Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
Loading...
HomeMy WebLinkAbout209-012Kaitlyn Barcelona Hilcorp North Slope, LLC
GeoTechnician 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: 907 564-4389
E-mail: kaitlyn.barcelona@hilcorp.com
Please acknowledge receipt by signing and returning one copy of this transmittal
Received By: Date:
DATE: 05/23/2022
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
DATA TRANSMITTAL
PBU 06-14B (PTD 209-012)
PPROF 05/06/2022
Report 05/11/2022
Please include current contact information if different from above.
PTD:209-012
T36646
Kayla
Junke
Digitally signed by
Kayla Junke
Date: 2022.05.25
09:54:01 -08'00'
OPERABLE: 06 -14B (PTD #2090120) Tubinggegrity Restored • Page Lo& -3""
Regg, James B (DOA)
From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com
Sent: Wednesday, October 12, 2011 7:16 PM ? 10111311i
To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); AK, OPS FS3 OSM; AK, OPS
FS3 DS Ops Lead; AK, OPS FS3 DS Operators; AK, D &C Well Services Operations Team Lead; AK, D &C
Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK,
RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; G GPB FS3 Drilisites
Cc: Walker, Greg (D &C); Arend, Jon (NORTHERN SOLUTIONS LLC); Olson, Andrew
Subject: OPERABLE: 06 -14B (PTD #2090120) Tubing Integrity Restored
All,
ZCRo1zc
Producer 06 -14B (PTD #8€9935) passed a TIFL after the orifice gas lift valve was changed out. The
passing test verifies two competent barriers and the well is reclassified as Operable.
Thank you,
Mehreen Vazir
rAlternate: Gerald Murphy)
Well Integrity Coordinator
BP Alaska Drilling & Wells
Well Integrity Office: 907.659.5102 -
ii; � : .
Email: AKDCWeIIIntegrityCoordinator @BP.com
From: AK, D &C Well Integrity Coordinator
Sent: Sunday, October 02, 2011 8:44 PM
To: 'Regg, James B (DOA); 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS FS3 OSM; AK, OPS,FS`3 DS Ops Lead; AK,
OPS FS3 DS Operators; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel,
Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; G GPB Drillsites
Cc: AK, D &C Well Integrity Coordinator; King, Whitney �1"
Subject: UNDER EVALUATION: 06 -14B (PTD #2090120) TxIA Communication - Failed y4:
All, /
Producer 06 -14B (PTD #2090120) failed a TIFL on 09/29/ 011. The well is currently under evaluation for
IA over MOASP during the pro- ration.
Plan forward:
1. Slickline: Change out the orifice gas lift val -. Set tubing tail plug.
2. Fullbore: MIT -T and CMIT -TxIA
3. Slickline pending: If MIT's fail, dumm, gas lift valves and MIT -IA
A TIO plot and wellbore schemati- have been included for reference.
« File: Producer 06 -14 B (r D # 2090120) TIO Plot.doc »
Please call if you have - y questions or concerns.
Thank you,
10/13/2011
UNDER EVALUATION: 06 -14B (PTD1090120) TxIA Communication - FaileeIFL Page 1 of 2
Regg, James B (DOA)
From: AK, D &C Well Integrity Coordinator [ AKDCWellIntegrityCoordinator @bp.com]
Sent: Sunday, October 02, 2011 8:44 PM Z 101 (cI II
To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); AK, OPS FS3 OSM; AK,
OPS FS3 DS Ops Lead; AK, OPS FS3 DS Operators; AK, D &C Well Services Operations Team Lead;
AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells
Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; G GPB FS3 Drillsites
Cc: AK, D &C Well Integrity Coordinator; King, Whitney
Subject: UNDER EVALUATION: 06 -14B (PTD #2090120) TxIA Communication - Failed TIFL
Attachments: Producer 06 -14 B (PTD # 2090120) TIO Plot.doc; Producer 06 -14 B (PTD # 2090120) wellbore
schematic.pdf
All,
Producer 06 -14 (PTD #2090120) failed a TIFL on 09/29/2011. The well is currently under evaluation for
IA over MOASP during the pro- ration.
Plan forward:
1. Slickline: Change out the orifice gas lift valve. Set tubing tail plug.
2. Fullbore: MIT -T and CMIT -TxIA
3. Slickline pending: If MIT's fail, dummy gas lift valves and MIT -IA
A TIO plot and wellbore schematic have been included for reference.
«Producer 06 -14 B (PTD # 2090120) TIO Plot.doc» «Producer 06 -14 B (PTD # 2090120) wellbore
schematic.pdf»
Please call if you have any questions or concerns.
Thank you,
Gerald Murphy (alt. Mehreen Vazir)
Well Integrity Coordinator ; : ;, , �F '`;; 4-
Office (907) 659 -5102
Cell (907) 752 -0755
Pager (907) 659 -5100 Ext. 1154
From: AK, D &C Well Integrity Coordinator
Sent: Monday, September 26, 2011 11:35 AM
To: AK, OPS FS3 OSM; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 DS Operators; AK, D &C Well Services Operations Team Lead; AK, D &C
Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK,
OPS PCC EOC TL; G GPB FS3 Drillsites
Cc: AK, D &C Well Integrity Coordinator; King, Whitney
Subject: UNDER EVALUATION: 06-14B (PTD #2090120) Evaluate for High IA Pressure During TAR
All,
Producer 06 -14B (PTD #2090120) had sustained IA pressure above the MOASP during the TAR. The
well is now ready to be brought online to perform a TIFL. In the event the TIFL fails, a follow -up e-mail
will be sent with a plan forward. The well is reclassified as Under Evaluation and may be returned to
production.
10/6/2011
UNDER EVALUATION: 06 -14B (PTD,090120) TxIA Communication - FaileoIFL Page 2 of 2
Please call if you have any questions or concerns.
Thank you,
Gerald Murphy (alt. Mehreen Vazir)
Well Integrity Coordinator
Office (907) 659 -5102
Cell (907) 752 -0755
Pager (907) 659 -5100 Ext. 1154
From: AK, D &C Well Integrity Coordinator
Sent: Monday, August 15, 2011 5:14 PM
To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy (DOA)'; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations
Team Lead; AK, RES GPB East Wells Opt Engr; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS FS3 Ops Lead; AK, OPS FS3 OSM; Cismoski, Doug
A; Daniel, Ryan
Cc: Walker, Greg (D &C); Stechauner, Bernhard; Lee, Timothy; Reynolds, Charles (ALASKA)
Subject: Producers with Sustained Casing Pressure on IA During TAR
All,
The following producers were found to have sustained casing pressure on the IA during shut down for turnaround activity.
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.
06 -04A (PTD #2001020)
06 -14B (PTD #2090120)
15 -36B (PTD #2060730)
All the wells listed above will be classified as Not Operable until start -up operations commence and are 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
10/6/2011
PBU 06 -14B
PTD # 2090120
10/2/2011
TIO Pressures Plot
Well: 06 -14
4,000
3,000
—1111— Tbg
—f— IA
—
2,000 A — OA
00A
••• ♦ 00 0A
On
1,000
07/02/11 07/09/11 07116111 07123/11 07/30/11 08/06/11 08/13/11 08 /20 /11 08/27/11 09/03/11 09/10/11 09117/11 09/24111 10/01/11
L —
S
TREE = CM/ SAFETY NO.** CHROME TBG, LNR & NIPPLES ***
WELLHEAD = FMC * * *ORJ WE06 -14A NOT SHOWN BELOW
ACTUATOR = BAKER C ® �, WHIPSTOCK***
KB. ELEV = 68'
BF. EEO' = ,' f f
KOP = 4200'
Max Angle = 106° @ 11500' l 2219' 1- 14 -1/2" HES X NIP, ID = 3.813" 1
Datum MD = 11008'
Datum TVD = 8800' SS
GAS LIFT MANDRELS
13 -3/8" CSG, 72 #, N -80, ID = 12.347" H 2685' f 1ST] MD TV D 1 DEV TYPE VLV I LATCH PORT DATE
5 3537 3537 0 KBG -2 DOME BK 16 04/10/09
ITOC -1 3000' T r 4 5918 5656 42 KBG -2 SO BK 20 03/16/10
3 8084 6977 56 KBG -2 DMY BK 0 04/04/09
Minimum ID = 3.725" @ 10568' 0 2 9367 7833 47 KBG -2 DMY BK 0 04/04/09
1 1 10102 8288 52 KBG -2 DMY BK 0 03/16/10
4 -1/2" HES XN NIPPLE �
1 4814' 1--- 9 -5/8" X 7" HRD ZXPN PKR w /TIEBACK
IT' CSG, 26 #, L -80 TCII, ID = 6.276" 1-1 4824' & LNR HGR, ID = 6.187"
1 1
1 1+
1
19 -5/8" WHIPSTOCK (03/13/09) ( MILLOUT WINDOW (06 -14B) 4982' - 4999'
-°{ 4982' ( �
10473' H4-1/2" HES X NIP, ID = 3.813" I
19 -5/8" CSG, 47 #, L -80, ID = 8.681" 1-1 8552' 1-
10504' H7" X 4 -1/2" BKR S -3 PKR, ID = 3.870" 1
PERFORATION SUMMARY
REF LOG: LDWG ON 03/13/09 ;; 10537' 1 1 4 -1/2" HES X NIP, ID = 3.813" 1
ANGLE AT TOP PERF: 51° @ 10895'
Note: Refer to Production DB for historical perf data �i 10565' 1- 7" X 5" ZXP LTPw/TIEBACK
SIZE SPF INTERVAL Opn /Sqz DATE SLV, ID = 5.56"
2 -7/8" 6 10895 - 10915 0 01/24/10
2 -7/8" 6 10970 - 10990 0 07/15/09 10568' 1-14 -112" HES XN NIP, ID = 3.725" 1
2 -7/8" 6 10990 - 11010 O 07/11/09 \ 10580' 1- 14 -1/2" WLEG, ID = 3.958" 1
2 -7/8" 6 11102 - 11140 O 04/02/09
2 -7/8" 6 11170 - 11190 0 04/02/09 10587' 1~ 7" X 5" FLEXLOCK
2 -7/8" 6 11480 - 11790 0 04/02/09 , LNR HGR, ID = 4.44"
2 -7/8" 6 11960 - 12020 0 04/02/09
1 10597' 1-I 5" X 4-1/2" X0,
ID =3.92"
4 -1/2 " TBG, 12.6 #, 13CRVAMTOP, -1 10580' •
1 .0152 bpf, ID = 3.958"
17" LNR, 26 #, L -80 BTC-M, .0383 bpf, ID = 6.276" 1 10725'
FISH: SMALL PIECES ???
OF FIRING HEAD
,.. I
2" X 3/4" (07/13/09) ����41Ik
PBTD 1 12242' .
14 -1/2" LNR, 12.6 #, 13CR -80 VAM TOP, .0152 bpf, ID = 3.958" H 12330'
•
DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT
06/21/80 ORIGINAL COMPLETION 04/23/10 ZS /JMD GLV C/O (03/16/10) WELL: 06 -14B
07/03/92 LAST WORKOVER PERMIT No: F 2090120
04/05/09 N9ES SIDETRACK (06 -14B) API No: 50 -029- 20458 -02 -00
07/25/09 MBM/PJC FISH & PERFS (07/11 - 15/09) SEC 2, T10N, R14E, 238' FSL & 1728' FEL
02/03/10 JMF /PJC PERFS (01/24/10)
03/19/10 /JMD GLV C/O (03/16/10) BP Exploration (Alaska)
Producers with Sustained Casing Press, on IA During TAR • Page 1 of 1
Regg, James B (DOA)
From: AK, D &C Well Integrity Coordinator [ AKDCWeIIlntegrityCoordinator @bp.com] ?e, tS(z<lli
Sent: Monday, August 15, 2011 5:14 PM
To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); AK, D &C Well Services
Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB East Wells Opt Engr; AK,
OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS FS3 Ops Lead; AK, OPS FS3 OSM; Cismoski,
Doug A; Daniel, Ryan
Cc: Walker, Greg (D &C); Stechauner, Bernhard; Lee, Timothy; Reynolds, Charles (ALASKA)
Subject: Producers with Sustained Casing Pressure on IA During TAR
All,
The following producers were found to have sustained casing pressure on the IA during shut down for
turnaround activity. 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.
06 -04A (PTD #2001020 ' 4 �` kr 8
7 1106-14B (PTD #2090120)
15 -36B (PTD #2060730)
All the wells listed above will be classified as Not Operable until start -up operations commence and are
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 M u rp h y)
Well Integrity Coordinator
BP Alaska Drilling & Wells
Well Integrity Office: 907.659.5102
Email: AKDCWeIIlntegrityCoordinator @BP.com
8/25/2011
DATA SUBMITTAL COMPLIANCE REPORT
8/26/2010
Permit to Drill 2090120 Well Name/No. PRUDHOE BAY UNIT 06-14B Operator BP EXPLORATION (ALASt(A) INC
MD 12331 TVD 8817 Completion Date 4/2/2009 Completion Status 1-OIL Current Status 1-OIL
API No. 50-029-20458-02-00
UIC N
REQUIRED INFORMATION
Mud Log No
Samples No
Directional Survey
DATA INFORMATION
Types Electric or Other Logs Run: USIT / CCL, DIR / GR /RES / PWD, DIR / GR /RES / NEU /DEN (data taken from Logs Portion of Master Well Data Maint
Well Log Information:
Log/ Electr
Data -Digital Dataset Log Log Run Interval OH /
T Med/Frmt Number Name Scale Media No Start Stop CH Received Comments
Log Cement Evaluation 5 Col 10600 12240 Case 4/21/2009 SCML-CB, MaxTrac
Tractor 1-Apr-2009
ED C Pds 17875~ment Evaluation 10600 12240 Case 4/21/2009 SCML-CB, MaxTrac
~~ Tractor 1-Apr-2009
ED C Lis 18094 Induction/Resistivity 4596 12324 Open 6/3/2009 LIS Veri, GR, ROP, FET,
RPX, RPS, RPM, RPD,
RAM Plus Graphics
Log Induction/Resistivity 25 BIu 4600 12286 Open 6/3/2009 MD Vision Service
og Induction/Resistivity 25 Blu 4600 12286 Open 6/3/2009 TVD Vision Service
Well Cores/Samples Information:
Sample
Interval Set
Name Start Stop Sent Received Number Comments
ADDITIONAL INFOR~N
Well Cored? f N
Chips Received? °4`l1~'~
Analysis ;~J-~1'~~
Received?
Daily History Received? <~ N
Formation Tops ~ N
Comments:
DATA SUBMITTAL COMPLIANCE REPORT
8/26/2010
Permit to Drill 2090120 Well Name/No. PRUDHOE BAY UNIT 06-14B Operator BP EXPLORATION (ALASKIy INC
MD 12331 ND 8817 Completion Date 4/2/2009 Completion Status 1-OIL Current Status 1-OIL
API No. 50-029-20458-02-00
UIC N
Compliance Reviewed By: ~~ Date: ~ ~ ~W L~
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
RECEIVED
FEB 0
1. Operations Abandon❑ Repair Well ❑
Plug Perforations ❑ Stimulate ❑
F-1Performed:
Alter Casing E] Pull Tubing El
AA�'O-�-th��,err
Perforate New Pool ElWaiver❑ Time Enittll"" 63S Con& COMMiSSi
Change Approved Program ❑ Operat. Shutdown ❑
Perforate Q Re -e er Suspended Well ❑ Anchorage
2. Operator BP Exploration (Alaska), Inc.
4. Well Class Before Work: . Permit to Drill Number:
Name:
Development El Exploratory ❑ 209-0120
3. Address: P.O. Box 196612
Stratigraphic❑ Service ❑ rk. API Number:
Anchorage, AK 99519-6612
50-029-20458-02-00
8. Property Designation (Lease NLAQber) :
9. Well Name and Number:
ADLO-028311
PBU 06-148
10. Field/Pool(s):
\ PRUDHOE
BAY FIELD
/ PRUDHOE OIL POOL
11. Present Well Condition Summary:
Total Depth measured \\N 12331 feet
Plugs (measured) None feet
true vertical , 8817.2 feet
Junk (measured) None feet
Effective Depth measured 12242 feet Packer (measured) 10504
true vertical 8837.99 feet (true vertical) 8538
Casing Length Size
MD TVD Burst Collapse
Structural
Conductor 110 20" 91.5 H-40
SURFACE - 110 SURFACE - 110 1490 470
Surface 2685 13-3/8" 72# N-80
SURFACE - 2685 SURFACE - 2685 4930 2670
Intermediate
Production 4982 9-5/8" 47#
SURFACE - 4982 SURFACE - 4896 9870 4760
Liner 10725 7" 26# L-80
SURFACE - 10725 SURFACE - 8685 7240 5410
Liner 1765 4-1/2" 12.6# 1-80
10565 - 12330 8577 - 8817 8430 7500
Perforation depth: Measured depth: SEE ATTACHED
True Vertical depth:
Tubing: (size, grade, measured and true vertical depth)
4-1/2" 12.6# 13CR SURFACE - 10580 SURFACE - 8587
Packers and SSSV (type, measured and true vertical depth)
4-1/2" BKR 83 PKR 10504 6538
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure:
13.
Representative Daily Average Production or Injection Data
Oil -Bbl
Gas-Mcf Water -Bbl Casing Pressure Tubing pressure
Prior to well operation: 291
1939 6604 258
Subsequent to operation:
14. Attachments:
Well Class after work:
Copies of Logs and Surveys Run
Exploratory❑ Development 0 Service ❑
Daily Report of Well Operations X
6. Well Status after work: Oil Gas WDSPL
GSTOR ❑ WAG ❑ GINJ❑ WINJ❑ SPLUG ❑
17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt:
N/A
Contact Gary Preble
Printed Name Gary Preble
Title Data Management Engineer
Signature
Phone 564-4944 Date 2/1/2010
Form tU-4U4 Vevised 7/2009 • MUNIZ5 rLD U J (UN � Submit Original Only
.? • 3 • /o .� �j� v
06-14B
209-012
PERF ATTACHMENT
Sw Name
06-14B
06-14B
06-14B
06-146
06-14B
06-14B
06-146
Operation Date Pert Operation Code
4/2/09 PER
4/2/09 PER
4/2/09 PER
4/2/09 PER
7/12/09 APF10,990.
7/15/09 APF
1/24/10 APF
Meas Depth Top Meas Depth Base Tvd Depth
11,102. 11,140.
11,170. 11,190.
11,480. 11,790.
11,960. 12,020.
11,010.
10,970. 10,990.
10,895. 10,915.
Top
8,907.82
8,931.99
8,974.48
8,882.81
8,855.36
8,844.67
8,800.75
Tvd Depth Base
8,920.88
8,940.35
8,912.66
8,876.54
8,865.65
8,855.36
8,813.13
AB
ABANDONED
PER
PERF
APF
ADD PERF
RPF
REPERF
BPP
BRIDGE PLUG PULLED
SL
SLOTTED LINER
BPS
BRIDGE PLUG SET
SPR
SAND PLUG REMOVED
FCO
FILL CLEAN OUT
SPS
SAND PLUG SET
FIL
FILL
SQF
SQUEEZE FAILED
MIR
MECHANICAL ISOLATED REMOVED
SQZ
SQUEEZE
MIS
-9-LK
MECHANICAL ISOLATED
STC
STRADDLE PACK, CLOSED
MECHANICAL LEAK
STO
STRADDLE PACK, OPEN
OH
OPEN HOLE
06-14B
DESCRIPTION OF WORK COMPLETED
NRWO OPERATIONS
EVENT SUMMARY
0 ***WELL SHUT IN ON ARRIVAL*** (ELINE: PERFORATION)
INITIAL T/I/I/O: 1600/1660/0/0 PSI
PERFORATED FROM 10895-10915 FEET WITH TWO 10 FT 2.88" PJ OMEGA
GUNS, 6 SPF.
VISUAL AND SURFACE INDICATION SHOTS FIRED.
TC INSTALLED AND PT, MASTER OPEN, SWAB CLOSED, SSV OPEN. WING
OPEN. NOTIFIED DSO.
FINAL T/I/I/O: 1600/1660/0/0 PSI.
***JOB COMPLETE. WELL FLOWING ON DEPATURE***
FLUIDS PUMPED
BBLS
2 METH
3 DIESEL
5 Total
TREE= 4-1/16" CIW
WELLHEAD=
FMC
ACTUATOR=
Note: Refer to Production DB for historical pert data
KB. ELEV =
64.56
BF. ELEV =
37'
KOP=
5,020'MD
Max Angle =106° @ 11500'
Datum MD =
11008'
Datum TVD=
8800' SS
t13� �►:
13-3/8" CSG, 72#, BTC, N-80, ID = 12.347" H 2.685'
Minimum ID = 3.725" @ 10568'
4-1/2" XN NIPPLE
7" CSG, 26#, L-80. TCII. ID = 6.276" W 4824'
1101061;&303ANT1121v2Trirm
FZSV
9-5/8" CSG. 47#, L-80, ID = 8.681" H8552'
MILLOUT WINDOW (06.14A) 8552'- 8613'
12.6#, 13CR VA MTOP, ID = 3.958"
PERFORATION SUMMARY
REF LOG: LDWG ON 03/13/09
ANGLE AT TOP PERF: 570 @ 10970'
Note: Refer to Production DB for historical pert data
SIZE
SPF
INTERVAL
Opn/Sqz
DATE
2-7/8"
6
10970 - 10990
0
07/15/09
2-7/8"
6
10990 - 11010
0
07/11/09
2-7/8"
6
11102 - 11140
O
04/02/09
2-718"
6
11170 - 11190
O
04/02/09
2-7/8"
6
11480 - 11790
O
04/02/09
2-7/8"
6
11960 - 12020
O
04/02/09
06-14B
nTD H 12242'
CSG, 12.6#, 13CR VAMTOP, ID = 3.958" W 12330'
SAFE. , NOTES: "`CHROMETBG & LNR— WELL
ANGLE>70- @ 11118' —
I --I4-1/2" X -NIP, ID = 3.813"
GAS LIFT MANDRELS
ST MD
I TVD
I DEV
I TYPE
I VLV
I LATCHI
PORT
I DATE
5 3537
3537
0
KBG-2
DMY
BK
0
04/04/09
4 5918
5656
42
KBG-2
DCK
BEK
0
04/04/09
3 8084
6977
56
KBG-2
DMY
BK
0
04/04/09
2 9367
7833
47
KBG-2
DMY
BK
0
04/04/09
1 10102
8288
52
KBG-2
DMY
BK
0
04/04/09
DATE
REV BY
COMMENTS
DATE REV BY COMMENTS
06/21/80
PKR141
ORIGINALCOMPLETION
4-1/2" WLEG, ID=4.00"
07103192
7" x 5" FLIX LOCK HGR, ID = 4 2
RWO
5" x 4-1/2" XO. ID = 3.92"
04/05109
N9ES
SIDETRACK(06-14B)
07/25/09
MBMJPJC FISH & PERFS (07/11 - 15/09)
4814' 9-5/8" x 7" BKR LT PKR, ID = 6.187"
w /TIEBACK & LNR HGR
MILLOUT WINDOW (06.146) 4982' - 4999'
X
110537'
10568'
H4 -1/2"X -NIP, ID=3.813"
4-1/2" XN-NIP, ID= 3.725"
10565'
4-1/2", 12.6# 13Cr Teback Top
10577'
7" x 5" ZXP LT PKR, ID = 5.56"
10580'
4-1/2" WLEG, ID=4.00"
10587'
7" x 5" FLIX LOCK HGR, ID = 4 2
10597'
5" x 4-1/2" XO. ID = 3.92"
10725' H 7" CSG, 26#, BTC -M, ID = 6.276"
P]�tlI:7I0CHay\�
X 3/4"
PRUDHOE BAY UNIT
WELL: 06-148
PERMIT No: 209-012
A PI No: 50-029-20458-02
SEC 11, TI ON, R14E, 5,084' FEL & 3,420' FNL
BP Exploration (Alaska)
Page 1 of 1
Schwartz, Guy L (DOA)
From: Johnson, Vern [Vern.Johnson@pxd.com]
Sent: Monday, February 01, 2010 10:51 AM
To: Schwartz, Guy L (DOA)
Subject: ODSK-42i PTD 209.120
Guy- to clarify, the upper bridge plug for abandonment was set a t 3540' MD, 100 ft below the casing cut. The
schematic sent with the 10-407, and the daily ops report for that day (Dec. 7) had a number transposed. Good
catch, sorry for the confusion. Let me know if we need to follow with any further information.
Vern Johnson
Sr. Staff Drilling Engineer
Pioneer Natural Resources Alaska
907-343-2111 office
907-575-9430 cell
Statement of Confidentiality:
This message may contain information that is privileged or confidential. If you receive this transmission
in error, please notify the sender by reply e-mail and delete the message and any attachments.
2/1/2010
.7
BP Exploration (Alaska) Inc.
Attn: Welt Integrity Coordinator, PRB-20
Post Office Box 196612
Anchorage, Alaska 99519-6612
January 1, 2010
•
by
Mr. Tom Maunder
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue ~~ ,.,
Anchorage, Alaska 99501 g
Subject: Corrosion Inhibitor Treatments of GPB DS 06
Dear Mr. Maunder,
Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS
06 that were treated with corrosion inhibitor in the surface casing by conductor annulus.
The corrosion inhibitor is engineered to prevent water from entering the annular space
and causing external corrosion that could result in a surface casing leak to atmosphere.
The attached spreadsheet represents the well name, API and PTD numbers, top of
cement depth prior to filling and volumes of corrosion inhibitor used in each conductor.
As per previous agreement with the AOGCC, this letter and spreadsheet serve as
notification that the treatments took place and meet the requirements of form 10-404,
Report of Sundry Operations.
