and CF desco, large
volume of cuttings across shakers for 15 min. final rate 550 gpm 12625
psi.
4.00 DRILL DRLG INTRM1 Drill, Slide & Survey from 10,214' to 10,526' MOl 5,294' TVD (312') ART
1.88 Hrs, AST .53 Hrs, 15-25K WOB, 100 Rpm's, 529 Gpm, Off Btm
Press 2,600 Psi, On Btm 2,750 Psi, Off Btm Torque 18K Ft#'s, On Btm
18.5K Ft#'s Rot WT 126K, PU Wt 240K, On Wt 80K, With 10.6 ppg
Mud ECD Ave 12.2 ppg, BGG Ave 90 Units
Drill, Slide & Survey from 10,526 to 10,716' MOl 5,395' TVD (190') ART
.95 Hrs, AST .74 Hrs, Added 565 bbls of 11.9 ppg New Whole Mud to
System While Drlg Ahead for Weighting Up System
Circ Hole at Reduced Rate While Cleaning & Raising Shakers, Had a
Large Amount of Cuttings Back with New Mud at Surface
Drill, Slide & Survey from 10,716' to 11,384' MD/5,802' TVD (668'), ART
5.17 Hrs, AST 2.21 Hrs, 1 0-25K WOB, 100 Rpm's, 500 Gpm, Off Btm
Press 2,650 Psi, On Btm 2,750 Psi, Off Btm torque 18.5K Ft#'s, On
Btm 18.5K Ft#'s, Rot Wt 140K, PU Wt 250K, On Wt 95K, Ave BGG 60
Units, Max Gas 150 Units, Mud Wt after Adding New Mud 10.8 ppg,
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
3S-08
38-08
ROT - DRILLING
N 1268@ ppco.com
Nabors 7E8
3/3/2003
12:00 - 00:00
3/4/2003
00:00 - 17:15
17:15 - 17:45
17:45 - 00:00
3/5/2003 00:00 - 02:30 2.50 DRILL DRLG INTRM1
02:30 - 03:00 0.50 RIGMNT RGRP INTRM1
03:00 - 19:30 16.50 DRILL DRLG INTRM1
19:30 - 20:00
20:00 - 00:00
3/6/2003 00:00 - 03:00 3.00 DRILL DRLG INTRM1
03:00 - 03:30 0.50 DRILL CIRC INTRM1
03:30 - 14:30 11.00 DRILL DRLG INTRM1
Start: 2/24/2003
Rig Release:
Rig Number:
Spud Date: 2/25/2003
End:
Group:
Printed: 4/3/2003 9:40:39 AM
) )
Conoc'oPhiHips Alaska Þage 5 of 12
Operations Summary Report
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
3S-08
3S-08
ROT - DRILLING
N1268@ppco.com
Nabors 7ES
Start: 2/24/2003
Rig Release:
Rig Number:
Spud Date: 2/25/2003
End:
Group:
'." :: ..... '. '.'
{ht. ·.!.···.o..·.·.:.u.:.:.·.t.·.·.:8.'. <.......... ·.··..'.·<3.·.·.···..·.·.0.:.'.:.ô.··.·...·.é.;.·· ·.l.:¡PµP· ".I?...·..·..h.·... a.·.···.·.·..s. ". e.: i.'.':.'
. .. . ··:.ø·øø~·¡:
3/6/2003 03:30 - 14:30 11.00 DRILL DRLG INTRM1 Began Raising MW to 11.9 ppg per Mud Program, Began Circ Out
Contaminated mud
14:30 - 18:00 3.50 DRILL CIRC INTRM1 Circ Out Contaminated Mud, Circ & Cond Mud to 11.9 ppg, Determined
Barite Used for Wt Up Had Been Contaminated with Cement. Circ @
500 Gpm's @ 2,600 Psi
18:00 - 19:15 1.25 DRILL DRLG INTRM1 Drill, Slide & Survey from 11,384' to 11,450' MD/5,849' TVD (66') ART
.43 Hrs, AST .42 Hrs, 10-15K WOB, 100 Rpm's, 500 Gpms, Off Btm
Press 2,650 Psi, on Btm 2,750 Psi, On & Off Btm Torque 19K Ft#'s,
Rot Wt 140K, PU Wt 250K, Dn Wt 95K, Ave Bgg 60 Units, 11.9 ppg Mw
with 13.23 ECD
19:15 - 20:30 1.25 DRILL CIRC INTRM1 Circ Btms Up & Cond Mud, Ave Bgg 60 Units, Max Gas 100 Units, Circ
@ 500 Gpm 2,600 Psi, 115 Rpm's with 11.9 ppg Mud In & Out
20:30 - 00:00 3.50 DRILL WIPR INTRM1 Monitored Well-Static, Began POOH Ave 275K PU Wt, Pulled 25K
Over Drag At 10,720', Base of Morraine Sand, Back Reamed Thru
Sand from 10,720' to 10,526', Cont POOH from 10,526' to 9,672' with
20K over Ave Drag
31712003 00:00 - 05:30 5.50 DRILL WIPR INTRM1 Cont Wiping Hole to Shoe, Pulled 25K Over at 9,672', Backreamed Out
F/9,672' to 9,578', Cont POOH to 4,251' with No Problems
05:30 - 07:00 1.50 RIGMNT RSRV INTRM1 Cut & Slip 106' of Drlg Line, Found Line to Have Broken Strands, Slip &
Cut add 240' (346' Total) Drlg Line
07:00 - 08:00 1.00 RIGMNT RSRV INTRM1 Serviced Top Drive & Crown
08:00 - 11 :00 3.00 DRILL WIPR INTRM1 Est Circ Outside of Shoe at 4,300' to Calibrate Sperry Sun Tool, TIH to
8,628', Took Wt @ 6,754' Wiped Back Thru & Ck Ok, No Other
Problems RIH
11 :00 - 11 :30 0.50 DRILL CIRC INTRM1 Est Circ & Circ Hole Prior to RIH to Btm, Circ @ 500 Gpm's, 2,500 Psi,
50 Rpm's, Rot Wt 125K with 15K Ft#'s Torque
11 :30 - 13:30 2.00 DRILL WIPR INTRM1 Cont TIH to Btm with No Problems
13:30 - 15:30 2.00 DRILL CIRC INTRM1 Pumped Barolift Sweep & Circ Hole Clean, Sweep Came Up on Calc
Strokes, Circ @ 500 Gpm's, 2,800 Psi, Max Gas 740 Units @ Btms Up
And Dropped Out in Several Min, Ave 60 Units Bgg
15:30 - 18:30 3.00 DRILL DRLG INTRM1 Drill 8 1/2" hole From 11,450' to 11,642' MD/5,986' TVD (192') ART 2.5
Hrs, AST -0-, Control Drilled Thru KUP "C" Sand @ 1 OO'lHr for Real
Time Logs, 500 Gpm's, Off Btm Press 2,600 Psi, On Btm 2,800 Psi, Off
Btm Torque 20K Ft#'s, On Btm 21K Ft#'s, Rot Wt 145K, Pu Wt 70K, Dn
Wt 95K, Ave 60 Units BGG, Max Gas From KUP sand 270 Units,
Added 2 ppb LCM While drlg Thru Sand and Had Full Returns,
Decision Made to Plugback and Sidetrack Well.
18:30 - 22:00 3.50 DRILL CIRC INTRM1 Backreamed Out of Hole While Circ 2 Btms Up from 11,642' to 10,420',
Thru Morraine Sand, No Problems, Backreamed Out at 80 Rpm's, 450
Gpm, 2,100 Psi, 165K Up Wt, Ave 20 Units BGG and 20K Ft#'s Torque
22:00 - 00:00 2.00 DRILL TRIP INTRM1 Monitored Well-Static, Pumped Dry Job & POOH to 8,434' with No
Problems
3/8/2003 00:00 - 03:45 3.75 DRILL TRIP INTRM1 Cont POOH From 8,434', Pumped Dry Job @ 8,326', Worked Thru
Tight Spot @ 7,095' POOH to Shoe to 4,251', Monitored Well-Static
03:45 - 04:30 0.75 DRILL OTHR INTRM1 Attempt to Turn Kelly Hose to Move Out Of Derrickmans Way and
Unable to Turn, Having to Swing Stand of Pipe Around Hose
04:30 - 07:00 2.50 DRILL TRIP INTRM1 POOH to BHA #2, LD 21 Jts of 5" DP
07:00 - 08:30 1.50 DRILL TRIP INTRM1 POOH & LD 17 Jts HWDP, Jars and 2 Flex Dc's, Cleaned Rig Floor
08:30 - 12:00 3.50 DRILL TRIP INTRM1 Held PJSM, Removed Radioactive Source, LD 1-Flex Dc, Download
MWD and LD BHA
12:00 - 15:00 3.00 ABANDf\ PULD ABANDN RU GBR Tbg Tongs & Handling Tools, PU & MU 30 Jts of 31/2" 9.3#
L-80 EUE Tbg for Cmt Stinger with Bull Nose Circ Sub
15:00 - 20:00 5.00 ABANDf\ TRIP ABANDN Tlh with 31/2" Tbg Stinger on 5" DP to 11,557', Est Circ & Washed 85'
Printed: 4/3/2003 9:40:39 AM
.)
)
5.00 ABANDt\ TRIP ABANDN to Btm, 11,642' with No Problems
3.00 ABANDt\ CIRC ABANDN Circ & Cond Mud for Setting Cmt Plug, Max Gas on Btms Up 380 Units
with No Gas Cut, Circ Hole Clean with 11.8 ppg Mud at 500 Gpm, 1,700
Psi with 21 OK Pu Wt & 85K Dn Wt, Held PJSM on Setting Cmt Plug &
Batch Mixed Cmt
1.00 CEMENT PUMP ABANDN RU Dowell, Pumped 5 bbls of 8.3 ppg CW 100, Found Low Torque
Valve Leaking, Changed Out Same, Tested Lines to 3,500 Psi & Ck
Ok, Pumped Add 5 bbls 8.3 ppg CW 100 Followed by 42 bbls, 203 sxs
of Class G CmtW/Add @ 15.8 ppg & 1.16 Yield, Pumped 1.5 bbls of
CW 100 Behind, Turned Over to Rig And Displaced Cmt with 181 bbls
of 11.8 ppg Mud to Balance Plug, CIP @ 24:00 Hrs Est T.O.C @
11 ,200'
POOH Slow from 11,642' to 10,765' after Setting Cmt Plug on Btm, Circ
100 bbls of 11.8 ppg Mud Down DP to Clear Same
POOH 15 Stds Wet to 9,340', Pumped Dry Job, Blow DownTop Drive,
Cont POOH to 5,156'
Pumped & Spotted 12.8 ppg High Vis Pill from 5,156' to 4,870'
POOH 3 Stds to 4,870'
Circ & Cond Mud for Kick-Off Cmt Plug, At Btms Up Did Not See Any
Weighted Pill, After Circ Hole Clean, MU Head Pin With TIH Valve and
Cont Circ Hole While Dowell Batch Mixed Cmt, Circ @ 500 Gpm, Initial
Pres 970 Psi, Final Press 920 Psi, Rot Pipe 15 Rpms with 5K Ft#'s
Torque, 11.8 ppg Mud in & Out
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
3S-08
3S-08
ROT - DRILLING
N1268@ppco.com
Nabors 7ES
.. .... . ..
.·~tÖ@:fhta,I~~~[~!,;:çÂ~~t!'~Q~él,
,".. . . '. .
.:...... ....: ......:..
..·::pb~s~'r
3/8/2003
15:00 - 20:00
20:00 - 23:00
23:00 - 00:00
3/9/2003 00:00 - 01 :00 1.00 CEMENTTRIP ABANDN
01 :00 - 04:45 3.75 ABANDt\ TRIP ABANDN
04:45 - 05:00 0.25 ABANDt\ CIRC ABANDN
05:00 - 05:15 0.25 ABANDt\ TRIP ABANDN
05:15 - 07:30 2.25 ABANDt\ CIRC ABANDN
Start:
Rig Release:
Rig Number:
2/24/2003
Spud Date: 2/25/2003
End:
Group:
0.75 CEMENT PLUG ABANDN RU Dowell, Pumped 5 bbls 8.3 ppg CW1 00 Spacer, Press tested Lines
to 3,500 Psi, Pumped 10 bbls Add CW100, Pumped 59 bbls, 328 SXS
of Class G Cmt @ 17.0 ppg and 1.01 Yield with Add, Follow with 3 bbls
CW100, Turned over to Rig Pump and Displaced Cement with 63 bbls
of 11.8 ppg Mud to Balance Plug, CIP @ 08:00 Hrs, Est TOC @ 4,203'
POOH slow with 7 Stds Dp to 4,203'
Circ Btms Up, Had 60 bbls of Cmt Contaminated Mud Back at Btms
Up, circ Clean at 580 Gpm, 1,070 Psi, 20 rpm's, 4K Ft#'s torque, St Wt
72K
Pumped Dry Job, Blow Down Top Drive, POOH & Stood Back 7 Stds
DP for 85 Stds in Derrick, POOH LD 84 jts 5" dp and 30 Jts of 31/2"
Stinger
07:30 - 08: 15
08:15 - 09:00 0.75 ABANDt\ TRIP ABANDN
09:00 - 09:30 0.50 ABANDt\ CIRC ABANDN
09:30 - 15:30 6.00 ABANDt\ TRIP ABANDN
15:30 - 16:00 0.50 ABANDt\ RURD ABANDN
16:00 - 16:30 0.50 WELCTL OTHR PROD
16:30 - 20:00 3.50 WELCTL BOPE PROD
~ 20:00 - 20:30 0.50 WELCTL OTHR PROD
~/D 20:30 - 20:45 0.25 RIGMNT RGRP PROD
0' 20:45 - 23:00 2.25 DRILL PULD PROD
23:00 - 23:15 0.25 DRILL SFTY PROD
~ 23:15 - 00:00 0.75 DRILL PULD PROD
3/10/2003 00:00 - 01 :30 1.50 DRILL TRIP PROD
01 :30 - 03:30 2.00 DRILL TRIP PROD
~
Note: John Spaulding with AOGCC Waived Witnessing of BOP Test,
Sim-Op Tested Choke Manifold to 250 Psi Low & 5,000 Psi High While
LD Dp & Tbg
RD GBR Tbg Equip, Cleared Rig Floor and Turned Kelly Hose
Pulled Wear Bushing
RU & Tested BOPE, Tested Rams, Valves and 7" Test Jt to 250 Psi
Low and 5,000 Psi High, Tested Annular to 250 Low & 5,000 Psi High,
Good Test, RD Test Tools
Installed Wear Bushing
Changed Out Flow Riser/Bell Nipple
PU & MU BHA #3, Orient BHA, Upload MWD & Surface Test
Held Safety Mtg with Crew & Sperry Sun on Loading Radioactive
Sources
Loaded Radioactive Sources & Cont PU & RIH with BHA #3 to 373'
Fin PU & MU BHA #3, PU 23 Jts 5" HWDP & Jars
Cont TIH with BHA #3 and tagged TOC at 4,210' (Est TOC @ 4,203')
Printed: 4/3/2003 9:40:39 AM
)
)
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
3/10/2003
03:30 - 04:30
04:30 - 12:00
12:00 - 18:45
18:45 - 19:00
19:00 - 00:00
3S-08
3S-08
ROT - DRILLING
N 1268 @ ppco.com
Nabors 7ES
:'H?~~§;:~i8~~~<i'~ó~@! iRh~ª~:!,:
1.00 DRILL REAM PROD
7.50 DRILL DRLG PROD
6.75 DRILL DRLG PROD
0.25 DRILL CIRC PROD
5.00 DRILL DRLG PROD
3/11/2003 00:00 - 01 :00 1.00 RIGMNT RGRP PROD
01 :00 - 02:00 1.00 DRILL DRLG PROD
02:00 - 02:15 0.25 RIGMNT RGRP PROD
02:15 - 07:45 5.50 DRILL DRLG PROD
07:45 - 08:15
08:15 - 17:30
17:30 - 17:45
17:45 - 00:00
0.50 DRILL CIRC PROD
9.25 DRILL DRLG PROD
0.25 RIGMNT OTHR PROD
6.25 DRILL DRLG PROD
Start: 2/24/2003
Rig Release:
Rig Number:
Spud Date: 2/25/2003
End:
Group:
Cleaned Out Med to Hard Cement from 4,210' to 4,300', Displaced 11.8
ppg Mud in Hole Over to New 8.9 LSND Mud While Cleaning Out Cmt,
Circ at 500 Gpm's, 975 Psi.
