Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout198-233~
SP Exploration (Alaska) Inc.
Attn: Well Integrity Coordinator, PRB-20
Post Office Box 196612
Anchorage, Alaska 99519-6612
Anehar~~~
~ ~~~~
,'.. -~~~~ .J~J' : ~~
July 10, 2009 ~g ,
8 ~'33
Mr. Tom Maunder (~~ ~
Alaska Oil and Gas Conservation Commission ` ~~
333 West 7ih Avenue ~
Anchorage, Alaska 99501
Subject: Corrosion Inhibitor Treatments of GPB R-Pad
Dear Mr. Maunder,
Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB R-
Pad that were treated with corrosion inhibitor in the surface casing by conductor
annulus. The corrosion inhibitor is engineered to prevent water from entering the
annular space and causing external corrosion that could result in a surface casing leak
to atmosphere. The attached spreadsheet represents the well name, API and PTD
numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in
each conductor.
As per previous agreement with the AOGCC, this letter and spreadsheet serve as
notification that the treatments took place and meet the requirements of form 10-404,
Report of Sundry Operations.
If you require any additional information, please contact me or my alternate, Torin
Roschinger, at 659-5102.
Sincerely,
Anna Dube, P.E.
BPXA, Well Integrity Coordinator
.,5~~ ~ ~ ~Q~~
~I~~k~ C~i~ ~ ~~~ Cd~~e ~o~tmwssio~ ~p
• ~
BP Exploration (Alaska ) Inc.
Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off
Report of Sundry Operations (10-404)
R-pad
Date Revised 7/10/2009
Well Name
API #
PTD #
Initial top of
cement
Vol. of cement
um ed
Final top of
cement
Cement top off
date
Corrosion
inhibitor Corrosion
inhibitor/
sealant date
~ ft bbls ft na al
R-02 50029203540000 1781000 1.25 NA 1.25 NA 6.8 5/11 /2009
R-03A 50029203640100 1981710 1.5 NA 1.5 NA 7.65 5113l2009
R-04 50029203740000 1790380 2.25 NA 2.25 NA 13.6 5/13/2009
R-05A 50029203800100 1972500 0 NA 0 NA 3 5/13/2009
R-06A 50029203880100 1981270 0.75 NA 0.75 NA 13.17 5/13/2009
R-07A 50029205230100 2000100 2.25 NA 2.25 NA 43 5/11/2009
R-OS 50029205480000 1810010 0.25 NA 0.25 NA 1.7 6l12/2009
R-09A 50029206090100 1982330 3.25 NA 3.25 NA 17.85 5/14/2009
R-10 50029206150000 1810930 2 NA 2 NA 14.5 6l22/2009
R-11A 50029208930100 1982060 0.25 NA 0.25 NA 1.7 6/11/2009
R-12 50029209210000 1830350 0.25 NA 0.25 NA 1.7 6(12/2009
R-13 50029209290000 1830440 24 NA 24 NA 96.9 6/23/2009
R-14 50029209090100 2021560 0 NA 0 NA 0.04 5/18/2009
R-15A 50029209170100 1990360 0 NA 0 NA 1.7 5l18/2009
R-16 50029206860000 1811740 15 NA 15 NA 107.5 5/17/2009
R-17A 50029206770100 1981380 4 NA 4 NA 27.2 5/15/2009
R-186 50029206330200 1981190 6.75 NA 6.75 NA 48.87 5/15/2009
R-19A 50029206370100 1971710 8.5 NA 8.5 NA 67.48 5/17/2009
R-21 50029209970000 1831200 0.25 NA 0.25 NA 3.4 6/13/2009
R-22 50029210050000 1831280 0.5 NA 0.5 NA 4.3 6/12/2009
R-23A 50029210130100 1972020 2.25 NA 2.25 NA 16.2 6/12/2009
R-24 50029212320000 1842160 9.5 NA 9.5 NA 37.4 6/12/2009
R-25A 50029222780100 1972300 0 NA 0 NA 1.7 5/18/2009
R-26A 50029215470000 1860370 0.75 NA 0.75 NA 4.3 6/22/2009
R-27 50029215570000 1860510 025 NA 0.25 NA 1.7 6/11/2009
R-29 50029222750100 1971070 20 3.9 1.25 NA 11.05 5/14/2009
R-31A 50029222770100 2021500 1.5 NA 1.5 NA 8.5 5/11/2009
R-32A 50029224130100 1980090 0.75 NA 0.75 NA 8.5 6/11/2009
R-34 50029224080000 1931530 0 NA 0 NA 2.5 5/1 S/2009
R-35 50029224240000 1931810 0.25 NA 0.25 NA 1.7 5/11/2009
R-36 50029225220000 1941440 3.25 NA 3.25 NA 44.2 5/14/2009
R-39A 50029225260100 1960840 2 NA 2 NA 22.1 5/11/2009
R-40 50029229260000 1982000 1.5 NA 1.5 NA 6.8 5/14/2009
R-41 50029233990000 2081530 3.25 NA 3.25 NA 22.1 5/12/2009
!
BP Exploration (Alaska) Inc.
Attn: Well Integrity Coordinator, PRB-20
Post Office Box 196612
Anchorage, Alaska 99519-6612
June 26, 2009
~p
~n~ :~~.
~ ~ ~3~ . ~ , ~
Mr. Tom Maunder ' ~ ~ d ~
(~ + ~UL ~ ~ 200~
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue ~~~~~~ ~~I ~ G~~ Con~. Co~nr~~~sip~
Anchorage, Alaska 99501 q~C~~t~
Subject: Corrosion Inhibitor Treatments of R-Pad
Dear Mr. Maunder,
Enclosed please find a spreadsheet with a list of wells from R-Pad that were treated
with corrosion inhibitor in the surface casing by conductor annulus. The corrosion
inhibitor is engineered to prevent water from entering the annular space and causing
external corrosion that could result in a surface casing leak to atmosphere. The
attached spreadsheet represents the well name, top of cement depth prior to filling and
volumes of corrosion inhibitor used in each conductor.
~~
As per previous agreement with the AOGCC, this letter and spreadsheet serve as
notification that the treatments took place and meet the requirements of form 10-404,
Report of Sundry Operations.
If you require any additional information, please contact me or my alternate, Anna Dube,
at 659-5102.
Sincerely,
- x_ , ~. - ~,~
~~~~~~~:: ,~i~~ ~~ . 2Ci~,.J
•
Torin Roschinger
BPXA, Well Integrity Coordinator
~
•
BP Exploration (Alaska ) Inc.
Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off
Report of Sundry Operations (10-404)
natp
R-pad
6/25/2009
Well Name
PTD #
Initial top of
cement
Vol. of cement
um ed
Final top of
cement
Cement top off
date
Corrosion
inhibitor Corrosion
inhibitor/
sealant date
ft bbls ft na al
R-02 1781000 1.25 NA 125 NA 6.8 5/11/2009
R-03A 1981710 1.5 NA 1.5 NA 7.65 5/13/2009
R-04 1790380 2.25 NA 2.25 NA 13.6 5/13/2009
R-05A 1972500 0 NA 0 NA 3 5/13/2009
R-06A 1981270 0.75 NA 0.75 NA 13.17 5/13/2009
R-07A 2000100 2.25 NA 2.25 NA 43 5/11/2009
R-08 1810010 0.25 NA 0.25 NA 1.7 6/12/2009
R-09A 1982330 3.25 NA 3.25 NA 17.85 5/14/2009
R-10 1810930 2 NA 2 NA 14.5 6/22/2009
R-11 A 1982060 0.25 NA 0.25 NA 1.7 6/11 /2009
R-12 1830350 0.25 NA 0.25 NA 1.7 6/12/2009
R-13 1830440 3.75 NA 3.75 NA 76.5 6/22/2009
R-14 2021560 0 NA 0 NA 0.04 5/18/2009
R-15A 1990360 0 NA 0 NA 1.7 5/18/2009
R-16 1811740 15 NA 15 NA 107.5 5/17/2009
R-17A 1981380 4 NA 4 NA 27.2 5/15/2009
R-186 1981190 6.75 NA 6.75 NA 48.87 5/15/2009
R-19A 197i 710 8.5 NA 8.5 NA 67.48 5/17/2009
R-21 1831200 0.25 NA 0.25 NA 3.4 6/13/2009
R-22 1831280 0.5 NA 0.5 NA 4.3 6/12/2009
R-23A 1972020 2.25 NA 2.25 NA 16.2 6/12/2009
R-24 1842160 9.5 NA 9.5 NA 37.4 6/12/2009
R-25A 1972300 0 NA 0 NA 1.7 5/18/2009
R-26A 1860370 0.75 NA 0.75 NA 4.3 6/22/2009
R-27 1860510 0.25 NA 0.25 NA 1.7 6/1 f/2009
R-29 1971070 20 3.9 1.25 NA 11.05 5/14/2009
R-31A 2021500 1.5 NA 1.5 NA 8.5 5/11/2009
R-32A 1980090 0.75 NA 0.75 NA 8.5 6/11/2009
R-34 1931530 0 NA 0 NA 2.5 5/18/2009
R-35 1931810 0.25 NA 0.25 NA 1.7 5/11/2009
R-36 1941440 3.25 NA 3.25 NA 44.2 5/14/2009
R-39A 1960840 2 NA 2 NA 22.1 5/11/2009
R-40 1982000 1.5 NA 1.5 NA 6.8 5/14/2009
R-41 2081530 3.25 NA 3.25 NA 22.1 5/12/2009
~ STATE OF ALASKA ~
ALASKA _jL AND GAS CONSERVATION COh, v1ISSION
REPORT OF SUNDRY WELL OPERATIONS
1. Operations Performed:
0 Abandon
0 Alter Casing
0 Change Approved Program
2. Operator Name:
BP Exploration (Alaska) Inc.
ress:
P.O. Box 196612, Anchorage, Alaska 99519-6612
7. KB Elevation (ft): 49.27'
8. Property Designation:
ADL 028279
11. Present well condition summary
Total depth: measured
true vertical
Effective depth: measured
true vertical
Casing
Structural
Conductor
Surface
Intermediate
Production
Liner
Length
Liner
Liner Tieback
Perforation Depth MD (ft):
Perforation Depth TVD (ft):
II Repair Well 0 Plug Perforations 0 Stimulate 0 Other
II Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension
0 Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well
13125
8813
13125
8813
feet
feet
feet
feet
Size
110'
2670'
9075'
20" x 30"
13-3/8"
9-5/8"
533'
4243'
8469'
7"
4-1/2"
7" x 5-1/2" x 4-1/2"
10105' - 13118'
8841' - 8814'
Tubing Size (size, grade, and measured depth):
Packers and SSSV (type and measured depth):
4. Current Well Class:
II Development 0 Exploratory
0 Stratigraphic 0 Service
5. ermit To Drill Number:
198-233
6. API Number:
50-029-20609-01-00
9. Well Name and Number:
PBU R-O9A
10. Field / Pool(s):
Prudhoe Bay Field / Prudhoe Bay Pool
Plugs (measured)
Junk (measured)
None
None
MD TVD Burst Collapse
110' 110'
2670' 2670' 5380 2670
9075' 8702' 6870 4760
8574' - 9107' 8253' - 8729' 8160 7020
8877' - 13120' 8525' - 8814' 8430 7500
20' - 8489' 20' - 8176'
4-1/2", 12.6# 13Cr80
4-1/2", 12.6# L-80
9-5/8" x 4-1/2" Baker '8-3' permanent packer; 7" x 4-1/2"
Baker '8-3' packer; 4-1/2" HES 'X' Nipple
Surface to 8452'
8489' - 8883'
8453'; 8295'
2058'
12. Stimulation or cement squeeze summary:
Intervals treated (measured): Tubing Punch: 1875' - 1880"
. .. ('
i;".: ¡~
)\,¡04
Treatment description including volumes used and final pressure:
Pumped 148 Bbls Cement to place cement in the 13-3/8" x 9-5/8" annulus. Pumped 190 Bbis Class 'G' to cement in place the Liner
Tieback (7" x 5-1/2" x 4-1/2".
13.
Oil-Bbl
Prior to well operation:
Subsequent to operation:
14. Attachments: 0 Copies of Logs and Surveys run
II Daily Report of Well Operations
II Well Schematic Diagram
Re resentative Dail
Gas-Met
Tubin Pressure
15. Well Class after proposed work:
0 Exploratory II Development 0 Service
16. Well Status after proposed work:
II Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL
ge. Sundry Number or N/A if C.O. Exempt:
N/A
1 . I hereby certl
Contact
Printed Name T erne Hubble
Title Technical Assistant
Date 08//I~
AfIJII8 BFL
Prepared By NameiNumbe~
Terrie Hubble, 564-4628
su."n1inaJ O~~~,
~
~
Well:
Field:
API:
Permit:
R-09A
Prudhoe Bay Unit
50-029-20609-01-00
198-233
Accept:
Spud:
Release:
Rig:
07/06/04
N/A
07/16/04
Nabors 4ES
PRE-RIG WORK
03/10/04
DRIFT W/3.80 CENT AND S.B. TO XN NIPPLE @ 8857' SLM. SET 4.5" PXN PLUG BODY IN XN NIPPLE @
8857' SLM. SET PXN PRONG IN PLUG BODY @ 8857' SLM (1" 3/8 FN, 96" OAL, 2" SB TO PULL). SET JUNK
CATCHER @ 8845' SLM (114" LONG, 3.75 MAX 0.0.)
06/12/04
CHEM CUT 4.5" TUBING AT 8493'. DID NOT TAG. RUN 1: TP @ 8420'-8422', RUN 2: SS @ 8482'-8494'.
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
Date
"------.-...
7/6/2004
71712004
7/8/2004
From - To
00:00 - 02:00
02:00 - 04:00
04:00 - 06:00
06:00 - 07:00
07:00 - 08:00
08:00 - 08:30
08:30 - 09:30
09:30 - 14:30
14:30 - 16:00
16:00 - 19:00
19:00 - 00:00
00:00 - 04:00
04:00 - 07:30
07:30 - 08:00
08:00 - 08:30
08:30 - 09:30
09:30 - 18:00
18:00 - 20:00
20:00 - 21 :00
21 :00 - 00:00
00:00 - 03:00
03:00 - 03:30
03:30 - 06:00
06:00 - 07:00
07:00 - 11 :30
11:30 - 12:30
12:30 - 15:30
,~
~
Page 1 of 6
BP EXPLORATION
Operations Summary Report
R-09A
R-09A
WORKOVER
NABORS ALASKA DRILLING I
NABORS 4ES
Hours! Task Code' NPT
.. .-......--...---
2.00 MOB
2.00 RIGU
2.00 RIGU
P
P
P
1.00 RIGU
P
1.00 PULL
0.50 PULL
P
P
1.00 KILL
P
5.00 KILL
P
1.50 KILL
P
3.00 RIGD
5.00 RIGD
P
P
4.00 BOPSUF P
3.50 BOPSUF P
0.50 BOPSUF P
0.50 WHSUR P
1.00 PULL
8.50 PULL
P
P
2.00 CLEAN P
1.00 CLEAN P
3.00 CLEAN P
3.00 CLEAN P
0.50 CLEAN P
2.50 CLEAN P
1.00 CLEAN P
4.50 WHSUR P
1.00 WHSUR P
3.00 CLEAN P
Phase
PRE
DECOMP
DECOMP
DECOMP
DECOMP
DECOMP
DECOMP
DECOMP
DECOMP
DECOMP
DECOMP
DECOMP
DECOMP
DECOMP
DECOMP
DECOMP
DECOMP
DECOMP
DECOMP
DECOMP
DECOMP
DECOMP
DECOMP
DECOMP
DECOMP
DECOMP
DECOMP
Start: 7/6/2004
Rig Release: 7/16/2004
Rig Number: 4ES
Spud Date: 7/10/1981
End: 7/16/2004
Description of Operations
__no ---.. .....-......._-----------------
Move rig to R-09A location.
Spot and R/U modules. Accept rig @ 0400 hrs.
R/U berm and spot 400 Bbl open top tank equipped w/ gas
buster.
RlU lines to annulus and tree. Take on warm seawater into rig
pits.
Wait on DSM crew to arrive on location to pull BPV.
RU DSM lub. Pull BPV. R/U line to tubing for circ ops.
Loading/strapping drill-pipe.
PJSM/Job scope for R-09A RWO. Emphasis on parted 13-3/8"
and leaning wellhead (fluted hanger hung up on 20" conductor,
did not go back down inside conductor).
Line up to circ warm seawater down the tbg w/rtns up IA.
Confirm circ and bring rate up to 5-6 bpm. Circ total of 10K
strokes. Monitor fluted hanger, which grew 2" above the 20"
conductor during circ.
Install TWC, test to 1000 psi. Attempts to center tree
unsuccessful. PJSM regarding the tree movement and required
addition of a new 7" spool. Decision made to RID rig in order
to build up sub base height.
Prepare to scope and lower derrick, then perform same.
RID and split Pipe Shed and Mud Pits from Sub. Move back
sub and build up base supports to add height to rig
components. Re-assemble rig; raise and scope derrick.
N/D tree, N/U BOPE. RlU lines and prepare for testing.
Test BOPE to BP/AOGCC requirements at 250/3500 psi.
State's right to witness test waived by C. Sheve.
Pick up Lubricator and pull TWC. Lay down same.
Make up Landing Joint and XO. BOLDS. Pull Tubing Hanger
to Floor. (Hanger broke free at 125K. Tubing pulling free at
110K).
Rig up 4 1/2" Handling Equipment.
POOH and single down 41/2", 12.6Iblft, L-80, IBT Tubing.
Found very good chem cut on cut joint.
Clear and clean rig floor and set up handling equipment for RIH
w/ BHA #1 and 3-1/2' DP.
M/U BHA #1: Outside 4-1/2" dressing shoe, 2 extensions, Drive
Bushing, 2 Junk baskets, 8-1/8" Scraper, Bit Sub, Bumper Sub,
Oil Jar, 9 ea 4-3/4" DCs.
RIH BHA #1 on 3-1/2" DP from Pipe Shed.
Continue RIH w/ BHA #1 on 3-1/2" DP to cleanout to top of
4-1/2" tbg stump @ 8489' DPM.
Parameters above stump: Up wt 137K, Dn wt 118K, 3 BPM @
400 psi. Tag stump and work down slowly and back up, twice,
watching pressure increase to 800 psi then falloff to 400 psi.
Reverse circulate 35 Bbl Hi-Vis sweep and full hole volume.
Work shoe over stump to ensure nothing has covered 4-1/2'
during circ ops. SIB Kelly, POH and SIB 5 stds DP.
M/U RTTS, set @ 28', test to 500 psi; UD running tool. P/U
pack-off tool, drain stack, BOLDS. Pull pack-ff w/18K; install
pack-off. RILDS, test to 3500 psi. UD pack-off tool.
Sting into RTTS, release, POH and UD same.
POH & SIB w/3-1/2" DP, DCs, and BHA #1.
Printed: 7/20/2004 12:18:56 PM
~
~
Page 2 of 6
BP EXPLORATION
Operations Summary Report
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
Date
R-09A
R-09A
WORKOVER
NABORS ALASKA DRILLING I
NABORS 4ES
From - To I Hours Task I Code
]
Start: 7/6/2004
Rig Release: 7/16/2004
Rig Number: 4ES
NPT I Phase I
, i
7/812004
----.........-n--.."--
7/9/2004
15:30 - 17:00
17:00 - 18:00
18:00 - 21:00
21 :00 - 23:30
23:30 - 00:00
00:00 - 01 :00
00:00 - 02:00
02:00 - 02:30
02:30 - 03:30
03:30 - 04:30
04:30 - 06:30
06:30 - 07:00
07:00 - 07:30
07:30 - 08:30
08:30 - 14:30
14:30 - 15:30
15:30 - 17:00
17:00 - 18:00
18:00 - 19:30
19:30 - 21 :30
21 :30 - 22:00
22:00 - 23:30
- - ... ..-...
1.50 CLEAN P
1.00 CLEAN P
3.00 CLEAN P
DECOMP
DECOMP
DECOMP
2.50 ZONISO P
DECOMP
0.50 ZONISO P
1.00 ZONISO P
DECOMP
DECOMP
2.00 ZONISO P
DECOMP
0.50 PRFADC P
1.00 PRFADC P
1.00 PRFADC N
2.00 PRFADC P
DECOMP
DECOMP
WAIT DECOMP
DECOMP
0.50 PRFADD P
0.50 PRFADD P
1.00 CLEAN P
DECOMP
DECOMP
DECOMP
6.00 CLEAN P
DECOMP
1.00 CLEAN P
1.50 REMCM P
1.00 REMCM P
DECOMP
DECOMP
DECOMP
1.50 REMCM P
2.00 REMCM P
DECOMP
DECOMP
0.50 REMCM P
DECOMP
1.50 REMCM P
DECOMP
Spud Date: 7/10/1981
End: 7/16/2004
Description of Operations
------"""'-'_U'" _n. ..--- .._..__n__..
UD 9 ea 4-314" DCs and BHA #1. Clear and clean rig floor.
PJSM; R/U SWS.
RIH SWS USIT log. Log up from 3500' to 1500' to find top of
cement between 9-5/8' and 13-3/8' casing. Top of cement at
1920'. POH and partial RID SWS.
M/U Halco RBP and RIH w/9 x 6-1/4" DCs, 18 stds 3-1/2" DP
and set @1990'.
Pressure test RBP to 500 psi for 15 mins.
P/U and SIB 1 stand; RlU and dump 20 sacks sand down DP
and circulate it to top of RBP.
POH and SIB 3 stds DC, 17 stds DP, and UD RBP runining
tool.
PJSM and R/U SWS for 9-5/8" tubing punch run.
SWS crew load guns: 5' wI 4 JSPF. SWS determined they
brought out wrong gun.
Wait on correct SWS guns.
RIH wI SWS tbg punch and tag sand @ 1963' on top of RBP.
P/U to position guns 1875'-1880' and fire. Good response.
POH wI SWS. Stand-by.
Break circulations to varify communations through Tubing
Punch holes...1.5 bpm/500 psi.
Release SWS and rig down.