If you require any additional information, please contact me or my alternate, 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)
DS-06
Date: 12/10/09
Well Name
PTD #
API #
Initial top of
cement
Vol. of cement
um ed
Final top of
cement
Cement top off
date
Corrosion
inhibitor Corrosion
inhibitor/
sealant date
ft bbls ft na al
06-01 1750490 50029201720000 NA Sealed NA
06-02 1770780 50029202820000 NA Sealed NA
06-o3A 1951520 50029201860100 NA Sealed NA
os-o4A 2001020 50029201790100 NA Sealed NA
06-05 1780200 50029202980000 NA Sealed NA
o6-o6B 2050980 50029202010200 NA Sealed NA
06-07 1780210 50029202990000 NA Sealed NA
os-o8A 1951950 50029203000100 NA Sealed NA
06-09 1790730 50029204000000 NA Sealed NA
os-10A 1981960 5002920ao201oo NA Sealed NA
06-11 1791100 50029204280000 NA Sealed NA
06-12A 1920640 50029204560100 NA 0.5 NA 3.40 10/6/2009
06-13A 2061020 50029204570100 NA Sealed NA
06-14B 2090120 50029204580200 NA Sealed NA
06-15 1800320 50029204590000 NA Sealed NA
06-16 1800330 50o292oasooooo NA Sealed NA
06-18A 2090630 50029207670100 NA 0.3 NA 1.70 11/5/2009
06-19A 2081020 50029207910100 NA 1.5 NA 6.80 10/4/2009
06-20A 2050790 50029207990100 NA 1 NA 5.10 10/4/2009
06-21 B 2080990 50029208020200 NA 6 NA 42.50 12/14/2009
06-22A 1930570 50029208060100 NA 1.5 NA 5.10 10/4/2009
06-23C 2080920 50029208080300 NA 4.6 NA 30.60 10/6/2009
os-24A 2000960 5oo29zos2zoloo NA Sealed NA
05/26/09
~~
i~
N0.5242
Alaska Data & Consulting Services Company: State of Alaska
2525 Gambell Street, Suite 40o Alaska Oil & Gas Cons Comm
Anchorage, AK 99503-2838 Attn: Christine Mahnken
ATTN: Beth 333 West 7th Ave, Suite 100
Anchorage,AK 99501
also i..f. ~ 1 .... nocnr:nfinn fl~fo RI Cninr CA
4-04AIT-30 BOCV-00014 CH EDIT PDCL-GR (SCMT) - 04/27/09 1
4-02/0-28 AYKP-00019 RST 05/07/09 1 1
H-19B B2WY-00004 MCNL 7/09 1 1
18-26B B2NJ-00001 MCNL - 04/14/09 1 1
J-206 AXED-00020 MCNL ~ 04/12/09 1 1
W-06A AZCM-00021 RST ~ _ L 05/16/09 1 1
15-15C BOOR-00004 MCNL ~ 03/15/09 1 1
14-31 BOCV-000015 RST .- { f 05/15/09 1 1
E-05B 09AKA0035 OH MWDlLWD EDIT 04/06/09 2 1
06-14B 09AKA0031 OH MWD/LWD EDIT 03/27/09 2 1
PLEASE AGKNUWLtUGt HtGEIPI t3Y SICiNINCi ANU Htl UHNINGi VNt GVYY tAI:H I U:
BP Exploration (Alaska) Inc. _
Petrotechnical Data Center LR2-1 _ ~ ~ ~ ~-,~
900 E. Benson Blvd. _ ~ = ~ 1..-~ ~ ~~'
Anchorage, Alaska 99508 '"
Date Delivered: ~I~.IN 0 3 ZOG9
~~ fit t~. ~®rrl»r~~siott
~/~ ~~Ch®t~~~
Alaska Data & Consulting Services
2525 Gambell Street, Suite 0
Anchorage, AK 9 3-28
ATTN: Beth
Received by:
04/14/09
~ /
~~
fi
f,.
e7~illl~~~~a~~
Alaska Data & Consulting Services
2525 Gambell Street, Suite 400
Anchorage, AK 99503-2838
ATTN: Beth
wpu _r„ti ~
N0.5188
Company: State of Alaska
Alaska Oil & Gas Cons Comm
Attn: Christine Mahnken
333 West 7th Ave, Suites 100
Anchorage, AK 99501
~_
W-18
11968978 -- -~~~ ~
RST
12/22/08
1 VVIVI VY
1
07-026 AXBD-00013 MCNL 02/12/09 1 1
K-05C AWJB-00016 MCNL ~ 12/30/08 1 1
F-18A AYLF-00020 CEMENT IMAGE LOG ~ l "~- 03/19/09 1 1
J-09A AP3O-00024 STP CROSS FLOW CHECK ~ c j ~ 03/25/09 1 1
X-05 AYTO-00014 PFCS CALIPER LOG j _ G 04/09/09 1 1
O-04A AYTU-00023 _
LDL & PLUG SET j95 _ ~ 04/02/09 1 1
04-40 AYTU-00025 USIT ~ ~- C~ 04/10/09 1 1
06-14B AVYO-00021 SCMT ~ 04/01/09 1 1
Z-016 AVYO-00025 INJECTION PROFILE --f0
~ 04/11/09 1 1
L3-15 AYTU-00023 __ ~
_
PRODUCTION PROFILE ~ 04/06/09 1 1
11-30 AXBD-00021 MEM PROD PROFILE j c~ , ~- 04/14/09 1 1
3-03/J-33 AZ4D-00013 RST W/INJ PROFILE - j - ~ a 04/05/09 1 1
3-17F/K-30 BIJJ-00006 MEM INJECTION PROFILE ' - (~ ~j 04/03/09 1 1
3-49A/M-40 AXBD-00019 MEM INJECTION PROFILE: 04/07/09 1 1
V-114A
'~ U ~_ AVY500032 INJECTION PROFILE ~ j 04/02/09 1 1
THESE 2 WELLS WERE DELIVERED SEPARETLY TO MEET COMPLIANCE TRANS # 5185
E-36A AYTU-00006 OH MWD/LWD EDIT (IFLEX) J _~'.}- ~-~9 01/14/09 1 1
MPS-43 AXML-00020 OH LDWG EDIT 12/29/08 2 1
PLEASE ACKNOW
5 ..~r,,~;~~t~-, LEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO:
BP Exploration (Alaska) Ina
Petrotechnical Data Center LR2-1
900 E. Benson Blvd.
Anchorage, Alaska 99508
Date Delivered:
Alaska Data & Consulting Services
2525 Gambell Street, Suite 400
Anchorage, AK 99503 838
ATTN: Beth
Received bV:
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
~~J"-~~~
moo?.?-09
APR 2 1 2009
WELL COMPLETION OR RECOMPLETION REPORT ANDAIOka nil ~ Gas tans. Cammissiari
1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended
zoAAC zs.,os zoAac zs.,,o
^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1b. Well Cla FlC Ot8g2
®Development ^ Exploratory
^ Service ^ Stratigraphic
2. Operator Name:
BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband.
4 /2009 12. Permit to Drill Number
209-012 -
3. Address:
P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded
3/14!2009 ~ 13. API Number
50-029-20458-02-00 -
4a. Location of Well (Governmental Section):
Surface: 7. Date T.D. Reached
3/27/2009 ~ 14. Well Name and Number:
PBU 06-148 -
238' FSL, 1728' FEL, SEC. 02, T10N, R14E, UM
Top of Productive Horizon:
3167' FNL, 3720' FEL, SEC. 11, T10N, R14E, UM
8. KB (ft above MSL): 68' -
Ground (ft MSL):
15. Field /Pool(s):
Prudhoe Bay Field / Prudhoe Bay
Total Depth:
3369' FNL, 5102' FEL, SEC. 11, T10N, R14E, UM 9. Plug Back Depth (MD+TVD)
12242' 8838' Oil Pool
4b. Location of Well (State Base Plane Coordinates, NAD 27):
Surface: x- 685263 y- 5940818 Zone- ASP4 10. Total Depth (MD+TVD)
12331' 8817' 16. Property Designation:
ADL 028311 -
TPI: x- 683358 y_ 5937367 Zone- ASP4
th: x- 681982
- 5937131 Zone- ASP4
T
l D
t 11. SSSV Depth (MD+TVD)
None 17. Land Use Permit:
y
o
a
ep
18. Directional Survey ®Yes ^ No
u mit el r ni nd rin infomta ion AA 2 0 19. Water depth, if offshore
N/A ft MSL 20. Thickness of Permafrost (TVD):
1900 (Approx.)
21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071):
USIT / CCL, DIR / GR /RES /PWD, DIR / GR /RES / NEU / DEN ,!/~irvDO`/~' -~98a? i`JQ ~9i6.3~?Y~
22. CASING, LINER AND CEMENTING RECORD
CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT
WT. PER FT. ' GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED
ondu or H-4 Surf 11 ' rface 11 ' 4" 4 Ar icset II
7 7- I
9-5/ " 47# rfa S rfa 4 12-1/4" 1 0 I 00 sx A I
7" 26# rf Ce 1 rf 86 8-1 /2" 345 sx LiteCrete 2.95 , 97 sx Class'G' 1.16 ,
322 sx Class'G' 1.17
4- / " 12.6# L- 10 6 ' 2 8 7 ' 1 T -1/ " 322 sx Class 'G' t17 , 274 sx Class 'G' t1
23. Open to production or inject ion? ®Yes ^ No 24. Tuewc RECORD
If Yes, list each i
MD+TVD
f T
& B
m
Pe
tt nterval open
rforation Size and Number): SIZE DEPTH SET MD PACKER .SET MD
;
(
o
op
o
o
2-7/8" Gun Diameter
6 spf 4-1/2", 12.6#, 13Cr80 10580' 10504'
,
MD TVD MD TVD
11102' - 11140' 8908' - 8921'
11190' 8932'
8940'
11170' 2rj. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
-
-
11480' - 11790' 8974' - 8913' DEPTH INTERVAL MD AMOUNT Es KIND OF MATERIAL USED
11960' -12020' 8883' - 8877' 2200' Freeze Protect w/ 75 Bbls of Diesel
26. PRODUCTION TEST
Date First Production:
April 11, 2009 Method of Operation (Flowing, Gas Lift, etc.):
Gas Lift
Date Of Test:
4/14/2009 HOUfS Tested:
12 PRODUCTION FOR
TEST PERIOD OIL-BBL:
334 GAS-MCF:
685 WATER-BBL:
2,011 CHOKE SIZE:
81 GAS-OIL RATIO:
2,052
Flow Tubing
Press. 572 Casing Press:
1,740 CALCULATeD
24-HOURF2ATE• OIL-BBL:
667 GAS-MCF:
1,369 WATER-BBL:
4,022 OIL GRAVITY-API (CORK):
Not Available
27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Cores Ac wired? ^Yes ®No
If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water
(submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071.
i:~~ '!
None ?
. d
~w .
Form 10-407 Revised 02/2007
CONTINUED ON REVERSE SIDE
~. APR ~ n 209 k!`~I'`i G
28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND RS ENCOUNTERED): 29. FORMATION TESTS
NAME MD TVD Well Tested . ^ Yes ®No
Permafrost Top If yes, list intervals and formations tested, briefly summarizing test
results. Attach separate sheets to this form, if needed, and submit
Permafrost Base detailed test information per 20 AAC 25.071.
Sag River 10713' 8677' None
Shublik 10752' 8704'
Sadlerochit 10857 8776'
45N 10887 8796'
45P 10896' 8801'
44N 10962' 8840'
4.4p 10987' 8854'
43N 11017' 8869'
43P 11020' 8871'
42N 11168' 8931'
42P 11193' 8942'
41 N 11273' 8968'
41 P 11284' 8971'
41 P 11489' 8972'
41 N 11496' 8970'
42P 11698' 8928'
42N 11720' 8925'
43N 12127 8863'
44N 12260' 8834'
Formation at Total Depth (Name):
44N 12260' 8834'
30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys
31. I hereby certify that the foreg ing is true and correct to the best of my knowledge.
~~
Zt~O
Signed Terrie Hubble Title Drilling Technologist Date
PBU 06-14B 209-012 Prepared By Name/Mumber. Terrie Hubble, 564-4628
Well Number Permit No. / A rOV81 NO. Drilling Engineer: Zach Sayers, 5645790
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. Submit a
well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.
ITeM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely
segregated. Each segregated pool is a completion.
ITEM 4b: TPI (Top of Producing Interval).
IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other
spaces on this form and in any attachments.
IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
ITeM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28.
ITeM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool.
ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the
producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,
showing the data pertinent to such interval).
ITeM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain).
ITeM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical
laboratory information required by 20 AAC 25.071.
IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory
information required by 20 AAC 25.071.
Form 10-407 Revised 02/2007 Submit Original Only
BP EXPLORATION Page 1 of 1
Leak-Off Test Summary
Legal Name: 06-14
Common Name: 06-14
Test Date Test Type
3/13/2009 FIT
3/25/2009 LOT
Test Depth (TMD T Depth (TVD)
4,982.0 (ft) 4,899.0 (ft)
10,746.0 (ft) 8,686.0 (ft)
AMW Surface Pressure Leak Off Pressure (BHP)
---
8.90 (ppg) 625 (psi) 2,890 (psi)
8.50 (ppg) 808 (psi) 4,643 (psi)
EMW
11.36 (PPg)
10.29 (ppg)
•
~
Printed: 4/13/2009 2:52:00 PM
BP EXPLORATION Page 1 of 16
Operations Summary Report
Legal Well Name: 0 6-14
Common W ell Name: 0 6-14 Spud Date: 6/5/1980
Event Nam e: REENTE R+COM PLET E Start : 3/6/2009 End: 4/4/2009
Contractor Name: N ABORS ALASK A DRI LLING I Rig Release: 4/5/2009
Rig Name: N ABORS 9ES Rig Number: 9ES
~
Date
From - To ,
Hours ', ~
Task. . ~
Code
NPT
Phase
Description of Operations
3/8/2009 09:00 - 12:00 3.00 MOB P PRE Rig release from DS03-32B Q 09:OOhrs, 3/8/09. Mobilize and
move pits, camp and shops from DS03 to DS06-14B.
12:00 - 16:00 4.00 MOB P PRE Prep for rig move from DS03 to DS06; lay down derrick, lower
h ~ ~
~J _ `tom Ifs
_` H cattle chute. Prep cellar, jack sub off 03-326, remove rig mats
from location.
,~~ O~ ~-7 16:00 - 23:00 7.00 MOB P PRE Move rig 9ES from DS03-32B to DS06-14B.
l 23:00 - 00:00 1.00 MOB N WAIT PRE Waiting to spot derrick; wait of gravel work and leveling pad.
3/9/2009 00:00 - 02:00 .2.00 RIGU P PRE PJSM. LD rig mats and level pad.
02:00 - 12:00 10.00 RIGU P PRE Spot rig over 06-146. Raise derrick, hook up interconnects to
pits. Rug up floor. Rig accept Q 12:OOhrs, 3/9/2009.
IA pressure = 325psi, OA pressure = 40psi.
12:00 - 15:00 3.00 RIGU P DECOMP Take on 8.5ppg seawater to pits; RU annular valves to test
downhole barriers.
15:00 - 18:30 3.50 WHSUR P DECOMP PJSM w/ LRHOS. RU LR and pressure test all connections.
Pressure test OA to 2000psi for 30min; good test. Pressure
-test IA to 2500psi for 30min (lost 40 psi in first 15min, lost 40
si in second 15min); good test.
18:30 - 20:00 1.50 WHSUR P DECOMP Rig up DSM lubricator; pressure test lubricator and pull back
pressure valve. Rig down lubricator.
20:00 - 00:00 4.00 WHSUR P DECOMP ~ Offload 8.5ppg seawater and sent to plant for weight-up to
9.8ppg before circulating out diesel. RU lines for circulating,
change out saver sub to 4-1/2" IF connection.
3/10/2009 00:00 - 02:00 2.00 WHSUR P DECOMP PJSM. Move 5" and 4" drill pipe into pipe shed. RU hardline to
open top tank from Flare line in prep for rev-circ and circulation.
02:00 - 04:00 2.00 WHSUR N WAIT DECOMP Wait on 9.8ppg brine from mud plant; seawater previously
offloaded from pits and sent in to weight-up.
04:00 - 07:00 3.00 WHSUR P DECOMP Circulate out diesel freeze protect through choke with 9.8 ppg
brine. Reverse 40 bbls down IA. Swap lines and pump long
way with Safe-Surf-O sweep followed by 9.8 ppg brine at 300
gpm with 650 psi. Take returns to open top tank through hard
line until 9.8 ppg brine back to surface.
07:00 - 09:00 2.00 WHSUR P DECOMP Rig up OA to open top tank with hard line. Monitor for pressure
build up and release. Circulate 9.8 ppg through gas buster
back to pits until OA thermally stable. Shut down and monitor
for 15 minutes - OK. Pump 9.8 ppg brine down hard line to
clean out any residual Arctic Pack. Blow down lines.
09:00 - 10:00 1.00 WHSUR P DECOMP Set BPV as er FMC. Jars left in tree. Shut in swab valve. Call
out fishing tools.
10:00 - 12:30 2.50 WHSUR N WAIT DECOMP Waiting on fishing tools to retrieve BPV running jars.
12:30 - 13:30 1.00 WHSUR P DECOMP Set BPV with blanking plug and test to 1000 psi from below -
OK.
13:30 - 15:00 1.50 WHSUR P DECOMP Nipple down tree.
15:00 - 17:30 2.50 BOPSU P DECOMP Nipple up BOP stack.
17:30 - 19:00 1.50 BOPSU P DECOMP PU testing tools and rig up test equipment.
19:00 - 00:00 5.00 BOPSU P DECOMP PJSM. Test u per rams with 4" and 5" test joints to 250 psi
low, 3500 psi high and Hydril with 4" test joint to 250 psi low,
3500 psi high as per AOGCC. Test witness waived by Chuck
Scheve with AOGCC. Test witnessed by WSL Mitch Skinner
and Toolpusher Chris Weaver. Lower rams to be tested when
tubing has been pulled.
3/11/2009 00:00 - 02:00 2.00 BOPSU P DECOMP PJSM. Test upper rams with 4" and 5" test joints to 250 psi
low, 3500 psi high and Hydril with 4" test joint to 250 psi low,
Printed: 4/13/2009 2:52:06 PM
BP EXPLORATION Page 2 of 16
Legal Well Name: 06-14
Operations Summary Report
Common W
Event Name
Contractor
Rig Name:
Date ell Name: 0
:
Name: N
N
From - To 6-14
REENTE
ABORS
ABORS
Hours
R+COM
ALASK
9ES
Task
PLET
A DRI
Code
E
LLING
`NPT
Start
I Rig R
Rig N
Phase. ~ Spud Date: 6/5/1980
: 3/6/2009 End: 4/4/2009
elease: 4/5/2009
umber: 9ES
Description of Operations
3/11/2009 00:00 - 02:00 2.00 BOPSU P DECOMP 3500 psi high as per AOGCC. Test witness waived by Chuck
Scheve with AOGCC. Test witnessed by WSL Mitch Skinner
and Toolpusher Chris Weaver. Lower rams to be tested when
tubing has been pulled.
02:00 - 03:30 1.50 BOPSU P DECOMP PJSM. Rig up DSM lubricator. Test to 500 psi - OK. Pull BPV.
Rig down lubricator.
03:30 - 06:00 2.50 PULL P DECOMP Rig up to pull 4 1/2" 12.6# Cr Completion. PU one joint of 5"
DP and crossover; screw into tubing hanger. Back out LDS,
unseat tubin han er and ull tubin from cut @ 9 000'. 155k
up to pull free, 140k up weight when pulling. Circulate Bottoms
up prior to laying down tubing.
06:00 - 18:00 12.00 PULL P DECOMP POOH with 4.5" 12.6# Cr13 tubing string, laying down joints
from 9,000' to -6805'. Spool control line while coming out of
the hole; 46 Stainless steel control bands recovered (records
indicate 53 control bands originally run). Inspect tubing in pipe
shed -looks good. Recovered a total of Hanger and pup, 203
jts, SSSV, 6) GLM'S, 15.12' cut off jt. and 46 SS bands.
18:00 - 18:30 0.50 PULL P DECOMP Rig down 4.5" tubing handling equipment. Clear and clean rig
floor.
18:30 - 19:00 0.50 BOPSU P DECOMP Rig up test equipment to test lower pipe rams.
19:00 - 20:30 1.50 BOPSU P DECOMP Test lower pipe rams with 4" & 5" test jts. to 250 psi low, 3500
psi high. Witness of test waived by Chuck Scheve with
AOGCC. Test witnessed by WSL O'Neal Coyne and Tool
pusher Roy Hunt. LDS leaked on tubing spool, FMC rep.
retorqued LDS and retested.
20:30 - 21:00 0.50 BOPSU P DECOMP Rig down test equipment and install 9-1/8" ID wear ring.
21:00 - 00:00 3.00 CLEAN P DECOMP PU 9-5/8" 47# casing cleanout assembly. 8.5" Bit, 9-5/8"
~ casing scraper, bit sub, Upper mill, float sub, drilling jars, 9)
6-1/4" DC's, and 15) 5" HWDP.
3/12/2009 00:00 - 06:00 6.00 CLEAN P DECOMP Continue to RIH with BHA #1 to cleanout 47# 9-5/8" casing to
-6000', picking up 5" DP 1x1 from pipe shed to 6255'. Up wt.
185K Dn wt. 165K. Stand back 2 stands in derrick.
06:00 - 06:30 0.50 CLEAN P DECOMP CBU 600 GPM Q 1000 PSI. No debris observed over shakers.
06:30 - 07:30 1.00 DHB P DECOMP PU 9-5/8" RTTS. Set 5' below wellhead, to nipple down BOP'S
07:30 - 08:00
08:00 - 09:00 0.50
1.00 CLEAN
DHB P
P DECOMP
DECOMP Pull wear ring in preperation to change Packoff.
Pressure test 9-5/8" RTTS to 2500 psi from above for 10
charted minutes. (Good test)
09:00 - 12:00 3.00 WHSUR P DECOMP Make up Packoff R&R tool on 1) jt. of DP, run in and J into PO.
Back out LDS and pull to floor and install new PO and set per
FMC rep. RILDS and test lower seals to 5000 psi for 10
minutes.
12:00 - 14:30 2.50 WHSUR P DECOMP Nipple down BOP's and remove tubing head.
14:30 - 18:30 4.00 WHSUR P DECOMP Install 7" casing head and N/U BOP's and test upper Packoff
seals to 5000 psi for 10 minutes.
18:30 - 20:00 1.50 BOPSU P DECOMP Make up test plug on 5" DP and set ih well head and test break
to 250 si low and 3500 si hi h usin to ipe rams. Rig down
testing equipment and set 9-1/8" ID wear ring.
20:00 - 21:00 1.00 DHB P DECOMP Check for pressure and unseat and lay down 9-5/8" RTTS.
21:00 - 23:00 2.00 CLEAN P DECOMP Monitor well and POOH from 6065' to 785' standing 5" DP back
in derrick.
23:00 - 00:00 1.00 CLEAN P DECOMP Stand back 5" HWDP and DC's in derrick and lay down mill,
jars, and bit.
rnmea: aiiaizuua z:oz:~o rm
'
BP EXPLORATION Page 3 of 16
Operations Summary Report
Legal Well Name: 06-14
Common Well Name: 06-14 Spud Date: 6/5/1980
Event Name: REENTER+COMPLETE Start: 3/6/2009 End: 4/4/2009.
Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/5/2009
Rig Name: NABOBS 9ES Rig Number: 9ES
Date ICI From - To Hours Task ,Code NPT ~ Phase ~'~, Description of Operations
3/13/2009 00:00 - 02:00 2.00 CLEAN P DECOMP Continue to L/D BHA #1 for 9-5/8" cleanout run. Clear and
clean rig floor.
02:00 - 03:30 1.50 DHB P DECOMP PJSM - Schlumberger E-Line crew, rig crew, Halliburton rep.,
3:30 - 06:00
.50
HB
P
ECOMP Baker rep., and WSL.
Discussed hand rail use, traction devices, pinch points, and
liners under vehicles.
Rig up E-Line sheaves and wire and make up EZSV.
RIH with EZSV on E-Line and set top of EZSV ~ 5002' E-line
measurement. Collar 5015'. wi - ine.
' 06:00 - 06:30 0.50 DHB P DECOMP PJSM. Test Casing/EZSV to 3500 psi for 30 charted minutes.
No pressure loss -
06:30 - 09:00 2.50 STWHIP P WEXIT PJSM. PU/MU whipstoc A to 899'. Install 45k shear pin.
Up/down weight 45k.
09:00 - 10:30 1.50 STWHIP P WEXIT RIH with drill collars and HWDP to 920. Up weight 85k.
10:30 - 11:00 0.50 STWHIP P WEXIT Shallow test MWD with 470 gpm and 763 psi. Up and down
weight 85k.
11:00 - 14:30 3.50 STWHIP P WEXIT RIH to 4884'.
14:30 - 15:00 0.50 STWHIP P WEXIT Orient whipstock slide to 80 degrees LHS. Run in and tag up
on plug at 5004' MD drill pipe measurement. Set 15k down and
set whipstock anchor. Pull up 15k and verify. Set down 45k and
shear pin. Pull up free and verify.
15:00 - 16:00 1.00 STWHIP P WEXIT Displace 9.8 ppg NaCI brine with 8.9 ppg LSND. Pump 9.3 ppg
hi-vis spacer followed by LSND at 500 gpm with 950 psi.
Rotate and reciprocate at 40 rpm. Up weight 160k, down 150k,
RT 155k.
16:00 - 21:00 5.00 STWHIP P WEXIT Mill 8- 'window in 9-5 8' casing wit at ,
4999'. Mill and drill new formation to 5024'. Upper string mill
exited window at 5021' with 3' of gauge open hole. Pump at
400 gpm with 700 psi. Rotate at 75 to 100 rpm with 5 to 10k
O Q~-` ` torque. WOB 1-5k. Up weight 160k, down 150k, RT 155k.
Recovered 300 Ibs of metal during milling operation. Some pH
and odor indication of cement. No noticable cement returns.
Some coal in returns.
21:00 - 22:30 1.50 STWHIP P WEXIT Pump super sweep surface to surface at 500 gpm with 880 psi.
Rotate at 60 rpm with 4k torque. Coal chunks back to surface.
Work through window several times with and without rotary.
Shut down pumps and work through window with no problems.
Mud weight in and out 8.9 ppg.
22:30 - 23:30 1.00 STWHIP P WEXIT Perform FIT to 11.3 ppg with 625 psi and an 8.9 ppg mud
weight. Monitor well -static. Mud weight in and out 8.9 ppg.
23:30 - 00:00 0.50 STWHIP P WEXIT Pump dry job and POOH to 4957'. Up weight 165k, down 150k.
3/14/2009 00:00 - 02:00 2.00 STWHIP P WEXIT PJSM. POOH to 899'.
02:00 - 03:30 1.50 STWHIP P WEXIT Lay down whipstock BHA. Upper mill in gauge.
03:30 - 05:00 1.50 STWHIP P WEXIT Clear and clean floor. Function rams and flush stack. Clean
under shakers and flow line.
05:00 - 06:00 1.00 STWHIP P WEXIT Pick up tools for 8-1/2" drilling BHA.
06:00 - 08:30 2.50 STWHIP P WEXIT PJSM. Make up 8-1/2" drilling assembly with vortex rotary
steerab a to 758'.
08:30 - 09:30 1.00 STWHIP P WEXIT Shallow test MWD at 450 gpm with 995 psi - OK.
09:30 - 13:30 4.00 STWHIP P WEXIT RIH to 4877' picking up 4" drill pipe, XO to 5" drillpipe and PU 1
stand. Fill pipe.
13:30 - 14:30 1.00 STWHIP P WEXIT Cut and slip 84' of drilling line.
14:30 - 15:00 0.50 STWHIP P WEXIT Service rig, drawworks, top drive and crown.
Printed: 4/13/2009 2:52:06 PM
BP EXPLORATION Page 4 of 16
Operations Summary Report
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
06-14
06-14 Spud Date: 6/5/1980
REENTER+COMPLETE Start: 3/6/2009 End: 4/4/2009
NABOBS ALASKA DRILLING I Rig Release: 4/5/2009
NABOBS 9ES Rig Number: 9ES
Date .From - To Hours Task Code
3/14/2009 115:00 - 00:00 I 9.001 DRILL I P
3/15/2009 100:00 - 06:00 I 6.001 DRILL I P
06:00 - 07:00 1.00 ~ DRILL N
07:00 - 07:30 0.50 DRILL N
07:30 - 09:00 1.50 DRILL N
09:00 - 12:00 3.00 DRILL N
12:00 - 14:00 2.00 DRILL N
14:00 - 14:30 0.50 DRILL N
14:30 - 16:45 2.25 DRILL N
16:45 - 17:00 0.25 DRILL N
17:00 - 20:30 3.50 DRILL N
20:30 - 21:00 0.50 DRILL N
21:00 - 00:00 3.00 DRILL P
3/16/2009 ~ 00:00 - 08:30 8.50 ~ DRILL ~ P
08:30 - 13:00 4.50 DRILL N
13:00 - 15:40 2.67 DRILL N
15:40 - 16:00 0.33 DRILL N
16:00 - 17:45 1.75 DRILL N
17:45 - 18:00 0.25 DRILL N
18:00 - 19:00 1.00 DRILL N
19:00 - 00:00 5.001 DRILL P
3/17/2009 100:00 - 12:00 I 12.001 DRILL I P
NPT ~, Phase Description of Operations
INT1 Establish baseline ECD of 9.44 ppg. Drill ahead to 5443' MD,-
5276' TVD. Pump at 550 gpm with 1750 psi off bottom, 1850
psi on bottom. Rotate at 60 rpm with torque off bottom 4k, on
bottom 5k. WOB 10k. Mud weight in and out 9.0 ppg.
Calculated ECD 9.63 ppg, ECD 9.7 ppg. Up weight 145k, down
125k, RT 138k. ART - 5.62.
INT1 PJSM. Directional drill ahead to 5766' MD, 5597' TVD. Pump at
550 gpm with 1850 psi off bottom, 2030 psi on bottom. Rotate
at 60 rpm with 4k torque off bottom, 5k torque on bottom. WOB
5-10k. Up weight 150k, down 125k, RT 145k. Mud weight in
and out 9.1 ppg. Calculated ECD 9.6 ppg, ECD 9.64 ppg.
DPRB INT1 Circulate BU at 543 gpm with 1890 psi. Rotate at 50 rpm with
4k torque. Mud weight in and out 9.0 ppg.
DPRB INT1 POOH to 5015'.
DPRB INT1 Perform MAD pass from 5015' to 4650' at 300 fph in recorded
mode.
DPRB INTi POOH to 762'.
DPRB INTi PJSM. Lay down bit, motor, RSS and MWD.
DPRB INT1 Clear and clean floor.
DPRB INT1 PU new motor with 1.83 degree bend, MWD and bit to 745'. Up
weight 74k, down 70k.
DPRB INT1 Shallow test MWD - OK.
DPRB INT1 RIH to 5617'.
DPRB INT1 Make up top drive. Wash down to 5766'.
INT1 Directional drill ahead to 5817' MD, 5583' TVD. Pump at 520
gpm with 1550 psi off bottom, 1575 psi on bottom. WOB 2-5k.
Up weight 155k, down 135k. Mud weight 9.1 ppg. Calculated
ECD 9.63 ppg, ECD 9.71 ppg. AST - 2.62.
INT1 PJSM. Drill ahead to 6121' MD. Pump at 526 gpm with 1610
psi off bottom, 1800 psi on bottom. Rotate at 40-50 rpm with 5k
torque off bottom, 7k torque on bottom. WOB 5-15k. Up weight
160k, down 130k, RT 145k. Mud weight in and out 9.0 ppg.