Drill, Slide & Survey Per Directional Plan from 4,300' to 4,957' MOl
3,108' TVD, ART 1.98 Hrs, AST 2.43 Hrs, 10-20K WOB, 100 Rpm's,
550 Gpm, Off Btm Press 1,625 Psi, On Btm 1,825 Psi, Off Btm torque
11 K Ft#'s, On Btm 12.5K Ft#'s, Rot Wt 100K, PU Wt, 158K, Dn Wt
70K, Ave BGG 15 Units, 9.2 ppg MW with 10.7 ECD, Pumped
Weighted Sweep 3 ppg Over MW at 4,816', Had 70-80% Increase in
Cuttings
Drill, Slide & Survey from 4,957' to 5,579', ART 2.97 Hrs, AST 1.74,
Raised Mw from 9.2 ppg to 9.6 ppg, Pumped Weighted Sweep 3 ppg
Over MW at 5,140', Had 70-80% Increase in Cuttings, Pumped
Weighted Sweep 3 ppg Over MW at 5,412', Had 30% Increase in
Cuttings
Fin Circ Btms Up After Backreaming Prior to Conn, Circ to Lower ECD,
Lowered ECD from 12.8 to 11.0 ppg with 9.6 ppg MW
Drill, Slide & Survey from 5,579' to 5,959' MDI 4,050' TVD, ART 1.02
Hrs, AST 1.85 Hrs, 1 0-25K WOB, 100 Rpm's, 550 Gpm, Off Btm Press
1,890 Psi, On Btm 2,070 Psi, Off Btm torque 13K Ft#'s, On Btm 13K,
Rot Wt 123K, PU Wt 205K, Dn Wt 83K, Ave 20 Units BGG, 10.15 Mw
In with 11.8 ECD,
Replaced Swab on #1 Pump, Worked Pipe & Circ Hole at 250 Gpm,
650 Psi
Drill, Slide & Survey Per Directional Plan from 5,959' to 6,054' TVD
(95'), ART .2 Hrs, AST .5 Hrs
Replaced Hose on Rod Oiler on #1 Mud Pump, Worked Pipe & Circ
Hole
Drill, Slide & Survey from 6,054' to 6,529' MDI 4,578' TVD (475') ART
1.19 Hrs, AST 1.89 Hrs, 10-20K WOB, 100 Rpm's, 550 Gpm, Off Btm
Press 2,150 PSi, On Btm 2,250 PSi, OfflOn Btm torque 16K Ft#'s, Rot
Wt 133K, PU Wt, 232K, Dn Wt 90K, 10.2 MW with 11.6 ECD, Top of
Morraine Sand 7,380' MD, 5,243' TVD, Max Gas 700 Units, Ave Bgg
50 Units, Pumped Weighted Sweep at 3 ppg Over Mw at 6,083', Had
70-80% Increase in Cuttings, Sweep @ 6,510 Had 70-80% Increase
Fin Circ Out Weighted Sweep Pumped at 6,510', ECD Went from 11.55
to 11.35, Max ECD 11.98 with 10.2 MW
Drill, Slide & Survey from 6,529' to 7,478' MDI 5,320' TVD (949') ART
4.33 Hrs, AST 1.46 Hrs, 1 0-20K WOB, 100 Rpm's, 540 Gpm, Off Btm
Press 2,370 PSi, On Btm 2,600 PSi, Off Btm torque 16.5K Ft#'s, On
Btm 15.5K Ft#'s, Rot Wt 140K, PU Wt, 250K, On Wt 95K, 10.5 MW
with 12.5 ECD, Max Gas 1,140 Units, Ave Bgg 120 Units, Pumped
Weighted Sweep at 3 ppg Over Mw at 6,909' Had 30% Increase in
Cuttings, Sweep @ 7,208' Had 70-80% Increase, Rig Off High Line
Power @ Hrs 16:30 Hrs
Put Rig Back On Highline Power, Rig OFF Highline for 1 1/4 hrs
Drill, Slide & Survey from 7,478' to 7,954' MDI 5,689' TVD, (476'), ART
3.53 Hrs, AST .28, 1 0-20K WOB, 110 Rpm's, 520 Gpm, Off Btm Press
2,340 PSi, On Btm 2,770 Psi, Off Btm Torque 17K Ft#'s, On Btm 18K
Ft#'s, Rot Wt 148K, PU Wt 265K, ON Wt 95K, Ave BGG 150 Units,
Max Gas 990 Units, 11.3 ppg MW, ECD 13.2 ppg Top of HRZ 7,714'
MOl 5,501' TVD, Base of HRZ 7,958' MOl 5,693' TVO, Pumped
Weighted Sweep @ 7,477', Had 50% Increase in Cuttings
Printed: 4/3/2003 9:40:39 AM
)
)
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
3S-08
3S-08
ROT - DRILLING
N1268@ppco.com
Nabors 7ES
."...........,..<. S h ...
··LJ······ . ...... ·:.t:'.':.·.'o..··.'.',.··.,¡i., ,·.......·e·.·'..·..·.·, ,.'.iÜ~<i~h..···.. ........
i:~i,:;()urs:,: \J u :C(j)q~,i;.t'~~~, .'.
Start: 2/24/2003
Rig Release:
Rig Number:
Spud Date: 2/25/2003
End:
Group:
3/12/2003 00:00 - 02:30 2.50 DRILL DRLG PROD Drill from 7,954' to 8,145' MD/5,843' TVD, (191') ART 1.4 Hrs AST -0-,
20-25K WOB, 110 Rpm's, 530 Gpm, Off Btm Press 2,350 Psi, On Btm
2,770 Psi, Off Btm Torque 17K Ft#'s, On Btm 18K Ft#'s, Rot 149K, PU
275K, Dn Wt 95K, Ave BGG 150 Units, Pumped Hi Vis Sweep with
50% Increase in Cuttings
02:30 - 05:00 2.50 DRILL CIRC PROD While Circ Hole for Wiper Trip had a Drop In DP Press, Checked
Surface Lines and Cleaned Pump Screens with No Change, Init Circ
Press @ 530 Gpm, 2,350 Psi, Final Press 1,850 Psi (500 Psi Drop)
05:00 - 09:00 4.00 DRILL TRIP PROD Began POOH Looking for Washout, Tigh Coming Off Btm, Pumped Out
10 Stds to Above Top of Morraine Sand @ 7,380', Cont POOH WIO
Pumping & Found Washout on 14th Std Out, Washed out in Neck Area
Below Box, LD Stand
09:00 - 09:30 0.50 DRILL CIRC PROD Circ Btms Up from 6,800', No Increase In Cuttings on Btms Up, Circ at
500 Gpm, 2,236 Psi, 120 Rpm's with 17.5K Ft#'s of Torque
09:30 - 12:00 2.50 DRILL WIPR PROD Cont POOH to Shoe, Had to Pump Thru Tight Spot at 6,674', Worked
Back Thru with No Problems, No Other Problems POOH to Shoe,
Cleaned Rig Floor after Wet Trip
12:00 - 13:00 1.00 RIGMNT RSRV PROD Monitored Well-Static, Serviced Rig & Top Drive
13:00 - 14:00 1.00 RIGMNT RSRV PROD Cut & Slip 108' of Drlg Line
14:00 - 16:00 2.00 DRILL WIPR PROD TIH to 8,049', Washed 96' to Btm, 8,145' with No Problems
16:00 - 18:00 2.00 DRILL CIRC PROD Pumped Hi Vis Sweep & Circ Hole Clean After Wiper Trip, Max Gas at
Btms Up 1,330 Units and Fell Off in Less than 10 Min, Ave Bgg 100
Units, Had Little Change in Cuttings from Sweep
18:00 - 22:30 4.50 DRILL DRLG PROD Drill from 8,145' to 8,475' MD/6, 116 TVD (330') T.D., ART 2.98 Hrs,
AST -0-, 15-25K WOB, 110-115 Rpm's, Control Drilled Thru KUP "C" @
100'/Hr, Top of Sand 8,168' MD/5,862' TVD, Base of Sand at 8,187'
MDI 5,878' TVD, 500 Gpm, Off Btm Press 2,200 psi, On Btm 2,400 psi,
Off Btm Torque 22.5K Ft#'s, On Btm 22K Ft#'s, Max Gas from Sand
520 Units, Ave Bgg 125 Units, 11.3 ppg MW, ECD Ave 12.4, Max 12.8
ppg, Rot Wt 160K, Up Wt 300K, Dn Wt 95K, Decision Made to
Abandon Lower Portion of Wellbore & Sidetrack
22:30 - 00:00 1.50 DRILL REAM PROD Pumped Hi Vis Sweep, Backreamed Out While Circ Out Sweep,
Backreamed Out from 8,475' to 7,954', Circ at 500 Gpm, 2,300 Psi, 100
Rpm's with 20K Ft#'s Torque, Had 50% Increase in Cuttings Back from
Sweep and Cleaned Up While Backreaming
3/13/2003 00:00 - 07:30 7.50 DRILL TRIP PROD POOH from 7,954' to 6,149' with No Problems, Pumped Dry Job, &
Cont POOH to BHA, No Problems on Trip Out
07:30 - 07:45 0.25 DRILL SFTY PROD Held PJSM with Sperry Sun on LD BHA & Radioactive Sources
07:45 - 11 :30 3.75 DRILL TRIP PROD LD BHA & Removed Radioactive Sources, Downloaded MWD, LD 2
Flex Dc's, Cleaned Rig Floor
11 :30 - 14:00 2.50 ABANDt\ PULD ABANDN RU GBR Tbg Tongs & Handling Tools, PU & MU 30 Jts of 31/2" 9.3#
L-80 EUE Tbg for Cmt Stinger with Bull Nose Circ Sub
14:00 - 17:30 3.50 ABANDt\ TRIP ABANDN TIH with 31/2" Stinger on 5" DP to 8,461', Washed 14' to Btm, 8,475'
with No Problems
17:30 - 20:15 2.75 ABANDt\ CIRC ABANDN Circ Btms Up Prior to Setting Abandonment Plug, Max Gas 200 Units at
Btms Up, Ave 80 Units BGG, Circ at 500 Gpm, Initial Press 1,960 Psi,
Final Press 1,880 Psi, Reciprocated Pipe, Up Wt 225K, Dn Wt 93K,
Held PJSM with Dowell & Rig Crew, MU Head Pin & Cement Hose &
Cont Circ While Batch Mixing Cement
20:15-21:00 0.75 CEMENT PLUG ABANDN RU Dowell, Pumped 5 bbls of 8.3 ppg CW 100,Tested Lines to 3,500
Psi & Ck Ok, Pumped Add 5 bbls 8.3 ppg CW 100 Followed by 48.5
bbls, 235 sxs of Class G Cmt W/Add @ 15.8 ppg & 1.16 Yield, Pumped
1.5 bbls of CW 100 Behind, Ave 5 Bpm at 450 Psi, Turned Over to Rig
Printed: 4/3/2003 9:40:39 AM
) ')
ConocoPhil'lips Alas~a Page 9 of 12
Operations Summary Report
!~Q~~: ;~hª~~!<
0.75 CEMENT PLUG ABANDN And Displaced Cmt with 125 bbls of 11.3 ppg Mud to Balance Plug,
Displaced Cmt 420 Gpm, 1,400 Psi, Reciprocated Pipe During Job, CIP
@ 20:50 Hrs Est T.O.G @ 7,968'
POOH Slow 9 Stds to 7,603', 1st 5 Stds at 1 Std/2 Min,
Circ Btms Up from 7,603', No Cmt Back at Btms Up, Pump and Spotted
35 bb112.3 ppg High Vis Pill from 7,603' to 7,300'
POOH 3 Stds to 7,317'
Circ & Cond Mud for Kick-Off Cmt Plug, At Btms Up Did Not See Any
Weighted Pill, After Circ Hole Clean, MU Head Pin With Cmt Hose and
Cant Circ Hole While Dowell Batch Mixed Cmt, Circ @ 425 Gpm, 900
Psi, Rot Pipe 10-15 Rpms with 15K Ft#'s Torque, 11.3 ppg Mud in &
Out
0.75 CEMENT PLUG ABANDN RU Dowell, Pumped 5 bbls 8.3 ppg CW100 Spacer, Press tested Lines
to 3,500 Psi, Pumped 10 bbls Add CW100, Pumped 57 bbls, 316 SXS
of Class G Gmt @ 17.0 ppg and 1.00 Yield with Add, Follow with 3.5
bbls CW100, Turned over to Rig Pump and Displaced Cement with 102
bbls of 11.3 ppg Mud to Balance Plug, Reciprocated Pipe, CIP @ 00:45
3/14/03 Hrs, Est TOC @ 6,700'
POOH Slow, 1st 6 Stds @ 1 std/3 min, POOH Total of 10 Stds to 6,369'
Circ Btms Up at 6,369' At Btms up Had 30 bbls of Cmt Contaminated
Mud Back, Circ Hole Clean with 11.3 MW In & Out ,Circ at 500 Gpm,
1,000 Psi Reciprocated & Rot Pipe
Monitored Well-Static, Pumped Dry Job & POOH to 31/2" Stinger
RU GBR Tbg Equip, POOH LD 30 Jts 31/2" 9.3# L-80 EUE 8 rd TBg
Stinger,
NOTE: Chuck Scheave with AOGCC Waived Witnessing of BOP Test,
Sim-Op-Tested Choke Manifold on Trip Out of Hole
0.25 WELCTL SFTY PROD Held PJSM on Testing BOP's
4.75 WELCTL BOPE PROD Pulled Wear Bushing, RU & Tested All Rams, Valves, and 7" Test Jt to
250 Psi Low, 5,000 Psi High, Tested Annular to 250 Low and 3,500 Psi
High, Good Test, RD Test Tools, Installed Wear Bushing & Blow Down
Kill & Choke Lines
Started MU BHA #4 Orient and Upload MWD
Changed Out Wash Pipe On Top Drive & Serviced Same
Surface Tested MWD and Blow Down Top Drive
Held PJSM with Sperry Sun on Loading Radioactive Sources
Loaded Radioactive Sources & Fin PU & RIH with BHA #4
TIH with BHA #4 and Began Taking Wt @ 6,455'
Est Girc at 500 Gpm, 2,450 Psi and 75 Rpms, Began Washing Down
from 6,455', Tagged Hard Cmt At 6,470', (Calc TOC was @ 6,700' with
35% Excess, Calc Gauge Hole) Drilled Hard Cmt from 6,470' to 6,496'
Began Sliding to Sidetrack Well, Slide Drilling from 6,496' to 6,515' with
500 Gpm, 2,450 Psi, with 25K WOB
Slide Drilling to Sidetrack Well from 6,515' to 6,531', Well Sidetracked
@ 6,531'
Drill, Slide & Survey Per Directional Plan from 6,531' to 7,220'
MD/5,093' (689') ART 4.12 Hrs, AST 4.24 Hrs, 20-25K WOB, 100
Rpm's, 500 Gpm, Off Btm Press, 2,250 PSi, On Btm 2,600 Psi, Off Btm
& On Btm Torque 17K Ft#'s, Rot Wt 140K, PU Wt, 240K, Dn Wt 105K,
11.3 MW, 12.7 ECD, Pumped Sweeps Every 300' with 50-100%
Increase in Cuttings
12.00 DRILL DRLG PROD Drill, Slide & Survey from 7,220' to 8,183' MD/5,668' (963') ART 6.08
Hrs, AST 2.96 Hrs, 20-25K WOB, 100 Rpm's, 500 Gpm, Off Btm Press,
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
3S-08
3S-08
ROT - DRILLING
N1268@ppco.com
Nabors 7ES
3/13/2003
20:15 - 21:00
21 :00 - 21 :30 0.50 ABANDf\ TRIP ABANDN
21 :30 - 22:45 1.25 ABANDf\ CIRG ABANDN
22:45 - 23:00 0.25 ABANDf\ TRIP ABANDN
23:00 - 00:00 1.00 ABANDf\ CIRC ABANDN
3/14/2003
00:00 - 00:45
00:45 - 01 :30 0.75 ABANDf\ TRIP ABANDN
01 :30 - 02:45 1.25 ABANDf\ CIRC ABANDN
02:45 - 05:30 2.75 ABANDf\ TRIP ABANDN
05:30 - 08:00 2.50 ABANDf\ PULD ABANDN
08:00 - 08:15
08:15 - 13:00
13:00 - 15:30 2.50 DRILL TRIP PROD
15:30 - 17:30 2.00 RIGMNT RSRV PROD
17:30 - 18:00 0.50 DRILL TRIP PROD
18:00 - 18:15 0.25 DRILL SFTY PROD
18:15 - 19:00 0.75 DRILL TRIP PROD
19:00 - 22:00 3.00 DRILL TRIP PROD
22:00 - 22:45 0.75 DRILL REAM PROD
~ ~22:45 - 00:00
'9 1.25 DRILL DRLG PROD
)~,¿:¡; 3/15/2003 00:00 - 00:45 0.75 DRILL DRLG PROD
00:45 - 12:00 11.25 DRILL DRLG PROD
12:00 - 00:00
Start: 2/24/2003
Rig Release:
Rig Number:
Spud Date: 2/25/2003
End:
Group:
Printed: 4/3/2003 9:40:39 AM
'\,
}
AOGCC
Lori Taylor
333 W. 7th Ave. Suite 100
Anchorage, AK 99501
DEFINITIVE
Re: Distribution of Survey Data for Well 3S-08 A
Dear Lori Taylor
Enclosed are two survey hard copies and one disk
Tie-on Survey: 4,279.85' MD
Window / Kickoff Survey: 4,300.00' MD (if applicable)
Projected Survey: 8,475.00' MD
Please call me at 273-3545 if you have any questions or concerns.
Regards,
William T. Allen
Su rvey Manager
Attachment(s)
'\
j
a08 .;03 7
20-Apr-03
RECEIVED
APR 2 2 2003
Alaska OJ} & Gas Cons. CommÌ38kJn
Anchomge
Sperry-Sun Drilling Services
Western North Slope
ConocoPhillips
Kuparuk 3S Pad
3S-DBA
-'
Job No. AKZZ2306056, Surveyed: 12 March, 2003
Survey Report
18 April, 2003
Your Ref: API 501032045001
Surface Coordinates: 5993923.52 N, 476305.45 E (70023' 40.3069" N, 150011' 34.0335" W)
Grid Coordinate System: NAD27 Alaska State Planes, Zone 4
'--
Surface Coordinates relative to Project H Reference: 993923.52 N, 23694.55 W (Grid)
Surface Coordinates relative to Structure: 80.05 N, 149.80 W (True)
Kelly Bushing: 56. 30ft above Mean Sea Level
Elevation relative to Project V Reference: 56. 30ft
Elevation relative to Structure: 0.20ft
5~1 ·...,y-5UI!
