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Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout202-186 OPERABLE: V -103 (PTD #2021860))bing Integrity Restored • Page 1 o
Regg, James B (DOA)
From: AK, D &C Well Integrity Coordinator [AKDCWelllntegrityCoordinator @bp.com]
Sent: Friday, August 19, 2011 5:42 PM �2e ci Oa)!
To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Cis'moski, Doug A; Daniel, Ryan;
AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS Prod
Controllers; AK, OPS GC2 OSM; AK, OPS GC2 Ops Lead; AK, OPS GC2 Wellpad Lead; AK, OPS GC2 Field
O &M TL; AK, OPS GC2 OSS; AK, RES GPB West Wells Opt Engr
Cc: Reynolds, Charles (ALASKA); Greaves, Damien C; King, Whitney
Subject: OPERABLE: V -103 (PTD #2021860) Tubing Integrity Restored
All,
Producer V -103 (PTD #2021860) passed an MIT -IA after dummy gas lift valves were set. The passing
test verifies two competent barriers and the well is reclassified as Operable.
Thank you,
Mehreen Vazir
(Alternate: Gerald Murphy)
Well Integrity Coordinator
BP Alaska Drilling & Wells
Well Integrity Office: 907.659.5102 tip J IF, .
Email: AKDCWeIlIntegrityCoordinator @BP.com
From: AK, D &C Well Integrity Coordinator
Sent: Sunday, July 24, 2011 2:50 PM
To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy (DOA)'; Cismoski, Doug A; Daniel, Rya , AK, D &C Well Services
Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS Prod Controllers; AK, OPS GC2 OSM; , OPS GC2 Ops Lead; AK,
OPS GC2 Wellpad Lead; AK, OPS GC2 Field O &M TL; AK, OPS GC2 OSS; AK, RES GPB West Wells Opt Engr; A &C Well Integrity
Coordinator /
Cc: Walker, Greg (D &C); Grey, Leighton (CH2M Hill); Reynolds, Charles (ALASKA); Greaves, Dami: C; Townsend, S. Eliot
Subject: UNDER EVALUATION: V -103 (PTD #2021860) Sustained Casing pressure on I. during proration
All,
Producer V -103 (PTD #2021860) was found to have su ained casing pressure on the IA during
shutdown activity. On 07/17/11 the wellhead pressur: were Tubing /IA/OA equal to SSV/2220/330 psi.
The facility is in the process of coming online and t well can be brought online to allow the well to warm
for diagnostic testing. The well has been reclass ed as Under Evaluation.
The plan forward is as follows:
1. DHD: TIFL
2. Slickline: Change out GLV's (depen•ent upon TIFL results)
3. DHD: Re -TIFL
A TIO plot and wellbore schematic have been included for your reference.
« File: V -103 TIO Plot.doc » « File: V- 103.pdf »
Please contact well integrity with any questions.
8/26/2011
UNDER EVALUATION: V -103 (PTD2021860) Sustained Casing pressure o during prora... Page 1 of 2
Regg, James B (DOA)
From: AK, D &C Well Integrity Coordinator [ AKDCWellIntegrityCoordinator @bp.com]
Sent: Sunday, July 24, 2011 2:50 PM 2� it
Z11(
To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Cismoski, Doug A; Daniel,
Ryan; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK,
OPS Prod Controllers; AK, OPS GC2 OSM; AK, OPS GC2 Ops Lead; AK, OPS GC2 Wellpad Lead; AK,
OPS GC2 Field O &M TL; AK, OPS GC2 OSS; AK, RES GPB West Wells Opt Engr; AK, D &C Well
Integrity Coordinator
Cc: Walker, Greg (D &C); Grey, Leighton (CH2M Hill); Reynolds, Charles (ALASKA); Greaves, Damien C;
Townsend, S. Eliot
Subject: UNDER EVALUATION: V -103 (PTD #2021860) Sustained Casing pressure on IA during proration
Attachments: V -103 TIO Plot.doc; V- 103.pdf
All,
Producer V -103 (PTD #2021860) was found to have sustained casing pressure on the IA during
shutdown activity. On 07/17/11 the wellhead pressure were Tubing /IA/OA equal to SSV/2220/330 psi.
The facility is in the process of coming online and this well can be brought online to allow the well to warm
for diagnostic testing. The well has been reclassified as Under Evaluation.
The plan forward is as follows:
1. DHD: TIFL
2. Slickline: Change out GLV's (dependent upon TIFL results) cp; 30 61, of
3. DHD: Re -TIFL
Ak)Hce ok per CD4cr 2-
A TIO plot and wellbore schematic have been included for your reference.
«V -103 TIO Plot.doc» «V- 103.pdf»
Please contact well integrity with any questions.
Thank you,
Taylor
Taylor Wellman filling in for Mehreen Vazir /Jerry Murphy
Office: 659 -5102
Pager: 659 -5100 x 1154
4 :--ANNED JUL 2 5 2Oi
From: AK, D &C Well Integrity Coordinator
Sent: Monday, July 18, 2011 3:53 PM
To: 'Regg, James B (DOA) ; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy (DOA)'; Cismoski, Doug A; Daniel, Ryan; AK, D &C Well Services
Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS Prod Controllers; AK, OPS GC2 OSM; AK, OPS GC2 Ops Lead; AK,
OPS GC2 Wellpad Lead; AK, OPS GC2 Field O &M TL; AK, OPS GC2 OSS; AK, OPS GC1 Wellpad Lead; AK, OPS GC1 OSM; AK, OPS GC1 Field
O &M TL; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 OSM; AK, OPS FS1
Ops Lead; AK, OPS GPMA Field O &M TL; AK, OPS GPMA OSM; AK, OPS GPMA OSS
Cc: Walker, Greg (D &C); Grey, Leighton (CH2M Hill); Reynolds, Charles (ALASKA); Kaminski, Alice; Warner, Ross L; Oakley, Ray (PRA);
Greaves, Damien C; Brown, Don L.
Subject: Producers with sustained casing pressure on IA during proration
All,
The following producers were reported to have sustained casing pressure on the IA during the proration
7/28/2011
UNDER EVALUATION: V -103 (PT 2021860) Sustained Casing pressure o during prora... Page 2 of 2
and shutdown activity July 15 -18. The im diate action is to perform a TIFL on each o e wells and evaluate for IA
repressurization. If any of the wells fail the TIFL, a follow up email will be sent to the AOGCC for each individual well.
05-41A (PTD #2031700)
P1 -04 (PTD #1930630)
L -104 (PTD #2012380)
V -04 (PTD #2061340)
V -103 (PTD #2021860)
W -36 (PTD #1881060)
Y -04 (PTD #1791050)
Y -16 (PTD #1830490)
All the wells listed above will be re- classified as Not Operable until start -up operations are complete and stable or the well
passes a pressure test proving integrity. After start -up, the wells will then be reclassified as Under Evaluation with POP
parameters to prevent any over - pressure incidents.
Please call with any questions or concerns.
Thank you,
Mehreen Vazir
(Alternate Gerald Murphy)
Well Integrity Coordinator
BP Alaska Drilling & Wells
Well Integrity Office: 907.659.5102
Email: AKDCWelllntegrityCoordinator @BP.com
7/28/2011
PBU V -103
PTD 2021860
7/24/2011
TIO Pressures Plot
Well: v -103
4,0 —
3.000 - • •
Tbg
f LA
2,000 - - OA
+„' n•r 00A
LI"I■i i r a 7 1 " 4 =4. •••441” :"."111 1 1"an"."1"11.
000A
■•••••On
1.000 -
•
i
08/20/08 10/21/08 12/22'08 0222/09 04/25/09 06/29/09 08/27/09 10/28109 12/29/09 03/01/10 05/02/10 07/03/10 09 /03/10 11/04/10 01/05/11 03/0811 05/09/11 07/10/11
11/1
TREE= 4-1/16" CM/
WELLHEAD = FMC • *Err NOTES:
ACTUATOR = NA V- 03
KB. ELEV = 82.5'
BF. ELEV =
KOP = 300'
ax Angle = @ 3-980 1 1015' H TAM PORT COLLAR I
Datum MD = 11000'
Datum TVD = 6600 SS 2212' 1-1 3-1/2" HES X NP, ID = 2.813" I
9-5/8" CSG, 40#, L-80, ID = 8.835" H
GAS LIFT MANDRELS
ST MD TVD DEV TYPE VLV LATCH PORT DATE
Minimum ID = .813" @ 2212' 3 5282 3502 62 MMG-W DOME RK 16 04/17/03
2
2 8787 5201 61 MMG-W DOME RK 16 08/28/05
3-1/2" HES X NIPPLE 1 10705 6412 27 MMG-W SO RK 24 08/28/05
I I 10762' H3-112" BKR CMD SLIDING SLV, ID = 2.813" I
■...3 10785' H7" X3-1/2" BKR PREMIER PKR, ID = 2.870"
10811' 1-1 3-1/2" HES X NIP, ID = 2.813"
10832' H 3-1/2" HES X NIP, ID = 2.813" I
3-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" H 10842' 1
10844' —j 3-1/2" WLEG, ID = 2.905"
10850' H ELMD TT LOGGED 01/06/03 I
PERFORATION SUMMARY
REF LOG:
ANGLE AT TOP PERF: 20 @ 10958'
Note: Refer to Production DB for historical perf data
SIZE SPF INTERVAL Opn/Sqz DATE
2-1/2" 6 10958 - 11000 0 01/07/03
2-1/2" 6 11008 - 11016 0 01/07/03
2-1/2" 6 11022 - 11028 0 01/07/03
10929' --I 7" MARKER JT W/ RA TAG I
PBTD —1 11114'
4 4
11240' 1 7 "
14 404 MARKER JT W/ RA TAG
4 *V
f' .71sto
144 44
7" CSG, 26#, L-80, ID = 6,276" H 11549'
DATE REV BY COMMENTS DATE REV BY COMMENTS BOREALIS UNIT
10/07/02 DCRIKK ORIGINAL COMPLETION 04/10/03 DRS/TP TVD/MD CORRECTIONS WELL: V-103
01/04/03 JM/KAK GLV C/O 04/17/03 JCIVVTLH GLV C/O PERMIT No: 2021860
01/07/03 CAO/TLH ADD PERFS 08/28/05 DAV/TLH GLV C/O AR No: 50-029-23117-00
01/16/03 MH//TLH GLV C/O SEC 11, T11N, R11E, 4878' NSL & 1620' WEL
01/24/03 TN/TP PBTD CORRECTION
01/24/03 JCM/TP GLV C/O BP Exploration (Alaska)
Producers with sustained casing pressuon IA during proration • Page 1 of 1
Regg, James B (DOA)
From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com]
Sent: Monday, July 18, 2011 3:53 PM
To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Cismoski, Doug A; Daniel, Ryan;
AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS Prod
Controllers; AK, OPS GC2 OSM; AK, OPS GC2 Ops Lead; AK, OPS GC2 Wellpad Lead; AK, OPS GC2 Field
O &M TL; AK, OPS GC2 OSS; AK, OPS GC1 Wellpad Lead; AK, OPS GC1 OSM; AK, OPS GC1 Field O &M
TL; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS FS1 DS Ops Lead; AK,
OPS FS1 OSM; AK, OPS FS1 Ops Lead; AK, OPS GPMA Field O &M TL; AK, OPS GPMA OSM; AK, OPS
GPMA OSS
Cc: Walker, Greg (D &C); Grey, Leighton (CH2M Hill); Reynolds, Charles (ALASKA); Kaminski, Alice; Warner, Ross
L; Oakley, Ray (PRA); Greaves, Damien C; Brown, Don L.
Subject: Producers with sustained casing pressure on IA during proration
All,
The following producers were reported to have sustained casing pressure on the IA during the proration
and shutdown activity July 15 -18. The immediate action is to perform a TIFL on each of the wells and
evaluate for IA repressurization. If any of the wells fail the TIFL, a follow up email will be sent to the
AOGCC for each individual well.
05-41A (PTD #2031700)
P1 -04 (PTD #1930630)
L -104 (PTD #2012380)
V -04 (PTD #2061340) Z U E i
r.,
V -103 (PTD #2021860
W -36 (PTD #1881060)
Y -04 (PTD #1791050)
Y -16 (PTD #1830490)
All the wells listed above will be re- classified as Not Operable until start-up operations are complete and
stable or the well passes a pressure test proving integrity. After start -up, the wells will then be
reclassified as Under Evaluation with POP parameters to prevent any over - pressure incidents.
Please call with any questions or concerns.
Thank you,
Mehreen Vazir
(Alternate: Gerald Murphy)
Well Integrity Coordinator
BP Alaska Drilling & Wells
I
Well Integrity Office: 907.659.5102
Email: AKDCWeIIIntegrityCoordinator @BP.com
7/19/2011
~
BP Exploration (Alaska) Inc.
Attn: Well Integriry Coordinator, PRB-20
Post Office Box 196612
Anchorage, Alaska 99519-6612
~ ~,
August 14, 2009 ,~~~; ~,'~U~~~~; °x~`'' ' '. ' ~~~~~
~
bp
~~~~~~~~
ocT o ~ zaas
Mr. Tom Maunder
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue
Anchorage, Alaska 99501
Subject: Corrosion Inhibitor Treatments of GPB V-Pad
Dear Mr. Maunder,
~alta Oil & Gas Cons. C~mm~~~inn
Anchorape
a o ~._ ~ ~~
~_l03
Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB V-
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.
lf you require any additional information, please contact me or my alternate, Anna Dube,
at 659-5102.
Sincerely,
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)
Date
V-pad
8/13/2009
Well Name
PTD #
API #
Initiai top of
cement
Voi. of cement
um ed
Final top of
cement
Cement top off
date
Corrosion
inhibitor Corrosion
inhibitor/
sealant date
ft bbls ft na al
V-01 2040900 50029232100000 NA 2 NA 17 6/30/2009
V-02 2040770 50029232090000 NA 3 NA 43.4 7/11/2009
V-03 2022150 50029231240000 SUrfBCe NA NA NA NA
V-04 2061340 50029233220000 NA 1.5 NA 20.4 6/29/2009
V-05 2080930 50029233910000 NA 1.75 NA 20.4 5/10/2009
V-07 2071410 50029233720000 NA 0.25 NA 1.7 6/29/2009
V-100 2010590 50029230080000 NA 1.5 NA 20.4 5/9/2009
V-101 2020560 50029230740000 NA 3.75 NA 32.3 7/10/2009
V-102 2020330 50029230700000 NA 7.75 NA 98.2 8/7/2009
V-t03 2021860 50029231170000 NA 0.5 NA 9.4 7/12/2009
V-104 2021420 5002923t030000 NA 1.5 NA 21.3 7/11/2009
V-105 2021310 50029230970000 NA 2.25 NA 23.8 6/29/2009
V-106A 2041850 50029230830100 NA 1.75 NA 17 6/29/2009
V-107 2021550 50029231080000 NA 1.75 NA 13.6 7/11/2009
V-108 2021660 50029231120000 NA 1.5 NA 14.5 7/10/2009
V-109 2022020 50029231200000 NA 1.2 NA 10.2 6/30/2009
V-111 2031030 50029231610000 NA 1.5 NA 11.9 7/12/2009
V-112 2060200 50029233000000 NA 1.5 NA 15.3 5/10/2009
V-113 2022160 50029231250000 NA 2.5 NA 37.4 5/10/2009
V-114A 2031850 50029231780100 NA 2.5 NA 34 6/30/2009
V-115 2040270 50029231950000 NA 1.5 NA 13.1 5/9/2009
V-117 2030900 50029231560000 NA 1.25 NA 22.1 5/10/2009
V-119 2040410 50029232010000 NA 2 NA 18.7 6/30/2009
V-120 2041790 50029232250000 NA 1.5 NA 8.5 7/12/2009
V-121 2070360 50029233480000 NA 1.9 NA 17 6/30/2009
V-t22 2061470 50029233280000 NA 1.5 NA 6.8 5/10/2009
V-20i 2012220 5002923054000o SC leak NA 4 NA 90.6 8/7/2009
V-202 2030770 50029231530000 NA 1.75 NA 12.8 7/11/2009
V-203 2051680 50029232850000 NA 2 NA 12.8 7/10/2009
V-204 2041310 50029232170000 NA 2 NA 22.1 6/30/2009
V-205 2061800 50029233380000 NA 1.8 NA 13.6 6/30/2009
V-207 2080660 50029233900000 NA 1.75 NA 18.28 1/9/2009
V-210 2042100 50029232310000 NA 2 NA 18.7 7/11/2009
V-211 2042200 50029232320000 NA 1.5 NA 13.6 7/10/2009
V-212 2051500 50029232790000 NA 1.2 NA 11.9 6/29/2009
V-213 2041160 50029232130000 NA 1.75 NA 6.3 5/9/2009
V-214 2051340 50029232750000 NA 0.5 NA 9.4 7/11/2009
V-215 2070410 50029233510000 NA 2.8 NA 30.6 6/30/2009
V-216 2041300 50029232160000 NA 1.5 NA 13.6 6/29/2009
V-217 2061620 50029233340000 NA 2.3 NA 25.5 6/30/2009
V-21 S 2070400 50029233500000 NA 2 NA 17.9 7/12/2009
V-219 2081420 50029233970000 NA 1 NA 16.2 7/12/2009
",-'~^ 2080200 50029233830000 NA 1.75 NA ~5 3/9/2008
V-22t 2050130 50029232460000 NA 0.8 NA 8.5 6/29/2009
V-222 2070590 50029233570000 NA 2.5 NA 21.3 7/11/2009
V-223 2080220 50029233840000 NA 2 NA 20.5 9/7/2008
.
.
MICROFILMED
07/25/06
DO NOT PLACE
ANY NEW MATERIAL
UNDER THIS PAGE
F:\LaserFiclte\CvrPgs _ Inserts\Microfilm _ Marlcer,doc
-7 h/¿ À (}Jð ,-
DATA SUBMITTAL COMPLIANCE REPORT
2/1/2005
Jj1'~cL .L J Y ~"o .t.-
Permit to Drill 2021860
Well Name/No. PRUDHOE BAY UN BORE V-103
Operator BP EXPLORATION (ALASKA) INC
API No. 50-029-23117-00-00
MD 11560 (,.../. - TVD 7215
Completion Date 117/2003 V--
Completion Status 1-01L
Current Status 1-01L
UIC N
-----------.----
----------
REQUIRED INFORMATION
Mud Log No
Samples No
Directional Survey éiii)'
- - ---------
DATA INFORMATION
Types Electric or Other Logs Run:
Well Log Information:
MWD, GR, PWD, RES, NEU, AZM DENS, US IT
(data taken from Logs Portion of Master Well Data Maint)
Log/ Electr "-'
Data Digital Dataset Log Log Run Interval OH/
Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments
--- ---
~og c>Jeutron 25 Blu 1 3560 11560 Case 11/1/2002
v¡1-0g ~duction/Resistivity 25 Blu 108 11560 Case 11/1/2002
~g Unduction/Resistivity 25 Blu 108 11560 Case 11/1/2002
LJ..gg (/[)ensity 25 Blu 3560 11560 Case 11/1/2002
Rpt Directional Survey 0 11560 Open 1 0/23/2002
~g CS6nic 5 Col 3295 11415 Case 1 0/25/2002
J..og vÐensity 25 Blu 3560 11560 Case 11/1/2002
Jog e... ( eutron 25 Blu 3560 11560 Case 11/1/2002
~ ~mperature 5 Blu 15 11439 Case 217/2003
ED D Directional Survey 0 11560 Open 1 0/23/2002
~C é4f250 See Notes 108 11 560 Case 11/1/2002 LDWG edit of PP, ARC,
ADN LWD log
--- -----------~ -
Well Cores/Samples Information:
Sample
Interval Set
Name Start Stop Seht ReèéLvêd Number Comments
ADDITIONAL INFORMATION
Well Cored? Y ®
Chips Received? - Y / N J
Daily History Received?
WN
't1p N
Formation Tops
Analysis Y / hi
Received?
- ---. --- --
- -------- --
DATA SUBMITTAL COMPLIANCE REPORT
2/1/2005
Permit to Drill 2021860
Well Name/No. PRUDHOE BAY UN BORE V-103
~perator ··SPEXPLORATION (ALASKA) INC
API No. 50-029-23117-00-00
MD 11560
TVD 7215
Completion Date 117/2003
Completion Status 1-01L
Current Status 1-01L
UIC N
Comments:
- - --- ---
')L
Date:
q fVlÞA/\ JJ-N;; --
--- -- -------- ---
Compliance Reviewed By: _
-'
'----
)
\
I
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
1. Operations performed:
FRAC
2. Name of Operator
BP Exploration (Alaska), Inc.
3. Address
P. O. Box 196612
Anchorage, AK 99519-6612
4. Location of well at surface
Operation shutdown_
Pull tubing _
Stimulate _X
Alter casing _
5. Type of Well:
Development _X
Exploratory_
Stratigraphic_
Service_
Plugging _ Perforate
Repair well _ Other
6. Datum elevation (DF or KB feet)
RKB 83 feet
7.UnnorPropertyname
402'FNL, 1620'FEL,Sec. 11,T11N, R11E, UM
At top of productive interval
3386'FNL,4313'FEL,Sec.36,T12N, R11E,UM
At effective depth
3241'FNL,4262'FEL,See.36,T12N, R11E,UM
At total depth
3210'FNL,4252'FEL,See.36,T12N, R11E, UM
12. Present well condition summary
Total depth: measured
true vertical
Prudhoe Bay Unit
8. Well number
(asp's 590680, 59701)v V-103
9. Permit number / approval number
(asp's 593168,5977732) 202-186/303-018
10. API number
(.
(asp's 593217,5977878)
50-029-23117 -00
11. Field I Pool
Prudhoe Bay Field I Borealis Pool
(asp's 593227,5977909)
11560 feet
7215 feet
Plugs (measured) TD tagged @ 11440' (01/06/2003)
Effective depth: measured 11440 feet Junk (measured)
true vertical 7100 feet
Casing Length Size Cemented Measured Depth True Vertical Depth
Conductor 108' 20" 260 sx AretieSet (Aprox) 136' 136'
Surface 3530' 9-5/8" 550 sx PF 'L', 405 sx 3558' 2679'
Class 'G'
Production 11 521' 7" 460 sx Mierolite Class 11549' 7205'
'G', 200 sx Class 'G'
Perforation depth:
measured Open Perfs 11958'-11000',11008'-11016',11022'-11028'
Cf=~VE···.'''''''D·· .
!7&.....M '. ,I
true vertical Open Perfs 6643'-6683', 6690'-6698', 6703'-6709'.
MAY 05 2003
Tubing (size, grade, and measured depth)
3-1/2" 9.2#, L-80 TBG @ 10842',
AJa2ka Oí1 & Gas Cons. OJmmflmion
Anmoœ~!e
Packers & SSSV (type & measured depth) 7" x 3-1/2" Baker Premier Packer @ 10785'.
3-1/2" HES X Nipple @ 2212' MD.