Calculated ECD 9.63 ppg, ECD 9.69 ppg. Having trouble
rotating with ghost reamer contacting orininal well bore casing.
Torquing and stalling out. Sliding is OK but slow. Decision
made to POOH. Mud weight in and out 9.1 ppg. Shut down
monitor well - OK.
DPRB INT1 Up weight 165k, down 135k. POOH to 743'. Monitor well - OK.
DPRB INTi PJSM. Rack back HWDP and 1 stand of collars. Lay down
ghost reamer. Inspect bit - OK. Change motor bend from a
1.83 deg to 1.5 deg. Dump LWD. Pick up BHA to 743'.
DPRB INT1 Shallow test MWD - OK.
DPRB INTi RIH to 4948'.
DPRB INT1 Make up top drive. Fill pipe. Orient to 90 L.
DPRB INTi Work through window with 5-10k drag. Wash down from 6083'
to 6121'.
INT1 Directional drill ahead to 6314' MD, 5951' TVD. Pump at 540
gpm with 1675 psi off bottom, 1900 psi on bottom. Rotate at 50
rpm with 5k torque off bottom, 7k torque on bottom. WOB
5-10k. Calculated ECD 9.63 ppg, ECD 9.66 ppg. Mud weight in
and out 9.1 ppg. ART - .77, AST - 2.58. Up weight 165k, down
135k, RT 148k.
INT1 PJSM. Drill ahead to 6929' MD, 6254' TVD. Pump at 550 gpm
Printetl: 4/13/2009 2:52:06 PM
~ ~
BP EXPLORATION Page 5 of 16
Operations Summary Report
Legal Well Name: 06-14
Common Well Name: 06-14
Event Name: REENTER+COMPLETE
Contractor Name: NABOBS ALASKA DRILLING
Rig Name: NABOBS 9ES
Date From - To 1, Hours Task Code NPT
3/17/2009 00:00 - 12:00 I 12.00 DRILL P
12:00 - 00:00 I 12.001 DRILL I P
3/18/2009 100:00 - 12:00 I 12.001 DRILL I P
12:00 - 00:00 I 12.001 DRILL I P
Spud Date: 6/5/1980
Start: 3/6/2009 End: 4/4/2009
I Rig Release: 4/5/2009
Rig Number: 9ES
Phase Description of Operations
INT1 with 1860 psi off bottom, 2100 psi on bottom. Rotate at 55 rpm
with 5k torque off bottom, 6k torque on bottom. WOB 5-10k.
Mud weight in and out 9.3 ppg. Calculated ECD 9.63 ppg, ECD
9.84 ppg. Up weight 170k, down 140k, RT 155k.
INT1 PJSM. Drill ahead to 7992' MD, 6928' TVD. Pump at 560 gpm
with 2200 psi off bottom, 2500 psi on bottom. Rotate at 80 rpm
with 5k torque off bottom, 6k torque on bottom. WOB 15k. Mud
weight 9.3 ppg. Calculated ECD 9.84 ppg, ECD 10.4 ppg. Up
weight 175k, down 147k, RT 157k. AST - 7.7, ART - 7.5.
INT1 PJSM. Directional drill ahead to 8780' MD, 7426' TVD. Pump at
565 gpm with 2545 psi off bottom, 2850 psi on bottom. Rotate
at 80 rpm with 6k torque off bottom, 8k torque on bottom. WOB
5-15k. Mud weight in and out 9.3 ppg. Calculated ECD 9.82
ppg, ECD 10.34 ppg. Up weight 200k, down 155k, RT 170k.
INT1 PJSM. Directional drill ahead to 9453' MD, 7896' TVD. Pump at
530 gpm with 2660 psi off bottom, 3050 psi on bottom. Rotate
at 80 rpm with 8k torque off bottom, 9k torque on bottom. WOB
5-15k. Mud weight in and out 10.7 ppg. Calculated ECD 11.21
ppg, ECD 11.75 ppg. Up weight 215k, down 160k, RT 180k.
Added s ike fluid at 9200' MD brin in wei ht to 10.7 ART
- 3.9, AST - 13.45.
3/19/2009 100:00 - 10:00 I 10.001 DRILL I P
Well 13-17 shut in at 23:00 hours
INT1 PJSM. Directional drill ahead to 10196' MD, 8352' TVD. Pump
at 536 gpm with 2970 psi off bottom, 3240 psi on bottom.
Rotate at 80 rpm with 10k torque off bottom, 11 k torque on
bottom. WOB 5-15k.Mud weight in and out 10.7 ppg.
Caclulated ECD 11.37 ppg, ECD 11.81 ppg. Up weight 225k,
10:00 - 12:00 2.00 DRILL N RREP INT1 PJSM. Change all swabs on #2 pump.
12:00 - 23:00 11.00 DRILL P INT1 Drill ahead to 10720' MD, 8689' TVD. Pump at 525 gpm with
2950 psi off bottom, 3050 psi on bottom. Rotate at 80 rpm with
14k torque off bottom, 15k torque on bottom. WOB 5-15k. Up
weight 235k, down 170k, RT 185k. Mud weight in and out 10.7
ppg. AST - 3.64, ART - 7.83. While drilling ahead to pick TD
encountered hard cap at 10717. At 10720 began loosing mud.
23:00 - 00:00 1.001 DRILL P
3/20/2009 100:00 - 02:00 2.001 DRILL ~ P
02:00 - 02:30 I 0.501 DRILL I P
02:30 - 07:30 I 5.001 DRILL I P
INTi Circulate up samples at 500 gpm with 2595 psi. Rotate at 90
rpm with 15k torque. Calculated ECD 11.38 ppg, ECD 11.41
ppg. Mud weight in and out 10.7 ppg. Dynamic losses ranging
from 50 to 80 bph. Static losses at 18 bph.
INT1 Circulate for samples at 500 gpm with 2595 psi. Rotate at 90
rpm with 15k torque. Mud weight in and out 10.7 ppg. Shut
down to monitor well. Dynamic losses still ranging from 50-80
bph. Static losses at 18 bph. Reduce rate to 180 gpm. Decide
to drill ahead through hard cap until drill off is observed.
INT1 Drill ahead to 10726'. Drilling rate increased throu h hard ca .
Pump at 525 gpm with 3050 psi. Rotate at 90 rpm with 15k
torque. WOB 4-6k. Up weight 235k, down 170k, RT 195k. Mud
weight in and out 10.7 ppg.
INTi Circulate up samples at 500 gpm with 2595 psi. Rotate at 90
rpm with 15k torque. Working pipe. Lost i e wor a
pipe. Still loosing fluid at 50-80 bph. Continue to work pipe and
Printed: 4/13/2009 2:52:06 PM
~ •
BP EXPLORATION
Operations Summary Report
Legal Well Name: 06-14
Common Well Name: 06-14
Event Name: REENTER+COMPLETE
Contractor Name: NABOBS ALASKA DRILLING I
Rig Name: NABOBS 9ES
Date '~, From - To ~ Hours Task ,Code NPT
3/20/2009 102:30 - 07:30
07:30 - 12:00
12:00 - 13:30
13:30 - 14:30
14:30 - 15:00
15:00 - 17:30
17:30 - 19:00
19:00 - 20:00
20:00 - 20:30
20:30 - 22:00
22:00 - 22:30
22:30 - 23:00
23:00 - 00:00
3/21/2009 00:00 - 01:30
01:30 - 11:00
11:00 - 12:30
12:30 - 15:00
15:00 - 15:30
15:30 - 16:00
16:00 - 19:00
19:00 - 20:30
20:30 - 00:00
Start: 3/6/2009
Rig Release: 4/5/2009
Rig Number: 9ES
Page 6 of 16 I
Spud Date: 6/5/1980
End: 4/4/2009
Phase I Description of Operations
5.00 DRILL P INT1 loose pressure. Reduce rate to 180 gpm with 1000 psi. Mix
LCM pill with 80 ppb. Drop ball to open up PBL for pumping
LCM. A 200 psi pressue increase observed with no drop off in
pressure. Break pipe and drop steel balls to push 2" activation
ball through ball catcher. No pressure changes. Bring pumps
up to 410 gpm and observe 50% pump pressure loss at same
rate while circulating up samples. Pump and spot LCM pill at
165 gpm with 385 psi. Shut down, monitor well - OK. Mud
weight in and out 10.7 ppg.
4.50 DRILL P INT1 POOH for wiper trip to 4948'. Up weight 290k, down 175k. Find
washed out single in the 5" drill pipe at 5196'. Pull and rep a7 ce-
Tight spot at 9218', work through 3 times, cleaned up. Tight
spot at 6770', worked once and cleaned up. No other problems.
Some small seepage losses while pulling out.
1.50 DRILL P INT1 Circulate BU at 533 gpm wit 222 psi. otate at 60 rpm and
reciprocate with 2k torque. With 175 bbls pumped observe
LCM at surface. No losses during pumping.
1.00 DRILL P INT1 PJSM. Cut and slip 72' of drilling line.
0.50 DRILL P INT1 Service rig, top drive, crown and blocks.
2.50 DRILL P INT1 POOH to 281'.
1.50 DRILL P INT1 Lay down intermediate BHA.
1.00 DRILL P INT1 Clear and clean floor.
0.50 BOPSU P LNR1 Pull wear ring. Run in test plug.
1.50 BOPSU P LNR1 PJSM. Change out 3-1/2" X 6" variable rams to 7" rams.
0.50 BOPSU P LNR1 Rig up to test 7" rams.
0.50 BOPSU P LNRi est 7 rams wit 7" test joint to 250 psi low, 3500 psi
high as per AOGCC. Test witnessed by WSL Mitch Skinner
and Toolpusher Roy Hunt.
1.00 BOPSU P LNR1 Rig down test equipment. Run in 9.125" ID wear ring.
1.50 CASE P LNR1 PJSM. Pick up handling equipment. Rig up to run 7", 26#, L-80,
BTC-M liner. Hold PJSM meeting with crew, casing crew and
Baker.
9.50 CASE P LNR1 Run 7", 26#, L-80, BTC-M liner. Average MU torque 7300 fUlbs.
Fill on the fly and top off every 10 joints. Run in to 4885'. Up
weight 139k, down 132k.
1.50 CASE P LNR1 Circulate surface to surface volume of 320 bbls at 6 bpm with
345 psi. LCM at surface.
2.50 CASE P LNR1 Run liner to 5886'.
0.50 CASE P LNR1 Make up hanger and packer with running tool. Mix and setup
debris barrier.
0.50 CASE P LNRi PU one stand of 5" HWDP and circulate an open hole volume
of 40 bbls at 6 bpm with 680 psi. More LCM at surface.
3.00 CASE P LNR1 Run in hole with 7" liner on 5" drill pipe to 9105'. Up weight
165k, down 135k.
1.50 CASE P LNR1 Circulate while washing last 3 stands down before entering the
HRZ. Stage pumps up to 6 bpm. Last stand started at 3 bpm
with 870 psi and 8.5% flow and ended at 6 bpm with 905 psi
and 18.4% flow. Still seeing LCM across shakers, but tapering
off towards the end.
3.50 CASE P LNRi RIH to 9640' and hang up. Work up 425k and down 40k with no
go. Pressure up and bleed off several times with no success
establishing circulation. Work pipe again and establish
circulation at 3.5 bpm with 900 psi. Attempt to pull up with no
Printed: 4/13/2009 2:52:06 PM
BP EXPLORATION Page 7 of 16 ~
Operations. Summary Report
Legal Well Name: 06-14
Common Well Name: 06-14 Spud Date: 6/5/1980
Event Name: REENTER+COMPLETE Start: 3/6/2009 End: 4/4/2009
Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/5/2009
Rig Name: NABOBS 9ES Rig Number: 9ES
Date From - To Hours 'i Tasl< ~ Code'; NPT Phase
-- l
3/21/2009 20:30 - 00:00 3.50 CASE P ~ I LNR1
3/22/2009 100:00 - 03:30 I 3.501 CASE I P
03:30 - 05:00 I 1.501 CEMT I P
05:00 - 05:30 0.501 CEMT P
05:30 - 06:49 ~ 1.32 ~ CEMT ~ P
06:49 - 09:00 I 2.181 CEMT I P
LNR1
LNR1
LNR1
LNR1
LNR1
Description of Operations
go. Wash down to 9673'. Work in hole dry to 10298' and hang
up in HRZ. Attempt several times to work free with no success.
Establish circulation at 2 bpm with 598 psi and wash down 1
joint to 10329'. Shut down pumps and work pipe down dry.
Hang up several times but able to work slowly through to
10360'.
PJSM. Work down through Kingak. Hanging up but able to
work slowly through without having to kick in pumps. Tag up at
10726' MD. Pull stretch plus 1'. Slack off stretch.
Establish circulation at 3 bpm with 735 psi at 5.9% flow. After
257 bbls away pressure dropped to 565 psi with 7.9% flow.
Stage up pumps to 6 bpm.
4 bpm / 713 psi / 10.3% flow
5 bpm / 947 psi / 15.0% flow
6 bpm / 1320 psi / 18.5% flow to start
PJSM. Hold pre job safety meeting with crew, truckers,
cementers and Baker packer reps.
Continue to circulate while cementers are batching up. Attempt
to pull up to 325k. No pipe movement.
6 bpm / 1093 psi / 19.5% flow before start of cement job.
Pump 10 bbls 11.0 ppg Mudpush II.
Pressue test lines to 4500 psi.
06:49 pump remaining 20 bbls Mudpush II at 5 bpm.
06:53 pump 181.5 bbls 11.5 ppg LitCREATE lead slurry at 5
bpm.
07:27 end lead slurry.
07:25 pump 20 bbls 15.8 ppg Class G tail slurry at 5 bpm.
07:33 drop plug and kick out with 5 bbls water.
Switch to rig pumps.
07:42 start displacement.
Latch up at 73.5 bbls.
BUfT1D olua at 298 bbls.
CIP at 08:40 hours.
Pressure up to 2800 psi and set hanger.
Set down liner weight plus 20k. Increase pressure to 4200 psi
and release from setting tool.
Check floats - OK.
Pick up 2' and verify running tool release.
PU to dogs out plus 2', rotate while slacking off 50k and set
packer.
Pressure up to 1000 psi. Pull out of tool and establish
circulation.
Lead Slurry:
181.5 bbls
345 sacks
2.95 yield
Tail Slurry:
20 bbls
97 sacks
Printetl: 4/13/2009 2:S1:Uti PM
BP EXPLORATION
Operations Summary Report
Page 8 of 16
Legal Well Name: 06-14
Common Well Name: 06-14 Spud Date: 6/5/1980
Event Name: REENTER+COMPLETE Start: 3/6/2009 End:. 4/4/2009
Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/5/2009
Rig Name: NABORS 9ES Rig Number: 9ES
Date ~ From - To ~ Hours Task ode NPT Phase Description of Operations
3/22/2009 06:49 - 09:00 2.18 CEMT P LNR1 1.16 yield
09:00 - 11:00 2.00 CEMT P LNR1 Circulate bottoms up at 350 gpm with 511 psi. Reciprocate
pipe. Approximately 10 bbls of cement back to surface.
11:00 - 15:30 4.50 CEMT P LNR1 Lay down cement head. POOH laying down 5" drill pipe to 480'.
15:30 - 16:30 1.00 CEMT P LNR1 RIH with 5" drill pipe stands to 2220'.
16:30 - 18:30 2.00 CEMT P LNR1 POOH laying down 5" drill pipe, HWDP and liner running tool.
18:30 - 19:00 0.50 CEMT P LNR1 Clear and clean floor. Function test BOP rams.
19:00 - 21:30 2.50 CASE P TIE61 PJSM. Pull wear ring. Rig up to run 7" tieback.
21:30 - 00:00 2.50 CASE P TIEB1 PJSM. Run 7", 26#, L-80, TCII tieback to 434'. Run and
Bakerlock Tieback Stem to 1 st joint above float collar. Fill and
check float - OK. Fill on the fly. Torque turn to 10100 ft/Ibs.
3/23/2009 00:00 - 07:00 7.00 CASE P TIEB1 PJSM. Run 7", 26#, L-80, TCII tieback. Torque turn
connections to 10100 ft/Ibs. Fill on the fly. Up weight 150k,
down 135k. Make up cement head and pup joint. Run into
rece tacle and to u on no- o. Pressure u to 1000 si. Pick
up and expose ports. Kick in pumps as pressure starts to
release.
07:00 - 08:00 1.00 CEMT P TIEB1 Stage pumps up to 5 bpm with 668 psi.
08:00 - 08:30 0.50 CEMT N WAIT TIEB1 Waiting on word to go back to work. Shut down because of
volcanic eruption. Still circulating. Life flights still flying as
needed. Decided to go back to work. Hold PJSM with crew,
SCH, Baker and LRS.
08:30 - 09:00 0.50 CEMT P TIEB1 Pump 40 bbls spacer with red dye.
Start 120 gpm with 360 psi.
Ending 181 gpm with 508 psi.
09:00 - 11:00 2.00 CEMT N SFAL TIEB1 Waiting on LRS to thaw out pump truck. Unable to thaw out
truck. Switch to SCH to pump diesel.
11:00 - 13:00 2.00 CEMT P TIEB1 Pump 10 bbls diesel. Pressure test lines to 4000 psi - OK.
11:03 pump remaining 75 bbls diesel.
11:50 stop pumping diesel.
Drop bottom plug.
11:53 Start pumping 49 bbls of Class G Tail at 4 bpm with
1012 psi.
11:56 26 bbls away with 916 psi.
12:05 End pumping with 467 psi.
Drop top plug and kick out with 5 bbls of water.
Swap to rig pumps.
Pump at 6 bpm with 994 psi.
12:31 slow to 5 bpm with 321 psi.
12:35 slow to 3 bpm with 605 psi.
12:42 Bump plug at 3104 strokes/179 bbls with 2530 psi.
Got back 28 bbls diesel to surface.
Lower stem seal assembly into receptacle to no-go while
bleeding off pressure.
Check float - OK.
Slack off to 100k and PU to 140k.
CIP at 12:42.
Cement volume 49 bbls.
Sacks of cement 235.
Yield 1.17
No losses during operation.
Printed: 4/13/2009 2:52:06 PM
BP EXPLORATION
Operations Summary Report
Legal Well Name: 06-14
Common Well Name: 06-14
Event Name: REENTER+COMPLETE
Contractor Name: NABOBS ALASKA DRILLING
Rig Name: NABOBS 9ES
i
Date From - To Hours II Task Code NPT
3/23/2009 13:00 - 13:30 0.50 CEMT P
13:30 - 18:00 4.50 WHSUR P
18:00 - 23:00 5.00 BOPSU P
23:00 - 00:00 1.00 BOPSU P
3/24/2009 00:00 - 02:00 2.00 BOPSU P
02:00 - 03:30 1.50 BOPSU P
03:30 - 10:00 6.50 BOPSU P
Start: 3/6/2009
Rig Release: 4/5/2009
Rig Number: 9ES
Page 9 of 16 ~
Spud Date: 6/5/1980
End: 4/4/2009
Phase Description of Operations
TIEB1
TIEB1
PROD1
PROD1
PROD1
PROD1
PROD1
Rig down and blow down cement head and lines.
PJSM. Remove mouse hole and ND BOP stack. Install
emergency slips with 100k. Make casing cut. Lay down cut joint
of 12.82'. Install new tubing spool with 7" secondary packoff.
Pressure test to 4300 psi - OK.
NU BOPE.
Change out top rams from 7" to 3-1/2" X 6" variables.
PJSM. C;0~7" rams to 3-1 2' x 6 vana es. ong a es. CO
5" saver sub to 4".
Rig up for BOP test. Run in test plug.
PJSM. Test BOPE to 250 psi low, 3500 psi high as per
AOGC .Test wit 4 an - es joints. Test witness
waived by John Crisp with AOGCC. Test witnessed by WSL's
Blair Neufeld and Mitch Skinner and Toolpushers Chris Weaver
and Roy Hunt.
Choke valve #15 passed initial test, but was broken while
attempting to re-open; replace choke valve #15.
Pressure test choke valve #15 to 250psi low, 3500psi high;
good test.
Blow down lines and install wear ring; PU BHA #6 (6-1/8"
MSX513M-A16 Hycalog bit, 1.83deg motor, Impulse MWD and
ADN w/ nuclear source). RIH with BHA from surface to 288'.
RIH with BHA #6, single in on 4" DP from 288' to 4739'.
Conduct shallow pressure test to check tieback liner integrity.
Test to 3500psi for 5min; good test.
Tag cement plug top Cat 4777'. Drill out top plug and cement;
rubber and cement over the shakers while drilling. Drill out plug
from 4777' to 4850'. Wash pipe down from 4850' to 4920' to
mitigate stringer hazards. 115k up, 100k down, 105k rotating.
1840psi off, 2160psi on Ca? 232gpm, 95spm. 40rpm; 1.2k off,
2.6k on. WOB = 15k. CBU at 4920' before continuing to trip in.
RIH, picking up singles of 4" DP from 4739' to 6076'. Encounter
stringer C«~ 5320'; wash by and clean up stringer.
PJSM. RIH with stands of 4" DP to 10,565'; 262k up, 126k
down. 1440psi C~ 122gpm.
Ria uo to test 7" casino. Pressure test casing to 3500psi for
10:00 - 11:30 1.50 BOPSU N SFAL PROD1
11:30 - 12:00 0.50 BOPSU P PROD1
12:00 - 15:00 3.001 DRILL P PROD1
15:00 - 19:30 4.50 DRILL P PROD1
19:30 - 20:00 0.50 BOPSU P PROD1
20:00 - 22:00 2.001 DRILL P PROD1
22:00 - 00:00 2.001 DRILL P PROD1
3/25/2009 100:00 - 04:00 4.00 DRILL P PROD1
04:00 - 05:30 1.501 DRILL P PROD1
05:30 - 06:30 1.00 DRILL P
06:30 - 09:00 2.50 DRILL P
09:00 - 11:30 I 2.501 DRILL I P
11:30 - 13:30 2.00 DRILL P
13:30 - 17:00 3.50 DRILL P
WSLs Amanda Rebol and Blair Neufeld and Toolpushers Roy
Hunt.
PROD1 Slip and cut drilling line.
PROD1 Drill out 7" shoe track from 10,565' to 10,706'. 2292 psi on,
2295 psi off Ca3 227gpm. 12k torque on, 11 k torque off. 265k
up, 120k down, 155k rotating; 30 rpm and WOB = 5k.
PROD1 Swap from 10.7ppg LSND to 8.5ppg FlowPro mud before
drilling ahead in production interval. 1547psi Cad 245gpm. 265k
up, 120k down, 155k rotating; 30rpm.
PROD1 Drill remaining shoe track and 40' of new formation; from
10,706' to 10,746'. 180k up, 150k down, 165k rotating. 1930 psi
off, 1910psi on ~ 107spm and 260gpm. 3.5k torque off, 5k
torque on, 40rpm and WOB = 10k. Preform LOT; 808psi at
surface mud wei ht at 8.5 .LOT = 10.29
PROD1 Drill 6-1/8" production hole from 10,746' to 10,897' with
Hycalog MSX513M-A1 B, 1.83deg motor, Impulse MWD and
Printed: 4/13/2009 2:52:06 PM
___
BP EXPLORATION
Operations Summary Report
Legal Well Name: 06-14
Common Well Name: 06-14
Event Name: REENTER+COMPLETE
Contractor Name: NABOBS ALASKA DRILLING I
Rig Name: NABOBS 9ES
Start: 3/6/2009
Rig Release: 4/5/2009
Rig Number: 9ES
Date From - To Hours Task Code NPT Phase I
3/25/2009 13:30 - 17:00 3.50 DRILL
P
17:00 - 18:00 ~ 1.00 ~ DRILL ~ P
18:00 - 20:00 I 2.001 DRILL I P
20:00 - 00:00 I 4.001 DRILL I P
3/26/2009 100:00 - 12:00 I 12.001 DRILL I P
12:00 - 00:00 I 12.001 DRILL I P
3/27/2009 100:00 - 09:00 I 9.001 DRILL I P
09:00 - 10:30 ~ 1.501 DRILL ~ P
10:30 - 15:30 I 5.001 DRILL I P
15:30 - 17:00 ~ 1.50 ~ DRILL ~ P
17:00 - 20:00 I 3.001 DRILL I P
20:00 - 22:00 I 2.001 DRILL I P
Page 10 of 16
Spud Date: 6/5/1980
End: 4/4/2009
Description of Operations
PRODi ADN logging tools (BHA #6). 180k up, 150k down, 165k
rotating. 1730psi off, 1910psi on @ 107spm and 260gpm.
3.5torque off, 5k torque on, 40rpm and WOB = 15k. Losses
started around 10,777', and loss rate steadily increased;
95bb1/hour loss rate @ 10,897' MD.
PROD1 Stop drilling and POH while building 45ppb LCM pill. Spot LCM
pill (40 bbls) just below the 7" casing shoe. Monitor well after
spotting pill; static with pumps off.
PROD1 Pull up above LCM pill from 10,690' to 9801'. Reciprocate pipe
and circulate in order to push pill down into formation. Circulate
bottoms up; 1330psi @ 89spm, 217gpm. Marginal losses while
pumping, no losses with pumps off.
PROD1 Run back to bottom, monitoring for losses. Begin drilling ahead
in formation; initial losses while drilling @ 40bb1/hr, but dropped
off to 20-25bb1/hr within 20 feet of new hole. Drill ahead from
10,897' to 10,947' (8838' TVD). 185k up, 150k down, 165k
rotating. 1730psi off, 1910psi on @ 107spm and 260gpm. 3.5k
torque off 5k torque on, 40rpm and WOB = 15k. Losses
consistent @ 20-25bb1/hr
PROD1 PJSM. Drill 6-1/8" production hole from 10,947' to 11,326'.
Sustained losses around 20-25bb1/hr. Building mud system w/
water @ 25-30bb1/hr. 187k up, 145k down, 168k rotating.
1759psi off, 2220psi on @ 257gpm. 4k torque off, 7k torque on,
40rpm and WOB = 15k. 4.75hrs sliding, 1.88hrs rotating.
PROD1 Continue to drill 6-1/8" production hole from 11,326' to 11,870'.
190k up, 140k down, 170k rotating. 1910psi off, 2340psi on @
107spm and 262gpm. 5k torque off, 9k torque on, 40rpm and
WOB = 18k. 4.53hrs sliding, 4.13hrs rotating. Losing drilling
mud at a rate of 20-25bb1/hr; adding water and building mud
volume @ 25-30bb1/hr.
PROD1 PJSM. Drill 6-1/8" production hole from 11,870'to 12,197' MD.
185k up, 135k down, 160k rotating. 2170psi off, 2495psi on @
107spm and 262gpm. 6k torque off, 10k torque on, 40rpm and
WOB = 18k. Consistent losses -25bb1/hr. 2.22hrs sliding,
2.07hrs rotating.
PROD1 Gradual losses increased to total losses @ 12,197'. POOH
loss of 600psi when losses were first encountered (geology
indicates resistivity break that indicates local fracture). Pump
down DP; 59psi @ 21spm and 51gpm. Drop 1.5" ball to PBL
open circ sub in prep for spotting LCM pill. 215k up, 155k
down.
PROD1 Shut in well• waiin on fluids in order to um LCM and fight
losses. State notified• ressure test of annular re wired at next
0 ortunit .Monitor well and service top drive while waiting.
PROD1 PJSM before opening well back up. Confirm circ sub open;
spot 40bb1 of 85ppb LCM pill @ 10,470' MD.
PROD1 Pull up above LCM pill from 10,660' to 9992'. Circulate above
pill to push LCM into formation. Monitor well; static losses @
PROD1 Run back to bottom; wash down through slight obstruction
11,803'. Finish running to bottom with no further problems. No
returns swap from 8.5 ppg FlowPro to 8.5ppg seawater to drill
Printed: 4/13/2009 2:52:06 PM
BP EXPLORATION Page 11 of 16
Operations Summary Report
Legal Well Name: 06-14
Common Well Name: 06-14 Spud Date: 6/5/1980
Event Name: REENTER+COMPLETE Start: 3/6/2009 End: 4/4/2009
Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/5/2009
Rig Name: NABOBS 9ES Rig Number: 9ES
Date From - To ~', Hours Task Code NPT Phase Description of Operations
3/27/2009 20:00 - 22:00 2.00 DRILL P PROD1 ahead; drill 6-1/8" production hole from 12,197' to 12,331' MD. ~
22:00 - 23:00 1.00 DRILL P PROD1
23:00 - 00:00 1.00 DRILL N DFAL PROD1
3/28/2009 00:00 - 06:30 6.50 DRILL N DFAL PROD1
06:30 - 08:00 1.50 DRILL N DFAL PROD1
08:00 - 10:00 2.00 DRILL P PROD1
10:00 - 13:00 3.00 DRILL N DFAL PROD1
13:00 - 19:30 6.50 DRILL N DFAL PROD1
19:30 - 00:00 I 4.501 DRILL I P
3/29/2009 00:00 - 02:30 2.50 DRILL P
02:30 - 06:30 4.00 DRILL P
~ 06:30 - 09:00 2.50 DRILL P
09:00 - 12:30 3.50 CASE P
12:30 - 16:00 3.50 CASE P
16:00 - 18:30 2.50 CASE P
18:30 - 00:00 5.50 CASE P
Call TD C~3 12,331' MD, 8817' TVD. 1.88hrs rotating. 215k up,
135k down, 170k rotating. 1919psi on, 1620psi off ~ 259gpm.