D FiiL L I N.r:;!iI5.~YI~I5~
A Halliburton Company
Survey Ref: svy1996
Sperry-Sun Drilling Services
Survey Report for Kuparuk 3S Pad - 3S-08A
Your Ref: API 501032045001
Job No. AKZZ2306056, Surveyed: 12 March, 2003
ConocoPhillips
Western North Slope
Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical
Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment
(ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 o Oft)
4279.85 65.920 108.830 2612.31 2668.61 1087.19 S 2606.00 E 5992828.07 N 478908.00 E 2820.68 Tie On Point
4300.00 64.580 108.580 2620.74 2677.04 1093.06 S 2623.34 E 5992822.15 N 478925.31 E 6.745 2838.98 Window Point
4373.15 59.740 109.780 2654.90 2711.20 1114.29 S 2684.41 E 5992800.73 N 478986.32 E 6.774 2903.63
4467.58 55.110 109.560 2705.72 2762.02 1141.07 S 2759.32 E 5992773.71 N 479061.14 E 4.907 2983.19
4563.89 50.460 109.730 2763.96 2820.26 1166.85 S 2831.54 E 5992747.71 N 479133.28 E 4.830 3059.86
4658.01 47.190 110.450 2825.91 2882.21 1191.17 S 2898.07 E 5992723.17 N 479199.73 E 3.522 3130.70 ~
4756.14 43.820 111.760 2894.68 2950.98 1216.34 S 2963.37 E 5992697.79 N 479264.95 E 3.564 3200.67
4847.67 40.190 112.020 2962.68 3018.98 1239.17 S 3020.19 E 5992674.78 N 479321.70 E 3.970 3261.87
4944.05 35.980 113.210 3038.53 3094.83 1262.00 S 3075.07 E 5992651 .78 N 479376.50 E 4.434 3321.25
5038.18 31.650 113.890 3116.72 3173.02 1282.91 S 3123.08 E 5992630.72 N 479424.45 E 4.617 3373.52
5134.02 27.000 118.070 3200.26 3256.56 1303.34 S 3165.30 E 5992610.15 N 479466.60 E 5.299 3420.18
5228.84 21.880 121.650 3286.56 3342.86 1322.76 S 3199.36 E 5992590.63 N 479500.60 E 5.619 3458.82
5325.54 18.740 124.890 3377.24 3433.54 1341.10 S 3227.44 E 5992572.20 N 479528.63 E 3.448 3491 .49
5419.46 16.790 129.540 3466.68 3522.98 1358.37 S 3250.28 E 5992554.86 N 479551.41 E 2.566 3518.86
5514.88 16.580 130.260 3558.08 3614.38 1375.94 S 3271.30 E 5992537.22 N 479572.37 E 0.309 3544.62
5610.64 13.590 135.640 3650.54 3706.84 1392.82 S 3289.60 E 5992520.28 N 479590.62 E 3.445 3567.58
5705.71 10.640 148.770 3743.50 3799.80 1408.32 S 3301.96 E 5992504.75 N 479602.93 E 4.228 3584.50
5801.13 8.370 170.600 3837.63 3893.93 1422.71 S 3307.67 E 5992490.34 N 479608.59 E 4.423 3594.78
5896.59 7.520 208.440 3932.24 3988.54 1435.06 S 3305.83 E 5992477.99 N 479606.71 E 5.447 3597.28
5990.64 9.450 246.540 4025.33 4081. 63 1443.55 S 3295.80 E 5992469.53 N 479596.66 E 6.183 3590.77
6087.02 13.340 264.240 4119.82 4176.12 1447.82 S 3277.47 E 5992465.32 N 479578.32 E 5.383 3575.00
6181.57 17.560 270.150 4210.93 4267.23 1448.88 S 3252.34 E 5992464.34 N 479553.18 E 4.758 3551.75
6276.68 22.010 271.040 4300.41 4356.71 1448.52 S 3220.16 E 5992464.80 N 479521.00 E 4.689 3521.38
6372.05 26.750 272.020 4387.25 4443.55 1447.44 S 3180.82 E 5992466.01 N 479481.67 E 4.988 3484.05 --
6465.61 31 .720 274.860 4468.87 4525.17 1444.61 S 3135.24 E 5992468.98 N 479436.09 E 5.514 3440.25
6560.77 37.1 00 274.700 4547.35 4603.65 1440.14 S 3081.67 E 5992473.62 N 479382.54 E 5.654 3388.38
6655.92 39.070 275.060 4622.24 4678.54 1435.14 S 3023.19 E 5992478.81 N 479324.08 E 2.084 3331.72
6751.16 39.080 274.800 4696.18 4752.48 1429.98 S 2963.38 E 5992484.15 N 479264.29 E 0.172 3273.75
6844.73 38.570 274.420 4769.07 4825.37 1425.26 S 2904.91 E 5992489.06 N 479205.83 E 0.602 3217.19
6940.45 37.880 275.300 4844.27 4900.57 1420.25 S 2845.90 E 5992494.26 N 479146.83 E 0.918 3160.02
7035.86 40.010 272.610 4918.47 4974.77 1416.15 S 2786.08 E 5992498.55 N 479087.03 E 2.850 3102.41
7131.40 39.550 272.170 4991.90 5048.20 1413.60 S 2725.00 E 5992501.29 N 479025.96 E 0.564 3044.15
7225.00 38.860 272.410 5064.43 5120.73 1411.23 S 2665.89 E 5992503.84 N 478966.85 E 0.755 2987.79
7318.83 37.690 272.540 5138.09 5194.39 1408.72 S 2607.82 E 5992506.54 N 478908.79 E 1.250 2932.36
7414.92 39.470 269.910 5213.21 5269.51 1407.47 S 2547.93 E 5992507.98 N 478848.90 E 2.519 2875.65
18 April, 2003· 15:37 Page2of4 DrillQuest 3.03.02.005
Sperry-Sun Drilling Services
Survey Report for Kuparuk 3S Pad - 3S-0BA
Your Ref: API 501032045001
Job No. AKZZ2306056, Surveyed: 12 March, 2003
ConocoPhillips
Western North Slope
Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical
Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment
(ft) (ft) (ft) (ft) (ft) (ft) (ft) CO/100ft)
7507.80 39.830 269.790 5284.72 5341.02 1407.63 S 2488.66 E 5992508.01 N 478789.64 E 0.396 2820.01
7606.03 39.250 270.120 5360.47 5416.77 1407.68 S 2426.13 E 5992508.16 N 478727.10 E 0.628 2761.27
7701.20 37.790 269.930 5434.93 5491 .23 1407.65 S 2366.86 E 5992508.38 N 478667.83 E 1.539 2705.56
7795.72 39.240 268.100 5508.89 5565.19 1408.68 S 2308.01 E 5992507.54 N 478608.99 E 1.951 2650.62
7891.20 37.880 268.170 5583.55 5639.85 1410.61S 2248.53 E 5992505.79 N 478549.50 E 1 .425 2595.39
7986.27 36.990 268.230 5659.04 5715.34 1412.43S 2190.77 E 5992504.15 N 478491.73 E 0.937 2541.73 ~
8080.95 36.060 268.150 5735.12 5791.42 1414.21 S 2134.45 E 5992502.55 N 478435.40 E 0.984 2489.41
8177.01 35.500 268.580 5813.05 5869.35 1415.81 S 2078.31 E 5992501.13 N 478379.26 E 0.639 2437.21
8272.54 34.670 268.620 5891.22 5947.52 1417.15 S 2023.41 E 5992499.96 N 478324.36 E 0.869 2386.08
8368.23 33.410 268.820 5970.51 6026.81 1418.35 S 1969.86 E 5992498.93 N 478270.81 E 1.322 2336.17
8409.97 32.970 268.550 6005.44 6061.74 1418.88 S 1947.02 E 5992498.48 N 478247.96 E 1.112 2314.89
8475.00 32.970 268.550 6060.00 6116.30 1419.77 S 1911.64 E 5992497.70 N 478212.58 E 0.000 2281.95 Projected Survey
All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North.
Vertical depths are relative to 3S-08. Northings and Eastings are relative to 3S-08.
Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4.
The Dogleg Severity is in Degrees per 100 feet (US Survey).
Vertical Section is from 3S-08 and calculated along an Azimuth of 110.000° (True).
Magnetic Declination at Surface is 25.174 0(26-Feb-03)
Based upon Minimum Curvature type calculations, at a Measured Depth of 8475.00ft.,
The Bottom Hole Displacement is 2381.20ft., in the Direction of 126.601° (True).
.~
18 April, 2003 - 15:37
Page 30f4
DrillQuest 3.03.02.005
Western North Slope
Comments
Measured
Depth
(ft)
4279.85
4300.00
8475.00
Sperry-Sun Drilling Services
Survey Report for Kuparuk 3S Pad - 3S-08A
Your Ref: API 501032045001
Job No. AKZZ2306056, Surveyed: 12 March, 2003
ConocoPhillips
Station Coordinates
TVD Northings Eastings
(ft) (ft) (ft)
2668.61
2677.04
6116.30
Comment
1087.198
1093.068
1419.778
2606.00 E
2623.34 E
1911.64 E
Tie On Point
Window Point
Projected 8urvey
~
Survey tool program for 3S-0BA
Fro m
Measured Vertical
Depth Depth
(ft) (ft)
0.00
87.00
18 April, 2003 - 15:37
0.00
87.00
To
Measured Vertical
Depth Depth Survey Tool Description
(ft) (ft)
87.00
8475.00
87.00 Tolerable Gyro (38-08)
6116.30 AK-6 BP _IFR-AK (38-08)
---'
Page 40f4
DrillQuest 3.03.02.005
)
AOGCC
Lori Taylor
333 W. 7th Ave. Suite 100
Anchorage, AK 99501
Re: Distribution of Survey Data for Well 3S-08 A MWD
Dear Lori Taylor
Enclosed are two survey hard copies and one disk
Tie-on Survey: 4,279.85' MD
Window / Kickoff Survey: 4,300.00' MD (if applicable)
Projected Survey: 8,475.00' MD
Please call me at 273-3545 if you have any questions or concerns.
Regards,
William T. Allen
Survey Manager
Attachment(s)
dO B-ö3 7
20-Apr -03
RECEIVED
APR 2 2 2003
Alaska ()H & Gas Coos. Commission
Anchorage
Ì'
(V)
Q.
I
tv)
0_
~.
Sperry-Sun Drilling Services
~
Western North Slope
ConocoPhillips
Kuparuk 3S Pad
3S-0BA MWD
Job No. AKMW2306056. Surveyed: 12 March. 2003
Survey Report
18 April, 2003
,-
Your Ref: API 501032045001
Surface Coordinates: 5993923.52 N. 476305.45 E (70023'40.3069" N, 150011' 34.0335" W)
Grid Coordinate System: NAD27 Alaska State Planes. Zone 4
Surface Coordinates relative to Project H Reference: 993923.52 N. 23694.55 W (Grid)
Surface Coordinates relative to Structure: 80.05 N. 149.80 W (True)
Kelly Bushing: 56.30ft above Mean Sea Level
Elevation relative to Project V Reference: 56.30ft
Elevation relative to Structure: 0.20ft
spe""''''''y-55U.-,
DRILLING seRVIc:es
A Halliburton Company
Survey Ref: 5vy2013
Sperry-Sun· Drilling Services
Survey Report for Kuparuk 38 Pad - 3S-0BA MWD
Your Ref: AP/501032045001
Job No. AKMW2306056, Surveyed: 12 March, 2003
\ ConocoPl1illips
Western North Slope
Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical
Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment
(ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft)
4279.85 65.920 108.830 2612.40 2668.70 1068.24 8 2613.95 E 5992847.00 N 478916.00 E 2821.67 Tie On Point
4300.00 64.580 108.580 2620.84 2677.14 1074.11 8 2631.28 E 5992841.08 N 478933.31 E 6.745 2839.96 Window Point
4373.15 59.740 111.050 2654.99 2711.29 1096.00 8 2692.12 E 5992818.99 N 478994.08 E 7.258 2904.62
4467.58 55.110 110.440 2705.82 2762.12 1124.198 2766.51 E 5992790.57 N 479068.38 E 4.933 2984.16
".,- 45G3.89 50.4GO 111.540 2764.06 2820.36 1151.63 S 2838.11 E 5992762.90 N 479139.89 E 4.913 30GO.83
4658.01 47.190 110.450 2826.01 2882.31 1177.038 2904.23 E 5992737.30 N 479205.94 E 3.582 3131.65
4756.14 43.820 111 .120 2894.78 2951.08 1201.858 2969.67 E 5992712.26 N 479271.29 E 3.469 3201.63
4847.67 40.190 111 .740 2962.78 3019.08 1224.21 S 3026.68 E 5992689.72 N 479328.23 E 3.992 3262.85
4944.05 35.980 113.290 3038.63 3094.93 1246.94 8 3081.59 E 5992666.82 N 479383.08 E 4.479 3322.23
5038.18 31 .650 114.110 3116.82 3173.12 1267.978 3129.56 E 5992645.64 N 479430.97 E 4.625 3374.49
5134.02 27.000 118.710 3200.36 3256.66 1288.70 S 3171.62 E 5992624.77 N 479472.97 E 5.388 3421.11
5228.84 21.880 122,170 3286.66 3342.96 1308.47 S 3205.48 E 5992604.90 N 479506.76 E 5.605 3459.68
5325.54 18.740 125.450 3377.34 3433.64 1327.078 3233.39 E 5992586.20 N 479534.62 E 3.453 3492.28
5419.46 16.790 130.120 3466.78 3523.08 1344.57 S 3256.06 E 5992568.64 N 479557.23 E 2.570 3519.56
5514.88 16.580 130.840 3558.19 3614.49 1362.35 S 3276.89 E 5992550.79 N 479578.01 E 0.309 3545.23
5610.64 13.590 136.070 3650.64 3706.94 1379.39 S 3295.04 E 5992533.69 N 479596.10 E 3.428 3568.11
5705.71 10.640 149.210 3743.60 3799.90 1394.988 3307.29 E 5992518.06 N 479608.30 E 4.229 3584.95
5801 .13 8.370 171.230 3837.73 3894.03 1409.42 S 3312.86 E 5992503.60 N 479613.82 E 4.450 3595.12
5896.59 7.520 209.470 3932.34 3988.64 1421.73 S 3310.84 E 5992491.30 N 479611.77 E 5.501 3597.44
5990.64 9.450 247.060 4025.43 4081.73 1430.11 S 3300.70 E 5992482.96 N 479601.60 E 6.112 3590.77
6087.02 13.340 264.530 4119.92 4176.22 1434.26 S 3282.33 E 5992478.87 N 479583.22 E 5.353 3574.93
/~'- 6181.57 17.560 270.370 4211.03 4267.33 1435.20 S 3257.20 E 5992478.00 N 479558.08 E 4.751 3551.63
6276.68 22.010 270.630 4300.51 4356.81 1434.92 S 3225.01 E 5992478.39 N 479525.90 E 4.680 3521.29
6372.05 26.750 271.780 4387.35 4443.65 1434.05 S 3185.67 E 5992479.38 N 479486.56 E 4.995 3484.02
6465.61 31.720 274.560 4468.97 4525.27 1431.44 S 3140.07 E 5992482.13 N 479440.97 E 5.505 3440.29
6560.77 37.100 275.140 4547.45 4603.75 1426.88 S 3086.51 E 5992486.87 N 479387.42 E 5.664 3388.39
6655.92 39.070 275.740 4622.34 4678.64 1421.31 S 3028.09 E 5992492.62 N 479329.02 E 2.107 3331.59
6751.16 39.080 275.270 4696.28 4752.58 1415.55 S 2968.33 E 5992498.57 N 479269.28 E 0.311 3273.4 7
6844.73 38.570 274.710 4769.17 4825.4 7 1410.44 S 2909.89 E 5992503.86 N 479210.86 E 0.662 3216.80
6940.45 37.880 275.560 4844.37 4900.67 1405.15 S 2850.90 E 5992509.34 N 479151.89 E 0.906 3159.56
7035.86 40.010 273.010 4918.57 4974.87 1400.70 S 2791.11 E 5992513.98 N 479092.11 E 2.794 3101.85
7131.40 39.550 272.320 4992.00 5048.30 1397.85 S 2730.05 E 5992517.02 N 479031.05 E 0.667 3043.50
7225.00 38.860 272.770 5064.53 5120.83 1395.23 S 2670.94 E 5992519.83 N 478971.96 E 0.797 2987.06
7318.83 37.690 272.980 5138.19 5194.49 1392.31 S 2612.90 E 5992522.93 N 478913.92 E 1.255 2931.52
7414.92 39.470 270.470 5213.31 5269.61 1390.54 S 2553.01 E 5992524.90 N 478854.04 E 2.466 2874.64
_________ ___.__ - ----__·.--0___-__-· _.___.
18 April, 2003 - 15:24 Page 20f4 DrillQlIest 3.03.02.005
DrillQuest 3.03.02.005
Page 3 of4
18 April, 2003 - 15:24
---.-------.------
Based upon Minimum Curvature type calculations, at a Measured Depth of 8475.00ft.,
~. The Bottom Hole Displacement is 2373.1 Oft., in the Direction of 126.1300 (True).
Magnetic Declination at Surface is 25.174 0(26-Feb-03)
The Dogleg Severity is in Degrees per 100 feet (US Survey).
Vertical Section is from 3S-08 and calculated along an Azimuth of 110.0000 (True).
All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North.
Vertical depths are relative to 3S-08. Northings and Eastings are relative to 38-08.
Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4.