13. Stimulation or cement squeeze summary
Intervals treated (measured) (see attached)
Treatment description including volumes used and final pressure
14. Representative Daily Average Production or Injection Data
Oil-Bbl Gas-Met Water-Bbl
1414 2604 60
Casinç¡ Pressure
Tubinç¡ Pressure
300
330
Prior to well operation
01/10/2003
Subsequent to operation 02/04/2003
15. Attachments
Copies of Logs and Surveys run _
Daily Report of Well Operations _ Oil X Gas
17. I he~e0certify that the foregoing i~ue()d /jrrect to the b~st of my knowledge.
.A-..J&~~ø~~ Hie: TechlcalAsslstant
DeWayne R. Schnorr ~ ~
4525
2657
16. Status of well classification as:
48
Suspended _
Service
Date April 21. 2003
Prepared by DeWayne R. Schnorr 564-5174
fi5)F'1J) 1:\'\) r. P ,',,"
'f\'íII))IU I~,'o~; :~';'
Form 10-404 Rev 06/15/88 ·
~~y
tj
ORIGINAL
SUBMIT IN DUPLICATE ~
)
)
V-103
DESCRIPTION OF WORK COMPLETED
NRWO OPERATIONS
01/21/2003 NEW WELL POST: AC-MONITOR
01/22/2003 NEW WELL POST: FRACTURING
01/24/2003 NEW WELL POST: FILL CLEAN OUT
01/24/2003 NEW WELL POST: GAS LIFT--FOR RATE
01/25/2003 NEW WELL POST: GAS LIFT--FOR RATE
01/26/2003 NEW WELL POST: HOT OIL TREATMENT
03/22/2003 NEW WELL POST: AC-FLUID LEVEL
04/12/2003 GAS LIFT--FOR RATE: AC-FLUID LEVEL
04/14/2003 TESTEVENT --- BOPD: 3/148/ BWPD: 619/ MCFPD: 1/797/ AL Rate: 0
04/16/2003 GAS LIFT--FOR RATE: GAS LIFT--FOR RATE
04/17/2003 GAS LIFT--FOR RATE: GAS LIFT--FOR RATE
04/21/2003 TESTEVENT --- BOPD: 3,393, BWPD: 689, MCFPD: 3,836, AL RATE: 2,015
EVENT SUMMARY
01/21/03 T/I/O = SSV/SI/O. (MONITOR POST MITIA).
01/22/03 FRACED KUPARUK C3/C4 PERFS 109581-11028' WITH YF125LG SYSTEM AND
202.125K# OF 16/20 CL. HELD IA PRESSURE DURING FRAC JOB. PUMPED
JOB TO COMPLETION, INTENTIONALLY UNDERFLUSHING WITH 92 BBLS ---
(10 BBLS FREEZE PROTECT IN TUBING). PLACED 200.525K# PROP BEHIND
PIPE LEAVING 1600# (2.6 BBLS) PROP IN THE CASING, EST. TOS IF PACKED
@ 11,350' WLM. MAX TREATMENT - 7123 PSI. AVERAGE TREATMENT = 6200
PSI. LOAD TO RECOVER = 1483 BBLS, ALL ISO TOOL CUPS RECOVERED.
01/24/03 RIG UP CTU #9. RIH WITH 2.25" JSN. TAGGED SAND TOP @ 11114' (86' OF
RATHOLE.) PULLED UP TO TT @ 10840'. POOH @ 80% PUMPING 1% XS KCL
(MADE EXTRA PASSES ACROSS ALL JEWELRY.) STAGED IN NEAT
METHANOL TO FREEZE PROTECT TO 3000'. JOB COMPLETE --- SLlCKLlNE
TO SET GLV's.
01/24/03 SET 3-1/2 X CATCHER SUB @ 10773' SLM.
01/25/03 PULL DGLV'S FROM STArs 1,2,3. SET NEW GASLlFT DESIGN IN STArs # 1,2, &
3. PULL CATCHER SUB. «< WELL LEFT SI »>
01/26/03 PUMPED DOWN IA; 10 BBLS NEAT MEOH, 90 BBLS DIESEL @ 180 DEGREES,
20 BBLS NEAT METHANOL.
03/22/03 T/1/0=340/1620/300 TEMP=50. IA FL @ 10705' (ST #1) FOR PAD OPERATOR.
04/12/03 T/I/0=300/1620/200 (FOR APE) TEMP 70* IA FL @ 10705' (ST # 1).
04/14/03 TESTEVENT --- BOPD: 3,148, BWPD: 619, MCFPD: 1,797, AL RATE: 0
Page 1
')
\)
V-103
DESCRIPTION OF WORK COMPLETED
NRWO OPERATIONS
04/16/03 «< WELL FLOWING UPON ARRIVAL »> ATTEMPED TO SET SSCS UNABLE
TO GET PAST STA 1. SET X-LOCK C-SUB @ 108231SLM.
04/17/03 PULLED STATION'S # 1,2,3. SET DOME (16/6411,1580#) IN STA 3. SET S/O (
24/6411 PORT) IN STA 2. SET DGLV IN STA 1. PULLED C-SUB. «< TURNED
WELL OVER TO PAD OP. TO POP »>
04/21/03 TESTEVENT --- BOPD: 3,393, BWPD: 689, MCFPD: 3,836, AL RATE: 2,015
FLUIDS PUMPED
BBLS
75 NEAT METHANOL
48 60/40 METHANOL WATER
227 DIESEL
197 1% DOUBLE SLICK KCL WATER
1817 FRESH WATER
2364 TOTAL
Page 2
Schlumberger
Alaska Data and Consulting Services
3940 Arctic Blvd, Suite 300
Anchorage, AK 99503-5711
ATTN: Beth
Well
Job#
Log Description
V-10~-dD~
V-103~()~_ ~/.2
S-115 ao~~;J 3n
STATIC BH SURVEY
TEMPERATURE SURVEY
23058 SCMT
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO:
BP Exploration (Alaska) Inc.
Petrotectnical Data Center LR2-1
900 E Benson Blvd.
Anchorage AK 99508-4254
Date Delivered:
RECEIVED
FEB 0 7 2003
Alæfœ on & Gas Cons. Commiaion
Anchorage
01/11/03
01/06/03
01122/03
NO. 2845
02106/03
Company: Alaska Oil & Gas Cons Comm
Attn: Lisa Weepie
333 West 7th Ave, Suite 100
Anchorage, AK 99501
Field: Borealis
Aurora
Date
BL
Sepia
Schlumberger DCS
3940 Arctic Blvd Suite 300
Anchorage AK 99503-5789
ATTN: .:::---¥ ., .
Rece~bY: / ~
Color
CD
2
--
G.O~
---
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
)
)
1. Status of Well
ŒI Oil 0 Gas 0 Suspended 0 Abandoned ',_" ,,0 §~!yip~,
2. Name of Operator ;" I,!,.\ 7. Permit Number
BP Exploration (Alaska) Inc. /. ¿~)2;S 202-186 303-018
3. A~.~~~~x 196612, Anchorage, Alaska 99519-6612 .___~~~¡~~.-.. 8. ~~!0~~~~r17_00
4. Location of well at surface 9. Unit or Lease Name
4878' NSL, 1620' WEL, SEC. 11, T11 N, R11 E, UM X = 590680, Y = 5970127 Prudhoe Bay Unit
At top of productive interval
1892' NSL, 966' EWL, SEC. 36, T12N, R11 E, UM X = 593168, Y = 5977732 10. Well Number
At total depth
2069' NSL, 1028' EWL, SEC. 36, T12N, R11E, UM X = 593227, Y = 5977909
11. Field and Pool
5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field 1 Borealis Pool
RKB = 82.5' ADL 028238 (Undefined)
12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 15. Water depth, if offshore 16. No. of Completions
9/23/2002 ., 10/1/2003 t 11712003 NIA MSL One
17. Total Depth (MD+ TVD) 18. Plug Back Depth (MD+ TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost
11560 7215 FT 11440 7100 FT ŒI Yes 0 No (Nipple) 2212' MD 1900' (Approx.)
22. Type Electric or Other Logs Run
MWD, GR, PWD, RES, NEU, AZM DENS, US IT
23. CASING, LINER AND CEMENTING RECORD
CASING SETTING DEPTH HOLE
SIZE WT. PER FT. GRADE Top BOTTOM SIZE
20" 91.5# H-40 Surface 109' 42"
9-5/8" 40# L-80 27' 3551' 12-1/4"
7" 26# L-80 25' 11549' 8-3/4"
Classification of Service Well
V-103
CEMENTING RECORD
260 sx Arctic Set (Approx.)
514 sx PF 'L', 400 sx Class 'G'
446 sx Class 'G', 189 sx Class 'G'
Top Job: 155 sx PF 'C'
AMOUNT PUllED
24. Perforations open to Production (MD+ TVD of Top and
Bottom and interval, size and number)
2-1/2" Gun Diameter, 6 spf
MD TVD MD TVD
10958' - 11000' 6642' - 6683'
11008' - 11016' 6690' - 6698'
11022' - 11028' 6703' - 6709'
25.
SIZE
3-1/2",9.2#, L-80
TUBING RECORD
DEPTH SET (MD)
10844'
PACKER SET (MD)
10785'
26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED
Freeze Protect with 270 BBls Diesel
10958' - 11028' Frac'd; Placed 200,525# 16/20 Carbolite
Behind Pipe
27. PRODUCTION TEST
Date First Production Method of Operation (Flowing, gas lift, etc.)
January 8, 2003 Gas Lift
Date of Test Hours Tested PRODUCTION FOR Oll-BBl GAs-McF WATER-BBl
1/31/2003 4 TEST PERIOD 4,528 2,261 42
Flow Tubing Casing Pressure CALCULATED Oll-BBl GAs-McF WATER-BBl
Press. 420 24-HoUR RATE
28. CORE DATA
Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips.
CHOKE SIZE GAS-Oil RATIO
1760 531
Oil GRAVITY-API (CORR)
No core samples were taken.
Form 10-407 Rev. 07-01-80
RBOMS BFl
~,. FEB I I 200.3
Submit In Duplicate
)
)
29.
Geologic Markers
30.
Formation Tests
Marker Name
Measured
Depth
True Vertical
Depth
Include interval tested, pressure data, all fluids recovered and
gravity, GOR, and time of each phase.
Ugnu
3994'
2890'
Ugnu M Sands
6498'
40881
Schrader Bluff N Sands
70331
4345'
Schrader Bluff 0 Sands
7361'
45081
Base Schrader I Top Colville
8187'
4913'
HRZ
10663'
6375'
Kalubik
10876'
6567'
Kuparuk C
10956'
6641'
Kuparuk B
11125'
6800'
Kuparuk A
11292'
6958'
Miluveach
11382'
7044'
31. List of Attachments:
Summary of Daily Drilling Reports and Post Rig Work, Surveys
32. I ~erebY certify that the fO~O~ng is true and eorre" ct to the best of my knowledge
Signed Terrie Hubble /f~ . ~ Title Technical Assistant Date 0 ~ · 0 (p .Q. ~
V-103 202-186 303-018 Prepared By Name/Number: Terrie Hubble, 564-4628
Well Number Drilling Engineer: James Franks, 564-4468
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
Legal Name:
Common Name:
Test Date
9/27/2002
LOT
V-103
V-103
Test Type
Test Depth (TMD) ,
3,590.0 (ft)
EMW
13.44 (ppg)
südiÌêê,.·Ptêssurø··.. l:.~äkØ)'f~~$$t.írø:(~FJe)
520 (psi) 1,868 (psi)
2,675.0 (ft)
9.70 (ppg)
--
-'
Printed: 10/14/2002 9:47:12 AM
)
')
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
V-103
V-103
DRILL +COMPLETE
NABORS ALASKA DRILLING I
NABORS 9ES
Start: 9/22/2002
Rig Release: 10/7/2002
Rig Number: 9ES
Spud Date: 9/23/2002
End: 10/7/2002
9/22/2002
12:00 - 18:00
From -To Hours Task Code NPT
DescriþtiÖhÖf Operéltion$ ,
Date
18:00 - 23:00
9/23/2002
23:00 - 23:30
23:30 - 00:00
00:00 - 02:30
02:30 - 04:00
04:00 - 04:30
04:30 - 14:30
14:30 -15:00
15:00 - 17:30
17:30 - 18:00
18:00 - 20:00
20:00 - 00:00
9/24/2002
00:00 - 05:00
05:00 - 06:00
06:00 - 10:00
10:00 - 10:30
10:30 - 11 :30
11 :30 - 15:00
15:00 - 17:00
17:00 - 18:45
18:45 - 19:30
19:30-21:00
21 :00 - 21 :30
21 :30 - 22:30
22:30 - 00:00
9/25/2002
00:00 - 06:30
06:30 - 07:00
07:00 - 09:15
09: 15 - 09:30
09:30 - 09:45
09:45 -10:15
6.00 MOB P
PRE
5.00 MOB P
PRE
0.50 MOB P
0.50 MOB P
2.50 DRILL P
PRE
PRE
SURF
1.50 DRILL P
0.50 DRILL P
10.00 DRILL P
SURF
SURF
SURF
0.50 DRILL P
2.50 DRILL P
SURF
SURF
0.50 DRILL P
2.00 DRILL P
SURF
SURF
4.00 DRILL P
SURF
5.00 DRILL P
SURF
1.00 DRILL P
SURF
4.00 DRILL P
SURF
0.50 DRILL P
SURF
1.00 DRILL P
3.50 DRILL P
SURF
SURF
2.00 DRILL P
1.75 DRILL P
0.75 DRILL P
1.50 DRILL P
0.50 CASE P
1.00 CASE P
1.50 CASE P
SURF
SURF
SURF
SURF
SURF
SURF
SURF
6.50 CASE P
SURF
0.50 CEMT P
2.25 CEMT P
SURF
SURF
0.25 CEMT P
0.25 CEMT P
0.50 CEMT P
SURF
SURF
SURF
Move shop, Move rig from V108 to V1 03. Spot and level rig.
Spot pits, cuttings tank, spot auxilary buildings.
Fill pits. NU blank divertor spool and riser. RU floor and Prep
BHA in pipe shed.
Service top drive.
Pre Spud meeting.
PU HWDP and jars. Standback same. MU BHA #1 and test
MWD.
RIH tag cement at 108' and drill to 353'.
Stand back 2 HWDP and PU jars and one HWDP.
Continue to drill from 353' to 1655'. 230 spm,600gpm, 2450 psi
on bottom,2200psi off bottom, 83kup, 72L dn,77k rot, 80
rpm,5.6k TO on, 2 TO off,AST=1.85 hrs, ART =.64 hrs.
Circulate Hi Vis sweep.
Monitor well. POH for bit. 94K up,70K dn, Pull tight at 1050' to
900'. Pull 25-35K over from 631' to 539'. Work pipe .OK>
Service top drive.
RIH Worked pipe through 550' to 600'. Tight at 728',972'
1033', and 1211'.
MU top drive and ream last stand to bottom. Drill from 1655' to
2495'. 90K up,78K dn,82K rot,230 spm,660 gpm, 3020 psi on,
2850 psi off, 80 rpm, 7-8K TO on, 5K TO off, 35K WOB, AST=
1.4 hrs, ART = .6 hrs.
Directionally drill from 2495 to 3570 TD.1 07up, 74dn, 82 rot,660
gpm @3350 psi.on bottom, 3080 psi off, TO off 3000, TO on
8000 (AST= 1.2 ART = 2.8 hrs)
Circulate and condition mud. Rotate and reciprocate 10 ' off
bottom at 660 gpm.
POH from 3570' to 1900'.Pulled tight at 3555' back ream to
3520'. POH intermittent drag 15 to 50 K overpull. Pulled slow to
avoid swabbing to 1900'.
Well swabbing - couldn't get well to take proper fill. Back ream
to 1600'.
POH to HWDP with intermittent drag.
RIH taking weight from 1100'. Ream from 2050' to 3140'. RIH
from 3140' to 3550'. Ream last stand to bottom.
Circulate hole clean 650 gpm,3200 psi, Pump weighted sweep.
POH to HWDP hole in good condition.
Standback HWDP and jars.
LD BHA.
Make dummy run with hanger. Clear floor.
Change out bails on top drive. RU Franks casing fill up tool.
MU float joint and fill shoe. Check floats OK. RIH with 9-5/8"
casing. MU TO 8600 ft-Ibs.
Continue to RIH with 9-5/8" casing. MU hanger and landing
casing with shoe at 3558' MD.
RD casing tools. RU cement head & lines.
Break circ slowly. Incr rate to 8 BPM and circlcond mud for
cement operations.
PJSM for cementing operations.
Cont circ while cementers air up & prime up.
Pump 5 bbl water. Test lines to 3500 psi. Pump 15 bbl water
followed by 75 bbl Alpha spacer at 10.2 ppg. 5 bpm @ 350 psi.
Printed: 10/14/2002 9:47: 19 AM
)
)
BPEXPLORATION
Q perati()ns .$ul11maI"YiReport
Release bottom plug.
Mix & pump 380 bbl (550 sx) Permafrost L lead 6.5 bpm @ 700
psi at 10.5 ppg - (downhole density 10.7 ppg).
Mix & pump 83 bbl (405 sx) Premium Class G at 15.8 ppg.
Reciprocate pipe throughout job until end of tail slurry when
started getting sticky. Attempt to land hanger - won't seat down
on landing ring. Approx l' above ring.
SURF Release top plug and kick out with 10 bbl water from Howco.
Switch to rig pump and displace with 255 bbl mud 8 bpm
dropping to 2 bpm prior to bumping plug. Continue attempts to
seat casing hanger but losing ground. Work pipe free upwards,
but then unable to get back down @ 7' above landing ring.
Cont displacement and bump top plug - 2200 psi.
CIP at 12:15 hrs. Saw dye in spacer at 205 bbl away. Started
seeing weight increase with final sample from riser weighing
10.5 ppg and pH of 11 + just prior to bumping plug.
Drain & flush flow lines & riser. RID cementing equip. RID
casing tools.
Hold PJSM wI FMC & crew. Prepare cellar for wellhead work.
PJSM. Cut & remove 12" section of 20" conductor pipe. Set
emergency slips wI casing in 100K tension.
Remove Gray Lock off diverter. Make rough cut on 9 5/8"
casing. Pull landing jt, hanger, pup jt & cut off stub to the rig
floor.
N/D Riser & blank diverter spool. Clean & dress 9 5/8" casing
stub. Prepare fl welding on transition head.
Pre-heat & weld on transition head. Wrap wI insulation & slowly
cool weld. as per procedure. Weld on 45 degree 4" outlet fl any
top jobs & to check cement level. Back out hanger from landing
jt & inspect same. Finish rigging down all casing equip. Change
out bails. Cut & slip drilling line. Service top drive, drawworks &
crown. Clean out below drawworks & adjust band rollers.
Change gear oil & filters on top drive. Replace bleed off valve &
line to flow line. put new extension & clamp on cement line.
Change out upper boot on 16" drilling nipple. Change out fluid
hinge on blind ram door. Clean rig. Test choke manifold.
Perform derrick inspection. Work on 3512s wI Cat tech. Repair
off-driller side mule sheave.
Prepare tansition head.
Install 11 " x 5000# Split Speed head wI 11" x 5m casing head
on top of transition head. Test seal to 1000# for 10 min, OK.
N/U XIO flange & BOP stack.
Presure test BOP. LP 250#, HP 4000#. Test annular, LP 250#,
HP 3500#. Testing witnessed by Chuck Sheve wI AOGCC.
RID test equip. Install wear bushing.
P/U Drill pipe, RIH & stand back in derrick.
Continue PU 4" DP from pipe shed and stand back in derrick.
MU BHA #3. Orient motor. Load source. MU collars, Jars,
HWDP. Shallow hole test MWD. PU DP to put bit below TAM
collar & test same to 1000 psi - OK. MU Porcupine reamer with
one jt HWDP above & below.
PROD1 RIH PU DP from pipe shed. Test TAM collar to 1000 psi once
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
V-103
V-103
DRILL +COMPLETE
NABORS ALASKA DRILLING I
NABORS 9ES
Date· From-to 'Hours Task Code ' NPT Phase
9/25/2002 09:45 - 10:15 0.50 CEMT P SURF
10:15-11:15 1.00 CEMT P SURF
11: 15 - 11 :30 0.25 CEMT P SURF
11 :30 - 12:30
1.00 CEMT P
12:30 - 14:00 1.50 CEMT N STUC SURF
14:00 - 16:00 2.00 WHSUR N STUC SURF
16:00 - 20:30 4.50 WHSUR N STUC SURF
20:30 - 22:00 1.50 WHSUR N STUC SURF
22:00 - 00:00 2.00 WHSUR N STUC SURF
9/26/2002 00:00 - 15:00 15.00 WHSUR N STUC SURF
15:00 - 15:30 0.50 WHSUR N STUC SURF
15:30 - 16:30 1.00 WHSUR P SURF
16:30 - 18:30 2.00 BOPSURP SURF
18:30 - 21 :30 3.00 BOPSUR P SURF
21 :30 - 22:00 0.50 BOPSURP SURF
22:00 - 00:00 2.00 DRILL P PROD1
9/27/2002 00:00 - 05:30 5.50 DRILL P PROD1
05:30 - 09:30 4.00 DRILL P PROD1
09:30 - 12:30
3.00 DRILL P
Start: 9/22/2002
Rig Release: 10/7/2002
Rig Number: 9ES
Spud Date: 9/23/2002
End: 10/7/2002
Déscri phon of OþeratiÒr1S',
Printed: 10/14/2002 9:47:19AM
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
Date
9/27/2002
9/28/2002
9/29/2002
9/30/2002
)
)
V-103
V-103
DRILL +COMPLETE
NABORS ALASKA DRILLING I
NABORS 9ES
'From-To HöursTask' Code NPT Phase.
09:30 - 12:30
12:30 - 13:00
13:00 - 15:00
15:00 - 16:00
16:00 - 16:30
16:30 - 18:00
18:00 - 18:30
18:30 - 00:00
00:00 - 09:00
09:00 - 09:30
09:30 - 10:00
10:00 - 13:30
13:30 - 14:00
14:00 - 15:00
15:00 - 15:30
15:30 - 16:30
16:30 - 00:00
00:00 - 02:30
02:30 - 04:00
04:00 - 00:00
00:00 - 12:00
3.00 DRILL P
0.50 DRILL P
PROD1
PROD1
2.00 DRILL P
PROD1
1.00 DRILL P
PROD1
0.50 DRILL P
1.50 DRILL P
PROD1
PROD1
0.50 DRILL P
5.50 DRILL P
PROD1
PROD1
9.00 DRILL P
PROD1
0.50 DRILL P
0.50 DRILL P
3.50 DRILL P
PROD1
PROD1
PROD1
0.50 DRILL P
PROD1
1.00 DRILL P
0.50 DRILL P
1.00 DRILL P
PROD1
PROD1
PROD1
7.50 DRILL P
PROD1
2.50 DRILL P
PROD1
1.50 DRILL P
PROD1
20.00 DRILL P
PROD1
12.00 DRILL P
PROD1
Page30f7,
Start: 9/22/2002
Rig Release: 1 0/7/2002
Rig Number: 9ES
Spud Date: 9/23/2002
End: 10/7/2002
Description ·'ofQperations
porcupine reamer below same. Continue RIH PU singles.
Test 9 5/8" casing to 3500 psi for 30 min, lost 20 psi only. Test
good.
Wash down & tag float collar @ 3464'. Drill out shoe track. Tag
shoe @ 3551'. Clean out rat hole to 3570' & drill 20 'of new
hole to 3590'.525 gpm, 60 rpm, 2100 psi, torq 5k.
Displace hole to 9.7 ppg new LSND mud @ 10 bpm & 1700
psi..
Conduct LOT to 13.4 ppg EMW.
Obtain initial benchmark ECD readings wi PWD tool, 10.26 ppg
EMW. Con't to directionally drill from 3590 to 3960'.230 spm,
590 gpm, 2400 psi on, 2010 psi off, 80 rpm,6-7k torq on, 4k
torq off, 14-25k WOB.
Circulate & pump sweep to reduce 11.1 ECD.
Directionally drill from 3960 to 4614'. From 3960 to 4614'
circulate to reduce ECDs after every stand. P/U 115K, S/O
74K, ROT 90K. 233 spm, 590 gpm, 2420 psi on, 2010 psi off,
80 rpm, 6-8k torq on, 4.3k torq off, 15-25k WOB. AST .11 hrs,
ART 1.58 hrs.
Directionally drill from 4614 to 6014'. P/U 136K, S/O 75K, ROT
98K. 240 spm, 600 gpm, 3055 psi, torq on 7-9k, torq off 5-6k.
WOB 20-25k.Calc. ECD 10.25, Act. ECD 10.66. ART 2.81,
AST .1. Back ream each stand. Pump Lo-Hi vis sweep every
200'.