Make up Mule Shoe and RIH with 59 its of 3 1/2" Drill Pipe to
-1,868'.
Pump Hot Sea Water down Drill Pipe and return up 9 5/8"
Casing to warm up Arctic Pack in the 13 3/8' (parted at -54') x
9 5/8" Annulus. Heat up 40 bbls of Diesel to 90 degs with Hot
Oil Truck. PT Lines 1500 psi. Little Red pump 40 bbls of 90
deg Diesel down Drill Pipe at an average rate of 1.0 bpm/1000
psi. Returns recovered up 13 3/8" x 9 5/8" Annulus in lined
cellar. RD Little Red. Bring Rig Pump on line and pump 40
bbls of 140 deg Sea Water with Surf-a-Sweep added.
Continue pumping hot Sea Water( at various rates and
pressures) until Arctic Pack and Drill Mud was removed from
annulus. Returns clean. Total pumped 194 bbls. Clean out
Cellar.
POOH with 3 1/2' Drill Pipe and Mule Shoe.
P/U Halco setting tool and FasDrili retainer and RIH to 1841'.
Establish circ and attempt to set retainer. Rotate 35 turns, but
FasDrili won't set. Rotate another 25 turns, still won't set. P/U
10', won't set.
POH, SIB DP. Work on setting tool. Nothing wrong with tool.
RIH Halco set tool and retainer to 1841'. Work tool, but FasDrili
won't set. P/U one joint and UD. Attempt to set FasDrili @
1810' is successful. Test injection 3 BPM @ 950 psi.
PJSM and lineup manifold and cement line valves. Pressure
test lines.
Squeeze cement:5 Bbls freshwater, pres test lines, 20 Bbls
freshwater, 148 Bbls slurry, + 2 Bbls slurry dumped on top of
retainer. Pumping rates from 0.1 BPM to 3.2 BPM; pres from
20 psi to 1300 psi. Had to slow rate to 2 BPM and 200-400 psi
to keep up wI sucking returns out of cellar by vac truck. Final
slurry density in returns, 15.5 ppg.
Printed: 7/20/2004 12:18:56 PM
~
~
BP EXPLORATION
Operations Summary Report
Page 3 of 6
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
Date
R-09A
R-09A
WORKOVER Start: 7/6/2004
NABORS ALASKA DRILLING I Rig Release: 7/16/2004
NABORS 4ES Rig Number: 4ES
From - To I Hours! Task Code NPT Phase I
._-- -..--.. ....._.n --.... . !
1-----""'"
7/9/2004
7/10/2004
7/11/2004
23:30 - 00:00
00:00 - 01 :30
01 :30 - 06:00
06:00 - 09:30
09:30 - 10:00
10:00 - 11 :00
11 :00 - 17:30
17:30 - 19:00
19:00 - 21 :00
21 :00 - 22:00
22:00 - 23:30
23:30 - 00:00
00:00 - 00:30
00:30 - 01 :30
01 :30 - 03:00
03:00 - 04:00
04:00 - 05:00
05:00 - 06:00
06:00 - OS:30
08:30 - 10:30
10:30 - 11 :30
11:30 - 12:00
12:00 - 13:00
0.50 REMCM P
DECOMP
1.50 REMCM P
DECOMP
4.50 REMCM P
DECOMP
3.50 REMCM P
DECOMP
0.50 REMCM P
DECOMP
1.00 REMCM P
DECOMP
6.50 REMCM P
DECOMP
1.50 REMCM P
2.00 REMCM P
DECOMP
DECOMP
1.00 REMCM P
1.50 REMCM P
DECOMP
DECOMP
0.50 REMCM P
0.50 REMCM P
DECOMP
DECOMP
1.00 REMCM P
1.50 REMCM P
DECOMP
DECOMP
1.00 REMCM P
DECOMP
1.00 REMCM P
DECOMP
1.00 REMCM P
DECOMP
2.50 REMCM P
DECOMP
2.00 BOPSUF P
TIEB1
1.00 CASE
0.50 CASE
1.00 CASE
P
P
P
TIEB1
TIEB1
TIEB1
Spud Date: 7/10/1981
End: 7/16/2004
Description of Operations
----------..-.._-_.._--
Reverse out cement from DP, clean lines from Schlumberger
to manifold to vac truck.
POH SIB DP, break out and UD Halco setting tool. Clean out
cellar wI Super Sucker vac truck.
WOC. Clear and clean rig floor. Load and tally 7",26#, L-SO,
NSCC and BTC into Pipe Shed.
Continue to WOC. Service and maintain Rig. Continue to load
and tally 7" Casing for Tie-Back Liner. Check with Dowell Lab
on final results of compressive strength of Cement...1500 psi +.
Make-up BHA as follows: 8-1/2" milled tooth bit, bit sub,
9-6-1/4" DCs.
RIH with BHA and 3 1/2" Drill Pipe. Tag TOC at 1784'.
Pick-up Kelly.
Drill Cement at 1784'. Drill up Cement Retainer at 1810'..
Continue to drill out Cement down to 1880' (bottom Tubing
Punch holes). Fell through. Continue down to top of sand at
1963'. Wash down to 1975'. Pump Hi-Vis sweep. Pump dry job.
POH, SIB DP, DCs; breakout and UD bit and bit sub.
Clear and clean rig floor. Pressure test 9-5/8" casing to 1000
psi. Had to chase down a small surface leak. Final test
recorded on chart was 1000 psi/15 min...Iost 30 psi.
M/U Halco RBP running tool; RIH to latch into and pull RBP.
Reverse circ down to 1975'. Tag hard. Work up and back down
to attempt to force tool through hard spot. CBU reverse. Try to
spud through, but no luck. CBU long way, try again to make
headway.
Circed out rubber pieces, bits of cement retainer, grey material.
POH and SIB DP, DCs.
POH, SIB DP, DCs. B/O RBP running tool. M/U retainer
drilling BHA: bit sub and 8-1/2" milled tooth bit.
RIH wI BHA and tag up wI hard material @ 1975'.
P/U Kelly, establish parameters: Up 54K, Dn 54K, Rot 54K.
Work down at 50 RPM, 2 BPM, 50 psi, 0.5-1.0K WOB. Drill
hard for 18", then broke through and driller stopped @ 1983'
DPM. Center of RBP element @ 1990', top @ 1985'. CBU, 6.5
BPM @ 500 psi; recovered retainer materials, rubber, and sand
dumped previously. SIB Kelly.
POH and SIB DP, DCs. Breakout bit sub & 8-1/2" bit. MlU
Halco RBP pulling tool.
RIH 3-1/2 DP, 6-1/4" DCs, and Halco RBP pulling tool. Reverse
circ fill off RBP at 6 BPM, 600 psi..
Reverse circ 6 BPM @ 600 psi. Recovered larger pieces of
retainer and sand, circulating pressure increased to 900 psi.
Lots of larger chunks of retainer plugging lines. Latched the
retainer and started out of the hole.
POOH with 9 5/8" RBP. Lay down RBP and Retrieving Tool.
Lay down 6 1/2" Drill Collars.
Set Test Plug. Change out Pipe Rams to 7". Test at 3,500 psi.
Pull Test Plug.
Clear and clean Floor. Rig up to run 7" Tie-Back Liner.
PJSM with All.
Pick-up Shoe Track as follows: 95/8" x 4 1/2" Unique
Printed: 7/20/2004 12:18:56 PM
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
I
I From - To
'-'---------..... _m -- ---
7/11/2004 12:00 - 13:00
13:00 - 00:00
7/12/2004
00:00 - 01 :00
01 :00 - 02:00
02:00 - 02:30
02:30 - 03:00
03:00 - 03:30
03:30 - 04:30
04:30 - 06:00
06:00 - 07:30
07:30 - 10:00
10:00 - 11 :30
11:30 -12:30
12:30 - 15:30
15:30 - 17:00
17:00 - 17:30
17:30 -18:00
18:00 - 21 :00
21 :00 - 22:30
22:30 - 00:00
7/13/2004
00:00 - 03:00
03:00 . 03:30
03:30 - 04:30
04:30 - 06:00
/""'".
,~
BP EXPLORATION
Operations Summary Report
R-09A
R-09A
WORKOVER
NABORS ALASKA DRILLING I
NABORS 4ES
Hours
I ! !
Task I Code NPT: Phase
------_u- ....
1.00 CASE
P
TIEB1
11.00 CASE
P
TIEB1
1.00 CASE
P
TIEB1
1.00 CASE
TIEB1
P
0.50 CASE
TIEB1
P
0.50 CASE
TIEB1
P
0.50 CASE
1.00 CEMT
P
P
TIEB1
TIEB1
1.50 CEMT
P
TIEB1
1.50 CEMT
P
TIEB1
2.50 BOPSUF P
TIEB1
1.50 BOPSUF P
1.00 BOPSUF P
3.00 BOPSUF P
1.50 BOPSUF P
0.50 CASE P
TIEB1
TIEB1
TIEB1
TIEB1
TIEB1
0.50 CASE
3.00 CASE
1.50 CASE
P
P
P
TIEB1
TIEB1
TIEB1
1.50 DRILL
P
TIEB1
3.00 DRILL
TIEB1
P
0.50 DRILL
1.00 DRILL
TIEB1
TIEB1
P
P
1.50 DRILL
P
TIEB1
Page 4 of 6
Start: 7/6/2004
Rig Release: 7/16/2004
Rig Number: 4ES
Spud Date: 7/10/1981
End: 7/16/2004
Description of Operations
,.----..--..
...._..--m -.-
Overshot guide, XO Pups, 5 1/2" Pup Jt, HES Float Collar, 5
1/2" Pup Jt, 5 1/2" Put Jt wI Baker Landing Collar (No-Shear), 5
1/2" x 7" XO Sub, 1 ea 7" x 26 Iblft Shoe Track Joint, Halco ES
Cementer. Baker-Loc all connections.
RIH, picking up 7", 261blft, L-80, IBT and NSCC casing (Liner
Tie-Back) from Pipe shed.
Work Unique Overshot down to top of 4-112" stump @ 8489'.
Watch pressure increase as stump is swallowed. Done twice to
verify, then set down -15K. Tally up to get space out
requirements. Parameters during spaceout: Up wt 218K, Dn
178K. 3 BPM @ 100 psi, then up to 400 psi.
Spaceout with 2-pup jts: 9.71' & 7.71' + 2.1' cement head
adaptor. Re-tag and swallow stump twice for same depth and
pressure increase. Pull up 2', set slips, and install cementing
manifold.
PJSM with all personnel on site: Veco and Peak truck drivers,
Schlumberger, Halliburton, Nabors Tour Pusher, Nabors Crew,
and Co Man.
Pressure test lines to 3500 psi, drop 1-1/2" ball, and begin
pumping 80 F seawater to chase ball to seat at 5-6 BPM. Ball
hits after 184 Bbls. Pressure up on liner and cementer opened
@ -2750 psi.
Switch over trucks and pump 50 Bbls of diesel @ 4-5 BPM.
Switch over to pump 190 Bbls, 15.8 ppg, class G cement @
5-6 BPM.
Drop Halco wiper plug and displace @ 5-6 BPM wI 321 Bbls of
80 F seawater to Halco cementer @ -8,400'. Displaced w/323
Bbls of seawater. Float check good!
Flush and blow down lines. Rig down Cementers. Suck out
BOP Stack.
Lift BOP Stack. Set Slips with a hanging weight of 200K. Rig
up WACHS Cutter. Cut-off 7" Liner (RU, Cut, RD = 28
minutes).
Set back BOP Stack. Lay down cut-off stub = 7.57' and space
out Pups. RID casing equipment.
Install new 7" tubing spool. Test to 4200 psi (80% pipe rating).
N/U BOPE. CIO pipe rams, test doors & body to 3500 psi.
Jet stack clean. Pump out stack. Pull test plug. Set Wear Ring.
Clear and clean rig floor. Load and strap BHA #2: 6-1/8" bit, bit
sub, oil jars, 9-DCs.
P/U BHA #2.
RIH wI BHA #2, tag cement @ 8378'.
P/U DP 10' and pressure test 7" casing to 3500 psi. Record for
30 minutes. Good test.
P/U Kelly, establish parameters: Up 146K, Dn 112K, Rot wt
125K, 5 BPM @ 1100 psi, 3-15K WOB. Hit hard @ 8384'.
Drilling on hard cement and Halco cementer @ -8384'-8390',
then drilled through and made quick progress to 8399'.
Circ Hi-Vis sweep to clean wellbore.
P/U one jt of DP and work down to 5-1/2" x 7" XO used as "No
Go" @ -8425.5' DPM. Cuttings over shaker: chunks of rubber,
slivers of metal and bits of paint.
Mix and pump Hi Vis sweep, 6 BPM @ 1200 psi.
Printed: 7/20/2004 12:18:56 PM
r-'"'
. ------
BP EXPLORATION
Operations Summary Report
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
R-09A
R-09A
WORKOVER
NABORS ALASKA DRILLING I
NABORS 4ES
,
Date From - To i Hours Task Code NPT Phase
....------.... -----.. ----..----. -..-- -- ..---.
7/13/2004 06:00 - 09:00 3.00 DRILL P TIEB1
09:00 - 10:00 1.00 DRILL P TIEB1
10:00 - 13:00 3.00 DRILL P TIEB1
13:00 - 14:00 1.00 DRILL P TIEB1
14:00 - 15:00 1.00 DRILL P TIEB1
15:00 - 22:30 7.50 DRILL P TIEB1
22:30 - 00:00 1.50 DRILL P TIEB1
7/14/2004 00:00 - 02:30 2.50 DRILL P TIEB1
02:30 - 03:30 1.00 DRILL P TIEB1
03:30 - 05:00 1.50 DRILL P TIEB1
05:00 - 08:00 3.00 DRILL P TIEB1
08:00 - 09:00 1.00 DRILL P TIEB1
09:00 - 10:00 1.00 DRILL P TIEB1
10:00 - 10:30 0.50 DRILL P TIEB1
10:30 - 14:00 3.50 DRILL P TIEB1
14:00 - 16:00 2.00 DRILL P TIEB1
16:00 - 21:00 5.00 DRILL P TIEB1
21 :00 - 22:30 1.50 DRILL P TIEB1
22:30 - 23:00 0.50 DRILL P TIEB1
23:00 - 00:00 1.00 RUNCO RUNCMP
7/15/2004 00:00 - 01 :00 1.00 RUNCO RUNCMP
01 :00 - 01 :30 0.50 RUNCO RUNCMP
01 :30 - 12:00 10.50 RUNCO RUNCMP
12:00 - 13:30 1.50 RUNCO RUNCMP
13:30 - 14:00 0.50 RUNCO RUNCMP
14:00 - 16:00 2.00 RUNCO RUNCMP
16:00 - 17:00 1.00 RUNCO RUNCMP
Page 5
Start: 7/6/2004
Rig Release: 7/16/2004
Rig Number: 4ES
Spud Date: 7/10/1981
End: 7/16/2004
Description of Operations
POOH with 81/2" Bit and Drill Collars.
Lay down Bit, Bit Sub, and Drill Collars.
Make-up BHA #3 as Follows: 43/4" Bit, Bit Sub, 2 its 2 7/8"
PAC Drill Pipe, XO, 2 ea Boot Baskets, Bit Sub, Oil Jars RIH wI
BHA # 3 on 31/2" DP.
Cut & slip 84' of drillihng line.
Con't to RIH wI BHA # 3. Tag up on cement @ 8426' in 7' x 5
1/2' X-over.
P/U kelly, break circulation & drill cement from 8426 to 8430'.
Drill Baker landing collar from 8430 to 8432'. (took 5 hrs.)
Ream up & down. Make coneection & con't in hole to 8451'.
Tagged float collar & drill same. ( took 1/2 hr) Con't in hole to 5
1/2" x 41/2" X-over @ 8472.5'. P/U 140K, S/O 108K, Rot
120K. 40-60 RPMs, 3.5 BPM @ 650 Psi, WOB 4-8K, Torq
3-5K.
Pump 20 Bbl Hi-Vis sweep around. Monitor well.
Set back kelly & blow down lines. UD 11 singles. POOH wI
BHA #3.
UD BHA # 3. Clean out boot baskets. recovered 4 handfulls of
metal nuggets & iron filings.
M/U BHA #4. 3.625" MM Mill, BS, 2* 2 7/8" DCs, 12 its 2 7/8"
PACX DP, XO, BS, Stabilizers, XO, 2 boot baskets, Csg
Scraper, Bumper Sub, Oil Jars. TL = 469.55'.
RIH wI BHA #4 on 31/2" Drill Pipe to 8,470'. Pick-up Kelly.
Circulate across top of Chemical Cut Stump at 8,489' several
times to 8,500'. Set back Kelly.
Continue run in hole to 8,689'. Set down solid. Unable to wash
through. Pick-up Kelly.
Rotate and wash from 8,689' - 8,700'.
Riverse Circulate. Recovered Sand, Rubber, Scale, bits of
aluminum, and fine Silt. Con't to clean out from 8700 to 8845'.
(top of junk catcher)
reverse circulate bottoms up. Mix & pump Hi-Vis sweep. 5 BPM
@ 1500 Psi. Monitor well.
POOH & UD 3 1/2" DP.
UD BHA # 4. Clean out junk baskets. Recovered sand, cement
& bits of metal junk. Mill was wom smoothe. Clear rig Floor.
Pull wear bushing. Clean rig floor.
RlU to run 4 1/2" completion.
Finish rigging up 4 1/2" tubing tools. Hold PJSM & Review
running plan for completion.
M/U tailpipe assy, Baker-Iok everything below packer.
RIH Jewelry and 194 Jts of 41/2" Chrome Tbg. M/U & torq
tum connections to 4440 ft-Ibs. Used Jet-lube Seal on
connections.
Tag up & space out completion string. M/U hanger & landing
it.
RID tubing tools & torq turn equip.
Reverse circulate & displace well wI 90 Bbls of heated
seawater, followed by 200 Bbls of heated inhibited
seawater.Pumped @ 3 BPM, 250 psi.
Drain BOP stack. Land completion string. Bottom of mule shoe
@ 8452'. RILDS. UD landing it.
Printed: 7/20/2004 12:18:56 PM
r--
~
BP EXPLORATION
Operations Summary Report
Legal Well Name: R-09A
Common Well Name: R-09A
Event Name: WORKOVER Start: 7/6/2004
Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/16/2004
Rig Name: NABORS 4ES Rig Number: 4ES
Date I From - To Hours I Task' Code I NPT I Phase
'P-""""""""""
7/15/2004 17:00 - 20:00 3.00 RUNCor P RUNCMP
7/16/2004
20:00 - 21 :00
21 :00 - 00:00
00:00 - 02:30
1.00 RUNcm P
3.00 BOPSUF P
2.50 WHSUR P
RUNCMP
RUNCMP
RUNCMP
02:30 - 03:30
03:30 - 07:00
1.00 WHSUR P
3.50 WHSUR P
RUNCMP
RUNCMP
07:00 - 08:00
1.00 WHSUR P
RUNCMP
Page 6 of 6
Spud Date: 7/10/1981
End: 7/16/2004
Description of Operations
-----
.-----.-
Drop bali/rod. Presure up on tbg to 3500 psi. Hold & test tbg for
30 min. Bleed off tbg to 1500 psi. & SI. Pressure up on annulus
to 3500 psi, hold for 30 min. Bleed off tbg to 600 psi & DCV
sheared. Bleed off pressure. Pump down tbg & then back side
to insure valve completely sheared. 3 BPM @ 1100 psi.
Charted entire test.
RID test equip. Set TWC & test same. Drain BOP stack.
Change out Blind rams. ND BOPE. RID 2nd annulus valve.
N/U adapter flange & X-mas tree. Test flange & tree to 5000
psi, Ok.
P/U lubricator. Pull TWC. RID lubricator.
RlU hot oiler. Pump 80 Bbls of diesel as freeze protection fluid
down annulus. Allow diesel to U-tube.
Set BPV and test. Secure Prod Tree and Cellar. Rig released
at 08:00 hrs.
Printed: 7/20/2004 12:18:56 PM
~
.~,
Well:
Field:
API:
Permit:
R-09A
Prudhoe Bay Unit
50-029-20609-01-00
198-233
Accept:
Spud:
Release:
Rig:
07/06/04
N/A
07/16/04
Nabors 4ES
'~m~_.'_._--_..,..."......_. .
POST RIG WORK
07/21/04
PULLED STA # 4 & 5, SET GENERICS. PULLED 4 112" RHC PLUG BODY. ATTEMPT TO PULL JUNK
CATCHER.
07/22/04
MADE SEVERAL ATTEMPTS TO PULL JUNK CATCHER. RECOVER RIG DEBRIS FROM BAILER.
07/23/04
PULL 4.5" JUNK CATCHER. PULL PX PRONG. BAIL WI 3" & 2.25" PUMP BAILER & DRIVE DOWN, BAILED
THICK MUD, PLASTIC & METAL PIECES, & RUBBER ELEMENTS.
07/24/04
PUMP BAIL THICK DRILLING MUD OFF PXN BODY, WI PUMP BAILER RUN GR, UNABLE TO LATCH.
07/25/04
RUN GR CAN'T LATCH. BAIL WI MANY BAILERS. 4.5" PXN PLUG BODY STILL IN WELL.
07/26/04
MUIRIH WITH JSN, UNABLE TO GET PAST TUBING STUB. POH. RBIH WITH EXTRA STINGER AND SAME 3"
JSN. TAG UP AT 8781' (UP). WASH TO 8860' (UP) 8862' (DOWN.) USING KCL AND FLO-PRO SWEEPS.
07/27/04
WASH TO 8860 AND CHASE FINAL FLO-PRO SWEEP TO SURFACE AT 80%. MU AND RIH WITH VENTURI.