9k torque on, 6k torque off C~ 40rpm.
Begin MAD pass from 12,331' to 12,267' C~ rate of 700fph,
40rpm. 1467psi ~ 259gpm. MWD tool failure; potential failed
seal.
POOH from 12,267' to 12,094', racking back 4" DP and
keeping hole full with 8.5ppg seawater.
PJSM. POOH from 12,094' to surface, racking back 4" DP and
keeping hole full with 8.5ppg seawater.
LD BHA #6; PJSM for removing ADN nuclear source. PU new
logging tool and new ADN. Check motor and bit; fit for rerun.
Orient BHA and stand back in derrick.
Pull wear ring and install test plug; test annular to 250psi low
and_2500psi high. Hold for 5 minutes and chart; good test.
Pressure test witnessed by WSL Blair Neufeld and Toolpusher
Charlie Henley. Rig down test equipment; pull test plug and
re-install wear ring.
RIH with BHA #7 (bit and motor from previous BHA, new
Impulse and ADN, PBL circ sub from previous BHA) to 96' and
attempt to install source in ADN tool; unable to do so. Swap out
ADN tools and re-load source in tool.
RIH from surface to 12,331'. Slight tight spots encountered ~
11,806' and 11,917'. Also from 12,114' to 12,125' and 12,205'
to 12,230'.
PROD1 MAD pass from 12,331' to 11,612' ~ 700fph. 225k up, 145k
down, 175k rotating. 1296psi @ 252gpm. 8k torque ~ 40rpm.
Pumps on; complete losses. 8.5ppg seawater being pumped
downhole.
PROD1 PJSM. Backream and MAD pass from 11,612' MD to the 7"
liner shoe at 10,725'. MAD pass at a rate of -700fph. 215k up,
145k down, 175k rotating. 8k torque @ 40rpm. 1296psi C~3
252gpm. Pumping 8.5ppg seawater; total losses.
PROD1 Drop 2-3%8" drift downhole and POOH from 7" liner shoe to
surface, racking back 4" DP. Hole fill on backside; no fluid
returns. 215k up, 150k down.
PROD1 LD BHA; break out circ sub and logging tools; PJSM for
handling nuclear source. LD motor and bit; bit grade 3 - 2 - WT
- A - X - I - BT -TD. RD third party tools; clean and clear rig
floor.
RUNPRD PJSM with casing hand. RU to run liner; change out bales, RU
compensator, torque-turning equipment, stabbing board and
double-stack tongs.
RUNPRD PJSM. Run 4.5" 12.6# 13Cr VamTop production liner.
Baker-lok shoe track and uti ize compensa or o joints.
Torque each joint to optimum 4440ft-Ibs. RIH with liner from
surface to 1727'.
RUNPRD MU production liner hanger. Attempt to circulate ~ max rate,
looking for returns. Pump 591 psi 273gpm; no returns
(pumped 396bb1s seawater total). RD liner running equipment,
change out bales.
RUNPRD RIH w/ 4.5" 13Cr production liner and 4" DP from 1727' to
Printed: 4/13/2009 2:52:06 PM
BP EXPLORATION Page 12 of 16
Operations Summary Report
Legal Well Name: 06-14
Common Well Name: 06-14 Spud Date: 6/5/1980
Event Name: REENTER+COMPLETE Start: 3/6/2009 End: 4/4/2009
Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/5/2009
Rig Name: NABOBS 9ES Rig Number: 9ES
Date From - To Hours Task Code NPT Phase Description of Operations
3/29/2009 18:30 - 00:00 5.50 CASE P RUNPRD 7093'. 135k up, 120k down; attempt to fill pipe every 15 stands;
no returns.
3/30/2009 00:00 - 02:00 2.00 CASE P RUNPRD PJSM. RIH w/ 4.5" 13Cr 12.6# VamTop production liner and 4"
DP from 7093' to 10,688'. 155k up, 130k down; attempt to fill
i e eve 15 stands no returns.
02:00 - 08:00 6.00 CASE N WAIT RUNPRD Stop running (~ the 7" casing shoe. Waiting on CH2MHill truck
support for cement job (all available trucks currently supporting
Northstar operations). Fill backside with 50 bbls every 30
minutes.
08:00 - 10:30 2.50 CASE P RUNPRD Trip in remaining depth from 7" casing shoe C~ 10,725' to
12,331'. Wash down through tight spots ~ 11,814', 11,900',
11,980' 12,05' and 12,042'.
10:30 - 12:30 2.00 CEMT P RUNPRD Rig up cementing head. Reciprocate pipe and circulate; 170psi
~ 3bpm. Fill down backside 5 bbls every 10 minutes; losses
still complete. 265k up, 145k down.
12:30 - 14:00 1.50 CEMT P RUNPRD PJSM with SLB cementing. Cement job as follows:
12:37 Pump 5 bbls 10ppg MudPush (no CemNet); pressure
test lines to 4500psi; okay
12:52 Pump remaining 25bbls 10 pgg MudPush with CemNet.
12:59 Pump 67bbls 15.8ppg Class G with CemNet. 5bpm with
206psi.
13:10 59.9 bbls away; 233psi @ 5.1 bpm.
13:14 Full cement volume away.
13:20 Drop plug; swap to rig pumps for displacement.
13:24 Pump 170psi @ 5bpm
13:36 Pump 450psi ~ 3bpm
Some returns while pumping
13:46 Bump plug C~ 3bpm and 530psi.
lift not seen while
Pressure up to 4300psi and release HR setting tool. Do NOT
set liner too packer: leave for remedial cement iob.
14:00 - 15:00
1.00
CEMT
P
RUNPRD Cement volume: 67bbls, 322sx with yield of 1.17cuft/sx
PU with DP w/ 1000psi on until RS tool free. Circulate 30bbls
and PU above tieback. Circulate and reciprocate to clean 7"
liner; 2260psi C~? 533gpm. 406bb1s pumped; return flow; no
cement in returns.
15:00 - 21:30 6.50 CEMT P RUNPRD POOH; LD cement head. Loss rate back to 185bb1/hr. Lay
down 48joints of drill pipe while tripping out. Rac back 4" DP
from 10,565' to rig floor.
21:30 - 00:00 2.50 CEMT P RUNPRD LD Baker liner running tool; dog sub NOT sheared (packer not
set). Function test variable bore rams and blind shear rams;
good. Pick up ported sub w/drill pipe stop and packoff for
remedial cement work.
3/31/2009 00:00 - 04:30 4.50 CEMT P RUNPRD PJSM. RIH with ball on shear seat, Baker packoff, no-go and
ported sub from surface to 10,565'. Sting into liner tieback
sleeve; tag up on liner top with no-go. Leave 2k on no-go to
confirm location. 230k up, 138k down. MU ball valve, 10' pup jt
and head pin for cement job.
04:30 - 08:00 3.50 CEMT N WAIT RUNPRD Waiting on SLB to receive thickening tests from lab before
Printed: 4/13/2009 2:52:06 PM
BP EXPLORATION Page 13 of 16
Operations Summary Report
Legal Well Name: 06-14
Common Well Name: 06-14 Spud Date: 6/5/1980
Event Name: REENTER+COMPLETE Start: 3/6/2009 End: 4/4/2009
Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/5/2009
Rig Name: NABORS 9ES Rig Number: 9ES
Date from - To Hours ~~, Task Code NPT Phase ~ Description of Operations
3/31/2009 04:30 - 08:00 3.50 CEMT N WAIT RUNPRD batching cement.
08:00 - 16:30 8.50 CEMT N HMAN RUNPRD Change of scope: displace secondary cement job with diesel
truck with heater to arrive on location.
16:30 - 18:00 1.50 CEMT P RUNPRD Pre-heat diesel to 70deg for displacement before batch-mixing
cement.
18:00 - 21:00 3.00 CEMT P RUNPRD PJSM with SLB cementing and LRHOS. Start batching cement
~ 18:35hrs; cement to weight ~ 19:03hrs. Fill lines with 5bbl
water and PT cement lines to 4500psi; PT LR lines to 4500psi.
Pump cement job as follows:
20:00 Close bag to squeeze cement down outside of 4.5"
production liner
20:02 Start pumping 15.8ppg slurry
Pump 57bbls of 15.8ppg Class G cement ~ 5bpm. Wellhead
pressure C~ 220-240psi throughout cement stage; slurry falling
on its own.
20:15 Cement away; swap from SLB cementing to LRHOS for
displacement
20:20 5bbls diesel away C~ 3.8bpm, 27psi on wellhead
20:25 30bbls diesel away @ 5bpm, 50psi on wellhead
20:29 50bbls diesel away (~ 5bpm, 50 psi on wellhead cement
at bottom of DP ~ 48bbls diesel awa
20:33 70bbls diesel away C~3 5bpm, 50psi on wellhead
20:35 -78bbls diesel away C~? 5bpm. Pressure spikes to
407psi; lower pump rate
20:36 80bbls diesel away Q 3bpm, 119psi on wellhead
20:38 90bbls diesel away ~ 3bpm, 412psi on wellhead; lower
pump rate again
20:40 93bbls diesel away ~ 2bpm, 394psi on wellhead
20:41 95bbls diesel away @ 2bpm, 439psi on wellhead
20:42 97bbls diesel away ~ 2bpm, 467psi on wellhead.
Shut down pumping ~ 97bbls diesel away. 467psi final
pressure on wellhead.
Pump 57bbls cement, 288sxs, 1.17cuft/sx. Leave 4lbbls
cement in the hole; -197sxs, 1.17cufUsx.
Set down 50k to set ZXP packer: positive indication that
21:00 - 22:00 1.001 CEMT P
RUNPRD ~ Reverse circulate with 8.5ppg seawater to displace diesel in DP_
hand anv remaining cement from wellbore. Pump 1335psi
C~J80spm~ 97bbls diesel and 16bbls cement to surface. 4lbbls
cement left in wellbore- equivalent o 2400' gauge hole x 4.5"
liner.
22:00 - 00:00 2.00 CEMT P
4/1/2009 100:00 - 01:30 I 1.501 CEMT I P
Attem t to ull out of PBR; over ull 45k; ball seat did not
shear. Pressure up to 1500psi to shear ball seat; seat shean
C~ 1437psi.
RUNPRD RD cement hose and headpin; POOH from 10,565' to 9053',
racking back stands of 4"DP. Monitor well; no losses. MC in
8.5ppg. MW out 8.5ppg.
RUNPRD PJSM. Cut and slip drilling line; service top drive.
Printed: 4/13/2009 2:52:06 PM
•
BP EXPLORATION Page 14 of 16
Operations Summary Report
Legal Well Name: 06-14
Common Well Name: 06-14 Spud Date: 6/5/1980
Event Name: REENTER+COMPLETE Start: 3/6/2009 End: 4/4/2009
Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/5/2009
Rig Name: NABOBS 9ES Rig Number: 9ES
Date 'From - To ~ Hours Task Code NPT ' Phase Description of Operations
4/1/2009 01:30 - 05:00 3.50 CEMT P
05:00 - 06:00 1.00 CEMT P
06:00 - 07:30 1.50 CLEAN P
07:30 - 12:30 5.00 CLEAN P
12:30 - 15:30 3.00 CLEAN P
15:30 - 20:00 4.50 CLEAN P
20:00 - 22:00 2.00 CLEAN P
22:00 - 00:00 2.00 EVAL P
4/2/2009 00:00 - 08:30 8.50 EVAL P
08:30 - 09:30 1.00 EVAL P
09:30 - 11:00 I 1.501 PERFOBI P
11:00 - 14:00 I 3.001 PERFOBI P
14:00 - 21:30 I 7.501 PERFOBI P
21:30 - 22:00 I 0.501 PERFOBI P
22:00 - 22:30 I 0.501 PERFOBI P
22:30 - 23:30 I 1.001 PERFOBI P
RUNPRD POOH from 9053' to surface, racking back 4" DP. 190k up,
130k down. No losses.
RUNPRD LD Baker remedial cement tools; packoff, drillpipe no-go and
ported sub. Monitor well..
RUNPRD PU Baker cleanout assembly; 3.75" bladed mill, two joints of
FOX tubing (to clean inside PBR) and 7" casing scraper.
Change out elevators and RU power tongs to handle 2-7/8"
FOX tubing.
RUNPRD RIH with cleanout assy from surface to 10,645 ;taking 4"DP
out of the derrick. 180k up, 140k down.
RUNPRD Circulate and reciprocate to clean casing. Pump 40bb1 high-vis
sweep around @ 1803psi and 328gpm. Monitor returns; no
cement in returns. Continue to circulate and reciprocate pipe in
10' strokes; 1958psi C~ 328gpm, -1.5xBU. 185k up, 147k
down.
RUNPRD Drop 2-3/8" drift and POOH from 10,645' to surface, racking
back 4"DP.
RUNPRD LD Baker cleanout tools; small amount of cement on the 7"
casing scraper; indication on the 3.75" mill where assy entered
the PBR, but no significant wear to either tool. Change out
elevators and RU power tongs to handle LD 2-7/8" FOX. Lower
Baker tools down beaver slide; clear rig floor of any other third
party tools.
RUNPRD PJSM with SLB wireline. RU SLB wireline, tractor and SCMT to
evaluate cement job on 4.5" production liner.
RUNPRD PJSM. Log with SLB wireline; tie into 4.5" liner top C~ 10,565'.
Use tractor to log down inside 4.5" liner from 10,565' to 12,242'
~ 1800ft/hr. Log back up while POOH. Stop logging at liner top
and POOH with wireline, tractor and SCMT logging tools. TOC
Q 11 030'. RD SLB wireline.
RUNPRD Pressure test 4.5" liner and liner la to 3500psi for 30min and
chart test; ood test. First 15 minutes: 15 si loss. Second 15
minutes: no loss.
OTHCMP PJSM with SLB perforating crew. PU 2-7/8" PowerJet Omeoa
2906 erforatin assembl and RIH to 953 ; MU firing head and
disconnect.
OTHCMP RD handling equipment for guns and RU to run 2-7/8" FOX tbg;
change out elevators and utilize power tongs to MU FOX
(2390ft-Ibs MU torque). PU 25'oints of FOX and RIH with guns
to 1727'. 50k up, 50k down. sX; 't,~j~
OTHCMP Change out bales and elevators to handle DP. IH with
PowerJet Ome a erf uns 2-7/8" FOX tb and 4" DP from
1727' to 12,242'. 210k up, 140k down. Tag up on 4.5" liner
landin collar and PU uns to erf de t bottom a oration ~
12,020' as er SLB hand.
OTHCMP PT lines to 3000psi; good. Initiate pert gun pressure sequence
as per SLB perforating hand and fire pert guns. Guns fire C~3
22:00; ood indication at surface. 11 bbl initial fluid loss after
firin .
OTHCMP After initial loss, POH to get above top shot; pull from 12,020'
to 11,084'. Initial overpull of 40k. Rack back 10 stands of 4"DP
and monitor for additional fluid loss. 215k up. ~ JP ^+~~'ji
OTHCMP Circulate bottoms-up C~? 11,084'; some gunpowder in
Printed: 4/13/2009 2:52:06 PM
BP EXPLORATION Page 15 of 16
Operations Summary Report
Legal Well Name: 06-14
Common Well Name: 06-14 Spud Date: 6/5/1980
Event Name: REENTER+COMPLETE Start: 3/6/2009 End: 4/4/2009
Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/5/2009
Rig Name: NABOBS 9ES Rig Number: 9ES
Date From - To Hours Task Code NPT Phase Description of Operations
4/2/2009 22:30 - 23:30 1.00 PERFO P OTHCMP bottoms-up returns, no pert debris.
23:30 - 00:00 0.50 PERFO P OTHCMP POH from 11,084' to 10,702' laying down joints of 4". Losing
seawater to erforations around 20bb1/hr.
4/3/2009 00:00 - 08:30 8.50 PERFO P OTHCMP PJSM. POH with 4" DP, 2-7/8" FOX tbg and PowerJet Omega
pert guns from 10,702' to 7000', laying down joints of 4"DP.
RIH with remaining stands from the derrick (14stands) and
come out sideways, LD remaining 4" DP to 1728'. Losses to
perforations -20bb1/hr.
08:30 - 10:00 1.50 PERFO P OTHCMP Change out bales and elevators to handle 2-7/8" FOX tubing.
POOH, laying down FOX from 1728' to 953'.
10:00 - 14:30 4.50 PERFO P OTHCMP PJSM with SLB perforating crew before bringing guns to
surface. LD perf guns from 953' to surface. All shots fired. RD
gun running tools; clear floor of third party handing equipment.
14:30 - 17:00 2.50 BUNCO RUNCMP MU tb han er and make dumm run with landin 'oint. RU to
run 4.5" 13Cr VamTop completion as per casing running hand.
Change out bales, RU stabbing board, compensator,
double-stack and torque-turn equipment.
17:00 - 00:00 7.00 BUNCO P RUNCMP Run 4.5" 13Cr VamTop completion from surface to 4393'.
Baker-lok all completion components below Baker S-3 packer.
Torque-turn tubing connections to 4440ft-Ibs (optimum torque)
and utilize compensator for picking up joints. 86k up, 84k down.
Losses to formation C~ 10bb1/hr.
4/4/2009 00:00 - 07:00 7.00 BUNCO P RUNCMP PJSM. Run 4.5" 13Cr VamTop tubing from 4393' to 4.5" liner
tieback at 10,585' MD. Utilize compensator to MU joints, and
torque-turn all tubing connections to 4440ft-Ibs. Losses to
formation ~ 10bb1/hr. LD 3 joints and space out completion
with pup joints. MU tubing hanger and land tubing. WLEG C~
10,580'. 165k up, 115k down.
07:00 - 08:00 1.00 BUNCO P RUNCMP RILDS as per FMC hand. Torque LDS to 450ft-Ibs. RD casing
running equipment; clean and clear rig floor.
08:00 - 10:00 2.00 BUNCO P RUNCMP Reverse circulate to spot corrosion inhibited seawater; pump
165bb1s clean seawater, 87bbls corr. inhibited seawater and
110 clean seawater. Pump 350psi ~ 3bpm.
10:00 - 12:00 2.00 BUNCO P RUNCMP Dro 1.875" ball and rod with rollers. Allow b&r to seat.
Pressure uo to 3500osi aaainst b&r to set Baker S-3 production
on annulus to
Tubing Test:
Omin: 3520psi
15min: 3424psi
30min: 3400psi
Annulus Test
Omin: 3550psi
15min: 3520psi
30psi: 3520psi
12:00 - 13:30 1.50 BUNCO P RUNCMP After pressure testing, bleed off tubing pressure to shear DCK
valve; good indication of shear. Pump 2bbls seawater
(820psiC~32bpm) down the annulus, then pump 2bbls seawater
(660psi ~ 2bpm) down tubing to confirm circulation ability. Set
TWC as per FMC hand; test TWC from above and below to
Printed: 4/13/2009 2:52:06 PM
•
~ BP EXPLORATION Page 16 of 16
Operations Summary Report
Legal Well Name: 06-14
Common Well Name: 06-14 Spud Date: 6/5/1980
Event Name: REENTER+COMPLETE Start: 3/6/2009 End: 4/4/2009
Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/5/2009
,Rig Name: NABOBS 9ES Rig Number: 9ES
Date From - To Hours Task Code NPT Phase Description of Operations
4/4/2009 12:00 - 13:30 1.50 BUNCO P RUNCMP 1000 si; ood test.
13:30 - 16:30 3.00 BOPSU P RUNCMP Blow down surface equipment and ND BOPs. Remove mouse
hole and riser; utilize sweeney wrench to break stack from
spool. Rack back stack.
16:30 - 20:00 3.50 WHSUR P RUNCMP NU adapter flange and FMC 4-1/16" tree. Test adapter flange
to 5000psi for 30min; okay. Test tree to 5000psi for 10min;
okay. RU lubricator and pull TWC.
20:00 - 00:00 4.00 WHSUR P RUNCMP RU LRHOS. Freeze protect well to -2200TVD by reverse
circulating 75bbls diesel down the annulus. Allow diesel to
U-tube through the tree to freeze protect tubing. PJSM. Finish
U-tubing diesel from annulus to tubing. RU DSM lubricator and
install BPV. Test BPV from below to 1000psi; good test.
Secure well and RD. RU bridle lines and ernc , ow own
pits. Clean out cellar and remove liner. Rig release from
DS06-14B Q OO:OOhrs, 4/5/09.
Printed: 4/13/2009 2:52:06 PM
rg
DS06-14B Survey Report
Report Date: 29-Mar-09 Survey /DLS Computation Method: Minimum Curvature / Lubinski
Client: BP Exploration Alaska Vertical Section Azimuth: 241.920°
Field: Prudhoe Bay Unit - EOA Vertical Section Origin: N 0.000 ft, E 0.000 ft
Structure /Slot: DS-06106-14 TVD Reference Datum: Rotary Table '
Well: 06-14 TVD Reference Elevation: 64.56 ft relative to MSL
Borehole: 06.146 Sea Bed /Ground Level Elevation: 37.00 ft relative to MSL
UWVAPIq: 500292045802 Magnetic Declination: 22.847°
Survey Name /Date: 06-14B /March 29, 2009 Total Field Strength: 57705.340 nT
Tort /AHD / DDI / ERD ratio: 324.697° / 6117.64 fl / 6.436 / 0.681 Magnetic Dip: 80.898°
Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: March 25, 2009
Location Lat/Long: N 7014 35.941, W 148 3012.900 Magnetic Declination Model: BGGM 2008
Location Grid N/E Y/X: N 5940818.230 ftUS, E 685262.560 ftUS North Reference: True North
Grid Convergence Angle: +1.40836923° Total Corr Mag North -> True North: +22.847°
Grid Scale Factor: 0.99993899 Local Coordinates Referenced To: Well Head
•I
Measured Azimuth Vertical Along Hole NS EW
Comments Inclination Sub-Sea TVD TVD Closure DLS Northing Easting Latitude Longitude
Depth True Section Departure True North True North
tt de de tt ft tt tt n tt n de o0 ft ttUS ftUS
rrolectea-up uw u.v~ U.UV -b4.bb U.VU V.VV V.VV U.VU U.UU U.UU U.UU 5y4U818.23 68526'1.56 N701435.941 W 1483012.900
WRP 27.56 0.00 0.00 -37.00 27.56 0.00 0.00 0.00 0.00 0.00 0.00 5940818.23 685262.56 N 70 14 35.941 W 148 30 12.900
SCI DRILNG 6/25/80
86.56 0.00 0.00 32.00 96.56 0.00 0.00 0.00 0.00 0.00 0.00 5940818.23 685262.56 N 70 14 35.941 W 148 30 12.900
#4440 GYRO
(CB GYRO MS) 196.56 0:00 0.00 132.00 196.56 0.00 0.00 0.00 0.00 0.00 0.00 5940818.23 685262.56 N 70 14 35.941 W 148 30 12.900
296.56 0.00 0.00 232.00 296.56 0.00 0.00 0.00 0.00 0.00 0.00 5940818.23 685262.56 N 70 14 35.941 W 148 30 12.900
396.56 0.00 0.00 332.00 396.56 0.00 0.00 0.00 0.00 0.00 0.00 5940818.23 685262.56 N 70 14 35.941 W 148 30 12.900
496.56 0.00 0.00 432.00 496.56 0.00 0.00 0.00 0.00 0.00 0.00 5940818.23 685262.56 N 70 14 35.941 W 148 30 12.900
596.56 0.00 0.00 532.00 596.56 0.00 0.00 0.00 0.00 0.00 0.00 5940818.23 685262.56 N 70 14 35.941 W 148 30 12.900
696.56 0.00 0.00 632.00 696.56 0.00 0.00 0.00 0.00 0.00 0.00 5940818.23 685262.56 N 70 14 35.941 W 148 30 12.900
796.56 0.00 0.00 732.00 796.56 0.00 0.00 0.00 0.00 0.00 0.00 5940818.23 685262.56 N 70 14 35.941 W 148 30 12.900
896.56 0.00 0.00 832.00 896.56 0.00 0.00 0.00 0.00 0.00 0.00 5940818.23 685262.56 N 70 14 35.941 W 148 30 12.~
996.56 0.00 0.00 932.00 996.56 0.00 0.00 0.00 0.00 0.00 0.00 5940818.23 685262.56 N 70 14 35.941 W 148 30 12.
1096.56 0.00 0.00 1032.00 1096.56 0.00 0.00 0.00 0.00 0.00 0.00 5940818.23 685262.56 N 70 14 35.941 W 148 30 12.900
1196.56 0.00 0.00 1132.00 1196.56 0.00 0.00 0.00 0.00 0.00 0.00 5940818.23 685262.56 N 70 14 35.941 W 148 30 12.900
1296.56 0.00 0.00 1232.00 1296.56 0.00 0.00 0.00 0.00 0.00 0.00 5940818.23 685262.56 N 70 14 35.941 W 148 30 12.900
1396.56 0.00 0.00 1332.00 1396.56 0.00 0.00 0.00 0.00 0.00 0.00 5940818.23 685262.56 N 70 14 35.941 W 148 30 12.900
1496.56 0.00 0.00 1432.00 1496.56 0.00 0.00 0.00 0.00 0.00 0.00 5940818.23 685262.56 N 70 14 35.941 W 148 30 12.900
1596.56 0.00 0.00 1532.00 1596.56 0.00 0.00 0.00 0.00 0.00 0.00 5940818.23 685262.56 N 70 14 35.941 W 148 30 12.900
1696.56 0.00 0.00 1632.00 1696.56 0.00 0.00 0.00 0.00 0.00 0.00 5940818.23 685262.56 N 70 14 35.941 W 148 30 12.900
1796.56 0.00 0.00 1732.00 1796.56 0.00 0.00 0.00 0.00 0.00 0.00 5940818.23 685262.56 N 70 14 35.941 W 148 30 12.900
1896.56 0.00 0.00 1832.00 1896.56 0.00 0.00 0.00 0.00 0.00 0.00 5940818.23 685262.56 N 70 14 35.941 W 148 30 12.900
1996.56 0.00 0.00 1932.00 1996.56 0.00 0.00 0.00 0.00 0.00 0.00 5940818.23 685262.56 N 70 14 35.941 W 148 30 12.900
2096.56 0.00 0.00 2032.00 2096.56 0.00 0.00 0.00 0.00 0.00 0.00 5940818.23 685262.56 N 70 14 35.941 W 148 30 12.900
2196.56 0.00 0.00 2132.00 2196.56 0.00 0.00 0.00 0.00 0.00 0.00 5940818.23 685262.56 N 70 14 35.941 W 148 30 12.900
2296.56 0.00 0.00 2232.00 2296.56 0.00 0.00 0.00 0.00 0.00 0.00 5940818.23 685262.56 N 70 14 35.941 W 148 30 12.900
SurveyEditor Ver SP 2.1 Bld( users) 06-14\06-14\06-146\06-14B Generated 4/16/2009 3:50 PM Page 1 of 5
Comments Measured
Inclination Azimuth
Subsea TVD
TVD Vertical Along Hole
Closure NS EW
DLS
Northing
Easting
Latitude
Longitude
Depth True Section Departure True North True North
ft de de ft tt ft ft tt ft tt de 100 tt ttUS ttUS
LJ~JU. Sb V.VU V.UU GJJL.VV GJ.YO. JO V.VV V.VV V.VV V.VV V.W V.VV J.7YV0IO. GJ VOJGVG. JV IV /V 1Y JJ. J'il YY IYO JV IL. JVV
2496. 56 0.00 0.00 2432.00 2496. 56 0.00 0.00 0.00 0.00 0.00 0.00 5940818. 23 685262. 56 N 70 14 35. 941 W 148 30 12. 900
2596. 56 0.00 0.00 2532.00 2596. 56 0.00 0.00 0.00 0.00 0.00 0.00 5940818. 23 685262. 56 N 70 14 35. 941 W 148 30 12. 900
2696. 56 0.00 0.00 2632.00 2696. 56 0.00 0.00 0.00 0.00 0.00 0.00 5940818. 23 685262. 56 N 70 14 35. 941 W 148 30 12. 900
2796. 56 0.00 0.00 2732.00 2796. 56 0.00 0.00 0.00 0.00 0.00 0.00 5940818. 23 685262. 56 N 70 14 35. 941 W 148 30 12. 900
2896. 56 0.00 0.00 2832.00 2896. 56 0.00 0.00 0.00 0.00 0.00 0.00 5940818. 23 685262. 56 N 70 14 35. 941 W 148 30 12. 900
2996. 56 0.00 0.00 2932.00 2996. 56 0.00 0.00 0.00 0.00 0.00 0.00 5940818. 23 685262. 56 N 70 14 35. 941 W 148 30 12. 900
3096. 56 0.00 0.00 3032.00 3096. 56 0.00 0.00 0.00 0.00 0.00 0.00 5940818. 23 685262. 56 N 70 14 35. 941 W 148 30 12. 900
3196. 56 0.00 0.00 3132.00 3196. 56 0.00 0.00 0.00 0.00 0.00 0.00 5940818. 23 685262 .56 N 70 14 35. 941 W 148 30 12. 900
3296. 56 0.00 0.00 3232.00 3296. 56 0.00 0.00 0.00 0.00 0.00 0.00 5940818. 23 685262 .56 N 70 14 35. 941 W 148 30 12. 900 I
3396 .56 0.00 0.00 3332.00 3396. 56 0.00 0.00 0.00 0.00 0.00 0.00 5940818. 23 685262 .56 N 70 14 35. 941 W 148 30 12.