Circulate sweep & clean hole. Reduce ECDs, 10.55.
POOH to 5734', pulled tight. P/U 140k, S/O 75k.
Back ream from 5734 to 4800'.590 gpm, 2500 psi, 100rpm,
torq 7-11 k, ROT 90k. Slow down pumps as neccessary to stay
within ECD limits.
Circulate Lo-Hi sweep around wI hole opener inside casing
shoe.
Con't to pull dry to shoe wi bit. P/U 115k, S/O 65k.
Service top drive.
TIH to 5920'. M/U top drive & ream last stand to bottom @
6014'. Hole looked good on trip in.
Directionally drill from 6014 to 7227'. P/U 143k, S/O 83k, ROT
108k. 235 spm, 590 gpm, 3200 psi on, 2800 psi off, 80 rpm,
torq on 7-9k, torq off7k. WOB 10-25k. ART 2.86, AST O. Back
ream every stand. Pump Lo-Hi vis sweep every 200'.
Directionally drill from 7227 to 7787'. P/U 151 k, S/O 56k, ROT
112k. torq on 9-12k, torq off 8-9k, 240 spm, 600 gpm, 3340 psi.
AST .11, ART 1.42.
Circulate to reduce ECD. Calc ECD 10.32. ECD 11.20 before
circ sweep & ECD 10.80 after sweep.
Directionally drill from 7787 to 9750'. P/U 163k, SIO 98k, ROT
125k. torq on 8-10k, torq off 7.7k. 585 gpm, 4000 psi on, 3600
psi off, 100 rpm. Calc ECD 10.63, Act. ECD 11.13. Back ream
each stand & pump hi-vis sweep every 200'. AST 1.31, ART
9.85. Started adding "spike fluid" at approx 9200' MD to raise
MW to 10 ppg.
Drill ahead to 10496' MD. Up 177K. Dn 11 OK. Rot 137K. 550
GPM @ 4050 psi.Torq off 7k, Torq on 10-11k, 240spm,
600gpm, 4040 psi on. Back ream every stand & pump Hi-vis
Printed: 10/14/2002 9:47:19 AM
)
')
BPEXPLORATION
OpèratiionsS urnrnary .,Report
Page4of7
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
V-103
V-103
DRILL +COMPLETE
NABORS ALASKA DRILLING I
NABORS 9ES
Start: 9/22/2002
Rig Release: 10/7/2002
Rig Number: 9ES
Spud Date: 9/23/2002
End: 10/7/2002
Date From - To Hours Task Code NPT Phase Description of Operations
9/30/2002 00:00 - 12:00 12.00 DRILL P PROD1 sweep every 200'. AST 6.35 hrs, ART 2.08 hrs.
12:00 - 13:00 1.00 DRILL P PROD1 Circ hole clean.
13:00 - 16:30 3.50 DRILL P PROD1 Monitor well. Short trip from 10495 to 9936'. P/U 195k, SIO
80k. Had 25k overpull from 10122 to 9936'. Work thru tight
spots, OK. Cont POH to 5548'.
16:30 - 18:30 2.00 DRILL P PROD1 TIH to 10402'. M/U top drive & ream last stand to bottom @
10495'.
18:30 - 20:30 2.00 DRILL P PROD1 Circulate bottoms up to clean hole & to reduce ECDs. Calc
ECD 10.63, Act ECD 10.86 after circulating. Getting thick,
heavy mud back when circ. Weight 11 ppg and high vis. Poss
wallcake from trip and some gas entrained in it.
20:30 - 00:00 3.50 DRILL P PROD1 Directionally drill from 10495 to 10805'. Back ream every stand
& circ hi-vis sweep every 200'. P/U 195k, SIO 106k, ROT 144k.
Torq off 9.5k, Torq on 11-132k. 212 spm, 530 gpm, 4200 psi
on, 100 rpm. ART .6 hrs, AST 1.12 hrs.
10/1/2002 00:00 - 06:15 6.25 DRILL P PROD1 Drill to TD at 11560' MD. 220K up. 120K dn. 157K rot.
06:15 - 07:30 1.25 DRILL P PROD1 Circ sweep around. Condition mud and hole for check trip to
shoe. ECD 10.9 ppg vs 10~6 ppg calc.
07:30 - 12:00 4.50 DRILL P PROD1 Monitor well. POH to 4775'. No circ or backreaming. Porcupine
reamer just outside shoe.
12:00 - 12:30 0.50 DRILL P PROD1 Break circ & stage up pumps. CBU at 540 gpm to clear
cuttings past porcupine before entering shoe - OK.
12:30 - 14:00 1.50 DRILL P PROD1 Cont POH to shoe. Started pulling 20-25K over and swabbing
at 4000'. Work pipe. Break circ and backream 5 stds to shoe.
14:00 - 14:30 0.50 DRILL P PROD1 Circ at shoe. Pump ECD's down 10.8 ppg act vs 10.6 ppg calc.
Seeing evidence of hydrates breaking out of mud at flowline.
Circ to clean up.
14:30 - 15:30 1.00 DRILL P PROD1 Cut drilling line. Inspect drawworks.
15:30 - 16:30 1.00 DRILL P PROD1 Service top drive, crown.
16:30 - 22:00 5.50 DRILL P PROD1 RH to bottom. break circ & move mud for 15 min at 5550',
7510',9470'. Took wt from 3770-4000' - 20-25klbs.
22:00 - 00:00 2.00 DRILL P PROD1 Circ hole clean. Pump ECD's down. Got significant amt cutting
from bottoms up. Cont circ & cond hole.
10/2/2002 00:00 - 01 :30 1.50 DRILL P PROD1 Cont circ & cond hole for casing. Spot casing running pill from
TD to 8000'.
01 :30 - 03:30 2.00 DRILL P PROD1 POH to 8100'. Work thru tight spot 11150-11000' - OK.
03:30 - 04:00 0.50 DRILL P PROD1 Spot SteelSeal pill 8100-3500'.
04:00 - 07:00 3.00 DRILL P PROD1 Cont POH to BHA - no problems.
07:00 - 08:30 1.50 DRILL P PROD1 Rack back HWDP. Unload source. LD BHA.
08:30 - 09:30 1.00 CASE P CaMP Clear & clean floor.
09:30 - 12:30 3.00 CASE P CaMP Pull wear ring. Flush BOPE. Change top pipe rams to 7" casing
rams. Test door seals to 3500 psi. Make dummy run with
casing hanger on landing jt.
12:30 - 14:00 1.50 CASE P CaMP RU Franks casing tool and casing equipment.
14:00 - 14:15 0.25 CASE P CaMP PJSM for running casing.
14:15 - 21 :00 6.75 CASE P CaMP MU shoe joint and float collar. Check floats, OK. RIH wI 7",
26#, L-80, BTCM casing. Break circulation every 10 joints.
21 :00 - 21 :30 0.50 CASE P CaMP Circulate 1.5 times annular volume at shoe, 4 bpm, 300 psi.
PU=108K, SO=80K. Full returns.
21 :30 - 00:00 2.50 CASE P CaMP Continue running casing into open hole. Fill every joint, break
circulation every 5 joints, circulate for 15 minutes every 15
joints, and CBU every 30 joints. Run casing at 1 minute per
joint and monitor returns.
Printed: 10/14/2002 9:47:19AM
)
)
f3P EX,PLORATION
OperationsSummaryRE!Port
. Pé3ge50f 7
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
V-103
V-103
DRILL +COMPLETE
NABORS ALASKA DRILLING I
NABORS 9ES
Start: 9/22/2002
Rig Release: 10/7/2002
Rig Number: 9ES
Spud Date: 9/23/2002
End: 10/7/2002
Date From.. To HöÜrs Task Code NPT Phase ,Déscri ption of Operations
10/3/2002 00:00 - 12:00 12.00 CASE P COMP Continue to run 7" casing. Started pushing mud away at
5,674'. Slow running speed to 10 ftImin and increase
circulation frequency due to mud losses. Totallosses=25 bbls.
12:00 - 13:00 1.00 CASE P COMP Circulate bottoms up. Stage pumps up to 5 bpm, 615 psi. No
losses.
13:00 - 17:00 4.00 CASE P COMP Continue to run casing to 9,714' at 10 ft/min. Lost 13 bbls.
17:00 - 18:00 1.00 CASE P COMP CBU at 5 bpm, 810 psi. No losses.
18:00 - 21 :30 3.50 CASE P COMP Continue to run casing to 10,949' at 10ft/min. Lost 5 bbls.
21 :30 - 22:30 1.00 CASE P COMP CBU at 5 bpm, 885 psi. No losses.
22:30 - 00:00 1.50 CASE P COMP Run casing to 11,522'. MU landing joint and hanger. Land
casing with shoe at 11,549'. Lost 2 bbls from 10,949' to
11,549'.
10/4/2002 00:00 - 00:30 0.50 CASE P COMP Rig down fill up tool and blow down top drive. Rig up
cementing head and lines.
00:30 - 03:30 3.00 CEMT P COMP Circulate and reciprocate casing. Bring circulating rate up
slowly to 7 bpm with 950 psi. Hold PJSM with cementers and
rig crew.
03:30 - 07:00 3.50 CEMT P COMP Pump 5 bbl water. Test cement lines to 4000 psi. Pump 5 bbl
water and 35 bbl Alpha spacer weighted to 11.0 ppg at 5 bpm.
Drop bottom plug. Mix and pump 191 bbl (460 sx) Microlite
lead cement slurry at 12.5 ppg at 6 bpm followed with 39 bbl
(200 sx) Premium "G" tail slurry with latex batch mixed 15.8
ppg at 6 bpm. Wash up cement lines, drop top plug and
displace with 438 bbl mud at 7 bpm using the rig pumps. Plugs
did not bump.
07:00 - 08:30 1.50 CEMT P COMP Rig down cementing head and lines. Lay down landing joint.
08:30 - 09:00 0.50 WHSUR P COMP Pick up pack off running tool and install FMC pack off. Test to
5000 psi.
09:00 - 10:30 1.50 REMCM-P COMP Run 1" pipe in conductor and 9 5/8" annulus to 72'. Pick up to
65' and perform secondary cement job with 25 bbl (155 sx)
Permafrost "C" cement. Good cement to surface.
1 0:30 - 11 :30 1.00 REMCM-P COMP POH and lay down 1" pipe and wash same with water.
11 :30 - 13:30 2.00 BOPSUR P COMP Install test plug. Change top rams from 7" to 3 1/2" x 6"
variable, test door seals to 4000 psi, pull test plug and install
wear bushing.
13:30 - 14:30 1.00 DHEQP P COMP Make up BHA with bit and 7" casing scraper, pick up 9 x 4 3/4"
drill collars and jars.
14:30 -18:30 4.00 CLEAN P COMP RIH with bit and scraper. Tag up on cement plugs at 11440'
18:30 - 20:00 1.50 CLEAN P COMP Circulate and stage pumps up to 330 gpm 3013 psi. Test
casing to 4000 psi for 10 minutes prior to displacing to sea
water.
20:00 - 22:00 2.00 CLEAN P COMP Displace mud in well with sea water at 360 gpm with 1640 psi.
Reciprocate and rotate pipe.
22:00 - 23:00 1.00 CLEAN P COMP Test casing to 4000 psi for 30 minutes.
23:00 - 00:00 1.00 DHEQP P COMP POH bit and casing scraper.
1 0/5/2002 00:00 - 01 :30 1.50 DHEQP P COMP POH with bit and casing scraper to 8370'. SLM. Stand 4" drill
pipe in derrick.
01 :30 - 02:00 0.50 DHEQP P COMP Service top drive and blocks.
02:00 - 03:00 1.00 DHEQP P COMP Slip and cut 50' drilling line.
03:00 - 08:00 5.00 DHEQP P COMP POH. Lay down 4" drill pipe.
08:00 - 09:00 1.00 DHEQP P COMP POH. Stand back HWDP and lay down 9 drill collars, jars, bit
and scraper.
09:00 - 10:00 1.00 EVAL P COMP Hold PJSM with logging and rig crews. Rig up to run US IT log.
Printed: 10/14/2002 9:47:19 AM
)
J
Page 6 of 7
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
V-103
V-103
DRILL +COMPLETE
NABORS ALASKA DRILLING I
NABORS 9ES
Start: 9/22/2002
Rig Release: 10/7/2002
Rig Number: 9ES
Spud Date: 9/23/2002
End: 10/7/2002
Date Frorn~Tö Code NPT Phåse Descti ptionof Oþerations
10/5/2002 10:00 - 19:30 9.50 EVAL P COMP Run USIT log from 3295' to 11415'
While logging: Inject 7.6 bbl drilling mud down 95/8" x 7" OA
with 2500 psi. EMW 18.0 ppg.
19:30 - 20:00 0.50 EVAL P COMP Rig down logging unit.
20:00 - 20:30 0.50 RUNCOI\.IP COMP Pull wear bushing. Make a dummy run with tubing hanger on
landing joint and lay down same.
20:30 - 22:00 1.50 RUNCOI\.IP COMP Rig up tongs and compensator to run 3 1/2" TCII tubing.
22:00 - 00:00 2.00 RUNCOI\.IP COMP Run 3 1/2" completion. Pick up completion tail pipe and
Packer. RIH with 3 1/2" TCII L-80 9.2# tubing, torque turn all
connections.
1 0/6/2002 00:00 - 13:30 13.50 RUNCOI\.IP COMP Run 3 1/2" completion TCII L-80 9.2# tubing, torque turn all
connections. Make up tubing hanger and land tubing with
WLEG at 10843'. Run in lock down screws.
Break down 9 5/8" x 7" annulus with 1710 psi. EMW 22.3 ppg.
Pumped 85 bbl of 10.0 ppg drilling mud down 9 5/8" x 7" outer
annulus at a final pumping rate of 3 bpm with 2575 psi.
Freeze protect outer annulus with 75 bbl of dead crude oil
pumped at 2.25 bpm with final pressure of 2750 psi.
13:30 - 15:30 2.00 RUNCOI\.IP COMP Rig up circulating lines. Reverse circulate 10 bbl clean sea
water with corrosion inhibitor and displaced with 274 bbl clean
sea water at 3 bpm with 330 psi.
15:30 - 16:30 1.00 RUNCOI\.IP COMP Drop 1 5/16" ball and rod. Ball not seating, circulate to attempt
to push on seat with no success. Call for slickline unit to run in
and chase ball & rod to RHC plug.
16:30 - 17:30 1.00 RUNCOI\.IP COMP Lay down landing joint. Install two way check.
17:30 - 19:30 2.00 BOPSURP COMP Remove riser, release turn buckles and nipple bown BOP.
19:30 - 21 :00 1.50 WHSUR P COMP Install seals, nipple up adaptor flange and 4 1/2" 5000 psi FMC
tree. Test to 5000 psi.
21 :00 - 21 :30 0.50 WHSUR P COMP Rig up lubricator. Pull two way check. Rig down lubricator.
21 :30 - 00:00 2.50 DHEQP N DPRB COMP PJSM with slick line and rig crews. Rig up slick line. Run in
with 2.6" blind box and bell guide with jars and sinker bars to
push ball and rod to RHC-M plug at 10831'.
1 0/7/2002 00:00 - 01 :30 1.50 DHEQP N DPRB COMP Run in with 2.6" blind box and bell guide with jars and sinker
bars on slick line. Push 1 5/16" ball and rod to RHC-M plug at
10831'. (WLM 10853')
01 :30 - 03:30 2.00 RUNCOI\.IP COMP PJSM prior to set packer and pressure test. Pressure up
tubing to 4200 psi and set permanent packer at 10785'. Hold
pressure for 30 minutes. Bleed tubing pressure to 2500 psi.
Pressure up 7" x 3 1/2" annulus to 4000 psi and hold for 30
minutes. Bleed annulus and tubing pressures to 0 psi.
Pressure up annulus to 3600 psi to shear DRC-1 valve in GLM
at 10705'.
03:30 - 04:30 1.00 RUNCOI\.IP COMP Reverse circulate 200 bbl 8.4 ppg clean sea water down
annulus at 4 bpm with 780 psi.
04:30 - 07:30 3.00 RUNCOI\.IP COMP PJSM with Hot Oil and rig crew prior to freeze protect. Test
Hot Oil lines to 3500 psi. Pump 270 bbl diesel at 80 deg F at
2.5 bpm to freeze protect well. Final circulating pressure 700
psi.
07:30 - 09:30 2.00 RUNCOI\.IP COMP Allow diesel to "U" tube across top of well.
Printed: 10/14/2002 9:47:19 AM
)
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
')
BP ~XPLQRATIO;N
OperatiQnsSumrnåry Report
V-103
V-103
DRILL +COMPLETE
NABORS ALASKA DRILLING I
NABORS 9ES
Start: 9/22/2002
Rig Release: 10/7/2002
Rig Number: 9ES
Spud Date: 9/23/2002
End: 10/7/2002
1 0/7/2002
09:30 - 11 :00
· Date Frorn-To Hours TaskCodè NPT Phase
11 :00 - 12:00
1.50 RUNCOIVP
1.00 WHSUR P
CaMP Rig up lubricator, install back pressure valve and test to 1000
psi.
CaMP Secure well prior to rig down.
Release rig at 12:00 noon 7 Oct 2002.
Top of cement in 20" conductor is 1" below 4" outlets.
Printed: 10/14/2002 9:47:19 AM
)
}
Well:
Field:
API:
Permit:
Date
V -1 03
Prudhoe Bay Field / Borealis Pool
50-029-23117 -00
202-186
Accept:
Spud:
Release:
Rig:
09/22/02
09/23/02
10/07/02
Nabors 9ES
POST RIG WORK
01/03/03
PULLED B&R FROM RHC PLUG @ 10834' SLM. PULLED DGLV'S FROM STA. # 2 & 3, AND RP GLV FROM
STA. # 1. SET LGLV'S IN STA. # 3 & 2. IN PROCESS OF SETTING SIO GLV IN STA. # 1.
01/04/03
PULL 3-1/2" RHC PLUG BODY @ 10,834' SLM. DRIFT TBG W/2.5" DG WrrEL & SB. TO 11,437' CORRECTED
TD. RETURNED WELL TO OPERATOR TO POP.
01/06/03
JEWELRY LOG I TEMP SURVEY. RIH - HEAD/AH38/3 WEIGHTS/PBMS-A = 22.3 FT X 1.6875" MAX OD.
CORRELATED TO SWS VISION DENSITY NEUTRON LOG DATED 1-0CT-2002. LOGGED TEMPERATURE
FROM SURFACE TO TD TAGGED AT 11440 FT MD, LOGGED JEWELRY UP. SHUT IN.
01/07/03
SHOOT IPERF INTERVALS 11028'-11022', 11016'-11008', 11000'-10958', WITH 2.5" HSD 12506 POWERFLOW
(BH) CHARGES @ 6 SPF (+1-10 DEG) ORIENTATION, TIE INTO SWS TEMP/JEWELRY LOG DATED 06-JAN-03
REFERENCED TO SWS VISION 23-SEP-03. DID NOT TAG TD. SHUT IN. HOT TO POP TO FOLLOW.
01/08/03
HOT OIL IA TO POP WELL. 5 BBLS OF METHANAL, 105 BBLS OF 190° F DIESEL, 22 BBLS OF 80° F
METHANAL PUMPED DOWN IA.
01/13/03
BRUSH & FLUSH; PUMPED 100 BBLS DEAD CRUDE @ 180° F + 10 BBLS DSL DOWN TBG TO ASSIST
SLlCKLlNE.
01/14/03
BRUSH & FLUSH TBG. PUMPED 190 BBLS DEAD CRUDE @ 180°F + 10 BBLS DSL TO ASSIST SLlCKLlNE.
PULL STA# 1 & 3. MITIA @ 3500 PSI; RIG UP TO lA, SL TO SET VALVE.
01/15/03
PULL OGLV FROM STA# 2. SET DGLV STA# 1 & 2. MITIA @ 3500 PSI; POSTPONE PUMPING DUE TO
DOWN HOLE PROBLEMS. RDMO.
01/16/03
MITIA @ 3500 PSI (PASSED). BLEED BACK TO 1000 PSI. LOADED IA W/ 300 BBLS DEAD CRUDE; SL SET
VALVE; PT IA W/6BBLS DSL. LOC TD (11 ,417'),WLM, LOC TT (10,836') WLM. RUN SBHPS WI DUAL MRT.
NOTIFY DSO OF WELL STATUS. WELL TO REMAIN SHUT IN.
01/22/03
FRAC'D KUPARUK C3/C4 PERFS 10958'-11028' WITH YF125LG SYSTEM AND 202.125K# OF 16/20 CL.
PUMPED JOB TO COMPLETION, INTENTIONALLY UNDERFLUSHING WITH 92 BBLS- (10 BBLS FREEZE
PROTECT IN TBG). PLACED 200.525K# PROP BEHIND PIPE LEAVING 1600# (2.6 BBLS) PROP IN THE
CASING, EST. TOS IF PACKED, 11350' WLM. MAX TREAT = 7123 PSI, AVG. TREAT = 6200 PSI, LOAD TO
RECOVER = 1483 BBLS, ALL ISO TOOL CUPS RECOVERED.
V-103, Post Drilling, Work suml.._.ì
Page 2
)
01/24/03
RIH WITH 2.25" JSN. TAG SAND TOP AT 11114' (86' OF RATHOLE.) PULL UP TO TT @ 10840'. POOH @ 80%
PUMPING 1% XS KCL (MAKE EXTRA PASSES ACROSS ALL JEWELRY). STAGE IN NEAT METH FREEZE
PROTECT TO 3000'. JOB COMPLETE - SLlCKLlNE TO SET GLV'S. SET 3-1/2 X CATCHER SUB @ 10773'
SLM.
01/25/03
PULL DGL V'S FROM STA'S 1,2,3. SET NEW GAS LIFT DESIGN IN STA'S # 1,2, & 3. PULL CATCHER SUB.
WELL LEFT SI.
01/26/03
PUMPED DOWN IA; 10 BBLS NEAT MEOH, 90 BBLS DIESEL @ 180°,20 BBLS NEAT MEOH.
ANADRILL
SCHLUMBERGER
Survey report
Client...................: BP Exploration (Alaska) Inc.