TAG AT 8861' (UP). HOVER ON TOP OF PLUG. POH.RECOVER 6" PIECES OF BALLED UP BRASS SHEAR
STOCK, LARGE CHUNKS ALUMINUM AND CEMENT. RIH WITH VENTURI. UNABLE TO GO PAST TOL 8495'
CTM. POH. NO RECOVERY IN BB. STRAIGHTEN PIPE ADD 4' BARREL EXTENSION.RIH CONTINUE SETTING
DOWN AT 8495'. UNABLE TO GET PAS TOL. POH. VENTURI BASKET AND FILTER CLEAN. MUIRIH WITH 4"
GS SPEAR FISHING ASSY. LATCH FISH AT 8861' (UP). HIT 50 JAR LICKS. NO MOVEMENT. PUMP OFF
PLUG AND POH.
07/28/04
CUT PIPE AND MAKE UP NEW FISHING ASSEMBLY. RIH WITH GS. LATCH JAR 50 LICKS, COULD NOT
FREE PLUG. PUMP OFF PLUG. POOH, CUT PIPE, AND INSTALL NEW DAILEY JARS AND ACCELERATOR.
RIH AND PUMP 6 BBLS 12% DAD ACID. MADE 37 JAR LICKS AND LOST JAR ACTION AND COULD NOT
PUMP OFF GS. WORKED PIPE AND ROCKED PUMP AND COULD NOT RELEASE FROM FN. PRESSURED
UP COIL AND SHEARED BURST DISC. DROPPED 7/8" DISCONNECT BALL AND RELEASED AT
DISCONNECT. TOP OF FISH AT 8859' CTM. (FN PROFILE LOOKING UP 3-1/2" G FN - BAKER 3" GS TO PULL-
LENGTH IS 3.08' WIO PLUG - SEE DRAWING IN WELL FILE). PUMPED 6 BBLS OF ACID TO CLEAN OUT
ABOVE FN
07/29/04
WASHED DOWN THROUGH ACID AND CHASED OOH AT 80%. FREEZE PROTECTED TUBING FROM 2500'
TO SURFACE W 50/50 METHANOL WATER. SI WELL AND RD. CONTACT PAD OPERATOR WI WELL
STATUS. JOB INCOMPLETE - FISH IN HOLE.
08/09/04
RIH BOT MHA WITH 31/2" G SPEAR. LATCH INTO FISH WITHOUT PROBLEM. PERFORM 12 LICKS,
INCREASING STRAIGHT WEIGHT PULLS UP. AT 29K OVER (47K SURFACE) SAW POSITIVE INDICATION OF
FISH MOVEMENT. POOH. SURFACE BREAK DOWN LUBRICATOR RECOVER ALL FISH LEFT IN HOLE AND
PXN PLUG. FREEZE PROTECT TUBING WITH 38 BBLS METHANOL. JOB COMPLETE.
~
TREE =
W8.LI-EAO =
A CTUA TOR =
KB. ELEV =
BF. ELEV =
KOP=
Max Angle =
Oatum MO =
Oatum NO =
4"CrN
FMC
AXELSON
49.27'
21.2'
4299'
97 @ 12897'
9477'
8800' SS
113-3/8" CSG, 72#, L-80,10 = 12.347" H
2670'
14-1/2TBG, 12.6#, 13-CR, .0152bpf, 10=3.833" H
IT' LNR, 26#, L-BO, .0383 bpf, 10 = 6.276" H
17" X 5-112" XO, D = 4.892" H
15-1/2" X 4-1/2" XO, D = 4.892" H
14-1/2" UNQUEOVERSI-OT H
8414'
8433'
8433'
8481'
8486'
Minimum ID = 3.725" @ 8871'
4-1/2" HES XN NIPPLE
1 TOP OF 7" Lt\R H 8574'
14-1/2" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" H
8883·
19-518" CSG, 47#, L-80, 10= 8.681" H 9075'
PERFORATION SUMMA RY
REF LOG: TIE INTO NA ffilLL ON 01/01/99
ANGLEATTOPÆRF: 91 @10105'
f\bte: Refer to A'oduction OB for historical perf da1a
SIZE SFf' INTERVAL OpnlSqz DA TE
2-7/8" 4 10105 - 10130 0 05/14AJO
2-7/8" 4 10305 - 10330 0 05/14AJO
4-1/2" 111BO -13118 SLTD 01/13199
R-09A
. I
~
SAFETY NOTES: 70° @ 9298' & 90° @ 9538',
***4-1/2" CHROME TBG***
2058' H4-1/2" HEB X NP, 10 = 3.813" 1
GAS LIFT MANffiELS
ST MO NO OBI TYPE VL V LA TD-I PORT DATE
6 3124 3124 1 KBG-2 avlY BK 0 07/16/04
5 3862 3862 1 KBG-2 OOME BK 16 07/21/04
4 5398 5328 23 KBG-2 SO BK 20 07/21/04
3 6348 6207 21 KBG-2 avlY BK 0 07/16/04
2 7214 7020 18 KBG-2 avlY BK 0 07/16/04
1 8206 7923 27 KBG-2 avlY BK 0 07/16/04
8274' H4-1/2" HEB X NIP, 10= 3.813" I
8295' H7"X4-1/2" BKRS-3PKR I
8403' H4-1/2" HEB X NIP, 10= 3.813" I
8452' H4-1/2" MLlESI-OE, 10 = 3.833" 1
8532' H4-1/2" HEB X NP, 10 = 3.813" I
8543' H 9-5/8" X 4-1/2" BKR S-3 PERM PKR, D = 3.875"
8567' H4-1/2" HEB X NP, 10 = 3.813" I
8871' H4-1/2" HEB XN NP,IO = 3.725" 1
8877'
8883·
8885'
HTEBACKSLV 1
H4-1/2"IfVLEG, 10 = 3.958" I
H BKR ZXP PKR & HMC LNR HGR
r----1 ~.
-
..
8879' H ELMO TT LOGGED 01/19/99 1
WlLLOUTWlNDOW 9081' - 9101'
10298' HRA TAG COLLAR 1
1 11000' HRA TAG COLLAR I
I 11178' HBKRPAYZONECTCPKR, 10= 3.969"
) 11690' HRA TAG COLLAR 1
".~ 12060' HRA TAG COLLAR I
...
ITOPOFWHPSTOCK H
9087'
IT' LNR, 29#, L-BO .0371 bpf, 10 = 6.184" H 9906'
14-1/2" Lt\R, 12.6#, L-80, .0152 bpf, 10 = 3.953" H 11178' I
'.'I2"SL1DLNR, '"6#,L·OO, 0152 bpf,"03.953· H 13118" ">J
4-1/2"LNRSHOEH 13120' ~
OA TE REV BY COMMENTS
07/28181 ORIGINAL COMPLETION
01/13199 SIDETRACK (R-09A)
07/17/04 JLMIKAK RWO
07/21/04 RMHiKAK GLV C/O
OA TE REV BY
COM\1ENTS
PRUŒiOE SA Y UNrr
WELL: R-09A
ÆRWIT No: 198-2330
API f\b: 50-029-20609-01
SEe 32, T12N, R13E, 774.46' & 1614.2' FWL
BP Exploration (Alaska)
198-233-0 PRUDHOE BAy'UNIT 'R-09A
Roll #1: Start: Stop Roll #2: Start
50- 029-20609-01 BP EXPLORATION
(ALASKA) rNC
Stop
MD 13125 TVD 08813 Completion Date: 1/13/99 Completed Status: I-OIL Current:
T Name Interval Sent Received T/CiD
v/L IMPULSE-MD FINAL 9109-13125 %~.. ~y OH 3/30/99 4/27/99
,//L IMPULSE-TVD FINAL 8700-8868~'~ ~/-' OH 3/30/99 4/27/99
v//R SRVYRPT SCHLUM 8999-13125. OH 2/17/99 2/22/99
g/~ 9042 1-3 SCHLUM IMP OH 3/30/99 4/27/99
Thursday, January 25, 2001 Page 1 of 1
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
1. Operations performed: operation shutdown_ Stimulate _X Plugging_ Perforate_
ACID STIM Pull tubing _ Alter casing _ Repair well _ Other _
2. Name of Operator
BP Exploration (Alaska), Inc.
3. Address
P. O. Box 196612
Anchorage, AK 99519-6612
4. Location of well at surface
774' FSL, 1614' FWL, Sec. 32, T12N, R13E, UM
At top of productive interval
2747' FSL, 1419' FWL, Sec. 32, T12N, R13E, UM
At effective depth
855' FNL, 1820' FEL, Sec. 31, T12N, R13E, UM
At total depth
849' FNL, 1824' FEL, Sec. 31, T12N, R13E, UM
5. Type of Well:
Development ~X
Exploratory__
Stratigraphic__
Service__
(asp's 635263, 5977255)
(asp' s n/a)
(asp's 631751, 5980843)
(asp's 631747, 5980848)
6. Datum elevation (DF or KB feet)
RKB 49 feet
7. Unit or Property name
Prudhoe Bay Unit
8. Well number
R-09A
9. Permit number / approval number
198-233
10. APl number
50-029-20609-01
11. Field / Pool
Prudhoe E~ ~¢j~I~L.~ ~.uC~no~J~a~ool
I 1- L.,I::: I V i--
12. Present well condition summary
Total depth: measured
true vertical
13125 feet Plugs (measured)-
8813 feet
JUL 2 0 ; 001
Effective depth: measured
true vertical
Casing Length
Conductor 110'
Surface 2642'
Intermediate 9047'
Liner 533'
Sidetrack Liner 4243'
13118 feet Junk (measured)
8813 feet
Size Cemented Measured Depth
20" x 30" 72 c.f. concrete 138'
13-3/8" 3720 c.f. Arcticset II 2670'
9-5/8" 1248 cf 'G', 130 cf AS I 9075'
7" 432 c.f. Class 'G' 8574' - 9107'
4-1/2" 327 c.f. Class 'G' 8877' - 13120'
Alaska Oil & Gas Cons, Commission
Anchorage
True VerticalDepth
138'
2670'
8701'
8252'-8728'
8524'-8814'
Perforation depth:
measured Slotted Liner 11180' - 13118'. Add Perfs 10105' - 10130', 10305' - 10330'
true vertical Slotted Liner 8847' - 8814'. Add Perfs 8841' - 8841', 8845' - 8846'
Tubing (size, grade, and measured depth)
Packers & SSSV (type & measured depth)
4-1/2", 12.6#, L-80 TBG @ 8543' MD. Tubing Tail @ 8883'.
9-5/8" x 4-1/2" BKR S-3 PKR @ 8543'. BKR ZXP PKR @ 8877'. BKR CTC PKR @ 11178'.
4-1/2" HES X Nipple @ 2006' MD.
13. Stimulation or cement squeeze summary
Intervals treated (measured) (see attached)
Treatment description including volumes used and final pressure
14.
Prior to well operation
Subsequent to operation
OiI-Bbl
Representative Daily Average Production or Iniection Data
Gas-Mcf Water-Bbl
Casing Pressure Tubing Pressure
15. Attachments
Copies of Logs and Surveys run __
Daily Report of Well Operations __
16. Status of well classification as:
Oil ___X Gas __ Suspended __
Service
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
DeWayne R. Schnorr
Date July 19, 2001
Prepared by DeWayne R. Schnorr 564-5174
Form 10-404 Rev 06/15/88 ·
SUBMIT IN DUPLICATE
R-09A
DESCRIPTION OF WORK COMPLETED
. NRWO OPERATIONS
03/22/2001
04/09/2001
04/1 O/2O01
PRE ACID TIFL
ACID STIM
ACID STIM
EVENT SUMMARY
03/22/01
PRE ACID TIFL PASSED. T/I/O =220/1760/0. TEMP= 158. INITIAL FL @ 8421'
BLED IA FROM 1760 PSI TO 280 PSI IN 6 OURS AND 40 MINS. MONITOR FOR
30 MINS. NO INCREASE IN PRESSURE. POST BLEED FL @ 8447'. FINAL
WHP's = 1120/280/0. POP.
04/09/01
MIRU CTU#3; MU 3.125" VENTURI BAILER W/3.25" SHOE; KILL WELL WITH 2%
NON SLICK KCL, RIH TO 10500' WNENTURI BASKET- NO DEBRIS
RECOVERED, RIH W/SCH MEM LOG, TIE IN FOR STRADDLE PACK ACID JOB;
RIH WITH PACKER; SIT AT 9900' TO DO INJ. TEST. CONTINUE ON NEXT DAY
WSR.
04/10/01
AT 9900'; LINE UP TO PUMP CRUDE DOWN BACKSIDE TO LOAD WELL; TIE-IN
TO FLAG AND CORRECT DEPTH; ON DEPTH ACROSS PERFS. AT 10,305'-
10,325'; ACTUATE TREATING PACKER; PUMP 30 BBLS. 12% HCL, 50 BBLS 2%
KCL, 30 BBLS. OF SCALE INHIBITOR, 50 BBLS. KCL, 50 BBLS DIESEL/10% U-66,
OVER FLUSH WITH KCL, REPEAT ABOVE AT 10,105'-10,125'; POOH; ***GIVE
WELL BACK TO PCC TO POP***
Fluids Pumped
450 NON SLICK 2%KCL WATER
250 2%KCL WATER
90 60/40 METHANOL/WATER
435 CRUDE
1225 TOTAL
Page 1
3/30/99
GeoQuest
3940 Arctic Bird
Anchorage, AK 99503
ATTN: Sherrie
NO. 12482
Company Alaska Oil & Gas Cons Corem
Attn: Lori Taylor
3001 Porcupine Drive
Anchorage, AK 99501
Field: Prudhoe Bay (Open Hole)
LIS
Well Job # Log Description Date BL Sepia Tape
R-09A ~~'t~)~.~ ~ 99095 IMPULSE MWD 990107 1
R-09A 99095 IMPULSE MD 990107 1 1
R-09A 99095 IMPULSE TVD 990107 1 1
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO:
BP Exploration (Alaska)Inc,
Petrotectnical Data Center MB3-3
900 E, Benson Blvd,
Anchorage, Alaska 99519-6612
Date Delivered:
Schlumberger GeoQuest
3940 Arctic BIvd 9 ~.~--~-)~ - -~-~....
Anchorage, AK 9
Received,~y,~ ~/'
' (/
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
1. Status of Well Classification of Service Well
[] Oil [] Gas [] Suspended [] Abandoned [] Service
2. Name of Operator 7. Permit Number
BP Exploration (Alaska)Inc. 98-233
3. Address 8. APl Number
P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20609-01
4. Location of well at surface 9. Unit or Lease Name
774' NSL, 1614' EWL, SEC. 32, T12N, R13E, UM ~-'
~-~--~-~'~"~-~ ..... i' Prudhoe Bay Unit
At top of productive interval i /'"/J~"?__.¢'/~..': il ~..¢;..~ !', 10. Well Number
2747' NSL, 1419' EWL, SEC. 32, T12N, R13E, UM ii4~~_ _ R-09A
At total depth i ..~'~_~~' ~;~ ill. Field and Pool
4430' NSL, 1837' WEL, SEC. 31, T12N, R13E, UM -'-
.................. Prudhoe Bay Field / Prudhoe Bay
5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool
KBE = 49.27'I ADL 028279
12. Date Spudded I 13. Date I.D. Reached I 14. Date Comp., Susp., or Abandll 5. Water depth, if offshore 116. No. of Completions
12/31/98 1/7/99 1/13/99 N/A MSLI One
17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD)I19. Directional Survey 120. Depth where SSSV set121. Thickness of Permafrost
13125 8813 FTI 13125 8813 FTI [~]Yes []NoI (Nipple) 2006' MDI 1900' (Approx.)
22. Type Electric or Other Logs Run
MWD, DIP, GR, RES
23. CASIN% LINER AND CEMENTING RECORD
CASING SETTING DEPTH HOLE
SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED
20"x 30" Insulated Conductor Surface 110' 36" ~8 cu yds concrete
13-3/8" 72# L-80 Surface 2670' 17-1/2" 37720 cu ft Arcticset II
9-5/8" 47# L-80 Surface 9075' 12-1/4" 1248 cu ft Class 'G', 130 cu ft Arcticset I
7" 29# L-80 8574' 9107' 9906' 432 cu ft Class 'G'
4-1/2" 12.6# L-80 8877' 13120' 6" 327 cu ft Class 'G'
24. Perforations open to Production (MD+TVD of Top and ;25. TUBING RECORD
Bottom and interval, size and number) SiZE DEPTH SET (MD) PACKER SET (MD)
4-1/2" Slotted Liner 4-1/2", 12.6#, L-80 8883' 8543'
MD TVD MD TVD
11205' - 11690' 8846' - 8831'
11694' - 12060' 8831' - 8823' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
12064' - 13118' 8822' - 8814' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED
.~ ¢..F.r. eese...P, r~t ,e6{ with 177 Bbls of Diesel
27. PRODUCTION TEST ~~ ~ it"'2' J~ V/"~ 1
Date First Production Method of Operation (Flowing, gas lift, etc.)
A~s~-,a 0ii & Gas C0r~s~ U0r[~-r'.i~si0~'t -'"'
January 23, 1999 F owing ' Anchor~9{¢
Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO
TEST PERIOD
I
Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR)
Press. 24-HOUR RATE
28. CORE DATA
Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips.
Form 10-407 Rev. 07-01-80 Submit In Duplicate
29. Geologic Markers 30. Formation Tests
Measured True Vertical Include interval tested, pressure data, all fluids
Marker Name Depth Depth recovered and gravity, GOR, and time of each phase.
Sag River 9098' 8721'
Shublik 'A' 9149' 8762'
Shublik 'B' 9222' 8810'
Shublik 'C' 9249' 8824'
Top of Sadlerochit 9297' 8844'
31. List of Attachments
Summary of Daily Drilling Reports, Surveys
32. I hereby certify that the foregoing is true and correct to the best of my knowledge
Terrio Hubblo .~ ~ Title Technical Assistant III Date(Z)~.,,.._'~',"~.___q~_,.
R-09A 98-233 Prepared By Name/Number: Terrie Hubble, 564-4628
Well Number Permit No. / Approval No.
INSTRUCTIONS
GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and
leases in Alaska.
ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water
supply for injection, observation, injection for in-situ combustion.
ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces
on this form and in any attachments.
ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item
16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional
interval to be separately produced, showing the data pertinent to such interval.
ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.).
ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of
the cementing tool.
ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In,
Other-explain.
ITEM 28: If no cores taken, indicate 'none'.
Form 10-407 Rev. 07-01-80
Facility
Date/Time
21 Dec 98
22 Dec 98
23 Dec 98
24 Dec 98
25 Dec 98
26 Dec 98
PB R Pad
Progress Report
Well R-09A
Rig ~ ~00t~ ~
Page
Date
Duration
Activity
06:00-20:00
20:00-00:30
00:30-01:00
01:00-05:30
05:30-06:00
06:00-07:00
07:00-09:00
09:00-14:00
14:00-15:30
15:30-16:30
16:30-18:00
18:00-05:00
05:00-05:30
05:30-06:00
06:00-07:30
07:30-13:00
13:00-14:00
14:00-14:30
14:30-17:30
17:30-18:00
18:00-19:30
19:30-22:00
22:00-23:00
23:00-02:30
02:30-03:00
03:00-04:00
04:00-06:00
06:00-08:00
08:00-11:00
11:00-12:00
12:00-13:00
13:00-14:00
14:00-16:30
16:30-17:00
17:00-18:00
18:00-21:00
21:00-21:30
21:30-23:00
23:00-02:00
02:00-06:00
06:00-07:00
07:00-09:00
09:00-13:30
13:30-15:00
15:00-15:30
15:30-18:30
18:30-19:00
19:00-23:00
23:00-00:00
00:00-01:30
01:30-05:00
05:00-06:00
06:00-09:00
09:00-10:00
14hr
4-1/2 hr
1/2 hr
4-1/2 hr
1/2 hr
lhr
2hr
5hr
1-1/2 hr
lhr
1-1/2 hr
llhr
1/2 hr
1/2 hr
1-1/2 hr
5-1/2 hr
lhr
1/2hr
3hr
1/2 hr
1-1/2 hr
2-1/2 hr
lhr
3-1/2 hr
1/2 hr
lhr
2hr
2hr
3hr
lhr
lhr
lhr
2-1/2 hr
1/2 hr
lhr
3hr
1/2 hr
1-1/2 hr
3hr
4hr
lhr
2hr
4-1/2 hr
1-1/2 hr
1/2 hr
3hr
1/2hr
4hr
lhr
1-1/2 hr
3-1/2 hr
lhr
3hr
lhr
Rig moved 100.00 %
Fill pits with Seawater
Held safety meeting
Circulated at 8496.0 ft
Installed BOP test plug assembly
Removed Xmas tree
Installed BOP stack
Rigged up BOP stack
Retrieved BOP test plug assembly
Removed Tubing hanger
Circulated at 8476.0 ft
Laid down 8496.0 ft of Tubing
Installed Wear bushing
Made up BHA no. 1
Made up BHA no. 1 (cont...)
R.I.H. to 8513.0 ft
Circulated at 8513.0 ft
Serviced Block line
Pulled out of hole to 310.0 ft
Pulled BHA
Made up BHA no. 2
R.I.H. to 8513.0 ft
Fished at 8513.0 ft
Pulled out of hole to 310.0 ft
Pulled BHA
Made up BHA no. 3
R.I.H. to 6000.0 ft
Milled Downhole equipment at 8513.0 ft
Pulled out of hole to 310.0 ft
Pulled BHA
Serviced Block line
Made up BHA no. 4
R.I.H. to 8513.0 ft
Fished at 8513.0 ft
Circulated at 8529.0 ft
Pulled out of hole to 310.0 ft
Laid down fish
Made up BHA no. 5
R.I.H. to 8531.0 ft
Milled Permanent packer at 8531.0 ft
Milled Permanent packer at 8531.0 ft (cont...)