Sperry-Sun Drilling Services
Survey Report for Kuparuk 3S Pad - 3S-0BA MWD
Your Ref: AP/501032045001
Job No. AKMW2306056. Surveyed: 12 March. 2003
ConocoPhillips
Western North Slope
Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical
Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment
(ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft)
7507.80 39.830 270.320 5284.82 5341 .12 1390.138 2493.75 E 5992525.50 N 478794.78 E 0.401 2818.81
7606.03 39.250 270.470 5360.57 5416.87 1389.708 2431.22 E 5992526.12 N 478732.25 E 0.598 2759.90
7701.20 37.790 270.110 5435.03 5491.33 1389.398 2371.95 E 5992526.62 N 478672.98 E 1.552 2704.10
7795.72 39.240 268.590 5508.99 5565.29 1390.07 8 2313.10 E 5992526.12 N 478614.13 E 1.832 2649.03
.'-' 7891.20 37.880 268.370 5583.65 5639.95 1391.658 2253.60 E 5992524.73 N 478554.63 E 1.432 2593.67
7986.27 36.990 268.010 5659.14 5715.44 1393.478 2195.84 E 5992523.09 N 478496.87 E 0.964 2540.01
8080.95 36.060 267.740 5735.22 5791.52 1395.56 8 2139.53 E 5992521.18 N 478440.55 E 0.997 2487.81
8177.01 35.500 269.160 5813.15 5869.45 1397.09 S 2083.39 E 5992519.84 N 478384.40 E 1.042 2435.58
8272.54 34.670 269.600 5891.32 5947.62 1397.68 S 2028.49 E 5992519.42 N 478329.50 E 0.908 2384.19
8368.23 33.410 269.140 5970.61 6026.91 1398.27 S 1974.93 E 5992519.00 N 478275.93 E 1.344 2334.06
8409.97 32.970 269.020 6005.54 6061.84 1398.638 1952.08 E 5992518.71 N 478253.09 E 1.066 2312.72
8475.00 32.970 269.020 6060.10 6116.40 1399.24 S 1916.70 E 5992518.21 N 478217.70 E 0.000 2279.67 Projected Survey
Western North Slope
Comments
Measured
Depth
(ft)
~-
4279.85
4300.00
8475.00
Sperry-Sun Drilling Services
Survey Report for Kuparuk 3S Pad - 3S-0BA MWD
Your Ref: AP/501032045001
Job No. AKMW2306056, Surveyed: 12 March, 2003
ConocoPhi/lips
Station Coordinates
TVD Northings Eastings
(ft) (ft) (ft)
2668.70
2677.14
6116.40
Comment
1068.24 8
1074.11 8
1399.24 8
Tie On Point
Window Point
Projected Survey
2613.95 E
2631.28 E
1916.70 E
Survey tool program for 3S-0BA MWD
From
Measured Vertical
Depth Depth
(ft) (ft)
0.00
87.00
---
18 April, 2003 - 15:24
0.00
87.00
To
Measured Vertical
Depth Depth Survey Tool Description
(ft) (ft)
87.00
8475.00
87.00 Tolerable Gyro (38-08 MWD)
6116.40 MWD Magnetic (38-08 MWD)
Page 4 of4
DriflQuest 3.03.02.005
~...:""..:~....).
.p.,.' ,
ConöcoPhiUips
)
Post Office Box 100360
Anchorage, Alaska 99510-0360
Randy Thomas
Phone (907) 265-6830
Fax: (907) 265-1535
Email: randy.l.thomas@conocophillips.com
March 10, 2003
Cammy Oechsli Taylor, Chair
Alaska Oil and Gas Conservation Commission
333 West ih Avenue
Suite 100
Anchorage, Alaska 99501
(907) 279-1433
Re: Application for Sundry Approval to plug back well 3S-08 (APD 203-022) / Application for Permit to
Drill Sidetrack well, 3S-08A
Dear Commissioner Taylor:
ConocoPhillips Alaska, Inc. hereby files this Application for Sundry Approval to plug back well 3S-08. /'.
Scott Lowry spoke with Winton Aubert on 3-7-03 to obtain verbal approval to proceed with operations. A
permit application for the sidetrack, 3S-08A, is included with this application.
Please find attached for the review of the Commission the information required by 20 ACC 25.005 (c).
If you have any questions or require any further information, please contact Scott Lowry at 265-6869.
Sincerely,
~~.
Randy Thomas
GKA Drilling Team Leader
RECE\\fED
M~R '\ G 12003
_ ~, ou & Gas consa ccmmisS\O\~'
N~t\!!.1. AAd'mra,qili
¡...J6A- -S I 1"-1/ Z-O ()"5
O~S o3/(//c~1
qf '1/17/03
APPLICATION FOR SUNDRY APPROVALS
)
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
')
('
1. Type of request:
Abandon _XX Suspend _
Alter casing _ Repair well _
Change approved program _
2. Name of Operator
ConocoPhillips Alaska, Inc.
3. Address
P.O.-Box 100360
Anchorage, AK 99510-0360
4. Location of well at surface
2492'FNL,954'FEL,Sec.18,T12N,R8E,UM
At top of productive interval
1371' FSL, 1140' FWL, Sec. 17, T12N, R8E, UM
At effective depth
At total depth
1374' FSL, 964' FWL, Sec. 17, T12N, R8E, UM
12. Present well condition summary
Total depth: measured
true vertical
8475
6116
Effective depth: measured 6700
true vertical 4189
Casing Length Size
Conductor 80' 30"x16"
Surface 4235' 9.625"
Perforation depth:
measured No Perforations
true vertical No Perforations
Tubing (size, grade, and measured depth No Tubing Run
Packers & SSSV (type & measured depth) No Packers or SSSV"s
Operational shutdown _
Plugging _
Pull tubing _
5. Type of Well:
Development _XX
Exploratory
Stratigraphic _
Service
(asp's: 476305, 5993924)
(proposed)
(proposed)
feet Plugs (measured)
feet
feet Junk (measured)
feet
Cemented
75 sx ArcticCrete
664 sx ASLite, 391 sx LiteCrete
13. Attachments Description summary of proposal _XX
14. Estimated date for commencing operation
March 13, 2003
16. If proposal was verbally approved
/'
Name of approver Winton Aubert Date approved Service
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
3/13/2003
Signed ~4 c-, (ßl (!. r- t2.~·ÎLio h4-';
R. Thomas
Re-enter suspended well _
Time extension Stimulate Other
Variance Periorate
6. Datum elevation (DF or KB feet)
RKB 28 feet
7. Unnor Property name
Kuparuk River Unit
8. Well number /'
3S-08A
9. Permit number / approval number
unassigned à03--oS-¡
10. API number
50-103-20450-01
11. Field / Pool
Kuparuk River Field/Kuparuk River Oil Pool
cement plug #1 from 8475' - 7968'
cement plug #2 from 7300' - 6700'
Measured Depth
108'
4263'
True vertical Depth
108'
2662'
RECEIVEÐ
MAR 14 2003
i%~"~nOIi& Qa9COns. GömifiMio,f1
~11\i1iî~'I¡\\Ø AndIe..
Detailed operations program
15. Status of well classification as:
BOP sketch
Oil
Title: Kuparuk Drilling Team Leader
FOR COMMISSION USE ONLY
Conditions of approval: Notify Commission so representative may witness
Plug integrity _ BOP Test Location clearance
Mechanical Integrity ;;. _ d ~ Subsequent form required 10-
Approved by order of the Commission XJ1 ~/
Form 10-403 Rev 06/15/88 ·
Gas
Suspended _
Plugged and Abandoned
Questions? Call Scott Lowry 265-6869
Date 51 I+~ð 3
Prepared by Sharon AI/sup-Drake
t.fDl
Approval no.
303-Dð'"&.
Commissioner
ffi ·V/1 ; ~.&~ Q
Date (J-.J // D/ :;;
RBDMS BFt
M~S' .:
SUBMIT IN TRIPLICATE
KR.U - 3S-08A Plu~.1ck Schematic
Plug back of 38-08A to new BHL (38-08B)
Planned KOP @ 7000' MD
16"x30"
insulated
conductor @
109' MD
i i
1 1
1 1
1 1
1 1
1 1
..~ 1
~ 1
~
~'.~
1
,I
'I
1
.~
1
Surface csg. f
9-5/8"40# L-80 ...J
BTC (4263' MD /
2662' TVD)
Cemented to
surface.
8 Y:z" open hole
r
~
.~
~
~
:~
~
~
~
~
~
~
b.....
I
~
~
~
~
~
.....
Top @ 4386' MD /2716' TVD
C-80
Base @ 4411' MD /2731' TVD
Top @ 6073' MD /4162' TVD
C-40
Base Undefined
Top @ 7380' MD /5243' TVD
Moraine
Base @ 7543' MD /5368' TVD
K-1 Marker@ 8086' MD /5795' TVD
Top @ 8168' MD / 5862' TVD
Kuparuk "C4" Sand
Base @ 8186' MD / 5878' TVD
TD @ 8475' MD /6116' TVD
)~
ConocoPhillips
Sidetrack plug:
316 Sacks /57 bbls Class G + additives mixed @ 17.0 ppg
/,e
Yield = 1.01 cuftlsk
Top of Plug @ 6700' MD
Bottom of Plug @ 7300' MD
35% excess cement in open hole
Cement plug across Kuparuk "C" sand:
233 Sacks / 48 bbls Class G + additives mixed @ 15.8 ppg
/'
Yield = 1.16 cuftlsk
Top of Plug @ 7968' MD
Bottom of Plug @ 8475' MD
35% excess cement
Scott L Lowry 03/13/03
'\
J
)
3S-USA Plug Back Procedure /'
Scott Lowry spoke to Winton Aubert with AOGCC @ 08:303/13/03 and obtained verbal approval
of the following plug back procedure. Mr. Aubert waived the tagging requirement for the
abandonment plug across the Kuparuk interval.
1. Contact inspector to witness job.
2. PU +/- 947' cement stinger w/ slotted flow diverting joint on bottom.
3. RIH with stinger and 5" DP to TD.
4. Circulate and condition mud to obtain consistent mud weight in and out.
Plug # 1
5. Spot balanced cement plug to cover the Kuparuk "c" sand interval. (see cement
calculations) Reciprocate pipe until cement reaches the end of the plugback string.
Spot plug at 8-10 BPM. /"'"
6. Pull stinger and DP out of plug no faster than 1 stand / 2 minutes. Pull out of hole to
+/- 7600' MD.
7. Circulate up spacers and contaminated mud/cement the long way at maximum rate.
Spot a weighted (1 ppg over mud weight) high viscosity pill from 7600' to 7300' MD.
Plug # 2
8. POOH to 7300' MD / circulate and condition mud to spot sidetrack plug. Reduce the
Yp to 15-20. Balance mud weight in and out.
9. Spot balanced cement plug from 7300' MD to 6700' (see cement calculations). /'
Reciprocate pipe until cement reaches the end of the plugback string. Spot plug at 8-
10 BPM.
10. Pull stinger and DP out of plug to 6500' MD no faster than 1 stand / 3 minutes while
pulling out of cement.
11. Circulate up spacers and contaminated mud/cement the long way at maximum rate.
12. POOH and UD cement stinger.
13. Test BOP equipment.
14. P/U directional assembly to dress off cement and sidetrack well. Directional plan will
be provided as soon as possible.
~\
>
)
35-08 Plu£ Back Requirements
Cement Plug #1 :
10 bbls CW 100 ahead of cement
48 bbls I 233 sacks Class G + additives @ 15.8 ppg (35% excess cement - batch mix
cement)
1.5 bbls CW1 00 behind cement to balance plug (verify volume of CW1 00 to balance)
Displace wi 126 bbls of mud (cut displacement 2.5 bbls short of calculated balance point)
Calculations:
(8475' - 7968') x (0.3941 cuft/ft) x (1.35)
= 269.7 cuft
269.7 cuft I 1.16 cuft/sk
= 233 sacks
Cement Plug #2 (Kick-Off Plug) :
15 bbls CW 100 ahead of cement
57 bbls I 316 sacks Class G + additives @ 17.0 ppg (35% excess cement - batch mix
cement)
3.5 bbls CW100 behind cement to balance plug (verify volume of CW100 to balance)
Displace wi 102 bbls of mud (cut displacement 2.5 bbls short of calculated balance point)
Calculations:
(7300' - 6700') x (0.3941 cuft/ft) x (1.35)
= 319.2 cuft
319.2 cuft 11.01 cuft/sk
= 316 sacks
~1!~u~
~
)
f ~ ~!Æ~~~!Æ
)
o
FRANK H. MURKOWSKI, GOVERNOR
A.I~A.~&A. OIL AlWD GAS
CONSERVATION COMMISSION
333 W. PH AVENUE, SUITE 100
ANCHORAGE, ALASKA 99501-3539
PHONE (907) 279-1433
FAX (907) 276-7542
Randy Thomas
Kuparuk Drilling Team Leader
ConocoPhillips Inc.
PO Box 100360
Anchorage AK 99510-0360
Re: KuparukRiver Unit 3S-08A
ConocoPhillips Inc.
Pennit No: 203-037
Surface Location: 2492' FNL, 954' FEL, Sec. 18, TI2N, R8E, UM
Bottomhole Location: 1374' FSL, 964' FWL, Sec. 17, TI2N, R8E, UM
Dear Mr. Thomas:
Enclosed is the approved application for pennit to drill the above referenced development well.
This pennit to drill does not exempt you from obtaining additional pennits or approvals. required
by law from other governmental agencies, and does not authorize conducting drilling operations
until all other required pennits and approvals have been issued. In addition, the Commission
reserves the right to withdraw the pennit·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 tenns and conditions of this pennit may
result in the revocation or suspension of the pennit. Please provide at least twenty-four (24)
hours notice for a representative of the Commission to witness any required test. Contact the
Commission's North Slope petroleum field inspector at 659-3607 (pager).
Sincerely,
ß,-N) ß-.c / lL"-~
Randy Ruedrich
Commissioner
BY ORDER O~THE COMMISSION
DATED thislt day of March, 2003
cc: Department ofFish & Game, Habitat Section w/o encl.
Department of Environmental Conservation w/o encl.
Exploration, Production and Refineries Section
9. Approximate spud date / Amount
March 7, 2003 $200,000
14. Number of acres in property 15. Proposed depth (MD and TVD)
2448 8442 ' MD I 6049 ' TVD
17. Anticipated pressure (see 20AAC 25.035 (e)(2))
Maximum surface 2497 psig / At total depth (TVD) 3135 psig
Setting Depth
)
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
20 AAC 25.005
1b. Type of well. Exploratory U Stratigraphic Test
Service D Development Gas D Single Zone
5. Datum elevation (DF or KB)
RKS = 28'
1a. Type of work: Drill ~ Redrill U
Re-entry DDeepen D
2. Name of Operator
ConocoPhillips Alaska, Inc.
3. Address
P.O. Box 100360 Anchorage, AK 99510-0360
4. Location of well at surface
2492' FNL, 954' FEL, Sec. 18, T12N, R8E, UM
At top of productive interval
1371' FSL, 1140' FWL, Sec. 17, T12N, R8E, UM
At total depth
1374' FSL, 964' FWL, Sec. 17, T12N, R8E, UM
12. Distance to nearest property line 13. Distance to nearest well
1374' at TD 3S-081
16. To be completed for deviated wells
Kickoff depth: 4400 MD
18. Casing program
size
6. Property Designation
ADL 380107 ALK 4624
7. Unit or property Name
Kuparuk River Unit
8. Well number /
3S-08A
feet
Maximum hole angle
65°
Top
Bottom
TVD
Hole
Specifications
Grade Coupling
MD
Casing
Weight
MD
Length
TVD
8.5"
7'
28'
L-80
STCM
26#
8414'
28'
8442'
6049'
19, To be completed for Redrill, Re-entry, and Deepen Operations.
Present well condition summary
y...tGÂ- 3' 1111 z-OO'5
)
ç~:j it t.( OJ
U
D
Development Oil ~
Multiple Zone D
10. Field and Pool
Kuparuk River Field
Kuparuk River Oil Pool
11. Type Bond (see 20 AAC 25.0251)
Statewide
Number
#59-52-180
Quantity of Cement
(include stage data)
240 sx Class G
Plugs (measured)
cement plug #1: 11642' - 11200'
Cement plug #2: 4870' - 4203'
,;~~~~tœ. on &. Gas GlOns. r~~1ffi1frf&~~~j~~imtÜ
,"to" l~o~~h@riUTí,~
20. Attachments Filing fee 0 Property Plat D BOP Sketch D Diverter Sketch D Drilling program 0
Drilling fluid program 0 Time vs depth plot Defraction analysis D Seabed report D 20 AAC 25.050 requirements 0
21. I hereby certify that the foregoing is true and correct to the best of my knowledge Questions? Call Scott Lowry 265-6869
, I ~ 'S/(ò/õ ~
~ ~~, ' Title: Kuparuk Drilling Team Leader Date
R. Thomas I Pn:::m;:m:::¡rl hv RhAmn AII.C:;/ln-nrAkp.
Total Depth: measured 11642 feet
true vertical 5986 feet
Effective Depth: measured 4203 feet
true vertical 2637 feet
Casing Length Size Cemented
Conductor 80' 16" 75 sx ArcticCrete
Surface 4235' 9.625" 664 sx AS Lite, 391 sx LiteCrete
Junk (measured)
Measured depth
108'
4263'
Perforation depth:
measured
none
true vertical
none
Signed
Commission Use Only
I API number //~ I APprovalza I ('
50- /D 3 -ZD"t~LJ-D/ 03 2·/, "~J
Conditions of approval Samples required D Yes ~ No Mud log r uired
Hydrogen sulfide measures DYes IKI No Directional survey required ø Yes
Required working pressure for BOPE D2M; D 3M; D 5M; D 10M; D D
Other: \~t '1;oPE Ie SOOO y-;'l.