Field. . . . . . . . . . . . . . . . . . . .: Prudhoe Bay / Borealis
Well. . . . . . . . . . . . . . . . . . . . .: V-103
API number...............: 50-029-23117-00
Engineer.................: St. Amour
COUNTy:..................: Nabors 9ES
STATE: . . . . . . . . . . . . . . . . . . .: Alaska
----- Survey calculation methods-------------
Method for positions.....: Minimum curvature
Method for DLS.... .......: Mason & Taylor
----- Depth reference -----------------------
Permanent datum..........: Mean Sea Level
Depth reference..........: Driller's Pipe Tally
GL above permanent.......: 55.10 ft
KB above permanent.......: N/A
DF above permanent.......: 82.50 ft
----- Vertical section origin----------------
Latitude (+N/S-).........: 0.00 ft
Departure (+E/W-)........: 0.00 ft
----- Platform reference point---------------
Latitude (+N/S-).........: -999.25 ft
Departure (+E/W-)........: -999.25 ft
Azimuth from rotary table to target:
18.82 degrees
((c)2002 Anadrill IDEAL ID6_1C_10]
1-0ct-2002 09:53:48
Spud date. . . . . . . . . . . . . . . . :
Last survey date.... .....:
Total accepted surveys...:
MD of first survey.......:
MD of last survey........:
Page
1 of 6
23-Sep-02
01-0ct-02
125
0.00 ft
11560.00 ft
'-'
----- Geomagnetic data ----------------------
Magnetic model.... '" ....: BGGM version 2001
Magnetic date.... ........: 22-Sep-2002
Magnetic field strength..: 1149.65 HCNT
Magnetic dec (+E/W-). ....: 25.92 degrees
Magnetic dip... ..........: 80.76 degrees
----- MWD survey Reference
Reference G... ........ ...:
Reference H...... ........:
Reference Dip... .........:
Tolerance of G........ ...:
Tolerance of H.... ..... ..:
Tolerance of Dip. ...... ..:
Criteria ---------
1002.68 mGal
1149.65 HCNT
80.76 degrees
(+/-) 2.50 mGal
(+/-) 6.00 HCNT
(+/-) 0.45 degrees
----- Corrections ---------------------------
Magnetic dec (+E/W-) .....: 25.80 degrees
Grid convergence (+E/W-).: 0.00 degrees
Total az corr (+E/W-)....: 25.80 degrees
(Total az corr = magnetic dec - grid conv)
Sag applied (Y/N) ........: No degree: 0.00
-'
ANADRILL SCHLUMBERGER Survey Report
-------- ------
-------- ------
Seq Measured
# depth
(ft)
---
Incl
angle
(deg)
-------- ------
-------- ------
1
2
3
4
5
0.00
198.24
294.00
385.38
479.16
6
7
8
9
10
571.76
660.89
755.08
847.19
940.83
11
12
13
14
15
1035.14
1129.23
1220.17
1313.43
1407.38
16
17
18
19
20
1500.87
1593.35
1687.58
1781.38
1875.38
21
22
23
24
25
1967.63
2060.93
2154.88
2248.13
2335.78
26
27
28
29
30
2433.53
2528.53
2621.55
2714.50
2807.80
0.00
0.45
1.15
2.13
3.83
5.65
7.59
9.42
10.40
11.13
13.13
16.18
20.50
23.68
26.52
30.69
34.39
38.64
38.52
40.54
41.95
46.18
49.76
52.26
54.37
57.26
59.98
59.70
59.69
59.37
1-0ct-2002 09:53:48
------- ------ -------- -------- ---------------- ---------------
------- ------ -------- -------- ---------------- ---------------
Page
Azimuth
angle
(deg)
Course
length
(ft)
TVD
depth
(ft)
Vertical
section
(ft)
Displ
+N/S-
(ft)
Displ
+E/W-
(ft)
Total
displ
(ft)
At
Azim
(deg)
------- ------ -------- -------- ---------------- ---------------
------- ------ -------- -------- ---------------- ---------------
0.00
9.20
9.20
346.03
343.56
347.46
355.13
8.04
17.61
19.41
20.61
20.54
20.92
20.29
19.84
20.52
21.12
19.34
18.52
17.56
19.74
19.18
17.96
17.25
18.60
18.96
19.81
20.47
20.79
20.60
0.00
198.24
95.76
91.38
93.78
92.60
89.13
94.19
92.11
93.64
94.31
94.09
90.94
93.26
93.95
93.49
92.48
94.23
93.80
94.00
92.25
93.30
93.95
93.25
87.65
97.75
95.00
93.02
92.95
93.30
0.00
198.24
293.99
385.33
478.98
571.26
659.79
752.95
843.69
935.68
1027.88
1118.90
1205.20
1291.61
1376.68
1458.74
1536.68
1612.40
1685.73
1758.23
1827.59
1894.62
1957.51
2016.18
2068.54
2123.46
2172.92
2219.66
2266.56
2313.87
0.00
0.77
2.09
4.42
8.44
14.86
24.00
37.27
52.98
70.47
90.28
114.07
142.67
177.72
217.56
262.29
312.00
368.03
426.53
486.34
547.15
612.02
681.79
754.25
824.52
905.38
986.47
1066.87
1147.08
1227.45
0.00
0.77
2.09
4.64
9.34
16.75
26.90
40.74
56.12
72.71
91.32
113.60
140.35
173.18
210.62
252.61
299.09
351.70
407.03
463.92
521.53
582.70
648.85
717.93
784.80
861.34
937.84
1013.35
1088.45
1163.68
0.00
0.12
0.34
0.07
-1.23
-3.10
-4.55
-4.00
-0.43
5.13
11.93
20.29
30.43
42.75
56.42
71.87
89.56
108.90
127.88
146.40
165.86
187.46
209.66
231.57
253.21
279.25
306.17
333.86
362.14
390.55
0.00
0.78
2.12
4.64
9.42
17.04
27.28
40.93
56.13
72.89
92.09
115.40
143.61
178.38
218.04
262.64
312.22
368.18
426.65
486.47
547.27
612.11
681.88
754.35
824.63
905.48
986.55
1066.93
1147.11
1227.47
0.00
9.20
9.20
0.92
352.48
349.53
350.40
354.39
359.56
4.04
7.44
10.13
12.23
13.87
15.00
15.88
16.67
17.20
17.44
17.51
17.64
17.83
17.91
17.88
17.88
17.96
18.08
18.24
18.40
18.55
2 of 6
DLS
(deg/
100f)
0.00
0.23
0.73
1.27
1.82
1.99
2.39
2.80
2.08
0.86
2.14 '
3.24
4.75
3.42
3.03
4.47
4.02
4.65
0.56
2.25
2.18
4.55
3.93
2.75
2.71
2.97
2.96
0.68
0.30
0.39
------
-----
------
Srvy
tool
type
Tool
qual
type
------
------
TIP
MWD incl. only
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
~
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR-MSA
MWD_IFR_MSA
MWD_IF~MSA
MWD_IFR-MSA
MWD_IF~MSA
MWD_IFR_MSA
MWD_IF~MSA
MWD_IF~MSA
MWD_IF~MSA
MWD_IFR_MSA
MWD_IF~MSA
MWD_IFR_MSA
MWD_IFR_MSA
--
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
ANADRILL SCHLUMBERGER Survey Report
--------
--------
Seq Measured
# depth
(ft)
51
52
53
54
55
56
57
58
59
60
--------
--------
31
32
33
34
35
2900.39
2993.06
3086.95
3180.12
3274.80
36
37
38
39
40
3367.76
3460.83
3510.47
3608.05
3702.33
41
42
43
44
45
3794.98
3887.97
3981.44
4074.70
4167.71
46
47
48
49
50
4261.78
4354.91
4448.42
4541.71
4636.05
4729.79
4823.73
4917.36
5011.25
5104.87
5198.18
5291.51
5384.69
5478.12
5571.64
------
------
Incl
angle
{deg}
------
------
60.46
60.20
62.13
61.86
61.06
60.47
61.05
60.92
60.23
59.86
61.56
61.93
61.71
61.43
61.31
61.48
61.17
61.07
61.72
61.98
62.55
62.51
61.94
61.46
61.17
61.20
61.68
61.39
61.52
61.20
-------
-------
Azimuth
angle
{deg}
-------
-------
19.81
19.18
19.13
19.81
19.17
19.00
19.45
19.14
19.24
19.40
20.02
21.00
21.34
21.12
21.54
21.88
21.86
21.43
21.33
21.06
20.63
20.52
20.60
20.12
20.71
19.95
20.30
20.54
20.36
20.48
------
------
Course
length
(ft)
------
------
92.59
92.67
93.89
93.17
94.68
92.96
93.07
49.64
97.58
94.28
92.65
92.99
93.47
93.26
93.01
94.07
93.13
93.51
93.29
94.34
93.74
93.94
93.63
93.89
93.62
93.31
93.33
93.18
93.43
93.52
--------
--------
TVD
depth
{ft}
--------
--------
2360.28
2406.16
2451.44
2495.18
2540.42
2585.82
2631.28
2655.36
2703.30
2750.37
2795.70
2839.72
2883.86
2928.26
2972.83
3017.87
3062.55
3107.72
3152.38
3196.89
3240.51
3283.85
3327.48
3371.99
3416.93
3461.90
3506.52
3550.93
3595.58
3640.40
1-0ct-2002 09:53:48
-------- ----------------
-------- ----------------
vertical
section
(ft)
--------
--------
1307.54
1388.06
1470.30
1552.56
1635.72
1716.84
1798.05
1841.46
1926.45
2008.13
2088.92
2170.80
2253.12
2335.06
2416.62
2499.10
2580.69
2662.47
2744.29
2827.40
2910.32
2993.63
3076.43
3159.07
3241.17
3322.90
3404.85
3486.73
3568.77
3650.82
Displ
+N/S-
(ft)
Displ
+E/W-
(ft)
Page
---------------
---------------
Total
displ
(ft)
At
Azim
(deg)
---------------- ---------------
---------------- ---------------
1238.86
1314.76
1392.46
1470.01
1548.42
1625.08
1701.76
1742.73
1823.00
1900.09
1976.15
2052.87
2129.70
2206.15
2282.19
2358.92
2434.75
2510.85
2587.12
2664.68
2742.21
2820.25
2897.81
2975.31
3052.29
3128.95
3205.92
3282.68
3359.58
3436.50
418.22
445.09
472.08
499.50
527.25
553.77
580.51
594.86
622.80
649.82
677.08
705.77
735.53
765.23
794.92
825.47
855.91
886.11
915.97
946.04
975.56
1004.86
1033.95
1062.71
1091.36
1119.76
1147.97
1176.55
1205.22
1233.86
1307.55
1388.06
1470.30
1552.56
1635.72
1716.84
1798.05
1841.46
1926.45
2008.13
2088.93
2170.80
2253.14
2335.09
2416.67
2499.18
2580.81
2662.63
2744.48
2827.63
2910.58
2993.91
3076.75
3159.41
3241.53
3323.28
3405.25
3487.16
3569.23
3651.30
18.65
18.70
18.73
18.77
18.80
18.82
18.84
18.85
18.86
18.88
18.91
18.97
19.05
19.13
19.20
19.29
19.37
19.44
19.50
19.55
19.58
19.61
19.64
19.66
19.67
19.69
19.70
19.72
19.74
19.75
3 of 6
-----
DLS
(deg/
100f)
-----
1.39
0.65
2.06
0.71
1.03
0.65
0.75
0.61
0.71
0.42
1.93
1.01
0.40
0.36
0.42
0.37
0.33
0.42
0.70
0.37
0.73
0.11
0.61
0.68
0.63
0.71
0.61
0.38
0.22
0.36
-----
------
------
Srvy
tool
type
Tool
qual
type
-----
------
------
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
--
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
-'
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
ANADRILL SCHLUMBERGER Survey Report
--------
--------
Seq Measured
# depth
(ft)
76
77
78
79
80
81
82
83
84
85
86
87
88
89
90
------
------
Incl
angle
(deg)
-------
-------
Azimuth
angle
(deg)
------ --------
------ --------
Course
length
(ft)
TVD
depth
(ft)
1-0ct-2002 09:53:48
--------
--------
Vertical
section
(ft)
Page
---------------- ---------------
---------------- ---------------
Displ
+N/S-
(ft)
Displ
+E/W-
(ft)
Total
displ
(ft)
At
Azim
(deg)
-------- ------ ------- ------ -------- -------- ---------------- ---------------
-------- ------ ------- ------ -------- -------- ---------------- ---------------
61
62
63
64
65
5664.20
5757.39
5849.92
5943.89
6035.17
66
67
68
69
70
6128.67
6223.15
6316.48
6409.90
6503.28
71
72
73
74
75
6596.47
6690.04
6782.14
6874.94
6969.26
7061.97
7156.30
7250.81
7343.89
7437.54
7529.72
7623.99
7716.68
7811.96
7904.53
7997.33
8090.34
8184.39
8278.09
8371.09
61.16
60.71
61.00
61.00
61.13
61.66
61.23
60.92
61.10
61.10
60.91
61.46
61.48
61.36
61.22
61.42
61.26
60.49
59.90
60.09
60.15
60.58
59.99
60.03
60.55
60.74
61.04
60.41
60.41
61.56
20.09
20.47
18.54
17.58
17.88
17.65
18.14
18.51
18.32
18.49
19.12
19.12
18.94
18.83
19.33
19.13
19.14
18.66
18.29
18.57
18.63
18.95
18.82
18.86
18.33
18.01
17.92
17.65
17.66
17.99
92.56
93.19
92.53
93.97
91.28
93.50
94.48
93.33
93.42
93.38
93.19
93.57
92.10
92.80
94.32
92.71
94.33
94.51
93.08
93.65
92.18
94.27
92.69
95.28
92.57
92.80
93.01
94.05
93.70
93.00
3685.02
3730.29
3775.36
3820.92
3865.08
3909.85
3955.01
4000.15
4045.43
4090.55
4135.73
4180.83
4224.82
4269.21
4314.52
4359.01
4404.25
4450.25
4496.53
4543.36
4589.29
4635.90
4681.85
4729.47
4775.35
4820.84
4866.09
4912.08
4958.35
5003.46
3731.89
3813.31
3894.12
3976.30
4056.17
4138.24
4221.22
4302.90
4384.61
4466.36
4547.87
4629.85
4710.77
4792.26
4874.98
4956.32
5039.09
5121.65
5202.41
5283.50
5363.43
5445.37
5525.87
5608.39
5688.79
5769.67
5850.92
5932.95
6014.41
6095.72
3512.57
3588.97
3665.15
3743.28
3819.38
3897.55
3976.52
4054.07
4131.60
4209.16
4286.32
4363.78
4440.28
4517.38
4595.56
4672.36
4750.56
4828.67
4905.27
4982.20
5057.96
5135.53
5211.69
5289.80
5366.00
5442.85
5520.15
5598.27
5675.91
5753.33
1261.97
1290.21
1317.19
1342.66
1366.99
1392.04
1417.54
1443.22
1469.03
1494.84
1521.12
1547.97
1574.35
1600.73
1627.77
1654.56
1681.69
1708.44
1734.03
1759.67
1785.16
1811.56
1837.61
1864.26
1889.90
1915.12
1940.18
1965.24
1989.95
2014.85
3732.39
3813.84
3894.65
3976.80
4056.64
4138.68
4221.63
4303.29
4384.99
4466.72
4548.23
4630.21
4711.12
4792.61
4875.33
4956.66
5039.44
5121.99
5202.74
5283.82
5363.74
5445.67
5526.17
5608.69
5689.08
5769.95
5851.19
5933.19
6014.64
6095.94
19.76
19.77
19.77
19.73
19.69
19.65
19.62
19.60
19.57
19.55
19.54
19.53
19.52
19.51
19.50
19.50
19.49
19.48
19.47
19.45
19.44
19.43
19.42
19.41
19.40
19.38
19.37
19.34
19.32
19.30
4 of 6
----- -----
------
------
DLS
(deg/
100f)
0.37
0.60
1.85
0.89
0.32
0.61
0.64
0.48
0.26
0.16
0.63
0.59
0.17
0.17
0.49
0.29
0.17
0.93
0.73
0.34
0.09
0.54
0.65
0.06
0.75
0.36
0.33
0.72
0.01
1.27
Srvy
tool
type
Tool
qual
type
------
------
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
~'-
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
-~-'
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
ANADRILL SCHLUMBERGER Survey Report
--------
--------
Seq Measured
# depth
(ft)
96
97
98
99
100
101
102
103
104
105
106
107
108
109
110
111
112
113
114
115
116
117
118
119
120
------
------
Incl
angle
(deg)
-------
-------
Azimuth
angle
(deg)
------
------
Course
length
(ft)
--------
--------
TVD
depth
(ft)
1-0ct-2002 09:53:48
Page
-------- ---------------- ---------------
-------- ---------------- ---------------
Vertical
section
(ft)
Displ
+N/S-
(ft)
Displ
+E/W-
(ft)
Total
displ
(ft)
At
Azim
(deg)
-------- ------ ------- ------ -------- -------- ---------------- ---------------
-------- ------ ------- ------ -------- -------- ---------------- ---------------
91
92
93
94
95
8464.47
8558.21
8650.85
8743.04
8836.56
8930.96
9023.92
9117.42
9211.23
9304.12
9397.65
9491.83
9584.75
9680.17
9772.68
9866.07
9959.90
10052.52
10146.01
10239.35
10331.79
10424.23
10516.37
10610.46
10703.46
10796.91
10891.06
10984.41
11077.81
11171.52
61.79
61.72
61.63
61.54
61.01
60.93
60.65
60.25
59.85
59.46
59.43
59.07
57.62
56.63
53.43
51.19
49.66
44.97
42.20
39.65
37.15
34.47
32.33
29.33
26.79
25.15
21.90
19.50
19.67
19.56
17.74
17.22
16.84
17.01
17.01
16.64
16.59
16.66
16.38
16.33
16.08
15.85
15.99
15.28
14.97
16.66
16.62
16.65
18.95
19.64
19.08
18.64
20.44
21.11
19.93
20.57
20.82
21.18
19.84
20.44
93.38
93.74
92.64
92.19
93.52
94.40
92.96
93.50
93.81
92.89
93.53
94.18
92.92
95.42
92.51
93.39
93.83
92.62
93.49
93.34
92.44
92.44
92.14
94.09
93.00
93.45
94.15
93.35
93.40
93.71
5047.76
5092.13
5136.08
5179.95
5224.90
5270.71
5316.07
5362.18
5409.02
5455.95
5503.49
5551.65
5600.41
5652.20
5705.22
5762.32
5822.09
5884.87
5952.59
6023.11
6095.54
6170.50
6247.42
6328.21
6410.27
6494.28
6580.60
6667.91
6755.91
6844.18
6177.91
6260.47
6341.97
6423.01
6504.98
6587.47
6668.55
6749.83
6831.05
6911.14
6991.60
7072.43
7151.43
7231.44
7307.08
7380.87
7453.14
7521.15
7585.58
7646.72
7704.13
7758.21
7808.92
7857.11
7900.83
7941.74
7979.29
8012.26
8043.56
8075.00
5831.57
5910.33
5988.30
6065.88
6144.30
6223.31
6301.06
6378.99
6456.92
6533.84
6611.18
6689.00
6765.06
6842.23
6915.40
6986.50
7055.80
7121.01
7182.38
7240.08
7294.25
7345.43
7393.23
7438.31
7479.27
7517.66
7552.81
7583.62
7612.94
7642.48
2040.07
2064.87
2088.75
2112.36
2136.35
2160.24
2183.44
2206.71
2229.83
2252.40
2274.88
2297.14
2318.83
2340.44
2360.22
2380.34
2401.05
2420.53
2440.20
2460.39
2479.43
2496.92
2513.86
2530.95
2546.30
2560.46
2573.73
2585.55
2596.52
2607.35
6178.11
6260.65
6342.13
6423.15
6505.11
6587.58
6668.64
6749.90
6831.10
6911.18
6991.63
7072.45
7151.44
7231.44
7307.08
7380.87
7453.14
7521.16
7585.59
7646.72
7704.13
7758.22
7808.92
7857.11
7900.83
7941.74
7979.29
8012.26
8043.56
8075.01
19.28
19.26
19.23
19.20
19.17
19.14
19.11
19.08
19.05
19.02
18.99
18.95
18.92
18.88
18.84
18.81
18.79
18.77
18.77
18.77
18.77
18.77
18.78
18.79
18.80
18.81
18.82
18.83
18.83
18.84
5 of 6
----- -----
------
------
DLS
(degl
100f)
0.34
0.49
0.37
0.19
0.57
0.35
0.30
0.43
0.50
0.42
0.23
0.44
1.57
1.21
3.47
2.79
1.63
5.06
3.41
2.77
2.73
2.91
2.56
3.21
2.80
1.78
3.45
2.57
0.51
0.24
Srvy
tool
type
Tool
qual
type
------
------
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
'-
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD~IFR_MSA
MWD_IFR_MSA
----
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
ANADRILL SCHLUMBERGER Survey Report
--------
------
------
---
--------
Seq Measured
# depth
(ft)
Incl
angle
(deg)
-------
-------
Azimuth
angle
(deg)
------
------
Course
length
(ft)
1-0ct-2002 09:53:48
-------- -------- ----------------
-------- -------- ----------------
TVD
depth
(ft)
Vertical
section
(ft)
Displ
+N/S-
(ft)
Displ
+E/W-
(ft)
Page
---------------
---------------
Total
displ
(ft)
At
Azirn
(deg)
-------- ------ ------- ------ -------- -------- ---------------- ---------------
-------- ------ ------- ------ -------- -------- ---------------- ---------------
121 11264.56 18.49
122 11357.47 16.88
123 11450.63 15.65
124 11488.90 15.51
Projected to TD:
125 11560.00 15.51
19.41
17.36
18.15
17.99
17.99
93.04
92.91
93.16
38.27
71.10
[(c)2002 Anadrill IDEAL ID6_1C_I0J
6932.14
7020.66
7110.09
7146.95
7215.46
8105.33
8133.55
8159.63
8169.91
8188.92
7670.99
7697.76
7722.61
7732.38
7750.46
2617.69
2626.62
2634.57
2637.75
2643.63
8105.33
8133.55
8159.63
8169.91
8188.92
18.84
18.84
18.84
18.84
18.83
6 of 6
----- -----
DLS
(deg/
100f)
1.21
1.86
1.34
0.38
0.00
Srvy
tool
type
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD
------
------
Tool
qual
type
------
------
'~
~/
V-103 Final Surveys Schlulberger
Survey Report - Geodetic
Report Date: 1-0ct-02 Survey / DLS Computation Method: Minimum Curvature I Lubinski
Client: BP Exploration Alaska Vertical Section Azimuth: 0.0000
Field: Prudhoe Bay Unit· WOA (Drill Pads) Vertical Section Origin: N 0.000 m, E 0.000 m
Structure / Slot: V-Pad I V-1 03 TVD Reference Datum: KB
Well: V-103 TVD Reference Elevation: 25.146 m relative to MSL
Borehole: V-103 Sea Bed / Ground Level Elevation: 16.764 m relative to MSL
UWIIAPI#: Magnetic Declination: +25.7890
Survey Name / Date: V-103 Final Survey I October 1, 2002 Total Field Strength: 57505.594 nT
Tort / AHD / DDI/ ERD ratio: 148.9870/8196.12 m/6.807/1.136 Magnetic Dip: 80.7700 -
Grid Coordinate System: NAD27 Alaska State Planes, Zone 4, US Fee1 Declination Date: October 08, 2002
Location LatILong: N 701941.227, W 1491552.454 Magnetic Declination Model: BGGM 2002
Location Grid NlE VfX: N 5970126.970 ftUS, E 590680.230 ftU~ North Reference: True North
Grid Convergence Angle: +0.692511160 Total Corr Mag North -> True North: +25.7890
Grid Scale Factor: 0.99990934 Local Coordinates Referenced To: Well Head
Grid Coordinates Geographic Coordinates
Station ID MD Incl Azim TVD vSec NI-S EJ-W DLS Northing Easting Latitude Longitude
(m) (0) (0) (m) (m) (m) (m) (o/30m) (ftUS) (ftUS)
0.00 0.00 0.0 0.00 0.00 0.00 0.00 5970126.97 590680.23 N 70 1941.227 W 149 1552.454
198.24 0.45 9.2 198.24 0.77 0.77 0.12 0.07 5970129.50 590680.61 N 70 19 41.251 W 149 15 52.442
294.00 1.15 9.2 293.99 2.09 2.09 0.34 0.22 5970133.83 590681 .26 N 70 19 41.294 W 149 15 52.421
385.38 2.13 346.0 385.33 4.64 4.64 0.07 0.38 5970142.20 590680.29 N 70 1941.376 W 149 1552.446
479.16 3.83 343.6 478.98 9.34 9.34 -1.23 0.55 5970157.55 590675.82 N 701941.528 W 1491552.572
571.76 5.65 347.5 571.26 16.75 16.75 -3.10 0.60 5970181.80 590669.41 N 701941.767 W 14915 52.750
660.89 7.59 355.1 659.79 26.90 26.90 -4.55 0.72 5970215.04 590664.24. N 70 19 42.095 W 149 15 52.889
755.08 9.42 8.0 752.95 40.74 40.74 -4.00 0.84 5970260.44 590665.49, N 70 19 42.541 W 149 15 52.837