Circulated at 8574.0 ft
Pulled out of hole to 310.0 ft
Pulled BHA
Made up BHA no. 6
R.I.H. to 8578.0 ft
Fished at 8578.0 ft
Pulled out of hole to 310.0 ft
Pulled BHA
Made up BHA no. 7
R.I.H. to 8578.0 ft
Fished at 8578.0 ft
Pulled out of hole to 310.0 ft
Pulled BHA
1
15 January 99
Facility
Date/Time
27 Dec 98
28 Dec 98
29 Dec 98
PB R Pad
Progress Report
Well R-09A
Rig (null)
Page
Date
Duration
Activity
10:00-11:00
11:00-14:00
14:00-15:30
15:30-19:00
19:00-20:00
20:00-21:00
21:00-23:00
23:00-00:00
00:00-02:00
02:00-02:30
02:30-06:00
06:00-07:30
07:30-08:00
08:00-09:00
09:00-10:00
10:00-11:00
11:00-12:00
12:00-13:00
13:00-16:00
16:00-17:00
17:00-21:30
21:30-23:00
23:00-01:00
01:00-03:00
03:00-05:30
05:30-06:00
06:00-06:30
06:30-07:30
07:30-10:30
10:30-10:45
10:45-14:30
14:30-16:30
16:30-17:00
17:00-20:30
20:30-21:30
21:30-23:30
23:30-00:00
00:00-02:00
02:00-02:15
02:15-02:30
02:30-02:45
02:45-05:00
05:00-05:15
05:15-05:30
05:30-06:00
06:00-07:00
07:00-11:00
11:00-12:00
12:00-12:30
12:30-13:00
13:00-15:30
15:30-20:00
20:00-22:30
22:30-04:00
lhr
3hr
1-1/2 hr
3-1/2 hr
lhr
lhr
2hr
lhr
2hr
1/2 hr
3-1/2 hr
1-1/2 hr
1/2 hr
lhr
lhr
lhr
lhr
lhr
3hr
lhr
4-1/2 hr
1-1/2 hr
2hr
2hr
2-1/2 hr
1/2 hr
1/2 hr
lhr
3hr
1/4 hr
3-3/4 hr
2hr
1/2 hr
3-1/2 hr
lhr
2hr
1/2 hr
2hr
1/4 hr
1/4 hr
1/4 hr
2-1/4 hr
1/4 hr
1/4 hr
1/2hr
lhr
4hr
lhr
1/2 hr
1/2 hr
2-1/2 hr
4-1/2 hr
2-1/2 hr
5-1/2 hr
Made up BHA no. 8
R.I.H. to 8557.0 ft
Fished at 8612.0 ft
Pulled out of hole to 310.0 ft
Pulled BHA
Made up BHA no. 9
R.I.H. to 5000.0 ft
Serviced Block line
R.I.H. to 8523.0 ft
Fished at 8612.0 ft
Pulled out of hole to 310.0 ft
Pulled out of hole to 310.0 ft
Pulled BHA
Made up BHA no. 10
R.I.H. to 2512.0 ft
Pulled out of hole to 310.0 ft
Pulled BHA
Made up BHA no. 11
R.I.H. to 8578.0 ft
Fished at 8578.0 ft
Pulled out of hole to 310.0 ft
Pulled BHA
Laid out BI-LA from derrick
Made up BHA no. 12
R.I.H. to 9077.0 ft
Washed to 9100.0 ft
Washed to 9097.0 ft (cont...)
Tested Liner - Via annulus and string
Drilled cement to 9111.0 ft
Flow check
Pulled out of hole to 895.0 ft
Pulled BHA
Made up BHA no. 13
R.I.H. to 8889.0 ft
Tested Casing - Via annulus
Pulled out of hole to 2000.0 ft
Serviced Block line
Pulled out of hole to 30.0 ft
Pulled BHA
Retrieved Bore protector
Installed BOP test plug assembly
Tested Well control
Retrieved BOP test plug assembly
Installed B ore protector
Made up BHA no. 14
Made up BHA no. 14 (cont...)
R.I.H. to 9100.0 ft
Set tool face
Held safety meeting
Set tool face
Circulated at 9100.0 ft
Rigged up Logging/braided cable equipment
Rigged up Logging/braided cable equipment
Conducted electric cable operations
2
15 January99
Progress Report
Facility PB R Pad
Well R-09A
Rig (null)
Page 3
Date 15 January 99
Date/Time
30 Dec 98
31 Dec 98
01 Jan 99
02 Jan 99
03 Jan 99
04 Jan 99
04:00-04:30
04:30-06:00
06:00-13:30
13:30-15:30
15:30-19:00
19:00-20:30
20:30-22:30
22:30-00:00
00:00-00:30
00:30-02:00
02:00-06:00
06:00-12:00
12:00-12:30
12:30-14:00
14:00-15:30
15:30-20:30
20:30-21:30
21:30-22:30
22:30-00:00
00:00-00:30
00:30-03:00
03:00-04:00
04:00-06:00
06:00-12:00
12:00-12:30
12:30-00:00
00:00-05:00
05:00-06:00
06:00-07:00
07:00-08:00
08:00-12:00
12:00-12:30
12:30-00:00
00:00-00:30
00:30-05:30
05:30-06:00
06:00-07:00
07:00-07:30
07:30-09:00
09:00-12:00
12:00-12:30
12:30-00:00
00:00-00:30
00:30-02:00
02:00-06:00
06:00-07:00
07:00-07:30
07:30-08:00
08:00-10:30
10:30-11:00
11:00-11:30
11:30-12:00
12:00-12:30
12:30-17:00
Duration
1/2hr
1-1/2 hr
7-1/2 hr
2hr
3-1/2 hr
1-1/2 hr
2hr
1-1/2 hr
1/2 hr
1-1/2 hr
4hr
6hr
1/2hr
1-1/2 hr
1-1/2 hr
5hr
lhr
lhr
1-1/2 hr
1/2 hr
2-1/2 hr
lhr
2hr
6hr
1/2 hr
11-1/2 hr
5hr
lhr
lhr
lhr
4hr
1/2 hr
11-1/2 hr
1/2 hr
5hr
1/2 hr
lhr
1/2 hr
1-1/2 hr
3hr
1/2 hr
11-1/2 hr
1/2 hr
1-1/2 hr
4hr
lhr
1/2hr
1/2hr
2-1/2 hr
1/2 hr
1/2 hr
1/2 hr
1/2 hr
4-1/2 hr
Activity
Worked toolstring at 9109.0 ft
Milled Casing at 9087.0 ft
Milled Casing at 9107.0 ft (cont...)
Circulated at 9107.0 ft
Pulled out of hole to 300.0 ft
Pulled BHA
Made up BHA no. 15
R.I.H. to 4500.0 ft
Held safety meeting
R.I.H. to 9107.0 ft
Drilled to 9155.0 ft
Drilled to 9270.0 ft (cont...)
Held safety meeting
Drilled to 9356.0 ft
Circulated at 9356.0 ft
Pulled out of hole to 500.0 ft
Pulled BHA
Rig moved 100.00 %
Made up BHA no. 16
Held safety meeting
Singled in drill pipe to 5000.0 ft
Serviced Block line
R.I.H. to 9356.0 ft
Drilled to 9563.0 ft
Held safety meeting
Drilled to 9907.0 ft
Drilled to 10230.0 ft
Circulated at 10230.0 ft
Pulled out of hole to 9050.0 ft
R.I.H. to 10230.0 ft
Drilled to 10451.0 ft
Held safety meeting
Drilled to 10984.0 ft
Held safety meeting
Drilled to 11271.0 ft
Circulated at 11271.0 ft
Pulled out of hole to 9045.0 ft
Serviced Block line
R.I.H. to 11271.0 ft
Drilled to 11367.0 ft
Held safety meeting
Drilled to 11907.0 ft
Held safety meeting
Circulated at 11907.0 ft
Pulled out of hole to 3500.0 ft
Pulled out of hole to 200.0 ft
Pulled BHA
Retrieved Wear bushing
Tested BOP stack
Installed Wear bushing
Serviced Kelly
Made up BHA no. 17
Held safety meeting
R.I.H. to 8550.0 ft
Progress Report
Facility PB R Pad
Well R-09A
Rig (null)
Page 4
Date 15 January 99
Date]Time
17:00-18:00
18:00-19:30
19:30-20:00
20:00-06:00
05 Jan 99 06:00-06:00
06 Jan 99 06:00-06:00
07 Jan 99 06:00-07:30
07:30-09:00
09:00-11:00
11:00-12:00
12:00-16:00
16:00-19:30
19:30-04:00
08 Jan 99 04:00-05:30
05:30-06:00
06:00-06:30
06:30-14:00
14:00-15:00
15:00-16:30
16:30-17:30
17:30-19:30
19:30-21:00
21:00-22:30
22:30-00:15
09 Jan 99 00:15-00:30
00:30-00:45
00:45-02:00
02:00-03:00
03:00-06:00
06:00-06:30
06:30-08:00
08:00-13:00
13:00-13:30
13:30-17:00
17:00-18:00
18:00-23:00
23:00-00:00
10 Jan99 00:00-00:30
00:30-06:00
06:00-08:30
08:30-13:30
13:30-14:30
14:30-15:00
15:00-15:30
15:30-19:00
19:00-20:00
20:00-21:30
21:30-23:00
23:00-23:30
23:30-02:30
11 Jan99 02:30-06:00
06:00-06:30
06:30-07:00
07:00-08:00
Duration
lhr
1-1/2 hr
1/2 hr
10hr
24 hr
24 hr
1-1/2 hr
1-1/2 hr
2hr
lhr
4hr
3-1/2 hr
8-1/2 hr
1-1/2 hr
1/2 hr
1/2 hr
7-1/2 hr
lhr
1-1/2 hr
lhr
2hr
1-1/2 hr
1-1/2 hr
1-3/4 hr
1/4 hr
1/4 hr
1-1/4 hr
lhr
3hr
1/2 hr
1-1/2 hr
5hr
1/2 hr
3-1/2 hr
lhr
5hr
lhr
1/2 hr
5-1/2 hr
2-1/2 hr
5hr
lhr
1/2 hr
1/2 hr
3-1/2 hr
lhr
1-1/2 hr
1-1/2 hr
1/2 hr
3hr
3-1/2 hr
1/2 hr
1/2 hr
lhr
Activity
Held safety meeting
R.I.H. to 11907.0 ft
Circulated at 11907.0 ft
Drilled to 12100.0 ft
Drilled to 12650.0 ft (cont...)
Drilled to 13080.0 ft (cont...)
Drilled to 13125.0 ft (cont...)
Circulated at 13125.0 ft
Pulled out of hole to 9012.0 ft
Serviced Block line
R.I.H. to 13125.0 ft
Circulated at 13125.0 ft
Pulled out of hole to 395.0 ft
Pulled BHA
Rigged up Tubing handling equipment
Held safety meeting
Ran Liner to 4249.0 ft (4-1/2in OD)
Circulated at 4249.0 ft
Ran Liner on landing string to 9000.0 ft
Circulated at 9000.0 ft
Ran Liner on landing string to 13125.0 ft
Circulated at 13125.0 ft
Functioned Casing hanger
Batch mixed slurry - 58.000 bbl
Pumped Water based mud spacers - volume 20.000 bbl
Mixed and pumped slurry - 58.000 bbl
Displaced slurry - 185.000 bbl
Circulated at 8886.0 ft
Pulled Drillpipe in stands to 800.0 ft
Pulled Drillpipe in stands to 0.0 ft (cont...)
Rigged up Drillstring handling equipment
Made up BHA no. 18
Rigged down Drillstring handling equipment
R.I.H. to 11166.0 ft
Tested Casing
Drilled installed equipment - Landing collar
R.I.H. to 13118.0 ft
Circulated at 13118.0 ft
Circulated at 13118.0 ft
Circulated at 8818.0 ft (cont...)
Pulled out of hole to 4692.0 ft
Functioned Circulating sub
Rigged up Drillstfing handling equipment
Serviced Block line
Pulled BHA
Rigged down Drillstring handling equipment
Rigged up Logging/braided cable equipment
Conduct braided cable operations - 5/16 size cable
Rigged down Wireline units
Ran Drillpipe in stands to 7500.0 ft
Laid down 5500.0 ft of 5in OD drill pipe
Laid down 2000.0 ft of 5in OD drill pipe (cont...)
Retrieved Wear bushing
Rigged up Tubing handling equipment
Facility
Date/Time
12 Jan 99
13 Jan 99
PB R Pad
Progress Report
Well R-09A
Rig (null)
Page
Date
Duration
Activity
08:00-08:30
08:30-19:30
19:30-22:00
22:00-23:00
23:00-00:00
00:00-00:30
00:30-01:30
01:30-06:00
06:00-20:30
20:30-22:00
22:00-23:00
23:00-01:00
01:00-03:30
03:30-04:30
04:30-06:00
1/2 hr
llhr
2-1/2 hr
lhr
lhr
1/2 hr
lhr
4-1/2 hr
14-1/2 hr
1-1/2 hr
lhr
2hr
2-1/2 hr
lhr
1-1/2 hr
Held safety meeting
Ran Tubing to 8883.0 ft (4-1/2in OD)
Reverse circulated at 8858.0 ft
Ran Tubing on landing string to 8883.0 ft
Tested Tubing
Tested Permanent packer
Installed BOP test plug assembly
Removed BOP stack
Removed BOP stack (cont...)
Installed Adapter spool
Installed Xmas tree
Tested Xmas tree
Freeze protect well - 177.000 bbl of Diesel
Tested Xmas tree
Cleared Standpipe manifold
5
15 January 99
ANADRILL
SCHLUMBERGER
Survey report
Client ................... : BP Exploration (Alaska/ Inc.
Field .................... : Prudhoe Bay
Well ..................... : R-09A
API number ............... : 50-029-20609-01
Last survey date ......... : 07-Jan-99
Engineer ................. : Dammeyer
Rig: .................... : Nabors 2ES
MD of last survey ....... : 13125.00 ft
State: .................. : Alaska
RECEIVED
JAN ! 7. 1 99
BPXA PDC
7-Jan-99 09:06:14 Page
1 of 6
Spud date ................ : 25-Dec-98
Total accepted surveys...: 130
MD of first survey ....... : 8999.00 ft
ORIGINAL
Survey calculation methods--
Method for positions ..... : Minimum curvature
Method for DLS ........... : Mason & Taylor
Depth reference -
Permanent datum .......... : Mean Sea Level
Magnetic dip ............. : 80.73 degrees
Depth reference .......... :
GL above permanent ....... : 21.20 ft
KB above permanent ....... : 49.27 ft
DF above permanent ....... : 47.87 ft
Vertical section origin
Latitude (+N/S-) ......... :
Departure (+E/W-) ........ :
0.00 ft
0.00 ft
Platform reference point ......
Latitude (+N/S-) ......... : -999.25 ft
Departure (+E/W-) ........ : -999.25 ft
Azimuth from rotary table to target: 300.50 degrees
Geomagnetic data ....
Magnetic model ........... : BGGM version 1997
Magnetic date ............ : 01-Aug-1998
Magnetic field strength..: 1146.34 HCNT
Magnetic dec (+E/W-) ..... : 28.04 degrees
MWD survey Reference Criteria
Reference G .............. : 1002.68 mGal
Reference H .............. : 1146.38 HCNT
Reference Dip ............ : 80.73 degrees
Tolerance of G ........... : (+/-) 3.00 mGal
Tolerance of H ........... : (+/-) 7.00 HCNT
Tolerance of Dip ......... : (+/-) 0.30 degrees
Corrections --
Magnetic dec (+E/W-) ..... : 27.71 degrees
Grid convergence (+E/W-).: 0.00 degrees
Total az corr (+E/W-) .... : 27.71 degrees
(Total az corr= magnetic dec - grid cony)
Sag applied (Y/N) ........ : No degree: 0.00
[ (c) 1999 Anadrill IDEAL ID5_iA_12R][]
ANADRILL SCHLUMBERGER Survey Report
7-Jan-99 09:06:14
Page
2 of 6
Seq Measured Incl Azimuth Course
# depth angle angle length
- (ft) (deg) (deg) (ft)
1 8999.00 26.73 8.8
2 9103.90 30.01 6,7
3 9123.34 34.70 4.8
4 9155.45 43.02 1.9
5 9186.79 50.09 358,9
6 9217.98 56.30 351.1
7 9249.38 61.21 343.1
8 9281.25 66.14 335.9
9 9298.41 68.74 331.2
10 9317.46 73.11 329.9
11 9349.38 81.26 327.1
12 9378.81 84.30 325.6
13 9411.52 84.82 323.3
14 9442.56 86.57 320.7
15 9473.81 88.39 320.4
16 9505.52 89.79 319.7
17 9538.11 90.62 317.1
18 9571.21 90.69 314.7
19 9601.56 90.48 311.1
20 9630.07 90.75 307.3
21 9664.05 92.02 307.1
22 9695.01 92.75 306.4
23 9727.71 93.91 305.0
24 9758.96 94.53 303.0
25 9790.73 94.46 302.0
26 9822.82 93.91 300.3
27 9853.46 93.67 299.1
28 9885.33 93.67 299.7
29 9919.06 93.60 300.2
30 9949.87 93.84 300.5
0.00
104.90
19,40
32.20
31,30
31.20
31.40
31.80
17.20
19,10
31.90
29,40
32.70
31.10
31.20
31.70
32.60
33.10
30.40
28.50
33.90
31.00
32.70
31.30
31.70
32.10
30.70
31.80
33.80
30.80
TVD
depth
(ft)
8633,60
8725.89
8742,27
8767,33
8788.84
8807.54
8823.84
8837,96
8844.56
8850.80
8857,87
8861.56
8864.66
8867.00
8868.37
8868.88
8868.76
8868.38
8868.07
8867.76
8866,94
8865,65
8863.75
8861.45
8858.97
8856.62
8854.59
8852.56
8850.42
8848.42
Vertical Displ Displ Total At DLS Srvy Tool
section +N/S- +E/W- displ Azim (deg/ tool qual
(ft) (ft) (ft) (ft) (deg) 100f) type type
1057.04 1779.30 -178.70 1788.25 354.26 0.00
1076.35 1828.68 -172.03 1836.76 354.63 3.27
1080.70 1839.01 -171.00 1846.94 354.69 24.73
1089.95 1859.16 -169.87 1866.90 354.78 26,44
1101,37 1881.86 -169.74 1889.50 354,85 23.63
1115.91 1906.70 -171.98 1914.44 354.85 28.21
1134.36 1932.81 -178.02 1941.00 354,74 26.80
1156.51 1959.47 -188.02 1968.47 354.52 25.53
1169,82 1973.68 -195.10 1983.30 354.35 29.41
1185,44 1989.39 -203.97 1999.82 354.15 23.77
1212.88 2015.88 -220.22 2027.87 353.77 26.94
1239.13 2040.16 -236.38 2053.80 353.39 11.51
1268.88 2066.64 -255.31 2082.35 352.96 7.18
1297.73 2091.07 -274.40 2109.00 352.52 10.06
1327.01 2115.14 -294.20 2135.50 352.08 5.91
1356.88 2139.44 -314.56 2162.44 351.64
1387.89 2163.81 -336.20 2189.78 351.17
1419.80 2187.58 -359.23 2216.88 350.67
1449.49 2208.27 -381.49 2240.98 350.20
1477.65 2226.28 -403.57 2262.56 349.73
1511.31 2246.77 -430.57 2287.65 349.15
1542.10 2265.30 -455.38 2310.62 348.63
1574.61 2284.35 -481.89 2334.62 348.09
1605.76 2301.80 -507.77 2357.14 347.56
1637.35 2318.78 -534.42 2379.57 347.02
1669.36 2335.34 -561.82 2401.97 346.47
1699.99 2350.52 -588.43 2423.05 345.95
1731.71 2366.10 -616.08 2444.99 345.41
1765.44 2382.94 -645.30 2468.77 344.85
1796.18 2398.47 -671.83 2490.78 344.35
4.94
8.37
7.25
11.86
13.37
3.79
3.26
5.55
6.67
3.15
5.55
3.98
1.88
1.49
1.25
TIP
MWD M
MWD M
MWD M
--
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
[ (c) 1999 Anadrill IDEAL ID5 iA 12RI[]
ANADRILL SCHLUMBERGER Survey Report
Seq Measured Incl Azimuth Course
# depth angle angle length
- (ft) (deg) (deg) (ft)
31 9981.89 93.36 299.6
32 10013.68 92.85 299.2
33 10044.58 92.95 299.2
34 10076.78 92.33 299.6
35 10109.24 90.89 299.1
36 10141.21 89.66 298.3
37 10171.41 89.21 298.5
38 10204.01 89.07 299.5
39 10235.31 88.80 298.4
40 10267.31 87.77 299.3
41 10298.72 86.95 298.6
42 10330.70 86.88 298.5
43 10362.70 86.88 298.5
44 10393.42 86.64 298.5
45 10424.83 86.61 299.2
46 10458.00 86.53 299.4
47 10488.44 86.64 300.0
48 10520.59 86.74 299.7
49 10552.39 86.47 299.3
50 10582.38 86.50 299.4
51 10614.15 86.98 299.4
52 10645.37 88.01 300.1
53 10675.71 89.11 301.2
54 10707.85 89.83 301.8
55 10739.83 90.55 302.3
56 10771.39 90.45 %02.9
57 10803.34 90.93 302.9
58 10835.49 92.06 302.1
59 10865.31 92.54 300.8
60 10896.69 92.95 299.5
TVD
depth
(ft)
7-Jan-99 09:06:14
Page
3 of 6
Vertical Displ Displ Total At DLS Srvy Tool
section +N/S- +E/W- displ Azim (deg/ tool qual
(ft) (ft) (ft) (ft) (deg) 100f) type type
32.00 8846.41 1828.12 2414.46 -699.47
31.80 8844.69 1859.86 2430.05 -727.13
30.90 8843.12 1890.71 2445.10 -754.07
32.20 8841.64 1922.87 2460.89 -782.10
32.40 8840.73 1955.25 2476.77 -810.33
32.00
30.20
32.60
31.30
32.00
8840.58 1987.24 2492.13 -838.39
8840.87 2017.42 2506.50 -864.96
8841.36 2050.00 2522.30 -893.47
8841.95 2081.28 2537.45 -920.85
8842.90 2113.25 2552.88 -948.86
8844.35
8846.07
8847.81
8849.55
8851.40
8853.38
8855.19
8857.05
8858.94
8860.77
8862.58
8863.95
8864.71
8865.00
8864.90
8864.62
8864.24
8863.40
8862.20
8860.70
31.40
32.00
32.00
30.70
31.40
2144.61
2176.54
2208.48
2239.11
2270.44
2303.58
2333.92
2366.06
2397.80
242'7.74
2459.38
2490.65
2520.94
2553. 03
2585. 02
2616.60
2648.47
2680.64
2710.41
2741.77
33.20
30.40
32.20
31.80
30.00
2568.06 -976.31
2583.34 -1004.38
2598.58 -1032.46
2613.21 -1059.40
2628.33 -1086.85
2644.55 -1115.75
2659.59 -1142.11
2675.59 -1169.99
2691.22 -1197.62
2705.89 -1223.72
2721.43 -1251.29
2736.95 -1278.44
2752.39 -1304.50
2769.16 -1331.87
2786.14 -1358.99
2803.17 -1385.61
2820.49 -1412.39
2837.79 -1439.54
2853.32 -1464.94
2869.07 -1492.06
2513.74 343.84 3.18
2536.51 343.34 2.04
2558.74 342.86 0.32
2582.18 342.37 2.29
2605.96 341.88 4.70
2629.38 341.41 4.59
2651.54 340.96 1.63
2675.87 340.49 3.10