Permit Number
ÃD3 -03?
Approved by
~
~~~ommissioner
by order of
the commission
Form 10-401 Rev. 12/1/85·
o ~¡GL"JA-
True Vertical depth
108'
2662'
R'E,C'EIVED
MAR 1 0 2003
Isee cover letter
for other requirements
U Yes Dd' No
D No
Date ¿' 7f z/ð J
Submit in triplicate
)
APi )on for Permit to Drill, Well 3S-08A
Revision No.O
Saved: 10-Mar-03
Permit It - Kuparuk Well 3S-08A
Application for Permit to Drill Document
MQxir'r'tizE
Well "IglUI¡
Table of Contents
1. Well Name...... ...... .... ......... .... ....... ... ....... ............... ........... .............. .... ... .... ......... ....... 2
Requirements of 20 AAC 25.005 (f). ........... ...... ............................... ......... ......................... ................. ....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 20 AAC 25.005(c)(3) .............. ........... ......... ...... ................. ........................... ...... ......... 3
4. Dri II i ng Hazards Information. .......... ......... ...... ..... ......... ...... ...... ......... ... ....... ...... ...... 3
Requirements of 20 AAC 25.005 (c)( 4) ...................... ...... .............. ................ ........ .................. .............. 3
5. Procedure for Conducting Formation Integrity Tests ........................................... 3
Requirements of 20 AAC 25.005 (c)(5) ..................................................................................................3
6. Casi ng and Cementi ng Program. ... ........... ... ...... ..... ...... ............. ........ ..... ..... .... ....... 4
Requirements of 20 AAC 25.005(c)(6) .......... ................ ........ ...... ............. ............ .............. .................... 4
7. Diverter System Information ............. .... ......... ....... .... ......... ............. ..... ....... ...... ...... 4
Requirements of 20 AAC 25.005(c)(7) ... ........................... ............................................ ......................... 4
8. Dri II i ng FI u id Program .......................... ........... ............................................. ........... 4
Requirements of 20 AAC 25. 005( c)(B) ................................................................................................... 4
9. Abnormally Pressured Formation Information ...................................................... 5
Requirements of 20 AAC 25.005 (c)(9) ......................... ......... ................... .............................................5
10. Seism ic Analysis... ... ........ ...... ..... ........... ........... ............................ ....................... .... 5
Requirements of 20 AAC 25.005 (c)(1 0) ......... .................. .....................................................................5
11. Seabed Condition Analysis .....................................................................................5
Requirements of 20 AAC 25.005 (c)(11) ................................................................................................5
12. Evidence of Bond i ng ....................................... ................... ..................................... 5
Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 5
13. Proposed Dri Iii ng Program .................. ...... ............................................ ................. 5
Ohl u uJA..
3$-OBA PERMIT IT. DOC
Page 1 of 7
Printed: 10-Mar-03
)
API )on for Permit to Drill, We1l3S-08A
. Revision No.O
Saved: 10-Mar-03
Requirements of 20 AAC 25.005 (c)(13) ........... .................................. ........... ......... ............. .................. 5
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............................ ............................................................... ..6
Attachment 3 Well Schematic. ......................................................... ............................... ..... 6
1. Well Name
Requirements of 20 AAC 25.005 (f)
Each well must be Identified by a unique name des~qnated by the opelator and a unique API number assigned by the commi!;,'"Sion
under 20 AAC 2.'i.040(b). For a well with multiple well branche!;,:. each branch mLlst similady 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 as!::J1gned to the well by ti7e
commission.
The sidetrack well for which this application is submitted will be designated as 3S-08A.
2. Location Summary
Requirements of 20 AAC 25.005(c)(2)
An application for a Permit to Drill mWit be accompanied by each of'the fOllowing item~ eXC6pt lor an item a/ready on file with the
commission and Identified in the application:
(2) a plat identifyli7g the property and the propelty's owners and showing
(A)the LYJordinatl7s of the proposed location of the well at the surface~ at the top of each objective formation and at total dl:?ptl7,
referenced to governmental section lines.
(8) tl7e coordinates of the proposed location of the well at the SlJrk1ce, referenced to the state plane coordinate system for thlt;
state as maintained by the National Geodetic Survey in tl7e National Oceanic and Atmospheric Administration;
(C) the proposed depth of the well at the top of each objective formation and at total deptlì/
Location at Surface
NGS Coordinates
Northings: 5,993,923
I 2492' FNL, 954' FEL, Sec 18, T12N, R8E, UM
RKB Elevation
Eastings: 476,305 Pad Elevation
/
56.1' AMSL
28.0' AMSL
Location at Top of
Productive Interval
(Kuparuk "C" Sand)
NGS Coordinates
Northings: 5,992,500
1371' FSL, 1140' FWL, Sec 17, T12N, R8E, UM
/.
Eastings: 478,400
Measured Depth, RKB:
Total Vertical Depth, RKB:
Total Vertical Depth, 55:
8142'
5806'
5750'
Location at Total Depth 11374' FSL, 964' FWL,
NGS Coordinates
Northings.· 5,992,504 Eastings.· 478,224
Sec 17, T12N, R8E, UM
Measured Depth, RKB.·
Total Vertical Depth, RKB:
Total Vertical Depth, 55.'
/
8442'
6049'
5993'
and
(D) other information required by 20 AAC 25.050(b);
Requirements of 20 AAC 25.050(b)
If a well is to be intentionally deviated, the application for a PermIt to Oril/ (Form 10-401) must
(1) include a plaç dlawn to a sUItable scale, showli7g the path of the proposed wet/bore, including all adjacent wet/bores within 200
feet of any portion of the proposed we/¿'
Please see Attachment 1: Directional Plan
Ci/G·'l\A-
3S-08A PERMIT IT. DOC
Page 2 of 7
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),
,
API )on for Permit to Drill, We1l3S-08A
Revision No.O
Saved: 10-Mar-03
and
(2) for a/I we/Is withli7 200 feet of the proposed wel/bore
(A) list the names of the operators of those well.?~ to the extent that tho~-e names are known or discoverable in public record~
and show that each named operator has been fumi~"hed a copy of the application by certified mall,' or
(B) state that the applicant is the only affected owner.
The Applicant is the only affected owner.
3. Blowout Prevention Equipment Information
Requirements of 20 AAC 25.005(c)(3)
An application for a Permit to Drill must be acx;ompanied by each of the following Items, except for an Item already on file with the
commission and identified in the application:
(3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 AAC 25.035, 20 AAC 2.5.034 or 20
AAC 25.037; as applicable,,'
Please reference BOP schematics on file for Nabors 7ES. /
4. Drilling Hazards Information
Requirements of 20 AAC 25.005 (c)(4)
An application for a Permit to Drill must be acc:ompanied by each of (tIe following Item5~ except for an Item already on file with the
commis..'ion and identified in the application:
(4) infol7Tlation on e/tilling hazard~ including
(A) the maxlÍTlum downhole pressure that may be encounterect criteJia used to detel771ine it and maximum potential sumlce
pressure based on a methane gradient·
A pressure build-up test performed on Palm lA (35-26) in 4/gJ< indicated a reservoir pressure in the
Kuparuk C sand of 3597 psi at 5830' tvd, 0.62 psi/ft or 11.9 ppg EMW (equivalent mud weight). Due to
pressure~.... ...ep tion, the predicted reservoir pressure for 3S-08A is predicted at 3130 psi at 5806' tvd, 0.54
psi/ft O j 10./ ppg EMW.
c¿'"
The maximum potential surface pressure (MPSP) while drilling 3S-08A is calculated using above
maximum reservoir pressure, a gas gradient of 0.11 psi/ft, and the Kuparuk C sand target at 5806' tvd:
MPSP =(5806 ft)*(0.54 - 0.11 psi/ft)
= 2497 psi
(8) data on potential gas zones;
The well bore is not expected to penetrate any gas zones.
and
(C) data concerning potential causes of hole prvblems such as abnormally geo-pressured strata, lost circulation z()ne_~ and zones
that have a propensity for differential sticking;
Please see Attachment 2 - Drilling Hazards Summary
5. Procedure for Conducting Formation Integrity Tests
Requirements of 20 AAC 25.005 (c)(5)
An application for a Permit to Dnll must be accompanied by each of the following items, except for an item a/ready on file with the
commi!:>-sion and Identified in the application:
(5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(1),'
A procedure is on file with the commission for perf07ing LOT's. For 3S-08A, the 9 5/8" surface casing
shoe has been tested to 17.9 ppg EMW on 3/3/03.
,: ilCiNh,.
3S-08A PERMIT IT. DOC
Page 3 of 7
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)
Ap, )on for Permit to Drill, We1l3S-08A
Revision No.O
Saved: 10-Mar-03
6. Casing and Cementing Program
Requirements of 20 AAC 25.005(c)(6)
An application for a Permit to Drill must be acc:ompanied by eact/ of the following ìtems¡ exæpt for an/tem already on file with the
commission and identified in the applic:<'7tion:
(6) a complete proposed casing and æmenting program as required by 20 MC 25.03Q, and a description of any slotted liner; pre-
perforated liner; or screen to be 1Ì7stalled.:
CasinCi and Cementing ProCiram
Hole Top Btm
Csg/Tbg Size Weight Length MD/TVD MD/TVD
00 (in) (in) (Iblft) Grade Connection (ft) (ft) (ft) Cement Program
30 X 16 42 62.5 H-40 Welded 80 28 / 28 108 / 108 9 cy High Early
Insulated
9-5/8 12-1/4 40 L-80 BTC ~/ 4235' 28'/28' 4263'/2662' Cemented to surface
as per APD 203-022
7 8-1/2 26 L-~' BTC-M~, 8414' 28'/28' 8442'/6049' 240 sx 15.8 ppg 'G' w/
add.
/ Planned TOC= 7342'
3-1/2 9.3 L-80 EUE 8rd 8014' 28' / 28' 8042'/5724' SAB- 3 packer set at
Mod 8042' MD.
If 7" casing must be top-set above the Kuparuk C sand, 6 1/8" hole would be drilled to total depth and a
3 112" 9.3 ppf L-80 SLHT production liner will be cemented across the productive interval.
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 tl7e followli7g items, except for an item already on file with the
commission and identified in tl7e application:
(7) a diagram and desCliption of the diverter system as required by 20 MC 25. 035~ unless this requirement is waived by the
commission l/flder 20 AAC 25:035(17)(2);
Please reference diverter schematic on file for Nabors 7ES.
8. Drilling Fluid Program
Requirements of 20 AAC 25.005(c)(B)
An application for a Permit to Drill must be accompanied by each of the fOllowing items/ except for ('1/7 item already 0/7 file with the
commission and identified i/7 the application:
(8) a drilling fluid program/ including a diagram and description of the drilling fll1ld :::ystern as required by 20 MC 25.033.:
Drilling will be done using mud systems having the following properties:
Production Hole mud properties
initial C40 Top Morraine Top HRZ Kuparuk
Density (ppg) 8.9 10.2 10.6 10.8 11.3 ,,/
Funnel Viscosity 40-55 42-55 42-58 42-58 42-58
(seconds)
Yield Point 11-15 20-25 20-25 20-25 20-25
(cP)
Plastic Viscostiy 6-12 8-15 8-16 8-18 15-25
(Iblt 00 sf)
10 second Gel 2-5 3-6 3-6 4-7 4-8
Strength (lblt 00 sf)
10 minute Gel 4-10 7-10 7-112 7-12 8-16
Strength (lb1100 sf)
pH 9-9.5 9-9.5 9-9.5 9-9.5 9-9.5
API Filtrate(cc) <6 <6 <6 <4 <4
Solids (%) 6-11 9-14 1 0-15 1 0-1 5 15-19
· J 8 .r~ if ,r\JA L
p, ¡U'i-. .
3S-08A PERMIT IT. DOC
Page 4 of 7
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)
~
APì )on for Permit to Drill, We1l3S-08A
Revision No.O
Saved: 10-Mar-03
Diagram of Nabors 7ES Mud System on file.
Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033.
9. Abnormally Pressured Formation Information
Requirements of 20 AAC 25.005 (c)(9)
An application for a Permit to Drill must be accompanied by eadl of the following Item5~ except for an item already on file with tfle
commission and identified in the application:
(9) for an exploratOlY or stratigraphic test wel¿ a tabulation setting out tile depths of predlçted abnormally geo-pres..<;ured strata as
required by 20 MC 25.033(f}/ /
NjA - 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 ead7 of tile following item::,~ exæpt for an item already on file with the
commis..c,ion and identified in tile applíGätion: ."
(10) for an exploratory or stratigrapfJic test well, a seismic refraäíon or reflection anaIY!Jì^:" Bþ1equired by 20 AAC 25: 061 (a)/
NjA - 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 f'ollowing item~ except f'or an item already on file with the
commi!;,""Sion and Identified in the applícation:
(1.1) for a we/I drilled from an off..,l7ore platfvrm~ mobile bottom-founded structure~ jack"up rig~ or floating drilling ves.."ie¿ an analysis
of seabed conditions as required by 20 AAC 25.061(b),·
/"
NjA - Application is not for an offshore well. (
12. Evidence of Bonding
Requirements of 20 AAC 25.005 (c)(12)
An application tor a Permit to Dlill n7llst be accompanied by each of the f'ollowing item~ except for an item already on tHe wIth the
commission and identified in the application:
(12) eVIdence showing that the requirements of 20 MC 25.025 {8onding}f1ave been met;
Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. /'
13. Proposed Drilling Program
Requirements of 20 AAC 25.005 (c)(13)
An application fo(' a PermIt to Drill must be ac"Companied by each of the following Items, except for an item already 017 file with the
commission and Identified in the applk-ation:
The proposed drilling program is listed below. Please refer as well to Attachment 3, Well Schematic.
1. Drill off cement plug and sidetrack well with a planned kick-off point of 4400' MD. /
2. Drill S-1/2" hole to total depth according to directional plan. Run LWD logging equipment w~'
GR, resistivity, and density-neutron. Run 7" 26# L-SO BTCM casing to surface and cement.
Note: If significant hydrocarbon zones are present above the Kuparuk C sand, sufficient cement
will be pumped for isolation in accordance with 20 AAC 25.030(d)(3)(C). /'
7. Run 3-1/2" 9.3#, L-SO Srd EUE Srd-Mod completion assembly wj SAB-3 permanent packer and
PBR. Set packer 100' above top planned perforation, shear out of PBR, PjU tubing hanger, and
land tubing. Pressure test tubing to 3500 psi. Pressure test 3 V2" x 7" annulus to 3500 psi./
Burst shear valve for freeze protect.
S. Set TWC and ND BOPE. Install and pressure test production tree.
9. Freeze protect. Secure well. Rig down and move out.
10. Handover well to Operations Personnel.
( ",~.f"dAL
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3S-0BA PERMIT IT. DOC
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}
APi )on for Permit to Drill, We1l3S-08A
,I Revision No.O
Saved: 10-Mar-03
14. Discussion of Mud and Cuttings Disposal and Annular Disposal
Requirements of 20 AAC 25.005 (c)(14)
An application fvr a Perrmt to Drill mustc be acc'Ompanied by eaäl of the following item~ except for an item already on file with the
commission and identified in the application:
(14) a generl~1 description of how tile operator plans to dispose ol drillli7g mud and cuttings and a statement of whether the
operator intends to request authorization under 20 AAC 25.080 lor an annular disposal operation in the well./
Waste fluids generated during the drilling process will be disposed of down a permitted annulus on 3S
pad or hauled to a KRU Class II disposal well. All cuttings will be disposed of either down a permitted
annulus on 3S pad or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for
injection down an approved disposal well.
At the end of drilling operations, an application may be submitted to permit 3S-08A for annular pumping
of fluids occurring as a result of future drilling operations on 3S pad.
15. Attachments
Attachment 1 Directional Plan
Attachment 2 Drilling Hazards Summary
Attachment 3 Well Schematic.
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3S-0BA PERMIT IT. DOC
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.~
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Sperry-Sun Drilling Services
ConocoPhi//ips A/ask
North S/opeAl '
Kuparuk R-
35-0
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roposal Report
10 March~ 2003
Surface Coordinates: 5993923.49 N, 476305.43 E (70023' 40.3066" N, 1500 11' 34.0341" W)
Grid Coordinate System: NAD27 Alaska State Planes, Zone 4
Kelly Bushing: 55.80ft above Mean Sea Level
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Proposal Ref: pro 1995
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ConocoPhillips Alaska, Inc.
North Slope, Alaska
Palm (3S Pad)
3S-08A=allback (wp01)
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2000,,;'
I...·..·"
....::~,\'
'''~''<.
2500
I
3000
I
3500
1
3250 -
Sidetrack Point ... Kick off of Cmt Plug
@ 5.0o/100ft in 8-1/2" Hole:
4400.0Oft MD, 2717.84ft TVD
2750 -
<) SIX ('s,~ PI
MD: -I2(i.U\()1I
¡VI): 2('(,1.6211
S)()()·OO
Reference is True North st.jJO.oo ·
3750 - - 3750
Current Well Properties
Well: 3S-08 Plan
ã) Horizontal Coordinates: S9()()·(~) ·
Ref. Global Coordinates: 599392:,.49 N, 476305.43 E
0 Ref. Structure : 80.02 N, 149.82 W ~~
en Ref. Geographical Coordinates: 70" 23' 40.3066" N, 209" 48' 25.9659" E
8 2492' FNL & 954' FEL, SEC. 1B- T12N - RBE ~ Q:j "
..c: RKB Elevation: 55.BOft above Mean Sea Level "'*'
ä. North Reference: True North @';¡<
Q) 4250 - Units: Feet (US) .::::. Ø}>' - 4250
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7" Cs~ PI.