847.19 10.40 17.6 843.69 56.12 56.12 -0.43 0.62 5970311.06 590676.59 N 70 19 43.038 W 149 15 52.495 -
940.83 11.13 19.4 935.68 72.71 72.71 5.13 0.26 5970365.67 590694.18 N 701943.573 W 1491551.962
1035.14 13.13 20.6 1027.88 91.32 91.32 11.93 0.64 5970426.99 590715.73 N 701944.173 W 1491551.311
1129.23 16.18 20.5 1118.90 113.60 113.60 20.29 0.97 5970500.42 590742.28 N 70 1944.892 W 149 1550.510
1220.17 20.50 20.9 1205.20 140.35 140.35 30.43 1.43 5970588.58 590774.47 N 701945.755 W 149 1549.539
1313.43 23.68 20.3 1291.61 173.18 173.18 42.75 1.03 5970696.75 590813.61 N 701946.815 W 149 1548.358
1407.38 26.52 19.8 1376.68 210.62 210.62 56.42 0.91 5970820.09 590856.95 N 70 1948.022 W 149 15 47.049
1500.87 30.69 20.5 1458.74 252.61 252.61 71.87 1.34 5970958.46 590905.98 N 70 19 49.378 W 149 15 45.569
1593.35 34.39 21.1 1536.69 299.09 299.09 89.56 1.20 5971111.64 590962.16 N 701950.877 W 1491543.874
1687.58 38.64 19.3 1612.40 351 .70 351.70 108.90 1.39 5971284.98 591023.52 N 70 19 52.575 W 149 15 42.022
V-103 ASP Final Surveys.xls
Page 1 of 4
10/21/2002-2:20 PM
1781.38 38.52 18.5 1685.73 407.03 407.03 127.88 0.17 5971467.23 591083.58 N 701954.360 W 149 1540.203
1875.38 40.54 17.6 1758.23 463.92 463.92 146.40 0.67 5971654.57 591142.06 N 70 19 56.196 W 149 1538.429
1967.63 41.95 19.7 1827.59 521.53 521.53 165.86 0.65 5971844.32 591203.61 N 70 19 58.054 W 149 15 36.565
2060.93 46.18 19.2 1894.62 582.70 582.70 187.46 1.37 5972045.84 591272.05 N 70 20 0.028 W 149 15 34.495
2154.88 49.76 18.0 1957.51 648.85 648.85 209.66 1.18 5972263.69 591342.25 N 70202.162 W 149 1532.367
2248.13 52.26 17.2 2016.18 717.93 717.93 231.57 0.82 5972491.17 591411.38 N 70 20 4.391 W 149 15 30.267
2335.78 54.37 18.6 2068.54 784.80 784.80 253.21 0.81 5972711.37 591479.72 N 70206.549 W 149 1528.193
2433.53 57.26 19.0 2123.46 861.34 861.34 279.25 0.89 5972963.50 591562.09 N 70209.019 W 149 1525.698
2528.53 59.98 19.8 2172.92 937.84 937.84 306.17 0.89 5973215.50 591647.38 N 70 20 11 .487 W 149 15 23.117
2621.55 59.70 20.5 2219.66 1013.35 1013.35 333.86 0.21 5973464.29 591735.22 N 70 20 13.923 W 149 15 20.463
2714.50 59.69 20.8 2266.56 1088.45 1088.45 362.14 0.09 5973711.77 591824.99 N 702016.346 W 149 15 17.753
2807.80 59.37 20.6 2313.87 1163.68 1163.68 390.55 0.12 5973959.66 591915.23 N 702018.773 W 149 15 15.028
-"
2900.39 60.46 19.8 2360.28 1238.86 1238.86 418.22 0.42 5974207.38 592003.00 N 70 20 21.199 W 149 15 12.376
2993.06 60.20 19.2 2406.16 1314.76 1314.76 445.09 0.20 5974457.43 592088.14 N 702023.648 W 149 159.799
3086.95 62.13 19.1 2451.44 1392.46 1392.46 472.08 0.62 5974713.35 592173.58 N 702026.155 W 149 157.211
3180.12 61.86 19.8 2495.18 1470.01 1470.01 499.50 0.21 5974968.85 592260.44 N 70 20 28.657 W 149154.582
3274.80 61.06 19.2 2540.42 1548.42 1548.42 527.25 0.31 5975227.15 592348.37 N 702031.187 W 149 15 1.921
3367.76 60.47 19.0 2585.82 1625.08 1625.08 553.77 0.20 5975479.67 592432.34 N 70 20 33.660 W 149 14 59.377
3460.83 61.05 19.5 2631.28 1701.76 1701.76 580.51 0.23 5975732.26 592517.02 N 702036.134 W 149 1456.812
3510.47 60.92 19.1 2655.36 1742.73 1742.73 594.86 0.18 5975867.23 592562.44 N 702037.456 W 149 1455.436
3608.05 60.23 19.2 2703.30 1823.00 1823.00 622.80 0.21 5976131.64 592650.90 N 702040.046 W 1491452.756
3702.33 59.86 19.4 2750.37 1900.09 1900.09 649.82 0.13 5976385.58 592736.50 N 702042.533 W 1491450.164
3794.98 61.56 20.0 2795.70 1976.15 1976.15 677.07 0.58 ',5976636.18 592822.88 N 702044.987 W 149 1447.549
3887.97 61.93 21.0 2839.72 2052.87 2052.87 705.77 0.30 5976888.97 592913.98 N 702047.462 W 149 1444.796
3981 .44 61.71 21.3 2883.86 2129.70 2129.70 735.53 0.12 5977142.18 593008.54 N 70 20 49.941 W 149 1441.941
4074.70 61 .43 21.1 2928.26 2206.15 2206.15 765.23 0.11 5977394.12 593102.93 N 70 20 52.407 W 149 14 39.091
4167.71 61.31 21.5 2972.83 2282.19 2282.19 794.92 0.13 5977644.75 593197.32 N 70 20 54.861 W 149 14 36.242
_/
4261.78 61 .48 21.9 3017.87 2358.92 2358.92 825.47 0.11 5977897.66 593294.49 N 702057.336 W 149 1433.310
4354.91 61.17 21.9 3062.55 2434.75 2434.75 855.91 0.10 5978147.60 593391.32 N 70 20 59.783 W 1491430.390
4448.42 61.07 21.4 3107.72 2510.85 2510.85 886.11 0.12 5978398.45 593487.38 N 70 21 2.238 W 149 1427.491
4541.71 61.72 21.3 3152.38 2587.12 2587.12 915.97 0.21 5978649.81 593582.30 N 70 21 4.698 W 149 14 24.625
4636.05 61.98 21.1 3196.89 2664.68 2664.68 946.04 0.11 5978905.40 593677.87 N 7021 7.200 W 149 1421.739
4729.79 62.55 20.6 3240.51 2742.21 2742.21 975.56 0.22 5979160.93 593771.64 N 70 21 9.702 W 1491418.904
4823.73 62.51 20.5 3283.85 2820.25 2820.25 1004.86 0.03 5979418.06 593864.63 N 7021 12.219 W 1491416.092
4917.36 61.94 20.6 3327.48 2897.81 2897.81 1033.95 0.18 5979673.65 593956.99 N 70 21 14.722 W 1491413.299
5011 .25 61.46 20.1 3371.99 2975.31 2975.31 1062.71 0.20 5979929.02 594048.26 N702117.222 W1491410.537
5104.87 61.17 20.7 3416.93 3052.29 3052.29 1091.36 0.19 5980182.64 594139.19 N 7021 19.705 W 149 147.786
V-103 ASP Final Surveys.xls
Page 2 of 4
10/21/2002-2:20 PM
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8743.04 61.54 17.0 5179.95 6065.88 6065.88 2112.36 0.06 5990108.60 597368.89 N 702256.920 W 149 1229.598
8836.56 61.01 17.0 5224.90 6144.30 6144.30 2136.35 0.17 5990366.80 597444.47 N 70 2259.450 W 149 1227.287
8930.96 60.93 16.6 5270.71 6223.31 6223.31 2160.24 0.11 5990626.91 597519.71 N 70231.998 W 149 1224.986
9023.92 60.65 16.6 5316.07 6301 .06 6301.06 2183.44 0.09 5990882.88 597592.73 N 70234.506 W 1491222.750
9117.42 60.25 16.7 5362.18 6378.99 6378.99 2206.71 0.13 5991139.46 597665.98 N 70237.020 W 149 1220.508
9211.23 59.85 16.4 5409.02 6456.92 6456.92 2229.83 0.15 5991396.00 597738.71 N 70239.534 W 149 12 18.281
9304.12 59.46 16.3 5455.95 6533.84 6533.84 2252.40 0.13 5991649.21 597809.71 N 70 2312.015 W 1491216.106
9397.65 59.43 16.1 5503.50 6611 .18 6611.18 2274.88 0.07 5991903.81 597880.37 N 702314.510 W 149 1213.939
9491.83 59.07 15.9 5551.65 6689.00 6689.00 2297.14 0.13 5992159.96 597950.31 N 702317.020 W 1491211.793
9584.75 57.62 16.0 5600.41 6765.06 6765.06 2318.83 0.47 5992410.32 598018.46 N 7023 19.474 W 149 129.702
9680.17 56.63 15.3 5652.21 6842.23 6842.23 2340.43 0.36 5992664.32 598086.26 N 70 23 21.963 W 149 127.619
9772.68 53.43 15.0 5705.22 6915.40 6915.40 2360.22 1.04 5992905.12 598148.25 N 70 23 24.323 W 149 125.712
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9866.07 51.19 16.7 5762.32 6986.50 6986.50 2380.34 0.84 5993139.15 598211.43 N 70 23 26.617 W 149 123.771
9959.90 49.66 16.6 5822.09 7055.80 7055.80 2401.05 0.49 5993367.27 598276.62 N 70 23 28.852 W 149 12 1.775
10052.52 44.97 16.6 5884.87 7121 .01 7121 .01 2420.53 1.52 5993581.97 598337.95 N 70 23 30.956 W 149 11 59.896
10146.01 42.20 19.0 5952.59 7182.38 7182.38 2440.20 1.02 5993784.05 598400.03 N 70 23 32.935 W 149 11 58.000
10239.35 39.65 19.6 6023.11 7240.09 7240.09 2460.39 0.83 5993974.15 598463.98 N 702334.796 W 149 11 56.054
10331.79 37.15 19.1 6095.55 7294.25 7294.25 2479.43 0.82 5994152.58 598524.29 N 70 23 36.543 W 149 11 54.219
10424.23 34.47 18.6 6170.50 7345.43 7345.43 2496.92 0.87 5994321.15 598579.63 N 70 23 38.194 W 149 11 52.533
10516.37 32.33 20.4 6247.42 7393.23 7393.23 2513.86 0.77 5994478.62 598633.31 N 702339.736 W 149 11 50.900
10610.46 29.33 21.1 6328.21 7438.31 7438.31 2530.95 0.96 5994627.18 598687.58 N 70 23 41.190 W 149 11 49.253
10703.46 26.79 19.9 6410.27 7479.27 7479.27 2546.30 0.84 5994762.15 598736.31 N 702342.511 W 149 11 47.774
10796.91 25.15 20.6 6494.28 7517.66 7517.66 2560.46 0.53 5994888.65 598781.23 N 702343.749 W 149 11 46.409
10891.06 21.90 20.8 6580.60 7552.81 7552.81 2573.73 1.04 5995004.49 598823.37 N 70 23 44.883 W 149 11 45.130
10984.41 19.50 21.2 6667.91 7583.62 7583.62 2585.55 0.77 5995106.00 598860.92 N 702345.876 W 149 11 43.991
11077.81 19.67 19.8 6755.91 7612.94 7612.94 2596.52 0.15 5995202.62 598895.73 N 70 23 46.822 W 149 11 42.934
11171.52 19.56 20.4 6844.18 7642.48 7642.48 2607.35 0.07 5995299.94 598930.09 N 70 23 47.775 W 149 11 41.890
---'
11264.56 18.49 19.4 6932.14 7670.99 7670.99 2617.69 0.36 5995393.87 598962.89 N 70 23 48.694 W 149 11 40.893
11357.47 16.88 17.4 7020.66 7697.76 7697.76 2626~61 0.56 5995482.04 598991.09 N 70 23 49.558 W 149 11 40.032
11450.63 15.65 18.1 7110.09 7722.61 7722.61 2634.56 0.40 5995563.87 599016.19 N 70 23 50.359 W 149 11 39.265
11488.90 15.51 18.0 7146.95 7732.38 7732.38 2637.75 0.11 5995596.05 599026.26 N 702350.674 W 149 11 38.958
11560.00 15.51 18.0 7215.46 7750.46 7750.46 2643.63 0.00 5995655.60 599044.80 N 702351.258 W 149 11 38.392
Survey Error Model: (No Error Model Selected)
V-103 ASP Final Surveys. xis
Page 4 of 4
10/21/2002-2:20 PM
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STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
1. Type of request:
FRAC
Abandon_ Suspend_
Alter casing _ Repair well _
Change approved program _
2. Name of Operator
BP Exploration (Alaska), Inc.
3. Address
P. O. Box 196612
Anchorage, AK 99519-6612
4. Location of well at surface
402'FNL, 1620'FEL,Sec. 11, T11N,R11E,UM
At top of productive interval
3386' FNL, 4313' FEL, SEC 36, T12N, R11 E, UM
At effective depth
3241' FNL, 4262' FEL, Sec. 36, T12N, R11 E, UM
At total depth
3210' FNL, 4252' FEL, Sec 36 T12N, R11 E, UM
12. Present well condition summary
Total depth: measured
true vertical
Effective depth:
measured
true vertical
Length
108'
3530'
Casing
Conductor
Surface
Production
11521'
Operational shutdown _
Plugging _
Pull tubing _
5. Type of Well:
Development _X
Exploratory _
Stratigraphic _
Service_
(asp's 590680, 5970127)
(asp's 593168, 5977732)
(asp's 593217,5977878)
(asp's 593227,5977909)
Re-enter suspended well _ /
Time extension Stimulate X
Variance Perforate
6. Datum elevation (OF or KB feet)
RKB 82.5 feet
7. Unit or Property name
Other
Prudhoe Bay Unit
8. Well number
V-103 .-/
9. Permit number I approval number
202-186 ---'
10. API number
50-029-23117-00
11. Field I Pool
Prudhoe Bay Field I Borealis Pool
Plugs (measured) TD Tagged @ 11440' (01/06/2003)
Perforation depth:
measured Open Perfs 11958'-11000',11008'-11016',11022'-11028' /'
11560 feet
7215 feet
11440 feet
7100 feet
Junk (measured)
Size Cemented Measured Depth True vertical Depth
20" 260 sx Arctic Set (Aprox) 136' 136'
9-5/8" 550 sx PF 'L', 405 sx 3558' 2679'
Class 'G'
7" 460 sx Mierolite Class 11549' /' 7205'
'G', 200 sx Class 'G'
RECE\\ ED
Jf\N L'\ 2003
. s\or;
0"\ & Gas Cons. Comrm5
ÞJas\<a \ A\1cnon1Ç\Ð
BOP sketch
true vertical Open Perfs 6643'-6683', 6690'-6698', 6703'·6709'
3-1/2",9.2#, L-80 TBG @ 10842' MD.
Packers & SSSV (type & measured depth) 7" x 3-1/2" BAKER Premier Packer @&I
3-1/2" HES X Nipple @ 2212' MD.
13. Attachments Description summary of proposal _X Detailed operations program _
14. Estimated date for commencing operation 15. Status of well classification as:
January, 2003 /
16. If proposal was vxrbalo/ ap,proved " (Oil _X
~. f\CAþt.vt I l....l 0'3 .
Name of approver Date approved Service
17. I hereby certify that the foregoing is truifd c:rr~ct to the best of my knowledge. Questions? Call Bruce Smith, (907) 564-5093.
Signed ~"-<.J / ~ Title: Borealis Development Petroleum Engineer Date January 21. 2003
Bruce Smith Prepared by DeWayne R. Schnorr 564-5174
Tubing (size, grade, and measured depth
Gas
Suspended _
FOR COMMISSION USE ONLY
Conditions of approval: Notify Commission so representative may witness
Plug integrity _ BOP Test Location clearance
Mechanical Integrity Test _ Subsequent fOI11'W€quired 10-
~?~
RBDMS BFt
Approved by order of the Commission
Form 1 0-403 Rev 06/15/88 ·
£.jot{
Approval no.
3c~ ::; - ¿'J/ ~
Commissioner
Date co ~ 2..0.1
~IAN 2 7 20m
SUBMIT IN TRIPLICATE
bp
January 21, 2003
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BP Exploration (Alaska) Inc.
900 East Benson Boulevard
P. O. Box 196612
Anchorage, Alaska 99519-6612
(907) 561-5111
Winton Aubert
Alaska Oil & Gas Conservation Commission
333 West 7th Avenue Suite 100
Anchorage, AK 99501
Dear Winton:
Re: Sundry Notice for V-1 03 Fracture Stimulation Program
BP Exploration Alaska, Inc. proposes to fracture stimulate well V-103. /'
Attached is the Fracturing procedure, which consists of 1500 bbls of water for /"
diagnostics and fracturing with 200 Mlbs of 16/20 and 50 Mlbs of 12/18
Carbo Lite proppant. See pump schedule for details. The pump schedule is
subject to change; fluid and proppant volumes should be adequate to aqdress any
contingencies. The procedure includes the following major steps: /
The procedure includes the following major steps:
Category
S
o
o
C
S
T
T
NOB
4500
4500
4500
4500
4500
4500
4500
STEP
1
2
3
4
5
6
7
Last Test:
Max Deviation:
Perf Deviation:
Min. ID:
Last TD tag:
Last Downhole Ops:
Latest H2S value:
Reference Log:
BHT & BHP:
Description
Pull and dummy GLV.
MIT IA /~
Perform Data Frac & Frac. Shut-in.
FCO. Freeze protect. Shut-in.
Install GL V's.
Frac, Flowback, HOT tubing, Simultaneously POP. /'
Mobile Test Separator Test schedule.
New Completion, never tested
62° @ 3980' MD
22° @ 10999' MD
2.813" SSSVN at 2212'
11440' RKB MD New Well
Static survey
o ppm 12/02
Schlumberger PEX
estimated 158° F & 3200 psia @ 6600' TVDSS
1. Slickline
a) Perforate and run static survey from prior programs before moving to this program.
) ')
b) Report well conditions. WHP, WHT, lA, OA. Production rate. Freeze Protect
wellbore and flowline.
c) Pull and dummy gas lift valves.
2. Fracture Treatment
a) Load Frac tanks with - 100 of seawater; - 1500 bbls are required (excluding tank
bottoms) .
b) RU the tree-saver/isolation tool for 3Y2 "- 9.3 #/ft. tubing (see attached tubing
detail). PT backside to 4000 psi and maintain 3500 psi throughout treatment (set
inner annulus pop-off at 4000 psi). Note this well has a 10' floating seal assembly
and maintenance of 2500 psi on IA is required to stay in the PBR. Pressure test
treating lines to 8500 psi. Set Nitrogen pop-off valve at 7500 psig. Set pu~p trips
afterwards to 7500 psi. This well is expected to treat at ± 6000 psi. It is
recommended that 4 pumps be on location (1 backup).
c) Breaker tests will be performed on fluids prior to frac. The breaker schedule will be
designed to ensure fluid stability at end of pump time with complete break with-in
one hour of shut down. A minimum of 100 cp @ 100 sec^-1 is required at shut
down.
d) Begin pumping Data Frac, initial rate will be 5 bpm while displacing wellbore fluid,
after spotting Data Frac fluid a few feet above top perf increase rate to 25 bpm and
displace data frac. Shut down for ISIP, monitor for closure time, calculate efficiency
and re-design frac schedule as necessary (Pad size, fluid loss additive, etc.)
e) Additional diagnostic tests may be performed after data frac analysis. Consult with
engineer before proceeding with trac.
f) Re-establish injection, when add rates are lined out start counting PAD. Pump the
proppant schedule as detailed in the attached pump schedule. Flush with linear
fluid.
g) Bleed off excess annulus pressure. Rig down Service Company.
3. Post Fracture
a) Perform CTU fill cleanout to original PBTD (-11240' MDRKB corr):
1 Perform an overbalanced pressure fill clean-out, circulating gel and sand to a
tank. A connection to a flowline will not be available.
2 Use filtered seawater to clean-out. If gel sweeps are required to clean-out, have
lab verify that breaker loading is adequate to break polymer & mix water at 150°
F.
3 Freeze protect to 3000' with 50/50 diesel/ neat MEOH.
a. Slickline to install gas lift design to lift from bottom.
b. Shut-in pending frac flowback.
4. Frac Flowback
a) As soon as possible flowback through portable flow-back separator:
1 For analog Kuparuk frac flowback, see L-110 & L-107 well files.
2 Kuparuk wells tend to hydrate-off, HOT oillA with 100 bbls of hot diesel followed /
by 20 bbls of neat MEOH. Kick off well simultaneouslv with POP well.
3 Expect FWHTs of 50 - 60°F and watercuts of 100% to begin with. Treat gas lift
with methanol to prevent freezing. Attempt to quantify returned proppant flushed
to tank.
4 Unload thl)1I with 0.5 MMSCFGPD./ ')
5 Conduct 4 hour well tests. If after 12 hours, solids are <0.10/0, then increase GL T
to 1 MMSCFGPD.
6 Conduct 4 hour well tests. If after 12 hours, solids are <0.10/0, then increase GL T
to 1.8 MMSCFGPD.
7 Do not surge well to flowback proppant. Surging could cause formation
failure and sand production.
8 Continue producing to the flowback separator until the gel load has been
recovered or watercut <100/0 and the solids production <0.10/0.
9 Schedule wellbore for Pad Separator test.
b) Place well on production at gas lift rate of 1.8 MMSCFPD, Place well on normal 15 ~
day AOGCC required testing schedule.
c) Service tree.
If you have any questions concerning this Sundry Application, please don't
hesitate to call me at 564-5093, hm: 345-2948, cell: 440-8008 or e-mail me at
SmithBW @BP.com
Sincerely,
~~~
Bruce W. Smith
GPB Borealis Development Engineer
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lREE= 4-1/16"CIW
WELLHEA D = FIVC
ÃCWATÕR;"-'···,,·'··"NÄ' V-1 0 3
KEf:ELE.\T;··-·-'·····''''''·''s:2':s;
ì3F.'I~[Ë\T ;;'"'''' ··,,",·'··"·NA
·Rõ"p;-·-"·-"-"··""··""'''3õ'õ;
·§,~~~9~.~=~:::J?~~~~:~~:~~' =
Datum MD =
..."..,.,.,.....,·,·,·,...,'w.w, , . "" "''"~~.~, ~ , ,^,", "" ,', . .'''''
Datum 1V D = 8800' SS
1 9-5/8" CSG, 40#, L-80, ID = 8.835" 1-1 3551' ~
':-1 1015' 1-1 TAM PORT COLLAR 1
I I 1 2212' 1-1 3-1/2" HES X NIP, ID = 2.813" 1
~
Minimum ID = 2.813" @ 2212'
3·1/2" HES X NIPPLE
-
-.-J
GAS LFT Ml\NDRELS
ST MD TVD DEV TYPE VL V LA TO; PORT DATE
3 5282 3502 62 MMG-W OOME RK 16 01/04/03
2 8787 5201 61 MMG-W OOME RK 16 01104/03
1 10705 6412 27 MMG-W OOME RKP 20 01/04/03
I I I 10762' l-þ-1/2" BKR CMD SLIDING SLV, D = 2.813" 1
:8: Z
10785' 1-1 7" X 3-1/2" BKR FREMIER PKR, D = 2.870" I
10811' 1-1 3-1/2" HES X NIP, ID = 2.813"
10832' Ii 3-1/2" HES X NIP, ID = 2.813"
10844' 1-1 3-1/2" WLEG, ID = 2.905" I
PERFORATION SUMMl\ RY
REF LOG:
ANGLEA TTOP PERF:
fl.bte: Refer to R"oduction DB for historical Jerf data
SIZ E SPF INTER\! AL OpnlSqz DA TE
H 10~2' ~ /~
I 3-1/2" 18G, 9.2#, L-80, .0087 bpf, ID = 2.992"
~ 10929' 1-1 7' MARKERJTW/ RA TAG I
. I 11240' H 7" MARKER Jf W/ RA TAG I
I FBTD H 11440' I ~.Jt.