2699.37 340.05 3.62
2723.52 339.61 4.27
2747.39 339.18 3.43
2771.72 338.75 0.38
2796.18 338.33 0.00
2819.78 337.93 0.78
2844.18 337.53 2.23
2870.29 337.12 0.65
2894.45 336.76 2.00
2920.21 336.38 0.98
2945.67 336.01 1.52
2969.74 335.67 0.35
2995.32 335.31 1.51
3020.81 334.96 3.98
3045.88 334.64 5.13
3072.80 334.31 2.92
3099.91 334.00 2.74
3126.92 333.70 1.92
3154.37 333.40 1.50
3182.03 333.10 4.30
3207.41 332.82 4.65
3233.86 332.52 4.34
31.70
31.30
30.30
32.10
32.00
31.60
31.90
32.20
29.80
31.40
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
[ (c) 1999 Anadrill IDEAL ID5_iA_12R][]
ANADRILL SCHLUMBERGER Survey Report
Seq Measured Incl Azimuth Course
# depth angle angle length
- (ft) (deg) (deg) (ft)
61 10928.32 92.74 297.9 31.60
62 10960.44 92.57 296.5 32.10
63 10992.32 92.33 294.7 31.90
64 11024.49 92.44 293.2 32.20
65 11056.45 92.37 290.7 32.00
66 11088.44 92.61 290.0 31.90
67 11120.79 92.88 290.2 32.40
68 11152.01 93.19 289.1 31.20
69 11183.46 93.05 287.9 31.50
70 11212.27 92.88 286.3 28.80
71 11246.50 92.54 284.9 34.20
72 11278.61 92.37 283.8 32.10
73 11310.45 92.06 282.1 31.80
74 11342.25 91.89 281.1 31.90
75 11374.37 91.54 280.4 32.10
76 11405.99 91.13 279.7 31.60
77 11437.58 91.03 280.3 31.60
78 11469.52 91.06 280.5 31.90
79 11500.46 91.37 280.0 31.00
80 11532.00 91.95 278.8 31.50
81 11563.98 91.81 278.9 32.00
82 11595.84 91.95 279.6 31.80
83 11627.39 91.51 279.5 31.60
84 11659.66 91.68 279.9 32.30
85 11691.52 91.81 281.2 31.80
86 11723.27 91.37 280.8 31.80
87 11754.97 91.20 280.0 31.70
88 11787.10 91.20 281.3 32.10
89 11818.58 91.30 281.0 31.50
90 11848.53 91.27 280.8 29.90
TVD
depth
(ft)
8859.13
8857.64
8856.28
8854.94
8853.60
8852.21
8850.66
8849.01
8847.29
8845.80
8844.18
8842.81
8841.58
8840.48
8839.52
8838.78
8838.19
8837.61
8836,95
8836.04
8834.99
8833.94
8832.99
8832.09
8831.12
8830.24
8829.53
8828.86
8828.17
8827.50
Vertical
section
(ft)
2773.31
2805.32
2837.08
2869.04
2900.65
2932.02
2963.85
2994.45
3025.22
3053.20
3086.21
3117.01
3147.31
3177.47
3207.67
3237.27
3266.86
3296.81
3325.89
3355.27
3384.99
3414.61
3444.11
3474.30
3504.17
3534.14
3563.90
3594.08
3623.80
3651.96
7-Jan-99 09:06:14
Page
4 of 6
Displ Displ Total At DLS Srvy Tool
+N/S- +E/W- displ Azim (deg/ tool qual
(ft) (ft) (ft) (deg) 100f) type type
2884.23 -1519.74
2898.89 -1548.26
2912.66 -1577.00
2925.72 -1606.41
2937.67 -1636.06
2948.75 -1665.94
2959.87 -1696.33
2970.35 -1725.67
2980.33 -1755.50
2988.78 -1782.99
2997.97 -1815.89
3005.92 -1846.96
3013.04 -1877.93
3019.45 -1909.16
3025.44 -1940.68
3030.95 -1971.78
3036.43 -2002.90
3042.19 -2034.27
3047.71 -2064.77
3052.85 -2095.83
3260.12 332.21 5.10
3286.44 331.89 4.39
3312.18 331.57 5.69
3337.72 331.23 4.67
3362.52 330.89 7.81
3386.81 330.54
3411.51 330.18
3435.25 329.84
3458.92 329.50
3480.21 329.18
2.32
1.04
3.66
3.83
5.58
3505.04 328.80 4.21
3528.00 328.43 3.46
3550.35 328.07 5.43
3572.39 327.70 3.18
3594.37 327.32 2.44
3615.88 326.95
3637.52 326.59
3659.67 326.23
3681,27 325.88
3703.03 325.53
2.57
1.92
0.63
1.90
4.23
3057.77 -2127.43
3062.88 -2158.80
3068.12 -2189.95
3073.56 -2221.78
3079.38 -2253.02
3725.04 325.17 0.54
3747.22 324.82 2.24
3769.51 324.48 1.43
3792.50 324.14 1.35
3815.58 323.81 4.11
3838.97 323.49 1.87
3862.17 323.17 2.58
3885.89 322.85 4.05
3909.46 322.54 1.00
3931.85 322.25 0.68
3085.44 -2284.23
3091.17 -2315.40
3097.10 -2346.94
3103.19 -2377.84
3108.84 -2407.19
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
lVfWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
lViWD
MWD
MWD
MWD M
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
--
[(c)1999 Anadrill IDEAL ID5 1A_12R][]
ANADRILL SCHLUMBERGER Survey Report
Seq Measured Incl Azimuth Course TVD
# depth angle angle length depth
- (ft) (deg) (deg) (ft) (ft)
91 11880,69 91.44 280.2 32.20
92 11912.83 91,41 279.1 32.10
93 11943.89 90.96 275.8 31.10
94 11976,18 91.10 272.6 32.30
95 12006,75 91.75 269.6 30.50
96 12038,79 91.58 266.8 32.10
97 12070.61 90.82 263.4 31.80
98 12102,65 91,03 260.5 32.00
99 12134,63 90,17 263.9 32.00
100 12166,29 88.83 266.7 31.70
101 12197,01 88.80 270.5 30.70
102 12227.83 88.53 273.2 30.80
103 12259,43 88.56 276.6 31.60
104 12291.66 88.42 280.0 32.30
105 12323.92 88.22 282.7 32.20
106 12355.26 87.91 287.0 31.40
107 12386.77 86.30 289.3 31.50
108 12419,13 86.88 292.4 32.30
109 12450,90 87.22 296.5 31.80
110 12482.77 85.58 300.1 31.90
111 12514,66 84.34 303.0 31,90
112 12546,64 85.06 306.4 31.90
113 12578.50 84.68 309.3 31.90
114 12610.75 84.92 313.2 32.20
115 12642.54 85.23 316.3 31.80
116 12674.01 86.57 318.6 31.50
117 12706.22 88.08 320.2 32.20
118 12737.70 90.89 319.7 31.50
119 12769.72 93.05 321.0 32.00
120 12801.51 94.36 321.8 31.80
8826.74
8825.94
8825.29
8824,71
8823.95
8823,02
8822.36
8821.84
8821.50
8821.78
8822.42
8823.13
8823.94
8824.79
8825.73
8826.79
8828.38
8830.30
8831.94
8833.95
8836.75
8839.70
8842.55
8845.47
8848.20
8850.45
8851.95
8852.24
8851.14
8849.08
7-Jan-99 09:06:14
Page
5 of 6
Vertical Displ Displ Total At DLS Srvy Tool
section +N/S- +E/W- displ Azim (deg/ tool qual
(ft) (ft) (ft) (ft) (deg) 100f) type type
3682.21
3712,20
3740.80
3769.75
3796.31
3823.43
3849.34
3874.36
3899.47
3925.37
3951.42
3978.44
4006.93
4036.82
4067.22
4097.43
4128.16
4159.94
4191.52
4223.32
3114.70 -2438.84
3120.08 -2470.48
3124.11 -2501.30
3126.48 -2533.51
3127.07 -2563.99
3126.06 -2596.05
3123.34 -2627.73
3118.86 -2659.40
3114.52 -2691.10
3111.92 -2722.69
3111.17 -2753.37
3112.17 -2784.14
3114.87 -2815.61
3119.53 -2847.56
3125.86 -2879.11
3133.90 -2909.44
3143.70 -2939.33
3155.17 -2969.46
3168.32 -2998.36
3183.41 -3026.39
3200.03 -3053.46
3218,11 -3079.57
3237.60 -3104.66
3258.74 -3128.76
3281.04 -3151.26
3304.19 -3172.51
3328.61 -3193.44
3352.72 -3213.70
3377.34 -3234.11
3402.14 -3253.90
3955.92 321.94 1.94
3979.72 321.63 3.43
4002.08 321.32 10.71
4024.12 320.98 9.91
4043.83 320.65 10.06
4063.46 320.29 8.74
4081.69 319.93 10.95
4098.75 319,55 9.09
4116.10 319.17 10.96
4134.86 318.82 9.79
4154.57 318.49 12.38
4175.77 318.18 8.81
4198.82 317.89 10.76
4223.75 317.61 10.53
4249.74 317.35 8.40
4276.23 317.13 13.72
4303.78 316.92 8.90
4332.76 316.74 9.75
4362.15 316.58 12.92
4392.39 316.45 12.38
4423.10 316.34 9.85
4454.21 316.26 10.85
4485.64 316.20 9.13
4517.58 316.17 12.08
4549.25 316.16 9.76
4580.66 316.16 8.43
4612.77 316.19 6.83
4644.20 316.21 9.06
4676.10 316.24 7.88
4707.70 316.28 4.82
4255.09
4286.76
4318.27
4349.77
4380.47
4410.52
4440.95
4470.65
4500.73
4530.37
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
[ (c) 1999 Anadrill IDEAL ID5_iA_12R][]
ANADRILL SCHLUMBERGER Survey Report
7-Jan-99 09:06:14
Page
6 of 6
Seq Measured Incl Azimuth Course
# depth angle angle length
- (ft) (deg) (deg) (ft)
121 12833.82 95.63 321.7 32.30
122 12865.49 96.56 322.4 31.70
123 12897.28 97.29 322.3 31.80
124 12926.93 97.15 322.4 29.60
125 12959.93 96.77 322.1 33.00
126 12991.78 96.95 322.4 31.90
127 13023.27 96.53 322.2 31.50
128 13053.89 96.22 322.2 30.60
129 13067.05 95.77 322.3 13.20
Survey projected to TD
130 13125.00 95.77 322.3 57.90
TVD
depth
(ft)
8846.27
8842.90
8839.07
8835.35
8831.35
8827.54
8823.84
8820.45
8819.07
8813.25
Vertical Displ Displ Total At DLS Srvy Tool
section +N/S- +E/W- displ Azim (deg/ tool qual
(ft) (ft) (ft) (ft) (deg) 100f) type type
4560.36
4589.68
4618.98
4646.24
4676.66
4706.08
4735.12
4763.38
4775.57
4829.06
3427.41 -3273.82
3452.26 -3293.21
3477.26 -3312.49
3500.51 -3330.43
3526.41 -3350.48
3551.45 -3369.87
3576.20 -3389.00
3600.23 -3407.64
3610.61 -3415.68
3656.19 -3450.91
4739.73 316.31 3.94
4771.10 316.35 3.66
4802.49 316.39 2.32
4831.70 316.43 0.58
4864.29 316.47 1.46
4895.80 316.50 1.09
4926.92 316.54 1.47
4957.19 316.57 1.01
4970.25 316.59 3.49
5027.57 316.65 0.00
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD M
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
[(c) 1999 Anadrill IDEAL ID5 iA 12RI
--
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Robert Christenso~/,~ DATE:
Chairman
December 22, 1998
THRU' Blair Wondzell, ~ FILE NO: .DOC
P. I. Supervisor f'f~'
FROM' Larry Wade,'~~ SUBJECT:
Petroleum I~ispect6r
BOP Test
Nabors 2ES
PBU R-09
PTD 98-233
December 22,1998: I traveled to BPX's R-pad to witness a BOP test on
Nabors2ES. The rumor is that it is the rigs last well before they are stacked out.
The testing went well except for a grease zert in a choke manifold valve and a
packing gland leak on the casing head. Both were repaired and the testing
proceeded in a professional manner.
SUMMARY: I witnessed a BOP test on Nabors 2 ES, 0 failures, 4 hours.
Attachments: aimglufe.xls
cc;
NON-CONFIDENTIAL
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
BOPE Test Report
OPERATION: Drlg: X
Drlg Contractor:
Operator:
Well Name:
Casing Size: 7
Test: Initial X
Workover:
Nabors Rig No. 2ES PTD #
SSD Re p.:
R-Oga Rig Rep.:
Set @ 9,906 Location: Sec.
Weekly Other
98-233
DATE:
Rig Ph.#
Charley Dixon
12_/22/98
Keifh Spoales
32 T. 12N R. 13E Meridian Umiat
Test Pressures 250/5000
Test
Well Sign X
Drl. Rig X
Hazard Sec. X
MISC. INSPECTIONS:
Location Gen.: ok
Housekeeping: ok (Gen)
PTD On Location X
Standing Order Posted X
FLOOR SAFETY VALVES:
Upper Kelly/IBOP
Lower Kelly/IBOP
Ball Type
Inside BOP
Quan, Pressure P/F
· 1 250/5000 P
250/5000 P
250/5000 P
250/5000 P
BOP STACK:
Annular Preventer
Pipe Rams
Lower Pipe Rams
Blind Rams
Choke Ln. Valves
HCR Valves
Kill Line Valves
Check Valve
Quan.
Test Press. P/F
250/3500 P
250/5000 P
250/5000 P
250/5000 P
250/5000 P
250/5000 P
250/5000 P
MUD SYSTEM: Visual Alarm
Trip Tank X X
Pit Level Indicators X X
Flow Indicator X X
Meth Gas Detector X X
H2S Gas Detector X X
CHOKE MANIFOLD:
No. Valves
No. Flanges
Manual Chokes
Hydraulic Chokes
Test
Pressure P/F
14 250/5000 P
34 250/5000 P
P
Functioned
Functioned
ACCUMULATOR SYSTEM:
System Pressure
Pressure After Closure
200 psi Attained After Closure
System Pressure Attained
Blind Switch Covers: Master:
Nitgn, Btl's: 4 @ 2200
3,000
1,600
minutes 27 sec.
1 minutes 23 sec.
x Remote: x
Psig.
Number of Failures: 0 ,Test Time: 3.0 Hours. Number of valves tested 20 Repair or Replacement of Failed
Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to
the AOGCC Commission Office at: Fax NO. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687
If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433
REMARKS:
Distribution:
Grig-Well File
c- Oper./Rig
c- Database
c - Trip Rpt File
c- Inspector
STATE WITNESS REQUIRED?
YES X NO
24 HOUR NOTICE GIVEN
YES X NO
Waived By:
Witnessed By:
Larry Wade
FI-021L (Rev.12/94) Aimglvfe.xls
TONY KNOWLE$, GOVERNOR
ALASKA. OIL AND GAS
CONSERVATION COMMISSION
3001 PORCUPINE DRIVE
ANCHORAGE, ALASKA 99501-3192
PHONE: (907) 279-1433
FAX: (907) 276-7542
November 23, 1998
Dan Stone
Engineering Supcr~'isor
BP Exploration (Alaska) Inc.
P O Box 196612
Anchorage, AK 99519-6612
Re:
Prudhoe Bay Unit R-09A
BP Exploration (Alaska) Inc.
Permit No: 98-233
Sur. Loc. 774'NSL, 1614'EWL, Sec. 32. T12N, R13E, UM
Btmhole Loc. 4516'NSL, 1809'WEL, Sec. 31, T12N. R13E, UM
Dear Mr. Stone:
Enclosed is the approved application for permit to redrill the above referenced well.
The permit to rcdrill docs not exempt you from obtaining additional permits required by law from
other governmental agencies, and does not authorize conducting drilling operations until all other
required permitting determinations are made.
Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035.
Sufficient notice (approximately 24 hours) must be given to allow a representative of the
Commission to ~¥itness a test of BOPE installed prior to drilling new hole. Notice ma5' be given
by c~cum field inspector on the North Slope pager at 659-3607.
David ~on / ~
Chairman
BY ORDER OF THE COMMISSION
dlf/Enclosure
CC:
Department of Fish & Game, Habitat Section w/o cncl.
Department of Environmental Conservation w/o encl.
STATE OF ALASKA
ALASK,~., _ ,'L AND GAS CONSERVATION CON.~_.~ISSION
PERMIT TO DRILL
20 AAC 25.005
la. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil
[] Re-Entry [] DeepenI [] Service [] Development Gas [] Single Zone [] Multiple Zone
2. Name of Operator i5. Datum Elevation (DF or KB) 10. Field and Pool
BP Exploration (Alaska) Inc. Plan KBE = 51' Prudhoe Bay Field / Prudhoe
3. Address 6. Property Designation Bay Pool
P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028279 v"
4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAO 25.025)
774' NSL, 1614' EWL, SEC. 32, T12N, R13E, UM Prudhoe Bay Unit
At top of productive interval "§. Well Number Number 2S100302630-277
3292' NSL, 4610' WEL, SEC. 32, T12N, R13E, UM R-09A
At total depth 9. Approximate spud date Amount $200,000.00
4516' NSL, 1809' WEL, SEC. 31, T12N, R13E, UM 11/24/98
12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD)
ADL 028257, 3055'I No Close Approach 2560 13071' MD / 8840' TVDss
16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)}
Kick Off Depth 9080' MD Maximum Hole Angle 100° Maximum surface 2520 psig, At total depth (TVD) 8790' / 3400 psig
18. Casing Program Specifications Setting Depth
Size Top Bottom Quantity of Cement
Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data)
6" 4-1/2" 12.6# L-80 IBT 4141' 8930' 8521' 13071' 8840' Uncemented Slotted Liner
19. To be completed for Redrill, Re-entry, and Deepen Operations.
Present well condition summary
Total depth: measured 9906 feet Plugs (measured)
true vertical 9488 feet
Effective depth: measured 9297 feet Junk (measured) Tubing tail cut and on bottom at 9806'
true vertical 8904 feet Inflatable bridqe plu_q on bottom at 9297' (01/91)
Casing Length Size Cemented MD TVD
Structural
Conductor 110' 20" x 30" 8 cu yds concrete 110' 110'
Surface 2641' 13-3/8" 3720 cuft Arcticset II 2670' 2670'
Intermediate 9046' 9-5/8" 1248 cu ft 'G', 130 cu ft Arcticset I 9075' 8701'
Production ....... ... ~.i :
Liner 1332' 7" 432 cu ft Class 'G' 8574' ~ 9906''i -' 8252' - 9488'
Perforation depth: measured 9092'- 9134' (Sag River); 9230'- 9286', 9250'- 9270', 929~i~,.-..;~2,.~i.!!v~_),:::~;~
Sqzd: 9320' - 9330' -.-...~.:~
true vertical subsea 8667' - 8704' (Sag River); 8792' - 8875' (three Ivishak interval~i';''~;~';~''~!~!:''
20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program
[] Drilling Fluid Program []Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements
Contact Engineer Name/Number: Philippa Stevenson, 564-5738 Prepared By Name/Number: Terrie Hubble, 564-4628
21.1 hereby certify that the foregoing is truce and correct to the best of my knowledge
Signed . . ~.~,,_.. --.,.,.7, ~'~ ~
Dan Stone Title Engineering Supervisor Date
I
Commission Use Only
Perm(:~ N~m_b,~. I APl Number I Approval Date...~ I See cover letter
'~ "~ 50-029-20609-01 //--~ -- ~'~' for other requirements
Conditions of Approval: Samples Required []Yes ~No Mud Log Required []Yes [~No
Hydrogen Sulfide Measures ii, Yes [] No Directional Survey Required II, Yes [] No
Required Working Pressure for DOPE []2K; []3K; []4K; ~hK; [] 10K; [] 15K
Other:
by order of
Approved By Ul'l~i~ai 5igi'i~.0 d~' Commissioner the commission Date//"-~
Form 10-401 Rev. 12-01-85 David W. Johnston
Submit In Triplicate
[Well Name: [R-09A
HST Sidetrack Summary
[Type of Well: IPr°ducer I
Surface Location: 774' FSL, 3666' FEL, S32, T12N, R13E, UM
Target Location: 3292' FSL, 4610' FEL, S32, T12N, R13E, UM
Bottom Hole Location: 4516' FSL, 1809' FEL, S31, T12N, R13E, UM
I AFE Number: 14Pl185
I Rig: I Nabors 2ES
I Operating days to complete:
I TVD: 18840ss I I I~glev.
Extended Horizontal Sidetrack
}Estimated Start Date: I 11/24/98
]MD: [ 13071'
[Well Design:
]23
151'
Objective:
The new sidetrack will re-establish Zone 4 offtake that has been lost due to a sus-
pected casing leak in the existing R-09 well. It will also expand Zone 4 line drive
production with an undulating horizontal well design. The well will be returned to
full mechanical integrity.