MD: &442.-I4fl
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TARGET (3S-08 BHL 2 Fallback) :
/ 8142.44ft MD, 5805.80ft TVD
// (1371' FSL & 1140' FWL, Sec. 17-T12N-R8E)
- 5750
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Circle, Radills: ISO. (J(Y¡
5805.80 'IT/), 1-1/ (¡)j.J S, 2(),)1J.07 t;
6250 -
Proposed BHL @ 8442.44ft MD/, 6048.98ft TVD
(1374' FSL & 964' FWL, Sec. 17-T12N-R8E)
- 6250
I
2000
I
2500
I
3000
I
3500
Scale: 1 inch = 500ft
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ConocoPhillips Alaska, Inc.
North Slope, Alaska
Palm (3S Pad)
3S-08AFallback (wp01)
Scale: 1 inch = 300ft
1500
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18100 ~,()().(X)
2100
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3S-USFB (Ceo Target)
Circle, Radim: 150.aOft
5805.80 TVD, 1416.84 S, 2099.07 E
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7" Csg Pt.
MO: 8442,44ft
TVO: 6048.98ft
-1 650 -
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Reference is True North
Current Well Properties
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Horizontal Coordinates:
Ref. Global Coordinales :
Ref. Structure :
Ref. Geographical Coordinates :
3S-08 Plan
RKB Elevation:
North Reference :
Units:
5993923.49 N, 476305.43 E
~g;Of}'J4ci~:i"~, 209' 48' 25.9659" E
2492' FNl & 954' FEL, SEC. 18- T12N· R8E
55.8Oft above Mean Sea Level
True North
Feet (US)
APP OVED Plan
2400
1
Eastings(3S-08)
2700
1
3000
I
3300
1
3600
I
3900
1
95/8" Csg Pr
;\iID: 4263.00 ~m
TVD: 2661.62 TVD
Sidetrack Point ... . 1/2" HI'
Kick off of Cmt Plug @ 5.00/100ft In 8- 0 e.
4400.00ft MD, 2717.84ft TVO
- -1050
- -1350
3S-0~ Fallback (wp~1)
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End Oir, Start Sail @ 35.84° :
6406.27ft MO, 4398.44ft TVO
- -1650
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TARGET (38-08 BHL 2 Fallback) :
8142.44ft MO, 58GS.80ft TVO
(1371' FSL & 1140' FWL, 8ee 17-T12N-R8E)
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Proposed BH L
@ 8442.44ft MOl, 6048.98ft TVD
(1374' FSL & 964' FWL, See 17-T12N-R8E)
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2100
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1500
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1800
Scale: 1 inch = 300ft
DrillQuesl 3.03.02.002
- -1950
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2400
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2700
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3000
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3300
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3600
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3900
Eastings(3S-08)
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MD Inc Azim. SSTVD TVD N/S Comment
(ft) (Deg) (Deg) (ft) (ft) (ft) (ft) (ft) (ft) '-'
4400.00 65.60 106.57 2662.04 2717.84 1095.57 S 2720.95E 5992819.30N 479022.89E 0;00 2931.56 SToffCrntPJug@.··S.OO!100ft(S·1/2"Hole)
6075.17 20.16 259,35 4051.00 4106.80 1427.91 8 3269.63 E 5992485.23 N 479570.52 E 5.00 3560.82 C-40 (K-3)
<:::) 6406.27 35.84 271.12 4342.63 4398.43 1436.63 8 3115.55 E 5992476.99 N 479416.41 E 5.00 3419.01 End Dir; 8tart 8ail
::r, 7393.63 35.84 271.12 5143.00 5198.80 1425.38 8 2537.48 E 5992490.08 N 478838.38 E 0.00 2871.96 Top Morraine
-. 7698.33 35.84 271 .12 5390.00 5445.80 1421.91 8 2359.08 E 5992494.12 N 478659.99 E 0.00 2703.13 Top HRZ
~:' ~) 7920.39 35.84 271 ,12 5570.00 5625.80 1419.37 8 2229.08 E 5992497.06 N 478530.00 E 0.00 2580.10 Base HRZ
"""""~......:.- "' 8056.09 35.84 271.12 5680.00 5735.80 1417.83 8 2149.63 E 5992498.86 N 478450.55 E 0.00 2504.92 K-1
-. .. 8142.44 35,84 271.12 5750.00 5805.80 1416,84 8 2099,07 E 5992500.00 N 478400.00 E 0.00 2457.07 TARGET (38-08 Fallback)
~..... 8178.22 35.84 271.12 5779,00 5834.80 1416.44 8 2078.13 E 5992500.47 N 478379.06 E 0.00 2437.25 Miluveach
"l.~ 8442.44 35.84 271 .12 5993.18 6048.98 1413.43 8 1 923.43 E 5992503.98 N 478224.37 E 0.00 2290.85 Proposed BHL
r--
.----
Sperry-Sun Drilling Services
Proposal Report for 3S-08tPlan
Revised: 10 March, 2003
Western North Slope
Measured
Depth
(ft)
Sub-Sea
Depth
(ft)
Vertical
Depth
(ft)
Local Coordinates
Northings Eastings
(ft) (ft)
Global Coordinates
Northings Eastings
(ft) (ft)
Incl.
Azim.
3S-08 (Rig Surveys)
0.00 0.000 0,000 -55.80 0.00 0.00 N 0.00 E 5993923.49 N 0.00
100.00 0.191 257.158 44.20 100.00 0.08 N O.22W 599392&57 N 0.191 -0.24
200.00 1.254 171.622 144.19 199.99 0.96 S 0.26 W 5003922:@3 N 1.254 0.09
300.00 4.494 162.374 244.05 299.85 5.91 S ~f,1.17 E~f~~599a917.!~BN 3.262 3.12
400.00 6.542 161.289 343.59 399.39 14.95 S "\'~93~'YXIS99~8.52 N 2.050 8.81
-
500.00 9.318 156,018 442.61 498.41 9.32~E~~'ê/ 5993895.68 N 476314.66 E 2.867 18.26
600.00 11.570 154.824 540.94 596.74 16.6'SJ}£ 5993879.06 N 476321.94 E 2.262 30.83
700,00 13.729 148.110 638.50 694.30 26.94 E 5993859.68 N 476332.17 E 2.608 47.11
C) 800.00 16.355 141,608 735.11 790.91 41.97E 5993838.68 N 476347.13 E 3.117 68.40
900.00 19.036 136.934 830.34 886.14 61.87 E 5993815.56 N 476366,95 E 3.033 94.98
::(J 1000.00 20.388 133.686 924.38 9~cR~ 1 ' 85.85 E 5993791.37 N 476390.86 E 1 .739 125.77
~-~
C~ 1100.00 23.341 127.261 1017.34 "'~ OI~~J 113.75 E 5993767.27 N 476418.69 E 3.797 160.20
1200.00 26.700 121,187 1107.93 "~~~~~~~l~~ "- 148.79 E 5993743.47 N 476453.65 E 4.225 201.23
1300.00 30.798 118,614 11 95J~2 190.51 E 5993719.58 N 476495.30 E 4.280 248.56
1400.00 35.548 116,848 t279i32 -i-_-- 1335:12 238.92 E 5993694.04 N 476543.63 E 4.846 302.73
"
;.,L~ ..- -c·_____-_,_
1500.00 39.947 114.876 >1358.36' 1414.16 255.37 S 294.02 E 5993667.19 N 476598.64 E ,/ 4.561 363.63
Q-- 1600,00 43.381 115/129' 1433.09 1488.89 283.51 S 354.19 E 5993638.86 N 476658.72 E 3.438 429.79
1700.00 48.598, 112:262 1502.52 1558.32 312.17 S 420.15 E 5993609.99 N 476724.59 E 5.609 501.58
1800.00 53.347 112.616 1565.59 1621.39 341.88 S 491.80 E 5993580.05 N 476796.14 E 4.757 579.07
1900,00 59.531 11:2.501 1620.93 1676.73 373.43 S 568.82 E 5993548.26 N 476873.06 E 6.185 662.23
2000,00 64.332 114,562 1666.73 1722.53 409.38 S 650.06 E 5993512.05 N 476954.19 E 5.133 750.88
2100,00 63.242 114.159 1711.33 1767.13 446.23 S 731.63 E 5993474.94 N 477035.64 E 1.149 840.12
2200.00 64.380 113.165 1755.63 1 811 .43 482.65 S 813.54 E 5993438.26 N 477117.44 E 1 .447 929.55
2300.00 65.637 112.217 1797.60 1853.40 516.83 S 897.62 E 5993403.82 N 477201.41 E 1.522 1020.25
2400.00 65.965 111 .278 1838.58 1894.38 551.82 S 981.86 E 5993368.56 N 477285.54 E 0.917 1111.38
2500.00 65.999 108.965 1879.16 1934.96 582.39 S 1067.98 E 5993337.71 N 477371.56 E 2,113 1202.76
2600.00 65.961 109,325 1919.95 1975.75 612.21 S 1154.28 E 5993307.63 N 477457.76 E 0.331 1294.05
2700,00 65.651 107,784 1960.78 2016.58 641.94 S 1240.58 E 5993277.62 N 477543.97 E 1.439 1385.32
2800,00 65.507 105.041 2002.26 2058.06 667.55 S 1327.88 E 5993251 .73 N 477631.19 E 2.502 1476.12
2900.00 65.455 104.956 2043.71 2099.51 690.52 S 1415.94 E 5993228.48 N 477719.17 E 0.093 1566.72
10 March, 2003 - 8:25
Page 2 of7
ConocoPhillips
Comment
--.?'
-
DrillQuest 3.03.02.002
Sperry-Sun Drilling Services
Proposal Report for 3S-08A1an
Revised: 10 March, 2003
ConocoPhilHps
Western North Slope
Measured Sub-Sea Vertical Local Coordinates Global Coordinates
Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings
(ft) (ft) (ft) (ft) (ft) (ft) (ft)
3000,00 65.728 105,274 2085.12 2140.92 714.40 S 1503.78 E 5993204.33 N 1657.43
3100.00 65.957 106.683 2126.01 2181.81 739.29 S 1591.57 E 5993179.16 N 1748.44
3200.00 65.738 106,132 2166.87 2222.67 765.39 S 1679.03 E 5993152.78 N 1839.55
3300.00 65.123 107.106 2208.42 2264.22 791.21 S 1766.24 E 5993126.69 N 1930.34
3400.00 65.376 108.373 2250.34 2306.14 818.87 S 1852.72 E 599 ~ 5N 2021,05
3500,00 65.828 107.889 2291.63 2347.43 }N 478242.00 E 0.631 2112,08
3600.00 65.727 107.437 2332.62 2388.42 y",'}' 2.27 N 478328.86 E 0.425 2203.22 -_/
3700.00 65.329 108.026 2374.17 2429.97 -014.09 N 478415.34 E 0.668 2294.11
3800.00 65.835 106,988 2415.41 2471.21 992986.52 N 478502.17 E 1.072 2385.12
3900.00 65.659 106.717 2456.45 2512.25 5992959.83 N 478589.36 E 0.304 2476.17
a 4000,00 65.537 107.293 2497.89 2553.69 5992933.32 N 478676.43 E 0.538 2567.03
4100.00 65.788 108.653 2539,01 2594.81 5992904.45 N 478762.88 E 1.264 2658.14
~~ 4200,00 65.806 108.367 2580.05 2635.85" 5992875.27 N 478849.28 E 0.261 2749,30
4276.00 65.914 108.265 2611.13 269~;9~~ 5992853.27 N 478915.05 E 0.188 2818.63 9 5/8in Casing
~.c-: 4300.00 65.863 107.918 2620,93 26r61]:$t 5992846.39 N 478935.85 E 1.337 2840.52
- eJ , '", ~
4400.00 65.595 106.573 2;¡;1c~33.4 1095.57 S 2720.95 E 5992819.30 N 479022.89 E 1.255 2931.56 Sidetrack Point ... Kick off of Cmt PI
@ 5.001100ft in 8-112" Hole: 4400.01
L~ MD, 2717.84ft TVD
~---- 35-08 Fallback (wp01)
4500,0.0 60.661 1.07.482 2707,23 2763.03 1121.67 S 2806.22 E 5992792.93 N 479108.08 E 5.000 3020.61
4600,00 55.734 108.483- 2759.91 2815.71 1147.88 S 2887.03 E 5992766.46 N 479188,81 E /" 5.000 3105.52
4700,00 '50.816 109.610 2819.69 2875.49 1174.00 S 2962.78 E 5992740.10 N 479264.47 E 5.000 3185.63
4800,00 45.910 110.905 2886.11 2941.91 1199.84 S 3032,88 E 5992714.04 N 479334.49 E 5.000 3260.34
4900.00 41 .022 112.436 2958.67 3014.47 1225.20 S 3096.80 E 5992688.48 N 479398.33 E 5.000 3329.08
-
5000.00 36.159 114.299 3036.81 3092.61 1249.88 S 3154.06 E 5992663.62 N 479455.51 E 5.000 3391.33
5100.00 31.331 116.651 3119.94 3175.74 1273.69 S 3204.21 E 5992639.65 N 479505.59 E 5.000 3446.61
5200.00 26.561 119.755 3207.43 3263.23 1296.47 S 3246.89 E 5992616.74 N 479548.19 E 5.000 3494.49
5300.00 21 .885 124.088 3298.61 3354.41 1318.02 S 3281.75 E 5992595.07 N 479582.99 E 5.000 3534.63
5400,00 17.378 130.582 3392.78 3448.58 1338.20 S 3308.55 E 5992574.81 N 479609.72 E 5.000 3566.71
5500.00 13.218 141.205 3489.24 3545.04 1356.83 S 3327,07 E 5992556.12 N 479628.18 E 5.000 3590.48
5600.00 9.853 159.975 3587.24 3643.04 1373.79 S 3337.17E 5992539.13 N 479638.22 E 5.000 3605.77
5700.00 8.312 190.568 3686.04 3741.84 1388.95 S 3338.77 E 5992523.97 N 479639.78 E 5.000 3612.47
5800.00 9.526 222.319 3784.88 3840.68 1402.18 S 3331.87 E 5992510.76 N 479632.84 E 5.000 3610.51
5900.00 12.730 242.516 3883.03 3938.83 1413.39 S 3316.51 E 5992499.59 N 479617.45 E 5.000 3599.91
10 March, 2003 - 8:25
Page 3 of7
Dri/IQuest 3.03.02.002
Sperry-Sun Drilling Services
Proposal Report for 35-08 "'an
Revised: 10 March, 2003
ConocoPhi/Hps
Western North Slope
Measured Sub-Sea Vertical Local Coordinates Global Coordinates
Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings
(ft) (ft) (ft) (ft) (ft) (ft)
6000.00 16.823 253.902 3979.72 4035.52 1422.49 S ~m:~~! mg~:~~ ~\~~ ']~~ 3580.76
6075.17 20.1 64 259.349 4051.00 4106.80 1427.91 S 3560,82 C-40 (K-3)
6100.00 21.298 260.781 4074.23 4130.03 1429.42 S 3553.20
6200.00 25.958 265.324 4165.82 4221.62 1434.12 S 3517.44
6300.00 30.719 268.552 4253.82 4309.62 1436.55 S 3173.83 E 59~~i~~9 N'~'Il9474.69 E 5.000 3473.75
6400.00 35.540 270.982 4337.54 4393.34 1436.70 S ~~~~ß\;~!~ ~'E~~:~~ ~ ~:gg~ 3422.47
6406.27 35.844 271.115 4342.63 4398.43 1436.63 S 3419.01 End Dir, Start Sail @ 35.84°:
6406.27ft MD, 4398.44ft TVD
6500.00 35.844 271.115 4418.61 4474.41 i¡J~ ~\t!~1!~1:mH~ ~ 479361.53 E 0.000 3367.08
6600.00 35.844 271.115 4499.68 4555.48 479302.99 E 0.000 3311.67
6700.00 35.844 271.115 4580.74 4636.54 479244.45 E 0.000 3256.27
a 6800.00 35.844 271.115 4661,80 4717.60 tl~ "þ~~~~:~~ ~ ~~~~1~~:~~ ~ 479185.90 E 0.000 3200.86
6900.00 35.844 271 .115 4742.86 479127.36 E 0.000 3145.46
::t:J 7000.00 35.844 271.115 4823.92 f4~~6 S 2767.93 E 5992484.86 N 479068.82 E 0.000 3090.05
~:':'~.'<.!.!'I 7100.00 35.844 271.115 4904,98 1428.72 S 2709.39 E 5992486.19 N 479010.28 E 0.000 3034.64
~~;'~) 7200.00 35.844 271.115 4986.04 1427.58 S 2650.84 E 5992487.51 N 478951.73 E 0.000 2979.24
7300.00 35.844 271.115 ß06I.11 1426.44 S 2592.29 E 5992488.84 N 478893.19 E 0.000 2923.83
7393.63 35.844 271.115 5143j)() 5198.80 1425.38 S 2537.48 E 5992490.08 N 478838.38 E 0.000 2871.96 T?p Morraine
...... 7400.00 35.844 271.115 :5148.17 5203.97 1425.30 S 2533.75 E 5992490.16 N 478834.65 E 0.000 2868.43
-'_~ ~.~':;J 7500.00 35.844 271.1 15 5229.23 5285.03 1424.16 S 2475.20 E 5992491.49 N 478776.10 E 0.000 2813.02
§~-- 7600.00 35.844 271.115 5310.29 5366.09 1423.03 S 2416.65 E 5992492.81 N 478717.56 E 0.000 2757.61
7698.33 35.844 271.115 5390.00 5445.80 1421.90 S 2359.08 E 5992494.11 N 478659.99 E 0.000 2703.13 Top HRZ
7800.00 35.844 271.115 5472.41 5528.21 1420.75 S 2299,56 E 5992495.46 N 478600.47 E 0.000 2646.80
7900.00 35.844 271 .115 5553.47 5609.27 1419.61 S 2241.01 E 5992496.79 N 478541.93 E 0.000 2591.40
7920.39 35.844 271.115 5570.00 5625.80 1419.37 S 2229.08 E 5992497.06 N 478530.00 E 0.000 2580.10 Base HRZ
8000.00 35.844 271.115 5634.54 5690.34 1418.47S 2182.47 E 5992498.11 N 478483.39 E 0.000 2535.99
8056.09 35.844 271.115 5680,00 5735.80 1417.83 S 2149.63 E 5992498.86 N 478450.55 E 0.000 2504.92 K-1
8100.00 35.844 271.115 5715,60 5771.40 1417.33 S 2123.92 E 5992499.44 N 478424.85 E 0.000 2480,59
8142.44 35.844 271.115 5750.00 5805.80 1416.84 S 2099.07 E 5992500.00 N 478400.00 E 0.000 2457.07 TARGET (3S-08 BHL 2 Fallback) :
8142.44ft MD, 5805.80ft TVD (137'
FSL & 1140' FWL, See 17-T12N-
R8E)
Kuparuk
Target - 3S-02FB, 150.00 Radius.,
Current Target
8178.22 35.844 271 .115 5779.00 5834.80 1416.44S 2078.13 E 5992500.47 N 478379.06 E 0.000 2437.25 Miluveach
10 March, 2003 - 8:25 Page 4 of7 DrillQuest 3.03.02.002
.C':)
,J,~J
tt-:.