7"CSG,26#,L-80,.0383bpf,ID=6.276" 1--1 11549' ~
DATE REV BY 00 Mv1ENTS
10/07/02 DCRlKK ORIGINAL OOrvPLErION
01/04/03 JM/KA K GL V C/O
DA. TE REV BY
CO Mv1ENTS
GFB BOREALIS
W8..L: V -103
PERMIT No: 2021860
API No: 50-029-23117-00
SEe 11, T11 N, R11 E, 4878' NSL & 1620' WEL
BP Exploration (Alaska)
Schlum~ePger
Alaska Data and Consulting Services
3940 Arctic Blvd, Suite 300
Anchorage, AK 99503-5711
ATTN: Beth
Well Job# Log Descñption
V-103 22476 OH EDIT PP, ARC & ADN LWD (PDC)
d ~- J~1t> V-103 22476 MD VISION RESISTIVITY
V-103 22476 TVD VISION RESISTIVITY
V-103 22476 MD VISION DENINEUTRON
V-103 22476 TVD VISION DENlNEUTRON
V-107 22474 OH EDIT PEX, AIT & BHC (PDC)
V-107 22474 PEX RESISTIVITY
V-107 ~474 PEX SONIC
V-107 22474 PEX NEUTRONIDEN
V-107 22474 PEX CAUPER
V-10B 22468 OH EDIT MWD/GRlRESIDEN-NEUTRON (PDC)
V-10B 22468 MD VISION RESISTIVITY
V-10B 22468 TVD VISION RESISTIVITY
V-10B 2246B MD VISION DENlNEUTRON-QUADRANT ,
V-10B 22468 TVD VISION DENlNEUTRON-QUADRANT
V-10B 2246B MD VISION-SERVlCE
V-10B 22468 TVD VISION-SERVICE
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO:
BP Exploration (Alaska) Inc.
Petrotectnical Data Cenler LR2-1
900 E Benson Blvd.
""""'mg. AK 99508-4254 ~ .
Dale Delivered: U... ~
ú-QQon~
7
10/01/02
10101102
10/01/02
10/01/Ó2
10101/02
10/13102
10/13/02
10/13/02
10/13/02
10/13/02
09/18/02
09/18/02
09/18/02
09/18/02
09/18/02
09/18/02
09/18/02
NO. 2519
Company: Alaska Oil & Gas Cons Comm
Attn: Lisa Weepie
333 West 7th Ave, Suite 100
Anchorage, AK 99501
Field: Borealis
P. Bay
Date
Color
Sepia
Schlumberger DCS
3940 Arctic Blvd Suite 300
Anchorage AK 99503-5789
A TTN: 8eth
Received by:
10/31/02
BL
CD
~
'''-"' '
RECEIVED
NOV 0 1 2002
Alaska Oi1 & Gas Cons. Conuniseion
Anchorage
SchlumlJerger
Alaska Data and Consulting Services
3940 Arctic Blvd, Suite 300
Anchorage, AK 99503-5711
ATTN: Beth
Well Job# Log Description
dCB - ~ V-103 22466 USIT
V-105 22419 OH PEX AITIBHC SONICIDENINEUTRON
V-105 22419 PEX RESISTIVITY
V-105 22419 PEX SONIC
dOdJ 3/ V-105 22419 PEX NEUTRONIDENSITY
V-105 22419 PEX RESINETIDEN/SONIC LOGS
V-105 22419 PEX CALIPER
V-104 22394 OH EDIT AITIBHC SONIC/PEX NEUTRON/DEN
V-104 22394 PEX RESISTIVITY
d(þ)-JLj~ V-104 22394 PEX BHC SONIC
V-104 22394 PEX NEUTRON/DENSITY
V-104 22394 PEX TRIPLE COMBO & SONIC
V-104 22394 PEX CALIPER
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETtmNING ONE COpy EACH TO:
BP Exploration (Alaska) Inc,
Petrotectnical Data Center LR2-1
900 E Benson Blvd,
Anchorage AK 99508-4254
Date Delivered:
RECE\VED
OCT 25 2.002
AiasKlOii & Gas Cons. eommiIIiÐR
AndØI98
10/05/02
09/04102
09/04102
09/04/02
09/04102
09/04102
09/04102
08/23/02
08/23/02
08/23/02
08/23/02
08/23/02
08/23/02
10/17/02
NO. 2491
Company: Alaska Oil & Gas Cons Comm
Attn: Lisa Weepie
333 West 7th Ave, Suite 100
Anchorage, AK 99501
Field: Borealis
P. Bay
Date
Color
CD
Sepia
BL
2
.-"
Schlumberger DCS
3940 Arctic Blvd Suite 300
Anchorage AK 99503-5789
ATTN: Beth
R'~. Ú C1op~
~.
')
)
,~I
dtil-Ir~
MWD/LWD Log Product Delivery
Customer
BP Exploration (Alaska) Inc.
Well No
V-103
Installation/Rig
Nabors 9ES
Data
Su rveys
Received By: ~ ~
LWD Log Delivery V1.1, Dec '97
Dispatched To:
Lisa Weepie
Date Dispatche
10-0ct-02
Dispatched By:
Nate Rose
No Of Prints No of Floppies
2
I~ECEIVED
OCT 23 2002
Alaslca o¡~ & Gas Cons. (;oß1l11jssion
Anchoraae
;;;;
Please sign and return to: James H. Johnson
BP Exploration (Alaska) Inc.
Petrotechnical Data Center (LR2-1)
900 E. Benson Blvd.
Anchorage, Alaska 99508
Fax: 907-564-4005
e-mail address:johnsojh@bp.com
Re: BOP test pressure question
)
Subject: Re: BOP test pressure question 'l,D ? - , i'
Date: Tue, 17 Sep 2002 07:18:59 -0800
From: Winton Aubert <Winton_Aubert@admin.state.ak.us>
Organization: AOGCC
To: "Franks, James D" <FranksJD@BP.com>
James,
This E-mail is sufficient. AOGCC approves the 4000 psi BOPE test pressure for
well V-103. All other permit stipulations apply.
Winton Aubert
AOGCC
793-1231
"Franks, James D" wrote:
> Winton,
>
> For the V-103 well we sent the permit out with the thought that we would
> need to test the BOP's and the casing to 4500 psi for a future frac job. As
> it turns out, we have recently finished looking at data that suggests we
> only need to test the casing to 4000 psi.
>
> Do I need to send you a Sundry to change the test pressure?
>
> Thanks for your time,
>
> james
>
> James Franks
> BP GPB Rotary Drilling - 9ES
> office: 907-564-4468
> cell: 907-440-0187
t
¡JL
AI~ASIiA. OILAlWD GAS
CONSERVATION COMMISSION
I
/
/
"
[
~7!Æ~E :} !Æ~!Æ~[«fÆ
TONY KNOWLES, GOVERNOR
333 W. PH AVENUE, SUITE 100
ANCHORAGE, ALASKA 99501-3539
PHONE (907) 279-1433
FAX (907) 276-7542
Lowell Crane
Senior Drilling Engineer
BP Exploration (Alaska), Inc.
PO Box 196612
Anchorage AK 99519
Re: Prudhoe Bay Unit V-103
BP Exploration (Alaska), Inc.
Permit No: 202-186
Surface Location: 4878' NSL, 1620' WEL, Sec. 11, T11N, RIlE, UM
Bottomhole Location: 2050' NSL, 1024' EWL, Sec. 36~ T12N, RIlE, UM
Dear Mr. Crane: (j~
Wú
Enclosed is the approved application for permit to ~l the above development well. .
The pennit to #IT ::s not exempt you ITom obtaining additional pennits or approvals
required by law from other governmental agencies, and does not authorize conducting drilling
operations until all other required permits and approvals have been issued. In addition, the
Commission reserves the right to withdraw the permit in the event it was erroneously issued.
Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the
Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure
to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska
Administrative Code, or a Commission order, or the terms and conditions of this permit may
result in the revocation or suspension of the permit. Please provide at least twenty-four (24)
hours notice for a representative of the Commission to witness any required test. Contact the
Commission's North Slope petroleum field inspector at 659-3607 (pager).
Sincerely,
( a ""~. ~ J1.J"L' ¥
C~~;O&c;hsli Taylor
Chair
BY ORDER OF THE COMMISSION
DA TED this 6ft, day of September, 2002
cc: Department ofFish & Game, Habitat Section wlo encl.
Department of Environmental Conservation wlo encl.
Hole
42"
12-1/4"
8-3/4"
, STATE OF ALASKA
ALASKA"'_,,! AND GAS CONSERVATION COMMI__ }ION
PERMIT TO DRILL
20 AAC 25.005
1 b. Type of well 0 Exploratory 0 Stratigraphic Test II Development Oil
o Service 0 Development Gas 0 Single Zone 0 Multiple Zone
5. Datum Elevation (DF or KB) 10. Field and Pool
Plan RKB = 82.3' Prudhoe Bay Field I Borealis
6. Property Designation Pool (Ul1ddin.)'Jt ~
ADL 028238
7. Unit or Property Name
Prudhoe Bay Unit
8. Well Number /'
V·103
9. Approximate spud date
09/28/02 .;' Amount $200,000.00
14. Number of acres in property 15. Proposed depth (MD and TVD)
2560 116121 MD 17237' TVD
17. Anticipated pressure {see 20 AAC 25.035 (e) (2)}
61 0 Maximum surface 2718 ~ig, At total depth (TVD) 6820' I 3400 psig
Setting Depth
T<;>D Bottom
MD TVD MD TVD
Surface Surface 110' 110'
Surface Surface 3740' 27781
Surface Surface 11612' 7237'
lJGA- 'l/~/ol
<:JIF Cfltf(~
1 a. Type of work II Drill 0 Redrill
ORe-Entry 0 Deepen
2. Name of Operator
BP Exploration (Alaska) Inc.
3. Address
P.O. Box 196612, Anchorage, Alaska 99519-6612
4. Location of well at surface
4878' NSL, 1620' WEL, SEC. 11, T11 N, R11 E, UM
At top of productive interval
1905' NSL, 979' EWL, SEC. 01, T11 N, R11 E, UM
At total depth
2050' NSL, 1024' EWL, SEC. 36, T12N, R11 E, UM
11. Type Bond (See 20 AAC 25.025)
Number 2S 100302630-277
12. Distance to nearest property line 13. Distance to nearest well /
ADL 028240, 2050' MD V-106 is 28' away at 600' MD
16. To be completed for deviated wells
Kick Off Depth 300' MD Maximum Hole Angle
18. Casin~ Program Specifications
$Ize
CasinQ Weiaht Grade Couolina
20" 91.5# H-40 Weld
9-5/8" 40# L-80 BTC
7" 26# L-80 BTC-M
LenQth
80'
3710'
11582'
Quantity of Cement
(include staae data)
260 sx Arctic Set (Approx.)
539 sx PF 'L', 401 sx Class 'GI .<"
390 sx Class 'G', 198 sx Class 'G' ..-
19. To be completed for Red rill , Re-entry, and Deepen Operations.
Present well condition summary
Total depth: measured feet Plugs (measured)
true vertical feet
Effective depth: measured feet Junk (measured)
true vertical feet
Casing
Length
Size
Cemented
MD
TVD
Structural
Conductor
Surface
Intermediate
Production
Liner
Perforation depth: measured
,ÙdéE;k~
~..j c;·:: ~ 'II ~ :'I'~ ~ ,j;; ~ t~) ,;
true vertical
20. Attachments
II Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch II Drilling Program
II Drilling Flui~,~rogram 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements
nks, 564-4468
21. I hereby certify th,a,t the fore . g is true ~~, 'an, , " 0, t, t,o, ,th",e, , ,b,e, S, t, Of, m, Y" ,~n, ,o,w, ,I,~" d,' g""e", '" .,
Signed Lowell Crane" ~ / V[ ~- - Title Senior Dnlllng Engineer
,,"{', I,;!:¡'.,'¡ "',I~mi~i~i,q.:"QnIY:"""""" ':'.':':""::""~;"",,
Permit Number API Number) Approval Date See cover letter
..:2..Q2.. - / ð'~ 50- 0 ¿, 9 - 2-.3 // ? c, \s I(~ for other requirements
Conditions of Approval: Samples Required 0 Yes ~ No Mud Log Required 0 Yes ~ No
Hydrogen Sulfide Measures 0 Yes I8J No Directional Survey Required I;!I Yes 0 No
Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU
Other: ',t?'!:;;;f- BoPE fc c.¡.ÇOO pS,'. (J~~ to AM c...S", o'5ç (k.) (l t ~,,~ f2y- W",.Ú/oi..- j VQ.c.(..{t¿ .
Ong,na\ S¡gned By by order of I '/
r.;¡mlT\.Y Oechsli Taytor Commissioner the commission Date C\ ~ tJ~
~J [) ~, r,: ~ ~\r l\ I Submit In Triplicate
l. !\ t \~, ,) ~ ~ \J 1"-\ L~
Prepared By Name/Number: Terrie Hubble, 564-4628
Date
:8 -:;2. ~ -~ J-
Approved By
Form 10-401 Rev. 12-01-85
) )
IWell Name: IV-103
Drill and Complete Plan Summary
I Type of Well (service I producer I injector): 1 Producer (contingency injector)
Surface Location:
As-Built
Target Location:
Top Kuparuk
Bottom Hole Location:
x = 590,680.23' Y = 5,970,126.97'
48781 FSL (4021 FNL), 16201 FEL (3660' FWL), Sec. 11, T11 N, R11 E
X = 593,180' Y = 5,977,745'
19051 FSL (33751 FNL), 4301' FEL (9791 FWL), Sec. 1, T11 N, R11 E
X = 593,223.34' Y = 5,977,890.01'
20501 FSL (32301 FNL), 4256' FEL (10241 FWL), Sec. 36, T12N, R11 E
1 AFE Number: 1 BRD5M4049 1
I Estimated Start Date: 19/28/2002 1
I MD: 111612' 'I I TVD: 17237' 1
I RiQ: 1 Nabors 9ES ./
I OperatinQ days to complete: 116.1 ,/
1 RT/GL: 128.5' 1
I RKB: 182.3'
I Well DesiQn (conventional, slim hole, etc.): 1 Ultra Slimhole (Iongstring)
Objective: Single zone producer into the Kuparuk formation. This well is to be left in a
condition for injection as a contingency.
Mud Program:
121M" Surface Hole (0-3740'):
Densitv
(ppg)
8.5 - 9.2
9.0 - 9.5
9.5 max
Viscosity
(seconds)
250-300
200-250
150-200
Initial
Base PF to top SV
SV toTO
83A" Production Hole (3740' - 11612'):
Interval Density Tau 0 YP
(ppg)
9.7
Upper
Interval
Top of HRZ
to TO
4-7
25-30
9.9 /
3-7
20-25
V-103 Drilling Permit
Fresh Water Surface Hole Mud
Yield Point API FL PH
(lb/1 OOft~) (mls/30min)
50 - 70 15 - 20 8.5 - 9.5
30 - 45 <10 8.5 - 9.5
20 - 40 <10 8.5 - 9.5
LSND
PV pH API 10' Gel
Filtrate
1 0-15 8.5-9.5 6-10 10
1 0-15 8.5-9.5 4-6 10
Page 1
') ')
Hydraulics:
Surface Hole: 12-1/4"
Interval Pump Drill AV Pump PSI ECD Motor Jet Nozzles TFA
GPM Pipe (fpm) ppg-emw ("/32) (in2)
0-1867' 550 4" 17.5# 90 1800 10.0 N/A 18,18,18,16 .942
1867' -3740' 650 4" 17.5# 110 2400 10.2 N/A 18,18,18,16 .942
Production Hole: 8 %"
Interval Pump Drill Pipe AV Pump PSI ECD Motor Jet Nozzles TFA
GPM (fpm) ppg-emw ("/32) (in2)
3740' -11612' 600 4" 17.5# 240 3400 11.2 N/A 3x14,3x15 .969
Hole Cleaning Criteria:
Interval 'Interval ROP Drill Pump Mud Hole Cleaning Condition
Pipe GPM Weight
Rotation
110'-3740' Surface Superior hole cleaning practices at
to SV-1 connections will greatly enhance
cuttings transport in the sliding mode
180 60 500 9.5 Acceptable
220 60 600 9.5 Acceptable
260 60 700 9.5 Acceptable
195 80 500 9.5 Acceptable
230 80 600 9.5 Acceptable
270 80 700 9.5 Acceptable
200 100 500 9.5 Acceptable
240 100 600 9.5 Acceptable
290 100 700 9.5 Acceptable
3740'-11612' 9-5/8" to Sweeps and fully reamed connections
TD to maintain minimum hole cleaning
requirements
280 80 500 9.7 Acceptable
340 80 600 9.7 Acceptable
300 100 500 9.7 Acceptable
350 100 600 9.9 Acceptable
V-103 Drilling Permit
Page 2
Di rectional:
Ver. Anadrill P4
KOP: 300'
Maximum Hole Angle:
Close Approach Wells:
None
Logging Program:
Surface
Intermediate/Production Hole
Formation Markers:
Formation Tops
SV6
SV5
Base Permafrost
SV4
SV3
SV2
SV1
UG4A
UG3
UG1
Ma
WS2 Na
WS1 Oa
Obf Base
CM2 (Colville)
THRZ
BHRZ (Kalubik)
K-1
TKUP
Kuparuk C
LCU (Kuparuk B)
Kuparuk A
TMLV (Miluveach)
TD Criteria
V-103 Drilling Permit
)
')
61 deg at 2804' MD
All wells pass major risk criteria. The nearest wells are:
V-106 - 28.27 ctr-ctr@ 600'
V-105 -76.07 ctr-ctr @ 550' (planned)
IFR-MS corrected surveys will be used for survey validation.
Camera Based Gyro will be needed for surface issues to 1000' MD.
Drilling:
Open Hole:
Cased Hole:
Drilling:
Open Hole:
Cased Hole:
TVDss
880
1650
1685
1785
2165
2295
2595
2925
3275
3760
3950
4180
4335
4725
4910
6320
6465
6550
6590
6590
6680
6820
7010
MWD/GR
None
None
MWD/GR/PWD/RES/NEU/AZM DENS
USIT cement evaluation
Estimated pore pressure, PPG
Hydrocarbon bearing, 8.5 ppg EMW
Hydrocarbon bearing, 8.5 ppg EMW
Hydrocarbon bearing, 8.5 ppg EMW
Hydrocarbon Bearing, 8.9 ppg EMW
Hydrocarbon Bearing, 8.9 ppg EMW
Hydrocarbon Bearing, 9.6 ppg EMW
~,~
.-"
150' MD below Miluveach top
Page 3
)
)
CasinglTubing Program:
Hole Csgl WtlFt Grad? Conn Length Top Btm
Size TbQ O.D. MD/TVD MD/TVD bkb
42" Insulated 20" 91.5# H-40 WLD 80' GL 110'/110'
12 14" 9 5/8" 40# L-80 BTC 3710' GL 3740'/2778'
8 3)¡." 7" 26# L-80 BTC-m 11582' GL 11612'/7237'
Tubing 3 Y2" 9.2# L-80 TCII 1 091 7' GL 10947'/6590'
Integrity Testing:
Test Point Depth
Surface Casing Shoe 20' min from
surface shoe
Test Type
LOT
EMW
11.5 ppg EMW Target
Cement Calculations:
The following surface cement calculations are based upon a single stage job using a port collar as a
contingency if cement is not circulated to surface.
Casinq Size 19-5/8" Surface I
Basis: Lead: Based on conductor set at 110', 1867' of annulus in the permafrost @ 225%
excess and 823' of open hole from top of tail slurry to base permafrost @ 300/0 excess.
Lead TOC: To surface
Tail: Based on 1050' MD(>500'TVD) open hole volume + 30% excess + 80' shoe track
volume. Tail TOC: At -2690' M+D >/'
Total Cement Volume: Lead 399 bbl I 2235 ft::l I 539 sks of Halliburton Permafrost L at
10.7 ppg and 4.15 disk.
Tail 82 bbl I 462 fe I 4g.,1 sks of Halliburton 'G' at 15.8 ppg
and 1 .15 disk.
Casinq Size 17" Production Longstring I
Basis: Stage 1: Based on TOC 500' above top of Kuparuk formation + 30% excess + 80' shoe
Cement Placement: Tail from shoe to 10527' MD, lead from 10527' to 5854' - 500'
above Ma sand -/
Total Cement Volume: Lead 163 bbls I 913 fe I 390 sks of Halliburton Premium "G"
at 12.5 ppg and 2.34 disk.
Tail 41 bbl I 229 fe I 1 ~sks of Halliburton 'G' at 15.8 ppg
and 1 .16 disk.
V-103 Drilling Permit
Page 4
)
)
Well Control:
~gl"f~¢e hole will be drilled with diverter (a diverter waiver has beenrªq~êê~~ci~. The
intermediate hole, well control equipment consisting of 5000 psi working pressure pipe rams(2),
blind/shear rams, and annular preventer will be installed and is capable of handling maximum
potential surface pressures. Based upon the planned casing test for future fracture
stimulation treatment, the BOP equipment will be tested to 4500 psi. ../
Diverter, BOPE and drilling fluid system schematics on file with the AOGCC.
Production Interval-
· Maximum anticipated BHP:
· Maximum surface pressure:
· Planned BOP test pressure:
required for fracture stimulation.)
· Planned completion fluid:
3400 ps~@ 6820' TVDss - Kuparuk A Sands
2718 pSI @ surface
(based on BHP and a full column of gas from TD @ 0.10 psi/ft)
v'
4500 psi (The casing and tubing will be tested to 4500 psi as
8.6 ppg filtered seawater / 6.8 ppg diesel
Disposal:
· No annular disposal in this well.
· Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind
and inject at OS-04.
· Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to OS-
04 for disposal. Haul all Class I wastes to Pad 3 for disposal.
V-103 Drilling Permit
Page 5
)
)
DRILL AND COMPLETE PROCEDURE SUMMARY
Pre-Rig Work:
The 20" insulated conductor was installed in Feb. 2002.
1. Weld an FMC landing ring for the FMC Ultra slimhole wellhead on the conductor.
2. If necessary, level the pad and prepare location for rig move.
Rig Operations: ""',/.,,, :-\
1. MIRU Nabors 9ES. / ... )
2. Nipple up diverter spool and riser (diverter waiver requested). PUi 4" DP as required and stand back
in derrick. ( ~___._--' //
3. MU 12 14" drilling assembly with MWD/LWD (page 4) and directionally drill surface hole to
approximately 100' TVD below the SV1 SançJs. An intermediate wiper/bit trip to surface for a will be
performed prior to exiting the Permafrost. /
4. Run and cement the 9-5/8", 40# surface casing back to surface. /'
5. NO riser spool and NU casing / tubing head. NU BOPE and test to 4500 psi.
6. MU 8-3/4" drilling assem~ with MWD/LWD(page 4) and RIH to float collar. Test the 9-5/8" casing to
3500 psi for 30 minutes.
7. Drill out shoe joints and displace well to 9.7 ppg drilling fluid. Drill new formation to 20' below 9-5/8"
shoe and perform Leak Off Test.
8. Drill ahead to first wiper trip.
9. Drill to +/-100' above the HRZ, ensure mud is in condition to 9.9 ppg and perform short trip as needed. /'
Ensure Pre-Reservoir meeting is held highlighting kick tolerance and detection prior to entering HRZ.
10. Drill ahead to TO at -150' MD below Top Miluveach.
11. Condition hole for running 7" 26# long-string casing. /
12. Run and cement the 7" production casing in a single stage. (To be reviewed based on log/operational
results.) Displace the cement with 8.5 ppg filtered seawater if single sta~
13. Verify zonal Isolation by running a USIT log for injection contingency.
14. Freeze protect the 7" x 9-5/8" annulus as required. Record formation breakdown pressure on the
Morning Report.