Formation Markers
Formation Tops
TSag
Kick Off Point
9088'
9080'
TVD (ss)
8661'
8653'
TSHU 9137' 8704'
TSAD 9247' 8789'
TD 13071 8840'
Zone 3 NR 8920'
Directional
I KOP: 19,080' MD I
Maximum Hole Angle:
Rig Move Close Approaches:
Drilling Close Approaches:
100° maximum, 27° at KOP
R-36 will be 16' from R-9 and will be
shut in during the rig move. R40 will be
54' from R9 but will not be on stream at
the time of the rig move
None
Casing/Tubing ?rogram
Hole Size Tubular Wt/Ft Grade '- ConnT Le~ngth Top Btm
O.D. MD/TVDss MD/TVDss
6" 4-1/2" 12.6# L80 IBT 4141' 8930'/8521' 13071'/8840'
Production Tubing
NA I 4-1/2" 12.6# L80 IBT 8930' surf/surf 8930'/8521'
Mud Program
Milling Interval: 6% Quickdiln
Density, ppg I Funnel Vis, secI LSRV I pH API FL, cc
8.7-8.8+ I 50 - 65 45,000 - 65000 8.5 - 9.0 NC
Hazards/Concerns I Maintain viscosity at 50 - 65 to insure adequate removal of metal cuttings.
I
Ensure adequate preparation to eliminate metal entering motor and MWD from mud
bypassing solids control equipment.
Production (6" hole) Section: 6% Quickdriln (viscosified SW)
Density, ppg I Funnel Vis, sec[ LSRV I pH I API FL, cc
8.7 - 8.8+ I 50 - 65 45,000 - 65000 8.5 - 9.0 NC
Hazards/Concerns Potential high torque could require lubricant use. If so, employ Lubetex. Be alert for
lost circulation, differential sticking due to overbalanced MW (approx 600 psi differ-
ential.) Maximize solids control to keep fluid as clean as possible. Max mud weight
8.8+ ppg.
Cement Calculations
Lead Cement Tail Cement
Casing/Liner Sk / Wt / Yield Sk / Wt / Yield Comments
4-1/2" N/A N/A - 4-1/2" slotted liner, un-cemented, to be run
Open Hole Logs:
6" Hole
Logging Program
IMWD Dir/GR/Res
No open hole logs unless MWD resistivity unavailable or unusable
None
Cased Hole Logs:
Well Control
Well control equipment consisting of 5000 psi w.p. pipe rams, blind rams, and annular preventer will be
installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and mud fluid
system schematics on file with AOGCC. Bottom hole pressure is expected to be 3400psi @ 8790'
TVDSS. Maximum expected surface pressure is 2520 psi (assuming gas column of 0.1psi/ft)
Hazards
The main production target for this well is Zone 4. Although no faults have been identified faults at R
pad'tend to be cemented up with pyrite. Therefore lost circulation is not expected to be a problem.
However preparations should be made to pump LCM if necessary. No potential close approaches have
been identified while drilling this well. Risk of differential sticking is low based on offset wells and is
mitigated by the use of the Quikdriln drilling fluid which is solids free and does not form a filter cake.
Sag River
The pad data sheet indicates that only one well (R-36i) has experienced major lost circulation in this
production interval, most other wells taking only minor losses. More recently losses were experienced
on R-40 with a 10.8ppg mud weight. This time the SAG will be drilled with an 8.8 ppg maximum.
Ivishak
Differential sticking has occurred frequently on older wells in the Ivishak at +/-9183' TVD. Once the
sticking occurs it is very strong and has created difficulty in freeing up the drillstring. On R-35A, the
sticking was successfully alleviated by pumping a 20bbl pill of Liquid Casing, OM Seal, and Barafibre
and reducing pump rate to 5bpm (to reduce ECD). Note however that these wells were drilled using
LSND mud; since this well will employ solids free Quikdriln, this should mitigate the risk of sticking.
High torque has been reported on several older wells in the production hole, hence some open hole lu-
brication may be required. The pad data sheet incorporates wells from R, F and J pad as the bottom hole
location of these wells are all in the same area. Wells from all three pads have experienced problems
with bridges, tight hole, differential sticking, and packing off while in the production interval. This has
caused numerous incidents of stuck logs, casing, and drillstring. This is a high potential stuck pipe area -
be alert while drilling this interval and employ frequent reaming if any sign of unstable hole is seen.
Note however, that recent R-pad wells have not experienced any trouble from sticking and it is expected
that this well will be drilled without a significant sticking problem.
Disposal
All cuttings should be hauled to the ball mill at CC-2A for disposal. Haul all drilling and completion
fluids and other Class II wastes to CC-2A for injection. Haul all Class I wastes to Pad 3 for disposal.
Pre-Rig Work:
NOTE: If any problems with the 9-5/8" packoff are observed during pre-rig work, contact the wellhead
manufacturer to initiate repairs and inform the Operations Drilling Engineer.
1. Test 9-5/8" packoff and tubing hanger packoff to 5,000psi if not recently tested (<1 month). Func-
tion lock down screws
,
R/U wireline and retrieve GLV's if necessary. RIH and attempt to retrieve AVA Model DWP tubing
patch from tubing at +_8262' with wireline retrieving tool. If tubing patch cannot be successfully re-
trieved skip to step 4.
3. RIH and retrieve 2-7/8 ....X" plug and reducing nipple at +_ 8568'.
,
R/U 1.75" coiled tubing unit. RIH and spot a balanced cement plug from 9315' to ,-, 8980'. A failed
IBP is stuck at the bottom perfs @ 9315'(last ELM 7/97) so care should be taken. Attempt to
squeeze 5bbls of cement to perforations before RIH to 9130' and circulate out excess cement with
contaminant to obtain the required TOC. Highest acceptable TOC is 9130' in order to leave room to
set whipstock at required depth for kick-off. Circulate the well bottoms up to clean seawater prior to
POOH. RD coiled tubing. Let the plug set up, then tag with slickline.
Note: A positive pressure test on the cement plug should not be attempted to avoid the potential of
breaking down the cement in the squeezed perforations above the top of cement. Request weight
test requirement only from the AOGCC.
1. R/U Wireline and RIH and cut tubing in pup joint above seal assembly at 8508'. If tubing patch was
not removed make cut in pup joint below gas lift mandrel 1 at 8247' (above tubing patch at 8262').
,
Circulate seawater through cut/holes in tubing until clean returns are obtained. Freeze protect tub-
ing and annulus to 2,200ft with diesel. Bleed pressures on tubing/annulus. Zero psi on all annuli re-
quired, ensure annulus and tubing levels are static (possible leak in casing).
3. Set and test BPV. Remove wellhouse and flowlines, level pad, dig out cellar.
Rig Work:
o
Prior to rig move confirm 9-5/8" packoff and tubing hanger packoff test results from PE group. If
any problems with the packoffs or Iockdown screws are identified, contact the wellhead manu-
facturer to initiate repairs.
2. MIRU. Circulate the well to clean seawater. Pull BPV and ensure well stands full of fluid.
Set/test TWCV. N/D tree, N/U and test BOPs rams to 5000 psi, annular to 3500 psi. Pull TWCV.
3. Pull tubing hanger, make repairs to wellhead if required with tubing hung off on storm packer.
Pull existing 4-1/2" completion.
.
RIH with fishing assembly and retrieve overshot, initially pinned to 80 Klbs. There is no record of
the overshot/SBR having been sheared but it may well have sheared during a frac job in 1990.
RIH and retrieve K-anchor latch assembly with 18 right hand turns.
4
5. RIH with milling assembly and mill up the packer. Retrieve the packer and the remainder of the
existing 4-1/2" completion.
,
RIH with 7" RTTS and scraper on drillpipe spaced out to scrape 7" liner to 9,110' (to scrape
across EZSV setting depth) with RTTS to set at 8,900'. Set RTTS at 8,900' (just below comple-
tion packer setting depth) and test the 7" casing and 7" x 9-5/8" liner lap to 3000psi. Confirm
TOC and adequate room required for setting EZSV. If casing is leaking reset RTTS just below 7"
TOL. Pressure test to confirm leak is in 13-3/8" casing or TOL.
Note: If casing is leaking RIH with 9-5/8" RTTS and establish depth of leak. If leak is witihin 100'
of 7" liner top, and at an acceptable rate, then consideration will be given to moving the produc-
tion packer above the leak in the final completion. Otherwise make dual polish mill run for 7" liner
top PBR. Run tie-back liner to cover leak with a stab in seal assembly. Test 9-5/8" casing, 7"
tieback liner top packer and stab in seal assembly to 3000 psi against cemented perfs. If test is
unsuccessful RIH with 7" RTTS and set at 8590' and repeat pressure test.
.
R/U wireline unit. Set EZSV at _+ 9100' (placed for window kick off at 9092'). R/D electric line unit.
RIH with bottom trip whipstock and set on EZSV. Shear off and mill window in 7" 9080 - 9092'.
POOH.
8. RIH with 6" drilling assembly with 4 phase resistivity LWD and tag TD of new hole. Displace well
to drilling fluid, and drill section to TD of 13071' as per directional plan.
9. M/U and run 4000' of 4-1/2" slotted L80 IBT liner to 13071' and set liner hanger at _+ 8930'
(contingency for solid cemented liner depending on MWD results).
10.
R/U and run 4-1/2" L80 completion with 7"x4-1/2" production packer set at _+8880', 6 x 4-1/2"
GLM's, and standard WOA tailpipe stabbed into 4-1/2" liner top. Circulate freeze protection to
Jr- '
_2,200 MD. Land completion and set packer.
11. Set and test BPV, ND BOP, NU tree. RDMO.
The N2ES Rig Supervisors can be reached at 659-4835. I may be reached at 564-5738 (office), or
275-6592 (pager).
TREE: 4"CIW R 139 KB. ELEV = 50.30'
WELLHEAD: FMC ~ BF. ELEV = 21.20'
ACTUATOR: AXELSON
SSSV LANDING NIPPLE
13-3/8", 72 #/ft, ~ (0AMCO)(3.813" ID)
L-80, BTRS DV 2584'-- ~
L26-7- ~ k GAS LIFT MANDRELS
f MERLA w/RA LATCH)
N9 MD(BKB) TVDss DEV
4-1/2", 12.6#/ft, L-80, BTRS TUBING 4 3320' 3270' 0o
TUBING ID: 3.958 ....
3 5892' 5730' 22°
CAPACITY: .01522 BBL/FT ] 2 8134' 7813' 27°
I
1 8237' 7905' 27°
4 1/2"x 19' DWP, AVA @ 8262' ~
Tubing Patch (ID - 2.441")
See Wellfile for Details
I I SLIDINGSLEEVE
I
OTIS "XA" ,
84-~'
I
( 3.813 "MIN. ID)
~ L TUBING SEAL ASSY I, 8513'
-- 9-5/8" TIW PACKER
RR~_cI'
r (HBBP) ( 4.0 "ID)
4 1/2", 12.6 #/ft, L-80 TAILPIPE
TOPOF [ i ]~ ~ i "X" NIPPLE ( 3.813 " ID) ~
7" LINER R-_~7/1~ ~ ~ 2 7/8" Reducing Nipple
(2.313" ID)
4 1/2" TBG TAIL
9-5/8",
47#/ft,
I
I
L-80, BTRS I _ClO7R' I ~ ' (JET-CUT) (3.958" ID)
- - ELMD
pERFORATION SUMMARY MARKER JOINT
REF LOG: SWS- BHCS - 7-24-
~;IZE SPF INTERVAL OPEN/SQZ'D
3 1/8 4 9092- 9134' SQZD/9-10-88
" 8 9230 - 9286 .....
" 8 9298 - 9330 ....
3 3/8' 6 9092 - 9134' OPEN/12-17o8E
" 4 9230 - 9286' OPEN/12-20-8~
" 4 9250- 9270' OPEN/9-11-90
" 4 9298- 9310' OPEN/12-20-8E
" I 9310- 9320' OPEN/12-20-8E ~ FISH · IBP, W/FN AT 9345' CTM.
ATTEMPTED TO FISH 6/29/91, NO
SUCCESS.
: -- FISH · TOP AT 9652' CORR WLM
41' LONG CUT-OFF TBG TAIL
AND
I
I
PBTD
, 9806' I 'ii;:i?::::;i;:i:;::'~:iiii::i:?,:il;i ,Bp. TBG TAIL CUT OFF ON 9-
· l 9906' I""'::":'":'::'"' ::":"~"::'::': 13-89 WITH IBP WEDGED IN IT
7",
29
#/ft,
L-80,
BTRS AND THEN PUSHED DOWNHOLE.
DATE REV. BY COMMENTS PRUDHOE BAY UNIT
7-27-81 INITIAL COMPLETION WELL: R-09 (22-32-12-13~
11-30-88 RWO APl NO: 50-029-20609
9-13-9o A. TEEL PUT ON MAC SEC 32 ' TN 12N: RGE 13E!
6-14-94 HUGHES REVISED, TO INCLUDE IBP FISH INFO
3/24/97 SRB Reduction Nipple/Tubing Patch BP Exploration (Alaska)
TREE: 4" Cameron
WTELLHEAD: FMC
EHST(Proposed
NOTE: THIS WELL WILL CONTAIN
AN X NIPPLE AT 2000' NOT AN
SSSV IN COMPLIANCE WITH
RECENT BP SSSV MANAGEMENT
IMPLEMENTATION PLAN
FCC
NABORS 2ES
KB. ELEV = 51'
BF. ELEV = 21.2'
6.8PPG DIESEL FREEZE
PROTECTION AT +/- 2200' MD
13 3/8", 72#/ft,
L-80, BTRS @ 2670'
Gas Lift Mandrels
4-1/2", 12.6#/ft, L-80 IBT
TUBING ID: 3.958"
CAPACITY: 0.0152 BBL/FT
8.5PPG SEAWATER
7" LINER TOP @
9 5/8", 47#/ft,
L-80, BTRS @ 9075'
4 1/2", 12.6#/ft, L-80 TAILPIPE
WOA CONFIGURATION X/X/XN
WHIPSTOCK SET ON CEMENT
RETAINER @ 9100'
(FOR WINDOW 9080' - 9092 ')
CEMENT RETAINER @ - 9100'
TOC (pre rig - 9130')
7" X 4-1/2" PRODUCTION
PACKER @ +/-8880'
4 1/2" WLEG STABBED INTO
LINER TOP
7"X 4-1/2" LINER HANGER@ 8930'
4 1/2", 12,6#/ft, L-80 IBT
SLOTTE LINER
Top perf 9092'
Bottom perf 9320'
6" TD @ 1307
---_~FISH @ 9345,
Failed IBP
PBTD @ 9806
@ 9652, 41'
long tubg tail
DATE
10-19-98
TD @ 9906' 7", 29#, L-80 IJ4$
-- _
REV BY COMMENTS
' , ,,, - PRUDHOE BAY UNIT
PAS ! Proposed Status WELL: R-09A
I! APl NO: 50-029-20609-01
.
Anadrill Schlu~%berger
Alaska District
1111 East 80th Avenue
Anchorage, AK 99518
(907) 349-4511 Fax 344-2160
DIRECTIONAL WELL PLAN for SHARED SERVICES DRILLING
Well ......... : R-09A (P1)
Field ........ : Prudhoe Bay, R-Pad
Compu=ation..: Minimum Curvature
Units ........ : FEET
Surface Lat..: 70.34875551 N
Surface Long.: 148.90202551 W
Legal Description
Surface ...... : 774 FSL 3666 FEL
Tie-in sur~;ey: 2553 FSL 3838 FEL
Target ....... : 3292 FSL 4610 FEL
BHL .......... : 4516 FSL 1809 FEL
LOCATIONS - ALASKA Zone: 4
X-Coord Y-Coord
S32 T12N R13E UM 635262.87 5977254.80
S32 T12N R13E b74 635052..14 5979030.41
S32 T12N R13E b74 634265.00 5979755.00
S31 T12N R13E UM 631760.00 5980935.00
PROPOSED WELL PROFILE
Prepared ..... : 06 Aug 1998
Vert sect az.: 300.60
KB elevation.: 53.10 ft
Magnetic Dcln: +27.757 (E)
Scale Factor.: 0.99992078
Convergence..: +1.03402023
FOR STUDY'ON'LY
mmmmmmmmmmmmmtmmmmmm mmlm{{mm mmmmmm
STATION MEASURED INCLN
IDEN~TIFIC~TION DEPTH ANGLE
TlR-IN SURVR¥ 9002.80 26.73
TOP WHIPSTOCK 9080.00 26.65
TOP SAG 9088.61 27.68
BASE WHIPSTOCK 9092.00 28.10
KOP CURVE 26/100 9122.00 28.10
m~mmmmmmm mmmml~mmm~mmmmm
DIRECTION VERTICAL-DEPTHS
AZIMUTH TVD SUB-SEA
8.80 8637.47 8584.37
9.57 8706.44 8653.34
7.39 8714.10 8661.00
6.57 8717.10 8664.00
6.57 8743.56 8690.46
mmmmmmmm
DEPART
1059.46
1072.12
1673.60
1074.24
1079.99
mmmmmmmmmmmmmmmmmmmmm mmmmmmm~mmmmmm#mmmmm
COORDINATES-FROM ALASKA Zone 4
\
WELLHEAD X Y
1779.27 N 178.66 W 635052.14 5979030.41
1813.50 N 173.13 W 63505?.06 5979064.7~
1817.38 N 172.55 W 63~057.57 ~979068.6~
1818.96 N 172.36 W 635057.73 ~979070.21
1833.00 N 170.74 W 635059.09 597908'4.27
TOP SHI/BLIK
9137..~1- 30.33
9140.00 30;72
9160.00 34.11
9180.00 37.86
9200.00 41.88
9220.00 46.10
(Anadrill (c)98 R09AP1 3.2C 4:36 PM P)
359.68 8757.10 8704.00 1083.49
358.66 8759.25 8706.15 1084.15
351.~8 8776.13 8723.03 1090.41
34'5.15 8792.32 8739.22 1098.34
340.00 8807.67 8754.57 1107.88
335.62 8822.06 8768.96 1118.95
185~.47~ 1~1.33
1863.95 N 173.?6
1889.01 N 182.88
R-09A (P1) 06 Aug 1998 Page 2
STATION
IDENTI FI C..~T I ON
90 DEG BASE
END 26/100 CURVE
CURVE 10/100
END 10/100 CURVE
START CURVE 3.72/100
TOP ZONE 4
PROPOSED WELL PROFILE
MEASURED INCLN DIRECTION
DEPTH ANGLE AZIMUTH
9240.00 50.46 331.82
9260.00 54.93 328.48
9280.00 59.49 325.49
9300.00 64.10 322.77
9320.00 68.76 320.26
9340.00 73.46
9360.00 78.18
9380.00 82.92
9400.00 87.67
9409.80 90.00
9420.00 92.42
9425.88 93.82
10068.14 93.82
10100.00 93.13
10200.00 90.93
10241.73 90.00
10241.73 90.00
10241.73 90.00
10300.00 87.83
10400.00 84.12
10500.00 80.40
10519.76 79.67
10600.00 82.65
10700.00 86.37
10797.80 90.00
10800.00 90.08
10900.00 93.80
11000.00 97.51
(Anadrill (c)98 R09AP1 3.2C 4:36 PM P)
VERTICAL-DEPTHS
TVD SUB-SEA
SECTION
DEPART
1131.45
1145.29
1160.35
1176.50
1193.62
8835.37 8782.27
8847.49 8794.39
8858.32 8805.22
8867.77 8814.67
8875.77 8822.67
m~{mmmmmmmmmmmmmmmmmm
COORDINATES-FROM
WELLHEAD
mmmmmmm
1902.38 N
1916.16 N
1930.25 N
1944.52 N
1958.86 N
mmmmmmmmmmmmmmmmmmmm
ALASKA Zone 4'
x y
189.50 W 635039.09 ~9791~3.30
197.42 W 63~030.92 ~979166.94
206.~9 W 636021.S0 ~979180.8~
216.92 W 63~010.91 ~979194.93
228.33 W 634999.2~ ~979209.07
317.90 8882.24 8829.14 1211.57 1973.15 N 240.72 W
315.65 8887.14 8834.04 1230.18 1987.27 N 254.00 W
313.'49 8890.42 8837.32 1249.32 2001.11'N 268.05 W'
311.36 8892.06 8838.96 1268.83 2014.55 N 282.76 W
310.33 8892.26 8839.16 1278.46 2020.96 N 290.17 ~
1288.53
1294.34
1928.89
1960.49
2060.30
309.25
308.63
308.63
305.51
295.75
8892.04 8838.94
8891.72 8838.62
8848.93 8795.83
8846.99 8793.89
8843.44 8790.34
2027.48 N
2031.17 N
2431.21 N
2450.38 N
2S01.22 N
298..01 W
302.~? W '
8.03.21 W
828.58 W
914.47 W
291.68 8843.10 8790.00 2101.71 2518~00 N 9~2.66
291.68 8843.10 8790.00 2101.71 2518.00 N 952.66
291.68 8843.10 8790.00 2101.71 2518.00 N 9~2.66
291.68 8844.20 8791.10 2159.27 2539.52 N 1006.80
291.68 8851.22 8798.12 2257.80 2576.37 N 1099.48
mmmm mmmm
TOOL DL/
~c~ lOO
32L 26.00
~0L 26.00
28L 26.00
27L 26.00
26L 26.00
291.68 8864.68 8811.58 2355.67
291.68 8868.10 8815.00 2374.90
291.6'8, 8880.43 8827.33 2453.22
291.68 8890.00 8836.90 2551.54
291.68 8893.10 8840.00 2648.09
2612.97 N 1191.55 W
2620.16 N 1209.63 W
2649.45 N 1283.30 W
2686.22 N 1375.78 W
2722.32 N 1466.60 W
291i. 68 8893.10 8840.00 2650.27
291.68. 8889.71 8836.61 2748.98
291.68 '8879.86 8826.76 2847.28
634986.60 5979223.13 2~L 26.00
634973.07 5979237.01 24L 26.00
634958.77 59792~0.~9 24L 26.00
634943.82'5979263.76 24L 26.00
634936,30 ~979270.03 24L 26.00
.