3496
.56
0.00
0.00
3432.00
3496.
56
0.00
0.00
0.00
0.00
0.00
0.00
5940818.
23
685262
.56
N 70 14
35.
941 W 148
30 12. ~
3596 .56 0.50 253.00 3532.00 3596. 56 0.43 0.44 0.44 -0.13 -0.42 0.50 5940818. 09 685262 .15 N 70 14 35. 940 W 148 30 12. 9
3696 .56 0.00 0.00 3632.00 3696. 56 0.86 0.87 0.87 -0.26 -0.83 0.50 5940817. 95 685261 .73 N 70 14 35. 938 W 148 30 12. 924
3796 .56 0.00 0.00 3732.00 3796. 56 0.86 0.87 0.87 -0.26 -0.83 0.00 5940817. 95 685261 .73 N 70 14 35. 938 W 148 30 12. 924
3896 .56 0.50 106.00 3832.00 3896. 56 0.54 1.31 0.56 -0.38 -0.42 0.50 5940817. 84 685262 .15 N 70 14 35. 937 W 148 30 12. 912
3996 .56 3.50 248.00 3931.94 3996. 50 3.27 4.16 3.27 -1.64 -2.83 3.91 5940816. 52 685259 .77 N 70 14 35. 925 W 148 30 12. 982
4096 .56 7.50 231.00 4031.46 4096. 02 12.71 13.68 12.76 -6.89 -10.73 4.28 5940811. 08 685252 .00 N 70 14 35. 873 W 148 30 13. 212
4196 .56 11.00 235.00 4130.15 4194. 71 28.60 29.74 28.80 -16.48 -23.62 3.56 5940801. 18 685239 .35 N 70 14 35. 779 W 148 30 13. 586
4296 .56 15.00 241.00 4227.57 4292. 13 51.02 52.22 51.24 -28.23 -42.77 4.22 5940788. 96 685220 .50 N 70 14 35. 663 W 148 30 14. 143
4396 .56 19.00 237.00 4323.19 4387. 75 80.19 81.44 80.44 -43.37 -67.75 4.17 5940773. 21 685195 .90 N 70 14 35. 514 W 148 30 14. 869
4496 .56 24.00 233.00 4416.20 4480. 76 116.52 118.06 117.03 -64.49 -97.66 5.21 5940751. 36 685166 .52 N 70 14 35. 307 W 148 30 15. 739
4596 .56 25.50 228.00 4507.03 4571. 59 157.51 159.90 158.69 -91.14 -129.91 2.57 5940723. 93 685134 .94 N 70 14 35. 045 W 148 30 16. 676
4696 .56 30.50 231.00 4595.30 4659. 86 203.36 206.83 205.45 -121.53 -165.65 5.19 5940692. 67 685099 .96 N 70 14 34. 746 W 148 30 17. 715
4796 .56 34.50 235.00 4679.63 4744. 19 256.42 260.53 259.14 -153.76 -208.59 4.54 5940659. 40 685057 .82 N 70 14 34. 429 W 148 30 18. 964
Tie-In Survey 4896. 56 35. 00 235.00 4761.79 4826.35 313. 00 317. 53 316.13 -186. 46 -255.28 0.50 5940625. 57 685011.95 N 70 14 34.107 W 148 30 20. 321
CB GYRO MS 4996. 56 35. 00 234.00 4843.71 4908.27 369. 88 374. 89 373.48 -219 .76 -301.98 0.57 5940591. 12 684966.09 N 70 14 33. 779 W 148 30 21. 679
(Run down old hole, 5096. 56 35. 00 234.00 4925.62 4990.18 426. 69 432. 25 430.84 -253 .48 -348.38 0.00 5940556. 28 684920.54 N 70 14 33. 448 W 148 30 23. 0
outside of casing) 5196. 56 35. 00 235.00 5007.54 5072.10 483. 56 489. 60 488.19 -286 .79 -395.07 0.57 5940521. 84 684874.68 N 70 14 33. 120 W 148 30 24.
5296. 56 35. 00 233.00 5089.46 5154.02 540. 37 546. 96 545.54 -320 .50 -441.47 1.15 5940487. 00 684829.13 N 70 14 32. 789 W 148 30 25.
5396. 56 34. 50 234.00 5171.62 5236.18 596. 75 603. 96 602.54 -354 .40 -487.29 0.76 5940451 .98 684784.16 N 70 14 32 .455 W 148 30 27. 066
5496. 56 35. 00 235.00 5253.79 5318.35 653. 27 660. 95 659.53 -387 .50 -533.69 0.76 5940417 .76 684738.59 N 70 14 32 .130 W 148 30 28. 415
5596. 56 35. 00 234.00 5335.70 5400.26 710. 15 718. 31 716.89 -420 .80 -580.39 0.57 5940383 .31 684692.73 N 70 14 31 .802 W 148 30 29. 772
(- 5700'md KOP away 5696. 56 34. 25 234.00 5417.99 5482.55 766. 42 775. 13 773.71 -454 .20 -626.36 0.75 5940348 .80 684647.60 N 70 14 31 .474 W 148 30 31. 108
from old hole)
Inc+Trend 5736. 63 35. 92 234.00 5450.78 5515.34 789. 23 798. 16 796.74 -467 .74 -644.99 4.17 5940334 .81 684629.30 N 70 14 31 .340 W 148 30 31. 650
5768. 14 37 .16 234.00 5476.10 5540.66 807. 82 816. 92 815.50 -478 .77 -660.17 3.94 5940323 .41 684614.40 N 70 14 31 .232 W 148 30 32 .091
5799. 19 38 .33 229.56 5500.65 5565.21 826. 51 835. 92 834.48 -490 .53 -675.08 9.53 5940311 .29 684599.78 N 70 14 31 .116 W 148 30 32 .525
5831. 68 39 .85 225.09 5525.87 5590.43 846. 32 856. 40 854.82 -504 .41 -690.13 9.85 5940297 .04 684585.08 N 70 14 30 .980 W 148 30 32 .962
5863. 37 40 .50 220.91 5550.09 5614.65 865. 65 876 .84 874.89 -519 .36 -704.06 8.75 5940281 .75 684571.52 N 70 14 30 .833 W 148 30 33 .367
5895 .15 41 .55 216.91 5574.07 5638.63 884. 84 897 .70 895.08 -535 .59 -717.15 8.90 5940265 .21 684558.83 N 70 14 30 .673 W 148 30 33 .748
MW D+IFR+MS 5926 .94 42 .28 213.44 5597.73 5662.29 903. 80 918 .93 915.28 -552 .95 -729.38 7.64 5940247 .56 684547.04 N 70 14 30 .502 W 148 30 34 .103
5957 .91 42 .34 213.10 5620.63 5685.19 922. 09 939 .78 934.95 -570 .38 -740.81 0.76 5940229 .85 684536.04 N 70 14 30 .331 W 148 30 34 .435
SurveyEditor Ver SP 2.1 Bld( users) 06-14\06-14\06-146\06-148 Generated 4/16/2009 3:50 PM Page 2 of 5
Comments Measured
Inclination Azimuth
Sub-Sea TVD
TVD Vertical Along Hole
Closure NS EW
DLS
Northing
Easting
Latitude
Longitude
Depth True Section Departure True North True North
tt de de ft ft ft tt ft ft ft de 100 tt ttUS ftUS
b`J8y.48 41. 252 YIV. Z`J bb44, V/ 8/V8. b3 ~4V.3/ 7OV.y3 yJ4.// -J88.3/ -/JI.y3 O.ly Jy4UG11.8~ 8840LA3/ IV /V 143V. IJ4 VV 148 JV J4./by
6019.34 41. 94 206. 85 5666. 30 5730. 86 957.02 980.86 973.09 -605.88 -761.46 7.70 5940193. 86 684516.27 N 70 14 29. 982 W 148 30 35.036
6052.54 42. 39 205. 01 5690. 91 5755. 47 975.05 1003.15 993.24 -625.92 -771.20 3.96 5940173. 59 684507.02 N 70 14 29. 785 W 148 30 35.319
6109.38 42. 28 204. 30 5732. 93 5797. 49 1005.51 1041.42 1027.70 -660.71 -787.17 0.86 5940138. 42 684491.92 N 70 14 29. 442 W 148 30 35.783
6143.99 41. 80 200. 77 5758. 64 5823. 20 1023.42 1064.60 1048.32 -682.11 -796.05 6.97 5940116. 81 684483.56 N 70 14 29. 232 W 148 30 36.041
6174.60 41. 19 199. 14 5781. 56 5846. 12 1038.50 1084.88 1066.02 -701.17 -802.97 4.05 5940097. 59 684477.11 N 70 14 29. 045 W 148 30 36.242
6203.19 40. 92 197. 30 5803. 12 5867. 68 1052.07 1103.65 1082.22 -719.00 -808.85 4.33 5940079. 61 684471.68 N 70 14 28. 869 W 148 30 36.413
6234.41 40. 95 196. 30 5826. 71 5891. 27 1066.51 1124.11 1099.70 -738.58 -814.76 2.10 5940059. 89 684466.25 N 70 14 28. 677 W 148 30 36.585
6266.12 42. 22 194. 44 5850. 43 5914. 99 1080.98 1145.15 1117.51 -758.88 -820.33 5.59 5940039. 47 684461.18 N 70 14 28. 477 W 148 30 36.747
6298.08 42. 43 193. 96 5874. 06 5938. 62 1095.45 1166.67 1135.62 -779.74 -825.61 1.21 5940018. 49 684456.41 N 70 14 28. 272 W 148 30 36.900
6328.65 42. 92 190. 60 5896. 54 5961. 10 1108.87 1187.39 1152.77 -799.98 -830.01 7.62 5939998. 14 684452.51 N 70 14 28. 073 W 148 30 37.028
6360.14 42. 90 188. 75 5919. 60 5984. 16 1121.99 1208.83 1170.10 -821.11 -833.62 4.00 5939976. 93 684449.43 N 70 14 27. 865 W 148 30 37.
6391.75
43.
43
187.
94
5942.
66
6007.
22
1134.83
1230.46
1187.42
-842.51
-836.75
2.43
5939955.
47
684446.82
N 70 14 27.
654 W 148 ~
30 37.
6422.59 43. 74 185. 48 5965. 00 6029. 56 1146.96 1251.72 1204.22 -863.62 -839.24 5.59 5939934. 30 684444.85 N 70 14 27. 447 W 148 30 37.296
6453.42 44. 33 184. 35 5987. 16 6051. 72 1158.63 1273.15 1220.89 -884.97 -841.07 3.19 5939912. 91 684443.55 N 70 14 27. 237 W 148 30 37.349
6485.11 44. 21 183. 08 6009. 85 6074. 41 1170.28 1295.27 1237.96 -907.04 -842.50 2.82 5939890. 81 684442.65 N 70 14 27. 020 W 148 30 37.391
6517.44 44. 73 181. 54 6032. 93 6097. 49 1181.74 1317.91 1255.25 -929.67 -843.42 3.70 5939868. 17 684442.30 N 70 14 26. 797 W 148 30 37.417
6549.22 44. 66 180. 43 6055. 52 6120. 08 1192.60 1340.26 1272.14 -952.02 -843.80 2.47 5939845. 82 684442.47 N 70 14 26. 577 W 148 30 37.428
6580.14 45. 76 179. 60 6077. 30 6141. 86 1202.93 1362.21 1288.65 -973.96 -843.80 4.04 5939823. 88 684443.00 N 70 14 26. 361 W 148 30 37.428
6611.38 45. 67 178. 71 6099. 11 6163. 67 1213.16 1384.57 1305.42 -996.32 -843.48 2.06 5939801. 54 684443.88 N 70 14 26. 142 W 148 30 37.419
6642.51 46. 40 177. 68 6120. 73 6185. 29 1223.08 1406.98 1322.14 -1018.72 -842.77 3.34 5939779. 17 684445.14 N 70 14 25. 921 W 148 30 37.398
6673.60 47. 59 175. 95 6141. 93 6206. 49 1232.65 1429.71 1338.91 -1041.42 -841.50 5.59 5939756. 51 684446.96 N 70 14 25. 698 W 148 30 37.361
6704.88 47. 79 175. 18 6162. 99 6227. 55 1241.93 1452.84 1355.82 -1064.48 -839.71 1.93 5939733. 50 684449.32 N 70 14 25. 471 W 148 30 37.309
6735.72 49. 05 174. 35 6183. 45 6248 .01 1250.88 1475.91 1372.64 -1087.45 -837.61 4.55 5939710. 59 684451.99 N 70 14 25. 245 W 148 30 37.248
6767.67 50. 64 173. 16 6204. 06 6268 .62 1259.96 1500.33 1390.35 -1111.72 -834.95 5.73 5939686. 39 684455.24 N 70 14 25. 007 W 148 30 37.170
6798.31 50. 94 173. 03 6223. 43 6287 .99 1268.54 1524.07 1407.58 -1135.29 -832.09 1.03 5939662. 90 684458.67 N 70 14 24. 775 W 148 30 37.087
6830.22 52. 56 172. 22 6243. 18 6307 .74 1277.39 1549.13 1425.82 -1160.14 -828.87 5.45 5939638. 14 684462.50 N 70 14 24. 530 W 148 30 36.994
6860.66 53. 89 171. 28 6261. 41 6325 .97 1285.66 1573.51 1443.52 -1184.27 -825.37 5.02 5939614. 10 684466.59 N 70 14 24. 293 W 148 30 36.892
6892.90 53. 93 171. 31 6280 .40 6344 .96 1294.31 1599.56 1462.50 -1210.03 -821.43 0.15 5939588 .46 684471.17 N 70 14 24. 040 W 148 30 36.
6925.01 55. 75 169 .67 6298 .89 6363 .45 1302.66 1625.81 1481.59 -1235.91 -817.09 7.04 5939562 .69 684476.14 N 70 14 23. 785 W 148 30 36.~
6956.75 57. 66 168 .54 6316 .31 6380 .87 1310.50 1652.34 1500.67 -1261.96 -812.07 6.71 5939536 .77 684481.80 N 70 14 23. 529 W 148 30 36.505
7051.68 58. 57 166 .42 6366 .46 6431 .02 1332.11 1732.95 1558.43 -1340.64 -794.59 2.12 5939458 .55 684501.20 N 70 14 22 .755 W 148 30 35.997
7144.44 57. 80 165 .57 6415 .36 6479 .92 1351.28 1811.77 1615.45 -1417.12 -775.52 1.14 5939382 .57 684522.15 N 70 14 22. 003 W 148 30 35.442
7239.75 59. 01 165 .16 6465 .29 6529 .85 1370.15 1892.95 1675.43 -1495.67 -755.01 1.32 5939304 .55 684544.59 N 70 14 21 .231 W 148 30 34.845
7334.25 58. 23 164 .31 6514 .50 6579 .06 1388.05 1973.63 1736.18 -1573.50 -733.77 1.13 5939227 .27 684567.73 N 70 14 20 .465 W 148 30 34.228
7427.99 57. 37 164 .82 6564 .45. 6629 .01 1405.41 2052.95 1797.29 -1649.96 -712.66 1.03 5939151 .36 684590.71 N 70 14 19 .713 W 148 30 33.614
7522.91 59 .05 164 .72 6614 .45 6679 .01 1423.35 2133.62 1861.03 -1727.80 -691.46 1.77 5939074 .07 684613.81 N 70 14 18 .948 W 148 30 32.998
7617.42 58 .25 163 .94 6663 .62 6728 .18 1440.70 2214.34 1925.70 -1805.51 -669.67 1.10 5938996 .92 684637.51 N 70 14 18 .183 W 148 30 32.364
7712.84 58 .48 165 .88 6713 .68 6778 .24 1458.96 2295.57 1992.44 -1883.95 -648.52 1.75 5938919 .03 684660.58 N 70 14 17 .412 W 148 30 31.749
7807.55 58 .53 168 .98 6763 .16 6827 .72 1480.56 2376.33 2061.67 -1962.75 -630.95 2.79 5938840 .69 684680.08 N 70 14 16 .637 W 148 30 31.238
7902.24 57 .96 168 .43 6813 .00 6877 .56 1503.81 2456.84 2132.38 -2041.71 -615.18 0.78 5938762 .15 684697.78 N 70 14 15 .860 W 148 30 30.780
7995.83 57 .04 171 .41 6863 .29 6927 .85 1528.18 2535.77 2203.07 -2119.41 -601.36 2.86 5938684 .82 684713.51 N 70 14 15 .096 W 148 30 30.378
8090.95 55 .64 175 .67 6916 .03 6980 .59 1557.32 2614.93 2276.48 -2198.04 -592.43 4.01 5938606 .43 684724.37 N 70 14 14 .323 W 148 30 30.118
SurveyEditor Ver SP 2.1 Bld( users) 06-14\06-14\06-146\06-146 Generated 4/16/2009 3:50 PM Page 3 of 5
Comments Measured
Inclination Azimuth
SulrSea TVD
TVD Vertical Along Hole
Closure NS EW
DLS
Northing
Easting
Latitude
Longitude
Depth True Section Departure True North True North
tt de de tt ft ft tt tt tt ft de 00 ft ftUS ftUS
tS1ti4.51 bb.:i:S
8277.58 54.29
8372.94 51.67
8467.01 48.84
8561.96 47.16
8655.60 44.83
8749.17 44.45
8843.51 45.17
8938.79 46.07
9033.21 46.06
9128.08 45.86
9221.96 44.78
9314.53 45.59
9409.06 47.98
9502.29 48.49
9597.76 50.93
9690.78 52.43
9784.75 53.73
9878.89 54.32
9973.25 53.18
10067.09 52.62
10161.45 51.50
10255.03 52.86
10348.91 51.89
10444.10. 50.57
10538.28 49.31
10570.27 48.68
10652.32 47.33
7" C~ 10725'md 10799.03 46.82
10830.56 46.25
10846.21 45.62
10862.75 47.46
10894.67 50.89
10926.68 53.59
10958.73 56.53
10990.09 58.22
11022.26 60.96
11055.01 61.13
11086.11 65.39
11118.14 70.79
11149.39 69.23
11181.42 64.58
11213.90 69.04
11245.74 71.98
1 /25.1L ti`.ib`J.UJ /U.i.S.bl lbi5y.t5/ Cb`JL.UL L:54`J.i5:5 -LL/J.VI -JtSrS.LJ
180.05 7022.69 7087.25 1624.58 2768.07 2423.23 -2351.06 -587.03
181.71 7080.10 7144.66 1661.42 2844.20 2497.42 -2427.17 -588.18
184.07 7140.24 7204.80 1698.61 2916.52 2568.50 -2499.40 -591.79
187.83 7203.79 7268.35 1738.06 2987.07 2638.47 -2569.56 -599.07
193.35 7268.86 7333.42 1780.06 3054.39 2705.70 -2635.72 -611.38
198.06 7335.46 7400.02 1825.52 3120.12 2771.34 -2698.98 -629.16
205.15 7402.43 7466.99 1876.17 3186.56 2837.03 -2760.70 -653.63
211.17 7469.10 7533.66 1932.75 3254.63 2902.84 -2820.67 -685.76
216.99 7534.64 7599.20 1992.82 3322.60 2966.60 -2876.94 -723.83
222.92 7600.62 7665.18 2056.01 3390.77 3028.08 -2929.18 -767.58
228.09 7666.66 7731.22 2119.99 3457.50 3085.57 -2975.95 -815.15
234.43 7731.93 7796.49 2184.46 3523.13 3138.90 -3016.98 -866.33
241.46 7796.70 7861.26 2253.11 3591.98 3190.37 -3053.43 -924.69
248.66 7858.85 7923.41 2322.45 3661.47 3237.05 -3082.70 -987.67
253.11 7920.59 7985.15 2394.34 3734.28 3281.21 -3106.48 -1056.46
256.31 7978.28 8042.84 2465.48 3807.25 3322.62 -3125.70 -1126.84
255.90 8034.73 8099.29 2538.32 3882.37 3364.91 -3143.75 -1199.77
256.30 8090.03 8154.59 2612.18 3958.55 3408.95 -3162.05 -1273.72
253.75 8145.83 8210.39 2686.28 4034.65 3455.17 -3181.70 -1347.23
250.31 8202.44 8267.00 2759.94 4109.48 3504.63 -3204.77 -1418.40
250.12 8260.46 8325.02 2833.58 4183.90 3556.41 -3229.96 -1488.43
250.31 8317.84 8382.40 2906.73 4257.82 3608.63 -3254.98 -1557.99
250.59 8375.15 8439.71 2980.26 4332.17 3661.70 -3279.86 -1628.05
250.50 8434.76 8499.32 3053.64 4406.39 3715.31 -3304.58 -1698.03
250.81 8495.37 8559.93 3124.88 4478.47 3767.96 -3328.46 -1766.04
250.71 8516.36 8580.92 3148.74 4502.61 3785.71 -3336.42 -1788.83
250.82 8571.25 8635.81 3208.99 4563.59 3830.84 -3356.50 -1846.41
251.72 8671.17 8735.73 3314.99 4671.02 3910.78 -3391.00 -1948.14
252.44 8692.86 8757.42 3337.51 4693.90 3927.76 -3398.05 -1969.92
252.76 8703.74 8768.30 3348.56 4705.15 3936.06 -3401.41 -1980.65
251.25 8715.12 8779.68 3360.38 4717.15 3945.02 -3405.12 -1992.06
250.31 8735.99 8800.55 3384.25 4741.30 3963.43 -3413.07 -2014.87
247.54 8755.59 8820.15 3409.36 4766.60 3983.30 -3422.18 -2038.47
246.95 8773.94 8838.50 3435.52 4792.87 4004.46 -3432.35 -2062.69
244.84 8790.85 8855.41 3461.86 4819.28 4026.15 -3443.13 -2086.80
247.77 8807.14 8871.70 3489.52 4847.02 4048.87 -3454.27 -2112.20
246.50 8822.99 8887.55 3518.05 4875.68 4072.18 -3465.41 -2138.60
250.90 8836.99 8901.55 3545.61 4903.44 4094.37 -3475.47 -2164.47
252.93 8848.94 8913.50 3574.87 4933.15 4117.16 -3484.68 -2192.71
255.13 8859.62 8924.18 3603.58 4962.51 4139.08 -3492.76 -2220.94
258.34 8872.18 8936.74 3632.05 4991.97 4160.22 -3499.54 -2249.60
260.58 8884.97 8949.53 3660.51 5021.82 4180.73 -3504.99 -2278.95
262.50 8895.59 8960.15 3688.77 5051.83 4200.67 -3509.40 -2308.63
Z.Irf byStlJZyAJ bt54/3V.44 IV /V 14 13.bOb VV 1403U L~.~~/
2.03 5938453.60 684733.53 N 70 14 12.818 W 148 30 29.961
3.08 5938377.49 684734.25 N 70 14 12.069 W 148 30 29.994
3.57 5938305.20 684732.41 N 70 14 11.359 W 148 30 30.099
3.43 5938234.89 684726.86 N 70 14 10.669 W 148 30 30.310
4.91 5938168.45 684716.18 N 70 14 10.018 W 148 30 30.668
3.56 5938104.77 684699.96 N 70 14 9.396 W 148 30 31.184
5.35 5938042.47 684677.02 N 70 14 8.789 W 148 30 31.895
4.61 5937981.73 684646.37 N 70 14 8.199 W 148 30 32.829
4.44 5937924.55 684609.70 N 70 14 7.646 W 148 30 33.935
4.50 5937871.26 684567.25 N 70 14 7.132 W 148 30 35.207
4.08 5937823.33 684520.85 N 70 14 6.672 W 148 30 36.~
4.94 5937781.06 684470.69 N 70 14 6.268 W 148 30 38.