15. Test casing to 4500 psi for$º[nir'l~t~~. ./
16. Run the 3-1/2", 9.2#, L-80 TCII completion assembly. Set packer and test the tubing to 4500 psi and
annulus to 4500 psi for 30 minutes. Shear DCK shear valve and install TWC. Test below to 1000 psi. /'
17. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. Remove TWC.
18. RU hot oil truck and freeze protect well by pumping diesel to lowermost GLM. Allow to equalize.
19. Rig down and move off.
V-103 Drilling Permit
Page 6
)
)\
V-103 Drilling Hazards and Contingencies
Job 1: MIRU
Hazards and Contingencies
~ V-Pad is not designated as an H2S site. None of the current producers on V-Pad have
indicated the presence of H2S. As a precaution however Standard Operating Procedures
for H2S precautions should be followed at all times.
~ The closest surface location is V-106, 30' to the West.
~ Check the landing ring height on V-103. The BOP nipple up may need review for space out.
Reference RPs
.:. "Drilling/ Work over Close Proximity Surface and Subsurface Wells Procedure"
:«««!~~»I>:.»""(.",.,.c.:.,':.,.(@:,:...:.:(.:o».-:-:««>:o~:«*X««*~*»~__~««,~»»_»»»_~~__.:-~:«-~:,.,-.:.>:v.':.:«.x('.M'«.:.,.x«(.X',.........~~__:««>:x>.'»:«<:(OO)x«-:«.;<.-.:...>H:«,.·,.u..,·.,,.....w..,.""'.............~___~~»:«-:-:*''»X««
Job 2: DrillinQ Surface Hole
~ There is one nearby well issue in the surface hole. Refer to page 4 for details.
~ Camera Based Gyro survey will be required per the directional plan to 1000' MD or until the
magnetic interference at the surface has dissipated. (To be confirmed)
~ Minimal gas hydrates have been observed in wells drilled on V-Pad. These were encountered
near the base of permafrost to TD in the SV1 sand. Hydrates will be treated at surface with
appropriate mud products and adjustment of drilling parameters. Refer to Baroid mud
recommendation
~ V-103 will cross one fault in the Surface hole @ 2150'TVDss, +/-100', with a throw of 70' to the
west. Faults in this area have not been problematic.
Reference RPs
.:. "Prudhoe Bay Directional Guidelines"
.:. "Well Control Operations Station Bill"
.:. Follow Schlumberger logging practices and recommendations
~~I:>:'~~;~:l.:¡;~,.~,',.,',';".,'.:;,.~~,..,.,.,";.;,.:..,.,¡.,·,·,<',·:·,,·,¡ri,·,·.·,·,·,;..·.·!,;:.,·.~~,·,'¡,~·;~,I,·ri,,,·,~M-,',·,·,,·,'.,;',,:';·.<·,..,,·;;,·,,·~.·,xx_,·:~...,_~i_1.'T.'.~'~_!o!<~.~r~!~;1..:~:~~~~)~..s.~~: .·,tM.,'"'.¡u.:;,..;,,.,w,'"..,,._.,.~~~.)'''~~~:<<-~~~:~~'1'!I'1~:~':~'101II~~:.;M,;¡.,.~~~~.1I'..~~,"'~~:..~:;\~""n':>^',.J""",,,~~,o/.lo...;,.~~e:",.SIo,.~~~.~,.:..:~",.,,,A.,,..,;,,¡...e,."',.,,....,.~~~~
Job 3: Install surface CasinQ
Hazards and Contingencies
~ It is critical that cement is circulated to surface for well integrity. 2250/0 excess cement through the
permafrost zone (and 30% excess below the permafrost) is planned. A 9-5/8" port collar will be
positioned at ±1 OOO'MD to allow remedial cementing.
~ "Annular Pumping Away" criteria for future permitting approval for annular injection.
1. Pipe reciprocation during cement displacement
2. Cement - Top of tail >500' TVD above shoe using 30% excess.
3. Casing Shoe Set approximately 100'TVD below SV-1 sand.
Reference RPs
.:. "Casing and Liner Running Procedure"
.:. "Surface Casing and Cementing Guidelines"
.:. "Surface Casing Port Collar Procedure"
V-103 Drilling Permit
Page 7
Page 8
V -103 Drilling Permit
~~m'!~~~~ffl~~~~~~~~~~~~~~~~~~~:::~~~:\!<~~~:~~~~~~~\(~~~~'m~~m~~~~~::::m~w~~~~,-:~~~~~w~
)
)
).
Job 7: DrillinQ Production Hole
Hazards and Contingencies
~ V-1 03 will cross one fault - in the Colville - 571 O'TVDss (+/- 125') with the estimated throw of the
fault being 60'. The well will be - 62 degrees when crossing the fault. Lost circulation is
considered low to medium risk. Consult the Lost Circulation Decision Tree regarding LCM
treatments and procedures.
~ KICK TOLERANCE: In the scenario of 9.6 ppg pore pressure at the Kuparuk target depth, gauge
hole, a fracture gradient of 11.5 ppg at the surface casing shoe, 9.9 ppg mud in the hole the kick
tolerance is 26.3 bbls. An accurate LOT will be required as well as heightened awareness
for kick detection. Contact Drilling Manager if LOT is less than 11.5 ppg. V-Pad development
wells have "kick tolerances" in the 30-50 bbl range. A heightened awareness of kick
detection, pre-job planning and trip tank calibration will be essential while drilling/tripping
the intermediate/production intervals
~ Hole angle of 62 degrees will require optimized flow rates, pipe rotation and mud rheology to
achieve hole cleaning. Follow hole cleaning guidelines outlined in operational specifics.
Reference RPs
.:. Standard Operating Procedure for Leak-off and Formation Integrity Tests
.:. Prudhoe Bay Directional Guidelines
.:. Lubricants for Torque and Drag Management.
.:. "Shale Drilling- Kingak & HrZ"
~:«~~~JN...~,.w",.,u..W.nm'''''''''''''''''''''''''''.WW'''~.:H'''····'·····'''N..U'''.^,"'".''''U''~~''··«::&~!I~~XXXX«*,~A",,''':I:Ia.lI_···'''''''''''·''''''''' .. :···XO(# , H:::;::~~*,-«<"''¡'¡I-II«{;''-i-'-·''-·' .............. .... .. :-..Ih.~,.¡.,...+;.:..,.,.,<-,.,.,.,__.¡.,.,.¡.......:"'.,.¡.,.,"'w............."'~,«-H~".¡.r""
Job 9: Case & Cement Production Hole
Hazards and Contingencies
~ The interval is planned to be cemented in a single stage with a 12.5 ppg lead (500'MD or 200'
TVD whichever is greater, above the Schrader Ma) and a 15.8 ppg tail (500' above the Kuparuk).
If a single stage cement job is deemed too risky, then a 2 stage cement job will be performed.
~ Ensure the lower production cement has reached a compressive strength of 500 psi prior to
freeze protecting. After freeze protecting the 7" x 9-5/8" casing outer annulus with dead crude
(2300' MD, 2221 'TVD), the hydrostatic pressure will be 7.7 ppg vs 8.5 ppg EMW of the formation
pressure immediately below the shoe. Ensure a double-barrier at the surface on the annulus
exists until the cement has set up for at least 12 hours. Trapped annulus pressure may be present
after pumping the dead crude as the hydrostatic pressure of the mud and crude could be
underbalanced to the open hole. (A second LOT will be required prior to displacing freeze
protect. This to satisfy AOGCC for future annular pumping permits.)
~ Ensure a minimum hydrostatic equivalent of 9.9 ppg on the Kuparuk formation during pumping of
cement pre flushes/chemical washes. Losses of hole integrity and packing off has resulted from a
reduction in hydrostatic pressure while pumping spacers and flushes.
~ Considerable losses during running and cementing the 7" longstring has been experienced on
offset wells. A casing running program will be jointly issued by the ODE and Drilling Supervisor
detailing circulating points and running speed. In addition an "LCM" pill composed of "Steel Seal"
will be placed across the Schrader and Ugnu to help arrest mud dehydration.
Reference RPs
.:. "Intermediate Casing and Cementing Guidelines"
.:. "Freeze Protecting an Outer Annulus"
.... ~11¡1I-1' .Ua- -¡. - ¡",;.I..'I ;-.;- '.....T -IT T.. .".
..1··....·.· ""'. "I" .
....;;IlI-- "I. ·'Io.¡:"'I;f T ... .... ~I:.... .-;'.....al-·...IIio. ·-m
V -103 Drilling Permit
Page 9
},
Job 12: Run Completion
Hazards and Contingencies
~ Watch hole fill closely and verify proper safety valves are on the rig floor while running this
completion. The well will be potentially underbalanced if there is a casing integrity problem.
~ Shear valves have been failing at lower than the 2500 psi differential pressure. When testing
annulus maintain no more than a 1500 psi differential: 3000 psi tubing pressure, 4500 psi annulus
pressure. Avoid cycling pressure (pumping up and bleeding off) prior to activating shear valve as
this is thought to cause shearing at lower pressures. Recommend having Camco rep on site to
witness valve shear.
Reference RPs
.:. uCompletion Design and Running"
.:. uFreeze Protection of Inner Annulus"
Job 13: ND/NU/Release Ria
Hazards and Contingencies
~ No hazards specific to this well have been identified for this phase of the well construction.
Reference RPs
.:. uFreeze Protection of Inner Annulus"
~o)(~~o»..:'»',""+:"oC««__...:<w:.;..o,\X<-~____-:«-:___'_««_:_~_':-:,'«:-:_"-""""'~I>"#.'«"I^'I~X#~~___~_':«+::',':','11::11.'1.':1-:
V-103 Drilling Permit
Page 1 0
TREE = . 4-1/16" CrN
WELLHEAD = FMC
'QM~!~f~9~:~::'~:::,:'::'::~::::'~'~'
"~B'F:""ECEV",';;M""'_^"""''''''~^'''M'''''''W^W~MNA'
KÕp";;;" ·"·""""'300'
:~~::~:~~~:i~=~,!~~~,~~~~~'
Datum MD =
'Öatum"iVÖ;" '''''" "Šãõ'Öï"ŠS
')
9-5/8" CSG, 40#, L-80, ID = 8.835" 1-1 3740' r-M
Minimum ID = 2.813" @ xxxx'
3-1/2" HES X NIPPLE
I 3-1/2" TBG, 9.2#, L-80, TCII, .0087 bpf, ID = 2.992"
13-1/2" TBG, 9.2#, L-80, TCII, .0087 bpf, ID = 2.992" 11 10947'
ÆRFORA TION SUMMARY
REF LOG: TCP ÆRF
ANGLE AT TOP ÆRF: xx @ xxxx'
Note: Refer to Production DB for historical perf data
SIZE SPF INTERV AL Opn/Sqz DA TE
I PBTD l-i 11532'
I 7" CSG, 26#, L-80, .0383 bpf, ID = 6.276" 1-1 11612'
V -1 03
):
=--1 1011' 1-1 9-5/8" TAM PORT COLLAR I
I ~ I 2200' l-l 3-1/2" HES X NIP, ID = 2.813" I
~ GAS LIFT MANDRELS
ST MD 1VD DEV TYÆ VLV LA TCH PORT I DATE
1 tbd MMG DCK-3 BTM 3.5x 1.5
2 5200 MMG Dummy BTM 3.5x1.5
3 3500 MMG Dummy BTM 3.5x1.5
L
-
I I
I
/
~
z
~t
I /
~
DA TE REV BY COMMENTS
08/15/02 jdf PROPOSED COMPLETION
DA TE REV BY
COMMENTS
10817' 1-13-1/2" BKR CMD SLIDING SL V, ID = 2.813"
/'
10827' II
7" X 3-1/2" BKR PREMIER PKR, ID =
2.992"
10887' 1-1 3-1/2" HES X NIP, ID = 2.813" I
10917' 1-1 3-1/2" HES X NIP, ID = 2.813"
1 0947' l-i 3-1/2" WLEG, ID = 2.875" 1
GPB BOREA LIS
WELL: V-103
ÆRMrT No:
API No:
SEC 11, T11 N, R11 E 4878' NSL & 1620' WEL
BP Exploration (Alas ka)
')
)
V-103 Well
Summary of Drillina Hazards
POST THIS NOTICE IN THE DOGHOUSE
Surface Hole Section:
· Gas hydrates may be encountered near the base of the Permafrost at 1867'MD and near the
TD hole section as well.
· Gravel beds below the Permafrost will tend to slough in when aerated (hydrate cut) mud is
being circulated out. Ensure adequate mud viscosity is maintained to avoid stuck pipe
situations.
Production Hole Section:
· A majority of the V-Pad development wells will have "kick tolerances" in the 25-45 bbl. A
heightened awareness of kick detection, pre-job planning and trip tank calibration will be
essential while drilling/tripping the intermediate/production intervals.
· The production section will be drilled with a recommended mud weight of 9.9 ppg to ensure
shale stability in the HRZ shale and to cover the Kuparuk 9.6 pore pressure.
· Tight hole, hole packing-off, and lost returns have been encountered in previous wells on this
pad. Pipe sticking tendency is possible if the HRZ shale gives problems. Back reaming at
connections and good hole cleaning practices have contributed to favorable hole conditions.
· V-103 will cross a fault at -5710' TVD (+/-125'). The estimated throw of the fault is
approximately 60'. Lost circulation is considered to be a minor risk. Consult the Lost
Circulation Decision Tree regarding LCM treatments and procedures.
HYDROGEN SULFIDE - H2S
. This drill-site not designated as an H2S drill site. Recent wells test do not indicate the
presence of H2S. As a precaution, Standard Operating Procedures for H2S precautions
should be followed at all times.
CONSULT THE V-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION
Version 1.0
Rigsite Hazards and Contingencies
ö
VERTICAL
Client:
Well:
Field:
Structure:
Section At:
SECTION VIEW
BP Exploration Alaska
V-103 (P4)
Date:
Prudhoe Bay Unit - WOA
V-Pad
18.83 deg
August 23, 2002
Schlumberuer
KOP Cry 1.5/1oœOO MD 300 TVD
0,00' 345,00' az 0 departure
CN 2.251100 567 MD 566 TVD
4,00' 345,00' az 8 departure
- Base Gubok328MD328Tvo-
!
- - --
Cry 31100 965 MD 961 TVD
1200' 18,95' az 61 departure
End CrY 2453 MD 2159 TVD
- -61-:31·T'1g94·aZ875departure - - - - - - - - - - - - - -
CN 2/100 1899 MD 1793 TVD
- ~- - - ~1~:~:~9;:~~;:~ - - - - - - - - - - - - - ~ - - - - - - - - - - - -
40 12" 18 95· az 529 departure
Cry 5/100 2099 MO 1945 TVD
4362' 1895· az 595 departure
- -- -------------
'Fnd"C'rv'm36'MD "1I743"lVo- _=--=-= -
38,12" 18,95' az ~ departure
------------'---------
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- 5Vs rflj¡ MD 9ð3 TŸD
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- 5V{'3532MD-2678TVD
9-518" Csg ~3740 MD 2778 TVD
-61-:3'1· 19,!W az~dej)ãrture -
--
- -UG4A 4220 MD 3ÔÕ8 ND
- Hoïd Angli61.31 0-
- UG34g. gMD~TŸD
, SBìgfTCIV3I100
, 7396 MD 4533 TVD
61,31' 19,94' az
5~O~r§e = = -
End CN '
H74};jD ::§7[:TVg::
60,75' 17,33' az
~78~pa~re_ _
-
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- -ObTBase 7959 MU 48U8 TVD -
- -on 8338 M!J '\'993 TVD -
- 'oprtRr10739 i;m æJ3 TVD - -
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-----
Dij:; 3.&100-
- - - '7' 9nOMD 566aW-
/"., 60.75' 17,33' az
/ i 7237 departure
End Drp I Kup 19t
11027MD-6673TVD
15,00' 17,33' az
~18~pa~r:":'
- - --
Holq Angle 60.750
------
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------
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1iQ]d]\[g~ 15110:
8000 -
---~-~~-
1D17" Csg PI
11612MD 7237TVD '
15,00' 17,33' az
8170 departure
---~--
I
-2000
I
o
Vertical Section Departure at 18.83 deg from (0.0, 0.0). (1 in =
2000
I
4000
I
6000
I
8000
2000 feet)
I
10000
6000
--2000
-0
- 2000
- 4000
- 6000
- 8000
- 10000
6000
Schlumberger
i
I
I
4000
EAST »>
I
I
2000
1899 MD 1793 TVD
38,12" 18,95" az
445N 139E
~- Cry 3.51100
1999MD ,1870TVD
- - 40,120- '18,95" az
504 IJ 159 E
Cry 2/100
S8 TgI 1 Cry 3/100
, naß.M.D."",.4,ii,~;¡,IYI;l".
61,31' 19,94" az
4907 N 1753 E
End Cry
- 7474 MD 4570 TVD
60,75" 17.33" az
4972 N 1775 E
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End Drp 1 Kup Tgt
110.7 MD 6673 TVD
15.00" 17.33" az
758E N 2592 E
Drp 3.5J1oo
9720 MD 5668 TVD
60.75" 17.33" az
..".!ì,ß'!,~,J':t ,,~,3,ii9,¡;; ,"
TD/7" Csg PI
11612MD 7237TVD
15,00" 17,33" az
7732 N 2637 E
4000
2000
I
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I
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End Cry
1836 MD 1743 TVD
38,12" 18,95'az ~
407 N 126 E
Cry 3/100
965 MD 961 TVD
12,00" 18.95" az~
62 N 7 E ~
,.."""",..."",,'1:'..