.:......;. )
.~--"-- --::u
:...~~
m~
Sperry-Sun Drilling Services
Proposal Report for 3S-08¡1llan
Revised: 10 March, 2003
Western North Slope
Measured Sub-Sea Vertical Local Coordinates Global Coordinates
Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings
(ft) (ft) (ft) (ft) (ft) (ft) (ft)
8200,00 35.844 271.115 5796.66 5852.46 1416.19 S 2065.37 E 5992500.76 N
8300.00 35.844 271.115 5877.72 5933.52 1415.05 S 2006.83 E 5992502.09 N
8400.00 35.844 271 .115 5958.78 6014.58 1413.91 S 1948.28 E 5992503.41 N
8442.44 35.844 271 .115 5993.18 6048.98 1413.42 S 1923.43 E 5992503.98 N
All data is in Feet (US SUNey) unless otherwise stated. Directions and coordinates are
Vertical depths are relative to 3S-08. Northings and Eastings are relative to 3S-08.
Global Northings and Eastings are relative to NAD27 Alaska State Planes, Z 4.
The Dogleg Severity is in Degrees per 100 feet (US SUNey)·cò--/'
Vertical Section is from 3S-08 and calculated along an Azimuth of 110.00Qo:{Truet.
Magnetic Declination at Surface is 25.165°(08-Mar-03) <,
Based upon Minimum CUNature type calculation~,?~i'M@~~f~d 8442.44ft.,
The Bottom Hole Displacement is 2386.91ft.. in:tfiéQJr~ptiòti~~Ð26.31 0° (True).
The Along Hole Displacement is 5104.48ff,thePfallDªcFTortuosity is 2.647°/100ft and the Directional Difficulty Index is 5.7.
Comments
Measured
Depth
(ft)
Station Coordinates
TVD Northings Eastings
(ft) (ft) (ft)
Comment
ConocoPhillips
2425.18
2369.77
2314.37
2290.85
Proposed BHL @ 8442.44ft MDI,
6048.98ft TVD (1374' FSL &964'
FWL, Sec. 17-T12N-R8E)
7in Casing
c-'"
-
4400.00
6406.27
8142.44
8442.44
2717,84
4398.44
5805.80
6048.98
1095.57 S
1436.63 S
1416.84 S
1413.42 S
2720.95 E
3115.55 E
2099.07 E
1923.43 E
Sidetrack Point... Kick off of Cmt Plug @ 5.0o/100ft in 8-1/2" Hole: 4400.00ft MD, 2717.84ft TVD
End Dir, Start Sail @ 35.84° : 6406.27ft MD, 4398.44ft TVD
TARGET (3S-08 BHL 2 Fallback): 8142.44ft MD, 5805.80ft TVD (1371' FSL & 1140' FWL, See 17-T12N-R8E)
Proposed BHL @ 8442.44ft MDI, 6048.98ft TVD (1374' FSL & 964' FWL, Sec. 17-T12N-R8E)
10 March, 2003 - 8:25
Page 5 of 7
DrillQuest 3.03.02.002
a
:-:~J
~-=:>~--- ~
c:. )
-";;j
1-~-
Western North Slope
Formation Tops
Formati on Plane
(Below Well Origin)
Sub-Sea Dip Up-Dip
(tt) Angle Dirn.
Profile
Measured Vertical
Depth Depth
(ft) (tt)
Sperry-Sun Drilling Services
Proposal Report for 35-08 Wan
Revised: 10 March, 2003
Penetration Point
Sub-Sea
Depth Northings
(tt) (tt)
Fo
4051 ,00 0.000 0.000 6075,17 4106.80 4051.00
5143.00 0.000 0.000 7393.63 5198.80 5143.00
5390.00 0.000 0.000 7698.33 5445.80 5390.00
5570.00 0.000 0.000 7920.39 5625.80 5570.00
5680.00 0.000 0.000 8056.09 5735.80 5680.00
5750.00 0.000 0.000 8142.44 5805.80
5779.00 0.000 0.000 8178.22 5834.80
Casina details
Fr om
Measured Vertical
Depth Depth
(tt) (tt)
.'T o.:.?
Measured' V___~Ì'tical
" Oèpth"''Oepth
(ftr (tt)
<Surtace> -<,Surface>'" 4276,00
<Surtace> <Surface> '. 8442.44
10 March, 2003 - 8:25
2666.93
6048.98
2099.07 E Kuparuk
2078.13 E Miluveach
Casing Detail
9 518in Casing
7in Casing
Page 6 of7
ConocoPhíllips
-"'"
-'
DrillQuest 3.03.02.002
a
~
~J.:~,~'.~9
r )
.-~~
~_....&::"....~,
Sperry-Sun Drilling Services
Proposal Report for 3S-Ds/flan
Revised: 10 March, 2003
Western North Slope
Targets associated with this weJ/path
Target Name
Target
TVD
(ft)
3S-02FB
2099.07 E
478400.00 E
1500 10' 32.5623" W
Mean Sea Level/Global Coordinates:
Geographical Coor
T
10 March, 2003 - 8:25
Page 70f7
Target
Shape
Circle
Co no coP hill ips
Target
Type
Current Target
.--,'
---
DrillQuest 3.03.02.002
)
Sperry-SUD
Anticollision Report
C~mpany:
Fi~ld:. ,"
Reference Si~e:
Ref~re~c~)YeÚ:~ '
:Reference W~Upath:
PhHlipsAla$kålnC,
,KuPa.ruKRiver Unit
KUþaruk 3SPad
Plan:;3S~Oa, .'
Plan:3,S,~08,~'
3/10/2003
'Time: ,Q6:37:Ö7"
Page';
NO GLOBAL SCAN: Using user defined selection & scan criteria
Interpolation Method: MD Interval: 50.000 ft
Depth Range: 4400.000 to 8442.377 ft
Maximum Radius: 1029.702 ft
Reference:
Error Model:
Scan Method:
Error Surface:
Well:..Plan:3$-08,.Jrue.. North
RKB=: 55.8'M~~55;8. '
'Pb;
Principal Plan & PLANNED PROGRAM
ISCWSA Ellipse
Trav Cylinder North
Ellipse + Casing
'. Co-ordinate(NE) R~ference:
, Vertical (TVD )Refe~e,nCé:
Survey Program for Definitive WeUpath
Date: 3/10/2003 Validated: No
Planned From To Survey
ft ft
87.000 4400.000
4400.000 8442.377
Version:
Toolcode
Tool Name
3S-08 (Rig) (4)
Planned: 3S-08 FB (wp01) V1
MWD
MWD
MW D - Standard
MW D - Standard
Casing Points
"MO,'. 'TVD
'" f,~ ,'.. ,ft ."
4166.000 2621.900
8442.377 6048.993
'Difin1eter
"In
9.625
7.000
Hole~Sii~,
"in
',Nam~
12.250
8.500
95/8"
7"
Summary
" <~~~_~~"~m~~~~~J~..-~Offset Wellpatb '.'. ~-"-~7--·~-~+·~.I_·~~> '
,Sit~ ....., . \Vëll ,.' '. '. WeUpath'
RefereJ;lce, Orrset.,Ctr"Ctr No-Go', ~Uo~~le, !~!'
MD,M)) '))isþ)nc~ A;~~ä. ' ':pe".atJ.o.n '.w....·.~..'...·. 'nin.·....'g. '>1. :
ft ' ',f~ 'ft n 'ft',' " 'I ..' ,.,.'.,'
3S-08 (Rig Surveys) V5 4400.003 4400.000 0.280 1.099 -0.366 FAIL: No Errors
Kuparuk 3S Pad
Plan: 3S-08
OR t /~ - "," j~. !
. , 'ì J L~,' ..
~
ToMD
4300
4400
4500
4600
4700
4800
4900
5000
5200
5400
5600
5800
6000
6500
7000
7500
8000
8500
9000
".~""",/
-10.0
~ ----5.0
f
.;,
q
.~
270 9O~ -0 270- 90
~-
\ ;2
~ i E Pl~,3S-08('
;:c '-\~
\ a
c6
0') ----5.0
~....
! ~ in
~O -10.0
-15.0
-'
-20.0
-21.8 18<fLð
SECTIOK DETAILS
S MD n An TVD +;\;I-S +FJ-W Dleg TFaœ VSec Target
I 4-UXJ.OOO 65.59 106.57 2717.838 -1095.597 2721.003 0.00 0.00 2841.306
6-106.180 35.84 271.11 -1398.352 -1-136.722 3115.638 5.00 170.87 3361.317
3 81-12377 35.8-1 271.11 5805.800 -1-117.057 2099.232 0.00 0.00 2530.71-1 3S (BHU FB) 3S-08Pli'allback (wpOl)
-I 8.-1-12.377 35.8-1 271.11 60-18.995 -1-113.658 1923.605 0.00 0.00 2387.193
--- Approved Plan ---
Travelling Cylinder Azimuth (TFChAZ[) [deg] vs Centre to Centre Separation [lOOft/in] Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [10ft/in]
ColoW'
From
o
4300
4400
4500
4600
4700
4800
4900
5000
5200
5400
5600
5800
6000
6500
7000
7500
8000
8500
\VEUPATH DETAILS
p!an:3S·œFB
3S-OS (BHL#2 Falib""k).
Páfwt Wè~::¡th: 3s·œ \]lig Surw.),
Tiëcn:\lD: 4300.000
Ri2.: ~7ES
Reì.~ RKB = 55.8' )'1SL 55. 800ft
.S~.c-noll 0ri.2in 0mi!J Stm1ill2
AngJe +"KT--s +EI':-W From TVD
lOC:' t. :.:X :.CX
COMPA';Y DET.-'JLS
PbiJ4>s Mis!æ Inc.
Eœ:rnriIœ
KÍIparuk -
(,~\;i.1lation~fethod: ~iínimumÜlt\'allir~
Error Syste.m; ISCWSA
SC.aIJ Method: Teav C}1roer North
EzrŒ Surf2C¢: B£ptic;31 + G2ng
W2!Illng ~le1hod: R~s B:;wI
M'TI-COLLISION SETTINGS
50.000
8442.3 77
Plan: 3S-08 FB ("-pOl
-21.8
-20.0
-15.0
Interval:
To:
Reference:
ToMD
4300
4400
4500
4600
4700
4800
4900
5000
5200
5400
5600
5800
6000
6500
7000
7500
8000
8500
9000
Colour
Interpolarion Method:MD
Depth Range From: 4400.000
Maximum Range: 1029.ï02
FTom
o
4300
4400
4500
WIlLDETAII.5
~<:.ID" +~J8 ;.[J-\\' ~onh.íl!_O;: l:k>til I-':1r.ud, I..ong1iud~- Slot
ìC;;:,(!S \'}(67 119.g18 59')3913.52 P&J05.~5 7û'2.nO.307S 150' 1 1'3~.O.BW NA
SURVEY PROGRAM
DI;'.pth Fm Depth To SurveylPlau Tool
4400.000 &442.377 Planned: 3S-08 F13 (wpOl) V 1 MWD
-207
-2(XJ
-150
-100
0-50
~rJ
~_.-~-...', -
---.... .~O
)
--5U
._ '- ._:!:Þ
-~
-100
-]50
-200
-207
).
)
3S-08A Drillina Hazards Summary
8-1/2" Hole / 7" Casing Interval
Event
Shale stability in HRZ, K-l, and
Miluveach
High ECD and swabbing with
higher MW's required
Barite Sag
Differential Sticking
Abnormal Reservoir Pressure
Lost Circulation
Risk Level
Low
Moderate
Low
Moderate
Moderate
Moderate
I M itiqation Strateqy
Control with higher MW and proper drilling
practices.
Condition mud prior to trips. Monitor ECD's with
PWD tool while drilling across pay interval. Pump
and rotate out on trips as a last resort.
Good drilling practices as documented in well plan.
Periodic wiper trips. Do not leave pipe static for
extended period of time.
Follow mud weight schedule and do not fall behind.
Stripping Drills, Shut-in Drills, PWD Tools, Increased
mud weight as needed. Ensure adequate kick
tolerance prior to drilling pay interval.
Use PWD to monitor hole cleaning. Reduced pump
rates, Mud rheology, LCM. Use GKA LC decision
tree.
/
/'
3S-0BA Drilling Hazards Summary. doc
prepared by Scott Lowry
3/10/03
0, r"'-¡ .f , "'I ," '1".1 .11
; fk.l:: ,~ ")ì ¡,; !
~..,' 11 i \;î if '~if', ~
Page 1 of 1
)
KRU - 3S-08A Producer
Proposed Completion Schematic
Single Completion wI Jet Pump Contingency
/'
)
C' " , ~Ph" _1'1"'·
'onoco ,":1 ' IpS
16"x30"
insulated
conductor @
+1- 109' MO
r I
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Surface csg. æ
9-5/8"40# L-80 .....J
BTC (4263' MO I
2662' TVO)
Cemented to
surface
C
Sand Perfs
(to be done
after rig moves
off)
Production <:sg.
7" 26# L-80
BTCM (+1- 8442'
MO)
r
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3-1/2" FMC Gen V tubing hanger, 3-1/2" L-80 EUE8RO pin down. Special Drift 2.91"
3-1/2", L-80, 9.3# EUE8RO Spaceout Pups as Required. Special
Drift 2.91"
3-1/2" Camco OS Landing Nipple with 2.875" 10 No-Go profile set @ +1- 500' MD.
GLM Placement:
Valves #1-4: 3-%" x 1" KBUG
Place gas-lift mandrels at the following depths:
TVO Approximate MO
Placement TBO
Valve #5: 3-1/2" x 1-1/2" 'MMG' GLM wI OCR Dump Kill Valve (3000 psi casing to tubing
shear). 6' L-80 handling pups installed on top and bottom of mandrel.
1 Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing.
3-1/2" Baker 'CMU' sliding sleeve wI 2.813" Camco No-Go profile, EUE8RO
box x pin. 3-1/2" x 6' L-80 EUE8RO handling pups installed above
1 Joint 3-1/2", L-80. 9.3# EUE 8rd Mod Tubing.
6' Handling Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing.
Baker '80-40' PBR.
Baker 7" x 3-1/2" 'SAB-3' Permanent Packer set +1- 100' MO above top planned perf.
Minimum 10 through the packer 3.00".
6' Pup Joint 3-1/2", L-80. 9,3# EUE 8rd Mod Tubing.
3-112" Camco 'D' nipple wI 2.75" No-Go profile.
6' Pup Joint 3-1/2". L-80. 9.3# EUE 8rd Mod Tubing.
Baker 3-1/2" WL Re-entry Guide wI shear out sub. Tubing tail 50' above top planned perforation.
TO @ 8442' MO I 6049' TVO
(300' MO below base of pay)
Scott L Lowry 03/10/03
OR [ ,.,..., r ~,1 I
' l .:' -hJ
, . u ~J s i.í ~k:
'~
¡~
--'
62-14/311
1028
RECEIVED
MAR 1 0 2003
~ Oil & Gas Gon& CommisSion
Anchordge
I: 0 ~ ~ ~ 0 0 ~ I.. 1..1: 2 ~ 8 0 0 0 0 I.. 2 7 2 5 7111 ~ 0 28
(
ME¡V¡O~~_~_~__~_~~~
..¡-
~.... CHASE Chase Manhattan Bank USA, N.A. Valid Up To 5000 Dollars
.., 200 WMe Clay Center Dr_. Newark. DE 19711
I
¡,~~~g~~ :',:;::~~::<:~'>~:C_' .~~~. >.~e)~2__'~(W.RS m
DiHE ::t/.1. />tÅ_ / "l
~-~-
S. K. ALLSUP-DRAKE
PHILLIPS PETROLEUM COMPANY
700 G ST. ATO 1530
ANCHORAGE AK 99501
,
)
)
TRANSMIT AL LETTER CHECK LIST
CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO
BE INCLUDED IN TRANSMtTT AL LETTER
3S-ð'BlJ
WELL NAME
PTD#
/(":)3-037
CHECK WHAT
APPLIES
ADD-ONS
(OPTIONS)
MULTI
LATERAL
(If API number
last two (2) digits
are between 60-69)
"CLUE"
The permit is for a new wellbore segment of
existing well
Permit No, API No.