5.98 5937743.19 684413.25 N 70 14 5.910 W 148 30 39.772
5.78 5937712.38 684351.01 N 70 14 5.622 W 148 30 41.602
4.38 5937686.92 684282.83 N 70 14 5.388 W 148 30 43.601
3.14 5937665.97 684212.95 N 70 14 5.199 W 148 30 45.646
1.43 5937646.15 684140.49 N 70 14 5.021 W 148 30 47.766
0.71 5937626.03 684067.02 N 70 14 4.841 W 148 30 49.915
2.49 5937604.59 683994.02 N 70 14 4.648 W 148 30 52.051
2.98 5937579.77 683923.44 N 70 14 4.421 W 148 30 54.119
1.20 5937552.87 683854.06 N 70 14 4.173 W 148 30 56.154
1.46 5937526.15 683785.14 N 70 14 3.927 W 148 30 58.175
1.06 5937499.55 683715.71 N 70 14 3.682 W 148 31 0.211
1.39 5937473.12 683646.37 N 70 14 3.438 W 148 31 2.244
1.36 5937447.58 683578.97 N 70 14 3.203 W 148 31 4.221
1.98 5937439.07 683556.38 N 70 14 3.125 W 148 31 4.883
1.65 5937417.57 683499.32 N 70 14 2.927 W 148 31 6.556 ~
0.57 5937380.59 683398.47 N 70 14 2.588 W 148 31 9.512
2.45 5937373.01 683376.88 N 70 14 2.519 W 148 31 10~
4.29 5937369.39 683366.23 N 70 14 2.485 W 148 31 10.456
12.95 5937365.40 683354.91 N 70 14 2.449 W 148 31 10.788 i
10.97 5937356.88 683332.31 N 70 14 2.371 W 148 31 11.451
10.86 5937347.20 683308.94 N 70 14 2.281 W 148 31 12.137
9.30 5937336.44 683284.97 N 70 14 2.181 W 148 31 12.840
7.82 5937325.07 683261.14 N 70 14 2.075 W 148 31 13.541
11.59 5937313.31 683236.02 N 70 14 1.965 W 148 31 14.279
3.43 5937301.53 683209.90 N 70 14 1.856 W 148 31 15.046
18.63 5937290.83 683184.29 N 70 14 1.757 W 148 31 15.798
17.85 5937280.93 683156.29 N 70 14 1.666 W 148 31 16.618
8.29 5937272.16 683128.27 N 70 14 1.586 W 148 31 17.438
17.20 5937264.68 683099.78 N 70 14 1.520 W 148 31 18.271
15.12 5937258.51 683070.59 N 70 14 1.466 W 148 31 19.124
10.84 5937253.38 683041.02 N 70 14 1.422 W 148 31 19.987
SurveyEditor Ver SP 2.1 Bld( users) 06-14\06-14\06-14B\06-14B Generated 4/16/2009 3:50 PM Page 4 of 5
Comments Measured
Inclination Azimuth
SutrSea TVD
7VD Vertical Along Hole
Closure NS EW
DLS
Northing
Easting
Latitude
Longitude
Depth True Section Departure True North True North
tt de de tt tt ft tt ft ft tt de 100 ft ttUS ttUS
l1G//..StS /4.b/ G04.4U 6`JV4.b/ O~O~.GJ J/10..`70 bVOL.IJ 4LLV.1/ -Ja IG. 00 -LJJO./4 IV.GV J~J/GY~. 10 VOJVII.VI IV /V IY I. JVO VY IVO JI Gv.oVl
11309.74 79.08 264.70 8912.02 8976.58 3746.04 5113.64 4240.11 -3515. 84 -2370.10 13.66 5937245. 42 682979.73 N 70 14 1. 359 W 148 31 21.773
11341.24 82.59 265.38 8917.04 8981.60 3774.64 5144.73 4259.72 -3518. 53 -2401.08 11.34 5937241. 98 682948.83 N 70 14 1. 332 W 148 31 22.673
11372.97 86.65 267.36 8920.01 8984.57 3803.39 5176.32 4279.21 -3520. 53 -2432.60 14.22 5937239. 20 682917.37 N 70 14 1. 313 W 148 31 23.589
11404.64 90.54 269.13 8920.79 8985.35 3831.76 5207.97 4298.07 -3521. 50 -2464.24 13.49 5937237. 46 682885.77 N 70 14 1. 303 W 148 31 24.508
11436.83 97.27 267.73 8918.60 8983.16 3860.48 5240.07 4317.26 -3522. 37 -2496.32 21.35 5937235. 79 682853.72 N 70 14 1. 294 W 148 31 25.441
11468.27 103.95 266.82 8912.81 8977.37 3888.39 5270.95 4336.36 -3523. 84 -2527.17 21.44 5937233. 57 682822.92 N 70 14 1. 280 W 148 31 26.337
11500.19 105.65 267.69 8904.66 8969.22 3916.28 5301.81 4355.59 -3525. 32 -2558.00 5.94 5937231. 33 682792.14 N 70 14 1. 265 W 148 31 27.233
11532.08 104.54 265.74 8896.35 8960.91 3944.23 5332.60 4375.14 -3527. 08 -2588.73 6.85 5937228. 81 682761.46 N 70 14 1. 248 W 148 31 28.126
11563.77 103.13 263.26 8888.77 8953.33 3972.64 5363.37 4395.70 -3530. 03 -2619.36 8.81 5937225. 11 682730.91 N 70 14 1. 219 W 148 31 29.016
11595.59 104.15 262.97 8881.27 8945.83 4001.47 5394.29 4417.03 -3533. 74 -2650.06 3.33 5937220. 65 682700.32 N 70 14 1. 182 W 148 31 29.9
11627.62 101.05 264.24 8874.28 8938.84 4030.51 5425.55 4438.50 -3537. 22 -2681.12 10.42 5937216. 41 682669.35 N 70 14 1. 148 W 148 31 30.8
11659.46 97.61 262.94 8869.12 8933.68 4059.70 5456.96 4460.21 -3540. 73 -2712.33 11.53 5937212. 13 682638.24 N 70 14 1. 113 W 148 31 31.717
11691.80 98.79 262.96 8864.51 8929.07 4089.58 5488.97 4482.71 -3544. 66 -2744.10 3.65 5937207. 43 682606.58 N 70 14 1. 074 W 148 31 32.641
11723.40 99.38 262.42 8859.52 8924.08 4118.76 5520.18 4504.85 -3548. 63 -2775.05 2.52 5937202. 70 682575.74 N 70 14 1. 035 W 148 31 33.540
11754.79 99.83 263.00 8854.28 8918.84 4147.69 5551.13 4526.91 -3552. 55 -2805.75 2.32 5937198. 02 682545.14 N 70 14 0. 996 W 148 31 34.432
11850.76 101.37 264.42 8836.63 8901.19 4235.28 5645.45 4593.62 -3562. 89 -2899.51 2.17 5937185. 38 682451.67 N 70 14 0. 894 W 148 31 37.156
11882.09 102.01 264.29 8830.28 8894.84 4263.64 5676.13 4615.28 -3565. 91 -2930.04 2.08 5937181. 61 682421.23 N 70 14 0. 865 W 148 31 38.043
11913.65 100.52 264.98 8824.11 8888.67 4292.19 5707.09 4637.14 -3568. 80 -2960.86 5.19 5937177. 96 682390.50 N 70 14 0. 836 W 148 31 38.939
11946.52 95.44 264.51 8819.55 8884.11 4322.18 5739.63 4660.18 -3571. 78 -2993.26 15.52 5937174. 18 682358.18 N 70 14 0. 807 W 148 31 39.881
12042.49 96.68 264.76 8809.42 8873.98 4410.21 5835.06 4728.52 -3580. 71 -3088.27 1.32 5937162. 93 682263.42 N 70 14 0. 718 W 148 31 42.641
12106.24 97.62 264.10 8801.49 8866.05 4468.64 5898.31 4774.48 -3586. 85 -3151.23 1.80 5937155. 25 682200.64 N 70 14 0. 658 W 148 31 44.471
12138.24 102.01 265.11 8796.03 8860.59 4497.73 5929.84 4797.48 -3589. 81 -3182.61 14.07 5937151. 51 682169.34 N 70 14 0. 628 W 148 31 45.383
12231.98 103.04 265.32 8775.70 8840.26 4581.78 6021.34 4864.09 -3597. 45 -3273.80 1.12 5937141. 64 682078.37 N 70 14 0. 553 W 148 31 48.032
Last Survey 12278.70 103.60 265.09 8764.94 8829.50 4623.54 6066.81 4897.49 -3601. 25 -3319.10 1.29 5937136. 73 682033.17 N 70 14 0. 515 W 148 31 49.349.
TD (Projected) 12331.00 103.60 263.39 8752.64 8817.20 4670.56 6117.64 4935.63 -3606 .35 -3369.68 3.16 5937130. 38 681982.74 N 70 14 0. 465 W 148 31 50.818
Survey Type: Definitive Survey
NOTES: CB-GYRO-MS - (Camera-based gyro multishot --Traditional optically referenced gyro surveys run on wireline
-including "level rotor" gyros a nd Sperry-S un SU3. Replaces ex-BP "PGMS" model. ) •
INC+TREND (Inclinometer + known azi trend -- Inclination only surveys in near-vertical hole-where formation dip and
experience enables di rection of drift to be predicted. Replaces ex-BP "Inclinometer (azimuth in known quadrant)" model. )
MWD + IFR + MS - (In-fiel d referenced MWD w ith mutt-stat ion analysis and correction applied in post-processing.
Assumes a BHA sag correction is applied to enhan ce inclinat ion accura cy. )
Legal Description: Northing (Y) f ftUSl Easting (X) fftUSl
Surface : 237 FSL 1728 FEL S2 T10N R14E UM 5940818.23 685262.56
BHL : 1910 FSL 510 1 FEL S11 T10N R14E UM 5937130.38 681982.74
SurveyEditor Ver SP 2.1 Bld( users) 06-14\06-14\06-14B\06-14B Generated 4/16/2009 3:50 PM Page 5 of 5
TREE= 4-1/16" CMJ
WELLHEAD = FMC
ACTUATOR =
KB ELEV = 64.56
BF. ELEV = 3T
KOP = 5,020' MD
Max Angle=106° @ 11500'
Datum MD = i t v(iis'
Datu m TV D = 8800' SS
~~ . ~..~£
13-3/8" CSG, 72#, BTC, N-80, ID = 12.347" H 2,685'
TOP OF CMT 3000'
Minimum ID = 3.725" @ 10568'
4-1 /2" XN NIPPLE
7" CSG, 26#, L-80, TCII, ID = 6.276" 4824'
TOP OF9-5/8"WINDOW H 8552'
WHIPSTOCK 4982'
¢sv H 5004'
9-5/8" CSG, 47#, L-80, ID = 8.681" 8552'
MILLOUT WINDOW (06-14A) 8552' - 8613'
4-1/2" CSG, 12.6#, 13CRVAMTOP, ID = 3.958" H 10580'
PERFORATION SUMMARY
REF LOG:
ANGLE AT TOP PERF: 68° aC~ 11102'
Note: Refer to Production DB for historical pert data
SIZE SPF INTERVAL Opn/Sqz DATE
2-7/8" 6 11102 - 11140 O 04/02/09
2-7/8" 6 11170 - 11190 O 04/02/09
2-7/8" 6 11480 - 11790 O 04/02/09
2-7/8" 6 11960 - 12020 O 04/02/09
PBTD 12242'
4-1/2" CSG, 12.6#, 13CR VAMTOP, ID = 3.958" 12330'
4814' 9-5/8" x 7" BKR LT PKR, ID = 6.187"
w /TIEBACK & LNR HGR
MILLOUT WINDOW (06-14B) 4982' - 4999'
DATE REV BY COMMENTS DATE REV BY COMMENTS
06/21/80 ORIGINAL COMPLETION
07/03/92 RWO
04/05/09 N9ES SIDETRACK (06-14B)
10473' H4-1/2" X-NIP, ID = 3.813"
10504' H 7" x 4-1/2" BKR S3 PKR, ID = 3.87"
~ 10537' H4-1/2" X-NIP, ID = 3.813"
10568' 4-1/2" XN-NIP, ID = 3.725"
10565' 4-1/2", 12.6# 13Cr Tieback Top
10577' 7" x 5" ZXP LT PKR, ID = 5.56"
10580' 4-1/2" WLEG, ID = 4.00"
10587' H 7" x 5" FLIX LOCK HGR, ID = 4.44"
10597' H 5" x 4-1 /2" XO, ID = 3.92"
10725' 7" CSG, 26#, BTGM, ID = 6.276"
PRUDHOE BAY UNff
WELL: 06-14B
PERMfT No: 209-012
API No: 50-029-20458-02
SEC 11, T10N, R14E, 5,084' FEL & 3,420' FNL
BP Exploration (Alaska)
06-14B
SA NOTES: ""*CHROMETBG & LNR""* WELL
ANGLE>70° @ 11118' & >90° @ 11405'
2219' H4-1/2" X-NIP, ID = 3.813"
GAS LIFT MANDRELS
ST MD TVD DEV TYPE VLV LATCH PORT DATE
5 3537 3537 0 KBG-2 DMY BK 0 04/04/09
4 5918 5656 42 KBG-2 DCK BEK 0 04/04/09
3 8084 6977 56 KBG-2 DMY BK 0 04/04/09
2 9367 7833 47 KBG-2 DMY BK 0 04/04/09
1 10102 8288 52 KBG-2 DMY BK 0 04/04/09
• Page 1 of ~
Maunder, Thomas E (DOA)
From: Regg, James B (DOA)
Sent: Friday, March 27, 2009 12:41 PM
To: Maunder, Thomas E (DOA)
Subject: FW:
Jim Regg
AOGCC
333 W.7th Avenue, Suite 100
Anchorage, AK 99501
907-793-1236
From: NSU, ADW Drlg Field Superintendent [mailto:NSUADWDrIgFieldSuperintendent@bp.com]
Sent: Friday, March 27, 2009 12:30 PM
To: Neufeld, Blair (ASRC); DOA AOGCC Prudhoe Bay
Cc: Sayers, Zach J
Subject: RE:
Blair,
Got your note. As discussed I will be by after my visit to 2-ES.
Alan Madsen
GPB Rotary Drilling Superintendent
907-306-4997 cell
907-659-4618 North Slope office
907-564-5780 Anchorage office
~" ;s ~ yw(&uc ~ X~C ~ ~«. G~x . ~ ~c +rus.cw~,. ~.c`u ~.ocn ( aw+~.
From: Neufeld, Blair (ASRC)
Senn Friday, Mard'+ 27, 2009 11:07 AM
To: doa.aoga.prudhoe.bay@alaska.gov
Cc: Sayers, Zach J; NSU, ADW Drlg Field Superintendent
Subject:
John,
This morning when drilling ahead this morning on well 06-148 at~12,197' we lost returns and had to pull out to
the casing shoe to open the circulation sub that was in the BHA. Losses were high enough that we became low
on fluid and needed to shut the well as a precaution while waiting on fluid.
Well shut in @ 11:00 AM using the annular preventer. Drill pipe pressure 0 psi Casing pressure 0 psi
Any questions call 659-4831
Blair Neufed
4/24/2009
1~ J
- Y ~+ 'PIS ul
- ~' 4 pV ~ n Y. ~/~
ALA58iA OIL A1~TD GrAS
CO1~T5ERQATIOI~T CODiDIISSIOI~T
Robert Tirpack
Engineering Team Leader
BP Exploration (Alaska) Inc.
P.O. Box 196612
Anchorage, Alaska 99519-6612
SARAH PALIN, GOVERNOR
333 W. 7th AVENUE, SUITE 100
ANCHORAGE, ALASKA 99501-3539
PHONE (907) 279-1433
FAX (907) 276-7542
Re: Prudhoe Bay Field, Prudhoe Bay Pool, 06-14B
BP Exploration (Alaska) Inc.
Permit No: 209-012
Surface Location: 238' FSL, 1728' FEL, Sec. 02, T10N, R14E, UM
Bottomhole Location: 3420' FNL, 5084' FEL, Sec. 11, TlON, R14E, UM
Dear Mr. Tirpack:
Enclosed is the approved application for permit to redrill the above referenced
development well.
This permit to drill does not exempt you from obtaining additional permits or
an approval required by law from other governmental agencies and does not
authorize conducting drilling operations until all other required permits and
approvals have been issued. In addition, the Commission reserves the right to
withdraw the permit in the event it was erroneously issued.
Operations must be conducted in accordance with AS 31.05 and Title 20,
Chapter 25 of the Alaska Administrative Code unless the Commission
specifically authorizes a variance. Failure to comply with an applicable
provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code,
or a Commission order, or the terms and conditions of this permit may result
in the revocation or suspension of the permit. When providing notice for a
representative of the Commission to witness any required test, contact the
Commission's petroleum field inspector at (907) 659-3607 (pager).
Sincerely,
Daniel T. Seamount, Jr.
~~~ Chair
DATED this ? day of January, 2009
cc: Department of Fish 8v Game, Habitat Section w/ o encl.
Department of Environmental Conservation w/o encl.
STATE OF ALASKA / Q?~ ~~~~GD
ALASK~L AND GAS CONSERVATION COMMIS~N ~~~,~~, ~ 2009
'\'O~ PERMIT TO DRILL ~-I~~~
1 ~ 20 AAC 25.005
1 a. Type of work
^ Drill ®Redrill
^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas
^ Service ^ Multiple Zone
^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well is pr ~
^ Coalbed Methane Gas ydrates
^ Shale Gas
2. Operator Name:
BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well
Bond No. 6194193 11. Well Name and Number:
PBU 06-146
3. Address:
P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth:
MD 12216 TVD 8757 12. Field /Pool(s):
Prudhoe Bay Field / Prudhoe Bay
4a. Location of Well (Governmental Section):
Surface:
'
' 7. Property Designation:
ADL 028311 Pool
238
FSL, 1728
FEL, SEC. 02, T10N, R14E, UM
Top of Productive Horizon:
3127' FNL, 3629' FEL, SEC. 11, T10N, R14E, UM
8. Land Use Permit:
13. Approximate Spud Date:
February 10, 2009
Total Depth:
3420' FNL, 5084' FEL, SEC. 11, T10N, R14E, UM 9. Acres in Property:
2560 14. Distance to Nearest Property:
13000'
4b. Location of Well (State Base Plane Coordinates):
Surface: x-685263 y-5940818 Zone-ASP4 10. KB Elevation
(Height above GL): 68' feet 15. Distance to Nearest Well Within Pool:
1150'
16. Deviated Wells: Kickoff Depth: 5000' feet
Maximum Hole An le: 103 de tees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035)
Downhole: 3415 Surface: 2516
1 in Pr r m: a ifi i To - in D th - m n ' of m n .f. or ck
Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data
- / " 7" 26# L- 0 BT -M 4 0' urf S rf 485 ' 47 95 x i C 172 x CI
-1/ " 7" 26# L-80 TC-M 7 48 0' 4788' 10608' 8 9' 2 7 sx I ss'G'
-/" 4-1/" V T 1 7' 121' '
19. PRESE NT WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations)
Total Depth MD (ft):
10145' Total Depth TVD (ft): Plugs (measured):
9167' 9395' & 9756' Effective Depth MD (ft):
9975' Effective Depth TVD (ft):
9034' Junk (measured):
9952'
Casing Length Size- Cement Volume MD TVD
Conductor /Structural 11 2 4 I 1 '
Surface 268 ' 1 - / " 22 sx F n 4 x AS II 2 85' 2 8 '
Intermediate 55 ' 9- / " 15 x la s' xA 8 5 ' 7 23'
P i
Liner 17 5' 7" 9 c ft I s 26 ' - 1 7 ' - 0 '
Perforation Depth MD (ft): 9728' - 9858' Perforation Depth TVD (ft): 8844' - 8944'
20. Attachments ^ Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis
® Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements
21. Verbal Approval: Commission Representative: Date:
22. I hereby certify that the foregoing is true and correct. Contact Zach Sayers, 564-5790
Printed Name Robert Tirpac Title Engineering Team Leader Brandon Peltier, 564-5912
Prepared By Name/Number
Si nature Phone 564-4191 Date ~/a~ ~9 Sondra Stewman, 564-4750
Commission' Use Onl
Permit To Drill
N m r: 09010 API Number:
50-029-20458-02-00 Permit Approval
D See cover letter for
t r r item
Conditions of Approval: ~~~~~ .~.~`„~~~ ` ~~~~~~~~~~ ~ ~cq~,~a-~ .eSS~~~r~ d
If box is checked,`` I may not be use o exp ore for, test, or pr duce coalbed methane, gas hydrates, or gas contained shales:
~~~es~ ra~~~ ~` Samples Req'd: ^ Yes ~No Mud Log Req'd: ^ Yes ~No
~~~ ~4 HZS Measures: Yes ^ No Directional Survey Req'd: Yes ^ No
t~:~i~ ~. Gr~r1~C.t.r..,~.5~
Other: 1 ,
APPROVED BY THE COMMISSION
Date ~ '; COMMISSIONER
Form 10-40ti Revised 12005' v ~-°~ Submit In Duplicate
~~
Permit to Drill Application
Well• 06-146 Well Oil Producer
_ _Type:
API Number: 50-029-20458-xx
•
Target Ivishak
Objective: Zone 4B
Current Status: 6-14A Shut-In due to IA x OA communication
Planned for 3/15/09,
but could move ua to
Estimated Spud Date• y~0/09 if Sag river ice prepared By: Zach Sayers and
' bridge does not freeze Brandon Peltier
sufficiently enough to
allow ri assa e.
Rig: Nabors 9ES BFE: 37' (~ RTE: 65.5'
Surface Northing Easting Offsets TRS
Location ~ 5,940,819 ~ 685,263 1,728' FEL / 238' FSL 10N, 14E, 2
Tar
et Start Northin Eastin TVDss Offsets TRS
g 5,937,409 683,448 8,678 3127' FNL / 3629' FEL 10N, 14E, 11
Bottom Northin Eastin TVDss Offsets TRS
Location 5,937,080 682,001 8,757 1,859' FSL / 196 FWL 10N, 14E, 11
Planned KOP: 5,o00'MD /
i 4,846'TVDss
Directional -Plan #9
Planned TD: 12,216' MD /
8,757'TVDss
Maximum Hole An le: -103° in the 6-1/8" section
Close A roach Wells: Reference AC report in directional plan #9
Surve Pro ram: MWD Standard + IFR /Cassandra / MS
Nearest Pro ert Line: 13000'
Nearest Well within Pool: 1150'
Contacts:
Drilling Engineer
Geologist
Production Engineer
Reservoir Engineer
Name:
Zach Sayers
Priya Maraj
Ana Seltenright
Erin O'Brien-Authier
Phone: Email:
(907) 564-5790 Zach.Sayers@bp.com
(907) 564-4181 Priya.Maraj@bp.com
(907) 564-4418 Ana.Seltenright@bp.com
(907) 564-5395 Erin.OBrien-Authier@bp.com
~ ~
FORMATION MARKERS 06-146 (BASED ON SOR)
, Formation Est. -
Formation
Tops ~
Dss) 1
I Uncertainty
(feet) ---- ------
Commercial
~ Hydrocarbon
Bearin
( (Yes/No) ~ ----- -~
j Est. Pore Press.
~ _ __ _
(Psi) Ag EMW) j
Base Permafrost 1,920'
SV4 2,680'
KOP @ 3700' MD
SV1 3,886'
UG4
UG3 4,741'
UG1 5,227'
WS2 5,803'
WS1 6,042'
CM3 6,290'
CM2 6,785'
CM1 7,440'
THRZ 7,870'
BHRZ 8,029'
LCU 8,087
TJC 8,245' ~
~ TJB 8,412'
TJA 8538'
TSGR 8,604' 20' ( es 3,252 si 7.3
TSHU 8,629' 20' no
TSAD 8,709' 20' es
42SB 8,840' 20' es 3,250 si 7.1
TCGL 8,916' 20' es
BCGL 8,994' 20' es
NEW CASING/TUBING PROGRAM
Hole
Size Csg /
Tb OD Wt /
Ft
Grade
Conn. Burst
si Collapse ;
si i Length Top ~
MD/T\/Drkb Bottom
MD/TVDrkb ~
9-5/8" 7" 26# L-80 BTC-M 7,240 5,410 4,850' GL 4,850'/4788'
8-'/z" 7" 26# L-80 BTC-M 7,240 5,410 5758' 4,850'/4788' 10,608'/8669'
6-%e" 4 -'h" 12.6# L-80 Vam To 8,430 7,500 1757' 10,458'/8573' 12,215'/ 8,823'
Tubin 4 -~h" 12.6# L-80 Vam To 8,430 7,500 10,458' GL 10,473'/8582'
MUD PROGRAM
Whi stock Milling Mud Pro
Depth Interval ~ Density erties: LSND
~ PV ~ YP API FL Whip Stock Window 9 5/8", 47#
LSVR _i MBT _ PH
5,000' 8.9 6-12 30-5 6.0-8.0 >22,000 < 3 9.0-9.5
8-~/z" Hole Sectio_n_ _
Intermediate Mud Properties: LSND Fluid
De th Interval ' Densi~~pp~ PV YP __
API FL LSVR MBT _ PH _
5000'-10608' 8.9-10.7 6-12 22-28 6.0-8.0 >22,000 < 3 9.0-9.5
Production Mud Properties: FLOPRO SF Reservoir Drill-in Fluid 6-%8" Hole Section
' Depth Interval ~Densit PV YP API FL LSVR MBT PH
10608'-12216' 8.5 6-12 22-28 6.0-8.0 >22,000 < 3 9.0-9.5
LOGGING PROGRAM
9-5/a" Surface: 9-5/e" Casing
Drilling: N/A
'~ Open Hote: N/A
Cased Hole: USIT/CCL SURF - 4,500'
8-'/z" Intermediate: 7" Casing
Drilling: Dir/GR/Res/PWD KOP - TD'
t Open Hole: None
Cased Hole: _ `__ ~ None
6-'/e" Production: 4-~/z" Casing
Drillin Dir/GR/Res/Neu/Den 7" Shoe - TD
Olen Hole: None
Cased Hole: None
Sam lin Sam le Catchers
CEMENT PROGRAM
7" Liner Section
'~Casin Size 7" 26#, L-80 BTC-M
Lead: Open hole volume with 40% excess, 150' of liner lap, 200' excess above lap
i B
i TOC at TOL
as
cs:
~ Tail: 1000 of open hole with 40% excess, 80' shoe track,
TOC 1000' above 7" shoe
~ Spacer 30 bbls of Viscous S acer wei hted to 11 p Mud Push II
~ T
t
l C
t
o
a
emen Lead 166 bbls, 931 cu-ft, 395 sks, 2.36 cu-ft/sk, 11.5 LiteCrete
Volume: Tail 36 bbls, 199 cu-ft, 172 sks 15.8 Ib/ al Class G + adds -1.17 ft /sk
i Tem BHST = 186° F
7" Liner Tie-Back Section
i Casin Size 7" 26#, L-80 BTC-M
~ Lead: None
Basics:
____ Tail: 1,850' of 7" liner tie-back
Tail TOC: 3000' MD
S acer 30 bbls of Viscous S acer wei hted to 9.5 Mud Push II
Total Cement Lead None
Volume: Tail 48 bbls, 266 ft , 227 sks 15.8 Ib/ al Class G + adds - 1.17 ft /sk
~ Tem BHST = 186° F
4-1/2" Produc tion Liner Section
_ Casing Size
__~_ 4-~/z" 12.6#, 13CR VAMTOP
B
i Lead: None
as
cs:
~ Tail: O en hole volume with 40% excess, 80' shoe track, 150' of liner la , 200' of 7"x4" excess
S acer 30 bbls of Viscous S acer wei hted to 9.5 Mud Push II
j Total Cement Lead None
Volume: ~ Tail 46.3 bbls, 260 ft , 222 sks 15.8 Ib/ al Class G + adds - 1.17 ft /sk
Tem BHST = 186° F
• •
Surface Shut-in Wells:
The 06-14B wellhead is located between wells 6-15 and 6-13 with a distance of 120' to each side.
Hydrogen- Sulfide
Recent HZS data from the pad is as follows:
Well Name
#1 Closest SHL Well HZS Level 06-14A
#2 Closest SHL Well HZS Level
#1 Closest BHL Well HZS Level
#2 Closest BHL Well HZS Level
Max. Recorded HZS on Pad/Facility
Other Relevant HZS Data
(HZS alarms from rigs, etc.)
Well Control
06-13A
H2S Level (ppm) Date of Reading
12 02/03/2001
10 03/20/2008
06-12A 12 01 /27/2001
06-066 10 03/31 /2008
06-13 250 01 /09/2004
Drill Site 6 is a H2S Pad.
Please follow procedures for high H2S.
Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and
annular preventer will be installed and are capable of handling the maximum potential surface pressures.
Based upon calculations below, BOP equipment will be tested to 3,500 psi.
BOP regular test frequency for 06-14B will be 14 days during drilling phase and 7 days during de-
completion.
Diverter, ROPE and drilling fluid system schematics on file with the AOGCC.
8-1 /2" Interval
Maximum Antici ated BHP 3,415 si C~ 8998' TVD, 7.3 EMW
Maximum Surface Pressure
_ 2,516 psi (.10 psi/ft gas gradient to surface) (Top of Sag River
Formation
Kick Tolerance 130bb1s with a 11.1 FIT
_____
Planned BOP Test Pressure Rams test to 3,500 psi/250 psi.
Annular test to 2,500 si/250 si
9-518" Casio" Liner Test 3,500 si surface ressure
Integrity Test - 6-1/8" Hole , FIT after drilling 20' of new hole
Planned Completion Fluids _' 9.0 NaCI Brine / 6.8 Diesel
6-1/8" Interval
_ Maximum Anticipated BHP ___ 3,415 si C~3 8998' TVD, 7.3 EMW
Maximum Surface Pressure
_ __ 2,516 psi (.10 psi/ft gas gradient to surface) (Top of Sag River
Formation
Kick_Tolerance Infinite with a 11.0 FIT
Planned BOP Test Pressure Rams test to 3,500 psi/250 psi.
Annular test to 2,500 si/250 si
4-112" liner test 3,500 si surface ressure
', Integrity Test - 6-1/8" Hole FIT after drillin 20' of new hole
'_Planned Completion Fluids 9.0 NaCI Brine / 6.8 Diesel
Other Requests: ~ ~~-~~~~~~
Given rig floor height limitations, a MASP < 3000 psi, and the fact that the three ram drillin BOP
configuration is preferred to a two ram configuration with a spool, BPXA will execute the provisions of 20
AAC 25.285 (f) (1) regarding the initial testing of the BOPE as follows when existing wellhead or testing
equipment prevents the testing of the lowest set of pipe rams: That lowest set of rams will be tested at
the earliest opportunity during path-forward de-completion work, i.e., after the completion has been pulled
from the well. Safety concerns and spacing limitations with the wellhead height and tubing spool preclude
us from installing a spacer spool in the three-ram drilling BOP stack.
Disposal
~~
L .J
• No annular injection in this well.
• Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject
at DS-04. Any metal cuttings will be sent to the North Slope Borough.
• Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for
injection. Haul all Class I waste to Pad 3 for disposal.
•
•
Drilling Hazards and Contingencies
POST THIS NOTICE IN THE DOGHOUSE
I. Well Control
A. The Ivishak in this fault block is expected to be under-pressured at 7.1-7.3 ppg EMW.
II. Lost Circulation/Breathing
A. The proposed 06-14B well lies in a high risk province of the field for lost circulation at faults.
Twelve loss circulation events were encountered in the Sadlerochit and Kingak sections in 6 of
the surrounding 16 wells (38%), with a high proportion of these in the Kingak and Sag River
section as detailed below. No faults are expected to be crossed in the planned well; however, a
significant fault (20 ft throw) is present in Zone 3 underneath the wellplan. Potential tipout
fractures from this fault are coincident with 350 bph loss circulation in the 06-06B Sag well.
Risks of loss circulation for the proposed 06-14B Ivishak well are moderate.
III. Kick Tolerance/Integrity Testing
8-1/2" Interval
Maximum Anticipated BHP 3,415 si C~3 8998' TVD, 7.3 EMW
Maximum Surface Pressure 2,516 psi (.10 psi/ft gas gradient to surface) (Top of Sag River
Formation
Kick_Tolerance _ 130bb1s with a 11.1 FIT
9-5/8" Casin "Liner Test 3,500 si surface ressure
Integrity Test - 6-1/8" Hole FIT after drillin 20' of new hole
6-1/8" Interval
Maximum Antici ated BHP 3,415psi C 8998' TVD, 7.3 EMW
Maximum Surface Pressure
_ 2,516 psi (.10 psi/ft gas gradient to surface) (Top of Sag River
Formation
_
___
Kick Tolerance Infinite with a 11.0 FIT
4-1/2" liner test 3,500 si surface ressure
Integrity Test - 6-1/8" Hole FIT after drillin 20' of new hole
IV. Stuck Pipe
A. Stuck pipe has not been an issues on past wells drilled from this pad, however there is a small
risk of occurrence due to the lower reservoir pressure.