Cry 2'251100~1
567 MD 566 TVD
4,00" 345,00" az
9N 2W
KOP Cry 1.51100
300 MD 300 TVD
0,00" 345,00" az
ON OE
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·f
~
~
£
-2000 -
0-
2000 -
~
True North
Mag Dee ( E 25.78°
o
-2000
23-Aug-2002
Date:
PLAN VIEW
Client: BP Exploration Alaska
Well: V-103 (P4)
Field: Prudhoe Bay Unit - WOA
Structure: V-Pad
Scale: 1 in = 2000 ft
')
)
6000 -
10000 -
ObP
I ' , ' '~ I ~
' ", , "
I
I-
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V
V
V
4000
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8000
ò
I
KBE
KOP Crv 1.5/100
Base Gubik
Crv 2.25/100
Crv 3/100
SV6
Report Date:
Client:
Field:
Structure / Slot:
Well:
Borehole:
UWIIAPI#:
Survey Name / Date:
Tort / AHD / DDI / ERD ratio:
Grid Coordinate System:
Location Lat/Long:
Location Grid N/E YlX:
Grid Convergence Angle:
Grid Scale Factor:
V-103
Proposed Well Profile - Geodetic Report
August 23, 2002
BP Exploration Alaska
Prudhoe Bay Unit - WOA (Drill Pads) /21/02
~::~r-103 APpro"ed 8
50029
V-103 (P4) I August 23,2002
110.383° /8174.23ft/6.161/1.12~
NAD27 Alaska State Planes, Zone 4, US Feel
N 70.32811850, W 149.2645704E
N 5970126.970 ftUS, E 590680.230 ftUS
-t{).69251116°
0.99990934
Survey / DLS Computation Method:
Vertical Section Azimuth:
Vertical Section Origin:
TVD Reference Datum:
TVD Reference Elevation:
Sea Bed / Ground Level Elevation:
Magnetic Declination:
Total Field Strength:
Magnetic Dip:
Declination Date:
Magnetic Declination Model:
North Reference:
Total Corr Mag North·> True North:
Local Coordinates Referenced To:
Schlumberger
Minimum Curvature I Lubinski
18.830°
N 0.000 ft, E 0.000 ft
KB
82.5 ft relative to MSL
55.000 ft relative to MSL
25.780°
57505.982 nT
80.771°
October 17 2002
BGGM 2002
True North
+25.780°
Well Head
'~
Grid Coordinates Geographic Coordinates
MD I Incl I Azim TVD I VSec I N/-S I E/·W DLS Northing I Easting Latitude I Longitude
(ft) (0) (0) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS)
0.00 0.00 345.00 0.00 0.00 0.00 0.00 0.00 5970126.97 590680.23 N 70.32811850 W 149.26457045
300.00 0.00 345.00 300.00 0.00 0.00 0.00 0.00 5970126.97 590680.23 N 70.32811850 W 149.26457045
327.50 0.41 345.00 327.50 0.08 0.10 -0.03 1.50 5970127.07 590680.20 N 70.32811877 W 149.26457069
400.00 1.50 345.00 399.99 1.09 1.26 -0.34 1.50 5970128.23 590679.87 N 70.32812194 W 149.26457320
500.00 3.00 345.00 499.91 4.35 5.06 -1.35 1.50 5970132.01 590678.82 N 70.32813232 W 149.26458139
566.67 4.00 345.00 566.45 7.73 8.99 -2.41 1.50 5970135.93 590677.71 N 70.32814306 W 149.26458999
600.00 4.53 352.09 599.69 9.87 11 .42 -2.89 2.25 5970138.35 590677.20 N 70.32814969 W 149.26459388
700.00 6.40 5.48 699.24 18.83 20.88 -2.90 2.25 5970147.81 590677.08 N 70.32817554 W 149.26459396
800.00 8.46 12.63 798.39 31.57 33.61 -0.76 2.25 5970160.57 590679.06 N 70.32821032 W 149.26457661
900.00 10.59 16.96 897.01 48.06 49.58 3.53 2.25 5970176.58 590683.16 N 70.32825394 W 149.26454182
'-
964.92 12.00 18.95 960.67 60.78 61.67 7.46 2.25 5970188.72 590686.94 N 70.32828697 W 149.26450995
966.79 12.06 18.95 962.50 61.17 62.04 7.59 3.00 5970189.09 590687.07 N 70.32828798 W 149.26450890
1000.00 13.05 18.95 994.92 68.39 68.87 9.93 3.00 5970195.95 590689.33 N 70.32830664 W 149.26448992
1100.00 16.05 18.95 1091.70 93.51 92.63 18.09 ~.OO 5970219.80 590697.20 N 70.32837155 W 149.26442375
1200.00 19.05 18.95 1187.03 123.66 121.15 27.88 3.00 5970248.44 590706.64 N 70.32844947 W 149.26434436
1300.00 22.05 18.95 1280.65 158.77 154.35 39.28 3.00 5970281.77 590717.64 N 70.32854017 W 149.26425191
1400.00 25.05 18.95 1372.31 198.72 192.14 52.26 3.00 5970319.71 590730.16 N 70.32864341 W 149.26414665
1500.00 28.05 18.95 1461.75 243.42 234.41 66.77 3.00 5970362.15 590744.16 N 70.32875888 W 149.26402898
Station ID
V-103 (P4) report.xls
Page 1 of 3
8/23/2002-10:49 AM
Grid Coordinates Geographic Coordinates
Station ID MD Incl Azim TVD VSec Nl-S I El-W DLS Northing I Easting Latitude I Longitude
(ft) (0) (0) (ft) (ft) (ft) (ft) (0/10Oft) (ftUS) (ftUS)
1600.00 31.05 18.95 1548.74 292.73 281.05 82.79 3.00 5970408.97 590759.61 N 70.32888630 W 149.26389907
1700.00 34.05 18.95 1633.02 346.53 331.94 100.26 3.00 5970460.07 590776.46 N 70.32902533 W 149.26375739
1800.00 37.05 18.95 1714.36 404.67 386.93 119.14 3.00 5970515.28 590794.67 N 70.32917555 W 149.26360427
End Cry 1835.51 38.12 18.95 1742.50 426.33 407.41 126.17 3.00 5970535.84 590801.46 N 70.32923150 W 149.26354726
Base Permafrost 1867.28 38.12 18.95 1767.50 445.94 425.96 132.54 0.00 5970554.46 590807.60 N 70.32928218 W 149.26349560
Cry 2/100 1899.06 38.12 18.95 1792.50 465.56 444.51 138.91 0.00 5970573.09 590813.74 N 70.32933286 W 149.26344394
1900.00 38.14 18.95 1793.24 466.14 445.06 139.10 2.00 5970573.64 590813.93 N 70.32933436 W 149.26344240
SV4 1995.68 40.05 18.95 1867.50 526.47 502.13 158.69 2.00 5970630.93 590832.83 N 70.32949027 W 149.26328352
Cry 3.5/100 1999.06 40.12 18.95 1870.08 528.65 504.18 159.40 2.00 5970632.99 590833.51 N 70.32949587 W 149.26327776
2000.00 40.15 18.95 1870.80 529.25 504.76 159.60 3.50 5970633.58 590833.70 N 70.32949745 W 149.26327614
Cry 5/100 2099.06 43.62 18.95 1944.54 595.38 567.30 181.07 3.50 5970696.36 590854.41 N 70.32966830 W 149.26310201 '-
2100.00 43.66 18.95 1945.22 596.03 567.91 181.28 5.00 5970696.98 590854.62 N 70.32966997 W 149.26310031
---
2200.00 48.66 19.29 2014.46 668.13 636.04 204.91 5.00 5970765.38 590877.42 N 70.32985609 W 149.26290866
2300.00 53.65 19.57 2077.16 745.99 709.46 230.81 5.00 5970839.10 590902.43 N 70.33005667 W 149.26269860
2400.00 58.65 19.82 2132.84 829.01 787.63 258.80 5.00 5970917.60 590929.47 N 70.33027022 W 149.26247158
End Cry 2453.19 61.31 19.94 2159.45 875.05 830.93 274.46 5.00 5970961.08 590944.60 N 70.33038851 W 149.26234457
SV3 2636.58 61.31 19.94 2247.50 1035.89 982.16 329.33 0.00 5971112.95 590997.64 N 70.33080165 W 149.26189951
SV2 2907.35 61.31 19.94 2377.50 1273.36 1205.43 410.35 0.00 5971337.16 591075.94 N 70.33141160 W 149.26124233
SV1 3532.20 61.31 19.94 2677.50 1821.38 1720.68 597.31 0.00 5971854.58 591256.65 N 70.33281918 W 149.25972566
9-5/8" Csg Pt 3740.48 61.31 19.94 2777.50 2004.05 1892.43 659.63 0.00 5972027.06 591316.88 N 70.33328837 W 149.25922006
UG4A 4219.53 61.31 19.94 3007.50 2424.20 2287.46 802.97 0.00 5972423.76 591455.42 N 70.33436752 W 149.25805706
UG3 4948.53 61.31 19.94 3357.50 3063.56 2888.59 1021.09 0.00 5973027.42 591666.24 N 70.33600968 W 149.25628709
UG1 5958.70 61.31 19.94 3842.50 3949.52 3721.58 1323.35 0.00 5973863.93 591958.38 N 70.33828521 W 149.25383388
Ma 6354.44 61.31 19.94 4032.50 4296.60 4047.90 1441.76 0.00 5974191.62 592072.83 N 70.33917662 W 149.25287269
Na 6833.49 61.31 19.94 4262.50 4716.75 4442.93 1585.09 0.00 5974588.32 592211.36 N 70.34025573 W 149.25170910
Oa 7156.33 61.31 19.94 4417.50 4999.89 4709.14 1681.69 0.00 5974855.65 592304.73 N 70.34098294 W 149.25092480
SB Tgt / Cry 3/100 7395.86 61.31 19.94 4532.50 5209.97 4906.65 1753.36 0.00 5975054.00 592374.00 N 70.34152247 W 149.25034288 '~
7400.00 61.28 19.81 4534.49 5213.60 4910.07 1754.59 3.00 5975057.43 592375.19 N 70.34153181 W 149.25033289
End Cry 7474.19 60.75 17.33 4570.45 5278.49 4971.58 1775.26 3.00 5975119.18 592395.11 N 70.34169984 W 149.25016505
Obf Base 7959.31 60.75 17.33 4807.50 5701.60 5375.61 1901.37 0.00 5975524.67 592516.32 N 70.34280353 W 149.24914089
CM2 8337.91 60.75 17.33 4992.50 6031.81 5690.93 1999.79 0.00 5975841.12 592610.91 N 70.34366488 W 149.24834153
Drp 3.5/100 9720.14 60.75 17.33 5667.92 7237.37 6842.13 2359.11 0.00 5976996.48 592956.26 N 70.34680957 W 149.24542259
9800.00 57.95 17.33 5708.63 7306.04 6907.71 2379.58 3.50 5977062.29 592975.93 N 70.34698871 W 149.24525628
9900.00 54.45 17.33 5764.24 7389.10 6987.02 2404.33 3.50 5977141.89 592999.72 N 70.34720535 W 149.24505518
10000.00 50.95 17.33 5824.83 7468.62 7062.95 2428.03 3.50 5977218.09 593022.50 N 70.34741277 W 149.24486262
V-103 (P4) report.xls Page 2 of 3 8/23/2002-10:49 AM
Grid Coordinates Geographic Coordinates
I Station ID MD I Incl Azim TVD VSec N/-S EI·W I DLS Northing I Easting Latitude I Longitude
(ft) (0) (0) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS)
CM1 10050.90 49.17 17.33 5857.50 7507.63 7100.20 2439.66 3.50 5977255.48 593033.68 N 70.34751452 W 149.24476812
10100.00 47.45 17.33 5890.15 7544.28 7135.20 2450.58 3.50 5977290.60 593044.17 N 70.34761013 W 149.24467939
10200.00 43.95 17.33 5959.98 7615.82 7203.51 2471.91 3.50 5977359.16 593064.67 N 70.34779672 W 149.24450608
10300.00 40.45 17.33 6034.05 7682.96 7267.63 2491.92 3.50 5977423.51 593083.91 N 70.34797188 W 149.24434348
10400.00 36.95 17.33 6112.07 7745.46 7327.31 2510.55 3.50 5977483.41 593101.81 N 70.34813490 W 149.24419210
10500.00 33.45 17.33 6193.77 7803.08 7382.33 2527.72 3.50 5977538.62 593118.31 N 70.34828519 W 149.24405258
10600.00 29.95 17.33 6278.84 7855.61 7432.49 2543.37 3.50 5977588.97 593133.36 N 70.34842221 W 149.24392541
10700.00 26.45 17.33 6366.95 7902.84 7477.59 2557.45 3.50 5977634.23 593146.89 N 70.34854541 W 149.24381099
Top HRZ 10739.47 25.07 17.33 6402.50 7919.99 7493.97 2562.56 3.50 5977650.67 593151.80 N 70.34859015 W 149.24376947
10800.00 22.95 17.33 6457.78 7944.61 7517.48 2569.90 3.50 5977674.26 593158.85 N 70.34865437 W 149.24370982
Base HRZ 10896.29 19.58 17.33 6547.50 7979.52 7550.82 2580.31 3.50 5977707.72 593168.86 N 70.34874544 W 149.24362523 -'
10900.00 19.45 17.33 6551.00 7980.76 7552.00 2580.68 3.50 5977708.91 593169.22 N 70.34874867 W 149.24362222
K-1 10985.68 16.45 17.33 6632.50 8007.16 7577.21 2588.55 3.50 5977734.21 593176.78 N 70.34881753 W 149.24355826
11000.00 15.95 17.33 6646.25 8011.16 7581.03 2589.74 3.50 5977738.04 593177.92 N 70.34882797 W 149.24354859
End Orp / Kup Tgt 11027.24 15.00 17.33 6672.50 8018.42 7587.96 2591.90 3.50 5977745.00 593180.00 N 70.34884690 W 149.24353104
Top Kuparuk / C 11027.25 15.00 17.33 6672.51 8018.43 7587.97 2591.90 0.00 5977745.01 593180.00 N 70.34884692 W 149.24353104
LCU / Kup B 11120.41 15.00 17.33 6762.50 8042.53 7610.98 2599.09 0.00 5977768.10 593186.91 N 70.34890978 W 149.24347261
KupA 11265.35 15.00 17.33 6902.50 8080.03 7646.79 2610.26 0.00 5977804.04 593197.64 N 70.34900760 W 149.24338184
TMLV 11462.05 15.00 17.33 7092.50 8130.92 7695.39 2625.43 0.00 5977852.81 593212.22 N 70.34914035 W 149.24325856
TO / 7" Csg Pt 11612.05 15.00 17.33 7237.39 8169.73 7732.45 2637.00 0.00 5977890.01 593223.34 N 70.34924159 W 149.24316453
Leaal Description:
Surface: 4878 FSL 1620 FEL S11 T11N R11E UM
Schrader Target : 4505 FSL 5142 FEL S1 T11N R11E UM
Kuparuk Target: 1905 FSL 4301 FEL S36 T12N R11E UM
BHL: 2050 FSL 4256 FEL S36 T12N R11E UM
Northina (Y) rftUSl
5970126.97
5975054.00
5977745.00
5977890.01
Eastina eX) rftUSl
590680.23
592374.00
593180.00
593223.34
.---
V-103 (P4) report.xls
Page 3 of 3
8/23/2002-10:49 AM
)
)
Schlumberger
Anticollision Report
Company: BP Amoco
Field: Prudhoe Bay
Reference Site: PB V Pad
Reference Well: V-103
Reference Wellpath: Plan V., 1 03
NO GLOBAL SCAN: Using user defined selection & scan criteria
Interpolation Method: MD Interval: 50.00 ft
Depth Range: 28.50 to 11612.05 ft
Maximum Radius: 3000.00 ft
Survey Program for Definitive Well path
Date: 9/13/2001 Validated: No
Planned From To Survey
ft ft
28.50 1000.00 Planned: Plan #4 V1
1000.00 11612.05 Planned: Plan #4 V1
Casing Points
MD
ft
3740.48
11612.05
TVD
ft
2777.50
7237.38
12.250
8.750
95/8"
7"
Diameter
in
Hole Size
in
Name
9.625
7.000
Summary
<---------.,------- Offset Wellpath -----------------.,-->
Site Well Wellpatb
PB V Pad
PB V Pad
PB V Pad
PB V Pad
PB V Pad
PB V Pad
PB V Pad
PB V Pad
PB V Pad
V-100
V-101
V-102
V-104
V-105
V-106
V-107
V-108
V-201
V-100 V7
V-101 V7
V-102 V5
V-104 V10
Plan V-105 V11 Plan: P
V-106 V10
Plan V-107 V4 Plan: PI
Plan V-108 V4 Plan: PI
V-201 V8
J);de: 8/23/2002
Time: 13:14:07
Page:
Co-ordinate(NE) Reference:
Vertical (TVD) Reference:
Well: V-103,TrueNorth
V-103 plan 82.5
Reference:
Error Model:
Scan Method:
Error Surface:
Db: Sybase
Principal Plan & PLANNED PROGRAM
ISCWSA Ellipse
Trav Cylinder North
Ellipse + Casing
Version: 3
Toolcode
Tool Name
CB-GYRO-SS
MWD+IFR+MS
Camera based gyro single shots
MWD + IFR + Multi Station
Reference Offset Ctr-Ctr ,No-Go Allowable
MD MD Distance' Area Deviation Warning
ft ft ft ft ft
298.90 300.00 186.91 6.37 180.54 Pass: Major Risk
598.00 600.00 262.85 11.35 251.51 Pass: Major Risk
550.08 550.00 145.28 11.94 133.34 Pass: Major Risk
500.25 500.00 206.97 9.74 197.24 Pass: Major Risk
549.45 550.00 76.07 12.15 63.92 Pass: Major Risk
599.07 600.00 28.27 10.86 17.42 Pass: Major Risk
597.51 600.00 175.68 12.98 162.70 Pass: Major Risk
500.20 500.00 295.76 10.59 285.17 Pass: Major Risk
499.09 500.00 162.62 9.72 152.91 Pass: Major Risk
Field: Prudhoe Bay
Site: PB V Pad
Well: V-103
Wellpath: Plan V-I03
\··F;'\-I'-'~,
21
'~
--
181:1 .:Y<JI
Tm~ C~1iDdtr .-\zi.uth (TrD+..QI) {~] nCml.n-toCm~ Srp.J.r.atiOA (lØ6f1!"m
Polygon
1
2
3
4
Site: PB V Pad )
Drilling Target Conf.: 99%
Description:
Map Northing: 5975054.00 ft
Map Easting: 592374.00 ft
Latitude: 70°20'29.481 N
+N/-S ft
-170.65
-21.89
196.90
53.15
Target: V -103 SB Tgt
+E/-W ft
133.96
-174.29
-71.63
236.68
)11: V-I03
....dSed on: Planned Program
Vertical Depth: 4450.00 ft below Mean Sea Level
Local +N/-S: 4906.64 ft
Local +E/-W: 1753.36 ft
Longitude: 149° 15'0 1.234 W
Northing ft
5974885.00
5975030.00
5975250.00
597511 0.00
Easting ft
592510.00
592200.00
592300.00
592610.00
5300
5200
5100
5000
4-900
4-800
4-l00
4-500
~ CJ CJ CJ CJ CJ CJ CJ CJ
CJ CJ CJ CJ CJ CJ CJ CJ
~ ~ Ln LD I m a- CJ N
N N N
9 ~
j
Target: V -103 Kup Tgt
Site: PB V Pad )
Drilling Target Conf.: 99%
Description:
Map Northing: 5977745.00 ft
Map Easting : 593180.00 ft
Latitude: 70020'55.849N
Shape: Circle
+:
)1: V-103
uased on: Planned Program
Vertical Depth: 6590.00 ft below Mean Sea Level
Local +N/-S: 7587.95 ft
Local +E/-W: 2591.90 ft
Longitude: 149°14'36.712W
Radius: 150 ft
900
l800
llOO
l500
lSOO
llrOO
l300
0 CJ CJ CJ CJ CJ CJ CJ
o 0 CJ CJ CJ CJ CJ CJ CJ
0 o ~ -=J- Ln LO I IT) a- D
( ~ N N N N N N (I)
0 0
0 ~ ~
~ ~
·
.~
)
.\tAtt. bp
.~.;:: ~~.
.-..- -.-.
.......~ ~...---
·'1'·'1'-
".
)
~... .
To:
Winton Aubert, AOGCC
Date: August 28, 2002
From: J ames Franks
Subject: Dispensation for 20 AAC 25.035 (c) on V-I03
BP Alaska Drilling and Wells requests your consideration of a waiver of the diverter
system identified in 20 AAC 25.035 (c) "Secondary Well Control for Primary Drilling
and Completion: Blowout Prevention Equipment and Diverter Requirements".
Experience and data gathered, summarized herein, support the rationale for the request.
To date, none of the Borealis/Kuparuk wells at L-pad or V -pad, nor the two NWE wells
I-Oland 1-02 drilled in 1998 experienced pressure control or shallow gas problems
above the surface casing depth, apart from minor and inconsequential hydrate shows.
All of the Borealis Development were drilled to the shale underlying the SVl sands.
The shale underlying the SV 1 is the deepest planned surface casing setting depth for
future pad development wells. This casing point is ±200' TVD above the U gnu horizon.
RFT's from NWE 1-02 recorded pore pressures of 1,275 psi at 2782' TVDss (8.8 ppg
EMW) and 1387 psi at 3059' TVDss (8.7 ppg EMW) in the Ugnu. V-I03 is planned to
reach a 9.5 ppg mud weight before TD at -2,778' TVDss.
This request is being made based on V-Pad data submitted regarding mud weight,
surface open hole logging in the Borealis development (PEX/Dipole sonic), and a
meeting between Jack Hartz, Robert Crandall, Steve Davies, Bob Dawson (BP), Ray
Eastwood (BP) and Kip Cerveny (BP).
Your consideration of the waiver is appreciated.
Sincerely,
~?
%
J s M"nks
GPB Rotary Drilling Engineer
564-4468
f -,"
~..;;.
i.- r. '). :
Z~QD::~
-, .,--
Aìaska Oil & D(;¡;:: LJün::;, vUII\lil¡~~¡Ü¡'
Anchorage
~L-114
. L-115
L-119
L-105
10
Page 1
.-L-110
--L-106
L-102
e L-103
--L-116
---L-107
..", L-120
A( L-108
t L -01
):( Pore Pressure
- --. L-104
L-109
x
.
~1
,
Borealis Surface Hole Mud Weight
MW (ppg)
9
9.5
8.5
)
)
3000
2500
.c
....
g. 2000
c
.-.
.c
~ 1500
c
>
I-
----
1000
500
8
o I
..... "
"
,
)
)
-f' .r '
8
o
Borealis Surface Hole Mud Weight
MW (ppg)
9
8.5
9.5
10
~
500
1000
.-.
.c
~ 1500 I
c
>
I-
---
.c
Q. 2000
Q)
c
2500
..
3000
3500 I
I-+-V-101 ---Pore Pressure ~V-102
V-106 ----V-104i I
H
207038
DATE
INVOICE I CREDIT MEMO
DESCRIPTION
J8/01/02 CK073102E
Permit to Dril~ Fee
DATE
8/01/02
CHECK NO.
H207038
GROSS
VENDOR
DISCOUNT
NET
$100.00
-; :..;-. ~
PIs contact Sondra Stewman X4750
for check picku?
~.\OÖ
THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE.
TOTAL ~
BP EXPLORATION, (ALASKA) INC.
P.O. BOX 196612
ANCHORAGE, ALASKA 99519-6612
PAY
B pr:~ ·ru.(1J~ ('Iht .(J CÞI;I~:
. .-:- _.J flIP {fil- ' 'Jllla Ðtllt. ......
TO THE
ORDER
OF
AlaskaOil & Gasu.Cons~rvation
333 W7thAve,Ste 100
Anchorage ,.AK ,99501
$100.00
FIRST NATIONAL BANK OF ASHLAND
AN AFFlUATE OF
NATIONAL CITY BANK
CLEVELAND, OHIO
No. H207038
CONSOLIDATED COMMERCIAL ACCOUNT
56-389
412
AMOUNT
***Auq~·l, 2002** *****$100.00*******
NOTVAlID AFTER 120DAYS
~~.~?:~.\.::;:t;· :::1~::~:).:::·)::·~:: .~;~. ·;:.~,~~~i:~::;~}:~.~:~§ ::\:;f.\
'h'·· ":::~>.¿,~;1,... ...... '..ft. ...... .....,. .....
Hklr.t.1{f~~:·2\~:.;t::::~>.
::,::::: .;:::::. .-;:::::,:;::. ~ ?::..~::::.. ::.~ ~:.. ";::::";".:::: ..::~ ::"::~::"i ~:.~
II- 20 ? 0 :i 8 II- I: 0 ~ . 2 0 :ì a q 51: 0 0 8 ~ ~ . q II-
')
)
TRANSMIT AL LETTER CHECK LIST
CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO
BE INCLUDED IN TRANSMITTAL LETTER
WELL NAME /¿Cf
t/-/ð.3
PTD# 2n7 - I~h
CHECK WHAT
APPLIES
ADD-ONS
(OPTIONS)
MULTI
LATERAL
(If API num ber
last two (2) digits
are between 60-69)
"CLUE"
The permit is for a new wellbore segment of
existing well
Permit No, API No.
Production should continue to be reported as
a function' of the original API number stated
above.
HOLE In accordance with 20 AAC 25.005(t), all
records, data and logs acquired for the pilot
hole must be clearly differentiated in both
name (name on permit plus PH)
and API number (50
70/80) from records, data and logs acquired
for well (name on permit).
PILOT
(PH)
SPACING
EXCEPTION
DRY DITCH
SAMPLE
Rev: 07/10/02
C\jody\templates
The permit is approved subject to full
compliance with 20 AAC 25.055. Approval to
peñorate and produce is contingent upon
issuance of a conservation order approving a
spacing exception.
(Company Name) assumes the liability of any
protest to the spacing exception that may
occur.
All dry ditch sample sets submitted to the
Commission must be in no greater than 30'
sample intervals from below the permafrost
or from where samples are first caught and
10' sample intervals through target zones.
WELL PERMIT CHECKLIST COMPANY A/X' WELLNAMEß/.( t!-/ð3 PROGRAM: Exp_ Dev~ Redrll_ Re-Enter_ Serv_ Wellboreseg_
FIELD & POOL ~ <7~/ ? ð INIT CLASS /)c.f/ - / - ~, ï
ADMINISTRATION 1. Permittee attached. . . . . . . . . . . . . . . . . . . . . . . ? N
2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N
3. Unique well name and number. . . . . . . . . . . . . . . . . Y N
4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N
5. Well located proper distance from drilling unit boundary. Y N
6. Well located proper distance from other wells.. . . . . . . . . Y N
7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N
.'¿2. C7 /.. /Þ2.. 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N
pi-'=- ~4 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N
10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N
11. Permit can be issued without conservation order. . . . . . . . Y N
12. Permit can be issued without administrative approval.. . . . . ~ N
(Service Well Only) 13. Well located w/in area & strata authorized by injection order #_ Y ß
(Service Well Only) 14. All wells wlin }'4 mile area of review identified. . . . . . . . .. /' N A/~.¡c.¡. ,
ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . ~N 'l,o II @ il 0
16. Surface casing protects all known USDWs. . . . . . . Y N
17. CMT vol adequate to circulate on conductor & surf csg. N ¡Up ç L<.J' ,h et usç .
18. CMT vol adequate to tie-in long string to surf csg. . Y ~ \ ~ 0
19. CMT will cover all known productive horizons. . . . . . j N
20. Casing designs adequate for C, T, B & permafrost. . . ,N ,
21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . N ¡Ú-tVÍJovs. ~ tEe;
22. If a re-drill, has a 10-403 for abandonment been approved. ~ /Ii./A-
23. Adequate wellbore separation proposed.. . . . . . . . . . . . 6l N , ' t- t \ I J'>' . / J
24. If diverter required, does it meet regulations. . . . . . . . . . ~tt...t t/4-y- r-e,,_~S-.-kJ.- (U>A-1.-c.......: s'{-cÞL- 1.-<....c...Ct-t."- fJ v1(,;I v L- Cù.{J 'l..' fJc(Q
25. Drilling fluid program schematic & equip list adequate. . . . . N IÞl <.~ /VlyJ 'Y I q PP1 . d-'ll (1· e~1'..e-(. L è("
26. BOPEs, do they meet regulation. . . . . ~ ¡ . . . . . . . . . N., 0 ¡
27. BOPE press rating appropriate; test to ,.5'00 psig. N rn S P L 71 u P ~ l .
I. Jt.;.k Q (r.{o L 28. Choke manifold complies w/API RP-53 (May 84) . ...... N
\N' l oJ 29. Work will occur without operation shutdown. . .. ...... N
30. Is presence of H2S gas probable.. . . . . . . . . dSV
31. Mechanical condition of wells within AOR verified. . . . . . . . -¥-N- Ail A;;-
@N
Uy A).A,
Y N
N
APPR
DATE
APPR
DATE
(Service Well Only)
GEOLOGY
APPR DATE
I~i <t/~47
~xploratory Only)
Rev: 07/12/02
GEOL AREA
rid
//6~)r1
ON/OFF SHORE-dN
UNIT#
('
\,
32. Permit can be issued wlo hydrogen sulfide measures. . . . .
33. Data presented on potential overpressure zones. . . . . . . .
34. Seismic analysis of shallow gas zones. . . . . . . . . . . . .
35. Seabed condition survey (if off-shore). . . . . .. ......
36. Contact namelphone for weekly progress reports. ......
(
GEOLOGY:
RP</If'!
PETROLEUM ENGINEERING:
TEM
RESERVOIR ENGINEERING
-
JDH" '\./r
UIC ENGINEER
JBR
COMMISSIONER:
Comments/Instructions:
COT f I
DTS O? ÔS O~
SFD_
WGA yJC,¡ Rr
MJW
G:\geology\perm its\checklist.doc