634928.35 $9~9276'.42 24L 26.00
634923:72 S979280.02 HS 26.00
63441~.9'8 ~979670.93 102L 0.00
..
634390.27'~979689.6~ 103L 10.00
634303.49 ~9797~8.9~ 103L 10.00
634265.00 ~9797~.00 LS 10.00
63426~.00 ~9~97~S~00 L~ 10.00
634265.00 S~9?SS.00 LS 10.00
634210.49 ~97977~.~4 LS 3.72
634117.16 ~979810.71 T~S 3.72
634024.46 597984~.64 LS 3.72
634006.2~ ~979872.~0 ~S 3.72
633932.07 6979880.4~ ~S 3.72
633838.9~ ~97991~.~4 ~S 3.72
633747.50 ~9799~0.00 H~ 3.72
2723.14 N 1468.65 W
2760.05 N 1561.~0 W
2796.81 N 16~3.96 W
633745.'44 5979950.78 HS 3.72
633651.94 5979986.'01 HS 3.72
633558.8'4 ~980021,09 HS 3.72
FOR'STUDY'ONLY
..
R-09A (P1)
PROPOSED WELL PROFILE
06 Aug 1998
Page 3
STATION
IDENTIFIC_~.TION
END 3.72/100 CURVE
MEASURED INCLN
DEPTH ANGLE
11075.84 100.33
11100.00 99.43
11200.00 95.72
11300.00 92.00
11353.87 90.00
11400.00 88.29
11500.00 84,57
11600.00 80,85
11631.91 79,67
11700.00 82,20
11800.00 85.91
11900.00 89.63
11909.94 90.00
~2000.00 93,35
12100.00 97.06
12187.98 100.33
12200.00 99.88
12300.00 96.17
12400.00 92.45
12466.02 90.00
12500.00 89.40
12600.00 87.65
12700.00 85.94
12800.00 84.30
12900.,0D, 82,78
I
END 8/10d iCURVE 12906.43 82.68
CURVE 8/~00 13071,67 82.68
TD 13071.67 82.68
(Anadrill (c)98 R09AP1 3.2C 4:36 PM P)
DIRECTION VERTICAL-DEPTHS
AZIMUTH TVD SUB-SEA
291.68 8868.10 8815,00
291.68 8863.95 8810.85
291.68 8850.77 8797.67
291.68 8844.04 8790,94
291,68 8843.10 8790,00
~m~mmmmm
SECTION
DEPART
2921.28
2944.80
3042.71
3141,26
3194,47
291.68 8843.79 8790.69 3240.04
291.68 8850.02 8796.92 3338.62
291,68 8862.70 8809,60 3436,59
291,68 8868,10 8815,00 3467,66
291,68 8878.83 8825,73 3534,08
291.68 8889.18 8836.08 3632.33
291,68 8893.07 8839.97 3731.03
291,68 8893.10 8840.00 3740,85
291.68 8890.47 8837.37 3829,77
291.68 8881.40 8828.30 3928.13
291,68 8868.10 8815,00
291,68 8865,9.9 8812,89
291.68 8852,03 8798.93
291.68 8844.51 8~91,41
291.68 8843,10 8790.00
4014.04
402~.73
4123.S4
4222.03
4287.23
m{m{mmmmmmmmmmmmmmmmm
COORDINATES-FROM
WELLHEAD
=mm=~m~m ~m~m~mm~
2824.49 N 1723.57
2833.28 N 1745.69
2869,90 N 1837,79
2906.75 N 1930.49
mmmmmmmmmmm~mmmmmmmm
ALASKA Zone 4
Y
633488,75 $980047,~0
633466,47 59800~,89
633373,74 ~980090,84
633280,40 ~980126,01
2926,65 N 1980,54 W 633230,00 ~98014~,00
2943,69.N 2023,40 W
2980,55 N 2116,13 W
3017.19 N 2208,28 W
3028,81 N 2237,~1 W
3053,65 N 2299,99 W
63318'6.84 5980161,26
633093.4? 5980196,45'
633000.68 5980231,%1
632971,25 5980242,50
632908,34 ~980266,21
3090,39 N 2392,40 W 632815,29 ~980301,27
3127,30 N 2485,24 W 632721,80 5980336,49
3130,97 N 2494,48 W 632712,50 59.80340,00
3164,22 N 2578,11 W 632628,28 ~980371,73
3201,01 N 2670,64 W 632~3~,12 ~980406,84
3233.13 N 27S1.44
3237.51 N 2762.44
3274.08 N 2854.44
3310.91 N 2947.09
3335.30 N 3008.41
294.33 8843,28 8790.18 4320,91 3348.58 N 3039,69 W
302.14 8845.86 8792.76 4420.71 3395.83 N 3127,69 W
309,'9:7', 8851.46 8798.36 4520.02 3454.54 N 3208.35 W
317,83 8859.98 8806.88 4616.91 3523.57 N 3280.09 W
325.73 8871,24 8818.14 4709.49 3601.56 N 3341.52 W
326.24 8872.06 8818.96 4715.25 3606.85 N 334S,09 W
32~,24 8893.10 8840.00 4863.00 3743,11 N 3436,16 W
326.24 8893.10 8840.00 4863.00 3743,11 N 3436.16 W
632453.75 59804371'.50
632442,68 5980441,67
632350.04 ~9'80476.S8
632256.75 S980511.73
632195,00 5980~35,00
632163,49 5980547,71
632074,66 ~980593,37
631992,96 ~980650,61
631920,00 ~980718,32
631857,17 ~98079~,19
631853.51.5980800,42
631760,00 5980935,00
631760.00 5980935,00
mmmm mmmm
~oo~ ~/
FACE 100
LS 3,72
LS 3,72
LS 3.72
LS 3,72
LS 3,72
LS 3,72
LS 3,72
LS 3,72
HS 3,72
HS 3,72
HS 3.72
HS 3,72
HS, 3.72
HS 3,72
~S 3.72
.'LS 3,72
LS 3,72
LS 3.72
LS 3,72
103R 3.72
103R 8.00
103R 8,00
102R 8,00
101R 8.00
101R 8,00
8.00
0,00
0,00
I VERTICAL SECTION VIEW
soo-- ISection at: 300.60 '
. IlVD Scale.: ! inch = 1000 feet
· ,~,,-~, IOep Scale.: I -inch _. JO00 feet
;0o- - ~UfllbSp.,,O~p.
Marker IdentifiCation ' ND BKB .SECIN INCLN
00--- A! lIE-IN l~tE¥ §003 8637 t05§ 26.73
81 TOP HHIPSTOCK 9080 8706 1072 26.65
C) BASE ltltlPSTOCK 9092 8717 1074 28. lO
[~0-- fl] KOP 011:i~ 26/100: 9122 [t744 t080
El 90 OEG 8ASE 9410 8892 't278 90.00
' Fi END 26/100 CURVE 9426 -8892 i294 93.82
.
G! CUFI~ ~0/t00 . 10068 -8849 t929 [13.82
~0-- HI -£ND t0/100 0IF!¥£ ~0242 fl84~ ~t02 §0.00
~ I} SII~I' QIR¥£ 3.72/t00 10242 884~ 2t02 §0.00
J) .END 3.72/t00 CURVE 12466 '8843 4287 90.00
}0-- K} END 8/100 OJRVE 12§06 13872 4715 82.61t
L) CURVE 8/t00 13072 8893 4863 82.68
Iq) ID 13072 8893 4863 82.68
%
%
%
:_
%
%
%
%
%
%
_.~.~, ~_~.~c: __ ~_~~ ~ ~ ..... ~
0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500
Sect ion Departure
.... -SHAR 'D SERvicES' DRI'LL [NG .......
.4nadr.i]] Sch]umberger
R-O9A (Pi)
VERTICAL SECTION ViEW
Section at: 300 60
,, IDep Sca]e.: ~_ ~.nch = 500 feet
- ~ , · Marker Identif~catton , MD BKB SECIN INCLI
~ A) TIE-IN SURVEY 9003 8637 2'059 26.7',
~ B) TOP I~HIPSTOCK '9080 8706 . ~072 26.6!
~ C} BASE ~HIPSTOCK 90g~ 87{7 1074 28.t,
'~ .............. D) KOP CURVE 26/100 9t~2 8744 1080 28.t
E)'90 OEO BAS~ g410 , 8892 t~78 90.0
~ j. . F) END ~$/100 CURVE ",g4~6 ,8892 1~94 93.8
' ...... ~Jr~~ .. G) CURVE ,0/~00 ,0068 8849 J929 93.8
~ ~' H) END 10/t00 CURVE. t0~4~ 884~ ~10~ 90.0
t I) START CURVE 3.72/t00' I02~2 8B43 2102 90.0
' ;":::' 0/~ ~ J) END 3.72/100 CURVE '12466 8843 4287 90.0
~ ...... ~ ~:.:.:.:~'. K) ENO 81100 CURVE ~2906 887~ 4715 82.~
~ ':'":~'~:.:::., .:" .. L) CURVE 8/100 13072 8893 4863 82. ~
.......... :~,': ::;.~ ;;~ , ......
,,~, :L ~' ':' "-
) ....... ~ ..... : ............... Cd '" ; "' ' "" , .......... "*-
, .............
"'g~'j; ~:.' . .....
......
,; ...... , ,:;.
) ~ ............ , ....... ~¢?, , ....... ,, ~ ......................
~ %'h' ' '
........ .' . ,., ~ ................................................
).. , ~ .........................
5o0 750 '~000 ~.250 ~,500 ~.750 2000 2250 2500 2750 3000 3250 3500 3750 ,~000 42~50'. 4500 4750 5000
Section Departure "
(d98 ROgAPI 3.2C 4:41 i°N P)
SHARE 3 .SERVZ.CES-DRT_LLI'NG
Marker Idenl i f 1cation MO N/S E/H
A) TIE'~IN SURVEY 9003 1779 N 179 ~ ~
m ToP w.I~STOCK ~o~o m~3 N' ~3
C) BASE WHIPSTOCK 9092 ~8~9 N ~72 ~
KOP CURVE 26/,00 9122 ,833.N ,7,
R-09A -(PC)
PLAN VZEH
6LOSURE .... - 508! fee[ a[ Azimuth 3~7.45
DECLINATION ' +27.757 (E]
SCALE · I inCh .= 800 feet
DRAWN ...... - 06 Aug tgg8
'/' Anadr i ] ] :Sch]umberger
,200 4800 4400 4000 3600 3200 2800 2
2800
- 1600
~ - 1200
400
<- WEST ' EAST ->
_ ~59'14"
/
/
/
/
/
t
NOTES /
1. DATE OF SURVI~Y: SEPTEMBER 6. 1994.
2. REFERENCE FIELD BOOK: WOA 94-03
(pgs. 26 THRU 32).
.3. ALASKA STATE PLANE COORDINATES SHOWN
ARE ZONE 4, ALASKA, NAD 27.
4. PAD SCALE FACTOR IS 0.9999209.
5. HORIZONTAL CONTROL IS BASED ON
R PAD MONUMENTS R-1 AND R-2.
6. ELEVATIONS ARE BP MEAN SEA LEVEL.
· 30
~4
· ,32
~5
LEGEND
AS-BUILT WELLS
EXISTING WELLS
LOCATED WITHIN PROTRACTED SEC. .32, T. 12 N., R. 13 E., U.M., AK.
WELl' ' A.S.P. PEANT GEODETIC CELLAR SECTION
NO. COORDINATES COORDINATES POSITION BOX ELEV. OFFSETS
Y= 5,9.77,262.67 N. 1742.92 70'20'44.791" 782' FSL
,36 X=. ..6`35,298~93 E. 1999.40 148'54'06.2,34" 19.6' .3629' FEL
Y= 5,977,748.19 N. 1504.27 70'20'49.54-2" 1265' FSL
38 X= 635,431.84 E. 2442.66 148'54'02.095" 19.2' 3486' FEL
Y= 5,977,090.00 N. 2512.34 70'20'43.226" 623' FSL
39 X= 634r549.18 E. 1999.64 148'54'28.229" 19.6' 4382' FEL
9/8/94
DATE
ORIGINAL AS-BUILT ISSUE
REVISIONS
SURVEYOR'S CERTIFICATE
I HEREBY CERTIFY THAT I AM
PROPERLY REGISTERED AND LICENSED
TO PRACTICE LAND SURVEYING IN
THE STATE OF ALASKA AND THAT
THIS PLAT REPRESENTS A SURVEY
MADE BY ME OR UNDER MY DIRECT
SUPERVISION AND THAT ALL
DIMI-d",ISIONS AND OTHER DETAILS ARE
CORRECT AS OF SEPTEMBER 6, 1994-.
F. R. BELL & ASSOCIATES
..BP EXPLORATION
I R PAD
CONDUCTOR AS-BUILT
WELLS 56, 38 AND 59
t i SEPT, 9, ~gg~l BARNHART I ^~,soN ALLISON
i I~: I~c~' I'~' °~ ~'~ ':
]'8 RFA ~I: [~a ~, o~c ~ ] ~[~r: ]~v~:"
/°~*~ /cH~o~ ! I / ~*~*"' ~' I°
._hared
ervices
' rilling
WELL NAME
R-09A
DRILLING PERNHT/SUNDRY/PRE-RIG
COVER SHEET
IThe attached work cannot commence without obtaining the required signatures in I
the "APPROVAL TO PROCEED" section at the bottom of this cover sheet.
I
"APPROVAL TO PROCEED" will signify AOGCC approval has been received.
This cover sheet is applicable to: (only one category per cover sheet)
[~] DRILLING PERMIT
Permit Documentation Prepared:
~---] Permit Application Reviewed:
[~Permit.),,pp!icati99 Sufil~t.,ted:
TA:"~~. , .~~ ~-~ D ate:l~/~¢¢!
PRE-RIG WORK
Pre-Rig Memo Reviewed:
SDEfES: Date:
Pre-Rig Memo Sent to Slope:
ODE: Date:~
Pre-Rig Sundry Documentation Prepared:
ODE: Date:~
Pre-Rig Sundry Application Reviewed:
SDE/ES: Date:~
Pre-Rig Sundry Application Submitted:
TA: Date:~
SUNDRY NOTICE
D Sundry Documentation Prepared:
ODE: Date:
D Sundry Application Reviewed:
SDE/ES: Date:
D Sundry Application Submitted:
1 ¢i:N/X,L NO,,: Date:~
IF SUNDRY IS FOR PRE-RIG WORK, USE
PRE-RIG WORK SECTION AT BELOW LEFT
AND CHECK "ABANDON" BOX BELOW
Reason for Sundry (Check aH that apply)
Abandon
Alter Casing
Suspend
Repair Well
Plugging
Pull Tubing
Variance
Other(Explain):
Change Approved Program
Operation Shutdown
Re-enter Suspended Well
Time Extension
Perforate
Stirfiul~te~ ~-
Wellbore prep for sidetrack
.......,*., !G
I APPROVAL TO PROCEED
Approved AOGCC Permit/Sundry Received TA: Date:
Approval to Commence Operations SDE/ES: Date:
COMPANY I~ ? WELl_ NAME ~ ~ V~* l~9 ¢~ PROGRAM: exp [] dev J~redrll l~l serv [] wellbore seg II ann. disposal para req II
· WELL PERMIT CHECKLIST
FIELD & POOL
ADMINISTRATION
A~ DATE ...
INIT CLASS ~ ~: U (-I~ I L
1. Permit fee attached .......................
2, Lease number appropriate ...................
3. Unique well name and number ..................
4. Well Iocaled in a defined pool ..................
5. Well Iocaled proper dislance from drilling unit boundary ....
6. Well Iocaled proper distance from other wells ..........
7. Sufficient acreage available in drilling {mil ...........
8. If deviated, is wellbore plat included ...............
9. Operator only affected party ...................
10. Operator has appropriate bond in force .............
11. Permit can be issued wilhout conservation order ........
12. Permit can be issued without administrative approval ......
13. Can permit be approved before 15-day wait ...........
ENGINEERING 14.
15.
16,
17.
18.
19.
20.
21.
22.
23.
24.
25,
DA'rE 26.
28.'
29.
GEOLOGY
30.
31.
32.
33.
34.
Conduclor string provided ...................
Surface casing protects all known USDWs ...........
CMl' vol adequate to circulate on conductor & surf csg .....
CM I' vol adequate to tie-in long string to surf csg ........
CMl will cover all known productive horizons ..........
Casing designs adequate for C, T, B & permafrost .......
Adequate tankage or reserve pit .................
If a' re-drill, has a 10-403 for abandonment been approved...
Adequate wellbore separation proposed .............
If diveder required, does it meet regulations ..........
Drilling fluid program schematic & equip list adequate .....
BOPEs, do they meet regulation ................
BOPE press rating appropriate; test to ~C) . psig.
Choke manifold complies w/APl RP-53 (May 84) ........
Work will OCCL, r without operation shutdown ...........
Is presence of H2S gas probable .................
Permit can be issued w/o hydrogen sulfide mea~-"
Data presented on potential overpre~ .......
Seismic analysis of shallow~s ..... ' ........
Seabed condO(if off-shore) .............
('~r'ess reports ....... ploratory only]
A~ DATE
ANNULAR DISPOSAL 35.
APPR IDAI"E
GEOL AREA '~ ~ ~ UNIT# I[ _~ )--~ ON/OFF SHORE 6~ z-t .........
(~N
C_~N
(~N
N
~)N
(~N
Y N ......
Y N
Y N ..............................................................................................................................................
With proper cementing records, this plan
(A) will contain waste iq,,a suitable receivin,9/[one; ....... Y N
(B) will not contaminate f~hwater; or~lse drilling waste... Y N
lo surface;
(C) will not impair mechanical i~he well used for disposal;
(D) will not damage produ~ formation orTll'n1~,~k.-.r~covery from a
pool; and
(.E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N
ENGINEERING: UIC/__~/ar COMMISSION:
BEW..~ t(/"~i~ ~ DWJ__
JDH --------'- ~ RNC
co
Y N
Comments/Instructions:
Mchel~hsl rev 05129198
rllf C \n~';()fh( i!\wl.diml\¢h;,rl;i\, I,!r Ih' I
Well HistorY File
APPENDIX
Information of detailed nature that is not
particularly germane to the Well Permitting Process-
but is part of the history file.
To improve the readability of the Well History file and to
simplify finding information, information of this
nature is accumulated at the end of the file under APPENDIX.
No special effort has been made to chronologically
organiZe this category of information.
* ALASKA COMPUTING CENTER *
. ............................ .
....... SCHLUMBERGER .......
COMPANY NAME : B.P. EXPLORATION
WELL NAME : R - 09A
FIELD NAME : PRUDHOE BAY
BOROUGH . NORTH SLOPE
STATE : ALASKA
API NUMBER : 50-029-20609-01
REFERENCE NO : 99095
RECF_IVED
APR 2 7 1999
O~ ~'G~s' Commissio~
* ALASKA COMPUTING CENTER *
....... SCHLUMBERGER .......
COMPANY NAME : B.P. EXPLORATION
WELL NAME : R-O9A
FIELD NAME : PRUDHOE BAY
BOROUGH : NORTH SLOPE
STATE : ALASKA
API ~ER : 50-029-20609-01
REFERENCE NO : 99095
LIS Tape Verifi~tion Listing
Schlumberger Alaska Computing Center
29-MAR-1999 11:03'~--~
PAGE:
**** REEL HEADER ****
SERVICE NAME : EDIT
DATE · 99/03/26
ORIGIN : FLIC
REEL NAME '. 99095
CONTINUATION #
PREVIOUS REEL
CON~IENT : BP EXPLORATION, R-OgA, PRUDHOE BAY, API #50-029-20609-01
**** TAPE HEADER ****
SERVICE NAME : EDIT
DATE : 99/03/26
ORIGIN : FLIC
TAPE NAME : 99095
CONTINUATION # : 1
PREVIOUS TAPE :
CO~ff4ENT · BP EXPLORATION, R-O9A, PRUDHOE BAY, API #50-029-20609-01
TAPE HEADER
PRUDHOE BAY
MWD LOGS
WELL NAME:
API NUMBER:
OPERATOR:
LOGGING COMPANY:
TAPE CREATION DATE:
JOB DATA
JOB NUMBER:
LOGGING ENGINEER:
OPERATOR WITNESS:
SURFACE LOCATION
SECTION:
BIT RUN1
99095
DANMEYER
WHIPP
TOWNSHIP:
RANGE:
FNL:
FSL:
FEL:
FWL :
ELEVATION (FT FROM MSL O)
KELLY BUSHING:
DERRICK FLOOR:
GROUND LEVEL:
WELL CASING RECORD
1ST STRING
2ND STRING
R-O9A
500292060901
B.P. EXPLORATION
SCHLO2VIBERGER WELL SERVICES
26-MAR-99
BIT RUN 2 BIT RUN 3
32
12N
13E
774
1614
49.27
47.87
21.20
OPEN HOLE CASING DRILLERS
BIT SIZE (IN) SIZE (IN) DEPTH (FT)
6. 000 9. 625 9075.0
LIS Tape Verifl-oL~ion Listing
Schlumberger Alaska Computing Center
29-MAR-1999 11:03
3RD STRING
PRODUCTION STRING
REMARKS:
Well drilled 31-DEC-98 through 7-JAN-99 with IMPULSE.
Data was collected in three bit runs. The second bit
run is memory data from 9300' - 9618' and real time
data from 9618' - 11907' due to tool failure.
$
$
PAGE:
**** FILE HEADER ****
FILE NAME : EDIT .001
SERVICE · FLIC
VERSION : O01CO1
DATE : 99/03/26
MAX REC SIZE : 1024
FILE TYPE : LO
LAST FILE :
FILE HEADER
FILE NUMBER: 1
EDITED MERGED MWD
Depth shifted and clipped curves; all bit runs merged.