VI. Hydrogen Sulfide
Recent HZS data from the pad is as follows:
Well Name H2S Level (ppm) Date of Reading
#1 Closest SHL Well H2S Level 06-14A 12 02/03/2001
#2 Closest SHL Well H2S Level
#1 Closest BHL Well H2S Level
#2 Closest BHL Well H2S Level
Max. Recorded H2S on Pad/Facility
Other Relevant H2S Data
(H2S alarms from rigs, etc.)
VII. Faults
06-13A 10 03/20/2008
06-12A 12 01 /27/2001
06-06B 10 03/31 /2008
06-13 250 01 /09/2004
Drill Site 6 is a HZS Pad.
Please follow procedures for high HZS.
• No planned fault crossings. See lost circulation for details.
VIII. Anti-Collision Issues
A. Reference Anti-collision report in directional plan #9
CONSULT THE DS 06-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL
INFORMATION
Rig Operations Summary
Pre Rig Screening Work to Be Completed:
1. S Pull TTP C~3 9,376' Installed 10/20/08
2. S Deflate & Pull IBP @ 9,756' MD throu h 4-~h" Tubin to Surface
3. C In case that IBP is not retrieved: Push IBT to bottom w/ Coil
4.
C Pump Cement from TD to TOC = 9,641' or higher
Inside 7", 26# Casing this volume should be approximately 12.8 bbls of 15.8 ppg Class G
cement
5. S Drift tubin and to TOC
5. O Pressure Test Cement Plu to 2,500 si
6. O Pressure Test to verif Abandonment & Barriers
MIT-IA to 3,500 si
If IA Fails contact Drillin En ineer to discuss runnin Leak Detection Lo
MIT-OA to 2,000 si
PPPOT-T to 5,000 si
PPPOT-IC to 5,000 si
Function Test Tub LDS-T & Prod Casin Han er LDS-IC LDS
7. E RIH and 'et cut tubin 039,000'
8. O Circulate the well to seawater. Freeze- rotect the IA and tubin with diesel to 2,200'.
9. O Bleed all ressures to zero. Set BPV. Secure well.
10. O Remove the well house. If necessar ,level the ad.
Scope of Work for Sidetrack:
1. MI / RU Nabors rig 9ES
2. Pull BPV. Circulate out diesel freeze protection and displace the well to seawater.
3. Set and test TWC to 1,000 psi from above and below.
4. Hook up OA to a bleeder tank and monitor (OA will not pass pressure test / no OA test required).
5. Nipple down tree & tubing adapter. Nipple up and test BOPE to 3,500psi high/ 250psi low with 4"
& 5-'/z". Pull TWC.
6. R/U & pull 5-'/z" x 4-'h" tubing from the cut depth at 9,000' MD. ~O~ _. `~
7. R/U & Run 9-5/8' casing scraper to 5,500'.
8. RU E-line and RIH w USIT (in PDC Mode)/CCU to 5,500' and log to surface. (E-Line Pressure
control NOT necessary)
9. RIH with HES EZSV bridge plug on E-line and set at 5,000' MD, as required to avoid cutting a
casing collar while milling the window. Test CSG to 3,500 psi. POOH.
10. String shot 9 5/8" casing at back off point (two full joints above where USIT indicates) to ease
break out. RD E-line.
11. MU a Baker 9 5/8" cutting assembly. RIH picking up DP. Cut the 9-5/" casing per Baker
representative instructions. Cut ~4' above the string shot casing collar. POOH, UD assembly.
12. Change out to 9 5/8' rams, and test rams.
13. BOLDS, RU/MU casing spear assembly, and unseat the 9 5/". Circulate the annulus. Pull the 9-
5/" casing from the cut.
14. MU wash-over assembly and 13 3/" casing scraper and 9 5/8" dress off assembly.
15. RIH, clean-out the 13-'/e" casing, and the 9-5/8" casing stub, dress off the 9 5/8' casing stub to
accept a casing patch. POOH, UD the assembly.
16. MU 9 5/8" ES Cementer on Bowen's casing patch, and RIH w/ 9-5/8" casing.
17. Test new 9-5/6" / ES cementer /casing patch to 2,000 psi for 10mins.
18. Pressure up to open the ES cementer and cement 9 5/8" x 13 3/" annulus with class G 15.8ppg
cement to surface.
19. Split stack and install FMC 13" x 9 5/8" emergency slips with primary pack off per FMC wellhead
specialist in the casing head. Set slips. Cut and LD excess 9 5/8" casing. Set back BOPE test
breaks to 3,500 psi and test packoff to 3800 psi.
20. NU BOPE. Change BOP rams back to VBR's and test rams to 250 psi / 3,500 psi with a 4" test
joint.
21. PU 4" DP and 8-'/2 "mill tooth bit.
22. Pressure-test the 9-5/8" casing to 3,500 psi for 30 minutes. Record test. ~ ~C~ ~\~~
23. Make clean out run through the ES Cementer and down to EZSV. ~l
24. Pressure-test the 9-5/8" casing to 3,500 psi for 30 minutes. Record test.
25. P/U and RIH with 9-5/8" Baker bottom-trip anchor whip stock assembly. Orient whipstock and set
on EZSV bridge plug. Shear off of whip stock.
26. Displace the well to LSND based milling fluid. Completely displace the well prior to beginning
milling operations.
27. Mill window in 9 5/8" casing at ± 5,000' MD, plus approximately 20' beyond middle of window.
Circulate well bore clean.
28. Pull up into 9 5/8" casing and perform FIT. POOH.
29. M/U 8-'/z" GR/RES/PWD/MWD assembly. RIH, kick off and drill the 8-'/z" intermediate section with
LSND drilling fluid.
30. Drill ahead to the 7" liner point at top of the Sag River, as per the directional plan. Circulate the
~\ ~ well clean, short trip to THRZ or higher as needed. POOH.
31., Change out to 7" rams, and test to 250 psi / 3,500 psi with 4" and 7" test joints.
-\~ 32. MU and run 7", 26#, L-80, BTC-M liner to bottom on drill pipe. Circulate and condition the hole.
per` ~ 33. Cement the entire 7" liner through the 8-'/z" hole and back 150' into the 9-5/8" casing to the liner
top. Set the hanger and packer, displace cement with mud.
34. Circulate bottoms up, POOH, UD liner running tool (LRT).
35. Test liner to 3,500 psi for 30 minutes after cement reaches its compressive strength.
36. MU &RIH with 7", 26#, L-80, TCII, liner tieback.
37. Sting in and establish seal, P/U to expose ports.
38. Cement the tieback to 3,000' MD, bury the seal. The top of the 9 5/8' x 7" annulus will be freeze
protected with diesel to the surface.
39. Test the tieback and plug to 3,500 psi for 10 minutes.
40. ND BOP and pick up BOP at wellhead.
41. Install and set weight on slips per Cameron Rep.
42. Cut the 7" casing per Cameron Rep, set BOP back.
43. Install tubing spool with secondary 7" casing in bottom.
44. Test Casing Hanger Flange and Pack-Off Seals to 80% of Casing Collapse or Flange rating
(which ever is lower).
45. NU and test BOP.
46. Change out rams to variable and test to 250 psi / 3,500 psi with 4" and 4-'/z" test joints.
47. M/U the first 6-%e" Dir/GR/Res assembly with an insert bit. Pick Up DP as necessary.
48. RIH to drilling the tieback float equipment, test to 3,500 psi for 10 minutes, and record.
49. Drill out of cement and tieback float equipment to the 7" liner float equipment.
50. Test the liner to 3,500 psi for 30 charted minutes.
51. Displace to 8.4 ppg Flo Pro Fluid.
52. Drill out of cement and float equipment to shoe.
53. RIH, and drill out the 7" shoe plus ~20' new formation, pull up into the shoe and perform a FIT.
54. Drill the 6-%8' production interval as per directional plan to end of the build section.
55. POOH for PDC bit.
56. POOH, PU second BHA with PDC.
57. RIH, drill ahead to TD.
58. POOH. UD BHA.
59. MU and RIH to bottom with 4-'/z", 12.6#, 13CR VAMTOP solid liner. This will include 150' liner lap
inside the 7" drilling liner.
60. Cement the liner.
61. Set liner top packer and displace well to clean seawater above the liner top.
a. A pert pill will be left in the 4-'h"" liner.
62. POOH, UD LRT.
63. Pressure test casing and liner to 3,500 psi for 30 minutes.
64. RU DPC pert guns, RIH and perforate. Perf intervals to be supplied by asset.
65. R/U and run a 4-'h", 12.6#, 13Cr, VamTop tubing completion, stinging into the 4-'h"" liner tie back
sleeve.
66. Space out and make up tubing hanger per Cameron Rep.
67. Land the tubing hanger, and run in lock down screws.
68. Circulate Corrosion Inhibitor.
~hz5
C ~\~..
69. Set packer and individually test the tubing and annulus to 3,500 psi for 30 minutes. Record each
test.
70. Shear Circulating Valve
71. Set a TWC.
72. Nipple down the BOPE. Nipple up the tree and test to 5,000 psi.
73. Freeze protect the well to 2,200' TVD. Secure the well.
74. RD and Move Off.
Post-Rig Operations:
1. MI / RU slick line. Pull the ball and rod / RHC plug from landing nipple below the production
packer.
2. Replace the DCK shear valve with a dummy GLV.
3. Install well house and instrumentation.
4. Modify S- Riser As Needed.
by
DS06-14B (P9) Pro
Report Date: January 22, 2009
Client: BP Exploration Alaska
Field: Prudhoe Bay Unit - EOA
Structure 1 Slot: DS-O6 / 06-14
Well: 06-14
~'''~
Borehole: ~'
Plan 06-146 Fe~
UWIIAPIO: 500292045802
Survey Name 1 Date: 06-14B (P9) sperry /January 22, 2009
Tort 1 AHD 1 DDI 1 ERD ratio: 191.922° 16013.91 ft / 6.19510.668
Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet
LocaOon LaVLong: N 70.24331691, W 148.50358325
Location Grid NIE YIX: N 5940818.230 ftUS, E 685262.560 ftUS
Grid Convergence Angle: +1.40836923°
Schlumherger
~osal
Survey 1 DLS Computation Method: Minimum Curvature I Lubinski
Vertical Section Azimuth: 221.590°
Vertical Section Origin: N 0.000 ft, E 0.000 ft
TVD Reference Datum: Rotary Table
TVD Reference Elevation: 65.50 ft relative to MSL
Sea Bed 1 Ground Level Elevation: 37.00 ft relative to MSL
Magnetic Declination: 22.847°
Total Field Strength: 57705.332 nT
Magnetic Dip: 80.898°
Declination Date: March 25, 2009
Magnetic Declination Model: BGGM 2008
North Reference: True Norlh
Total Corr Mag North -> True North: +22.847°
Comments Measured
Inclination
Azimuth
Sub-Sea TVD
TVD Vertical
NS
EW Mag 1 Grav
DLS Directional
Northing
Easting
Latitude
Longitude
Depth Section Tool Face Difficulty
ft de de ft ft ft ft ft de de 1100 ft Index ftUS ftUS
i ie-in survey 4aar.ou 3~.UU L34.VU 484J.r I 4yVy.G l 304 AL -L I ~.IO -JU I.~O yV.VVL vAr w. is aay~aa i. is vowavv.va i~ / V. GYL/ ivo i vv iwo. ovo~c iov
Top Whipstock 5000.00 35.00 234.00 4845.76 4911.26 366.22 -220.61 -303.14 85.00E 0.00 4.19 5940590.25 684964.96 N 70. 24271421 W 148. 50603123
KOP Crv 4/100 5020.00 35.28 229.86 4862.11 4927.61 377.54 -227.70 -312.19 87.56E 12.00 4.23 5940582.94 684956.08 N 70. 24269482 W 148. 50610437
5100.00 35.54 224.35 4927.33 4992.83 423.63 -259.23 -346.12 83.07E 4.00 4.31 5940550.59 684922.94 N 70. 24260868 W 148. 50637831
5200.00 36.21 217.62 5008.39 5073.89 482.16 -303.43 -384.48 77.61 L 4.00 4.40 5940505.46 684885.67 N 70. 24248793 W 148. 50668812
5300.00 37.25 211.16 5088.56 5154.06 541.42 -352.75 -418.19 72.43E 4.00 4.49 5940455.34 684853.19 N 70 .24235320 W 148. 50696028
5400.00 38.62 205.04 5167.46 5232.96 601.12 -406.94 -447.07 67.60E 4.00 4.56 5940400.45 684825.66 N 70 .24220514 W 148. 50719347
UG1 5476.86 39.87 200.61 5227.00 5292.50 647.13 -451.74 -465.90 64.17E 4.00 4.62 5940355.20 684807.94 N 70. 24208274 W 148. 50734549
5500.00 40.28 199.32 5244.70 5310.20 660.97 -465.74 -470.98 63.18E 4.00 4.64 5940341.08 684803.20 N 70 .24204448 W 148. 50738654
5600.00 42.21 194.00 5319.91 5385.41 720.69 -528.88 -489.81 59.18E 4.00 4.71 5940277.51 684785.93 N 70 .24187201 W 148. 50753856
5700.00 44.37 189.09 5392.71 5458.21 779.98 -596.03 -503.47 55.61E 4.00 4.77 5940210.05 684773.93 N 70 .24168855 W 148. 80
5800.00 46.72 184.55 5462.75 5528.25 838.55 -666.87 -511.88 52.43E 4.00 4.84 5940139.02 684767.25 N 70 .24149501 W 148. ~
71
5900.00 49.24 180.37 5529.70 5595.20 896.12 -741.06 -515.01 49.62E 4.00 4.90 5940064.78 684765.95 N 70 .24129232 W 148. 0'1'~4
196
End Crv 5967.96 51.03 177.70 5573.26 5638.76 934.52 -793.21 -514.12 --- 4.00 4.93 5940012.68 684768.12 N 70 .24114986 W 148. 50773471
WS2 6333.27 51.03 177.70 5803.00 5868.50 1139.23 -1077.01 -502.73 -- 0.00 5.05 5939729.25 684786.48 N 70. 24037453 W 148. 50764261
WS1 6713.32 51.03 177.70 6042.00 6107.50 1352.18 -1372.26 -490.89 --- 0.00 5.15 5939434.40 684805.58 N 70. 23956793 W 148. 50754681
CM3 7107.67 51.03 177.70 6290.00 6355.50 1573.16 -1678.63 -478.60 --- 0.00 5.23 5939128.45 684825.39 N 70. 23873095 W 148. 50744741
CM2 7894.79 51.03 177.70 6785.00 6850.50 2014.23 -2290.13 -454.06 --- 0.00 5.37 5938517.78 684864.94 N 70. 23706037 W 148. 50724904
Crv 4/100 7981.27 51.03 177.70 6839.39 6904.89 2062.69 -2357.31 -451.37 117.79R 0.00 5.38 5938450.68 684869.29 N 70 .23687683 W 148. 50722724
8000.00 50.69 178.56 6851.21 6916.71 2073.23 -2371.83 -450.90 117.25R 4.00 5.39 5938436.18 684870.12 N 70 .23683717 W 148. 50722341
8100.00 48.95 183.28 6915.75 6981.25 2131.12 -2448.18 -452.08 114.20R 4.00 5.42 5938359.83 684870.82 N 70 .23662859 W 148. 50723292
8200.00 47.41 188.23 6982.45 7047.95 2191.47 -2522.29 -459.51 110.90R 4.00 5.45 5938285.57 684865.21 N 70 .23642613 W 148. 50729286
8300.00 46.10 193.42 7050.98 7116.48 2254.01 -2593.80 -473.15 107.34R 4.00 5.49 5938213.75 684853.33 N 70 .23623077 W 148. 50740295
8400.00 45.04 198.82 7121.01 7186.51 2318.42 -2662.35 -492.93 103.56R 4.00 5.52 5938144.73 684835.24 N 70 .23604347 W 148. 50756264
WeIlDesign Ver SP 2.1 Bld( doc40x_100) 06-14\06-14\Plan 06-148\06-146 (P9) sperry Generated 1/22/2009 5:41 PM Page 1 of 2
Comments Measured
Inclination
Azimuth
Sub-Sea TVD
TVD Vertical
NS
EW Mag 1 Grav
DLS Directional
Northing
Easting
Latitude
Longitude
Depth Section Tool Face Difficulty
ft de de ft ft ft ft ft de de 700 ft Index ftUS ftUS
ifbUU .UU 44.23 ZV4.4U /lyZ.ly /Zb/. by Z3C4.Sy -Z/Z/.b3 -5 "I b.// `J,`/. b`JK 4.VU b.b4 Dy325V/i5 .t5D b254if1"I.VL N /V .L3bi5bOl3 VV 14t5 .5U///"I"Ib
8600 .00 43.71 210.11 7264.19 7329. 69 2451.59 -2789.30 -550.52 95.48R 4.00 5.57 5938016 .41 684780.79 N 70 .23569664 W 148 .50802748
8700 .00 43.47 215.91 7336.65 7402. 15 2519.71 -2847.08 -588.05 91.28R 4.00 5.60 5937957 .74 684744.70 N 70 .23553880 W 148 .50833036
8800 .00 43.53 221.72 7409.22 7474. 72 2588.41 -2900.67 -631.15 87.06R 4.00 5.62 5937903 .11 684702.92 N 70 .23539238 W 148 .50867832
CM1 8842. 50 43.64 224.18 7440.00 7505. 50 2617.69 -2922.11 -651.11 85.28R 4.00 5.64 5937881. 18 684683.50 N 70. 23533380 W 148. 50883943
8900 .00 43.88 227.49 7481.54 7547. 04 2657.35 -2949.81 -679.64 82.89R 4.00 5.65 5937852 .79 684655.67 N 70 .23525811 W 148 .50906967
9000 .00 44.52 233.15 7553.26 7618. 76 2726.19 -2994.28 -733.26 78:83R 4.00 5.67 5937807 .03 684603.16 N 70 .23513663 W 148 .50950250
9100 .00 45.43 238.66 7624.03 7689. 53 2794.61 -3033.84 -791.76 74.92R 4.00 5.70 5937766 .04 684545.65 N 70 .23502853 W 148 .50997470
9200 .00 46.59 243.98 7693.51 7759. 01 2862.27 -3068.31 -854.85 71.23R 4.00 5.72 5937730 .04 684483.43 N 70 .23493434 W 148 .51048397
9300 .00 47.99 249.08 7761.36 7826. 86 2928.84 -3097.51 -922.23 67.77R 4.00 5.75 5937699 .18 684416.80 N 70 .23485453 W 148 .51102783
9400 .00 49.61 253.95 7827.24 7892. 74 2994.00 -3121.32 -993.56 64.56R 4.00 5.77 5937673 .63 684346.08 N 70 .23478947 W 148 .5 0363
End Crv 9422 .33 50.00 255.00 7841.65 7907. 15 3008.32 -3125.88 -1009.99 --- 4.00 5.77 5937668 .66 684329.76 N 70 .23477699 W 148 .631
THRZ 9466. 43 50.00 255.00 7870.00 7935. 50 3036.52 -3134.63 -1042.62 --- 0.00 5.78 5937659. 12 684297.35 N 70. 23475309 W 148. 51199970
BHRZ 9713. 79 50.00 255.00 8029.00 8094. 50 3194.70 -3183.67 -1225.66 --- 0.00 5.80 5937605. 60 684115.59 N 70. 23461903 W 148. 51347714
LCU 9804. 02 50.00 255.00 8087.00 8152. 50 3252.40 -3201.56 -1292.42 --- 0.00 5.81 5937586. 07 684049.29 N 70. 23457013 W 148. 51401608
TJC 10049. 83 50.00 255.00 8245.00 8310. 50 3409.58 -3250.30 -1474.30 --- 0.00 5.83 5937532. 89 683868.68 N 70. 23443689 W 148. 51548420
TJB 10309. 63 50.00 255.00 8412.00 8477. 50 3575.71 -3301.81 -1666.55 --- 0.00 5.86 5937476. 67 683677.77 N 70. 23429606 W 148. 51703594
TJA 10505. 65 50.00 255.00 8538.00 8603. 50 3701.06 -3340.67 -1811.59 --- 0.00 5.87 5937434. 26 683533.73 N 70. 23418979 W 148. 51820669
TSAG 10608. 33 50.00 255.00 8604.00 8669. 50 3766.72 -3361.03 -1887.57 --- 0.00 5.88 5937412. 04 683458.29 N 70. 23413412 W 148. 51881994
7" Csg 10608. 35 50.00 255.00 8604.01 8669. 51 3766.73 -3361.03 -1887.58 --- 0.00 5.88 5937412. 03 683458.28 N 70. 23413411 W 148. 51882003
Crv 3/100 10622 .33 50.00 255.00 8613.00 8678. 50 3775.67 -3363.80 -1897.93 HS 0.00 5.88 5937409 .01 683448.00 N 70 .23412653 W 148 .51890356
TSHU 10647. 41 50.71 255.00 8629.00 8694. 50 3791.79 -3368.80 -1916.58 HS 2.83 5.89 5937403. 55 683429.48 N 70. 23411286 W 148. 51905411
10700 .00 52.20 255.00 8661.77 8727. 27 3826.12 -3379.45 -1956.31 HS 2.83 5.90 5937391 .94 683390.02 N 70 .23408375 W 148 .51937478
TSAD 10779. 08 54.44 255.00 8709.00 8774. 50 3879.06 -3395.86 -2017.56 HS 2.83 5.91 5937374. 02 683329.19 N 70. 23403887 W 148. 51986923
10800 .00 55.04 255.00 8721.08 8786. 58 3893.32 -3400.28 -2034.06 HS 2.83 5.91 5937369 .20 683312.81 N 70 .23402678 W 148 .52000241
10900 .00 57.87 255.00 8776.33 8841. 83 3962.89 -3421.85 -2114.56 HS 2.83 5.93 5937345 .66 683232.87 N 70 .23396779 W 148 .52065213
11000 .00 60.71 255.00 8827.40 8892. 90 4034.65 -3444.10 -2197.60 HS 2.83 5.95 5937321 .38 683150.41 N 70 .23390694 W 148 .52132236
42S8 11026. 05 61.44 255.00 8840.00 8905. 50 4053.68 -3450.00 -2219.62 HS 2.83 5.95 5937314. 93 683128.54 N 70. 23389080 W 148. 52150015
11100 .00 63.54 255.00 8874.15 8939. 65 4108.43 -3466.98 -2282.97 HS 2.83 5.97 5937296 .41 683065.63 N 70 .23384438 W 148 . 145
Crv 15/100 11151 .48 65.00 255.00 8896.50 8962. 00 4147.14 -3478.98 -2327.77 9.41 R 2.83 5.98 5937283 .31 683021.14 N 70 .23381155 W 148 . 02
11200 .00 72.18 256.25 8914.20 8979. 70 4184.54 -3490.18 -2371.50 8.95R 15.00 6.00 5937271 .04 682977.71 N 70 .23378092 W 148 .52 2598
TCGL 11206. 04 73.08 256.39 8916.00 8981. 50 4189.28 -3491.54 -2377.10 8.91R 15.00 6.00 5937269. 54 682972.14 N 70. 23377719 W 148. 52277116
11300 .00 87.01 258.56 8932.20 8997. 70 4264.05 -3511.52 -2467.22 8.53R 15.00 6.05 5937247 .35 682882.54 N 70 .23372252 W 148 .52349861 ',
90° Pt 11320. 15 90.00 259.00 8932.73 8998. 23 4280.09 -3515.44 -2486.98 8.52R 15.00 6.06 5937242. 95 682862.89 N 70. 23371180 W 148. 52365807 'i
End Crv 11399 .87 101.83 260.80 8924.53 8990. 03 4342.21 -3529.33 -2564.90 -- 15.00 6.10 5937227 .15 682785.33 N 70 .23367378 W 148 .52428704 ~,
Crv 4/100 12177 .96 101.83 260.80 8765.07 8830. 57 4932.28 -3651.07 -3316.68 31.48E 0.00 6.20 5937086 .98 682036.82 N 70 .23334039 W 148 .53035493
12200 .00 102.58 260.33 8760.41 8825. 91 4949.03 -3654.60 -3337.93 31.58E 4.00 6.20 5937082 .93 682015.66 N 70 .23333071 W 148 .53052647
TD 12215 .33 103.10 260.00 8757.00 8822. 50 4960.72 -3657.16 -3352.66 -- 4.00 6.20 5937080 .01 682001.00 N 70 .23332372 W 148 .53064537
Leval Description: Northing (Yl fftUSl Eastins~ (X) fftUSl
Surface : 237 FSL 1728 FEL S2 T 10N R14E UM 5940818.23 685262.56
BHL : 1859 FS L 5084 FEL S11 T10N R14E U M 5937080.01 682001.00
WeIlDesign Ver SP 2 .1 Bld( doc40x_ 100) 06-14\06-141PIan 06-14B\06-146 (P9) sperry Generated 1/22/2009 5:41 PM Page 2 of 2
by
. ~ ~ M Schlumberger
WELL FIELD STRUCTURE
DS06-14B (P9) Prudhoe Bay Unit - EOA DS-06
Magnetw Parameters 6urtace Loralan NAD2I Alaska BMIe Plates. Zone 04, US Feet Miscellaneous
MoGel'. BGGM 2008 Dip 00098° Date: Marcb 28, 2009 Lal: N]0+635961 NorMing: 894fi810.23 ftU5 GnE Conv .1 a08J5923° Slot. O6-td ND Ref'. Rdary Table (6558flabove MSLI
Ma9 DBC'. •2]84]• FS'. 5]]05.3 nT Lon. W140 J°129110 Easling. 685282.56 flUS Scale Fact. 0.9999309899 Bfi-1681P9)sperrv Srvy Dale: January 22. 21109
800 1600 2400 3200 4000 4801
4800
5600
6400
`o
0
c
7200
m
U
Cn
0
H
8000
31100
8800
9600
-..-..-..-..-..-..-.._..-..-..-..-..-..-..-y-..-..-.._..-.._.. _.. _..- -. -..-..-. ~. _.._.._.. _.._.._.._.._ _. _.. _.. _.._ ._.
,• •r•. 06-748 (P9)
6-L+4A 90° Pt
6-14
.......................i..................................i.................................. i..................................y..................................~..................................:............
4800
5600
6400
7200
8000
8800
9600
800 1600 2400 3200 4000 480(
Vertical Section (ft) Azim = 221.59°, Scale = 1(in):800(ft) Origin = 0 N/-S, 0 E/-V
• by
~ ~ Schlumberger
WELL DS06-14B (P9) FIELD Prudhoe Bay Unit - EOA 9TRUDTURE DS-06
Magnetic Parameters SuRace Location NgD2] AlasNa State Planes. Zane 04, US Feel cellaneous
Motel: BGGM 2008 Dip. 00.898° Dale rcb 25.2009 Lat. N]0 td 35941 Nortbirg: 5960818.2] flU5 GnG Cpnv: .t ao036926" Bbt. 0fi-'6 ND Re` Rotary cable Ifi550 8 above MSLI
Mag Dec'. •2286]° FS 5]]08.1 nT Lon'. Wr6A 8012900 Eastitg. 685262.56 tt1:5 Scale Fad'. 09999]89899 O6~I60 (P91 s0erry Snry Date January 22, 2009
-3600 -3000 -2400 -1800 -1200 -600
0
-600
-1200
n
n
Z
o -1800
(O
C
O)
N
In
~ -2400
v
v
v
3000
-3600
-4200
..............:...................................;..................................;..................................5................................-...................................;. ...... ~
.N Tie-In Survey
~ Top Whipstock 6-14
KOP Crv;4N 00
..............:...................................:..................................i...........-......................:-.................................:..................... ............s.... .-................... _
End Crv =
s-1a
6-14A
Crv 4N 00
.............. ~...................................-y..................................-
. - t ..................................t.............................-.....;..................................y.......
crv shoo ~.. csg
90° Pt Crv 15/100
Crv 41100 End Crv End Crv
TD
06-148 FIt 4 85105s 06-148 Flt 5 8490ss [ `
06-146 Flt 1 8916ss:
06-146 (P9)
06-146:FIt 3 BBOOss
-3600 -3000 -2400 -1800 -1200 -600
c« W Scale = 1(in):600(ft) E »>
100
200
800
400
000
600
---- -
- ~P -AIa~a _ -
i - --- -
Cumpanv: - -- _. -
BP Amoco - - -- -
Date: 1/22/2009 Time: 12;30:04 Page: 1
Field: Prudhoe Bay
1eference Site: PB!]S-Q6 Coa~oXdinate(NE) Reference: Well: 06-14, True North
Reference Well: 06-1'4 Vertical (TVD) Reference: 06-14B plan 65.5
Reference Wellpath: Plan 06-146 Db: Oracle
GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference -There are [Ef~litBoeells in thisRtiidipal Plan & PLANNED PROGRAM
.Interpolation Method: MD Interval: 5.00 ft Error Model: ISCWSA Ellipse
~eptfi Lange: _ 5006:Ofrto -t22Y5.34~ __ ---- - Scan iVLetRod: - -Tray Cylin~ridarttr
Maximum Radius: 1418.68 ft Error Surface: Ellipse + Casing
Survey Program for Definitive Wellpath
Date: 8/6/2008 Validated: No Version: 1
~, Plannedlironv- Tom- c,.rvey-- ---
- _.--Toolcede- --- ----TooLName- -__---
ft ft
97.50.--_.-5000.00 06-14 Srvy 1 CB GYRQMS X7.50 __-.._ - CB GYRO-MS.__ ___ Camera based g ry o multishot ___ __
5000.00 8608.00 Planned: plan 06-14 Wp 9.0 V21 MWD+IFR+MS MWD +IFR + Multi Station
', 8608.00 12215.34 Planned: plan 06-14 Wp 9.0 V21 MWD+IFR+MS MWD +IFR + Multi Station
Casing Points
- -- - -
- --- - -
- ---- -
-_----
-
-
-NID TVD Diameter -. Hele Size- ---- -Name-
- -
- _
-
-
ft ft in in
2682.50 2682.50 13.375 17.500 13 3/8"
~, 5500.00 5310.20 9.625 12.250 9 5/8"
'~ 10608.33 8669.50 7.000 8.500 7"
' r.