Production should continue to· be reported as
a function· of the original API number stated
above.
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
name (name on permit plus PH)
and API number (50
70/80) from records, data and logs acquired
for well (name on permit).
paOT
(PH)
SPACING
EXCEPTION
DRY DITCH
SAMPLE
Rev: 07/10/02
OJ ody\templates
The permit is approved subject to full
compliance with 20 AAC 25.055. Approval to
perforate and produce is contingent upon
issuance of a conservation order approving a
spacing exception.
(Company Name) assumes the liability of any
protest to the spacing exception that may
occur.
All dry ditch sample sets submitted to the
Commission must be in no greater than 30'
sample intervals from below the permafrost
or from where samples are first caught and
10' sample intervals through target zones.
WELL PERMIT CHECKLIST COMPANY (!~fi.,I{¡¡NELL NAME K~ ...5S-~,4 PROGRAM: Exp _ Dev ~ Redrll / Re-Enter _ Serv _ Well bore seg _
FIELD & POOL t/16/~ INIT ðLASS ~V /' t:J1L- GEOL AREA fS9n UNIT# / /I(J) ON/OFF SHORE 5!!!:L
ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . Y N
2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N
3. Unique well name and number. . . . . . . . . . . . . . . . . N
4. Well located in a defined pool.. . . . . . . . . . . . . . . . . N
5. Well located proper distance from drilling unit boundary. . . . N
6. W ell located proper distance from other wells.. . . . . . . . . N
7. Sufficient acreage available in drilling unit.. . . . . . . . . . . N
/7--.. 1 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . N
~ :5'¡'¡ ·D3 9. Operator only affected party.. . . . . . . . . . . . . . . . . . N
10. Operator has appropriate bond in force. . . . . . . . . . . . . N
11. Permit can be issued without conservation order. . . . . . . . N
12. Permit can be issued without administrative approval.. . . . ~N .
(Service Well Only) 13. Well located w/in area & strata authorized by injection order #
(Service Well Only) 14. All wells w/in ~ mile area of review identified. . . . . . . . .. N
ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . '¥-'-M- ,,/ ,1
16. Surface casing protects all known USDWs. . . . . . . . .. K'1f--¥-N- ~J..Y-e'/( ¿}' -L-;¿i.shÁ5 ~. ~
17. CMT vol adequate to circulate on conductor & surf csg. . . . -¥--N-Ã//)f- ¿;
18. CMT v~1 adequate to tie-in long s~ring to. surf csg. . . . . . . . ~ ¡;OÇ~ bt¿. AÐ.
19. CMT will cover all known productive hOrizons. . . . . . . . . . '~7' N
20. Casing designs adequate for C: T, B & permafrost. . . . . . . <.Y_ N ~ I b () 7 6Ç
21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . j.. N IU,fJ...,rS
22. If a re-drill, has a 10-403 for abandonment been approved. . .. N"S / l 0/ ()2f> .
23. Adequate we II bore separation proposed.. . . . . . . . . . . . ,N
24. If diverter required, does it meet regulations. . . . . . . . . . ,y N ,N/A-- f. /
25. Drilling fluid program schematic & equip list adequate. . . . . I.... N mæ.~ 1.'J1. 1M 1(. S f pCl .
26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N ¡J r
27. BOPE press rating appropriate; test to S r9 0 D psig. ~") N (t{, S 2- qq 7 p > ¿, .
28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . .:-k. N
29. Work will occur without operation shutdown. . . . . . . . . . . .' ~..,
30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y tv
31. Mechanical condition of wells within AOR verified. . . . . . . . -¥--N'" rJI/f-
32. Permit can be issued w/o hydrogen sulfide measures. . . . ~ N
33. Data presented on potential overpressure zones. . . . . . . . ¿fr' N
34. Sèismic anal~~is of shallo~ gas zones. . . . . . . . . . . . . ¡vII: Y
35. Seabed condition survey (If off-shore). . . . . . . . N
36. Contact name/phone for weekly progress reports. . Y N
GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING
APPR
DATE
APPR DATE
\iJGA- ) i IIlQ'~
(Service Well Only)
GEOLOGY
APPR DATE
/{'ð 3-//-()5
(Exploratory Only)
Rev: 2125/03
\welLpermiCchecklist
UIC ENGINEER
RPC_
TM
JH
JR
SFD~
WA ./
MW
COMMISSIONER:
SP ~ k; ~
-u--. - '-->
RR ~'">
DS
(
(
Commentsllnstructions:
)
Well History File
APPENDIX
Information of detailed nature that is not
particularly germane to the Well Pennitting Process
but is part of the history file.
To improve the readability of the Well History file and to
sim.plify finding infonnation, information of this
nature is accumulated at the end of the file under APPEN.DIX.
No special effort has been made to chronologically
organize this category of information.
)
)
6I03~D3 7
(/1/4
Sperry-Sun Drilling Services
LIS Scan Utility
$Revision: 3 $
LisLib $Revision: 4 $
Wed Apr 30 10:29:12 2003
Reel Header
Service name............ .LISTPE
Date.................... .03/04/30
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. . . . . . . . . . . . . . . . . . . . .03/04/30
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
Kuparuk
MWD/MAD LOGS
#
WELL NAME:
API NUMBER:
OPERATOR:
LOGGING COMPANY:
TAPE CREATION DATE:
#
JOB DATA
3S-08A
501032045001
Conoco Phillips Alaska, Inc.
Sperry-Sun Drilling Services
30-APR-03
JOB NUMBER:
LOGGING ENGINEER:
OPERATOR WITNESS:
MWD RUN 3
MW0002306056
P. SMITH
M. THORNTON
#
SURFACE LOCATION
SECTION:
TOWNSHIP:
RANGE:
FNL:
FSL:
FEL:
FWL:
ELEVATION (FT FROM MSL 0)
KELLY BUSHING:
DERRICK FLOOR:
GROUND LEVEL:
18
12N
8E
2492
954
.00
56.30
27.70
#
WELL CASING RECORD
1ST STRING
2ND STRING
OPEN HOLE CASING DRILLERS
BIT SIZE (IN) SIZE (IN) DEPTH (FT)
8.500 9.625 4263.0
~
)
)
3RD STRING
PRODUCTION STRING
#
REMARKS:
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. THIS WELL WAS EFFECTED BY KICKING OFF CEMENT IN THE
PLUGGED-BACK
3S-08 WELLBORE. 3S-08A, TOO, WAS TD'D PREMATURELY DUE
TO POOR RESERVOIR
QUALITY.
4. MWD RUN 1 WAS DIRECTIONAL ONLY. NO DATA ARE INCLUDED
IN THIS
PRESENTATION.
5. MWD RUN 3 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY
(DGR,
UTILIZING GEIGER-MUELLER TUBE DETECTORS) i
ELECTROMAGNETIC
WAVE RESISTIVITY-PHASE 4 (EWR4) ¡STABILIZED
LITHO-DENSITY (SLD) i
AND COMPENSATED THERMAL NEUTRON POROSITY (CTN).
6. MWD DATA ARE CONSIDERED PDC PER E-MAIL AUTHORIZATION
FROM THE GKA
GEOSCIENCE GROUP.
7. MWD RUN 3 REPRESENTS WELL 3S-08A WITH API#
50-103-20450-01. THIS
WELL REACHED A TOTAL DEPTH OF 8475' MD / 6116' 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, ACAL-
DERIVED HOLE SIZE) .
CTFA SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE.
CTNA SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE.
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.
SLDSLIDE = SLIDE INTERVALS ACCOUNTING FOR BIT-TO-SENSOR
DISTANCE.
PARAMETERS USED IN POROSITY LOG PROCESSING:
)
)
HOLE SIZE: ACAL-DERIVED (8.5" BIT)
MUD WEIGHT: 11.3 PPG
MUD SALINITY: 350 PPM CHLORIDES
FORMATION WATER SALINITY: 25,000 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...... .03/04/30
Maximum Physical Record. .65535
File Type................LO
Previous File Name...... .STSLIB.OOO
Comment Record
FILE HEADER
FILE NUMBER:
EDITED MERGED MWD
Depth shifted
DEPTH INCREMENT:
#
FILE SUMMARY
PBU TOOL CODE
NCNT
FCNT
PEF
FET
RPD
RPM
RPS
RPX
GR
NPHI
DRHO
RHOB
ROP
$
1
and clipped curves; all bit runs merged.
.5000
START DEPTH
4191.0
4191.5
4203.5
4238.5
4238.5
4238.5
4238.5
4238.5
4246.5
4250.0
4267.5
4267.5
4276.5
STOP DEPTH
8388.0
8388.0
8400.5
8436.0
8436.0
8436.0
8436.0
8436.0
8443.5
8388.0
8400.5
8400.5
8475.0
#
BASELINE CURVE FOR SHIFTS:
CURVE SHIFT DATA (MEASURED DEPTH)
--------- EQUIVALENT UNSHIFTED DEPTH ---------
BASELINE DEPTH
$
#
MERGED DATA SOURCE
PBU TOOL CODE
MWD
$
#
REMARKS:
BIT RUN NO MERGE TOP
3 4191.0
MERGE BASE
8475.0
MERGED MAIN PASS.
$
#
Data Format Specification Record
Data Record Type..................O
Data Specification Block Type.....O
Logging Direction. . . . . . . . . . . . . . . . . Down
Optical log depth units.......... .Feet
Data Reference Point............. .Undefined
Frame Spacing.................... .60 .1IN
Max frames per record............ .Undefined
) ')
Absent value. . . . . . . . . . . . . . . . . . . . . . - 999
Depth Units. . . . . . . . . . . . . . . . . . . . . . .
Datum Specification Block sub-type...O
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1
ROP MWD FT/H 4 1 68 4 2
GR MWD API 4 1 68 8 3
RPX MWD OHMM 4 1 68 12 4
RPS MWD OHMM 4 1 68 16 5
RPM MWD OHMM 4 1 68 20 6
RPD MWD OHMM 4 1 68 24 7
FET MWD HOUR 4 1 68 28 8
NPHI MWD PU-S 4 1 68 32 9
FCNT MWD CNTS 4 1 68 36 10
NCNT MWD CNTS 4 1 68 40 11
RHOB MWD G/CM 4 1 68 44 12
DRHO MWD G/CM 4 1 68 48 13
PEF MWD BARN 4 1 68 52 14
First Last
Name Service Unit Min Max Mean Nsam Reading Reading
DEPT FT 4191 8475 6333 8569 4191 8475
ROP MWD FT/H 6.99 388.3 160.495 8398 4276.5 8475
GR MWD API 48.06 428.71 118.724 8395 4246.5 8443.5
RPX MWD OHMM 0.52 1732.76 4.06125 8396 4238.5 8436
RPS MWD OHMM 0.58 1733.44 4.02337 8396 4238.5 8436
RPM MWD OHMM 0.19 2000 6.18171 8396 4238.5 8436
RPD MWD OHMM 0.02 2000 13.0809 8396 4238.5 8436
FET MWD HOUR 0.16 242.43 2.89022 8396 4238.5 8436
NPHI MWD PU-S 14.9 48.1 32.8342 8277 4250 8388
FCNT MWD CNTS 610.99 2387.51 990.485 8394 4191.5 8388
NCNT MWD CNTS 112885 188835 137799 8395 4191 8388
RHOB MWD G/CM 1.827 3.117 2.34151 8267 4267.5 8400.5
DRHO MWD G/CM -0.079 0.664 0.0858949 8267 4267.5 8400.5
PEF MWD BARN 1.65 14.25 3.35959 8395 4203.5 8400.5
First Reading For Entire File......... .4191
Last Reading For Entire File.......... .8475
File Trailer
Service name............ .STSLIB.OOl
Service Sub Level Name...
Version Number.......... .1.0.0
Date of Generation...... .03/04/30
Maximum Physical Record. .65535
File Type. . . . . . . . . . . . . . . . LO
Next File Name.......... .STSLIB.002
Physical EOF
File Header
Service name............ .STSLIB.002
Service Sub Level Name...
Version Number.......... .1.0.0
Date of Generation...... .03/04/30
Maximum Physical Record. .65535
F i 1 e Type.. . . . . . . . . . . . . . . LO
Previous File Name...... .STSLIB.OOl
Comment Record
FILE HEADER
FILE NUMBER:
RAW MWD
Curves and log
BIT RUN NUMBER:
DEPTH INCREMENT:
#
FILE SUMMARY
VENDOR TOOL CODE
NCNT
FCNT
PEF
FET
RPD
RPM
RPS
RPX
GR
NPHI
DRHO
RHOB
ROP
$
)
2
)
header data for each bit run in separate files.
3
.5000
START DEPTH
4191.0
4191.5
4203.5
4238.5
4238.5
4238.5
4238.5
4238.5
4246.5
4250.0
4267.5
4267.5
4276.5
#
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME) :
TD DRILLER (FT):
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT):
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
MINIMUM ANGLE:
MAXIMUM ANGLE:
#
TOOL STRING (TOP TO
VENDOR TOOL CODE
DGR
EWR4
SLD
CTN
$
#
STOP DEPTH
8388.0
8388.0
8400.5
8436.0
8436.0
8436.0
8436.0
8436.0
8443.5
8388.0
8400.5
8400.5
8475.0
BOTTOM)
TOOL TYPE
DUAL GAMMA RAY
ELECTROMAG. RESIS. 4
STABILIZED LITHO DEN
COMP THERMAL NEUTRON
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT):
#
BOREHOLE CONDITIONS
MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S):
MUD PH:
MUD CHLORIDES (PPM):
FLUID LOSS (C3):
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TERMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
#
12-MAR-03
Insite
66.37
Memory
8475.0
4276.0
8475.0
7.5
59.7
TOOL NUMBER
164580
145654
039307
105918
8.500
4263.0
LSND
11.30
47.0
9.0
350
3.7
2.050
1.170
1.350
3.100
71.0
129.0
71.0
71.0
)
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
#
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
#
REMARKS:
$
#
Data Format Specification Record
Data Record Type..................O
Data Specification Block Type.....O
Logging Direction................ . Down
Optical log depth units.......... .Feet
Data Reference Point............. .Undefined
Frame Spacing.................... .60 .1IN
Max frames per record............ . Undefined
Absent value. . . . . . . . . . . . . . . . . . . . . . -999
Depth Uni t s . . . . . . . . . . . . . . . . . . . . . . .
Datum Specification Block sub-type...O
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1
ROP MWD030 FT/H 4 1 68 4 2
GR MWD030 API 4 1 68 8 3
RPX MWD030 OHMM 4 1 68 12 4
RPS MWD030 OHMM 4 1 68 16 5
RPM MWD030 OHMM 4 1 68 20 6
RPD MWD030 OHMM 4 1 68 24 7
FET MWD030 HOUR 4 1 68 28 8
NPHI MWD030 PU-S 4 1 68 32 9
FCNT MWD030 CNTS 4 1 68 36 10
NCNT MWD030 CNTS 4 1 68 40 11
RHOB MWD030 G/CM 4 1 68 44 12
DRHO MWD030 G/CM 4 1 68 48 13
PEF MWD030 BARN 4 1 68 52 14
Name
DEPT
ROP
GR
RPX
RPS
RPM
RPD
FET
NPHI
FCNT
NCNT
RHOB
DRHO
PEF
Service Unit
FT
MWD030 FT/H
MWD030 API
MWD030 OHMM
MWD030 OHMM
MWD030 OHMM
MWD030 OHMM
MWD030 HOUR
MWD030 PU-S
MWD030 CNTS
MWD030 CNTS
MWD030 G/CM
MWD030 G/CM
MWD030 BARN
Min
4191
6.99
48.06
0.52
0.58
0.19
0.02
0.16
14.9
610.99
112885
1.827
-0.079
1.65
Max
8475
388.3
428.71
1732.76
1733.44
2000
2000
242.43
48.1
2387.51
188835
3.117
0.664
14.25
Mean
6333
160.495
118.724
4.06125
4.02337
6.18171
13.0809
2.89022
32.8342
990.485
137799
2.34151
0.0858949
3.35959
First Reading For Entire File......... .4191
Last Reading For Entire File.......... .8475
File Trailer
Service name............ .STSLIB.002
Nsam
8569
8398
8395
8396
8396
8396
8396
8396
8277
8394
8395
8267
8267
8395
,)
First
Reading
4191
4276.5
4246.5
4238.5
4238.5
4238.5
4238.5
4238.5
4250
4191.5
4191
4267.5
4267.5
4203.5
Last
Reading
8475
8475
8443.5
8436
8436
8436
8436
8436
8388
8388
8388
8400.5
8400.5
8400.5
\
'èV
Service Sub Level Name...
Version Number.......... .1.0.0
Date of Generation...... .03/04/30
Maximum Physical Record. .65535
File Type................ LO
Next File Name.......... .STSLIB.003
Physical EOF
Tape Trailer
Service name............ .LISTPE
Date. . . . . . . . . . . . . . . . . . . . .03/04/30
Origin. . . . . . . . . . . . . . . . . . . STS
Tape Name............... . UNKNOWN
Continuation Number.... ..01
Next Tape Name.......... . UNKNOWN
Comments................ .STS LIS Writing Library. Scientific Technical Services
Reel Trailer
Service name.. . . . . . . . . . . .LISTPE
Date. . . . . . . . . . . . . . . . . . . . .03/04/30
Origin. . . . . . . . . . . . . . . . . . . STS
Reel Name............... . UNKNOWN
Continuation Number..... .01
Next Reel Name.......... . UNKNOWN
Comments................ .STS LIS Writing Library. Scientific Technical Services
Physical EOF
Physical EOF
End Of LIS File