DEPTH INCREMENT: O. 5000
FILE SUMMARY
LDWG TOOL CODE START DEPTH STOP DEPTH
MWD 9070.0 13125.0
$
BASELINE CURVE FOR SHIFTS: NONE
CURVE SHIFT DATA (MEASURED DEPTH)
BASELINE DEPTH
$
MERGED DATA SOURCE
LDWG TOOL CODE
$
REMARKS:
No depth adjustments were made to the data as per
Steve Jones via D. Douglas. The data from run two is
both memory and real time data due to tool failure.
$
.......... EQUIVALENT UNSHIFTED DEPTH ..........
BIT RUN NO. MERGE TOP MERGE BASE
1 9070.0 9356.0
2 9300.0 11907.0
3 11850.0 13125.0
LIS FORMAT DATA
LIS Tape Verif~ion Listing
Schlumberger Alaska Computing Center
29-MAR-1999 11: 03~ .... ·
PAGE:
** DATA FORMAT SPECIFICATION RECORD **
** SET TYPE- 64EB **
TYPE REPR CODE VALUE
1 66 0
2 66 0
3 73 48
4 66 255
5 66
6 73
7 65
8 68 0.5
9 65 FT
11 66 21
12 68
13 66 0
14 65 FT
15 66 68
16 66 1
0 66 0
* * SET TYPE - CHAN * *
NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS
ID ORDER # LOG TYPE CLASS MOD NTJM~ SAMP ELE~ CODE (HEX)
DEPT FT 4000307 O0 000 O0 0 1 1 1 4 68 0000000000
FET MWD HR 4000307 O0 000 O0 0 1 1 1 4 68 0000000000
ROP MWD FPHR 4000307 O0 000 O0 0 1 1 1 4 68 0000000000
GR MWD GAPI 4000307 O0 000 O0 0 1 1 1 4 68 0000000000
RPD MWD 0H~4~4000307 O0 000 O0 0 1 1 1 4 68 0000000000
RPM MWD 0H~4000307 O0 000 O0 0 1 1 1 4 68 0000000000
RPS MWD 0H~4~4000307 O0 000 O0 0 1 1 1 4 68 0000000000
RPX MWD 0H~I~4000307 O0 000 O0 0 1 1 1 4 68 0000000000
RPXXMWD Op2V~4 4000307 O0 000 O0 0 1 1 1 4 68 0000000000
RAD MWD OH~M4000307 O0 000 O0 0 1 1 1 4 68 0000000000
RAM MWD 0~4000307 O0 000 O0 0 1 1 1 4 68 0000000000
RAS MWD 0H~4000307 O0 000 O0 0 1 1 1 4 68 0000000000
** DATA **
DEPT. 9071.000 FET.MWD 1.144 ROP.MWD -999.250 GR.MWD
RPD.MWD -999.250 RPM. MWD -999.250 RPS.MWD -999.250 RPX.MWD
RPXX.MWD -999.250 RAD.MWD -999.250 RAM. MWD -999.250 RAS.MWD
48.840
-999.250
-999.250
LIS Tape Verifl.u~.~ion Listing
Schlumberger Alaska Computing Center
29-MAR-1999 11:03'--~-~i
PAGE:
DEPT. 10000.000 FET.MWD -999.250 ROP.MWD 72.760 GR.MWD
RPD.MWD 22.540 RPM. MWD -999.250 RPS.MWD 18.150 RPX.MWD
RPXX.MWD 13.590 RAD.MWD -999.250 RAM.MWD -999.250 RAS.MWD
DEPT. 11000.000 FET.MWD -999.250 ROP.MWD 66.330 GR.MWD
RPD.MWD 7.910 RPM. MWD -999.250 RPS.MWD 7.630 RPX.MWD
RPY~X.I~WD 7.360 RAD.MWD -999.250 RAM.MWD -999.250 RAS.f4WD
DEPT. 12000.000 FET.MWD
RPD.MWD 21.930 RPM. MWD
RPXX.MWD 14.700 ~.I~WD
DEPT. 13000.000 FET.MWD
RPD.MWD 36.770 RPM. MWD
RPXX.MWD 22.100 RAD.MWD
3.235 ROP.MWD
20. 640 RPS.MWD
22. 720 RAM. MWD
3.183 ROP.MWD
34.400 RPS.MWD
32.480 RAM. MWD
15.750
18.880
23.640
7.120
30.690
34.470
GR .~47WD
RPX.MWD
RAS.MWD
GR.MWD
RPX.MWD
RAS.MWD
DEPT. 13124.500 FET.MWD -999.250 ROP.MWD 29.900 CR.MWD
RPD.MWD -999.250 RPM. MWD -999.250 RPS.MWD -999.250 RPX.MWD
RPXX.MWD -999.250 RAD.I~WD -999.250 RAM. MWD -999.250 RAS.MWD
24.415
-999.250
-999.250
21.975
-999.250
-999.250
90. 410
16. 840
22.640
105. 170
26.310
31.370
-999.250
-999.250
-999.250
** END OF DATA **
**** FILE TRAILER ****
FILE NAME : EDIT .001
SERVICE : FLIC
VERSION : O01CO1
DATE : 99/03/26
MAX REC SIZE : 1024
FILE TYPE : LO
LAST FILE :
**** FILE HEADER ****
FILE NAME : EDIT .002
SERVICE · FLIC
VERSION · O01CO1
DATE : 99/03/26
MAX REC SIZE : 1024
FILE TYPE : LO
LAST FILE :
FILE HEADER
FILE NUMBER 2
RAW MWD
Curves and log header data for each bit run in separate files.
BIT RUN NUMBER: 1
DEPTH INCREMENT: O . 5000
FILE SUfff4ARY
LIS Tape Verifi'~_~ion Listing
Schlumberger Alaska Computing Center
29-MAR-1999 11:03~l
PAGE:
VENDOR TOOL CODE START DEPTH
MWD 9070.0
$
LOG HEADER DATA
DATE LOGGED:
SOFTWARE:
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY or REAL- TIME):
TD DRILLER (FT) :
TOP LOG INTERVAL (FT);
BOTTOM LOG INTERVAL (FT) :
BIT ROTATING SPEED (RPM) :
HOLE INCLINATION (DEG)
MINIMUM ANGLE:
MAXIMUM ANGLE:
STOP DEPTH
9356.0
07-JAN-99
5.1A-12
5.0-53
~!~40RY
13125.0
9070.0
13125.0
50.9
73.1
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE
IMP RESIST./GR
$
TOOL NUMBER
IMP 012
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLERS CASING DEPTH (FT) :
6.000
9075.0
BOREHOLE CONDITIONS
MUD TYPE: QUICKDRILN
MUD DENSITY (LB/G): 8.90
MUD VISCOSITY (S) : 58.0
MUD PH: 8.8
MUD CHLORIDES (PPM) :
FLUID LOSS (C3): 5.5
RESISTIVITY (OH~) AT TEMPERATURE (DEGF) :
MUD AT MEASURED TEMPERATURE (MT) : O. 100
MUD AT MAX CIRCULATIONG TEMPERATURE :
MUD FILTRATE AT (MT): O. 130
MUD CAKE AT (MT): O. 340
70.0
70.0
70.0
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN)
TOOL STANDOFF (IN) '.
EWR FREQUENCY (HZ):
20000
REMARKS:
*** RUN1 9109'-9356' ***
*** RUN2 9356'-11907' ***
RUN2 MEMORY DATA TO 9300', THEN MEMORY FAILED
RUN2 RT DATA FROM 9300' - 11907'
*** RUN3 11907'-13125' ***
LIS Tape Verifi~-'~tion Listing
Schlumberger Alaska Computing Center
29-MAR-1999 11:03
PAGE:
$
LIS FORMAT DATA
** DATA FORMAT SPECIFICATION RECORD **
** SET TYPE - 64EB **
TYPE REPR CODE VALUE
1 66 0
2 66 0
3 73 48
4 66 255
5 66
6 73
7 65
8 68 0.5
9 65 FT
11 66 21
12 68
13 66 0
14 65 FT
15 66 68
16 66 1
0 66 1
** SET TYPE - CHAN **
NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS
ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX)
DEPT FT 4000307 O0 000 O0 0 2 1 1 4 68
TAB LW1 S 4000307 O0 000 O0 0 2 1 1 4 68
ROP$ LW1 F/HR 4000307 O0 000 O0 0 2 1 1 4 68
A22H LW1 OH~M 4000307 O0 000 O0 0 2 1 1 4 68
A28H LW1 OHMM 4000307 O0 000 O0 0 2 1 1 4 68
A34H LW1 OH~M4000307 O0 000 O0 0 2 1 1 4 68
PiOH LW1 OhT4M 4000307 O0 000 O0 0 2 1 1 4 68
P16H LW1 Ot~4M 4000307 O0 000 O0 0 2 1 1 4 68
P22H LW1 OHNk~4000307 O0 000 O0 0 2 1 1 4 68
P28H LW1 0H~4000307 O0 000 O0 0 2 1 1 4 68
P34H LW1 OHMM4000307 O0 000 O0 0 2 1 1 4 68
GR LW1 GAPI 4000307 O0 000 O0 0 2 1 1 4 68
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
** DATA **
LIS Tape Verif£C~ion Listing
Schlumberger Alaska Computing Center
29-MAR-1999 11: 03~'
PAGE:
DEPT. 9016. 500 TAB. LW1
A28H. LW1 0.106 A34H. LW1
P22H. LW1 1 . 549 P28H. LW1
DEPT. 9355. 500 TAB. LW1
A28H. LW1 6.102 A34H. LW1
P22H.LW1 10. 426 P28H. LW1
O. 000 ROPS.LW1 3625958. 000 A22H.LW1
O. 100 PiOH. LW1 1. 451 P16H.LW1
1 . 136 P34H. LW1 O. 832 GR.LW1
O. 650 ROPS. LW1
6. 874 PiOH.LW1
11 . 256 P34H. LW1
105.237 A22H. LW1
8. 306 P16H. LW1
12. 491 GR. LW1
0.112
1.670
44.267
5. 447
9.574
49. 696
** END OF DATA **
**** FILE TRAILER ****
FILE NAME : EDIT .002
SERVICE : FLIC
VERSION : O01CO1
DATE : 99/03/26
MAX REC SIZE : 1024
FILE TYPE : LO
LAST FILE :
**** FILE HEADER ****
FILE NAME : EDIT .003
SERVICE : FLIC
VERSION : O01CO1
DATE : 99/03/26
MAX REC SIZE : 1024
FILE TYPE : LO
LAST FILE :
FILE HEADER
FILE NUMBER 3
RAW MWD
Curves and log header data for each bit run in separate files.
BIT RUN NUMBER: 2
DEPTH INCREMENT: O. 5000
FILE SUMMARY
VENDOR TOOL CODE START DEPTH
MWD 9356.0
$
LOG HEADER DATA
DATE LOGGED:
SOFTWARE:
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY or REAL-TIME):
TD DRILLER (FT) :
STOP DEPTH
11907.0
07-JAN-99
5.1A-12
5.0-53
MEMORY
13125.0
LIS Tape Verifi'=~ion Listing
Schlumberger Alaska Computing Center
29-MAR-1999 11:03'-~'
PAGE:
TOP LOG INTERVAL (FT) :
BOTTOM LOG INTERVAL (FT) :
BIT ROTATING SPEED (RPM) :
HOLE INCLINATION (DEG)
MINIMUM ANGLE:
MAXIMUM ANGLE:
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE
IMP RESIST./GR
$
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLERS CASING DEPTH (FT):
9070.0
13125.0
73.1
91.27
TOOL ~ER
IMP 052
6.000
9075.0
BOREHOLE CONDITIONS
MUD TYPE: QUICKDRILN
MUD DENSITY (LB/G): 8.90
MUD VISCOSITY (S) : 58.0
MUD PH: 8.8
MUD CHLORIDES (PPM) :
FLUID LOSS (C3): 5.5
RESISTIVITY (OH~ff4) AT TEMPERATURE (DEGF):
MUD AT MEASURED TEMPERATURE (MT): O. 100
MUD AT MAX CIRCULATIONG TEMPERATURE :
MUD FILTRATE AT (MT): 0.130
MUD CAKE AT (MT): 0.340
70.0
70.0
70.0
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN)
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
20000
REMARKS: *** RUN1 9109'-9356'
*** RUN2 9356'-11907' ***
RUN2 MEMORY DATA TO 9300', THEN MEMORY FAILED
RUN2 RT DATA FROM 9300' - 11907'
*** RUN3 11907'-13125' ***
$
LIS FORMAT DATA
LIS Tape Verifie~-cion Listing
Schlumberger Alaska Computing Center
29-MAR-1999 11:03~-~
PAGE:
** DATA FORMAT SPECIFICATION RECORD **
** SET TYPE - 64EB **
TYPE REPR CODE VALUE
1 66 0
2 66 0
3 73 48
4 66 255
5 66
6 73
7 65
8 68 0.5
9 65 FT
11 66 21
12 68
13 66 0
14 65 FT
15 66 68
16 66 1
0 66 1
** SET TYPE - CHAN **
NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS
ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX)
DEPT FT 4000307
TAB LW2 S 4000307
ROP5 LW2 F/HR 4000307
A22H FSO 0H~944000307
A28H FSO 0H~44000307
A34H FSO 0PL~44000307
PiOH FSO 0P~4~4000307
P16H FSO 0P~94 4000307
P22H FSO OH~4~ 4000307
P28H FSO OH~M 4000307
P34H FSO 0H~44000307
GR FSO GAPI 4000307
O0 000 O0 0 3 1 1 4 68 0000000000
O0 000 O0 0 3 1 1 4 68 0000000000
O0 000 O0 0 3 1 1 4 68 0000000000
O0 000 O0 0 3 1 1 4 68 0000000000
O0 000 O0 0 3 1 1 4 68 0000000000
O0 000 O0 0 3 1 1 4 68 0000000000
O0 000 O0 0 3 1 1 4 68 0000000000
O0 000 O0 0 3 1 1 4 68 0000000000
O0 000 O0 0 3 1 1 4 68 0000000000
O0 000 O0 0 3 1 1 4 68 0000000000
O0 000 O0 0 3 1 1 4 68 0000000000
O0 000 O0 0 3 1 1 4 68 0000000000
** DATA **
DEPT. 9295.000
A28H. FSO 0.136
P22H. FSO 0.171
DEPT. 10000.000
A28H. FSO -999.250
P22H. FSO 18.150
TAB.LW2 0.164 ROPS.LW2 -999.250 A22H. FSO
A34H. FSO 0.247 PiOH.FSO 2.260 P16H. FSO
P28H. FSO 0.500 P34H.FSO 1.000 GR.FSO
TAB. LW2 -999. 250 ROPS. LW2 72. 760 A22H. FSO
A34H. F50 -999.250 PiOH. FSO 13.590 P16H. FSO
P28H. F50 -999.250 P34H.FSO 22.540 GR.FSO
0.101
1. 786
212. 449
-999.250
-999.250
24.415
LIS Tape Verifr~c~ion Listing
Schlumberger Alaska Computing Center
29-MAR-1999 11:03-~.~'
PAGE: 10
DEPT. 11000.000 TAB.LW2
A28H.FSO -999.250 A34H. FSO
P22H.FSO 7.630 P28H. FSO
DEPT. 11907.000 TAB.LW2
A28H. FSO -999.250 A34H. FSO
P22H.FSO -999.250 P28H.FSO
-999.250 ROPS.LW2
-999.250 PiOH. FSO
-999.250 P34H. FSO
-999.250 ROP5.LW2
-999.250 PiOH. FSO
-999.250 P34H. F50
66.330 A22H.FSO
7.360 P16H.FSO
7.910 GR.F50
-999.250 A22H. F50
-999.250 P16H. FSO
-999.250 GR.FSO
-999.250
-999.250
21.975
-999.250
-999.250
-999.250
** END OF DATA **
**** FILE TRAILER ****
FILE NAME : EDIT .003
SERVICE : FLIC
VERSION : O01CO1
DATE : 99/03/26
MAX REC SIZE : 1024
FILE TYPE : LO
LAST FILE :
**** FILE HEADER ****
FILE NAME : EDIT .004
SERVICE · FLIC
VERSION : O01CO1
DATE : 99/03/26
MAX REC SIZE : 1024
FILE TYPE : LO
LAST FILE :
FILE HEADER
FILE ArUblBER 4
RAW MWD
Curves and log header data for each bit run in separate files.
BIT RUN NUMBER: 3
DEPTH INCREMENT: O . 5000
FILE SUI4MARY
VENDOR TOOL CODE START DEPTH
MWD 11907.0
$
LOG HEADER DATA
DATE LOGGED:
SOFTWARE:
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY or REAL-TIME)
STOP DEPTH
13125.0
07-JAN-99
5. lA-12
5.0-53
MEMORY
LIS Tape Verifi-~-uion Listing
Schlumberger Alaska Computing Center
29-MAR-1999 11: 03
PAGE: 11
TDDRILLER (FT):
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT):
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG)
MINIMUM ANGLE:
MAXIMUM ANGLE:
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE
IMP RESIST./GR
$
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN) :
DRILLERS CASING DEPTH (FT) :
13125.0
9070.0
13125.0
91.3
95.8
TOOL NUMBER
IMP 031
6. 000
9075.0
BOREHOLE CONDITIONS
MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S) :
MUD PH:
MUD CHLORIDES (PPM) :
FLUID LOSS (C3):
RESISTIVITY (OPk4~) AT TEMPERATURE (DEGF):
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATIONG TEMPERATURE :
MUD FILTRATE AT (MT):
MUD CAKE AT (MT):
QUIC~RILN
8.90
58.0
8.8
5.5
0.100
0.130
0.340
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
20000
REMARKS: *** RUN 1 9109'-9356' ***
*** RUN 2 9356'-11907' ***
RUN 2 MEMORY DATA TO 9300', THEN MEMORY FAILED
RUN 2 RT DATA FROM 9300' - 11907'
*** RUN 3 11907'-13125' ***
$
LIS FORMAT DATA
70.0
70.0
70.0
LIS Tape Verifit~r~ion Listing
Schlumberger Alaska Computing Center
29-MAR-1999 11:03~-~
PAGE:
12
** DATA FORMAT SPECIFICATION RECORD **
* * SET TYPE - 64EB **
TYPE REPR CODE VALUE
1 66 0
2 66 0
3 73 48
4 66 255
5 66
6 73
7 65
8 68 0.5
9 65 FT
11 66 21
12 68
13 66 0
14 65 FT
15 66 68
16 66 1
0 66 1
** SET TYPE - CHAN **
NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS
ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~I CODE (HEX)
DEPT FT 4000307 O0 000 O0 0 4 1 1 4 68 0000000000
TAB LW3 S 4000307 O0 000 O0 0 4 1 1 4 68 0000000000
ROP5 LW3 F/HR 4000307 O0 000 O0 0 4 1 1 4 68 0000000000
A22H LW3 0It~4000307 O0 000 O0 0 4 1 1 4 68 0000000000
A28H LW3 OP2Vi~4000307 O0 000 O0 0 4 1 1 4 68 0000000000
A34H LW3 0H~4~I4000307 O0 000 O0 0 4 1 1 4 68 0000000000
PiOH LW3 OFAv~I4000307 O0 000 O0 0 4 1 1 4 68 0000000000
P16H LW3 0It~ff44000307 O0 000 O0 0 4 1 1 4 68 0000000000
P22H LW3 0H1~14000307 O0 000 O0 0 4 1 1 4 68 0000000000
P28H LW3 0PE4~4000307 O0 000 O0 0 4 1 1 4 68 0000000000
P34H LW3 0H~44000307 O0 000 O0 0 4 1 1 4 68 0000000000
GR LW3 GAPI 4000307 O0 000 O0 0 4 1 1 4 68 0000000000
* * DA TA * *
DEPT. 11846. 000 TAB.LW3 O. 000 ROPS.LW3 288. 000 A22H.LW3
A28H.LW3 19.374 A34H. LW3 18. 653 PiOH. LW3 11. 435 P16H.LW3
P22H. LW3 21 . 130 P28H. LW3 24. 561 P34H. LW3 27. 044 GR. LW3
DEPT. 12000. 000 TAB.LW3 3. 361 ROPS.LW3 15. 748 A22H. LW3
A28H.LW3 23. 643 A34H.LW3 22. 724 PiOH.LW3 14. 699 P16H.LW3
P22H.LW3 18. 882 P28H. LW3 20. 639 P34H. LW3 21. 928 GR.LW3
19.100
16.236
24. 437
22. 645
16. 839
93. 563
LIS Tape Verif~'6~%ion Listing
Schlumberger Alaska Computing Center
29-MAR-1999 11:03
PAGE:
13
DEPT. 13000. 000 TAB. LW3
A28H.LW3 34.470 A34H.LW3
P22H. LW3 30. 690 P28H. LW3
DEPT. 13124. 500 TAB. LW3
A28H. LW3 25. 880 A34H. LW3
P22H. LW3 16. 766 P28H. LW3
3. 561 ROPS. LW3
32. 484 PiOH. LW3
34. 404 P34H. LW3
2. 335 ROPS . LW3
24. 915 P1 OH. LW3
18. 556 P34H. LW3
7.117 A22H.LW3
22. 103 P16H.LW3
36. 771 GR. LW3
29. 899 A22H. LW3
12. 009 P16H. LW3
20. 080 GR. LW3
31.368
26.308
110.301
24.357
14.540
46.041
** END OF DATA **
**** FILE TRAILER ****
FILE NAME : EDIT .004
SERVICE : FLIC
VERSION · O01CO1
DATE · 99/03/26
MAX REC SIZE : 1024
FILE TYPE : LO
LAST FILE :
**** TAPE TRAILER ****
SERVICE NAME : EDIT
DATE : 99/03/26
ORIGIN : FLIC
TAPE NAME : 99095
CONTINUATION # : 1
PREVIOUS TAPE :
COGENT : BP EXPLORATION, R-O9A, PRUDHOE BAY, API #50-029-20609-01
**** REEL TRAILER ****
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DATE : 99/03/26
ORIGIN : FLIC
REEL NAME : 99095
CONTINUATION # :
PREVIOUS REEL :
COMMENT · BP EXPLORATION, R-O9A, PRUDHOE BAY, API #50-029-20609-01