.. -
-- _--- - _ _ - -- -- ~
Summary
<~-------- __--- Offset ~Yellpath - -> Reference `Offset Ctr-Ctr No-Go Allowable
Site Well Wellpath ~MD MD Distance Area Deviation Warning
-
-
----- {~ -
- - -ft
ft
ft
ft i
PB DS 06 06-06 06-06B V8 10781 18 11305.00 172.67 171.60 1.07 Pass: Major Risk ~,
RB DS 06_ _. -_ - 06-OFr -- -06-066PB~ X10-- - 11072.48 'I15E3-1.00- 164-.3~- 'F88:02 --23-05 - FAIL:-MejefRisl~----~I
PB DS 06 06-11 06-11 V10 5029.88 5035.00 613.41 105.58 507.83 Pass: Major Risk
PB DS 06 06-12 06-12 V9 6442.04 6155.00 254.67 84.12 170.55 Pass: Major Risk ,
PB DS 06 06-12 06-12A V6 6442.04 6155.00 254.67 84.24 170.43 Pass: Major Risk
PB DS 06 06-13 06-13 V2 1221602---88~~34 -4-500 F
425
~'IE~
Out of range
PB DS 06-_ _- __ 06-13__ _________ _ 06-13A V3_ - 7381 _9__8 7485.00 1274.96 _1.36.9.1- 1138..06 Pass_ Major Risk_
PB DS 06 06-13 06-13AP61 V13 7381.98 7485.00 1274.96 136.91 1138.06 Pass: Major Risk
PB DS 06 06-14 06-14 V2 5032.47 5035.00 1.00 153.27 -152.28 FAIL: Major Risk
PB-DS-06 - -X36-14 - -06-'F4AA{1 - 5032.47 - 503x00-=X001-5-3~~-152.28- --FR1~: Major-Risl~
PB DS 06 06-15 06-15 V1 5000.11 5225.00 554.09 108.18 445.91 Pass: Major Risk
PB DS 06 06-16 06-16 V1 5000.39 5200.00 555.12 103.34 451.78 Pass: Maior Risk
PB DS 06
~ PB DS 06
PB DS 06
PB DS 06
--PB DS 06
', PB DS 06
PB DS 13
', PB DS 13
PB DS 14
PB DS 14
06-16 Plan 06-16A V0 Plan: 0 5001.73 5200.00 556.24 103.34 452.90
06-17 06-17 V11 8546.65 8245.00 812.98 430.15 382.83
06-21 06-21 V5 7998.80 5480.00 855.16 129.28 725.88
06-21 06-21A V6 7998.80 5480.00 855.16 129.28 725.88
--06 21- 06-2?B-V-3- - 5002.57- 545-00 8-5-5$5 97-:35 _ 758:49
06-25 Plan 06-25 Plan V1 Plan: 06 11227.71 10075.00 242.42 168.84 73.58
13-09 Plan 13-09A VO Plan: 1 8844.45 11370.00 577.26 205.12 372.14
---T3=iT- 13=1TV1- -- _ -T06fi4.Z0 T063U-00 19531 666~4T_ =467:56
13-28 Plan 13-28A V1 Plan: 1 8904.10 13140.00 123.88 374.11 -250.23
- 13-33- ---_- -_- Plan 13-33A VO.P~an: 1 8463.32 ..1.0845.00__ 289.92- 215.22 74.70
14-02 14-02C V28
14-14 14-14 V2 12123.03 12000.00 811.69 296.43 515.26
Pass: Major Risk
Pass: Major Risk
Pass: Major Risk
Pass: Maior Risk
Pass: Major Risk
Pass: Major Risk
FAIL: Maior Risk
Out of range
Pass: Major Risk
From KOP to TD
~~ Scan interval 100 ft
_ -Scale-fi:1fJ0- _ _ _ ---
Risk Base 1:200 - 06-06BPB1 and B, also
-~- - --- 13=47-~2~A-fWP4) _---
tgo- -
Travelling Cylinder Azimuth ('CF(}FAZI) [deg vs Centre to Cen[re Separation [ 100Ninf
- - fiarget~6~~ ~~
- -
• _
~~te PB-D~O~ -- - - -- _ ~i-f4 --- - -
Drilling-Target ~onl:. g5
B on: Planne T~gram -- - -- -
escnphon: enc~a ept a ow can ea eve
- Map Northing: 5937409:00 ft Local +N7=S: =7363:87 -
_ _ _- __ - _ -- --_ ap. ast~ng: -- __- - _---- - - - _ -- oea - ' - - - - _ -- -___- - --
atitu e: ongitu e:
go ygon
~ ~ $ eft ~p E f't ~GIap~T~- - -----
~ - - - -- ~3~3~- -- -- -- _150:12 - -- - 6834g5~~ - -_ _ 3g~7260:0~ -
2 -1559.89 -460.83 681900.00 5936910.00
- - - 3 _ _ _ _ - -- -- - t6f1L-65-- -- - - - -- - r~~68--- - -- - - 68Ifi5fL00- _ _ --593-7245:00 - - - --- ---
- - - ~ 8~'~ 75~~ _ 683~5~60 5937483:00
~-
~~
~ ~ ~ 0 ~ ~ 0 ~
~- - ~- --Q-- - Q -- -0 - ---- ~ -- - 0- ~- - -
l~ ~ 0 ~ ~ ~ ~
wITH/N
O s2an
T
R
f 4 E
_
'
.
.
.,
UA4AT MERIDIAN, ~,.
' y
`
j
ALASKA r ,
4
s - 'ti•~.
`
~
2'~0 7M/s
O 1 230 ~ ~y
O 2 220 ~ ~
~6• 03 21Q ,.; ~'
O ~ 2~0 ~,
17
, OS 190
1
6
13• O Is0
12• 0~ 1~0
NOTES
--•
-o~
9~
PAD 3
CELL ~j L
2
WELL A.S.P. COO NDNATES GEODETIC POSITIQN
No•
NIORTF~/~G
EASThIG
LATITUpE
LOiMpTtJgE PLANT COOS LOCHTpN NV SECTNON
s s,94o,Za4.4a itk1.40/.! 1b•F4•J0.107• 14!•~'a.ZZY s I7M9.9~ / E atl.4D ~• iN. / 1~4• tEi. sEC ,
to s.s4o,asl.ae e•s.m.71 70•I4•JI.~f• 14!•~•IO.00, s /Q4l.t~i / E JI!'J.1M Zsl' Flrt. / Isss• Fr:L SEC -
11 s.190.4i7.9f !»,J4i.>ef 7n• 14'dt.47i' MI •~' 10.717 s 18!!. ~ / E JZa. x I l s' F'1~t / 1!s' 4' F>:t ~ 1 f
I! s,l40~dN.41 6lf~slt.l0 70.11'?J.0' MO•JD'II.bO S 1410.10 / E ~.g '' it / /iJ!' /EL ~
13 s~l40~7b1.40 ~~lDO./i 7b•14'34.7M• tN•JO'fZ.lral : ItM.~ / E J~.07 tm' it / 17W' f41 SEC
14 s,~10,111.A MS~Ht.st TO.14'~.lN• IM•JO'IZ.D00 ! IIM.77 / E ~.SI ?,.1f' ri / 17Zf' fB. ~
/s s.9~0,A1~.7~ ~!~>Z34.~ 7b•J4'37.QM• 14f•~'l~.ll S IOM.>f0 / E x.7.~ Jrl~' Fi / 17:1.1' I~E1. JR+C
l6 s,941,Q41.M M~'i~>sOi.O 70•I4'JA.PN•
~~ ~ ~
..
..: •:
s P~ ,•,,.
'• ~
~''~ '
•
• tansrrMS MEtL
A.~eu-Lr THIS stxrvEY
-
- r1EREf3Y CERT~Y THAT 1 a~J PROPERLY
• c
f?E s~S F"ERES3 Alm LICENSED TO PRAC• i *
~
r~ t~l~ suRVr:Yr~ rv r~lE srA TE ~.... , ... _ ..... ,*,
' ¢ ;
R08ER T BEL L d ASSOCIA TES
AL.4 SICA APD THAT THIS PUT /
tAF ,
ffiEr'R£SETlTS' AN AS-BtJ~.T SU1tVEY f .~ --^""
n~aL~E QY ME oR ~R MY aRECr ~.~; • ... •.,.. 4
' AACO A~ O
5Lfi£RY15r~1 Alm THAT ALL 0!MIENSJOI~ ~, ~
~
~6 •
~
67
A/~ EtTt~k7i DETA~S ARE CORRECT
;~
~.•' ,,
AS OFD DEC. 8, 1989 ~~'~r~''•. ~'
.
~
~~;
~ WELLtt4EEA0 AS-BtJ~LTS
``
Y DRILL SITE 6 -WELLS 9-16
r~
~~' 12/07/89 HTCH ~ ~
o -2/O -sst~v FoR l~s'oRw T10N >~rr s5 ND~ tOALS' K rs •'~'•
~,- s 0
~A
a-tE REVISIgrS t~ p« N
OP 0000 3~oo-ao
Kt3. tLtV =
BF. ELEV =
KOP=
Max Angle = @
Datum MD =_
Datum T`JD =
Proposed 06-146Q
13-3/8" CSG, 72#, BTC, N-80, ID = 12.347" ~--~ Z,6t35' ~ ---.
Top Of Cement 3,000'
Minimum ID = 3.725" @ tbd
4-1 /2" XN NIPPLE
EZ S V 5, 000'
~9-5/8" CSG, 47#, L-80, ID = 8.681" ~
---- 2,200' 4-1/2" X-NIP, ID = 3.813"
GAS LIFT MANDRELS
ST MD TVD DEV TYPE VLV LATCH PORT DATE
5
4
3
2
1
4,850' 9-5/8" x 7" Baker Liner Packer
14-1/2" X-NIP, ID = 3.813"
10,378' H7" x 4-1/2" S3 Packer
tbd 4-1/2" X-NIP, ID = 3.813"
tbd 4-1/2" XN-NIP, iD = 3.?25"
14-1/2" CSG, 12.6#. 13CR VAMTOP. ID = 3.958" 1
PERFORATION SUMMARY
REF LOG:
ANGLE AT TOP PERF:
Note: Refer to Production DB for historical perf data
SIZE SPF INTERVAL Opn/Sqz DATE
4-1/2" CSG, 12.6#, 13CR VAMTOP, ID = 3.958" 12,216'
~WLEG I
7" x 5" ZXP w / 10" TBS Hanger
17" CSG. 26#, BTC-M, ID = 6.276"
DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT
ORIGINAL COMPLETION WELL:
PERMfT No:
API No:
BP Exploration (Alaska)
WELLHEAD = FMC
ACTUATOR = OTIS
i{B. ELEV = 68'
BF. ELEV = ?
KOP = 4200'
Max Angle = 45 @ 9294'
Datum MD = 9759'
Datum TVD = 8800' SS
Pre-F~g 06.14A
NOTES: ***CHROM E TBG 8~ CHROM E LNR*""
--~ 31' ~~ 5-1 /2" X 4-1 /2" XO, ID = 3.938"
® 2195' 4-1/2" CAM BAL-O SVLN SSSV NIP, ID = 3.813"
5-112" TBG, 17#, 13-CR-80, 31'
.0232 bpf, ID = 4.892"
TOP OF 4-1 /2" TBG 31'
13-3/8" CSG, 72#, N-80, ID = 12.347" 2685'
Minimum ID = 3.725" @ 9395'
4-1 /2" OTIS XN NIPPLE
TOP OF 7" LNR 8277'
9-5/8" CSG, 47#, L-80, ID = 8.681" 8552'
TOP OF CEMENT
7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 9052'
TOP OF 7" LNR 9052'
1/2" TBG, 12.6#, 13-CR-80, .0152 bpf, ID = 3.958" ~ 9408'
PERFORATION SUMMARY
REF LOG: BHCS ON 06/25/92
ANGLE AT TOP PERF: 40 @ 9741'
Note: Refer to Production DB for historical pert data
SIZE SPF INTERVAL Opn/Sqz DATE
2-7/8" 6 9741 - 9746 C 4/4/2004
2-1/8" 1 9760 - 9770 S 04/08/95
2-7/8" 6 9760 - 9770 C 02/04/04
2-1/8" 4 9770 - 9775 S 04/08/95
2-7/8" 6 9770 - 9780 C 01/13/04
2-1/8" 4 9777 - 9786 S 04/08/95
2-7/8" 6 9778 - 9796 C 06/28/03
3-3/8" 4 9786 - 9796 C 04/17/95
2-1/8" 4 9805 - 9815 C 04/17/95
3-3/8" 4 9818 - 9828 C 04/17/95
3-3/8" 6 9848 - 9858 C 03/17/96
GAS LIFT MANDRELS
ST MD TVD DEV TYPE VLV LATCH PORT DATE
1 3000 3000 0 TE-TGPDX DOME RK 16 04/10/95
2 4798 4746 35 TE-TGPDX DOME RK 16 04/10/95
3 6632 6252 34 TE-TGPDX DMY RK 0 04/04/95
4 7698 7156 29 T~TGPDX DMY TG 0 07/03/92
5 8116 7526 27 TE-TGPDX DMY TG 0 07/03/92
X 7" BAKER LNR PKR, ID = 6.187"
PBTD
7" LNR, 26#, 13-CR-80, .0383 bpf, ID = 6.276"
TD
~4-1/2" TBG TAIL, ID = 3.958" ~
9397' ELMD TT LOGGED 07/01/92
9952' 11/16" BTM NOSE
OF TOOL STRING
LOST ON 05/07/93
I 9975' I
I 10040' I
DATE REV BY COMMENTS DATE REV BY COMMENTS
06/21/80 ORIGINAL COMPLETION
07/03/92 LAST WORKOVER
09/23/05 MOR/TLH XX TTP SET (09/14/05)
04/15/08 KSB/TLH TTP PULLED (04/05/08)
11/21/08 BSElTLH PXN PLUG SET (10/20/08)
PRUDHOE BAY UNIT
WELL: 06-14A
PERMIT No: 1920570
API No: 50-029-20458-01
SEC 2, T10N, R14~ 4479.65' FEL ~ 1416.77' FNL
BP Exploration (Alaska)
,OOU. ~-1Tubing Cut ~
9285' 4-1/2" OTIS X NIP, ID = 3.813"
9352' 7" X 4-1 /2" OTIS MHR PKR, ID = 3.875"
9377' 4-1/2" OTIS X NIP, ID = 3.813"
9395' 4-1/2" OTIS XN NIP, ID = 3.725"
WELLHEAD = FMC
ACTUATOR = OTIS
KB. ELEV = 68'
BF. ELEV = ?
KOP = 4200'
Max Angle = 45 @ 9294'
Datum MO = 9759'
Datum TV D = 8800' SS
Current 06-14A
5-1/2" TBG, 17#, 13-CR-80, 31'
.0232 bpf, ID = 4.892"
TOP OF 4-1 /2" TBG 31'
13-3/8" CSG, 72#, N-80, ID = 12.347" 2685'
Minimum ID = 3.725" @ 9395'
4-1 /2" OTIS XN NIPPLE
TOP OF 7" LNR 8277'
9-5/8" CSG, 47#, L-80, ID = 8.681" 8552'
TOP OF CEMENT 8557'
NOTES: ""*CHROM E TBG 8~ CHROM E LNR"*"
31~--) 5-1 /2" X 4-1 /2" XO, ID = 3.938" I
2195' 4-1/2" CAM BAL-O SVLN SSSV NIP, ID = 3.813"
GAS LIFT MANDRELS
ST MD TVD DEV TYPE VLV LATCH PORT DATE
1 3000 3000 0 TE-TGPDX DOME RK 16 04/10/95
2 4798 4746 35 TE-TGPDX DOME RK 16 04/10/95
3 6632 6252 34 TE-TGPDX DMY RK 0 04/04/95
4 7698 7156 29 TETGPOX DMY TG 0 07/03/92
5 8116 7526 27 TE-TGPDX DMY TG 0 07/03/92
6 8232 7630 26 T~TGPDX SO RK 16 05/03/95
8273' 9-5/8" X 7" BAKER LNR PKR, ID = 6.187"
9285' ~-~ 4-1/2" OTIS X NIP, ID = 3.813"
7" LNR 26#, L-80, .0383 bpf, ID = 6.276" 9052'
TOP OF 7" LNR 9052'
4-112" TBG, 12.6#, 13-CR-80, .0152 bpf, ID = 3.958"
PERFORATION SUMMARY
REF LOG: BHCS ON 06/25/92
ANGLE AT TOP PERF: 40 @ 9741'
Note: Refer to Production DB for historical pert data
SIZE SPF INTERVAL Opn/Sqz DATE
2-7/8" 6 9741 - 9746 C 4/4/2004
2-1/8" 1 9760 - 9770 S 04/08/95
2-7/8" 6 9760 - 9770 C 02/04/04
2-1/8" 4 9770 - 9775 S 04/08/95
2-7/8" 6 9770 - 9780 C 01/13/04
2-1/8" 4 9777 - 9786 S 04/08/95
2-7/8" 6 9778 - 9796 C 06/28/03
3-3/8" 4 9786 - 9796 C 04/17/95
2-1/8" 4 9805 - 9815 C 04/17/95
3-3/8" 4 9818 - 9828 C 04/17/95
3-3/8" 6 9848 - 9858 C 03/17/96
PBTD
7" LNR, 26#, 13-CR-80, .0383 bpf, ID = 6.276"
( ~ 1
9352' ~--( 7" X 4-1 /2" OTIS MHR PKR, ID = 3.875"
9377' --14-1/2" OTIS X NIP, ID = 3.813" I
9395' 4-1 /2" OT1S XN NIP, ID = 3.725"
9395' 4-1/2" PXN PLUG (10/20/08)
9408' 4-1/2" TBG TAIL, ID = 3.958"
9756' I-~ IBP (04/04/04) I
9397' ELMD TT LOGGED 07/01/92
9952' 11/16" BTM NOSE
OF TOOL STRING
LOST ON 05/07/93
9975'
10020'
10040'
DATE REV BY COMMENTS DATE REV BY COMMENTS
06/21/80 ORIGINAL COMPLETION
07/03/92 LAST WORKOVER
09/23/05 MOR/TLH XX TTP SET (09/14/05)
04/15/08 KSB/TLH TTP PULLED (04/05/08)
11/21/08 BSE/TLH PXN PLUG SET (10/20/08)
PRUDHOE BAY UNff
WELL: 06-14A
PERMff No: 1920570
API No: 50-029-20458-01
SEC 2, T10N, R14E, 4479.65' FEL & 1416.77' FNL
BP Exploration (Alaska)
Alaska Department of Natural Resources Land Administration System ~ Page 1 of 2
•
l~l~tura R~~~r~s
~~~ ,: s'. ~ `..~;- ~.r3CC1 ..,~vt .~I ii~IS ~~' .. .C;(;tJC~~'(S ~°ai"Cf"t 5~8t@ ~r']~.11I15
Alaska DNR Case Summary
File Type ADL File Number: 28311 ~ Printable Case File_Summary
See Township, Range, Section and Acreage? New search
~` Yes No _.___~__.__..~___~ __._
LA.~a A11er== ~ Case Abstract ~ Case Detail ~ Land Abstract
..
Fi/c: ADL ?8311 '''~'s'_~ Search for Status Plat Updates
~ti OI Ol /' ii200~)
Customer: 000]07377 BP EXPLORATION (ALASKA) INC
PO BOX 1 966 1 2/900 E. BENSON BL ATTN: LAND MANAGER-
ALASKA
ANCHORAGE AK 995196612
Case Zype: 784 OIL & GAS LEASE COMP DNR Unit. 780 OIL AND GAS
File Location: DOG DIV OIL AND GAS
Case Status: 35 ISSUED Status Date: 08/19/]965
Total Acres: 2560.000 Date h~ritiated: 05/28/1965
Office of Primary Responsibilil~~: DOG DIV OIL AND GAS
Last Transaction Date: 12/04/2006 Case Subtype: NS NORTH SLOPE
Last Transaction: AA-NRB ASSIGNMENT APPROVED
Meridian: U Township: OION Rc~rrge: 014E`' Section: O1 Section Acres: 640. Search
Plats
tlleridian: U Tr~tivnshii?: O1 ON Raja,ge: 014E .~'ectin~r.~ U~ Section ~I crc~.~ _ fibO
Nleridicm: U luivnshi/~: OIUN Rn>2ge: U14E Srctiuir.~ 1 I ,Section Acre~~.~ 640
t~leridian: U 7nwnshi~: O1ON Range: 01.4E 5~~~~tic~t~.~ 12 Section Acres: 640
Legal Description.
03-25-1963 '~ * *SALF, ~'VOTICE LEGAL D~SCRIPTION*
C14-13210N 14E U,~1 I, 2,11,12.2560.00 U- 3- 7
~ Ll3 11"
Last updated on 01/27/2009.
http://dnr.alaska.gov/projects/las/Case_Summary.cfm?FileType=ADL&FileNumber=2831... 1 /27/2009
•
TRANSMITTAL LETTER CHECKLIST
WELL NAME ~/S°~ O6'~~3
PTD# ~~90~~
Development Service Exploratory Stratigraphic Test
Non-Conventional Well
FIELD: /~i~L/Q~OE ~'i4y POOL: ~,E'l//~•5~0~ ~y O~
Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter
CHECK ADD-ONS
W~.I. (OPTIONS) TEXT FOR APPROVAL LETTER
APPLIES
MULTI LATERAL The permit is for a new wellbore segment of existing
well ,
(If last two digits in permit No. ,API No. 50- - -
API number are
between 60-69)
Production should continue to be reported as a function of the
original API number stated above.
PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs
acquired for the pilot hole must be clearly differentiated in both
well name ( PH) and API number
(50- - -_~ from records, data and logs
acquired for well
SPACING The permit is approved subject to full compliance with 20 AAC
EXCEPTION 25.055. Approval to perforate and produce /inject is contingent
upon issuance of a conservation order approving a spacing
exception. assumes the
liability of any protest to the spacing exception that may occur.
DRY DITCH All dry ditch sample sets submitted to the Commission must be in
SAMPLE no greater than 30' sample intervals from below the permafrost or
from where samples are first caught and 10' sample intervals
throu h tar et zones.
Non-Conventional please note the following special .condition of this permit:
Well production or production testing of coal bed methane is not allowed
for (name of well) until after (Company Name) has designed and
implemented a water well testing program to provide baseline data
on water quality and quantity. (Company Name) must contact the
Commission to obtain advance approval of such water well testing
ro ram.
Rev: I! 11 /2008
WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL -640150..- _ Well Name: PRUDHOE BAY UNIT 06-14__B___ ______Program DEV ____ ___ _ Well bore seg ',
PTD#:2090120 Comp any BP E.X_PLORATION_(ALASI(A~ INC _ - __ __- _ Initial Class/Type DEVI PEND__GeoArea $90___ ____ __ _ _ Unit 11650 _ On10ff Shore On__ ____ Annular Disposal '_J
Administration ',1 .Permit fee attached. - NA-
'2 Lease number appropriate _ _ _ _ _ _ Yes - - - - - - _
13 .Unique weq name and number _ _ _ - _ - - - - - - - Yes _
4 Well located in-a-defined pool Yes
~~5 Well located proper distance from drilling unit_boundary_ - Yes - - -
~,6 Well located proper distance from other wells- - Y_es - -
',7 Sufficient acreage"available in-drilling unit- - - - - - Yes -
8 If-deviated, is. wellbore plat included Yes
',9 Operator only affected party_ - _ _ - - _ - " _ Yes - _ _ -
10 Operator has appropriate"Oond in force - - _ _ - - - - - - - - Yes - - - - -Blanket Bond.#6194.193.- - -
11 Permit can be issued without conservation order- - - _ _ - _ " " " . Yes _ . .
Appr Date ' 12 Permit. can be issued without administrative-approval - - - - Yes - - -
_.. ._
13 Can permit be approved before 15-day wait. Yes - -
ACS 1!271200 9
;14
Well located within area and_strataauthorized by Injection Order# (put 10# in_comments)-(For
NA
15 All wells within 114 mile area_of review identified (For service well only)" NA- - - - - - -
16 Pre-produced injector; duration-of pre-production less than 3 months (Fgr sevice well only) NA - - - - - - - - - - -
',17 Nonconven, gas conforms to AS31.05,030(1.1-.A),(j.2.A-D) - - - - NA. "
j -
18 --- _- -- - - -
Conductor string_p_rovided
NA-
Conductor satin D$ 06-14 (180-031")._
Engineering i19 Surface casingprotectsall-known USDWs NA N4 aquifers, A104B, conclusion 5,
X20 -CMT vol adequate to circulate-on conductor & surf csg NA - - Surface casing set in. D$ 06-14..
!21 CMT vol adeguate_to tie-in-long string to surf csg- - - NA. Production-casing set in-DS 06-14, New 7" liner fully-cemented..
22 .CMT will coverall known-productive horizons. _ _ Yes - - - _
',23 Casing designs adequate for C,-T, B &"permafrost.... " Yes - - -
24 Adequate-tankage_or reserve pit Yes Rig equipped with steel pits. No reserve pit plann_ed._ All waste-to approved disposal well(s):.. .
'25 If a re-drill, has. a 10-403 for abandonment been approved - Yes - - - 309-117 " - - . " " . -
'26 Adequate wellbore separation_proposed- - - - - - - - - - - - Yes - - - - -Proximity analysis performed. Traveling cylinder path calculated...
'27 Jf diverter required, does it meet regulations_ - - - - - NA- - - BOP st_ackwill already_be in place. -
Appr Date ,28 Drilling fluid. program schematic_& equip list adequate- - - Yes . Maximum expected formation pressure 7,3-EMW, MW planned up to 10.7 ppg in 8.5" hole and-8.5 ppg in zone.
29
TEM 1!27/2009
BOPEs, do they meet regulation
Yes -
- - - -
/
~
~ 30 BOPE press rating appropriate; test to-(put prig in comments) Yes - MASP calculated at 2516psi. 3500-psi ram test planned.-
~
.
d
,
~ 31 -Choke manifold complies w/APt RP-53 (May 84) Yes _ _
"
~
/,
~
~j 32 Work will occur without-operation shutdown- - Yes -
',33 Is presence. of H2S gas. probable- - - - Yes H2S is known at l)S 06.-Mud should preclude H2S-on rig, Rig has sensors and alarms...... -
34 Mechanical condition of wells within AOR verified (For service well only) NA-
-___ _
35
Permit can be issued wlo hydrogen sulfide measures
No
Max level H2$ on Pad 250ppm 1/9/04; well 06-13A=10ppm_(3/20108);well 06-066=10ppm-(3131/08)
Geology
36
Data. presented on_ potential overpressure zones
NA-
-------
Appr Date 37 Seismic analysis of shallow gas-zones- NA
ACS 1/27/2009 '38 Seabed condition survey (ifoff-shore) NA
39 Contact name/pho_ne forweekly_progress reports (exploratory only]- - Yes - - " " . _ Zach Sayers-_564-5790; Brandon Peltier- 564-5912, " "
Geologic Engineering Public
Commissioner: Date: Com fission r: Date Commissioner Date
